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Home My WebLink About185-015MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-10 MILNE PT UNIT C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 C-10 50-029-21278-00-00 185-015-0 G SPT 6913 1850150 1728 3448 3450 3449 3445 30 34 34 34 4YRTST P Brian Bixby 8/19/2024 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:MILNE PT UNIT C-10 Inspection Date: Tubing OA Packer Depth 691 2036 1994 1987IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240820132220 BBL Pumped:2.7 BBL Returned:2.7 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 10:40:43 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, August 17, 2020 �,, P.I. Supervisor `C�`� g1gz'j� SUBJECT: Mechanical Integrity Tests Hilcoip Alaska, LLC C-10 FROM: Bob Noble MILNE PT UNIT C-10 Petroleum Inspector Well Name MILNE PT UNIT C-10 Insp Num: mitRCN200811125806 Rel Insp Num: Src: Inspector Reviewed By: P.1. Supry NON -CONFIDENTIAL Comm API Well Number 50-029-21278-00-00 Inspector Name: Bob Noble Permit Number: 185-015-0 Inspection Date: 8/10/2020 Monday, August 17, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --- -- Well C-10 Type Ind G 'TVD 6913 I Tubing'. 4397 - 4398 4384 4389 - -- PTD 1850150 Type Test SPT I'Test psi 1728 IA 63 1940 1900 1884 ' BBL Pumped: 1.4 BBL Returned: 1.3 OA 4 - 4 5 - 4 - Interval - 4vRTST — P/F'- P -✓ — Notes: Monday, August 17, 2020 Page 1 of 1 DATE 10/04/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 MPU C-10 185-015) Halliburton INJECTION PROFILE 19 AUG 2019 CD 1: Ti MPU_C-10i_fPROF_19AUG19 9/13/20191:35 PM PDF Docu MPU_C-10i_IPROF_19AUG19_DN40 9/13/.20191:37 PM LAS Fife MPU _C -10i IPROF_19AUG19_DN80 9!13.120191:37 PM LAS Fife C O MPU_-10i_[PROF_19AUG19_img 9/13/20191:36 PM TIFF Fife J� MPU_C-10i_IPROF_19AUG19 POOH 9/13/20191:37 PM LAS Fife MPU_C-10i_IPROF_19AUG19_RfH 9/13/20191:37 PM IAS File MPU_C-10i_IPROF_19AUG19 SS7880 9113/20191:36 PM LAS Fife ,;j MPU_C-10i_IPROF_19AUG19_SS7960 9/13/20191:36 PM LAS Fife 2 MPU_C-10i_IPROF_19AUG19_S58 M 9/1112019 1:36 PM LAS File C 3 MPU_-10i_[PROF_19AUG19 SS8100 9/13/20191:36 PN1 LAS Fife MPU_C-10i_IPROF_19AUG19 SSR240 9/13/20191:36 PM LAS File 7z MPU_C-10i_IPROF_19AUG19 SS8300 9/13/20191:36 PM LAS File MPU_C-10i_€PROF_19AUG19_UP40 9113/20191:36 PM LAS File MPU_C-10i_IPROF_19AUG19_UP80 9/13/20191:36 PM LAS Fife MPU_C-10i_IPROF_19AUG19_UP120 9/13/20191:36 PM LAS Fife Please include current contact information if different from above. 1850 1s 31295 'DECEIVED OCT 0 4 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 07,2016 TO: Jim Regg P.I.Supervisor 'fe Ci(i(v(i(f, 1 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C-10 FROM: Chuck Scheve MILNE PT UNIT KR C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry, — NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-10 API Well Number 50-029-21278-00-00 Inspector Name: Chuck Scheve Permit Number: 185-015-0 Inspection Date: 9/4/2016 Insp Num: mitCS160906110650 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-10 - Type Inj W 'TVD 6913 - Tubing 3335 "I 3335 , 3334 - 3333 - PTD 1850150 ' Type Test SPT Test psi 1728 - IA 912 2431 - 2404 - 2415 - Interval 4YRTST PAF P ✓ OA 467 610 - 595 593 - Notes: ------------ -------- SCANNED JUN 2 0 2017 Wednesday,September 07,2016 Page 1 of 1 PTO 186 -015 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 1`Cfei 011Z. Sent: Sunday, January 29, 2012 4:16 PM To: AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Well Ops Coord; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M Subject: OPERABLE: Injector MPC -10 (PTD 1850150) IA Pressure Stable Attachments: MPC -10 TIO Plot 01- 29- 12.doc; MIT MPU MPC -10 01- 05- 12.xls All, WAG Injector MPC -10 (PTD #1850150) passed an MIT -IA to 3000 psi on 01/05/2012 confirming two competent barriers in the wellbore. A Packoff Test on the tubing hanger was also performed on 01/05/2012. The lockdown screws were re- torqugd during the Packoff Test in order to re- energize the primary seal. The IA pressure has been monitored over the last two weeks and has been stable as exhibited in the attached TIO Plot. The repressurization has been mitigated indicating that the communication was through the wellhead. The well is reclassified to Operable and can be placed on injection. An updated TIO plot and MIT form are attached for reference: «MPC -10 TIO Plot 01- 29- 12.doc» «MIT MPU MPC -10 01- 05- 12.xls» ✓ Thank you, Mehreen Vazir (Alternate. Gerald rllurp /ry'I Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 z 1i` Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, December 25, 2011 7:42 PM To: AK, D &C Well Integrity Coordinator; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, •: C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Well Ops Coord Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M (Northern Solutions); LeBaron, Mi •:el 3; 'Scott.McEntyre @bp.com' Subject: UNDER EVALUATION: Injector MPC -10 (PTD 1850150) IA Repressurization After Bleed All, WAG Injector MPC -10 (PTD #1850150) exhibited IA repressurizat after a bleed. The IA pressure was bled on 12/24/11 from 1750 psi to 500 psi. The overnight monitor indicated that t - IA pressure had increased 1040 psi overnight while shut it. This well is being reclassified as Under Evaluation. Pleas- eave the well shut in until further diagnostics can be performed to confirm two competent barriers in the wellb. °-. 1 MPU C -10 PTD #1850150 1/29/2012 TIO Pressures Plot Well. MPC -10 1 4,000 i • 1 3,000 - I I f Thy —M—IA 2,W0- 00A I —.— 000A — On I I I 1 i i i i I Loon I I ` I I i 10/29/11 11/05/11 11/12/11 11/19/11 11/26/11 12/03/11 12/10/11 12/17/11 • 12/24/11 12/31/11 01/07/12 01/14)12 01/21/12, 01 /26/12 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reocaalaska.gov; doa. aoacc.prudhoe.bav(rDalaska.gov; phoebe.brooksealaska.aov; tom.maunderaialaska.00v OPERATOR: BP Exploration (Alaska), Inc. �,' t 1(56 I 1--- FIELD / UNIT / PAD: Milne Point/ MPU/ C -Pad DATE: 01/05/12 OPERATOR REP: Jeff Rea AOGCC REP: Not Witnessed Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPC -10 ' Type Inj. N ' TVD ' 6,913' Tubing 3450 3450 3450 3450 Interval 0 P.T.D. 1850150 ' Type test P Test psi 1728.25 Casing 1040 3020 - 2906 2881' P/F P Notes: MIT -IA for TxIA communication diagnostics OA 2.3 bbls 60/40 methanol pumped to reach test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE 1NJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Vanance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPU MPC - 10 01 - 05 - 12 Monthly Injection Report for GP•GPMA, Northstar, Milne Point & Endie for Decem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Tuesday, January 17, 2012 8:52 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for December 2011 Attachments: AOGCC Inj Report 01- 12.ZIP Tom, Jim, Phoebe, and Guy, Attached is the December 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 01- 12.ZIP>> Notes on wells: 5 idittitiED FEE (,f 3 niZ Added to Report: NGI- • #1770800) Under evaluation for IA repressurization. MPC -10 (PTD #18 1 150) nder evaluation for IA repressurization. Taken off Report: 16 -05A (PTD #2010100) Economic evaluation completed and well returned to Not Operable status. NGI -03 (PTD #1750610) Under Evaluation for IA repressurization in October 2011. No repressurization observed post SSSV change out WGI -03 (PTD #1790490) AA 4E.027 for TxIA communication cancelled post RWO. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1/31/2012 Well MPC -10 Injection Plot TIO Plot Well: MPC -10 °o Pressure vs. Rate o PTD #: 1850150 0 0 o - Tbg IA Under Evaluation for IA - OA repressurization a a '''' Yom• u • • • • • • • • ••• o _ .. rn •• •r• I.& M rn v a. a_ 0 x o • i o 0 °o N • N • Last 90 days • Last Month r o • � , o - 0 500 1,000 1,500 2,000 2,500 3,000 3,500 8/2/11 10/23/11 1/13/12 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/12 0 0 01/01/12 0 840 0 01/01/12 0 0 12/31/11 0 840 0 12/31/11 0 0 12/30/11 0 800 0 12/31/11 0 0 12/29/11 0 800 0 12/30/11 0 0 12/28/11 0 800 0 12/30/11 0 0 12/27/11 0 710 0 12/29/11 0 0 12/26/11 0 600 0 12/29/11 0 0 12/25/11 0 500 0 12/28/11 0 0 12/24/11 0 1,760 0 12/28/11 0 0 12/23/11 0 1,680 0 12/27/11 0 0 12/22/11 0 560 0 12/27/11 0 0 12/21/11 0 560 0 12/26/11 0 0 12/20/11 3,733 520 0 12/26/11 0 0 12/19/11 3,748 800 0 12/25/11 0 0 12/18/11 3,711 820 0 12/25/11 0 0 12/17/11 3,696 780 0 • 12/24/11 0 0 12/16/11 3,662 860 0 12/24/11 0 0 12/15/11 3,662 860 0 12/23/11 0 0 12/14/11 3,700 1,100 0 12/23/11 0 0 12/13/11 3,659 1,240 0 12/22/11 0 0 12/12/11 3,695 1,460 0 12/22/11 0 0 12/11/11 3,716 1,340 0 12/21/11 0 0 12/10/11 3,708 1,440 0 12/21/11 0 0 12/09/11 3,692 1,340 0 12/20/11 967 3,391 12/08/11 3,763 1,440 0 12/20/11 0 0 12/07/11 3,701 1,500 0 12/19/11 888 3,729 12/06/11 3,755 1,020 0 12/19/11 0 0 12/05/11 3,805 820 0 12/18/11 848 3,728 12/04/11 3,788 1,100 0 12/18/11 0 0 12/03/11 3,788 1,100 0 12/17/11 725 3,282 12/02/11 3,802 810 0 • • °CAL C -to Regg, James B (DOA) PT6 t @s -o1S From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, December 27, 2011 11:32 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: UNDER EVALUATION: Injector MPC -10 (PTD 1850150) IA Repressurization After Bleed Attachments: Injector MPC -10 (PTD #1850150) TIO PIot.ZIP; Injector MPC -10 (PTD #1850150).ZIP Tom, Please see notification for Injector MPC -10 (PTD #1850150) exhibiting IA repressurizaiton and plan forward. The well remains shut in and diagnostics are being progressed. BP will provide further notification once diagnostics are complete. Thank you, Mehreeyz Vaz!r (Alternate: Gerald A1urphv) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 C `( Email: AKDCWeIIIntegrityCoordinator @BP.com gjuigatED FEB From: AK, D &C Well Integrity Coordinator Sent: Sunday, December 25, 2011 7:42 PM To: AK, D &C Well Integrity Coordinator; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Well Ops Coord Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M (Northern Solutions); LeBaron, Michael J; 'Scott.McEntyre @bp.com' Subject: UNDER EVALUATION: Injector MPC -10 (PTD 1850150) IA Repressurization After Bleed All, WAG Injector MPC -10 (PTD #1850150) exhibited IA repressurization after a bleed. The IA pressure was bled on 12/24/11 from 1750 psi to 500 psi. The overnight monitor indicated that the IA pressure had increased 1040 psi overniaht while shut it. This well is being reclassified as Under Evaluation. Please leave the well shut in until further diagnostics can be performed to confirm two competent barriers in the wellbore. Plan Forward: 1. Milne Point: Bleed IA to 500 psi - DONE 2. Wellhead: PPPOT -T - FAILED 3. F: MIT -IA 4. DHD: Monitor wellhead pressures for 7 - 10 days pending a passing MIT -IA A wellbore schematic, TIO plot, and Injection Plot have been included for reference. «Injector MPC -10 (PTD #1850150) TIO PIot.ZIP» «Injector MPC -10 (PTD #1850150).ZIP» r Please call with any questions or concerns. Thank you, 1 • • Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 • • MPU C -10 PTD #1850150 12/27/2011 TIO Pressures Plot Wd YPC -10 • • • • • • • • 3,000 w OA 00A 2800 On • 1 000 - • • 1051/11 10/68/11 1071511 10/22/11 10/29/11 11/05/11 11 /12)11 11/19/71 11746/11 12/03/11 12/10/17 - 12/17/11 12/24;11 • • Injection Plot • wtrwm 4.400 3300 4,200 0.200 0,10D 3000. �n • 2saD 3.600 • ! 2/600 00 • 3107 • 2500 2SW dW 3.000 � 2200 2,800 - 2,700 2600 1.9� m —WHIP • 2400 • / 1,iM)0 2100 - 1 700 — PV/ 111 5m G 61 2,000 - / 1 /600 � On • 1,806 V I / 1,000 1200 • V L jfA,�' 1 / , 800 • aD 600 �f 1 400 000 400: � 200 0G 100 10/01/11 10/18/71 10/15/11 10/22/11 10/29/11 11/05111 11/1 11/19/11 11/i6/11 1253/11 12/10/11 12/17/11 12/24111 Tree: 3 1/8" - 5M FMC M P U C -I O j Orig. Elev. = 52.0 Wellhead: 11" 5M FMC g. GL Elev. =17.0' w/ 3 1/2" FMC Tubing Hanger, RT To Tbg. Spool = 29.95' NSCT lift threads, 3" CIW H BPV profile 13 - -3/8" , 48 #/ft , H -40 99' ii KOP @ 3,000' Max. hole angle = 43° @ 3,600' Hole angle thru' perfs = 29 ° ii i 9 5/8 ", 36 # /ft, K -55 & L -80 Btrc. I k 1 4,843' ' 3.5" 9.3 #/ft , L -80 , NSCT. ft 1 Bbls /ft = .0087 ID = 2.992" 7" 26 #/ft , L -80, BTRC Casing. (drift ID = 6.151", cap. = 0.0383 bpf ) 111 II Minimum tubing restriction = 2.75" y. "XN" profile @ 8,222' Stimulation Summary 7" x 4.5" Baker" S -3" Packer 17,895' IMMINWMANNONStiMMEM 71 I Perforation summary Ref Log: Dil Log (2 -21 -85 _ 3.5" x 1 " Camco "KBUG " glm 7,919' Size SPF Interval (TVD) 1 Middle Kup 5" 12 8,052' - 8,070' 7,039' - 7,054' .. ' = 3.5" x 1" Camco " KBUG " glm 8,008' 4.5" 5 8,052 - 8,070' " " " " 5" 12 8,140' - 8,144' 7,112' - 7,115'. a ECP 8,131' 4.5" 5 8,140' - 8,144' " " " y 7" Baker HYD Releasing Anchor 8,193' 5" 12 8,166' - 8,170' 7,134' - 7,137' mewl 4.5" 5 8,166' - 8,170' " " " " Er ' 7" x 4.5" Baker " S -3" Packer 1 8,196' LK -1 Ea i 2-5/8" 4 8,251' - 8,270' 7,204'- 7,221' 3.5" HES XN- Nipple (2.75" min ID) 8,222' IlLi 4.5" 5 8,251' - 8,270' " " " " - LK 2 ECP 8,238' WLEG 8,234' 2 -5/8" 8 8,278' - 8,308' 7,228' - 7,254' - 4.5" 5 8,278' - 8,308' 7,228' - 7,254' - JB / GR Tagged on rig 7/ 30/ 96 PBTD 12 spf @ 120° Phasing ( 21 - 85) 4 spf @ 180° Phasing ( 2- 21 -85) ( PBTD} 8,403' 8 spf @ 180° Phasing ( 2- 21 -85) " �'� "' '''' / ... 8 483' 5 spf @ 135/ 45 ° Phasing Alpha jet ( 7- 30 -96) 7" float shoe , DATE REV. BY COMMENTS MILNE POINT UNIT 2 / 26 / 85 Cased hole and completion WELL C -10i 8 / 01/ 96 MDO RWO Completion 4ES API NO: 50- 029 -21278 BP EXPLORATION (AK) ~_~, PeoACrivE DIAGNOSTIC SEltvicES~ INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 ~~~l~s ~bCtS ~ptd~ 1) Injection Profile 14-Aug-10 MPU G10 BL/ EDE 50-0296-21278-00 ~ ~ - 2) ~ ~ ' -`~ _ _.. ~` ~ _`~ - Signed : Date ~~ Print Name: ~ '-~ PROACTIVE DIAGNOSTIC SERVICES, 1NC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-mA1L: ~c~s~a~ch®ra~eCa7rsaera~®a-~t9®~.~.~~ WEBSITE: nr~nr~~v.r,s~rrscs~~,~o€~~~~ • SELL LOS T1~a4/U11°~.4L :,~ .: , .. .v jfj~l^ C:\Documents and Settings\Diane Williams\Desktop\Transmit_BP.docx STATE OF ALASKA ALAS L AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ gRIGHT WATER PerFormed: Alter Casing ~ Pull 7ubing ~ PerForate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown [] PerForate ~ Re-enter Suspended Well ~ 2. Operator BP Expioration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: -vame: De~lopment ~ Exploratory ~ ~s5-o~50 / 3. Address: P.O. Box 196612 Stl'atigrc]phlC ~ Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-2127&00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 52 KB MPC-10 / 8. Property Designation: 10. Field/Pool(s): ADLO-047434 / / MILNE POINT UNIT Field/ KUPAf~~,~tl'~i'Ef~~S ~ip o 11. Present Well Condition Summary: ~ „,,.,, 1 LJ ~~ ~ Q// ~ ~ ~ °'~~a Total Depth measured ,~848'3~ feet 7/' ~~ Plugs (measured) None `~ ~ h~~• ' true vertical 7 feet Junk (measured) None ,; Effective Depth measured 8403 feet • true vertical 7336 feet Casing Length Size MD ND Burst Collapse Conductor 80' 13-3/8" 48# H-40 SURFACE - 115 SURFACE - 115 1740 750 Surtace 4806' 9-5/8" 36# K-55 SURFACE - 4842 SURFACE - 4641 5120 2370 Production 8449' 7" 26# L-80 SURFACE - 8483 SURFACE - 7492 7240 5410 '"~ j~i~: . '4,' ~ „~.:.r . Perforation depth: Measured depth: see attached - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 SurFace - 8234' 0 0 - ~ Packers and SSSV (type and measured depth) 7"X4-1/2" S-3 BAKER PKR 7895' <~---~ip~ ~ `l 7"X4-1/2" S-3 BAKER PKR 8196' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions inGuding 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: 2004 2765 Subsequent to operation: 1998 2752 14. Attachments: 15. Wel! Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~'"` Senrice ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Prebte Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/10/2009 I Form 10-404 Revi~ed 04/2006 t~~~x~~.°~ ~s-~ ';~' $ ~'s ?OD~ ~l ~ ~ Submit Original Only G~` ,,C~?~''~f,/!~ ~~ MPC-10 185-015 PFRF ATTdCHMFNT ~ • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-10 2/21/85 PER 8,052. 8,070. 7,039.35 7,054.03 MPC-10 2/21/85 PER 8,140. 8,144. 7,111.64 7,114.97 MPC-10 2/21185 PER 8,166. 8,170. 7,133.32 7,136.67 MPC-10 2121/85 PER 8,251. 8,270. 7,205.2 7,221.45 MPC-10 2121/85 PER 8,278. 8,308. 7,228.32 7,254.14 MPC-10 2126/85 STC 7,929. 8,204. 6,940.1 7,165.28 MPC-10 8/18/85 APF 8,251. 8,270. 7,205.2 7,221.45 MPC-10 8/18/85 APF 8,278. 8,308. 7,228.32 7,254.14 MPC-10 7/29/96 APF 8,251. 8,270. 7,205.2 7,221.45 MPC-10 7/29/96 APF 8,166. 8,170. 7,133.32 7,136.67 MPC-10 7/29/96 APF 8,278. 8,308. 7,228.32 7,254.14 MPC-10 7/29196 APF 8,052. 8,070. 7,039.35 7,054.03 MPC-10 7/29/96 APF 8,140. 8,144. 7,111.64 7,114.97 MPC-10 8/1/96 STC 7,895. 8,196. 6,912.95 7,958.52 MPC-10 1/22/00 BPS 8,181. 8,191. 7,145.9 7,754.37 MPC-10 1/22/00 FIL 8,133. 8,981. 7,105.83 7,145.9 MPC-10 1/22/00 STO 7,895. 8,196. 6,912.95 7,158.52 MPC-10 4I18/02 FCO 8,133. 8,181. 7,105.83 7,145.9 MPC-10 4/18/02 BPP 8,181. 8,191. 7,145.9 7,154.31 MPC-10 1/13103 FIL 8,301. 8,403. 7,248.1 7,336.57 MPC-10 1/13/03 STC 7,895. 8,196. 6,912.95 7,158.52 MPC-10 1/26/03 BPS 8,222. 8,232. 7,180.52 7,189,02 MPC-10 1126/03 STO 7,895. 8,196. 6,912.95 7,158.52 MPC-'10 7/25/03 BPP 8,222. 8,232. 7,180.52 7,189.02 MPC-10 7/25/03 STC 7,895. 8,196. 6,912.95 7,158.52 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FlLL SQF SQUEE2E FAILED M!R MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • MPC-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/21/09 - 8/9/2009~ Bright Water pump operations. Began EC9360A (surfactant) pre-flush injection ;on 7/21/09 with a water injection rate of 1648 BWPD and injection pressure of ~2418 psi. Began EC9378A (polymer) injection on 07/24/09 with a water jinjection rate 1734 BWPD and injection ressure of 2392 si. Finished pumping ' EC9378A 08 08/09 with a water injection rate of 2004 BW PD and injection ' pressure of 2765 psi. Finished pumping EC9360A on 08/09/2009 with a water ~injection rate of 1998 BWPD and injection pressure of 2752 psi. Total EC9378A , injection volume 23276 gallons. Total EC9360A injection volume 7600 gallons. ~ ~-=~ ; ~~~aiv~ ~eroa~n~sTi~ ~~c~ic~, a~:c_ _ ~~~ ~ ~ ~~: f, ~~ ~~~~~~~i~ • To: ~OGCC Christine Mahnicen 333 W. 7tF- ,4ve Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hoie/Mechanica! Lags and /or Tubing Inspection(Caliper / MT~ 1) 2) The technical data listed below is being submitted herewith_ Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ~~~ "~"~ ~~ "'"~"'"' ""' BP Exploration (Alaskaj, lnc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd ~'~~~~ ~` ~~~- ~' ~ ~~~~ ' Anchorage, ~ltaska 99508 and PraActive Diagnostic Services, Inc. Attn: Rob~t A. Richey 130 West Internationa~ Airport Roac Suite C Anchorage, AK 99518 ~ Z~- I f S- d r S Fa~c (907~ 245-8952 ~ ~ a r ~- Injection Profile 06,Jun-09 MPG10 P a p ! '; i ~,~--,,.~.~- ~ Signed : P~int Name: Color Log / E~ 50-029-21278-00 Date : PROACTIVE DIAGNOSTIC SERVICES, iNC., 130 UN. lNTERN14TIONAL s41RPORT RD SUITE C, AIVCMCRAGE, ~4K ;19518 PHONE: (907)245-8951 FAX: (90T)245~8952 YVEBSITE : ` ' ~-MflIL : ,:;; .__._ ~ C.`.Documen6 and Settings\Oaner~Desktop\T[ansmit BP.doc~: MEMORAI~IDUM • To: Jim Regg '~ ~ (~'Zh~+~ P.I. Supervisor ~~ I FRO1vI: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 15, 2008 SLBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-10 MILNE PT UNIT KR C-10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `1~- Comm Well Name: MILNE PT UNIT KR C-10 Insp Num: mitCS081010063936 Rel Insp Num: API Well Number: 5 0-02 9-2 1 2 78-00-00 Permit Number: 185-015-0 / Inspector Name: Chuck Scheve Inspection Date: to/9/2008 Packer Pretest Initial Depth 15 Min. 30 Min. 45 Min. 60 Min. Well I c-IO 'Type Inj. c 'I'mo ~ 6913 '- II IA 280 2220 2180 2180 P.T. Issolso ~TypeTest SPT Test psi 1728.25 ..Y OA ! loo ~~ 2so zso 2so j Interval 4YRTST p~F P Tubing ~ 4240 4240 ~ 4240 4240 Notes' Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. tr"`~1„J/ WG 6i~' iicr" {ti ~~1 E ; ~ /". rf l'i./~7 Wednesday, October I5, 2008 Page 1 of 1 09/10/07 Schlumberger NO. 4406 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED SEP 1 8 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WI! Field: Prudhoe Bay Endicott C I CD J b# L D . f D t BL e 0 011 I esc rI Dllon ae o or 17-14 N/A JEWELRY/SBHP HKf\- J~4-'1.(_ 08/17/07 1 MPC-10 11767137 MEM INJ PROFILE I }'I:~ l"'lf.'-ð/< 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG 1'11f'. - O~<" 08/15/07 1 P2-30 11686776 PRODUCTION PROFILE I ~ :l - (')C>¡,~ 08/25/07 1 L 1-31 11865639 LDL I q"" 1_' L 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE /C¡'t -tA'7- 08/17/07 1 17 -03A N/A JEWELRY/SBHP ¡qq..- /J./I_ 08/17/07 1 C-26 11824342 LDL ,t1<íÇ - l./~ 08/22/07 1 15-07C 11594517 SBHP SURVEY ~f"'I?-.- Oq.q 08/23/07 1 D-04B 11591451 SBHP SURVEY ;Jö3 - II ö 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE IC¡'í( - ('If")'i< 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE IC\~ - D44 08/19/07 1 09-44 11855501 SBHP/JEWELRY /C1(') - Qt... 08/16/07 1 09-23 11824337 SBHP/JEWELRY I~ - ('ý-.,~ 08/16/07 1 2-52/S-41 11846807 PRODUCTION PROFILE J~-:' -(")~~ 08/18/07 1 F-08A 11638646 USIT :J{)~ -0 06/28/07 1 02-16C 11628790 SCMT dbr-07t5 08/24/07 1 L2-32 11695060 RST I }"T'.I" , I""'~ _I~-:} .. t."'" 14 {,. OS/23/07 1 1 L5-09 11492259 RST ¡Ci{')-I!Jl/ *' ,KuJ':J. 11/11/06 1 1 02-12B 11767132 MCNL f)()~-(~~ .. I~/,..... 06/21/07 1 1 18-09B 11366500 MCNL I'Hr- ~* #- 1:":¡-410 1 0/23/06 1 1 G-14A 11485777 MCNL I~'j' -()~~ it 15'-/:J-ò 11/27/06 1 1 05-20B 10942220 MCNL ::J nLI - ::J:~ (I it- 1."\4:J / 06/26/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY At.ln~\T~NI~NE COpy EACH TO: BP Exploration (Alaska) Inc. 1F:;:~ E:. C:t: ~ ~\ ß ",-~ '% J1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 ~i ",Jr ~-.".., "'~' 2525 Gambell Street Suite 400 900 E, Benson Blvd, Anchorage, Alaska 99508 ('CD 1 L\'Oo-t ,)LI .'. ' Anchorage, AK 9. ~H2 ATTN: Beth 1.. Received bY:C /£. ^--- Date Delivered: C·' II", \ ,nl \ 11\ ,LJJtOR /\lHG~{n CHi r~( (~~t~:' ,~}, ,) . . MEMORANDUM TO: Jim Regg V1 /),. D('7 Î } '"'4 P.I. Supervisor l')Uti l v"b U FROM: Chuck Scheve Petroleum Inspector Well Name: MILNE PT UNIT KR C-I0 Insp Num: mitCS041 024164507 Rei Insp Num: Packer Well C-I0 Type Inj. G TVD P.T. 1850150 TypeTest SPT Test psi Interval 4YRTST P/F P Notes: Pretest pressures observed for 30+ minutes and found stable. ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 27,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-I0 MILNE PT UNIT KR C-l 0 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-21278-00-00 Permit Number: 185-015-0 l qyS,-é) ¡:t Reviewed By~ P.I. Suprv .::::J~ Comm Inspector Name: Chuck Scheve Inspection Date: 10/24/2004 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6912 IA 0 2020 1980 1980 1728 OA 0 0 0 0 Tu bing 4600 4600 4600 4600 SCANNED NOV 0 9 20D4 Wednesday, October 27,2004 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ DUMMY OFF 'C' SANDS Pull tubing _ Alter casing _ Repair well _ Other_X DUMMY 'C' SDS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4384' FNL, 2360' FEL, Sec. 10, T13N, RIOE, UM At top of productive interval 1769' FNL, 1023' FEL, Sec. 10, T13N, RIOE, UM At effective depth 1617' FNL, 911' FEL, Sec. 10, T13N, RIOE, UM At total depth 1584' FNL, 890' FEL, Sec. 10, T13N, RIOE, UM 5. Type of Well: Development __ Explorato~_.. Stratigraphic__ Service__X (asp's 558103, 6029177) (asp's 559414, 6031802) (asp's 559524, 6031955) (asp's 559545, 6031988) 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or Property name Miline Point Unit MPC-lO 9. Permit number / approval number 185-0150 10. APl number 50-029-21278-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conduc~r 80' Sudace 4806' Production 8449' 8483 feet Plugs(measured) 7406 feet 8403 feet Junk(measured) 7336 feet Tagged TD @ 8301' (01/13/2003). Size Cemented Measured Depth True Vertical Depth 16" To Surface 115' 115' 9-5/8" 1156 sx PF 'E', 433 sx 4842' 4641' Class 'G' 7" 330 sx Class 'G' 8483' 7492' Perforation depth: measured true vertical I'ubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Closed Perfs 8052' - 8070', 8140'- 8144', 8166' - 8170'; Open Perfs 8251' - 8270', 8278' - 8308' Closed Perfs 7039'- 7054', 7112'- 7115', 7134'- 7137', Open Perfs 7204' - 7221', 7228' - 7254' Straddle3-1/2"' 9.3#, L-80 NSCT to 8234' MD.is open @ 7919' & 8008'. Plug in tailpipe c°vered bY 48'~ 1~C E ! V ED Two 7" x 4-1/2" S-3 Baker Packers set @ 7895' & 8196'. NoSSSV. JAN 3 ~ LVV~J 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Cornmissio, Anchorage 14. Prior to well operation 01/12/2003 Subsequent to operation 01/27/2003 Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1195 SHUT-IN Tubing Pressure 2352 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 6. Status of well classification as: Oil _ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr RBDNS BFL Form 10-404 Rev 06/15/88 · FEB Date January 27, 2003 ~N ~m~o~.~,~ b ~ e ~a ?~c h n o r r 564-5174 SUBMIT IN DUPLICATE 05/17/2002 07/1 O/2OO2 09/04/2002 10/23/2002 12/20/2002 01/13/2003 01/15/2003 05/17/O2 MPC-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WAG SWAP FROM WATER TO GAS INJECTION. WAG SWAP FROM GAS TO WATER INJECTION. WAG SWAP FROM WATER TO GAS INJECTION. WAG SWAP FROM GAS TO WATER INJECTION. WAG SWAP FROM WATER TO GAS INJECTION. SLICKLINE/TAGGED TD/DUMMY OFF 'C' SANDS RESV SURV/PRESSURE FALLOFF EVENT SUMMARY WELL SUPPORT TECHS RIGGED UP AND SWAPPED BLINDS AND TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 20 BBLS METHANOL DOWN TUBING. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. 07/10/O2 09/04/02 WELL SUPPORT TECHS SWAPPED BLINDS. FLUSHED SENSOR LINES, AND GREASED TREE. ALL FLANGES WERE TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL FOLLOWED BY 90 BBLS SOURCE WATER AND THEN 2 BBLS METHANOL. PUMPED FROM 3250 TO 2500 PSi @ 2 BPM. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS'TURNED OVER TO OPERATOR TO PUT ON INJECTION. PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU FECO. PT'd TO 4000 PSI. PUMPED 20 BBLS METHANOL DOWN THE TUBING @ 1.45 BPM AT 2750 PSi. RDMO. TURNED OVER TO THE OPERATOR TO BE PUT ON INJECTION. JOB WAS COMPLETED WITH NO PROBLEMS. PUT ON GAS INJECTION @ 3000 MSCFD. 10/23/02 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU FESCO. PT'd TO 4600 PSI. PUMPED 19 BBLS METHANOL DOWN TUBING @ 1.5 BPM, 2800 PSi AND 1 BBL METHANOL DOWN THE FLOW LINE FOR FREEZE PROTECTION. RDMO. WELL WAS CONVERTED TO GAS AND PUT ON INJECTION @ 2500 MCFPD. 12/20/02 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUE FLANGES TO SPEC. MIRU FESCO. PT'd TO 5000 PSI. PUMPED 5 BBLS METHANOL @ 1.25 BPM, 4250 PSI. SWITCHED TO SOURCE WATER AND PUMPED 80 BBLS @ 2.7 BPM, 4175 TO 3100 PSI AND 3 BBLS METHANOL @ 2.0 BPM, 2550 PSI. RDMO. WELL WAS CONVERTED TO WATER AND PUT ON INJECTION @ 2000 BPD. SCANNED FEB 1 0 2003 Page I 01/13/O3 01/15/03 MPC-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TAGGED FILL 8301' MD, 7' ABOVE BOTTOM PERFORATIONS @ 8308' MD. PULLED CIRCULATING VALVES AND SET DUMMY VALVES. CLOSED 'C' SANDS. PJSM. MIRU FESCO. PT'd TO 4500 PSI. PUMPED 2 BBLS METHANOL DOWN THE FLOW LINE @ 1 BPM, 2700 PSI. SWITCHED TO TUBING AND PUMPED 20 BBLS METHANOL @ 1.8 BPM, 2200 TO 3600 PSI. RDMO. WELL IS FREEZE PROTECTED AND RIGGED TO MONITOR PRESSURE FALL OFF. FLUIDS PUMPED BBLS DISCRIPTION 124 METHANOL 170 SOURCE WATER 294 TOTAL SCANNED FEB 1 0 2003 Page 2 Tree: 3 1/8"-5M FMC MPU C 10i Orig. KB Elev. = 52.0 Wellhead: 11" 5M FMC ' Orig. GL Bev. =17.0' w/ 3 1/2" FMC Tubing Hanger, ~ RT To Tbg. Spool =29.95' NSCT lift threads, 3" CIW H BPV 13--3/8", 48 #/ft, H-40 ~ ~ KOP @ 3,000' Max. hole angle = 43° Hole angle thru' perfs = 29 o 9 5/8", 36 #/ft, K-55 & L-80 Btrc. t~ ~ ~ ;i Note: Plug in tailpipe ! covered by 48' of fill 3.5" 9.3 #/ft, L-80, NSCT. :;'~' plug has1' trash Bbls/ft = .0087 ID = 2.992" ;;~;~ extension. Straddle is 7" 26 #/ft, b-80, BTRC Casing. ~i!~ open with 1" c:rcu'a"n- (drift ID = 6.151", cap. = 0.0383 bpf) valves. 1/22/00 M.Linder. Minimum tubing restriction = 2.75- "XN" profile @ 8,222' Stimulation Summary .................... 7" × 4.5" Baker" S-3" Packer Perforation summary Ref Log: Dil Log { 2-21-85 ) 3.5" × 1" Camco "KBUG "giro Size SPF Interval (TVD) Middle Kup 5" 12 8,052'-8,070' 7,039'-7,054' 3.5"xl"Camoo"XBUG"glm J8,008' 4 5" 5 8,052 - 8,070 .......... 5" 12 8,140'-8,144' 7,112'-7,115' ~ ECP 8,131' 45" 5 8,140' - 8,144 7" Baker HYD Releasing Anchor I 8.~ 93' 5" 12 8,166' - 8,170' 7,134' - 7,137' ~ 2~5/8" 4 8 251' ~ 8,270' 7,204' ~ 7,221' 3.5" HES XN-Nipple (2.75" rain ID) 4 5" 5 8,251' - 8,270 ......... ECP 8,238' WLEG 2-5!8"8 8,278' - 8,308' 7,228' - 7,254' 4 5" 5 8 278' - 8,308' 7,228' - 7,254' JB / GR Tagged on rig 7/30/96 PBTD 12 spf @ 120° Phasing ( 2-21-85 ) 4 spf@ 180°Phasing (2-21-85) (PBTD) 8 spf@ 180" Phasing (2-21-85> J ~ i~ I ~ ~a"~' I 5 spf @ 135/45 ° Phasing Alpha Jet ( 7-30-96 ) 7" float shoe DATE ~EV BY COMMENTS IVtlLNE POINT 'ONIT 2 / 26 / 85 Cased hole and completion WELL C-10i 8 / 01/96 MDC RWO Completion 4ES APl NO: 50-029-21278 aP EXPLORATION {AK r~ Z Z STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X WAG SWAP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development- RKB 59 feet 3. Address Exploratory- 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchors e, AK 99519-6612 Service_X Miline Point Unit 4. Location of well at surface 4384' FNL, 2360' FEL, Sec. 10, T13N, R10E, UM (asps 558103, 6029177) MPC-10 At top of productive interval 9. Permit number /approval number 1769' FNL, 1023' FEL, Sec. 10, T13N, R10E, UM (asp's 559414, 6031802) 185-0150. At effective depth 10. API number 1617' FNL, 911' FEL, Sec. 10, T13N, R10E, UM (asps 559524, 6031955) 50-029-21278-00 At total depth 11. Field /Pool 1584' FNL, 890' FEL, Sec. 10, T13N, R10E, UM (asp's 559545, 6031988) Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8483 feet Plugs (measured) true vertical 7406 feet Effective depth: measured 8403 feet Junk (measured) true vertical 7336 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 16" To Surface 115' 115' Surface 4806' 9_5/g~~ 1156 sx PF'E', 433 sx 4842' 4641' Class 'G' Production 8449' 7" 330 sx Class 'G' 8483' 7492' e ~_ Perforation depth: measured Open Perfs 8052' - 8070', 8140' - 8144', 8166' - 8170', No Injection into these Perfs 8251' - 8270', 8278' - 8308' true vertical Open Perfs 7039' - 7054', 7112' - 7115', 7134' - 7137', No Injection into these Perfs 7204' - 7221', 7228' - 7254' ,,,,,~;. , . Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 NSCT to 8234' MD. Plug in tailpipe covered by 48' of fill. Straddle is open C~3 7919' & 8008'. Packers &SSSV (type & measured depth) Two 7" x 4-1/2" S-3 Baker Packers set ~ 7895' & 8196'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 01/27/2002 2087 3927 Subsequent to operation 01/30/2002 1226 2677 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations _ Oil _ Gas _ Suspended _ Service WAG Infector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~,/~/y„o J ~~~f~ ~ Title: Technical Assistant Date February 27. 2002 ~ - ~ x'77 DeWayne R. Sc norr Prepared b DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 ~' ~ ~~ ~ ~ ~, ~: RBDMS BFL pr i ~ tq~ 5 f " SUBMIT IN DUPLICATE. M PC-10 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS • 01/28/2002 WAG SWAP FROM GAS TO WATER INJECTION EVENT SUMMARY 01/28/02 PJSM. SAFED OUT & BLED DOWN SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUED FLANGES TO SPEC. MIRU HB&R. PT'd TO 4900 PSI. PUMPED 80 BBLS SOURCE WATER DOWN THE TUBING AT 2 BPM, 3900 PSI TO 2900 PSI TO KNOCK DOWN THE PSI, SWITCHED TO METHANOL AND PUMPED 17 BBLS METHANOL AT 2 BPM, 2700 PSI. PT'd FLANGES TO 4000 PSI. RDMO. FLUIDS PUMPED BBLS DISCRIPTION 17 METHANOL 80 SOURCE WATER 97 TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I.' Supervisor DATE: May 19, 2001 FROM: 'John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19,2001: I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the ^OGCC Policy Supplement, i told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells #4,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6 failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc Alas,.~ Oil and Gas Conservation Commis. a Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Jolm, ,,.Cr',mp ..... Submitted By: John Crisp,~ Date: Field/Unit/Pad: Milne Point l~lnit C Pad Separator psi: LPS 140 HPS 5/19/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI ES1 ,Trip ,Code Code Code Passed GAS or.,CYCLE C-01 i811450 140 100 110 P P OIL C-02 1821940 C-o3 ....... 1820500 140 1 oo .....951 P '" P " 0iL c-o4 1821260 '14o lOO ilo P " 4 ' (~IL C-05A' 18424'30 140 ' ' 100 100 P P ...... OIL C-06 184241'0 ' 4300 ' 2000 1950 P 4 WAG C-07 1850020 140 100 95 P 4 OIL C'08 1850140 4300 2000 1900 P 4 WAG 'C-09 ' 18~0360 ' 140 i'00 " 105 P P oil C-13 1850670 ~-14 1850880', 146 100 100 P 4 .... 1 OIL C-15 1851030 · : · . , , C-17 1852630 C-20 ' 1890150 .... C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A ' 1960210 4300 2000 1906 P 4 ' WAG C-26 1952060 C-28 1960290 C-36 1980010 C-39 1972480 C-40 2002130 C-10 1850150 4300 2000 1850 ' P 'P ' ~ wAG Wells: 12 Components: 24 Failures: 6 FailUre Rate: 25.00oA~ 90 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM TO: Dan Seamount Commissioner THRU: BlairWondzell ~ P.I. Supervisor tO/'~'¢ FROM: John Crisp'Cc Je~,~ d~. Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1,2000 SUBJECT: Mechanical Integrity Tests BPX B,C,J,L Pads B-05i,C-06i,10i,J-02i,L-24i Milne Point Unit Milne Point Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well! B-05i I Type nj.I S P.T.D.i 1851480 ITypetestl P ITest.psiJ 1744 I casingl 1825 J 3000 J 3000 J 3~06 J P/FI_Pt Notes: Well! C-06i ]Typelnj.! S I T.V.D. } 6732 I Tubingl 2550 ! ~2550 I 2550 I 2550 l lntervall 4 / P.T.D.I 1842410 ITypetestl P ITestpsiI 1683 I Ca'singl 590 I .1900 I 1890 I 1890 I P/l~ J __Pl Notes: we,,! ' P.T.D.I'~"1850150 ITypetestl P I Testpsil 1728 ICa. sing Notes' WellI O-02i I Typelnj. I S ! T.V.D. 13810 I Tubing I 2050 12050 12050 12050 I,nterva~l 4 P.T.D.I 1900960 Typetest Notes' WellI L~24i I Typelnj. J G I T.V.D. I 6952 ]Tubir~gl-4400 I 44.00 I 4400 ] 4400 l lntervall 4 P.T.D.I 1950700 Type testI P .IT.estpsil 1738 I casing1 0 1'18401182011'8201 P/FI_P. Notes: 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 Test's Details I witnessed 5 successful MIT's. No problems cncotmtered. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) .I.T.'s performed: 5_ Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. cc: MIT report form 5/12/00 L.G. MIT MPU B,C,J,L Pads 10-01-00jc.xls 10/3/00 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 [] Other Convert from Water to WAG 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 894' NSL, 2360' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 3510' NSL, 1023' WEL, Sec. 10, T13N, R10E, UM At effective depth 3661' NSL, 917' WEL, Sec. 10, T13N, R10E, UM At total depth 3694' NSL, 895' WEL, Sec. 10, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-10i 9. Permit Number / Approval No. 85-15 10. APl Number 50- 029-21278 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8483' feet true vertical 7406' feet Effective depth: measured 8403' feet true vertical 7336' feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner ~L,..~'' .: Perforation depth:, measured true~/ertic-al Length Size Cemented 80' 16" To surface 4806' 9 5/8" 1156 sx PF 'E', 433 sx Class 'G' 8449' 7" 330 sx Class 'G' 8052'-8070',8140'-8144',8166'-8170',8251'-8270',8278'-8308' 7039'-7054',7112'-7115',7134'-7137',7204'-7221',7228'-7254' Tubing (size, grade, and measured depth) 3 1/2" 9.3# L-80 to 8234' Packers and SSV (type and measured depth) 2, 7" x 4.5' Baker "S-3" Packers @ 7895' & 8196' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MD 115' 4842' 8483' TVD 115' 4641' 7492' ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip ..~).~~/~,,~ Title Engineering Supervisor Date AIvord Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Du SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: MPC-10i Rig Name: N-4ES AFE# 339020 Accept Date: 07/25/96 Spud Date: . Release Date: 07/31/96 JULY 26, 1996 RIG ACCEPTED @ 2200 HRS. SCOPE DOWN DERRICK MOVE RIG OFF C-06 SET HERCULITE, MATS & SPOT RIG ON C-10i BERM RIG. RIG UP SAFETY EQUIPMENT & SCOPE UP DERRICK. PULL BPV W/LUBRICATOR, RU HARDLINE TO TREE F/WELL KILL. TAKE ON 11.2 PPG BRINE IN PITS F/BAROID TAKE ON BRINE FROM TIGER TANK & WEIGHT UP TO 11.2 SITP 1150 SICP 370 BULLHEAD 80 BBLS 11.2 PPG BRINE DOWN TUBING TO PERFS CIRC DOWN TUBING & TAKING RETURNS TO TIGER TANK. JULY 27, 1996 KILL WELL W/11.2 PPG BRINE TAKING RETURNS TO TIGER TANK. MONITOR WELL FOR 30 MIN LOST 11 BBLS OF BRINE DURING BU, MIX & SPOT 20 BBL XANVIS & LCM PILL MONITOR WELL FOR 15 MINUTES WELL ON VACCUM. INSTALL TWC, ND TREE & NU BOP'S. TESTED ALL RAMS & VALVES TO 250/5000 PSI. TESTED ANNULAR 250/3000 PSI. REPAIRED ONE VALVE ON CHOKE MANIFOLD RIGHT TO WITNESS WAIVED BY AOGCC INSPECTOR BOBBY FOSTER. PULL TWC, MU LANDING JOINT IN TUBING HANGER ABOVE ROTARY TABLE CIRCULATED BU. LD TUBING HANGER PULLED OUT OF HOLE LD TUBING LD 249 JTS TUBING, ONE GLM & SEAL ASSEMBLY (4.25 OD) RU FLOOR TO RUN FTA #1 - LOADING PIPE SHED W/4 ~" DRILL COLLARS. JULY 28, 1996 RIG SERVICE STRAP, CALIPHER & MU FTA #1 PU 25 JOINTS OF 3.5" DRILL PIPE SLM & DRIFT MU & SET HOWCO STORM PACKER CONTINUED RIH W/3.5" DRILL PIPE TO 7880' BRK CIRC. ENGAGE PACKER @ 7903' JARRED PACKER FREE W/200K (70k OVER STRING WEIGHT) CIRC BU CIRCULATED OUT GAS FROM UNDER PACKER MONITORED WELL POOH W/FISH. LD FTA #1 ALONG W/RETRIEVABLE PACKER & TAIL ASSY FULL RECOVERY MU FTA #2 & START IN HOLE. JULY 29, 1996 RIG SERVICE TIH W/3.5" DRILL PIPE & TAG PACKER @ 8189' MILL ON PACKER F/8189'-8192 WORKED PACKER DOWN TO 8211' CIRCULATED BU MONITORED WELL, WELL STATIC. TOOH W/FTA#2 & PACKER. LD PACKER W/TAIL PIPE ASSY & FTA #2. STRAP & MU BHA #3 SPACE OUT 7" CASING SCRAPPER & STARTED IN HOLE CUT 80' & SLIP 42' OF DRILL LINE. CONTINUED TOOH TAG FILL @ 8270' REAM & REV CIRCULATE FILL OUT OF HOLE FROM 8270' TO PBTD @ 8403'. REVERSE CIRCULATED SWEEP @ 74 SPM @ 850 PSI TO CLEAN UP HOLE. LOST 50 BBLS FLUID DURING CLEAN OUT. Page I of 2, SUMMARY OF DALLY OPERATIONS JULY 30, 1996 JET & FLUSH OUT FLOW LINE. RIG SERVICE. POOH LD DRILL PIPE & BHA. CLEAN BOOT BASKETS & CLEAR FLOOR. PULL WR ND FLOWLINE & NU PERF FLANGE WAITING ON ATLAS WIRELINE TO PERFORATE WELL RU ATLAS WIRELINE & LUBRICATOR, TEST LUBRICATOR TO 1000 PSI. RIG DOWN ATLAS WIRELINE. ND PERF FLANGE & NU BELL NIPPLE MU TAIL PIPE ASSY, PACKERS, GLMS & TIH W/3 1/2" COMPLETION. JULY 31, 1996 RIG SERVICE RIH W/3 'Y2" COMPLETION STRING MU HANGER & LAND TUBING, RILDS, SET TWC. ND BOP'S NU TREE & ADAPTER FLANGE TEST ADAPTER FLANGE & TREE TO 5000 PSI RU LINES TO TREE & TIGER TANK. TEST TREE & LINES TO TREE TO 250/5000 PSI PULL TWC. DISPLACED 11.2 PPG BRINE W/SOURCE WATER INHIBITED W/COREXIT @ 3 BPM. FREEZE PROTECTED ANNULUS W/60 BBLS DIESEL BULLHEADED 20 BBLS DIESEL DOWN TUBING. DROP 1.313" BALL/STEM DOWN TUBING PRESSURE UP ON TUBING & SET PACKERS W/2500 PSI DIFFERENTIAL PERFORMED MIT TEST. RIGHT TO WITNESS WAIVED BY AOGCC INSPECTOR, BOBBY FOSTER. PRESSURE TESTED TUBING TO 5000 PSI FOR 30 MINUTES & PRESSURE TESTED ANNULUS TO 5000 PSI FOR 30 MINUTES BLED ANN TO 0. 1500 PSI ON TUBING. INSTALL BPV, SECURE WELL & RD CELLAR. RIG RELEASED @ 0300 HRS. APR 2 0 '1998 0il & Gas Cons. Cornmis~ior~ Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: ~ Abandon [] Suspend [] Plugging [] Time Extension [] Perforate Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to WAG Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 894' NSL, 2360' WEL, SEC. 10, T13N, R10E At top of productive interval 3510' NSL, 1023' WEL, SEC. 10, T13N, R10E At effective depth 3629' NSL, 940' WEL, SEC. 10, T13N, R10E At total depth 3704' NSL, 888' WEL, SEC. 10, T13N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ORIGINAL 6. Datum Elevation (DF or KB) KBE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-10 9. Permit Number 85-15 10. APl Number 50-029-21278 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8505 feet true vertical 7425 feet Effective depth: measured 8330 feet true vertical 7271 feet Casing Size Structural Conductor 80' 16" Surface 4806' 9-5/8" Intermediate Production 7" Liner Plugs (measured) Junk (measured) Length Cemented To Surface 1156 sx PF 'E', 433 sx Class 'G' 8449' 330 sx Class 'G" MD TVD 115' 115' 4842' 4641' 8483' 7492' Perforation depth: measured 8052'-8070'; 8140'-8144'; 8166'-8170'; 8251'-8270'; 8278'-8308' R E ¢ E IV E D true vertical 7039'-7054'; 7112'-7115'; 7134'-7137'; 7204'-7221 '; 7228'-7254' JUL 2 2 199G Tubing (size, grade, and measured depth) 3-1/2", L-80 to 8240' Alaska Oil & 6as Cons. C0mmJs~l A~ch0raoe...., Packers and SSSV (type and measured depth) Camco TRDP-1A SCSSV at 715'; BOT HB Pkr at 7929'; 2B Pkr 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch . 4. Estimated date for commencing operation O7/3O/96 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Name of approver Date approved Contact Engineer Name/Number: Bob Laule, 564-5195 Prepared By Name/Number Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is tr~Je and qpr~ect to the best of my knowledge Signed . ~' "'""~ _~~.-~/.._ Tim Schofield /~_.~-r3 Title Senior Drilling Engineer /,/ Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~" Subsequent form required 10- ~(~/'r". Date 7/~//~, I Approval NO. C)/,, _ / ~ ¢ Original Signeo dy Approved by order of the Commission 9o,,vid W. -Joh-n. stor' Form 10-403 Rev. 06/15/88 .,.,~ Oog"J Commissioner Submift In Thplicate OBJECTIVE: The objective of this workover is similar to MP C-15i, MP C-17i, MP C-19i, and 0-08 to convert C-10i from water to WAG (water alternate gas) injection .well by pulling the existing 3-1/2" buttress tubing and straddle packers completion, re- perforating the Kuparuk A, & C intervals, and re-complete the well with new 3- 1/2" L-80 NSCT tubing with Baker straddle packer assembly. MP C-10i WAG injection is critical for fulfilling future MPU gas disposal requirements and to support offset producers. MP C-10i is AFE'd for $539 M and estimated 11 days to complete. All associated costs should be charged to AFE No. 339020. SCOPE: . Pre- rig: Test packoff. Punch the tubing at 7,800'. Monitor and record daily surface tubing pressure and estimate stabilized SBHP for final kill weight brine requirement. Freeze protect to 200' and install BPV. Remove wellhouse and flo.wline for rig move. , MIRU Nabors 4ES workover rig. R/U hardline for well kill operation. Pull BPV. Circulate and bullhead with kill weight brine until the well is dead. . Set BPV for N/D tree and N/U BOPE. Pull BPV and set TWC to test BOPE. Pull TWC. . Pull tubing seal assembly out from the PBR and circulate buttoms up with kill weight brine through choke until the well is completely dead. . Pull and L/D the existing 3.5" L-80 BTC tubing. Retrieve the straddle assembly. Mill and recover the straddle packer. Cleanout well bore to PBTD. . Perform wireline conveyed perforations at Kuparuk A ,B and C sands, i.e. 8,052'-8,070' MD (18') 8,140'-8,144' MD (4') :8,166'-8,170' MD (4'): 8,251'-8,270'MD (19) and 8,278'-8,308' MD (30'). . Complete well with new 3.5" L-80 NSCT tubing and Baker straddle assembly, set BPV for N/D BOPE and N/U tree. . Freeze protect well with diesel to 2,000'TVD. Set packers and test tubing to 5,000 psi and annulus to 5,000 psi. RDMO Nabors 4ES. RECEIVED JUL 2 2 1996 Alaska Oil & Gas Cons. C,3mmissio~ Anchorage SCHLUMBERGER WELL SERVIC[ A ~I~,;::51ON OF SCHLUMBERGER TECHNOLOGY CC... '-ORATION HOUSTON. TEXAS 77251-217~ NOV'0 1993 PLEASE REPLY TO SCHLUMBERGER WELL SERVICESPouch 340069 Prudhoe Bay, AK 99734-006 Attn: Bernie/Shelley Conoco, Inc. 3201 'C" Street, Suite 305 Anchorage, AK 99503 Attention: Dorothy Bourbeau Gentlemen: Enclosed ore..2 BLprints of the CompQny Conoco, Inc. Well Injection Profile, Run 1, 10/27/93 MPU C-10 on: Field Hilne Poinl; Additional prints are being sent to: 1 BLprints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 - Attn: George Lamb, OF 2018 EPT o 1 Blorints Conoco, Inc. 1000 South Pine. Ponca City, OK 74602-1267 Attn: Janet Webb, 1239 EB ERS .-~~rints, 1 RF Sepia Alaska Oil & Gas Consei-vation Cnmmi ms~ nn 3001 Porcupine Drive Anchorage, AK 99501~ Attn: Larry Gran~/ County North Slope State Alaska 1BL prints, 1RF Sepia Chevron Production Company 1301McKinney Houston, TX 77010 Attn: Gary Forsthoff 713/754-5618 1BL prints, 1RF Sepia OXY U.S.A.. Inc,L 6 Desta Drive, Suite 6002 Midland, TX 79705 Attn: John Carrol gls/68fi-SRO3 ~.prints printsR ECEI VED ,,ur 0 4 1993 '"' "'" ~ Gas Co/ts. ~n~, . Anchorage ..... ',,sston The film is returned to Conoco, Dorothy Bourbeau ReceSSed by~ ' Dat~: We oppreciote the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES SW$-- ~ 327-F CH (7 BL/3 RF) Ra~'mond N. Dickes OISTR IGT MANAG£1~ / -' STATE OF ALASKA ALASi~ . OIL AND GAS CONSERVATION COMMIS$,~aN APPLTCATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown__ Re-enter suspended well Alter casing .... Repair well __ Plugging __ Time extention Stimulate __ Change approved program __ Pull tubing X Variance . Perforate X Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 59' KDB feet 3. Address Exploratory __ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Sffatigraphic __ Milne Point Unit Service X 4. Location of well at surface 8. Well number 894' FSL, 2360' FEL, Sec. 10, T13N, RIOE, U.M. C-10 At top of productive interval 9. Permit number 3510' FSL, 1023' FEL, SeC. 10, T13N, RIOE, U.M. 85-15 At effective depth 10. APl number 3629' FSL, 940' FEL. Sec. 10, T13N, RIOE, U.M. 50-029-21278 At total depth 11. Field/Pool 3704' FSL, 888' FEL, Sec. 10, T13N, RIOE, U.M. Kuparuk River Fie!~ -1 ~ ~'~' "'~'~ · , · . / ,.~ ... 12. Present well condition summary ' ~, ~:.~ 'i .~ ~ :: ~ ;:~ ,, Total depth: measured 8505' feet Plugs (measured) true vertical 7425' feet Effective depth: measured 8330' feet Junk (measured) ' , ...... ':~ ~7~ ..... flue veracal 7271' feet ; ~:~ '~''~ ~L~'~ Casing Length Size Cemented Measured depth True vortical depth Structural Conductor 80' 16" To Surface 115' 115' surface 4806' 9-5/8" 433 sx Class G 4842' 4641' Intermediate 1156 SX Permf E Production 8449' 7" 330 SX Class G 8483' 7492' Liner Perforation Depth: measured 8052-8070', 8140-8144', 8166-8170', 8251-8270', 8278-8308' ffuevertical 7039-7054', 7112-7115', 7134-7137', 7204-7221', 7228-7254' Tubing (size, grade, and measured depth) 3-1/2", L-80, 8240' Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @715';BOT HB Pkr @7929', 2B Pkr @8204' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: February 1991 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of a pproverI Date approved Service Waterflood Injector 17. I hereby ~ ~rtify th~ t the foregoing is true and correct to the best of my knowledge. Signed ~.)'~ ~ ~0{;4 J.H. Andrew 'r~le Production Engineer Date 12/08/90 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity B(~P/Test __ Location clearanceI Mechanical Integrity Test __/~_ Subsequent form required 10- z~-o ~ ORIGINAl- $1GNEO BY ~ Approved Copy LONNIE C. SMITH~Beturned/~' /~___/j'~/d.~ Ap pro ved by order of the Co m mi ssi on _~,..~ ~ "~--/{ O Co m mi ss ioner Date / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MPU C-lO Norkover - Reperforate to Access LK-! Injection Zone Procedure Summary 1. Monitor SITP to determine reservoir pressure. 2~ MIRU workover rig on well. Kill well with NaBr/NaC1 .brine (density determined by SITP). ND tree, NU and test BOP's. e PU to release from Brown Oil Tools PBR assembly at 7929'. Circulate hole full of kill weight fluid. POOH and LD 3-1/2" production tubing. TIH with overshot/grapple BHA to Brown Oil Tools PBR above HB retrievable packer at 7929'. Latch PBR stinger and release packer. POOH and LD PBR stinger, Packer, and isolation tubing. e PU packer milling/pulling BHA and TIH to Brown Oil Tools 2B permanent packer at 8204'. Latch packer and mill slips. POOH with packer and tailpipe assembly. e GIH with 5" perforating guns and reperforate the LK-1 sand 8252-8270'. Make an additional run to reperforate the L-8 zone 8141-8145'. TIH with full bore retrievable packer on drillpipe and set below L-9 Zone perforations at 8166-8170'. Circulate down source water and establish injection into LK-1 and LK-2 sands. Allow injection to stabilize. RU electric line. GIH with production logs while injecting source water and confirm LK-1 is taking fluid at an acceptable rate. NOTE' Additional perforations will be added if measured injectivity is insufficient. 9. Kill well. Release retrievable packer and POOH. 10. PU permanent packer and 3-1/2" tailpipe with wireline nipple and re-entry guide. GIH on electric line and set packer at 8195'. POOH with setting tool and RD electric line. 11. PU isolation assembly for MK, L-8, L-9 perforations consisting of production seals, 3-1/2" gas lift mandrels, and wireline nipple below retrievable packer/PBR assembly . TIH on 3-1/2" production tubing pinned to packer PBR. 12. Sting into permanent packer at 8195'. Space out, land hanger. RU wireline and set tubing plug in nipple below packer. Set retrievable packer near 7910'. 13. ND BOP's. NU and test tree. 14. 15. RU slickline. GIH and pull tubing plug and dummies from isolation mandrels. RD slickline. Return well to waterflood injection service. AILNE POINT UNIT £-IIZI KDB - EL .52' KDB - 13.. 35' /gL,'(. ~ ,43.5 67O5' ?15' CAPCI) TRDP SSSV 12.812 ID) 3 1/2' 9.2J L'88 BUTTRESS ( ID: 2.9921 KDP' 2888' FAC 3 I/8' ,~l 5888, TREE V/ 3 1/2' 8 RD. TREETm CCl~CT. A]N. CI),ISTR]£T IDN , 2.75 CAACD 'D' NIPPLE APl NO.' .SB-O29-2J2'T8 COAPLETION FLUID ,10.2 PPG N~CI/ NoBr BRIBE PERFC~I [CltS: 12 5. GL~I~m'~ AK: ?I~39-?JF-'J4 ' TVD L-B: 8148-8144' AD ?112-?115' TVD ?853' CAJ'CO 3 1/2' KBLG~ 7917" 2' CENTRAL [ZER ~Y I ID: 3.251 79,~' mT 'i'~' PACKER ( ID · 2.89 7968' C. AACO 'V-I ' NIPI:LE I ID · 2.812) 8Ri)8' ~ 8041' C~ 'AJ'd]-2' ~ lID · 2.92) 80~' BLAST JOINT I ID, 3.0) 29.64' L-97 8283' mT 'CL' ~AL 811~-81~' AD ASSEAELY V/LOCATER lID ?13.4-?!37' TVD i 1 4--'8284' BOT '2B' 4 BT'~ 188 ~ ~ ~i FERA,U4ENT PACKER V/ AILLB. JT EXTENSIDI 8Z~l-eZ'~' ~ L__J 2 5/8'~ v'i-- 82;18' TUBING TAIL LK'2:8278 83B8' ADh'> ~'?/~j~I:.. -'~l'/8330' J~ FILL (VIi~L[I~ 7/3/90 Fi~CTL~ SI[H.: 7228]7254. T'VDI?_'-- ~ :-::J 8,J)3' 7'. ~ L-8~ BI'RS &/tO/SS LK-2 69.000 LBS. .j.--'~." .' I~ 16.2~ ID. b. 151 i 6-L:K) 1~ SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION ATTENTION _t' ",_; %. ¢. J .... COMPUTING CENTER PRINT CENTER WELL NAME SERVICES · X4ILNE o'UiNT T~ '" ..... ~i? C-!9 WELL NAME · ADVISOR REPORT - SERVICES ' NO. OF BOXES: JOB NO. · ADD'L TAPES · ALL iN ONE BOX 73952 NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME SERVICES · ~'MILNE POINT UNIT C-10 _ _ ,, P~ ADVISOR REPORT WELL NAME · SERVICES · NO. OF BOXES' JOB NO. ' ADD'L TAPES · · %T,T, IN ONE BOX NO. OF BOXES' 'JOB NO. · ADD'L TAPES · WELL NAME ' SERVICES ' NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · , ADD'L TAPES · RECE1VED Alaska 0ii & Gas Cons. comm'tssmn--' Ancl~or~g~ .- "' ' _.~;~ , ..... RECEIgED. BY': :;" WATER FLOW ADVISOR PL ADVISOR MPU C- 10 Company Field Logging Date Processing Date Reference - CONOCO, INC. - MILNE POINT - 04-JUL Y- 1990 - 17-JUL Y- 1990 - 73945 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 INTERPRETATION SUMMARY Water Injection Well - 1785 BWPD Zone Injection Water % of Interval BPD Total M. KUP 8052 - 8063 560 32.3 8063 - 8070 0 0.0 L-8 8140 - 8144 0 0.0 8151 -8153 10 0.6 L-9 LK-1 LK-2 8158-8162 5 0.3 8166-8170 0 0.0 8171-8173 80 4.6 8251-8270 0 0.0 8278-8290 0 0.0 8290-8300 1080 62.2 8300-8308 0 0.0 Total Injected Water 1735 100.0% Zone Water % of Total M. KUP 560 BWPD 32.3% L-8 10 8WPD 0.6% L-9 85 BWPD 4.9% LK-1 0 BWPD 0.0% LK-2 1080 BWPD 62.2% Surface well head injection pressure was 2900 + 40 psi. Well C-10 was logged in two parts: Water being injected into all zones at once. The CFM was used to determine the injection pro- file between GLMs and below the tubing tail. 2.) The water flow log (WFL) was used to determine the injection profile behind the 3.5 inch tub- ing. There was a tubing plug set in the tubing tail while the WFL log was run. The injection rate into the GLM's was almost the same for both surveys. Additional information: There is a 130 BPD leak in the tubing above the upper packer, and the upper packer is allowing this water to flow down beside it. WATER FLOW ADVISOR MPU C- 10 Company Field Logging Date Processing Date Reference - CONOCO, INC. - MILNE POINT . 04-JUL Y- 1990 - 17-JUL Y- 1990 - 73945 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 CONOCO, INC. Milne Point MPU C- 10 Water Flow Logs 04-Jul-90 INTERPRETATION SUMMARY Data from Water Flow Log Surface Injection Rate - 660 BWPD Zone Injection Water % of Interval bpd Total M. KUP 8052 - 8063 560 85.5 8063 -8070 0 0.0 L-8 8140 - 8144 0 0.0 8151 -8153 10 1.5 L-9 8158-8162 5 0.8 8166-8170 0 0.0 8171 -8173 80 12.2 Total Injected Water 655 100.0% ®The tubing tail has a tail plug set in it. There is no water going below 8190. ®There was a 130 BWPD leak in the tubing above the upper packer and flowing down past the upper packer. WATER (BWPD) SO00 8100 8250 CONOCO, INC. ~ Milne Point MPU C- 1L- i Water Flow Logs 04-Jul-90 66O BWPD Minitron Detector Det. Measured Flow No. Depth (ft) Depth (ft) Type Velocity Area (in2) 1 7876.1 7891.0 GR 75.2 4.79 2 8050.1 8052.1 Far 24.3 16.75 3 8052.2 8054.2 Far 17.0 16.75 4 8054.2 8056.2 Far 18.5 16.75 5 8056.3 8058.3 Far 16.6 16.75 6 8058.3 8060.3 Far 4.1 16.75 7 8060.2 8062.2 Far 4.0 16.75 8 8062.3 8064.3 Far 2.5 16.75 9 8064.3 8066.3 Far 3.6 16.75 10 8066.4 8068.4 Far 4.2 16.75 11 8068.2 8070.2 Far 2.2 16.75 12 8070.5 8072.5 Far 3.2 16.75 13 8072.3 8074.3 Far 3.2 16.75 14 8100.1 8102.1 Far 4.5 21.31 15 8148.3 8150.3 Far 2.9 21.31 16 8150.1 8152.1 Far 3.2 21.31 17 8152.1 8154.1 Far 2.5 21.31 18 8154.1 8156.1 Far 2.5 21.31 19 8156.1 8158.1 Far 2.5 21.31 20 8160.2 8162.2 Far 1.8 21.31 21 8164.1 8166.1 Far 2.5 21.31 22 8166.1 8168.1 Far 2.9 21.31 23 8168.1 8170.1 Far 2.8 21.31 24 8170.4 8172.4 Far 2.4 21.31 25 8172.3 8174.3 Far 2.1 21.31 26 8190.2 8192.2 Far 0.0 21.31 CONOCO, INC. Milne Point MPU C- I Water Flow Logs 04-Jul-90 Processed Data Depth Interval Average Average No. (ft)- (ft) Velocity Flow Rate 1 7876.1 - 8050.1 75.2 653.0 2 8050.1 - 8052.2 24.3 653.0 3 8052.2 - 8054.2 17.7 476.0 4 8054.2 - 8056.3 17.7 476.0 5 8056.3 - 8058.3 16.6 446.0 6 8058.3 - 8060.2 4.1 110.0 7 8060.2 - 8062.3 4.0 107.0 8 8062.3 - 8064.3 3.5 94.0 9 8064.3 - 8066.4 3.5 94.0 10 8066.4 - 8068.2 3.5 94.0 11 8068.2 - 8070.5 3.5 94.0 12 8070.5 - 8072.3 3.5 94.0 13 8072.3 - 8100.1 3.5 94.0 14 8100.1 - 8148.3 2.7 92.7 15 8148.3 - 8150.1 2.7 92.7 16 8150.1 -8152.1 2.7 92.7 17 8152.1 -8154.1 2.5 85.5 18 8154.1 -8156.1 2.5 85.5 19 8156.1 -8160.2 2.5 85.5 20 8160.2 - 8164.1 2.4 82.0 21 8164.1 - 8166.1 2.4 82.0 22 8166.1 - 8168.1 2.4 82.0 23 8168.1 - 8170.4 2.4 82.0 24 8170.4 - 8172.3 2.4 82.0 25 8172.3 -8190.2 2.1 71.8 26 8190.2 - 8192.2 0.0 0.0 (conoco~ ~ PL ADVISOR Production Logs Interpretation Using a Global Solver (V3) MPU C- 10 Company - CONOCO, INC. Field - MILNE POINT Logging Date - JUL04,1990 Processing Date - JUL 17,1990 Reference - 73945 Water Injection Well Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 CONOCO, INC. Milne Point MPU C- 10 Production Logs 04-Jul-90 INTERPRETATION SUMMARY Data from Continuous Flowmeter Surface Injection Rate- 1785 BWPD Zone Injection Water % of Interval bpd Total GLM's 7994 - 8004 ~455 29.6 8034 - 8044 LK-1 8251 -8270 0 0.0 LK-2 8278-8290 0 0.0 8290 - 8300 1080 70.4 8300 -8308 0 0.0 Total Injected Water '1535 100.0% *There is a leak in the tubing above the upper packer. 10 (GAPI) 1~0 8000 8100 8300 GA¢,~A RAY 1990 110. 7950 8000 8100 8150 8300 CONOCO, INC. Milne Point MPU C- Production Logs 04-Jul-90 COMPUTED CUMULATIVE FLOWRATES At Down hole conditions Zone Depth Depth Total Water Oil Gas Global # DH Rate DH Rate DH Rate DH Rate Into- Feet Feet Bpd Bpd Bpd Bpd herence 1. 8331.0 8300.5 0. 0. 0. 0. 0.000 2. 8290.0 8240.5 1079. 1079. 0. 0. 0.000 3. 8200.0 8044.5 1079. 1079. 0. 0. 0.043 4. 8034.0 8004.5 1495. 1495. 0. 0. 0.007 5. 7994.0 7949.5 1533. 1533. 0. 0. 0.024 COMPUTED FLOW DESCRIPTION Assuming a 1 - 11/16" tool presence Zone Water Gas Mixture Friction Liq/Liq Gas/Liq Flow # Holdup Holdup Density Gradient Slip vel Slip vel Regime Gr/cc Gr/cc Ft/mn Ft/mn 1. 1.000 0.000 0.970 0.000 0.00 0.00 No Flow 2. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 3. 1.000 0.000 0.970 0.013 0.00 0.00 WATER 4. 1.000 0.000 0.970 0.024 0.00 0.00 WATER 5. 1.000 0:000 0.970 0.025 0.00 0.00 WATER CONOCO, INC. Milne Point MPU C- 10 Production Logs 04-Jul-90 PRODUCTION LOG MEASUREMENTS Zone Depth Spinner Thermo # #1 #1 Feet Ft/mn DegF 1. 8331.0 0.00 103.733 8300.5 102.456 2. 8290.0 22.82 98.587 8240.5 98.289 3. 8200.0 96.51 98.266 8044.5 97.386 4. 8034.0 133.53 97.451 8004.5 97.413 5. 7994.0 136.79 97.369 7949.5 97.194 MEASUREMENT RECONSTRUCTION QUALITY Measured minus Reconstructed values Zone Spinner Thermo # #1 #1 Ft/mn DegF 1. 0.00 0.000 2. 0.00 -51.202 3. -0.09 0.221 4. 0.01 -14.051 5. -0.05 -1.266 CONOCO, INC. ~ Milne Point MPU C- 10 Production Logs 04-Jul-90 PL Advisor Program Parameters for Zone 1 (at downhole conditions) Zone bottom depth ................................................ 8331. Feet Zone top depth .................................................... 8301. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 30.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 6024. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.2770 Cp Reservoir temperature .............................................. 150.0 DegF Minimum water rate .............................................. 0.0000 Bpd Maximum water rate .............................................. 0.0000 Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.5190 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF PL Advisor Program Parameters for Zone 2 (at downhole conditions) Zone bottom depth ................................................ 8290. Zone top depth .................................................... 8241. Pipe internal diameter .............................................. 6.276 Pipe Deviation ..................................................... 30.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 6024. Water density ..................................................... 0.9700 Water viscosity .................................................... 0.2770 Reservoir fluid temperature ......................................... 149.8 Minimum water rate ......................................... ' ...... 1079. Maximum water rate ............................................... 2000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8580 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ........................................ '. ........ 0.0000 Feet Feet Inches Degrees Inches Gr/cc Cp DegF Bpd Bpd Inches Ft/mn DegF CONOCO, INC. Milne Point MPU C- 10 Production Logs 04-Jul-90 PL Advisor Program Parameters for Zone 3 (at downhole conditions) Zone bottom depth ................................................ 8200. Zone top depth .................................................... 8045. Pipe internal diameter .............................................. 2.992 Pipe Deviation ..................................................... 30.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 6024. Water density ..................................................... 0.9700 Water viscosity .................................................... 0.2770 Reservoir fluid temperature ......................................... 149.3 Minimum water rate ............................................... 1079. Maximum water rate ............................................... 2000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8920 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Feet Feet Inches Degrees Inches G r/cc Cp DegF Bpd Bpd Inches Ft/mn DegF PL Advisor Program Parameters for Zone 4 (at downhole conditions) Zone bottom depth ................................................ 8034. Zone top depth .................................................... 8005. Pipe internal diameter .............................................. 2.992 Pipe Deviation ..................................................... 30.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 6024. Water density ...................................................... 0.9700 Water viscosity .................................................... 0.2770 Reservoir fluid temperature ......................................... 148.2 Minimum water rate ............................................... 1495. Maximum water rate ............................................... 2000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8940 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Feet Feet Inches Degrees Inches Gr/cc Cp DegF Bpd Bpd Inches FtJmn DegF CONOCO, INC. Milne Point MPU C- 1~. Production Logs 04-Jul-90 PL Advisor Program Parameters for Zone 5 (at downhole conditions) Zone bottom depth ................................................ 7994. Zone top depth .................................................... 7950. Pipe internal diameter .............................................. 2.992 Pipe Deviation ..................................................... 30.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 6024. Water density ..................................................... 0.9700 Water viscosity .................................................... 0.2770 Reservoir fluid temperature ......................................... 148.0 Minimum water rate ............................................... 1533. Maximum water rate ............................................... 2000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688' Geometrical factor ................................................ 0.8950 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Feet Feet Inches Degrees Inches G r/cc Cp DegF Bpd Bpd Inches Ft/mn DegF MILNE POINT UNIT C-10 ACTUAL COMPLETION SKETCH COMPLETED ON 2-26-85 I,I OT E ~,: FMC TLI~ING MANGER w/ 3 /! 'M' 8PV PROFILE 1. All meeeuremenl! ere from KDB of 2. KOB - 5L : 52' 3. KDB - GL : 35' 81ant ty~e hole YES 7. MIn. angle 29.8° ~ TD FMC 3 118' APl 60008 tree ~.h 3 1/2' 8 r~. treetop con.ectlon. 9. Min. reltrlction il CA~O 'D' ~p~ 0t 8250' (2.75" ID) 10. APl No. 50-029-EI278 I 1. Cemaletlon fluid IO,Z ppg ~I-NoBr Ciling eno cemo~l Information ouoO#ed off cllbflO Ind cemenf iketch. ~3 I/2",92# L-80 ButlreaS tul~n~ (2.992" ID, 2.867" dr~ft) 1909' CAMCO TRDP*IA - SSA $$SV ( 2.812" ID) 2814' 3409' 4076' 4674' 7338' 7877' GL M GLM \ ',, GLM \ GLM GLM GLM GLM GLM CAMCO 3 l/Z" KSUG GLM eOT P~q, Se~l A~-m~7 (3.25" ID) : T929' eOT 'NIB' pecaM (2 89" ID) CAMCO 'W-I' Saiechve hi. pla (2.812' ID) ~0' "MMG-2' ~ i Jrt ~ (~LM~ : 2.92 GLM 8050' Best dOnt (Z9 64' t0fol I~gf~ 425" C~, 5,00" ID} 4 SPt, 180° phasing, 2 5/8" g~n~ (Alldept~ from OIL log 2-21-85) LK-I 8'2 51 ' - 8Z70' MD 7204'- rg21' TVD 8 ~F, 90° pm3smg, 2 5/8 guns (All depths from OIL log 2-21-85) LK-2 ~2.78' - 8:308' MD 7228'- 7254' TVD FRACTURE STIMULATION 8 ' 20 - 85 Lower Kup ( 2 ) 69,OO0 lbs I$- 20 ISP ol/cl 3 I/2", g,2,#, L-80 8TRS lubl~ (3 I/2" BTRS I ....8203' 80T 'CL' ' . .... 8~4' ~T '29' ~t ~&e~ (5,875" ~, 4,00" 10~ ~J with ~,ll~t lXfl~ll~, ' ~403' PBTD 848~' 7". ~ L'~OBT~S (~.~7~" ID~ ~.1~1 drift] Pffi~UCTIO~ I. R/A Trocer Survey (I-30/31- [: FROM ? '!~ ADDRESS ,.:.' .,...... '.: .'::,.~ i..,. ~ ..~:...... .'..>. '..~ .:~,..'.~.... ,' ..:' "'"" ~ '....: ., . ..... ... ' '~.i'..!-:. '. '~ ?~C?~~ .. . .. :..:.. '.'.' ..:.....; '., . .....-.: . ,,., .. . ~ . .. ;?,:~..~,~. ~:.~ .... ~.. . . . . . ,.:.,.;[..... .. .. - , .,., . . .' .,..~ ..... ~, ..~ .,~.' . 5...' :~,:;=";...~-: ,,~ ....... . ,.. .-., ....... . .... ~ ... =. -..' ............. ~-~,_~,.?~.,;,,~ ...... . ~: "': :...:'..: :'.:,' "~::::. :,'},". :.'.,',-:::.: ,~.. :;:?~,:::~,. '. ~. 24 HOUR ... ~, .: .... . .;.~ CASE NO. ~' DOCUMENTS . : .. · ..... ..,*:?. - . GEORGE'S . COURIER SERVICE I82452 344-3323 CITY ~ STATE ZIP SHIPPER d,/,~'~,.:., ,,,~C'"~:-~,, IDATE ':71.'?"~i. ., . ~'Ji TIME --~,~,, i .,~ ~. ,. ::.,,..~ ('~. . TO.,-,',' ,..-., ,, . .- . . ',_ ~ , .. .~.~,~-~ ADDRESS :'"' "'J? ~'~"' //' ~/" ::C'. "' :~,-~," ' ""' ~ :' ~ ' ~ ~' / CI~ ~ATE ZIP X I RECEIVED BY SAME DAY P/U BY 3PM . .. .. ONE HOUR $ .[~] ONE HOUR · . . SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ I , ./' .-, .,.DATE I TIME SCHLUMBERGER WELL SER¥tCES I-IOU~;TOIN. 'rEx, AS 77~,5 JUL CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Marc Shannon ~,C, HLUMBERGEI=. WELL ~ERMiC, ES Pouch 340069 ?rudhoe BaT, AY, 99734-0069 Attn: Bernl e/Shelle:y C-~ent!emen' WFL, Run 1, 7/04/90 Enc;o~ed ore~,rintsofthe Injection Profile Log, Run 1, 7/03/90 Company CONOCO, Inc. Well Milne Point Unit C-lO Field . Mi!ne Point Ad<Jit;ono! prints ore being ~ent to: 1 BL prints CONOCO., Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: .George Lamb - OF 20t8 PER County Nnrth S!ope State, Alaska _l_B_L__prints, 1 RF Sepia CONOCO. Thc 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. 6 _D e~_~_D r i %~ Midland, TX 79710 At,n: John Carrol *(9! 5/685-5600) _l_~_L_~rints, 1RF Sepia Chevron U.S.A. .6001Bol!in[er Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) Alaska Oil & Gas Cons~ation / Commjssion ( 3001 Porcupine Drive \ Anchorage, AK 99501 k Attn: JOhn' BoYle The film is returned to Conoco, Log Library. We appreciate the priviIecje of se~incj you. .. prints prints prints Received by: ' g Date: / //z'~ ,JUL ! 3 !990 AIaska 0ii a Gas Gone, Ve~ truly yours, A~ch0rag~ SCHLUMBERGER WELL SERVICES STATE OF ALASKA U ,~/-"KA OIL AND GAS CONSERVATION COMK---~ION REPOh OF SUNDRY WELL OF._,.tATIONS J )¥ 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging Pull tubingx..~ Alter casin¢ __ Repair wellx___ Pedorate __ Other 2. Name of Operator CONOCO INC. 3. Address 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service ](' 4. Location of well at surface 894' FSL, 2360' FEL, SEC 10, T13N, RIOE, U,H, At top of productive interval 3510' FSL, 1023' FEL, SEC. 11, T13N, RIOE, U.H. At effective depth NA At total depth 3704' FSL, 888' FEL, SEC. 11, T13N, RIOE 12. Present well condition summary Total depth: measured 8505 ' true vedica~425, Effective depth: measured 8403 ' true vedical7336 ' feet feet feet feet Plugs (measured) NA Junk(measured) NA 6. Datum elevation (DF or KB) KB 52 feet 7. Unit or Property name Milne Point Unit 8. Well number C-10 9. Permit number/approval number 85-15/9-724 10. APl number 50- 029-21278 11. Field/Pool Kuparuk River Field Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 13 3/8 9 5/8 7" measure(:8052 ' -8070' · true verticg039 ' -7054 Tubing (size, grade, and measured depth)3 1/2, Cemented 8140'-8144'; Measured depth 99' 4843' 8483' 8166'-8170'; True vedical depth RECEIVED AJaska 0ii & Gas Cons, C0ml~[ssi0p~ Anchora~o 82-51'-8270' ~ 8278"-8308' 7112'-7115'; 7134'-7137'; 7204'-7221'; 7228'-7254' 9,2 # L-80 BTR$, 8203' Packers and SSSV (type and measured depth)BOT "HB" pkr, 7929'; B0T "2B" Perm pkr; Camco TDRP-1A; 715 13. Stimulation or cement Squeeze summary NA Intervals treated (measured) NA Treatment description including volumes used and final pressure NA 14. Prior to well operation Subsequent to operation R.epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 1363 0 0 1466 Tubing Pressure 0 2560 0 2606 15. Attachments Copies of Logs and Surveys run __ Daily Repod of Well OPerations X.__ 16. Status of well classification as: Oil__ . Gas m Suspended__ Service .u. ater !nj. 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed~'~~'~~'~' TitleI I Form 10-404 F~ev ~'6/15,88 Date/~::r'~'~ SUBMIT IN DUPLICATE ? WORKOVER OPERATIONS C .... ,~O SET F:'LUG iN W-i N'iF:'F'i..E AT 7968'. ~ ~ i'fiiRU, ND TREE.~ NU BOP, TEST BOP. POOH WiTH 3 1/2': TUBING, SSSV AND SEA!_ ASSEMBLY. RE¥')F.'ES-~'] SE:'AL ASSEMBLY AND c:. ~::. ...-._ ,. ~ ["]'Ii'"i WITH .3 1/2" "i'UB;[NF:i AND SSSV i::'RESSLIRE TESTING TO 8('~0".] f:'S'~-, iNSTALl .... G/L MANDREL AT '7853 ' F'OR C IRCULAT I ON F"URF'OSES. DiSI::'L. ACE HOLE WITH 'i':}~-2 F:'F'G NACi_-NABR Bi::'..' :i: NE: ~ SF'OT F, BBLS DIESEL ON TOP OF :5 1/:.:.7" X '7" ANNULUS. S TA'~:"~ ]: N T 0 PBR, T E S T TUB i N G TO 3000 F:"S :i:, T E S T 3 '± / 2'" X 7:' T('.) 2()00 1' .....~ ~:'F~ ,, ~ ND BOP, NU TREE, RDMO. COMPLETFZ i"i:[ T I NSPEC]"i ON. STAI[ OF ALASKA ALASKA OIL AND OAS CONSERVATION COfJtl~ION BOP[ Intpeotion Report I n~pe~toe Locke, fen (g~nerel} .~~ Well IIgC ~ Trlp tenk Ptt g~u~e Flow ~nl~Qr Blind rime Choke line v~lVll HCR rely. KIll llne vllvee Cht~k valve ) L~er Ke11~ ~;_, _ Bell ~ype Inefde BOP ..,.,,_. · Choke manifold Nvmber Humber fl,ngee _~ ~ _ - ,,, - . ·. . _~- ,, : _ c-~ " AdJueteble oh~e~ , ~ .:. -- TE,~T RESULTS1 _~ , ..., __, Failures ....... Tea~ CI~e ~ , hre Repe~r or repleo~mtnC of felled equf{~n~ to 1~ made end InlplOtOr/Co~'~lillOn offloe notified. Remlrkll __ , .... ._ _ RECEIVI'D OCT u :;:.. ]gill) Alaska Oil & Gas Cons, C,c, mmissio. Anchorage -- _ ..: - _ -_: - _-_ ....... --_,~., ::-- ~ :_---::___ ~/-- , ~_- -:::--- ~ ~ or{g · AOOCC 0 - lupervf~oe C.O0~ (rev 05/17/8g) IniptotOrl o. 0 ALASKA OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casing __ Change approved program __ Pull tubing x__ Variance __ 2. Name of Operator ! 5. Type of Well: Conoco Tnc. I Development__ Exploratory __ 3. Address Stratigraphic_ 3201 C Street Ste 200, Anchorage, AK 9503 Service_.M~ Suspend __ Operation shutdown __ Re-enter suspended well __ Repair well ~ Plugging __ Time extension ~ Stimulate __ Pedorate ~ Other __ 6. Datum elevation (DF or KB) KB 52 7. Unit or Property name Milne Point Unit 4. Location of well at sudace 894' FSL, 2360' FEL, Section 10, T13"N, R10E, UM At top of productive interval 3510~ FSL, 1023' FEL, Section 10, T13N, R10E, UM At effective depth N/A At total depth 3704' FSL, 888' FEL, Section 10, T13N, R10E, UM 8. Well number C-10 9. Permitnumber 85-15 10. APInumber 50--029-21278 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 8505 ' feet Plugs(measured) N/A 7425 ' feet Effective depth: measured 8403 ' feet Junk (measured) N/A true vertical 7336 ' feet Casing Length Size Cemented c,./Measured depth Structural 13-3/8" O"" 99 Surface 9-5/8" 4843 ' Intermediate Production 7" ~~~ 8483' Liner Perforation depth: True vertical depth measured 8052-8070'; 8140-8144'; 8166-8170', 8251-8270'; 8278-8308' truevertical 7039-7054'; 7112-7115'; 7134-7137'; 7204-7221'; 7228-7254' Tubing (size, grade, and measured depth) 3-1/2", 9.2¢f, L-80 BTRS, 8203' Packers and SSSV (type and measured depth) BOT "HB" Packer~ 7929'; BOT "2B" Permanent Packer~ 8204'; Camco 13. Attachments Description summary of proposal ~ Detailed operations program __ TDRP-1A SSSV; BOP sketch 1909' 14. Estimateddateforcommencingoperation September 4, 1989 16. If proposal was verbally approved Name of approver NA Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water In-] ection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~,,~~ Title Senior Production Foreman r/ / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __. Mechanical Integrity Test _~.. Subsequent form required 10-/-f,~ ~ Original Signed David W. Johnsto~ Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 Date lappr°va' N°. Approved Copy Returned Date ~:;~ I~u",_~'-3 SUBMIT IN TRIPLICATE WELL C- 10 PROPOSED OPERATIONS . 2. 3. 4. 5. 6. 7. 8~ Set plug in W-1 nipple at 7968'. MIRU, ND Tree, NU BOP, Test BOP. POOH with 3-1/2" tubing, SSSV and seal assembly. Redress seal assembly and SSSV, RIH with 3-1/2" tubing and SSSV. Displace hole with 10.2 ppg NaC1-NaBr brine, + 350 bbls. Spot 5 bbls. diesel on top of 3-1/2 x 7" annulus. Stab into PBR, test tubing to 4000 psi, test 3-1/2 x 7" annulus to 2000 psi. ND BOP, NU tree, RDMO. MIT (Note' Communication is thought to be the result of a leaking packer assembly. ) I Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and .5 inactive production wells at Milne Point. B-3, ~-4A~ , B-6, B-9, B-10, B-Il, B-13, B-15, B-16, C-i, C-2, C-3, C-~, C-SA C-7 C-9 C-13 C-I~ C-16 STATIC: B-20, B-21, B-22 C-17, C-18 All active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injectLon wells in the Milne Point Unit. L.'~ L. ~ \' ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-Ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing~ A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. %ne weilbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questions on the shutdown procedure please contact Don G~c .... 564-7637. Yours very truly, STATE OF ALASKA ALASKa-. ,.)IL AND GAS CONSERVATION COMM, ,ON 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 2. Na~e of Oper,.ator 5. Dat~,elc,.~,ation (DF or KB) uonoco ~nc. feet 3. Add~e2~1 C Street, Ste 200, Anchorage, Alaska 99503 6. Unit.o~Promert¥ name .. . Fil/ne '~'o~_n[ unlI~ 7. Well number C-10 4. Location of well at surface 894' YSL, 2360' YEL, Sec. At top_ of productive interval 3510' FSL, 1023' FEL, Sec. At effective depth N/A At t~tC¢0~ePt~L' 888' FEL, Sec. 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. 8. Permit number 85-15 9. APl num%e~9_21278 50-- 10..POO~uparuk River 11. Present well condition summary Total depth: measured 8505 true vertical 7425 feet Plugs (measured) feet Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80 ' 16" To Surface 115' Surface 4806' 9 5/8" 1589 Sxs 4842' Intermediate . - Production 8449' 7" 67 bbls 8483' Liner Perforation depth: measured 8278'-08'; 8251'-70'; 8166'-70'; 8140'-44'; 8052'-70' True Vertical depth 115' 4641' 7492' true vertical 7228'-54'; 7204'-21'; 7134'-37'; 7112'-15'; 7039'-54' Tubing (size, grade and measured depth) 3½", L-80, 8240' T R SCSSV @ 19009; Ret.. Pkr. @ 7929' Packers and $S$V (type and measured d~pth) ; Perm. Pkr. @ 8204' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation Januar7 1987 14. If proposal was verbally approved ~. ~ .............. Name of approver ?,!2.s',(~Date~aCFfrove~o. - 15. I here~z_qertify that the,,fo[egoing is true and correct to the best of my knowledge Signed %I~.~--_~'~~L~._ Title Sr. Produc-t~on KnE~n~r Date Commission Use Only Approved by Conditions of approval [] Plug integrity [] BOP Test > ~,,..:-..-/_ /.~- ....... / /',' I~¥ L0~';,~ ~. S~if8 Notify commission so representative may witness [] Location clearance Commissioner IApproval No. ~/ 7 / by order of /, ~ the commission Date ,/~_./.>~¢:;/¢~. ~'~ Subrr(it in t"riplicate Form 10-403 Rev 124-85 October 1, 1986 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 {907) 564-7600 Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: Attached to this letter is an application for Sundry Approval to re-establish water injection into the Milne Point C-10 well. This proposal is recommended as a temporary solution that will be read- jdressed within the next six months. i / Y~, s~ery truly, ivision Manager DRG/vv C-10 Well File {.~C:'i' 0 .z lqRG Anc!iora~e ~ ~-'~" STATE OF ALASKA.- ~" ALA,, ,,. JIL AND GAS CONSERVATION COl ._,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 [] 2. Name of Operator 5. Datum elevation (DF or KB.) CONOCO INC. 52 feet 3. Address 6. Unit or Property name 3201 C Street, Ste. 200., Anchorage, Alaska 99503 Milne Point Unit 7. Well number C-10 4. Location of well at surface 894' FSL, 2360' FEL, Section 10, T13N, R10E, U.M. Attop ofproductiveinterval 3510' FSL, 1023' FEL, Section 10, T13N, R10E, U.M. Ateffectivedepth 3682' FSL, 915' FEL, Section 10, T13N, R10E, U.M. Attotaldepth 3704' FSL, 888' FEL, Section 10, T13N, R10E, U.M. 8. Permit number 85-15 9. APl number 50-- 029-21278 10. Pool kuparuk River 11. Present well condition summary Total depth: measured true vertical 8505 feet 7425 feet Plugs (measured) Effective depth: measured 8403 feet true vertical 7336 feet Junk (measured) Casing Length Size Cemented Structural Conductor 80' 13 3/8" to surf. Surface 4807' 9 5/8" to surf. Intermediate Production 8448 ' 7" 325 sxs. Liner Perforation depth: measured Measured depth 115' 4842' 8483' 8052'-8070'; 8140'-8144'; 8166'-8170-' ;8251'-8270' 7039'-7054't!ueT~-~_rLt2ica17115'; 7134'-7137'; 7204'-7221'; 7228' Tubing (size, grade and measured depth) 3~"; L-80 @ 8240' MoD, Packers and SSSV (type and measured depth) Packers @ 8204' & 7929'; True Vertical depth 115' 4643' 7405' ; 8278'-8308' -7254' C;C'i' o 3 1986 Alaska 0il & Gas Cons. Anchorage SCSSV @ 1909' M.D. 12.Attachments Description summary of proposal EX Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 1, 1986 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 _~~_~%,- ~, _~_L,,., Title Sr. Production Engineer Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Date 9/25/86 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner IApprOVal NO' by order of the commission Date 7~-/~-~¢(0 Submit in triplicate Application f~ dry Approval Well C-10 September 29, 1986 PROPOSAL: Water injection into the C-10 well was discontinued in May of 1986 after a tubing leak was detected. Low oil prices have forced Conoco to minimize operating costs and delay remedial operations. Unfortu- nately, lack of injection support from C-10 will eventually affect the production from two offset C-pad producers (one well has already fallen-off by nearly two hundred BOPD). Conoco proposes that the Commission allow water injection into the C-10 well under the following conditions; 1. Within six months an Addition Sundry Notice must be submitted to the AOGCC with a request for approval to initiate remedial operations, a justification for continuation of injection, or a request to discontinue injection. 2. Annular pressure should be monitored on a daily basis. 3. Casing pressure must not be allowed to exceed a pressure which will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength (4890 psi for the C-10 well). 4. A drop in casing pressure of more than 200 psi between consecutive readings, while injecting under steady state conditions must be reported to the AOGCC. Primary justification for this request is that the maximum casing pressure will never exceed the surface injection pressure because the annular fluids are denser than the injection water. Maximum injection pressure is 2750 psi while the burst rating for the 7" production casing is 7240 psi. In addition, the packer density of 9.6 ppg does not significantly add to the pressure differential across the casing. Conoco is also preparing an application to have the Tertiary sands classified as an exempt freshwater aquifier. These are the only non-exempt freshwater aquifiers penetrated by Milne Point wells. D. R. Girdler Sr. Production Engineer V¥ Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 27, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are daily drilling recaps for MPU wells B-5A, B-8, B-12, B-i4, B-i8, B-19, B-21, C-10, C-II, C-12, C-18. Completion reports were submitted by our letter of August 18, 1986. If you should have any questions please call Charles Taylor at 564-7606. Yours very truly, E. D. Wilson Division Administrative Manager CLT/vv Well File RECEIVED AUG 2 8 1986 Alaska Oil & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,...¢-~ STATE OF ALASKA ~ ALASKA .... AND GAS CONSERVATION CL MISSION 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~] 2. Name of Operator 7. Permit Number Conoco Inc. 85-15 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, Alaska 99503 50-029-21278 4. Location of well at surface 9. Unit or Lease Name 894' FSL, 2360' FEL, Sec. 10, T13N, Ri:0E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 3510' FSL, 1023' FEL, Sec- 10, T13N, R10E, U.M. C-10 At Total Depth 11. Field and Pool 3704' FSL, 888' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field 52' KB ADL 47434 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 2-13-85 2-21-85 Susp, 3-13-85 N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8505' (7425') 8403' (7336') YES~ NO[] 1909 feetMDI 1800-+ 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 361~ K-55 0 ARA2' 17~" 11~fi ~lz'.q P~rmm¢rn~P 7" 26~ I,-80 0 gag3' g~" 67 h'hl.q Clm.~.~ ~. 33 bbls Permafrost rio bbl.q Arcti p. Pmk 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) q~" gglqq' 7qgq~ /RgoR' 8052'-8070' (Middle Kuparuk) 8140'-8144' (L8) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8166'-8170' (L9) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OILoBBL GAS-MCF WATER-DEL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 5:--;',q '~ ''J " /;,. ;:', .;, , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · GEOLOGiC-MARKERS· . , ~. ' .i" ~ -i : :~ . .;~-'7~; '. ~ : -- FOX NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ugnu 3779' 3748' DATE SAND BOPD PWH °API WATER INTERVAL West Sak 4550' 4409' 3--~10 MK 8052' 70' Middle Kuparuk 8053' 7040' L8 150 110 22.5 0 8140'-44~ Lower Kuparuk 8250' 7204' L9 8166'-70' · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~:~J~~~'¢/' T i t I e ¢--~/~;~,/~ ~ ~/ ,// 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". Kuparuk River Field -~O'z~ SI.ope Borough, Alaska Wi~'%.~--~52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 AP1 No. 50-029-21278. Ak. Permit No. 85-15. Elevation: 52' KB. Location: 894' FSL, 2360' FEL, Sec. 10, T13N, RiOE, U.M. 2-13 - Accept rig @ 2030 hrs on 2-12-85. Install flowline, diverter line, mix mud. Strap & PU BHA, install diverter lines. Service ~CWD, function test 20" Hydril, finish diverter lines. Function test BOP & fluid test MWD. Drilled f/99' to 510'. Alaska United Rig #3 (0-1-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 8.8 ppg. Visc. - 88 Weather: Temperature: -41°/-56° Wind: NE 5 knots Visibility: 3 miles Kuparuk River Fie].d - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-14 - Drld. f/510' to 2800'. POOH f/2800'. PU BHA, test b~. TIH from surface to 2800, work through tight spot @ 1485' to 1585', bridge @ 1820'. Drld., surveyed, oriented f/2800' to 3205'. Surveys: 2775' Vertical Depth Angle Direction Depth An~le Direction 2886' 3.4° N 4E 3071' 7.7° N16E 2978' - 5.7° N15E 3162' 9.7° N23E Alaska United Rig #3 (0-2-0) Dr]g. Foreman - D.L.Mountjoy Mud Wt. - 9.2 ppg. Visc.- 36 Weather: Temperature: -48°/~78° Wind: SW 9 knots Visibility: 3 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-15 - Drlg., survey & orient f/3205' to 3864'. POOH f/3864. LD mud motor, change BHA & service MWD. PU angle building assembly. TIH to 3864', tight f/3210' to 3864'. Drld. f/3864' to 4337'. POOH f/4337. LD BHA, PU Mach I Navtdrill, orient bB~D to Navidrill. Surveys: Depth Angle Direction Depth Angle Direction 3253' 11.7° N18E 3813' 21.3° N19E 3346' -i3.7° N19E 3935' 24.7° N22E 3438' 15.8° N22E 4027' 27.2° N23E 3529' 19.2° N22E 4121' 30.2° N25E 3623' 21.4° N20E 4216' 31.8° N29E 3713' 20.I~ N12E 4307' 33.6° N34E Alaska United Rig #3 (0-3-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 9.1 ppg. risc. - 37 Weather: Temperature: -48°/-63° Wind: SW 6 knots Visibility: 2 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-16 - Orient ~D w/Navidrill. TIH f/surface to ~337'. Drld. & surveyed f/4337' to 4857'. Short trip f/4857' to 3200', had 4' fill. Circ. & cond. hole. Drop survey. POOH f/4857' to surface, LD 12 jts. HWDP & BHA. RU to run csg. Run 60 its. of 9-5/8" K-55, 36# csg., breaking circ. @ its. #30 & #60. Surveys: Depth An~le Direction Depth An~le Direction 4360' 34.6° N34E 4690' 37.2° N30E &512' 36.3° N34E 4797' 37.9° N30E 2-17 - Ran 62 jts. 9-5/8" 36# K~5~. BTRC csg.(total jts.122). S~oe @ 4842', FC @ 4760'. Total. centralizers: 72. Full] returns while running pipe. Make up landing jt. & Halliburton cmt. head. Circ. csg. Pumped 40 bbls. of 11 ppg Sepiolite spacer, 1156 sks. of 12.3 ppg Permafrost "E" & 433 sks. of 15.8 ppg. Class "G" w/3% salt & 1% CFR-2;. displaced w/9.3+ ppg mud ~371 bbls). Bumped plug to 2500 psi, floats held. Had full returns & circ. 80 bbls. of cmt. to surface. CIP @ 1500 hrs. LD landing jr., RD csg. tools, LD cmt. head, ND BOP's. Do top job (10 sks. Class "G" @~15.8 ppg w/3% salt & 1% CFP-2).Install Tankco trash ring & lock ring; install speed head, torqued to 16,500 ft/lbs, NU BOP's. PU test jt. & test plug. Test BOPE: pipe rams, kelly cocks, blind rams, choke manifold w/250# & 5000 #, Hydril w/250# & 3500#. Test witnessed by AOGCC, B. LeNorman. 2-18 - PU 8~" BHA. TIH f/surface to 4741'. Drlg. cmt. f/4741' to 4762'. Tested csg. to 1500#, tested o.k. Drld. cmt. & shoe f/4762' to 4842'. Drlg. f/4842' to 4887'. Ran 12.2 ppg EbB~ shoe test. Drlg. f/4887' to 4948'. POOH. Change BHA, orient MWD. TIH to 4948'. Morning tour: BOP & drill safety meeting. Surveys: Depth An~le Direction 4939' 40.1° N30E 5100' 41.6° N28E 5251' 41.8° N26E Drlg. & surveyed f/4948' to 5820'. Dep.th Angle Direction 5500' 42.1° N26E 5776' 42.0° N26E 2-19 - Drlg. f5820' to 7745'. POOH f/7745'. Surveys: Depth Angle Direction 6027' 41.8° N26E 6284' 42.9° N26E 6519' 42.4° N24E 6705' 43.5° N22E Alaska United Rig #3 (0-7-0) Mud Wt. - 9.8 ppg. Weather: Temperature: -28° Depth Angle Direction 6955' 42.9° N24E 7206' 42.6° N24E 7491' 41.9° N23E Drlg. Foreman - D.L.Mountjoy-" Visc. - 40 Wind: SW 8-20 knots Visibility: 2 mil_es Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-20 - POOH. LD MWD & Navidrill & PU BHA. TIH to 7730' tight spots @ 5420'-5435' and 6755'-6615'. Clean out tight hole to bottom ~/7730' to 7745'. Drlg. f/7745' to 8345'. Surveys: ~ -An__n~ Direction 7693' 41.7° N22E Alaska United Rig #3 (0-8-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 10.1+ ppg. Visc. - 37 Weather: Temperature: -45~/-95° Wind: SW 15-25 knots .... Visibility:. 3-5 miles Kuparuk River Field - Morth Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 ~ CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-21 - Drlg. f/8345' to 8505'. Circ. bottoms up. Pump pill & short trip to shoe. Circ. Hi Vis sweep, drop survey & pump pill. POOH f/logs, SLM, no correction. RU Schlumberger. Log Run #1DIL-LDC-CNL-GR-CAL. RD Schlumberger Surveys: Depth ~ Direction 8449' 29.75° N33E · Alaska United Rig f~3 (0-9-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2+ ppg. Visc. - A1 Weather: Temperature: -35~/-80° Wind: SW 15 knots Visibility: 3/4 mile Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Mi]ne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-22 - RD Sch].umberger. TIH to 8505' .- · , no fill. Circ. & cond mud POOH, L/D DP & BHA. Change rams to 7". Run 7" 26# L80 buttress csg. Alaska United Rig #3 (0-10-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2 ppg. Visc. - 35 Weather: Temperature: -23~/-63° Wind: SW 18 knots Visibility: 4 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-23 - Run 214 jts. of 7" 26# L-80 Butt. csg. Shoe @ 8483', Float Collar @ 8403', ECP #1 @ 8238', ECP #2 @ 8131', Marker jr. @ 7953', 45 bow centralizers 36 r~gid cent. Circ. Mix & pump 40 bbls. Desco Spacer 8.3 ppg; mixed 67 bbls. 15.8 ppg Class G cmt. w/l% CFR-2, 3% HAL-24; displaced w/321 bbls. of 10.2 ppg NaC1/NaBr; bumped plug w/1500 psi. Inf].ated ECP's w/3400 psi, held 15 min., floats held. CIP @ 1445. RD Halliburton. RU Dresser. Run #1 run gage ring, Junk basket, gamma ray f/8373' to 7900'; run #2 gyro f/surface to 8350', gyro spun out while POOH, no check shots f/3000' to surface; run #3 gyro f/surface to 3300', spun out @ 3300'. Checked w/first gyro run. 2-24 - Run #4, perf. gun run 5" - 12/spf, perfs @ 8166-8170 L9, 8140-8144 L8. Run #5, perf gun run 5"-12/spf, perfs @ 8052-8070 MK; Run #6, B.O.T. "2B" packer, did not set; Run #7, B.O.T. "2B" packer, set @ 8198'. RD DreSser. Change rams to 3~ & test 500-5000 psi. Run 3!~ 9.2# L-80 Buttress tbg. 2-25 - Run 3~ 9.2# L-80 Butt. 256 jts, 4 pups, B.O.T. "2B" pkr. set @ 8198'. B.O.T."HB" pkr. set @ 7910'. Drop ball, "HB" pkr. set w/2500 psi, shear out bail 3000 psi, shear PBR. Space out & install hanger; connect control lines & test to 5000 psi. Displace 70 bbls. diesel down tbg., 20 bbls. diesel down annulus. Land tbg. in head & lock down screws & test tbg. to 1500 psi, annulus 1500 psi, test the SSSV, 1500 psi & close SSSV. Remove landing joint. ND BOP's. Alaska United Rig #3 (0-13-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2 ppg. Visc. - 35 Weather: Temperature: -36°/-41° Wind: SW 4 knots Visibility: 15 miles Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-26 - NU tree; test pack off & tree to 5000 psi. Install BPV & secure tree. RIG RELEASED @ 1000-hrs on 2-26-85. DROPPED FROM REPORT PENDING FLOW TESTING. Alaska United Rig #3 (0-14-0) Drlg. Foreman - R. Larkin Weather: Temperature: -27°/-41° Wind: SW 5 knots Visibility: 10 miles STATE OF ALASKA ALASKA t~¢ AND GAS CONSERVATION CO..~VllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-15 3. Address 3201 C Street, Anchorage, Alaska 99503 4. Location of Well 894' FSL, 2360' FEL, Section 10, T13N, RllE, U. M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 12. I 6. Lease Designation and Serial No. 47434 8. APl Number 50- 029-21278 9. Unit or Lease Name Milne Point Unit 10. Well Number C-10 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] RePair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-10 well was recently found to have 2500 psi on the casing by tubing annulus which is identical to the well injection pressure. Annular pressure was bled-off but increased to the previous level within two days. It was confirmed that the tubing leak was above the SCSSV by closing the valve and bleeding-off the tubing pressure. Initial pressure was 1800 psi. Eight hours after bleeding-off, the pressure had increased to 1500 psi (identical to the annular pressure). Pressure was then bled-off both the tubing and the annulus. After eight hours, the pressure remained at zero. Conoco proposes pulling the dummy valve from the top gas lift mandrel located 208' below the SCSSV. Diesel would then be displaced down the annulus to displace any water that was bled into the annulus. Once the annulus is displaced with diesel, the dummy valve will be replaced, then the tubing will be displaced to 4000± with methanol. The well will then be suspended, pending remedial work. The SCSSV will be closed, a BPV set and all surface safety valves closed. When a procedure for corrective action is complete, the proposal will be submitted to the State for approval. · 14. I ~ify that the foregoing is true and correct to the best of my knowledge. s,,..d%'% The space below for Commission use Conditions of Approval, if any: Approved by Form 10~,03 Rev. 7-1-80 Date May 7, 1986 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Repor'ts" in Duplicate _ . ~ ..... ~;J ..... Ai.~SK~,~,L AND GAS CONSERVATION C( )~ISSION 'SUNDRY NOTICES AND REPORTS'ON WELLS 1. DRILLING WELL !:3 ' ' COMPLETED WELL OTHER I-! 2. Name of Op~ator . . Conoco lac. ' .... 3201 C Street~ An,chorage~ A.laska 4. Location of Well 99503 894' FSL, 2360'.~EL, Section 10, T13N, RILE, U. H. o 5. Elevation in feet (indicate KB, DF, etc,) I 52' KB - I 12. 6. Lease Designation and Serial No. 47434 -' 7. Permit No. 85-15 APl Numb~ so-029-212~8 g. Unit or Lease Name Fctlne Point Unit 10. Well Number . C-lO " 11. Field and Pool -. · · guparuk River . . Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Perforate' Stimulate Repair Well NOTICE OF INTENTION TO: _ (Submit in Triplicate) [] Alte~ Casing l-! Perforations . · [] Abandon [] Stimulation [] 'Change Plans []' Repairs Made SUBSEQUENT REPORT OF: ' ' (Submit in Duplicate) · : '- [] ~ Altering Casing " 0 . [] Abandonment O [] Other :' :- .... [] Pull Tubing [] . ' ' Other * ~ - Pulling Tubing [] -- ' ._ (Note: Report multiple co~pletions on Form 10-407 with a submitted Fom~ 10-407 fo~ each completion.).;.;.,~ ..... a.:; ........~.: ..... ::~ .;-,-, ..: ....'.: .... 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any . · . · proposed work, for Abandonment see 20 AAC 25.105-170). - -. -. . - · The 'C-10 'well was recently found to have :2500 Psi on the Casing by tubing annulus': '.'-:' - :_ which is identical to ~he well injection pressure.. Annular pressure was bled-off - but increased to the previou, s' level within Mo days. It was confirmed that the tubing leak was above the SCSSV by closing the valve and bleeding-off the tubing pressure. . Initial pressure was 1800 psi. Eight hours after bleeding-off, the ~ressure had increased to 1500 'psi (identical to the annular pressure). Pressure was then bled-off both the tubing and the an~ulus. A~ter eight hours, Lhe pressure remained at Conoco proposes to conttnue"injection :into the'well and to monitor and reCo~d an~Ular -- pressure weekly. Production casing is 7" 26 PPF L-80 with a burst rating of 7240 psi. Maximum burst pressure on the casing with an annular pressure of 2700 psi and 10.2 ppg brine in the annulus would be 3380 psi'(assuming fresh water gradient on the backside and 7000' .TVD depth). Injection would be continued for a maximum of thirty days June 8, 1986). During this periOd, a proposal for corrective measures would be .. ': completed then submitted to the State. The corrective measures would be-implemented- during the thirty-day injection period. ;iIf the problem cannot be corrected, injection ' . . would be-terminated by June 8, 1986. :' [~ ' ' :' : -- ..... .. . . · · 14. I h~w. certify that the foregejl~ is true and correct to the best of my knowledge. . - - ·. . - - -. : - .. . -, ~ ~ = ~, ---[ ~1: .- ... ..- ' - - : -.* _ :..~'-,.u::::~;:~!~i.-. -T.:'i~? :' $i'gnecl t~/~'~'~'~/~ ~-,-,--._~~ '-:' ' Title' Senior'Production Engineer' Date MaY 7: i986' The space below for Commission use ' . ' ' Rev. 7-1~0 ~ ' ~ ~ '/ / ' ' and"Su~uent Reports" in Dupli~te II OPERATOR: CONOCO I~C. - . SURFACE LOCATION: 894' FSI,, 2360' FEL, .- .' Section lO,'~I3N, RIOE · BOTTOH HOLE LOCATION: · DAm 02/ 3/8 370&' FSL, 888' Section 10, T13N, .: · · ~ ~r .. : .. NOTES: I. 2. 13 3/8" ~8l H-40 at 99' I_ lVll I0115 !~1'S 9 5/8'. 36t K-55 Bits. at t843' Est. TOC at 7050'±~ ECP 8131' . ECP 8238' 26~ I.-80 Btr~. ! ~ - at 8183' :.. _ - All measurements fro~KDB of Alaska United #3 KDB - SL - 52' . KDB - ~L - 35' '. Hax. angle - ~3.5° @ 6705' H.D. KOP at 2800' Slant Type-Hole - YES (min. angle at TI) -..29.75®) 9 5/8' Surface Casin~ 1. Pumped &O Bbls of 11 ppg Sepiolite followed by 25 Bbls of water as preflush. 2. Pu.ped &05 Bbls (I156 sx) o~ 12.3 ppg Permafrost Type 'E'. 3. Pumped 88 Bbls (~33 ax) of 15.8 ppg Class "C" cement with 31 salt and II CFR-2. &. Displaced with 371Bbls 9.3 ppg mud. NOTE: Had full re~urns durin$ ~ob and circulated 80 Bbls cement. 5. Did top job with an additional 10 sx of 15.8 ppg Class 'G" cement with 3I salt and 12 CFR-2. CentraLizers: I per 80~ surface' - ~000' I per 40' &O00* - 48A2' 7" Production Casin; 1. Pumped 38 Bbls of 8.33 ppg Desco spacer as a preflush. 2. Pumped 67.5 Bbls (330 sx) of 15.8 ppg Class "G' cement with 12 CFR-2 and 0.3I Halad-2~. 3. Displaced with 321Bbls of 10.2 ppg NaC1-NaBr. 4. Pumped down 7' x 9 5/8" annulus: 33 Bbls of 15.6 ppg Permafrost "C" followed by 60 Bbls of 7.7 ppg Arctic Pack. Centralizers: I per 80' 50' - 3000', 6460' - 7000 1 per 40' 7000' - 8483' 7" x 9 5/8' Annulus 1. Pumped 33 Bbls of 15.6 ppg Pe~nafrost."C' followed by 60 Bbls 7.7 ppg Arctic Pack. Based on 100~ excess in 8%" hole. NOTES: ,J. KDO - eL · 35' 7. urn. ,SeoLo ~.e~ 4) TO L FMC 3 118' APl IO00~ t~o,s 0. MI4. rootrJ4ct~f~ Il CAMCO 8230' (2.75' If)) 10. APl NO. ~0-029-2L278 ~IL Io~ 2-21o85) Lo8 814(~- 8144' Id0 7l 12'- 7115' MILNE POINT'UNIT C-10 ACTUAL COMPLETION SKETCH COMPLETED ON 2-26-85 FMC TUBING 8161'-8170' 71 $4'-7131" TVD ... 4 ~PF, 180e pleoela& ~' S/I" ee.J ~AJI depflJ f~m f~L k~ 2-2J-8S) . LKol . 8~5 I'- 82'70' Id) - -. - - T~o4'-7~ ~D · ' . f~m iX. lu~ _. . 827U'-830S' HO ' . . 7228 FiqACTURtr STJIdUL&TION 8 - 20 - 85 i.e~ew Kep ( 2 ) 69,4:)00 lbs f6-20 ISP :240* Tdiq Td 0403' POT0 - 8483' ?', 26~1' L-8OBTRS (6.2760 1O~, 6.151' d~lft) o .. -._.._ STATE OF ALASKA ...~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 7. Permit No. 85-15 OTHER [] 2. Name of Operator Conoco Inc. 4. Location of Well 894' FSL, 2360' 3. Address 8. APl Number 3201C Street, Suite 200, Anchorage, Alaska 99503 5o-029-21278 9. Unit or Lease Name Milne Point Unit 5. Elevation in feet (indicate KB, DF, etc.) 12. FEL, Sec 10, T13N, RllE, U.M. 52' KB I 6 . Lease Designation and Serial No. 47434 10. Well Number C-lO 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as a water injection well on 12-4-85, and its status should be changed from suspended to service and classified as a water injection wel 1. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate " N SILL ,-~ LAGOON 'SCALE IN ~LES CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO-ORDINATES ARE Z~NE 4. Z. ALL GEODETIC POSITIONS ARE BASED N.,&. D. 19Z7. OFFSETS TO SECTION LINES ARE COMPUTED BASED-ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. I . LOCATION IN SECTION FROM S. L.INE 1168' FROM E. UNE Z256' 1229' 2459' 1595'. 2326' 1344' - -2494' 551' 2254' 665' 2289' 1009' 2396' 4. LOCATED WITHIN S~CT. I0, T I~N, RIOE, LLM.~AK. STATE PLANE CO'ORDS. NORTHINGS I EASTINGS 6,029,450.20 - 558,20~.57 6,029~509.93 I 557,999.98 6,0Z9 ~ 677.42 I 558 ,I~ I .06 ,029,624.27 557,963.42 ,028 ,854.07 5~8,2li .74 ,028,947.80 558 , 175.18 ,029 ~290. 40 55a ,065.29 GEODETIC POSITION LATITUDE 70029. 27. 86 8"N. ?0029, 2~. 4.71' N. 70°29' 30. 108" N. 70°29' 29.598" N. 70°29' 21. 807"N ?0°29'22.929"N ?0029, 26. ~07"N LONGITUDE 1490 31' 27.056"W' 149~ 31' 33.054"W. 14.9° 31' 29.137" W. 149° 31' 149° 31' 2S.95Z"W. 149° 31' 28.007"W. 149° 31' 31. 162 "W. DATE l CHEO<EEi 6. !,85 [ J.B.S. I I0. 30,~1. ! d.B.~. il il : 3.18,85 J.B.S. FIELD BCX)K :_ 22 -85 . 1114' 2428' 6,029~395.Z2 558,031.82 70°29'27'340"N' 149°31'$2'125"W' I 6. I, 85 O. S. 22-8~ 894' 2360' 6,029, 176.48 558,101.82 70029. 25.184"~ 149°~' ~. 115" ~ ' " ! I C' P A D .......... ~.~>~....o.~,~, ~'~% Ill. ~ , ~: [~ I ..... · ~ ~ p. --Oo ': ~.-. ' . ., I!1 I AS-BUILT WELL CATION CERTIFY THAT.I AM P~OPERLY ~L~.. ~"::~:~ %-??M III t ll[~] I 0 -~:~.~, '.. ,-'.~-~l~tl Ill& ~qRk I ,' · '00'il I ~',ZuFEsSION~L~',~ ..... I!1- A~ , ', / COU~ENTS= %~%- ~~ Vii 6 ~a~l~ns 'b~mmlssl01 CONOCO O~ 2' I John R. Kemp Manager of Alaskan Operations September 24, 1985 U. S. E.P.A. Water Division, Region X 1200 6th Avenue Seattle, WA 98101 Conoco Inc. 3201 C Street Suite 200 Anchorage. AK 99503 Attn: Mr. Robert Burd, Director Attached please find completion sketches, casing diagrams, and geophysical logs for wells C-10 and C-ii to supplement our letter of September 13, 1985. Also included for each well are more descriptive mechanical integrity test results. Because of the recent conversion of Milne Point Unit wells C-lO and C-ii from Froducers to injectors, Conoco is requesting an emergency permit under 40 CFR 144,34 (a) (3) for the wells. A timely response is appreciated because production should commence on October 20, 1985, and an injection delay would significantly impact oil production. I~?~ have any questions, please call Rod Schulz at (907) 564-7600. ~slV~y Truly, - ~ohhm. Kemp q' ~anager of Alaska Operations xc: Mr. C. V. Chatterton, Chairman Alaska 0±1 and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 C-lO ATTACHMENTS Ao See attached drawing. B. Pressure tested 9-5/8" casing for 30 minutes with no bleed-off. Pressured up on tubing to 3000 psi to set packer. Pressure tested tubing to 15OO psi for 10 minutes with no bleed-off. Pressure tested 7" casing-tubing annulus to 1500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5000 psi for 10 minutes with no bleed-off. C. A report was submitte~ on May 15, 1985 which was approved on June 21, 1985. D. No defective wells. E. Included are prints of the DIL-SFL-GR and LDT-CNL-CAL logs. -i MILNE POINT UNIT OPERATOR: CONOCO, INC. NOTES: SURFACE LOCATION: 8cl0r FSL, ~-~.~O /cE'Z., BOTTOMHOLE LOCATION: 3904 FSL, 8,~ FEL. SPUD DATE:: ;;2.-~- 25' I. All measurements from KDB of Z. KDB - SL = , 3. GL - SL = , 4. Max. engle = ~-3,5'" 5. KOP , 'O ' 0 · O '[ °"" ....~'/z~/~ *O PBTD (:~ ~ · · · · / 6. Slant type hole- ~/~-5 (t~,,., o.,.,..~[~ ~ i NOTES: Al me&aurementa are from KDB of 2. KDB-SL 5~' 3. KDB-GL Slinl tyDe hole ~ FMC 3 111' ~PI 5000~ ~ree with 3 112%Rd. treetop conn~ct~of~. CASING: t I ,, L-8 $14o - MILNE POINT UNIT ACTUAL COMPLETION SKETCH COMPLETED ON o~-~- ~" ¢__..-/0 IfloCl-- ~o.~-o TP, OP-~Ft .~arOO~ -- GLnfl ! I 5qq q -- GL~ ')B]')'-' GL/W ---Iq~_c~'-- J[aT '~1~' j~¢cl~er [Z. SA" t:bk) ! .o · ['< ~ C F!V_E D ,'-~!ask'a Oi! & Gas Cons. Commission, ' '~ ""l'.'.' ,~. ,.~;, ~, . . ~ - .. John R. Kemp Manager of Alaskan Operations (conoc__ Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 {907) 504-7600 August 13, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-5, C-6, C-8, and C-10. These are being sent in response to your request dated August 2, 1985. If you require additional information concerning these well histories, please contact Kent Stolz at 564-7641. Very truly yours, ~tions "~ ALASKA 011. AND ~A$ GO#$EIlIIAI'IOII-GOMMI$$10# / 200, PORCUPII~IE DRIVE AI~/CHORA~GE.ALASKA 0050l'1-3f 0:~ 'rECEPHOI~E (007) DATE: TO: RE.' Loc. -~~ ...//'~ Permit No. We wish to bring to your attention that the Commission has yet received the following required items on the subject well which our records indicated was completed /~._~-/3~~ ? Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled*well. Please submit the above missing material. ~.~.e~~~C~C. V. Chatterton/ Chairman lc:C.024 ¢ono¢o John R. Kemp Manager of Alaskan Operations June 17,- 1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564~7600 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention C. V. Chatterton Gentlemen: Enclosed are the originals and copies of completion reports for Milne Point Unit C No. 6, C No. 8, and C No. 10. These updated completion reports reflect the change in bottomhole location from magnetic to gyroscopic survey. Should you have any questions, please contact Don R. Girdler at 564-7637. Yours very truly, Manager of Alaskan Operations JC/kss Enc cc: D. I. Robertson RECEIVED J U N 2 4 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ' ALASK/ L AND GAS CONSERVATION C i, MISSION WELL COMPLETi'" N OR RECOMPLETION' HEPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED){~[ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number CONOCO INC. 85-15 ,, 3. Addrp..~ 8. APl Number 3201 "C". Street, Suite 200, Anchora8e, AK 99503. . 50_029-21278 4. Location of well at surface 9. Unit or Lease Name 894' FSL, 2360' FEL, Section 10, T13N, R1OE, UM Milne Point Unit ,. At Top Producing Interval 10. Well Number 3510' FSL, 1023' FEL, Section 10, T13N, RiOE, UM C No. 10 At Total Depth 11. Field and Pool 3704' FSL, 888' FEL, Section 10, T13N, RiOE, UM I Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No.t - 52 'KBI ADL 47434 Kupa~-nk R~ver 12. Date Spudded 13. Date Y.O. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offs.bore 116. No. of Completions 2-13-85 2-21-85 Suspended 3-13-85I NA feet MSLI OlRe 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+-rVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8505, _7425, 8403, _7336, YES [] NO []I 1909 feet MDI 1800+- 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED -~ 5/8" 36// K-55 O' 4842' 12~" 1150 sks Permafrost E O 433 sks Class G 7" 26# L-80 O' 8483' 8~" 67 bbls Class G O 33 bbls Permafrost C 60 bbls Arctic Pak 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) 8052'-8070' (Middle Kuparuk) 3~" 8203' 7929'/8203' 8140'-8144' (L8) 8166 '-8170' (L9) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED NONE All perforations shot .at 12 JSPF 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 2 · · Alaska 0il & Gas Cons. Commission ~g Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ugnu 3779' 3748' DATE SAND BOPD P~WH °API WATER INTERVAL West Sak 4550' 4409' 3-10 MK 8052.' 70'~ Middle Kuparuk 8053' 7040' L8 150 110 22.5 0 8140'-44' Lower Kuparuk 8250' 7204' L9 ~ 8166 '-70' ._ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and'correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1: Classification of Service-Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DRILLING WELL COb~[ENC~4ENTS .'Kup~ruk River Field - N~-th Slope Borough Alaska W T - 52 0595~% Milne Pt. C No. 10 - C~ i;DENTIAL (8~62' - Kuparuk Rivez,_~AFE 10-61-1100 API No. 50-029-21278.--~. Permit No. 85-15. Elevation: 52' KB. Location: 894' FSL, 2360' FEL, Sec. 10, T13N, R10E, U.M. 2-13 - Accept rig @ 2030 hrs on 2-12-85. Install flowline, diverter line, mix mud. Strap & PU BHA, insta%l diverter lines. Service MWD, function test 20" Hydril, finish diVerter lines. Function test BOP & fluid test MWD. Drilled f/99' to 510'· Alaska United Rig #3 (0-1-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 8.8 ppg. Visc. - 88 ' Kuparuk River Field - North Slope Borough· Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-14 - Drld. f/510' to 2800'. POOH f/2800'. PU BHA, test PfWD. TIH from surface to 2800, work through tight spot @ 1485' to 1585' bridge @ 1820' · · Drld., surveyed· oriented f/2800' to 3205'· Surveys: 2775' Vertical Depth Angle Direction D~pth Angle Direction 2886' 3.4° N 4E ~ 3071' 7.7° N16E 2978' 5.7° N15E 3162' 9.7° N23E Alaska United Rig #3 (0-2-0) Dr].g. Foreman - D.L.Mountjoy Mud Wt. - 9.2 ppg. Visc. - 36 - . Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-15 - Drlg., survey & orient f/3205' to 3864'. POOH f/3864. LD mud motor, change BHA & service MWD. PU angle building assembly. TIH to 3864', t~ght f/3210' to 3864'. Drld. f/3864' to 4337'. POOH f/4337. LD BHA, PU Mach I Navidrill, orient MWD to Navidrill. Surveys: Depth Angle Direction Depth Angle Direction 3253' 11.7° N18E 3813" 21.3° N19E 3346' 13.7° N19E 3935' 24.7° N22E 3438' 15.8° N22E 4027' 27.2° N23E 3529' 19.2° N22E 4121' 30.2° N25E 3623' 21.4° N20E 4216' 31.8° N29E 3713' 20.1° Ni2E 4307' 33.6° N34E Alaska United Rig #3 (0-3-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 9.1 ppg. Visc. -~37 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - KupAruk River) AFE 10-61-1100 2-16 - Orient MWD w/Navidrill. TIH f/surface to 4337'. Drld. & surveyed 'f/4337' to 4857' Short trip f/4857' to 3200' had 4' fill. Circ. & cond · · · hole. Drop survey. POOH f/4857' to surface, LD 12 j ts. ~DP & BHA. RU to run csg. Run 60 jts. of 9-5/8" K-55, 36# csg., breaking circ. @ jts. #30 & #60. Surveys: Depth Angle Direction Depth Angle Direction 4360' 34.6° N34E 4690' 37.2° N30E 4512' 36.3° N34E 4797' 37.9° N30E 2-17 - Ran 62 its. 9-5/8" 36# K-55 BTRC csg.(total jts.122). Shoe @ 4842'· FC @ 4760'· Total. centralizers: 72. Full returns while running pipe. Make up landing jt. & Halliburton cmt. head. Circ. csg. Pumped 40 bbls. of 11 ppg Sepiolite spacer, 1156 sk~.. of ~.12~.3 .ppg..P~rmafrost "E" & 433 sks. of 15.8 ppg. Class "G" w/3% sal-~-&-~i% CFR-2; displaced w/9.'3'+'----ppg--mud' (371 bbls). Bumped plug to 2500 psi, floats held. Had full returns & circ. 80 bbls. of cmt. to surface· CIP @ 1500 hrs. LD landing jt., RD csg. tools, LD cmt. head, ND BOP's. Do top job (10 sks. Class "G" @ 15.8 ppg w/3% salt & 1% CFP-2).Install Tankco trash ring &'lock ring; install speed head, torqued to 16·500 ft/lbs, NU BOP's. PU test it. & test plug. Test BOPE: pipe rams, kelly cocks, blind rams, choke manifold w/250# & 5000 #, Hydril w/250# & 3500#. Test witnessed by AOGCC, B. LeNorman. ~2-~8 - PU 8~" BHA. ~--'~ f/surface to 4741'. Drlg. t. f/4741' to 4762'. Tested csg. to 1500#,.~_~ted o.k. Drld. cmt. & shoe ~_~762' to 48A2'. Drlg. f/4842' to 4887'. Ran 12.2 ppg EMW shoe test. Drlg. f/4887' to 4948'. POOH. Change BHA, orient MWD. TIH to 4948'. Morning tour: BOP & drill safety meeting. Surveys: Depth An~le Direction 4939' 40.1° N30E 5100' 41.6° N28E 5251' 41.8° N26E Drlg. & surveyed f/4948' to 5820'. Depth Angle Direction 5500' 42.1° N26E 5776' 42.0° N26E 2-19 - Drlg. f5820' to 7745'. POOH f/7745'. Surveys: D. epth Angle Direction 6027' 41.8° 6284' 42.9° 6519' 42.4° 6705' 43.5° Alaska United Rig #3 (0-7-0) Mud Wt. - 9.8 ppg. N26E N26E N24E N22E Visc. - 40 pepth An~le Direction 6955' 42.9° N24E 7206' 42.6° N24E 7491' 41.9~ N23E Drlg. Foreman - D.L.Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kup~ruk River) AFE 10-61-1100 2-20 - POOH. LD MWD & Navidrill & PU BHA. ~ TIH to 7730', tight spots @ 5420'-5435' and 6755'-6615'. Clean out tight hole to bottom f/7730' to 7745'. Drlg. f/7745' to 8345'. Surveys: Depth Angle Direction 7693' 41.7° ~22E Alaska United Rig #3 (0-8-0) Drlg. Foreman - D.L.Mountjoy Mud Wt. - 10.1+ ppg. Visc. - 37 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-21 - Drlg. f/8345' to 8505'. Circ. bottoms up. Pump pill & short trip to shoe. Circ. Hi Vis sweep, drop survey & pump pill. POOH f/logs, SLM, no correction. RU Schlumberger. Log Run #1DIL-LDC-CNL-GR-CAL. RD Schlumberger Surveys: Depth Angle Direction 8449' 29.75° N33E ~ Alaska United Rig #3 (0-9-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2+ ppg. Visc. - 41 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-22 - RD Schlumberger. TIH to 8505', no fill.. Circ. & cond. mud. POOH, L/D 'DP & BHA. Change rams to 7". Run 7" 26# L80 buttress csg. Alaska United Rig #3 (0-10-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2 ppg. Visc. - 35 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kup~ruk River) AFE 10-61-1100 2-23- Run 214 its. of 7" 26# L-80 Butt. csg. Shoe @ 8483', Float Collar @ 8403' ECP #1 @ 8238' ECP #2 @ 8131' Marker jt @ 7953' 45 bow centralizers 36 r~gid cent. Circ. Mix & pump 40 bbls. Desco Spacer 8.3 ppg; mixed 67 bbls. 15.8 ppg Class G cmt. w/l% CFR-2, 3% HAL-24; ~isplaced w/321 bbls. of 10.2 ppg NaC1/NaBr; bumped plug w/1500 psi. Inflated 'ECP's w/3400 psi, held 15 min., floats held. CIP @ 1445. RD Halliburton. RU Dresser. Run #1 run gage ring, junk basket, gamma ray f/8373' to 7900'; run #2 gyro f/surface to 8350', gyro spun out while POOH, no check shots f/3000' to surface; run #3 gyro f/surface to 3300' spun out @ 3300' Checked w/first gyro run , · · 2-24 - Run #4, perf. gun run 5" - 12/spf, perfs @ ~_~6-817.0 L9, 8140vS144.L8. Run #5, perf gun run 5"-12/spf, perfs @ 8052-8070 MK; Run #6, B.O.T. "2B" packer, did not set; Run #7, B.O.T. "2B" ~acker, set @ 8198'. RD Dresser· Change rams to 3~ & test 500-5000 psi. Run 3~ 9.2# L-80 Buti~s tbg. 2-25 - Run 3~ 9.2# L-80 Butt. 256 jts, 4 pups, B.O.T. "2B" pkr. set @ 8198'. B.O.T."HB" pkr. set @ 7910'. Drop ball, "HB" pkr. set w/2500 psi, shear out ball 3000 psi, shear PBR. Space out & install hanger; connect control lines & test to 5000 psi. Displace 70 bbls. diesel down tbg., 20 bbls. diesel down annulus. Land tbg. in head & lock down screws & test tbg. to 1500 psi, annulus 1500 psi, test the SSSV, 1500 psi & close SSSV. Remove landing joint. ND BOP's. Alaska United Rig #3 (0-13-0) Drlg. Foreman - R. Larkin Mud Wt. - 10.2 ppg. Visc. - 35 K~paruk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 10 - CONFIDENTIAL (8462' - Kuparuk River) AFE 10-61-1100 2-26 - NU tree; test pack off & tree to 5000 psi. Install BPV & secure tree. RIG RELEASED @ 1000 hrs on 2-26-85. DROPPED FROM REPORT PENDING FLOW TESTING. Alaska United Rig #3 (0-14-0) Drlg. Foreman - R. Larkin STATE OF ALASKA ALASKA c AND GAS CONSERVATION CC /IISSION -MONTHLY REPORT ¢ DRILLING AND WORi OVER OPERATIONS · Drilling well E~X Workover operation [] 2. Name of operator Conoco Inc. 7. Permit No. 85-15 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21278 4. Location of Well at surface 2360' FEL, Section 10, T13N, R1OE, U.M. 894' FSL, 6. Lease Designation and Serial No, ADL 47434 5. Elevation in feet t'indg"~ate KB, OF, etc.) 52 'KB 9. Unit or Lease Name Milne Point Unit 10. Well No. C No. 10 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of May , 19 85 12. Del~th at end of monzh, footage drilled, fishing jobs, directional drilling problems, spud date, remarks None. 13. Casif~g or ~ine~ run and quantities of ceneflt, ~esults of pressure tests None. 14. Coring ~'~e a¢~l b¢ief dea:~i~tion None. 15. Logs run and de~r.h where run None. 16. DST data, perforating data, shows of H2S, m~sceiJaneous data None. Well suspended. Completion report to follow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 *DDITIONAL TAPES TO: = * ]ITIES .SERVICE' BAKERSFIEIJD, CA ~EADING & BATES :TULSA, OK Jt{EVRON USA:ANCHORAGE kLAS KA OIL&GAS:ANCHORAGE X)NOCO :ANCHORAGE ]ONOCO: PONCA CITY, OK SCHLUMBERGER OFFSHORE SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 N_e 000604 1/// COMPUTING CENTER PRINT CENTER WELL NAME SERVICES WELL NAME ' JOB NO. ADD'L TAPES NO. OF BOXES' JOB NO. ' ADD'L TAPES ' WELL NAME SERVICES NO. OF BOXES' JOB NO. ' ADD'L TAPES ' - ,ff'ff,,z~d'-d ~? --/0 WELL NAME - /'-- ~Z'Pff ~/_~f' SERVICES NO. OF BOXES' JOB NO. · ADD'L TAPES ' WELL NAME · SERVICES · WELL NAME ' SERVICES ' NO. OF BOXES' NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER JOB NO. · ~ ~ ?. ~ r ? -. ' -~ ~'--- ADD' L TAPE DATE D:L. IVERED RECEIVED ~., STATE OF ALASKA ALASKA;~i_ AND GAS CONSERVATION O&__ ,~.., ISSION 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 Conoco Inc. 85-15 3. Address 8. APl Number 3201 C Street, Suite 200 Anchorage, AK 99503 50-029-21278 4. Location of well at surface 9. Unit or Lease Name 894' FSL, 2360' FEL, Section 10, T13N, RiOE, UM Milne Point Unit At Top Producing Interval . i VERIFIED ! 10. Well Number , FSL, 1025' FEL, Section 10, T13N, RiOE, UM jSur[.~, C No. In 3508' · At Total Depth ~'/ ~i 11. Field and Pool 3703' FSL, 890' FEL, Section,lO, T13N, RIOE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KBI ADL 47434 Kuparuk River 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 2-13-85 2-21-85 Suspended 3-~3-85I NA feet MSLI One 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8505'-7425' 8403 '-7336 ' YES ~] NO []I NA feet MD '1800-+ 22. Type Electric or Other Logs Run DIL-LDC-CNL-GR-CAL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED a ~/~,, ~A~ ~_~ (~' &g&?' 12 1/4" _1.~.56 sks Permafrost; ~, 0 433 sks Class G 7t' 26# T._~n O' R~R3' R ~/2" 67 bbls Class G, O 33 bbls Permafrost C, 60 bbls Arctic Pak 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) 8052'-8070' (Middle Kuparuk) 3 1/2" 8203' 7929'/8203' 8140'-8144' (L8) 8166'-8170' (L9) 26. ACI D, FRACTUR E, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED None All perforations shot at 12 JSPF 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I . Date of Test Hours Tested PRODUCTION FOR OILoBBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAY 0 · Alaska 0ii & 6as Cons, C0mmissiori Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - · · ; ..-..~ ~ . - ... . -'-: .. . :, ·: -. -.: ---:-~--' . , ~.,-;~'-~ · ~, ~;..i --. .-: '-~' -..'~'- : ~ . -~ . ~ ..~;;~:'¢.'- ' :~ .... · ; '~' ~ 7- ~ :~: ' ' ; · · . · :-r GEOLOGIC MARl(ERS :'": ..... ': --: ' :': ~r'?'""'~¥':-~ ~.~:~ ~:::',:'~:- ~'~ 'i ':r:"'-~-L" ¥~:~"FORMATION:~ESTS~ .':/ ~: ~-? '{ ':':~ : ~ . NAME Include interval tested, pressure data, all fluids recovered and gravity, · . MEAS. DEPTH TRUE VERT. DEPTH GOR, and trime of each phase. _ . · . Date' Sand' BOPD PWH °APi Water Interval Ugnu 3779 .' 3 748 ' West. Sak 4550 ' . 4409' 3-_10 MK~' ' 8052'-70' _ = _Kunaruk 8053," 7040"LL~ 150 110 22.5 0 8140"~44' Middle L-8 .... 8i40" 7111' . 8166'-70' · L-9 8166' 7133' Lower Kuparuk ' 8250' 7204' · . . : . · · : 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (Where .not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. . : . Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item· 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interVal. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etC.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". Directional Services Pressure Services Chemical Transmission Systems April 25, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Att: William Van Alen Re"- CONFtDENTIM- Our Boss Gyroscopic Survey Job No. AK-BO-50017 Well: C10 Milne Pt., Alaska Survey Date: February 25, Operator: T. McGuire 1985 William Van Alen: Please find enclosed the copy of our Boss Gyroscopic Survey on the 'above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. District Manager Enciosure cc: According to distribution list NL Sperry-Sun/NL Industries, Inc: P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED Alaska Oil & Gas Cons. Comrn/ss)o~ ::,F ERRV-.=,UN "I;,IELE - ~11RVEY INA' C:r'~MF.~ANY ............... i~AFiE 1 ANCHEIRAGE ALASKA C. ONOC:I], INC:. DATE Fig ':'i IRUFV FEBRLIARY ":'q ,~.,_ '~1 · ~, ...... ~ ,:, ,_, ...................................................... I,yF~U,z,L. UP I L. ~- RgEY ........ · ~-I'O .................. COMPL]TPi'T-IOM'- [iA ]'E .......................... BI~i!~;'._~- ':" .... F' ;~: ~.= ..... >.-:-F.i] =,, ........... id ILNE F'OINT FEBRUARY 25, 1985 ,_lOB NUMBER A1<-80-50017 .... :-q N G - 52. F) O F T ALAc, KA KELLY BU.~HI ELEV. - . OPERATORZHC~3U i-RE VERTICAL SECTION RALCULATED ALONG L. LUoLRE --- TRUE ......... SLIB=SEA' COLIRc, E~ COLIR.=,E DIDGZLEF~- .......................... --TL'iTAE ............................................... MEASURED VERT I CAL VERT I CAL I NCL I NAT I ON D I REC:T I ON SEVER I TY RECTANGULAR I]:OORD I NA'TES V.,ERT IF' '~L i- ,' ,-' -I ~' '-' SEC~ DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/100 N.IR FH/c,u.ITH EA~ F/WEL~T 0 0.00 -52.00 0 0 N 0. 0 E 0.00 0.00 0.00 0.00 100 .99. ';'7 47. '.-77 I 55 N 66.10 E 1. ¥?2 O. 6::-: N 1.53 E I. 31 -'-~200 1'99 :-92 ................ 1-'47]?.2 :[ ...... 3~- .............. N-67]-30-'E .............. 0':"3 I-- ..................... i"~ ".:~ O'-"N .............. -4']-3 ~,--E ..................... :_"-: ~-7' 1 .... '300 299.8'~ 247.89 1 25 N 71.19 E 0.22 2. :_::4 N 6.83 E 5.6.9 400 3:P9.86 347.86 i 8 N 65.80 E 0.30 3.65 N 8.92 E 7.37 ....................... 500 ....................... 499 ;'84 ............. 447';-8~ ............................. I .......... 8 ......N"'7~,'30"" E ........................ 0 ,"I 5 4 ;"35'"'iq ......................... 1"0:78 "E 8]' 86 ..... 600 579.83 54.7.8::: 0 57 N '77.89 E 0.20 4.81 N 12.56 E 10.07 700 69'.~.81 647.81 I I N 77.39 E 0.06 5.18 N 14.24.E 11.20 · 800 ......... 7$/9';"80 ............ 7'~7.--8. 0 .............. 1 ............ 3 ..... ~N-'- 75:'87--E ....................... 0':"05 ......................... 5";"'$'0'-' N --'I-~::-O'l-- -E- ........................ I'2~ 39 .900 :399.78 :347.78 0 57 N 70,60 E 0,15 6.10 N 17.69 E 13.61 1000 97'..~.77 947.77 0 48 N 76.60 E 0.17 6.54 N 19.16 E 14.68 .............. l-! '00 ............. 1-0 'P 9 ',' 76' ............. i' 047;-7 $- ................ 0 ......... 5'I ........... N-~.8 :"3 O' "E ........................ O'i'l' 3 ............................. G"Z-'P 8-N ................... ~O'ZSzF- -'E .............................. 15 ':'72 1200 1199.75 1147.75 0 46 N 71.1S/ E 0.10 7.47 N 21.88 E 16.77 1300 12~'?.74 1247.74 0 51 N 77.8.9 E 0.13 7.85 N 23.25 E 17.74 ........................1400 lc'~:~'-' '~7',:. .................. 1 oz~7.'"'-7~ -'~ ............................ 0 zI,.-~- ................... N 7~;. ~.0") ....................... E O. 1..'5 ...................... .c, .... 1'5 "N .......................... 1500 14'~..o.72 1447.72 0 49 N 71.69 E 0.13 '-' " ,_-,. 5'Z N 25.,_,':'/-_, E 1 '~ , "'; 1600 15'~9.71 1547.71 0 46 N 75.80 E 0.08 8. '.-? 1 N 27.19 E 20.52 · I'-700 .................... ].:S?..o';"70 ............... 1'~'47:'70 0 ....... '~1-: ........... N'-81":'I-T~'--E ...................... 0 :I"I .................................. 9':"-17"' N 1800 17~.9.69 1747.69 0 36 N 65. :BO E O. 19 '.-?. 4::: N 2'.-?. 51 E 22.09 1.900 18~..o. 6~ 1847.6..o 0 4:3 N 65.89 E 0.12 '.P. 'PS N -30.56 E 23.00 .................. 2000' ................ 1',~.~',-~'8 ............ 1'9~77'~'8 ................. O,'~.9-----'""N--"6'8'J'B'..~-'"E ................... 0'~"08 ....................... i 0 ~'-41"' 'N ................... 2100 20.9~. 67 2047.67 0 45 N 67.3'P E O. 10 10. :::7 N 32.80 E 24.85 2200 219~./:"7 2147.67 0 24 N 79.30 E 0.37 11.19 N 33.74 E 25.57 ....................... 2300 ............... 2277'~"~:.7 ............... '-22z~7':-~.'7 .............. 0 ....... I-0- ............. N' 82J'8 ..~"' E ..................... 0 ."22 ................................... i '1"-': 27' 'N ....................... '~4'~' 2'~-'"'E 25, 88 2400 2 :3 '.-.? 'R . 67 2347.67 0 ::: S :_::7.50 E O. 04 11.29 N ;::4.5:3 E 26.02 2500 24'~.9./:,6 2447.66 C! :-? S 75.50 E 0.04 11.25 N 34.80 E 26.11 .................... 2'600 .............. 25~/'~7"z.~6--- .... 25'z~'7-.-~;6 ...................... 0 .... 1'5 .................. S'--18';' 60' "'E .................. 0";'21 I'1 ',' 01 N ....................... ]::5-."0'0--'~ 25. ~'~ 2700 2d,'.~?. 66 2647.66 0 13 S 29./.-,0 W O. 20 10. 62 N 34. 'P7 E 25.64 2800 27'.-.?'.~. 66 2747.66 0 48 N 3. 0 E 1.02 11.16 N 34..91 E 26.08 ............ "2850 .................. 28~?':'~2 .................... 27?7 ~'62 ............3 .......... 7 ............. N 4,"8.~?' 'E 4.62 1'2.: 87' N 35:04"'E ................ 27, 66 CONOCO, INC. .......... C=i-0 .............................................................. MILNE POINT ALASKA ...................................................................................................................................................................................... OPERATOR=MCGIJ IRE VERTICAL SECTION CALCULATED ALONG CLOSURE SPERRY-.:-& N WEEIZ' .:,LRVEYING COMF'ANY PAGE ANL':HORAGE ALASKA DATE OF ~=:URVEY FEBRUARY 2'::....., 1':'" '-' ='::- ,=, ._, ............................ COMPL]TAT I ON'"'DATE ................................. BOSS "GYRO'.=;COP I]_-:--'SURVEY FEBRUARY=._":".~., 1'2:.35 ,..lAB NUMBER AK-BO-.'=;,O(')17 ..... KELLY B_Ic.,H I NG ELEV 5'.:-' ¢)0 FT ...... FRUE ...................... SUB=SEA .................. COURSE---[OUR"SE DOG=LzEG ......................... TO]"AE .............. MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY REC]'ANGULAR COORDINATES VERTI?'~L DEPTH DEPTH DEPTH .DEG M I N DEGREES BEG/100 NuRTH/..~uUTH EAST/WEST SEC]I ...- ..c;,(j t).-,,-,oc:, · .-c, ~. r. · 51 2847.51 4 19 N 10.6'.-.-~ E 2. ~2 16.07 N ._~,. 5¢).. E 30.71 2'~50 294..~. ':":' 2897 3:3 5 26 N 17 '" ' = c,- - ,=,L) E '.-" ~,4. =o 1~: N 36. M~ 7 E34 '~F, :-..:,0 ..'...,. 1 ,_, N ,i,~,. 1 ._, E .............. 3000 ................. 2'..799;,-05 ........... ~'..-74'7;'05 ...................... 6 .... 35' ....... N--1-Y";"'~'9'-E ........................... 2 '- ........................... ""'= ...... =' ..................................... ~ ')-' ' ' 3050 304:~, 66 '-' "'? '=,' [ 66 7 ':'"q '":' 1 "" 3 · .. .... :...., N 17 :~(] E ..' I O,'FY N ~'-? 99 E 46. i n, ,~,L) E 58 c, 7 /-,'=: N 42.4:_--: E 53,09 .c, 100 3098.16 :3(')46 16 8 ":'3 '.~ . ,, d~ %.1 d.. · ~ m~ ._1 m · '-'"'"' - ~'=' N '.~' i :~c.," E ":' '-'..'9 72,28 1'4 5/-,, 37 E 9('), ! 8 3300 ...:,.z..-.?4 ='--' .-...~-..~l._-, SE: 12 ....,_, · ...1,.'~ ".,~d2.-1'~"- · ,.,.,.. · -- . ~' ~ d~..'-- -- -- 3600 3580·~'~,_ ~,.,..' ,;.;,'~'-'-¢-". 85 21 13 N 21 , ._OF,' E .,:.."~', 41 1._4~ ,24 N 9'0 ,...u'-" E 178 .4~ 3700 3674 ":"-" "¥..,~"'-' 22 2(') '-" 52 · .:,(.) N 14 30 E ":' 66 1'"'-',:,,:, 06 N 101 16 E ":' 1 ..::'- m n m · · d~. · ~00 o7~7.6~ .',7I,.,. 6o ~I ~£) N ~o. ,:,0 E .~. 61 ......................... '"'"": .... ":":"'""~" ....................... ' ...... ~ ...................................... 3'200. 385~.. 4~ 3807.49' z. 4 51 N ~'~"~:'~. ,_,'--'c~.. E .,,'-'. '..-'"~). ..'"'~':' ...... ".?. 1 N 1 ~":"6 · 7:=: E ~,_ ,=,. · _-, .', ~ ... ~ 6 ,.,..~ ,. ~., 27 .~..., N ~ 4. E ~.. ~...- .. . 1 ~ 4 . ~_ 8 E ..., .....................~- ;[ O0 '-'4;0¢~.;...j?' '~- :'---= ............. ..... ~'~...j ..='~ ......... ?~,~)' ........ ~1 -- ....... N ~'"~7 · ...,[]=' E:'" ........................ .~,/..~, ........ :; .... ........................ ':,' ~..,:...':,-o..z~ .............................. N 1 ~.,..,,..:.~.r-.,:.,,,:-.,.., .................................. E ....... ':":'~ (')i' ..~_, - ..~ , - , ,- .-,.-, ~, .-,.7~ .-, .. .-., ,-~ . .'j ?-.,,~. ,~ ¢'! .'-,, .:, 4~:00 41 ~ 1 · ~ 1 4[)6 ~..:~ 1 o~ .': N c,~. oD E ~.. 06, ~,,:- ..... 16, Iq 1 .;71..-. ~: E 4._,... .-~ .-, .- ..... . '~' ~ . ~.' 60 4..,c,. 79 N y.._.'~. 11 E 4,_ 7 J2':, .. 4300 4.'-0~,. 60 4153 60 34 19 N 34.60 E ~.. . ...............Z~O(.'IZ~.. ~7¥~'~ "~,_ ............. Z~ ~'t~..-'~Jm "~"*~-· ~.,~tO'~ ............... -~-~_:~_------.-r-O~.~ -"' -tr-~--.-~-~p4 ,.] .... ....... z~"~,.,E O. 77 4,_-,0 ,'-'~ ........... z~.,.,-o- ......................... N ~"~.Jz~ .......... · ~:7'"~ ...................... E ,.~ 4~],·"" .............. 77 ~ _ ~' ..-,._-: . ~-~ ~'-~'" 64 N ...-,_,7.46 E 601.67 4500 4.'~A~. 08 4317.08 ~6 16 N '"". 50 E I ._ ._-, ._ ~-,:,. '-"':' ~ 1 42 E 660 78 4600 444~~,,_~:'-~ 4397. ~':' '-'._-,63A N 31 A9 E 1 09 578 62 N '~ '~ · N.. ;., . · -- . # · ,' · · .........~700-45~ ,.'"~,58 z~ 77, ._,,=,='~"-------~- ,.., 7--1: ¢~ ............. N '"='-._,l, .................................. ~0 E 0;~0 5.,:-. ~":-:;'----'"' -.~-. ,..,._, N ......... ..... '='"-'-, 076,_,-'=' .............. E 7.._ ~. 6z~'-'.( .................. 4800 460..: 14 4557 14 o7 21 N '" · ,:, 1 '-"(' '-""--' ~' · ..:,.) E 0 1~ 681 65 N 06 E 781 11 · · # %..m I&,;' a~,. m · ":"- 3¢,' 48 N 31 1 () E 2 45 734 '::.',,9 N 414.::"'.'6 E :q*"~. 4900 4687 -.-~ 4635 '-~"= ' . ..-.v ..... ~-,~ 34 · .....................-,000~0~~~_ ............. ~r ........ Z~7~'~.-,..~'~_ ...................................... ~4 Z~TI ][. ~,-4 ' ............... z~O ,:,~,. ~(o-'~5 ............. N .z,O,~'"-~.z, .- ~ O· ~;'~.'..J 7."¢0, ...... Zl'"?.. ................................... N ~7, .-,7~ ............................. ~' .~QT~. . ,.../~'~ 5100 4828· 90 4786. ?.?0. . 41 43 N ~-'-'"',:,./.'~_ .. E ! .56 ..,47 .76 N 47'2. ,.':~"-'._, E 973 .62 ~2AO.. . 4913.47 4,=,6:1. .47 41 ~.[) N 27.3¢). E (2). '.:)4 '.*O&. _....F,c',_, N ._11 .11 E .'1.¢)4¢). 24 ..................,.., ._', 0 0= '""' .................... ~L9,=,7.88-"" ........ : .......... ~.. o...,O""'=--o'"'""""'J~ .......... Z~* ........................... "0 N '""".,::.7, I 0 E ............. 0;'2I ................ ?. 66',-01 N ... z~ I, 6._,~ ............. -'=' E 1107,0._=,, · _7N ~400 5062 ' '" 1 (")2~. ?] '~'~E 1174 (]'8 _ · 'U,:, 5 O' 1 C) · (]. 8 42 11 1'4:2:7 · 5 O' E 0 · 33 . . ... _.,:...=,"z":., ._, . . ~'= ' '~ '":" . . 1 17 N 6(.) .... 0'~ E 1241 12 · ...JO(..) 5136, .,.c-9 50:-':4, -..9 42 0 N 27 () E 0 :":8 '"'""= . ' c, t.,~ ,""~..I · , ............................· _600M ................. ._..." ~t 0 .M~ .......... 5....,=- ........... ..-=;'". =' oi ..., ,_, · ...'9'=..., ...................... q,...., ............ =._, ............ N' .,.' '..', ."V' ,=""'"" .... E 0 ,' I ~; 1 J 44 ,' 90'" N 6.:,...'"' 2 ".37 E ANCHORAGE ALASKA CONOCO, I NC. DATE ;IF_ '-'~.L~RVEY' ' FEBRUARY _';'3 , 1 '~'-'=, ow MILNE PO INT FEBRUARY '-'~ ~._, 1 ~ .,w JOB NUMBER AK-BCl-50017 ALASKA KELLYB_Iz, HING ELEV. -- 5~.00 FT. OPERATOR-zMCC~U'~R~ VERTICAL SECTION CALCULATED ALONG CLO'SURE I'RUE 'SUB=SEA ................... COLIRSE-- ..... CI]I-IRSE- ............. DOG=LEa ........................ TOTAL ......... MEASURED VERTICAL VERTICAL INCLINATION DIRECTII,:IN SEVERITY RECTAN?LILAR COORDINAT,ES VERTIF'~L DEPTH DEF'TH DEPTH .DEG MIN DEGREE..~ DEG/100 NORTH/SOUTH EAST/WEST SEC~ ~ 5700 5284.77 5232.77 42 4 N 26.69 E 5800 5358.95 5306.95 42 ? N 26.39 E 5~00 ........... 5433;I'2 .......... 53~;-I'2 .............. ~2---'-5------N-2~.~--~ 6000 5507.44 5455.44 41 53 N 26.3? E 6100 5581.82 552?.82 42 0 N 26.39 E 0.07 1204.74 N 663.5!5 E 0.22 1264.73 N 6?3.53 E .... ~ .......~ ......... 7~.:,.4._, E 0. I.., I~z4.76 N .......... ~' ...... 0.24 1384.6,7: N 753.30 E 0.11 1444.50 N 783.03 E i375.09 1442.14 i576.09 1642.91 ~'20'0 ............ 56'55 ;"72 ........ 5~'03'; 6300 5729.12 5677. 6400 5802.61 5750.6,1 42 33 N 25.80 E 0.2'.'? 1627.15 N 871 . 84 E 1845. 6500- ............ 5',~76-.-'39 .......... 5'8;~4';--3'~ ............. -42----21' -N--'-25T7. 50 "E ....................... 0720 ............. 1'-~;8870 O-'N .................. .9'OTT-'O'~--E .................. I"~'I'3 6600 5949.85 5897.85 43 4 N 24.89 E 0.83 174'.;/. 39 N 929. ?5 E 1981 . ......................z~...'" .... -4.:-';' ............. N ""z6. ......................................... 0 E O. 7'_',~' ................... I..,(.)4.~' ...... ':/'=.'. ,-, ..................... Iq ,_ 1 -' .77'D ""-' .................... E ......... 171 (')""2A. _" 4.2 50 N'..' .-,'"=. 69 E 0 · ~4 1SAA_ _.. 07 N P.,4~.'"' · ..'~':',_, E 1778.14 ..'?2 16 6700 6022.55 5.970.55 43 38 N' 24. 0 E O. 83 1811.88 N '.-958.36 E 2049.71 ................. ~800 ................. -~0.95";'1'0 ............... '60'~3 ;'"I"0 ............... z~3 ...... 2'I ............. N-"2ll-, ..... O'-E ........................... 0 ,"2 ? ............... 1'874".'"76""' N .................... :..-?8'~;'T'35-'E .................... 2'I' 18 "- -40 6900 6168.05 6116.05 42 57 Iq 2:3.89 E 0.40 1'~37.27 N 1014.12 E 2186.65 7000 6241.31 6189.31 42 49 N 23.80 E 0.15 1 ??'.-.?. 52 N 1041.64 E 2254.57 _~,' 7I'00 ................. 65~I'4T"70 ............. 7200 6388, 45 ":-'"'/' '-' '-' ""-~ ' (') ~'" '"~ :-'"' '~ '~:~ ':'-' -' --,'-,,-,,- 6,.,o:-,.45 4~. 1.c N z.,:,.6(.) E .... -, z.:..':.:,,c,l N 10~..,.../,:, E .~..:,,:,~,/u 7300 646,2.72 6410.72 41 51 N 23.69 E 0.36 2184.95 N 1122.84 E 2456.50 -': ................. -74 O0 ................ 6-597;."3'0 ............... 6485';" 30 ............... -4-1 ......... 4 IT .......... N-23 ;"I '"'E 0737 .................... 22'~ 8';-06;""N 1 I'49";-35-E .......................... 2 522' '94 7500 6611.86 6559.86 41 53 N 23.19 E 0.20 2:307.31 N 1175.61 E 2589.3:--: 7600 6686.37 6634.37 41 46 N 22.89 E 0.23 2368.6,8 N 1201.72 E 2655.86 ............... : .... 7700 ............... 6'7'~' 1"; 25-.- ........... 6'70'9';' 25 .... T '~'I.'--1'5-:'".--TN-23:-~ 0"- E O'T"6 ~ .................... -2'42'P'; 58'" N ................ 1'227:' 88'""'E ..................... 2721 ',' 94 7RO0 6837'71 6785.71 : :38 .5'.~, N 25.60 E 2~6:I 24:-':8.18 N 1254.68 E 27:E:6.28 7?00 6.916. 45 6864. 45 37 8 N 31.3? E 4.02 2542.."34 N 1284.02 E 2847.88 800'0 .............. -6'9'?.?'6";"~'_~; 81 O0 7078.10 7026.10 7:4 48 N :36.89 E 1.4'.-.? 26:::7.61 N 17:!5:::. 0'~ E 2'~64.32 8200 7161.38 7,109.38 32 23 N 35.60 E 2.52 26,82.21 N 1385.81 E 3£)19.01 8300 .............. 72'4~";-70 ............... 7 I'?. il770 ..... .._'30 ..... 27- ............. N -.-311T-I'?-E ................... 2'~ 0-~, ........... 2'72'4 ~' 95'""' lq ............ i"zi'I"5";'?S'5--E ............... .S: 070]-'72 ........ 8350 7289. ?7 723:7. ?7 29 40 N 3:_'-:. 50 E 1.7:'-: '.'..."745.75 N 1429.6,0 E 3095.62 8400 7333' 42 7281.42 2'.-? 40 N 33.50 E 0.00 2'766.3? N 1443.26 E :--:120.24 8500 ............ 7~'20":-3.I ............ 736;B-,'3'I ............. -2? .......... zlO ............. N""33'/50"E O'ii"O0 .... 2807" '6'7"N ................. I'ZlTO'~'58-'E ............................ 3'1"69, 48 ...................................................... SPERRY=SUN WELL ,:,LIRVEYING COMPANY PAGE 4 ANCHORAGE ALASKA CONOCO, INC. DATE OF SURVEY FEBRUARY 2:3, 1'.~85 ......... L-:.=-IO ................................................. COMPUTAT I ON -DATE-'- BO,.,.:, L~YRLI._,L. UF I i.. oI:JRV EY MILNE F'OINT FEBRUARY 25, 1985 dOB NUMBER AI<-BO-50017 ALASKA KELLY BUSHING ELEV. = 52.00 FT. .............................................................................................................................................................................................................. AF'ERATOR=MCGU I RE VERTICAL SECTION CALCULATED ALONG CLOSLIRE ]'RUE ................. SUB=SEA cnr.]RSE ..... '~]IJRE:E ........... riOG'=E. EG ........................... TOTAL .................................................... NEASURED VERT ! CAL VERT I CAL I NCL I NAT I ON D I REF:T I ON .. EVER I TY RE .. FANL~LILAR CAORD I NATE'.:'; VERT D"" ~L DEPTH DEPTH DEPTH BEG MIN DEGREES ]]lEi]/100 NCIRTH/SOLITFI EAST/WEST SEC]{ ,q 8505 7424.65 7372.65 -..-'--"-"/ 40 N 33.50 E 0 .0¢:) .,o~""""~"~;. 7:3 N 14'71 . "'=~._, E 3171.94 HORI-ZONTAE-DI SPEACEMENT'"'= ........ 31-7'I-;-94 ..... FEE-T-AT-NORTH-27-DE'G';- ..... 3:5:'-'M I Iq-: EA.'_=;T'-A."'-'-'"~,-,,.."'~ ............ - c,..,,.='o~?, ,, THE CALCULATION F'ROC. EDURE'._~ ARE BASED ON ]'HE U~E OI-- THREE DIMENSIONAL RADIL~, OF L. URVA]URE METHOD ................................................................ SPERRY:SLIN WELL SLIRVEVINO L'~OMF;ANY ........................................ F;AGE 5 ANCHORAGE ALASKA CONOCO, INC· DATE OF SURVEY FEBRUARY 2'3, 1985 ...... C='10 COMPUTATIO'N DATE" ' I ' '-'~ MILNE POINT FEBRL ARY ~._, 1':]:::~. __ dOB NI_IMBER AK-BO-50017 ALASKA KELLY BUSHING ELEV - ~. 00 FT. ..................................................................................................................................................................................................................... OPERATOR=MCGU IRE INTERPOLATED VALLIES FOR EVEN 1000 FEET OF MEASURED DEPTH ]'RUE SUB-SEA TrITAL MEASURED VERT I CAL VERT I C'.AL REL. TANL~L LAR F:ru]RD I NATES MD-TVD VERT I r:AL . ........ DEPTH .......................... DEPTH ........................... DEPTH ............... NORTHTSOUTH ...... EA'STTglES'T .... DX'FFERENCE- L. URREL.TI JN 0 O. O0 -52. O0 O. O0 O. O0 1-000 ........ --S) 9';" ;-77 .......... ~ ~'7 ;'-77 ..... ~' ' _-:5;-. 5~-- R' I'..o-.-l'~ - E' 2000 1999.6:E: 1947.68 10.41 N :-': 1 ' 67 E 3000 2999.05 2947.05 25.18 N 38.15 E z~.O00 ........... 39'4 .'?':"2~; ................. 38 ..o7;2~ 2 ..~..~:~20-"N ..................... l'~zT-;"58-E 5000 4763.64 4711.6,4 790.49 N 447.7:7 E 6000 5507.44 5455.44 1384.63 N 753.30 E 0.00 · n-: ....................... O' '--o_. ,:, ................... O. 32 0.09 O. 95 O. 6,3 50'Z'7~' ................................ 4'.-?':-7'P .,-':..:,6, '"/- "'-'% /-":' 492 · 56 256.20 ...... 7000 ......... ~2~'1-;~'I ........ ~;'I'._S~.-31' i ???. ,-.-' N ---I-OZ~ 86 ...'-44 6.2 (.)(.)...~ :241 '-' 8000 6996 6:~ 6944 6.'.~ .~,~o 1 46. N 1317 E 1 .... '" I I ~..s.,, ,, · ,-,~-,"..~ , 77 04 ~,~,.. 7424 65 7372.65 2809 73 N 1471. . ' I " ' ""i' · THE C:ALCLILATIrIN PROCEDURES ARE BASED ON THE I ISE OF THREE DIMENSICINAL RAF_IUS OF C. URVAILRE hlETHOD · , ......................................................................... ~:,PERRY-~.,_N~ ' ' ~"11 ............................ WELL SURVEYING CFIMPANY PAGE ANL. HURAL E ALA~--:KA CONOCO, INC. DATE OF SURVEY FEBRUARY~c,'-"-', lO']':.. ,-,._, ......... C=1-0 ....................................................................................................... COMPUTAT I ON 'DATE i ' MILNE POINT FEBRUARY 25, l'~A=..,_~, JOB NJMBER AK-BO-50017 ALASKA KELLY I'-' - ~'~ BI_m, HING ELEV 00 FT CiF, ERATOR=MCGLi iRE I NTERF'OLATED VALLIES FOR EVEN 100 FEET FIF SUB-SEA DEPTH ]'RUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL REF:TANGULAR COnRD I NATES MD-TVD VERT I F:AL ~ NURTH/:,UUTH EA~,T/WE~T DIFFERENCE ........ CCIRREC:T I ON ............ DEPTH .......................... [ EF l I'-I DEF'TH ............. ' ......................... '-' ' ................. 0 O. O0 52 ..................... 52;'00 152 152.00 100. O0 252 252.00 200.00 '352 .................... 352;-'00 ................... 300'700 452 452.00 400. O0 552 552. O0 500. O0 '~52- ................... ~52';00 ........ ~00¥-00 752 752. O0 700. O0 852 852, 00 800. O0 -52. O0 O. O0 O. O0 O. O0 0700 ................... O';-08-1xl O'.--I"G~E ..................... 0:0 0 ......................... 07'0'0 ........................................... 1.:2:7 N :3.10 E 0.06 0.05 2.45 N 5.69 E 0.10 0.04 '3 ;-26-N ......................... 8';" 0'2-'E 0: 13 ........................................ 0; '0'3 4.07 N ::~.E::_--: IS 0.15 0.02 4.63 N 11.76 E 0.17 0.02 5]-O0-'N ]..-3,]-zi.2-"-E ............................... O' ;,'" :t 8 .................................... 0 ;""0' I 5.3'..9 N 15.15 E 0.20 0.02 5.84 N 16.¢,3 E 0.21 0.02 .~52 ................ ?. 52;;"00 ................ .'P. 0'0 ,"0'0 ......................................... 6 ;'37'- N ................................. 1'8'-'z~9" E ............................ 0";;"'23"i.', ........................................ 0"'01 ................................................... 1052 J. 052. O0 J. 000.00 6.72 N 1.9. F:,'_=: E O. 24 O. 01 1152 1152.00 1'100.00 7.26 N 21.26 E 0.25 0.01 :J. ~ ~-~'" "" ..................... :I..'",...". 00 "~' ~'" .................. "J: ,"[ 0.00-~- ] ...... ,,"~'--z:'~'4-- ~'~. ,~, .. I~ .............. ~.~, .'o-. '-..__. ~"-:' -' ,-._, ._, r_ ~.~'" '"'~'- ~'-:. ~ c, .................................... ,.,r~-"O ].. -(' ..... 1352 1352.00 1200.00 8.0:t N 24.00 E 0.27 0.01 1452 1452.00 1400.00 8,32 N 25.22 E 0.28 0.01 ............................. I-552 ............... 1552'."00 .............. 1-50'0700 .................................... 8;'75"-' N ......................... 26";"57 '- E 0 ;;' 2 ? 0';-' 1652 1652.00 1600. O0 '.-?. 08 N 27. :E:7 E O. 30 0.01 1752 1752. O0 1700. O0 '.~. 28 N 2'P. 05 E 0. :30 0.01 :,FERRY-sEIN WELL c.,JRVEYINL~ 6:OMPANY ....................................................................... FAUE 7 ANCHORAGE ALA~-':KA C:ONOCO, INC. DATE OF .=,JRVEY FEBRUARY~':"R, 1985. C=l 0 ............. ...................................... COMF'L~'I'-I'O~- DATE MI LNE POINT FEBRUARY ':'~ =~, 1~,=,._, dOB NUIdBER AK-BO-50017 ALASKA KELLY BUSHING ELEV, = ~':' ~ =, 00 FT. I '-' .: L B-.=,EA DEF'TH I NTERF'OLATED VALLE._..-, FOR EVEN 100 FEET OF ,=:1 '-' TRUE SUB-SEA TOTAL' MEASURED VERT I C:AL VERT I CAL RECTANGULAR L. 3UR£ I NATE.=, MD-TVD VERT I CAL .... DEPTH ....................... --DEPTH ................... DEPTH .........NORTFiTS'OU'TH ..........EAST/WES'T ...... DIFFEREN 1852 1852.00 1800.00 9.71 N 30.02 E 0.:31 0.01 1:952 ................ 19 52 :-00 .......... 19'00-: 0'0 .......................... I 0;-2]:''-'''lq ......................... 31']- 15'-E .......................... 0732 ................................ 0 .-O'I 2052 2£)52·00 2000.00 10.64 N 32.23 E 0.32 0.01 :2152 2152.00 2100.00 11.11 N :3:3.40 IE 0.33 0.01 .......................... 2252 ........... 2252-;"00 ............. 22'00; O0 ............................... I"1-;' 25-'N ........ . ................... 34'",'-08 "'E 0 ;":33 0 ;'00 2352 2352.00 2300.00 11.29 N :::4.40 E O. 7::3 O. 00 2452 2452.00 2400.00 11.28 N 34.67 E 0.33 0.00 ............. 25'52 .................. 2552;00 .......... --250 0';'00 ............................. I1";" I' ?"'N ........................ 34% 3--E .................... O';-3q.- .................................. 0';- O0 2652 2652. O0 2600. O0 10. 79 N :::5.05 E O. :34 0. O0 2752 2752.00 2700.00 10.55 N 34.8L=: E 0.34 0.00 ................ ~--'""'"~L'",~-*"~,..,, i.~:..I -" ............. "',L~."'r.,. ~,..,.I.~, .................... 00 """"'.~LSO0. O0 1 ""¥"",~:.. ~:~.' ~ .............................. N ...,..~'--~l=t ........ (.),.jr.~ E (-)'" "."t,'~". ~ ..., ~/ (.). (..)._~" 2952 2952. O0 2900.00 20.42 N 36.65 E 3053 3052.00 3000.00 31.52 N 40.12 E --'3':1:"54- .......... 3'1-5'2-.-00 .............. -3I'0'0; O0 ~Zl.'5;'37-N ...................... 4'5';"81 ..... E 3256 3252.00 3200.00 : 63.21 N 52.82 E 3359 3352.00 3300.00 85.36 N 61.52 E , ~6,:. ,:.z~5...-. O0 ~z~O0.00 'i-II-;~'"N .................... 727.37-E 3569 3552. O0 :2:500.00 147:. :=:2 N :=:6.09 E 3676 3652. O0 3600. O0 179.97 N 98. 'F~5 E CONOCO, INC. .... C=-i-O MILNE POINT ALASKA ~PERRY=SI"IN'WELL''~'_ .:,URVEYIN~P'""~L. OMPANY .......................................................... PAGE R_ ANCHORAGE ALASKA DATE OF SURVEY FEBRUARY~._'~'~, 1'P85 COMPUTATION"DATE FEBRUARY 25, 1'~'~;~, .JOB NUMBER AK-BA-~¢)017_ _. KELLY BLISHING ELEV. = 52.00 FT. ........................................................................................................................................................................................................ OF'ERATOR=MCGt] I RE'- INTERPOLATED VALUES FOR EVEN 100 FEET OF '-'1 ol. B-oEA DEPTH TRUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL REF:TAN~]I ILAR r.L URD I NATEo MD-TVD VERT I CAL ....... DEPTH ............................. DEPTH ............................. DEF'TH ............. NORTHY'SOIzlTH ............ EAST'/WEST .......D I FFERENC:E .......... COI-~REF:T'I ON ...................................................... 3783 3752. O0 3700. O0 216.50 N 10'F~. '~ 1 E 31.19 7.03 :-~.~:':-.-~ I ........ ~:852;-00 ............. 38(~0 .~Cr~ .................... 255";-7'~--N ........... :I:-25 ;-~-6-- E' ............... 39-,---7x_-~ 8~'-57 4003 3952.00 3~00.00 300.51 N 145.19 E 51.10 11.:33 4117 4052.00 4000.00 351.12 N 170.30 E 65.97 14.87 'z;~5 ........... 4'1"52"-'" 00 ................ Zk:l:'O 0'¥ O0 ....................... -4:0'~':-'26--' N ................ ~0'2'". 28 "" E ........................ 83 '~"6 ~':~ ................................... '17';;" ~? 4356 4252. O0 4200. O0 45'P. 'P4 N 240.20 E 104.25 20.5:3 4478 4352.00 4300.00 518.1~ N 280.54 E 126.81 22.57 ~-E:03 ..... -z~'4'~;2~'00 ...... 4~0¢r.-0'0 580~-1'5-'N ...... -320";-3'~-'E' ............... -1-5'1-~'-0-1- ........................... 2~;':-'20 4728 4552.00 4500.00 644.41 N 35'P.47 E 176.15 25.14 4854 4652.00 4600.00 70',~-.,.'~4 N 3'2'..~.24 E 202.16 26.01 'z;'98'z~- ....... 4752-~-'00 ............... z~7'O0';'O0 ......................... 78I'"-'-87- N .......... '~'42'~-32'"E 232";-'6'~:;- 30:50 5117 4852. O0 4800. O0 858. O0 N 485.44 E 265.55 32. 5251 4~52. O0 4'BO0.00 . '.-'x37.26 N 526. ~3 E 2S.~'.-.'~. 73 34.18 5521 5152. O0 51 O0. O0 1097.78 N 60'R. 51 E 36'.-}. 14 :34.75 5655 5252. O0 5200. O0 1178.32 N '650.26 E 403.86 34.71 5790 .......... 5352'l"0'0 ............... 5300';"00 ................... I'259]~0..~-'N .................... 690'~"73' "E ................... '.'--438" 62 ............................................. 34'~"7'7 5'P25 5452. O0 5400. O0 1:::40.01 N 7:31. O'P E 473.45 :2:4. :_::2 605'..~ 5552. O0 5500. O0 1420.45 N 771.09 E 507.87 34.43 ,.PERRY-.:,UN 'WELE'"'~URVEYIN~]'"'-COMPANY PAGE' 'P ANE:HORAGE ALA~.,KA C. ONOCO, INC. DATE OF'-'i.:.JRVEY' FEBRUARY 22:, 1'-?'-'=. o._, ~-C=i'O- ......................................................................................... C-L'iMPEIT~-T'I ON'- DA TE M I LNE POI NT FEBRUARY '-'= 98.'s I , .~.~J., 1. . ~ii"iB N_IMBER AK-BCI-50017 ALASKA KELLY BUSHING ELEV. = 52.00 FT. ............................................................................................................................................................................................. OPERATr~R:iPIC~3CI I'~'l~ I'-' .:,UB-._,EA DEF'TH INTERPOLATED VALLE~ FOR EVEN 100 FEET OF '-' ':' MEASURED ........ DEPTH' TRUE SUB-SEA TOTAL .- VERT I CAL VERT I CAL RECTANGLILAR COORD I NATES MD-TVD VERT I C:AL DEPTH ................ DEPTH ............ NORTHTSOLI]'H .......... EA..-STTWEST ........ DIFFERENCE .............. CORRE~]T'I'ON ............................................... 6194 5652.00 5600.00 1501.86 N 811.26 E 542.94 35.07 6~',".3'1 ........... 5752:00 ..........5700';0 0 ...................... I'585 ';-l'B-N-, ........... B 51 ";' 5~" E ................ 57 '~;' 20 ................................ 36'-.-'26- 6466 5852.00 5800.00 1667.93 N :::91.49 E 615.00 35.80 6602 5952. O0 5900. O0 1751.21 N 930.7'.'.-' E 650.94 35. 'P5 6-740 ................. 6052';O0 ............. '~;'0'0 0;' 00 .......................... 1'837: 53.-~N .............. 96'~'; 78'"'E .......................... 58'8';'"~_4"8 3'7ZTZ~ 6878 6152. O0 6100. O0 1923.61 N 100A. 07 E 726.07 .'37.39 7014 6252.00 6200.00 2008.59 N I045.64 E 762.58 36.50 ........... --7150 ............ :635~'-;"00 .......... ~300';-'00 .............. 2093;-2~:-'N-','--'~ ....... I082';'-73-'E ................... 7.98';-7~ ................................ -3~,Z'I'B 7285 6452. O0 6400. O0 2176.15 N 1118.98 E 833.61 :34. :.-':5 7419 6552.00 6500.00 2258.10 N I154.51 E 867. ..................... 7553 ................. '665'2-;' O0 ................ '6'600';,"00 23'~'0';"4'0'- N .......... -]:"I 8~';'7'~'"'E ............................ ~0'1 7687 6752. O0 6700. O0 2422.15 N 1224.63 E '.-'.~35. 7818 6852. O0 6800. O0 2498.49 N 1259.74 E 966. ................... 7..'?'4-4 ................... 6..~ 52 :'-00: ........... ~.~ :~?00-;'-00 .................... 25 ~.z~.;- 76,'-N ................. I'278";"4'?-'"E ........................... ~ 92 ,' 8068 7052.00 7000.00 2623.10 N 1342.19 E 1016. 69 34.09 '~ 1 ....................................... 34':'22~ ................................................................ 70 :3:3.79 34 30.64 4. 5 ~:..'"' Z- ........ 'I..'"?" ........ -~' 21 2::. 76 81.88 7152.00 7100.00 2677.37 N 1382.35 E 1036.89 20.68 ........................ 8'306 ................... 7'252;"00 ............... 7200';-'00 27'27";"53'""'N ....................... I'~17"Z~O"'"E ....................... I"054";'"15 8421 7352.00 7300.00 2775.22 N 1449.11E 1069.39 15.24 8505 7424.65 7372.65 2809.73 N 1471.95 E 1080.35 10.96 ]'HE CALCULATION PROCEDURESiUSE A LINEAR INTERPOLATION BE]'WEEN THE NEAREST 20 FOOT'MD (FROM RADIUS OF CURVATURE) POINTS' ............................................................................................................... SPERRY'SUN' WELL" 'SLIRVE¥ I NG' COMPANY .............................................................................. PAGE .1. 0 ANCHORAGE ALASI<A CONOCO, I NC:. DATE OF SURVEY FEBRUARY 23, 1::;:35 .......... C=IO CCIMPUTAT ION- DATE MILNE POINT FEBRUARY 25 1985 ,JOB NUMBER Ak.-Bu-~oo17 ALASKA KELLY BI_oilING ELEV. 52 O0 FT OPERATOR-MCGU I RE ............................. INTERF'OLATED VALLEo FOR SPECIAL :,LRVEY F'OINTS ]'RUE SUB-SEA TOTAL. I MEASURED VERT I CAL VERT I F:AL RECTANGULAR I]:OORD INA TE'.=; "(' DEPTH .............................. DEPTH ......................... DEPTH .... NDRTH/.- OUTH EA.:,T/WE.:,T MA RI'.':..'ER-- 3779 3748 10 o696 10 21F, ]= · L._, N 1"- . ._ , (.) .-.; '-,,:~ . .:,.. E KA ..................... · -',,_~_l=, .......... , .,.'.'.'~ ---', ............. --., ~,,_-,---~_.-, ....................... -":,-'", - .~- ...................... r:: ...... :, ........................................................................ o~.,~;,-, o7 .. 0. ~U ,.,7,_,o .... 0 -.-,.,1.0.. N 1 1 ._,. 4~ rT. .................. I<B 3871 ' '-"' '-'-' 3,=,.:-~o, 08 3781.08 247· 86 N 122.17 E KC: .'~ ~ .'~,- .-, .-, ~ ,',,'~. .~ .-, ,-, .--,,-, .-.., .--, ..., ...~ ~,..;,o,.,.._ 1 ~,=,-',--, · ,.:, 1 -.'67, 90 Iq 13F)., 62 E KD ...... 7.J N 1 ._-,:,. C)~ E E A ~9(..5._, ,:,91,_,. (]7 ,:..-~A~. 07 .."84 .... '=' ............................. "'- .... 3995 .-,,:;,zt ~ q.~ .-,,--,,~.":, ,:,.. -, .... ~ ,:,o .. ~. c,--." 297.12 N 142.63 E LB 4062 4003.75 3.o51.75 '"'-'"= :~'=' · ~.-'~,.._,:, N 157·35 E MA z~ 151- zP,.;,=,O....4 ~[r2~....~ ,_,6~. 0 ~ N 'i 7,;,. 6'1 E .............. MB .................................................. 4~.:,5 4151 45 409'~ 45 403.95 N '~'"=' . . . . ~(:).~. 07 E MC . ~4~,. E NA 4~0~ O0 464,51 N 40 4366 4260. O0 ~ '" '-' '-~ z~-o~'~. --: ...... ............ 4,.,.,~. ':-~- ........................ 10 z~ .._~-~20. ........ I O. .......................................... 477.1 '-).. ............................. N ,-:~'-'~'~.~ .......'-: 1 E NB 4419 '" ' '-' 4~, 1 41 N 260 90 E NC 4o0,:,. 29 '"= '-"~ 489 · . · ,1 .,.~1 .. · 4444 /"~'"'-" ,=,6 4271 86 . .._,01 15 N -::,A'.~ 15 E ND -"r .-- '"' ._t · ~-i ii ~ -- , z~'zl'65 ................. z~3'4'0';"'87 .............. -4288-;'87' ..?,'*'~--3~'-"~,, ~.., _ ,~ .............. --~. -~A--~":,-'"'~. ~-,,.. ,,,, ,_ ................... ,,,-~t~' t./ ....... 43.<..,. 95 534.07 N 2~1,05 E NF' 4511 4377.' =- .. "'" ~.~, %.1 / .-,, I~' .', . · ol N '"" ' "' 4550 440.-.?, :'4,.? ~-'~:~ o ~ ~,5o '"" .... · :,0.=,. 79 E CiA ..........................46._~'~ ...................... 4480. ?..~'~- 44..' o.~"""~....- ...... ......................... 5~9;':2~-; ......................... N '"".--o ........ 1. ~; 1E IDB . 66c...'. 87 2367.45 N 1201.20 E i_INC. 7598 /=,684 87 '~'" 1=.-4 71 E Mi 76~,0_, 6752 '~'"' ,'-4~.'..3..., N ")'-' '-? . _ . ..',' 6700 .:,.'r, .--, .-.,.-, · o ................................................................................ SPERRY'~SLIN' 'WEEL '-'~;'URVF"¥ I NJ3"" ~iOMF;ANY ..................................................................................... P'AGE i 1 ANCHORAGE ALASKA CONOCO, INC. DATE OF '-'c, LRVEYI ' FEBRUARY ~,'- ~ l'~qM..,_~ ...... C=-10 COMPUTATION' DAT~ M ILNE F'OINT FEBRUARY '-'= 9'''~ ~ , z~,, 1; ,=,~, dOB NL MBER AK-BO-50017 ALASKA KELLY BUSHING ELEV. = 52.00 FT. ......................................................................................... ' OPERATORzNCOIJ IRE INTERF'OLATED VALUES FOR SPECIAL oLIRVEY F'OINT'.-'; MEASURED ~DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTIC:AL RECTANGULAR COORDINATES DE PT H ................... DEP TH--C---NORTF1ZS OUT FI ........ E-ABT7 W E ~ '~'R'-'~ 6903 73 'q= .._ o~. . ,--,,~ .., 1.73 *'qt- ........ '~' ................... · ..... 8~o 7oo ~. 5I 6 ~87. ~ 8070 7053.47 7001.47 o-:,~n 7~0o. 60 7151 60 2534.03 N 1279.04 E 2E,3-~7"I~-~-- ..... i~'3E.-~..E-E 2623.92 N 1342.81E 2703.99 N 1401.40 E P1ARRER T /I< I TTMK"I B/MK-2 , T/LK- 1 8'269 ............. 72'I'9-;"98 8278 7227.73 7175.73 2715.73 N 1409.38 E T/LK-2 8311 7256.18 7204.18 272~.56 N 1418.78 E B/LK-2 83~8 ........... 7305';'~'! ........... 725~;"~I ...................... 2753'~1-~-N ........... I'~34';'52""E ....................... B~"I 8350 7289.97 7237.97 2745.75 N 1429.60 E SURVEY DEPTH 8505 7424.65 7372.65 2809.73 N 1471.95 E ]"D Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: Date Required Date Received' Remarks " ,, Samples ...... _ . Core Description /~ Inclination Survey ...... - ........ ....... , Drill Stem Test Reports W~ ~, ,--~ ..... ¢~ Digitized Data ~~ ~_ ~ ~ ~ [~p~ . , ., ..... , . . . , _ . ,- CONOCO, INC. 3201 "C" STREET SCHLUMBERGER OFFSHORE SERVICE3 A Division of Schlumberger Limited HOUSTON, TEXAS 77OOI ANCHORAGE, AK 99503 Attention: D-AN ROBERTSON 1 APR. 85 POUCH 340059 PRUDHOE BAY, AK 99734 ATTN: B;~RBARA HARRISON PAGE i OF 2 , 2" 5" Enclosed are_ 2 prints of tl,e. & Cam _C_ONQ_C.O_,___I.NC ................... Fietd , County._N_O_.~H __S_=~.&~_~;_ .... _State ALASKA Additional prints are being ser, t to: ].BL nrint~. & 1RF -~'~:~[~O, "INC. OFFSHORE EXPLORATION F/OUSTON, TX 77252 1BL prints & 2RF : CHEVRON U._S__._A__._,. INC. ATTN: J.L. WEAVER CON0','=O, I blC. O~'i:' J~:{(>i~m BL IL.DING P.O:, BOX 2197 .... !!S~..~.:?.?P}D: ...... l:a ..... 7.Y.~5.2 .............................. z.,.~: O G. KIEL ._.~.~'I~._.p rh'~i's P.o. Box L36_% .... ATTN: H.E. GI LLILA~)_/6.3 5 6 The film 1BL .prints & 1RF CHAMPLIN PETROLEUM COMPANY .... P.O. BOX 1257 E N G L E wa O D ~_..._C_Q .... 8_0__1_5__0 ATTN: DALE BOSSERT 1BL prints & 1RF READING & BATES PETROLEUM CQ__ 3200 MID CONTINENT TOWER DATE: Gas U(~'-'~ornmission We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER OFFSHORE SERVICES A.D. HUFFMAN DISTRIGT MANAGER SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PLEASE REPLY TO CONOCO~ INC. 3201 "C" STREET ANCHORAGE, AK 99503 Attention: DAN ROBERTSON POUCH 340069 PRUDHOE BAY, AK 99734 ATTN: BARBARA HARRISON PAGE 2 OF 2 Gentlemen' 2 Enclosed are .... Drints of the __ Company CONOCO· TNC. Field MILNE POINT 2" & 5" DIL, FDC/CNL , Well C-10 , County. NORTH SLOPE _State_A.LASKA ! Additional prints ore being sent to: ~B]'.L_,p.~ints & 1RF Cl_Imo SERVICE OIL AND GAS CORP. '--~'16-i ..... BOX 939 ~- ;('r':Fr~ S F i ELD, ~ ...... CA 93302 ATTN': NEIL BUTTRAM C/O JIM QUINN prints ........ prints prints .......... prints ____,prints .......... prints ~prints 'The film is returned to CONOCO We appreciate the privilege of serving you. SO$-- ! .5 '5 [% - A RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Very truly yours, SCHLUMBERGER OFFSHORE 'SERVICES A.D. IIUFFMAN · o,'~'Jf;';3r ~i ~f~ i'~ ...... ~--, STATE OF ALASKA ~-', ALASKA"' _AND GAS CONSERVATION CC. MISSION MONTHLY REPORT OF DRILLING AND WORKOVER · Drilling well J~ Workover operation [] 2. Name of operator 7. Permit No. CONOCO INC. 85-15 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503 50- 029-21278 4. Location of Well at surface 894' FSL, 2360tFEL, Section 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 10 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 8505' TD Spud date 02/12/85 13. Casing or liner run and quantities of cement, results of pressur~ tests Size Wt. Grade From' To 9 5/8" 36# K-55 0' 4842' 7" 26# L-80 0 ' 8483 ' Cement 1156 sks. Permafrost E, 433 sks Class G w/3% salt. Top job-10 sks Class G w/3% salt 40 bbls. Desco Spacer,67bbls.Class G cement, 321 bbls. NaC1/NaBr. 14. Coring resume and brief description NONE 15. Logs run and depth where run SP-GR-DIL-SFL GR-CNL GR-CNL-LDT Caliper 4839'-8496' 3490'-4825' 7495'-8340' 4839'-8340' I 6. DST data, perforating data, shows of H2S, miscellaneous data Perforations 8166'-8170' 8140'-8144', 8052'-8070' w/12 JSPF , , RECEIVED 2 6 198 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate [;)~,, "'/ I on John R. Kemp Manager of Alaskan Operations Conoco Inc. 2525 C Street Suite 1 O0 Anchorage, AK 99503 February 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99601 Dear Mr. Chatterton: Attached is a Sundry Notice for Milne Point Unit Well C-10. The Notice is an application to perforate and complete. Verbal approval was given by Mike Minder on' February 23, 1985. If you have any questions, pi. ease call Don Girdler at 279-0611. Very truly yours, Manager of Alaskan Operations DRG/vv Sundry Letter cc: MP C-6 Correspondence File RECEIVED F' 2 5 198,5 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA .~., ALASKA ' AND GAS CONSERVATION C(. MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. CONOCO, INC. 85-15 3. Address 8. APl Number 2525 "C" Street, Suite 100, Anchorage, AK 99503 50- 029-21278 4. Location of Well 894' FSL, 2360' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet {indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 52' Pad 17'I ADL 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number C- 10 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well was drilled to a total depth of 8505' M.D.. It is now proposed that the well be perforated in the Laminated Zone 8140'-8144' (4') then in the Middle Kuparuk formation 8052'-8070' (18'). These perforations will be isolated behind tubing and produced through a gas lift mandrel. The base of the tubing string will be set above the Lower Kuparuk formation in order to perforate the Lower Kuparuk for water injection at a later date. (Lower Kuparuk is water bearing in C-10). · The perforations will be flow tested after releasing the drilling rig. Verbal approval was given by Mike Minder on February 23', ]985. RECEIVED F 2 5 198,5 Alaska Oil & Gas Cons. Commission Anchorage 14' I her~ertify that th~ ~egj~I~., Signed ~ "~ ,/~p~-~?'~-.~ ~" The space below for Commission use is true and correct to the best of my knowledge. Title Pro~!lr'F~ mn ~,ng~nc_c_r Date 2-25 -85 , Conditions of Approval, if any: Approved by ~prov~ C~ Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate January 28, 1985 Mx. James B. Fox Engineering Techician Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Milne Point Unit ~o. C-10 Conoco Inc. Permit No. 85-15 Sur. Loc. 894'FSL, 2360'FEL, Sec. 10, Ti3N, R10E, UM. Btmho!e Loc. 1350'FNV~, 962'FEL, Sec. 10, T13N, R10E, UM. Dear Mr. Fox: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the state is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. James B. Fox ~lne Point Unit C- 10 -2- January 28, 1985 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. L~here a diverter system is required, please also no~i~v_ ~.~ 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yo~.ur~, C. V. Chatter~ton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill applica- tion for Milne Point C-10. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Don Girdler at 279-0611. Very truly yours, John R. Ke2° ~~~ Manager of Alaskan Operations DRG/kr cc: MP C-10 Correspondence File REr' IVED JA 2 1985 Alask~ ~ .... . .... ,-nissiort ,' ' STATE OF ALASKA ALASKA f~iL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] s~RATI DEVELOPMENT OIL E~ SINGLE ZONE [] DEVELOPMENT GAS [] MULT.PLEZONE la. Type of work. 2. Name of operator DRILL [~ REDRILL [] DEEPEN [] Conoco Inc. 3. Address 2525 "C" Street, Suite 100, Anchorage, 4. Location of well at surface 894' FSL, 2360' FEL, Sec. At top of proposed producing interval 1650' FNL, 1100' FEL, Sec. At total depth 1350" FNL, 962' FEL, Sec. 5. Elevation in feet (indicate KB, DF etc.) RKB 52' Pad 17' 12. Bond information (see 20 AAC 25.025) Type Blanket 99503 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. 10, T13N, R10E, U.M. 6. Lease designation and serial no. ADL 47434 9. Unit or lease name Milne Point Unit 10. Well number CNo. 10 11. Field and pool Kuparuk River Surety and/or number 8086-15-54 Amount $200,000.00 KICK OFF POINT 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi. NW of Deadhorse miles 3054' @ Surf. feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8590' M.D, (7450' TVD) feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2600feet. MAXIMUM HOLE ANGLE 40°I (see 20 AAC 25.035 (c) (2) 21 SIZE Hole Casing 17~" t3 3/8' 12~" 9 5/8" 8½" 7" Weight 48 36 26 Proposed Casing, Liner and Cementing Program CASING AND LINER SE1 lING DEPTH Grade Coupling Length / MD TOP TVD H-40 PELP 80' 35' I 35' K-55 BTRS I 4850 35' I 35' L-80 I BTRS 8555 35' I , 35' I I [ 15. Distance to nearest drilling or completed well C-1 10 feet 18. Approximate spud date 02-14-85 3000 psig@ Surface 3800 P-~g~0 ft. TD (TVD) M D BOTTOM TV D 115' 115' 4885'I 4600' 8590' I 7450' QUANTITY OF CEMENT (include stage data) _+100 cf ±2400 cf CMT ±700 cf CMT 22. Describe proposed program: Conoco Inc. proposes drilling the subject well as a delineation well in the Kuparuk River filed. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20", 2000 psi diverter will be installed on the 13 3/8" conductor for drilling the surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests willbe performed as per state regulations. Maximum surface pressure is based on initial reservoir pressure. The closest wellbore will be C No. 1 which is a vertical well that lies within 10' of the proposed path of C-10. A navigational drilling assembly will be used to steer to the left of C-1. Arctic pack willbe placed in the 7" x 9 5/8" annulus after disposing to test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. -23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED~c~.~-~ ~-~~ ~ TITLE Engineering TechnicianOATE The space below for Commission use Samples required []YES [~O Permit number APPROVED BY Form 1 0~,01 Rev. 7-1-80 01-14-85 CONDITIONS OF APPROVAL Mud log required I Directional Survey required I APl number I--lYES []~-NO t [~YES [-1NO I 50- (.2 I Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 28, 1985 by order of the Commission Submit in triplicate Ie CEMENTING PROGRAM A~ SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-~ Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 The 13-3/8" conductor w~ll be set ar 80~ below the surface (115~ K.B.), then cemented to the surface wSth permafrost cement. Be The 9-5/8" surface casing will be cemented with 900± sacks of Permafrost "E" cement followed by 600± sacks of Class "G" cement. The top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The primary cementing job will consist of 700± sacks of Class "G" cement pumped around the casing shoe (estimated 2000± of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 200± sacks of permafrost type "G" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at 1700'±. 4500' - TD Predominately shale until the Kuparuk Sands - expected at 7000'± subsea TVD. III. FORMATION EVALUATION A. Sidewall cores to be taken as determined by onsight geologist. Be Wireline logs for the 8~" hole from T.D. to ±1000' above the Kuparuk interval wi].l include: Dual Induction Laterolog; Sypherically Focused Log; Litho Density; CNL with GR-caliper. IV. DRILLING FLUIDS A high viscosity gel-fresh water (non-dispersed) mud system O' - 1000' Low solids non-dispersed gel/water mud system 1000' - T.D. Ye DIRECTIONAL PROGRAM The well will be drilled to a pro~sed KOP of 2600', then build angle in a north 24.7° west directior~DThe closest that the C-10 will come to another wellbore is 3700'±~here the proposed C-10 wi].l be northwest of the existing C-1 well. An MWD too]. is to be run while drilling for surveying purposes. The C-10 wellbore will be diverted around the C-1 well by using a navigational drilling assembly. Final hole angle will be 40°. PAD C. WELL NOt 10; P~..OPOSED · HILNE PT., NORTH SLOF 'i ALASKA ......... i" ' . .... i ............. i .... i-~ ~ ¥'~ .... 71 i - ' ~ ........ ~ .... ii ............ I . - i : . . . ! ........ ~.._: ...... i .. ! . ~ ~ .... f ............... i -: - -- ~ -: - -~ ~ .... ~ ..... ~ '' ~ - ~' ' '1-' ' ~ ....... , } .... ...~:. ; ~.:: .... ~ i ' ' '''~ ...... ~ , - _ . ~ ~ _ _ ~ ........ KOP~'-T~D=2600;'THD=2600'~DEP=O-; ............ ; ............................... "'- ' i ' ' ' . ~ -.-~ ~ ........ i ~ : : .~ ...... 5 ; .... ) ....... ; ; ''~ ........ · · ILD 2'1/2 DEO ..... ~ , : i ........... .... PER I -: ~'--'4 - , t O0 FT; ~ ~ ( ....... ~ . ~, : , ... 30 i ......... ~ ~ ..... : · i i ~ : : ..... .... ~D=4190-DEP=530~ ~ . . ~ . ~ . . . ' -.,. ~ ~ i ~ ~. ~ ...... ....................... g'5/8' CSG' PT ~-'TVD=4600 - TMD=4885-DEP=97~'Y--~'~ ' AVERAGE ANGLE __~ . ~ : .~ ............. ; ......... ,._. ;Z: , ; ~ ...... ; : ' ~ N ;ID rVO=r350 T~D=8462 DEP~3262 ~ · ........... ; ...... : · i ..... i ........ ~ .............. t ............... ..... 8000 : ; 0 ~ ;1000 2000 5000 . 4000 · { Alaska Oil & B~s Cons. ;C°mmiss~on ~~,.. ~~ ............................... ~ .... VERT~ CAL~. SECT1 ON ~ ........... : ....... . ~ ......... ~: .... AnChorage ............... I I ; t' t ' .... :-"''- .......... ' "'-i '- '' ~ ''' ! : ' - : ..... : - ' ~ ........... : ' ! ........ ' ! ..... i ' i ....... ' '': - '' ~ .... i ' i i ~ . i t- ' I * '' i .... .......... ~. i .~ ...i -, i .... i I ~ .... ' - I' ' i ~ i "' ' ' ' " ' RECE]VEB "' ..... ............ ., . =_ ~ .... - · : - ' ~ 5 ............ ............ . ...... . .......... :~ ............. 5 .... : ......... i ............ : ......... ~._~ ............. i .........a ..........~__ .... · ' :::' ~' ~ ~ ' :~ ' ~1985' ' -- ', -, - - ~ .-. ~ - . CONOCO, INC. J -:..~ ~O0 _ ~PAD _C.j ~ELL~ NO', ~ O PROPOSED. ~ ~. ~ X ~e.m~_ ,~_; _~ ~ ......... . -- . . - HJLNE ;PT,,: NORTH SLOPE, ALASKA-~ '::'-;'::~:~- -~-;!::" :~;...~/:I':-:~ ..~ ' i .... HOR ~--XONI.^L .... PROJEC..,EI. ON_i-- ' i- ..,.;ALE li, IN. = 1000 FEET ! CONOCO, !NCo ~ : PAD C. WELL NOt 10 PROPOSED · HILNE PT., NORTH SLOPE, ALASKA ..................... , ......... ~ ......... ~ .................. ~ . ~ .... EASTHAN WH: PSTOCK, INC. , : ' '- ' WESTYEAST L_~ ! · . : ~ooo ' b '.. . -.~ooo 2ooo · 3ooo · ........... ; ....... : . . . : J . . .,. . : .......... · . i TAROEf LOCATION ~ ........... ~ !650'_.FNL, !!.00' FEL ..... ' ' ........................................ ~ .......... - ..... - ........ ? ..... SEC. I0. T13N. RIOE . . ., . . . . 4 - 4. 3000~ TD ...... ; ....................................................... J -TA T ,- - ~ ............... i ..... ~P-~O!2' .. -- , ~ ' _ ......... !~ ..... 2000--_ ' ~o . · ' ~- ' i - ~ NORFH 2736 t_ , ~ ..... : .... !'~ ~ EAST 1260 ' ' ' 't ..... ;~ -- - i ..... }. { -- ; ~ .... ;~ i . ~ ....... i ....~ ;~ . ~ - . , : { . . , - ....... ~ ......~ ............ ~ : _ -;_;'{~;;' ~ ; ; '' .... ............ ' ' - '-' ' ~ ............. LOCATION',: : ~ ~ -~ .................. ~ ...............................................~ .... ' ' ' - ...... i =~894' FSL. 2360' FEL ' { ''' ~ ' ' ~ ~ ~C, lO. TI3N. RI~ ' ~ ...... l.O00 .... '~ " ,-- , N 24 DEG 44 HI N E ....... ~ ..... ~ .......... " ........... ; ......................................... 3012-"-' (TO' TARGET) .......... ~ ....................... ~ ~ ~ , Alaska Oil'~ ~Oag C~ns.-Cdmmibsion ............. ~ " ; ; : · ' Anchorage ...... ~ ............ ~ ...... ................. :.::, l:::. I....,f,:::.,..:. ',1 !,,J Ii::: 1... I...::, [,.Jl!ii:i_ L. :L t.'..JF:Z L..L.. :;ii: ,z ........ I:::'T 'TO ~ Eastman ~ SIM~N LAGOON MILPi[ Fi'. UNIT . 21 ~ -"i -- .................... ,;"~ .................... [ T~ '. SC~t_F IN ~LES CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO-ORDINATES ARE ZONE 4. ALL GEOOETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. WE LL ! IJ)CATION II1 SECTION c-4 J PLANE CO-ORDS. CASTINGS GEODETIC POSITION FROMS. LINE FROM E. UNE NORTHINGS LATITUDE LONGITUDE DATE CHECKED FIELD BOOK C-! I 1168' 2256' 6,029,450. 18 $58,203.55 70°29'27-868"N. 149031'27.056" W. 4-20-82 LK. 10-82 1229' 2459' 6 ,029,510. 13 5§7,999.90 70029' 28.473"N. 149051, 33.056"'W. 12-8 -82 L.K. lO- 82 C-3 I 1395' 2326' 6 ,029,G77.35 558,131 .12 70°29'30. IOB"N. 149~ 31' 29.135" W. -4-20-82 L K~ 10-82 ~344' c- 5 ! c:JSl' c-6 ! 6G5' c-Igl 75o' c -'~ol & 94' 577,963.21 5c-~,, ZiI. $4 556, 17~. 21 .,_,8 Iol. 9C .55-8, OGg. 34 558 o~t. 77 70° 29' 29. 59¢ N. 7,::,'_7_9- Zl. Sol N 7~'- z~- 22 .fizz, 7o'- zc)_ 24.o541 7o"- z9- z$. J,5~ u 7o'- 7-9-~b..~o,:5 ,,.,J 7o'- 29 -27. 540 ~"! c-¢1 ,,, ,4' 149° 31' 34.089'W. t47: 51- z(::,. 9~t- w 2 -20-83 II - I - 2~4 II - I -&4 !1 -I fl - ~ - 84- i[-i- 84 I1-1 - [54 J.H, CERTIFICATE OF SURVEYOR : I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ~ND LICENSED LAND SURVEYING IN THE STATE OF ALAS~ ~Y SUPERVISION, ~ND Anchorage ENGINEERS AND L~ND SURVEYO.¢~5 'C' PAD AS- BUILT WELL LOCATION I0 ~ T I-~ h.' , '~Fc, Io Survej'ed for CONOCO · SCALE : J SHEET : I I" · 400' I OF 2 ~MF__L.L¢'5 T~J~'OUC~PI V,~---LLC- io AI~,F_. V~I ~-; LL- LDCATI 0 I,~ $ .... CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK Fill-up Line ~ ~ i20'' 2000 psil ! ~nular l Preventer / ~ HCR F . 1 HCR Valve' . , ~ Valve , ,, * Drilling ~ ,, 6 Relief Line ~'' ~) Spool (l" ~ 6 Relief Valve 1 0,, x , I 2o0o psi ~ ~ ~ Diverter Quick ~' ~ Con~ect Assembly · ~'-~.~1 /~l ~' I ~~} Assembly ~ ~ I %~ ! ,' ', 1. Relief lines.from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-uP Lineb Annular Preventer ~Flow Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet AP1 RP 53 class 5M requirements. LtRAM 13 5/8" - 5000 13 5/8" - 5000 2" - 5000 Side Outlets 3" - 5000 Side Outlets- i 3" - 5000 Side Outlets 13 5/8" - 5000 11" - 5000 RECEIVED Oii& 6.% Cons. Commission Aachorage ALASKA UNITED RIG NO. 3 DRILLING H H CHOKE . . . MANIFOLD: LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6"x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type ' Choke (2) Type 10,000 psi w/ (2) Manual (1) Automatic CAPACITIES ,ACTIVE SYSTEM I Sand trap 6 bbl I Oegasser tank S6 bbl I Desander suction 5~I bbl I Desilter suction SS bbl I Desllter discharge 66 bbl SUBTOT,AL Mud Tank No. I I Common 2 Suction Mud Tank No. 2 Receiving Discharge Mud Tank NO, 3 SUBTOT. A.L ,ACTIVE SYSTEM TOT,AL TRIP T,ANK SURF,ACE VOLUME GR^ND TOT,AL ~Calculated 4" below tank top} 237 bbl 38 bbl 122 bbl 18'~ bbl 184 bbl 240 bbl 76B bbl 1005 bbl 150 bbl I 155 bbl (2) HCR valves ALASKA UNITED DRILLING , , RIG NO. 3 BUTTERFLY.. VALVE CLOSED DE:~flNDER SUCTION CLOSED I~WiVEL Flow path.' -'.. __._-] Solids removal ~ · DEGASSING FLOW PATH Flowline (in) & pass shaker screens Shaker discharge into sand trap (ditch to pit room closed) Sand trap overflow into degasser suction (desander suction closed) Degasser discharge into ditch Overflow returns to degasser suction (underflow butterfly closed) Switch desander suction out of degasser t~nk Desilter suction (Normal) Cleaned mud to treatment pit Underflow from treatment to suction pit 10 Gravity-flooded suction CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc (2 thru 8) (3) Admin ~(~ thru 12) 10. ti0' t2. (4) Casg ::~th ~/5 ru il)/ (22 thru 26) 1. Is YES NO _ the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. /~3k_. . 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 pooi. ..~ 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ............................... 8 Can permit be approved before ten-day wait . REMARKS 13. 14. 15. 16. 17. 18. 19. 20. 21. 22, 23. 24. 25° 26. 27. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ..................................... ~-~ Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ~ __ Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 7~Zf~ ... Is a diverter system required ............................. Are necessary diagrams of diverter and ~{'gqui;ment ;t~achg~ . . ~ '" 'Does BOPE have sufficient pressure rating - Test to ~..~p psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78)..' ............... Is the presence of H2S gas probable ................................. . ...... Additional requirements ............................................. ~o Geology: ~ F~ngineering: HWK _~ LCS .,'"h'~:i BEW ~-' ~A~ JKT~~JH ~T~ rev: 10/29/84 6. CKLT POOL IN IT IAL CLASS STATUS GEO. AREA , UNIT N.O. ON/OFF SHORE Well Histow 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. _ ._ , L..~, .5 T...~ P .~ · ' ~,,~' ~ ,~. ". ' ':" :~,:. "t.~..: ':~;'::'.."'~ ~.- :~ "~' .,,, .V,.. R.~'~:I~:.~'T,: B..~i' ~.~, "~::~:'~:'"':'::: ' ...... ' :' · ' ......... '"'"' ~" ' ... · '. · · '' '" .... "· .... · ' '' ' ' ' ' ' ' ' · .......... "'' :':.: 'f'.:..::: :. .': '. ~. i .": ': " ':. ': t .....: ..~'" ', ' :. "' .' ".".' .' ".'"". ...... ' ...... .i'~:':~':":~';~i"'.'"' ':.'." ... '" ~."".t".'.' ~' ' ".'...' .: 7 ... i.:' '...',:"....~':'. '....'.i ': ':.':::'"!'?:'.'~.':.'~'.'.:'"'".'~. ~.....'". i' '"':"~'"'?'::':i.~. ' ..... ...'. · '...' 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