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182-103
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1H-04 KUPARUK RIV UNIT 1H-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 1H-04 50-029-20770-00-00 182-103-0 W SPT 6255 1821030 1564 2710 2710 2710 2710 50 140 140 140 4YRTST P Sully Sullivan 8/18/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1H-04 Inspection Date: Tubing OA Packer Depth 190 1905 1855 1850IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS251021133932 BBL Pumped:1.5 BBL Returned:1.3 Wednesday, October 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor lZ. FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 4, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IH -04 KUPARUK RIV UNIT 1H-04 Src: Inspector Reviewed By: P.I. Supry J�2 Comm Well Name KUPARUK RIV UNIT I H-04 API Well Number 50-029-20770-00-00 Inspector Name: Bob Noble Permit Number: 182-103-0 Inspection Date: 8/1/2021 Insp Num: mitRCN210802091140 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well1H-oa ''Type Type Inj W "TVD 6255 - Tubing 1675 _ 1675 - 1675 _ 1675 PTD 1821030 Test SPT ;Test psi 1564 IA 510 2405 - 2350 - 2345 - BBL Pumped: 1.7 IBBL Returned: 1.6 OA 20 _ 20 . 20 zo - Intervall 4vRTST p/F P Notes: Wednesday, August 4, 2021 Page 1 of 1 Schlumberger -Private 182103 3 1 1 8 8 Originated: Delivered to: Schlumberger TRANSMITTAL + 11 -Se -19 -� PTS - PRINT CENTER AOGCC TRANSMITTA115e 19•JW01 6411 A Street �, ATTN: Natural Resources Technician II �--� Alaska Oil & Gas Conservation Commision Anchorage, AK 9951& • (907) 273-1700 main (907)273-4760 fax 333 W. 7th Ave, Suite 100 .+ Anchorage, AK 99501 Schlumberger -Private (1) • -r-i-- . a). M N H I 1 N. / o . . . . . — � � sx C U LI o _ Y L a, . 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Q O N -J r M N N N N Cl) Cl) To �� . r-1 w +-+ N .--1 tJ n f0 C CO v N (0 O COD a t6 a 1= a` a Q • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,August 21,2017 P.I.Supervisor C'ij�l t-)12.1 [ 7 SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA,INC. 1H-04 FROM: Brian Bixby KUPARUK RIV UNIT 1H-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-04 API Well Number 50-029-20770-00-00 Inspector Name: Brian Bixby Permit Number: 182-103-0 Inspection Date: 8/17/2017 Insp Num: mitBDB170817165518 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IH-o4 (Type Inj W -TVD 6255 Tubing 2030 - 2040 - 2040 2045 - PTD 1821030 Type Test SPT Test psi 1564 - IA 310 2810 - 2740 - 2720 BBL Pumped: 1 2 4 BBL Returned: 2.4 OA 1 220 260 - 260 - 260 Interval 4YRTST P/F j P ✓ Notes: %Ale° h i Monday,August 21,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 24,2015 TO: Jim Regg �� l<,(Z4.�/S P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-04 FROM: Chuck Scheve KUPARUK RIV UNIT 1H-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,j i— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-04 API Well Number 50-029-20770-00-00 Inspector Name: Chuck Scheve Permit Number: 182-103-0 Inspection Date: 6/18/2015 Insp Num: mitCS150621110458 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1H-04 TType Inj I W"TVD 6255 - Tubing 1800 • 1800- 1 1800 1800 • PTD - 1821030 Type Test SPT Test psi 1564 - IA 520 J 2500 2470 - 2470-- Interval 11NITAL P/F P_ OA 900 i 1030 1030 1030 - i Notes: Initial test post workover/coil tubing sidetrack SCANNED . Wednesday,June 24,2015 Page 1 of 1 ' STATE OF ALASKA AL,,SKA OIL AND GAS CONSERVATION CONM...,dSION S,,-r.1 ,`„i c-'''' i '' ,r REPORT OF SUNDRY WELL OPERATIONS J q 99,,''II 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r DIpILt tiAs"stftlfdoW n r Performed Suspend r Perforate r Other Stimulate r Alter Casing r' Chang P,�ppr(c��edrogram r' Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: o'd to`1MI�J' 2 Operator Name 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development N-,.., Exploratory r 182-103-00 3.Address: 6.API Number: Stratigraphic r Service r P. 0 Box 100360,Anchorage,Alaska 99510 50-029-20770-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL 25639 ALK 464 KRU 1H-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary. Total Depth measured 8086 feet Plugs(measured) None true vertical 7082 feet Junk(measured) None Effective Depth measured 7600 feet Packer(measured) 7073, 7081, 7104, 7333, 7333 true vertical 6674 feet (true vertical) 6229,6235,6255,6449,6450 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 0 0 SURFACE 2162 10.75 2191 2191 0 0 WINDOW L1 8 7 7443 6542 0 0 PRODUCTION 8043 10 8071 7070 0 0 0 0 0 0 0 0 Perforation depth: Measured depth 7180-7242,7291-7324,7482-7486,7496-7520 True Vertical Depth: 6320-6373,6414-6442,6575-6578,6587-6607 SCANNED JUL 2 8 2015 Tubing(size,grade,MD,and ND) 3.5, L-80, 7342 MD,6457 TVD Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER 80-40 SEASL ASSEMBLY(SPACED OUT 7.70')@ 7073 MD and 6229 TVD PBR-BAKEAR 80-40 20' PBR @ 7081 MD and 6235 TVD PACKER-BAKERR 4762 FHL PACKER @ 7104 MD and 6255 TVD LOCATOR-BAKER LOCATOR @ 7333 MD and 6449 TVD SEAL ASSY-BAKER 80-40 GBH-22 SEAL ASSEMBLY(SPACED OUT 1')@ 7333 MD and 6450 TVD TRDP-CAMCO TRDP-1A-NC @ 1798 MD and 1798 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured) Treatment descriptions including volumes used and final pressure- 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 416 1363 1253 1027 256 Subsequent to operation 0 0 4590 500 1789 14.Attachments(required per 20 MC 25 070,25.071,&25 283) 15 Well Class after work: Daily Report of Well Operations PI Exploratory r Development r Service r.' Stratigraphic 1— Copies Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 315-315 Contact Darrell Humphrey/Bob Christensen Email n1139tc'�i conocophillips.com Printed Name Darrell Humphrey Title , tion Engineering Specialist Signature Phone.659-75� ,'..,a k... Date ,‘1" Co- Zo - I S t7L �l1 jUN232ul!, Form 10-404 Revised 5/2015 `15- RBDI�I`bmOrigjr�al Only 1H-04 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/07/15 Well brought on water injection 06/18/15 ISW (CHUCK SCHEVE) MIT-IA PASSED TO 2500 PSI. KUP PROD 1H-04 p COttOCOPI'1ill1P$ a' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CrnrcoRdltips 500292077000 KUPARUK RIVER UNIT PROD 41.78 4,100.00 8,086.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-04,528/20153:34:35 PM SSSV:NIPPLE Last WO: 10/21/2014 35.001 7/23/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,586.0 11/18/2014 Rev Reason:GLV C/O lehallf 5282015 HANGER;24.1 °-11-1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 4e rJ CONDUCTOR 16 15.060 31.0 110.0 110.0 65.00 H-40 WELDED • and Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 103/4 9.950 28.7 2,191.0 2,190.8 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread ,7.WINDOW L1 7 2.800 7,435.0 7,443.0 6,542.5 CONDUCTOR;31.D-110.0 i. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 28.5 8,071.0 7,069.6 26.00 K-55 BTC • NIPPLE;514.8 - Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection I TUBING WO-2014- 31/2 2.992 24.1 7,341.5 6,457.0 9.30 L-80 EUE 8Rd • Upper • Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) SURFACE;28.6.2,191.0-• 24.1 24.1 0.07 HANGER TUBING HANGER 2.992 l 514.8 514.8 0.13 NIPPLE CAMCO"DS"NIPPLE 2.875 GAS LIFT;2,523.7 I4,504.5 4,212.4 41.17 BARRIER BH,ORBIT BARRIER VALVE 2.890 II VLV 7,073.0 6,228.8 31.11 SEAL ASSY BAKER 80-40 SEASL ASSEMBLY(spaced out 7.70') 2.990 GAS LIFT;8847.4 7,080.7 6,235.4 31.08 PBR BAKEAR 80-40 20'PBR 2.990 7,103.8 6,255.2 31.03 PACKER BAKERr 4782 FHL PACKER 2.930 7,175.5 6,316.4 31.54 Blast Joint 4.5"Blast Joint 20#/ft Top of joint @ 7175'length=72' 2.992 7,257.3 6,385.9 32.17 SLEEVE-C BAKER CMU SLIDING SLEEVE,run in the closed 2.813 BARRIER VLV;4,504.5 '. position.BX PROFILE 7,286.2 6,410.3 32.39 Blast Joint 4.5"Blast Joint 20#/ftTop of joint @ 7287'length=40' 2.992 7,332.6 6,449.4 32.53 LOCATOR BAKER LOCATOR 2.950 GAS LIFT;5,087.6 1 7,333.4 6,450.1 32.53 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY(spaced out 1') 2.980 M. Tubing Description String M ..ID(in) Top(ftKB) Set Depth(ft.. D)(...Wt(Ib/ft) Grade Top Connection • TUBING WO 2014- Ia. 5.971 5.0501 7,333.51 7,455.0 6,552.6 Depth(ND) 1 14.001 H-40 I STC GAS LIFT;6,0260 Lower • Completion Details ® Nominal ID U Top(ftKB) Top(ND)(ftKB) Top Incl 1°) Item Des Corn (in) 7,333.5 6,450.2 32.53 PACKER BAKER 85-40 F-1 PERMANENT PACKER 4.000 GAS LIFT,6,847.6 Ili I 7,336.8 6,453.0 32.53 SBE BAKER 80-40 SBE 4.000 7,347.4 6,462.0 32.54 NIPPLE CAMCO"X"NIPPLE 2.812 7 410.6 6,515.2 32.63 WLEG 5 1/2"14#J-55 STC w/WEARSOX with WLEG Btm of 5.050 GAS LIFT;7,017.1 Joint:7455' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) SEAL ASSY;7,073.0 - 7,430.0 6,531.5 32.72 WHIPSTOCK 5.5"Gen II Delta Whipstock.Set at O deg.Two pip 11/25/2014 5.050 PER;7,080.7 tags installed in whipstock at 7437.35'RKB. PACKER;7,103.8 Perforations&Slots I Shot Dens Top(ND) Btm(TVD) (shots/f PRODUCTION;7,156.4Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com 7,180.0 7,242.06,320.3 6,372.9 C-4,C-3,1H- 12/30/1985 4.0 IPERF 120 Deg.PH Geo-Vann 04 5" (PERF;7,180.0-7,2420 r. 7,291.0 7,324.0 6,414.4 6,442.2 C-1,UNIT B, 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann 1 H-04 5" 7,482.0 7,486.0 6,575.2 6,578.6 A-5,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann SLEEVE-C;7,257.3 5" 7,496.0 7,520.0 6,587.0 6,607.1 A-4,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann 5" Blast Joint,7,2862 Mandrel Inserts IPERF;7,291.0-7,324.01 St ati I. N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model 00(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;7,332.6 { 2,523.7 2,523.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/162015 PACKER;7,333.5 i Z 2 3,847.4 3,717.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/162015 SEAL ASSY;7,333.4- ' 3• 5,087.6 4,652.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 SBE;7,330.0 1. 4 6,024.0 5,361.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/21/2015 5 6,647.6 5,867.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/21/2015 NIPPLE;7,347.4 - 6 7,017.1 6,181.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 7 7,156.4 6,300.1 CAMCO MMG 1 1/2 PROD DMY RK 0.000 0.0 11/6/2014 g,. Notes:General&Safety End Date Annotation 12/30/1985 NOTE:WORKOVER SLOTS;7.370,1.9,589.8L_ LINER L1-01;7,369.3-9,600.0 923/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/21/2014 NOTE:WORKOVER WLEG;7,410.6 WHIPSTOCK,7,430.6 I 11/172014 NOTE:BARRIER VLV control lines/system @ Wellhead marked Open/Close WINDOW L7;7,415.0-7,443.0 11/172014 NOTE:BARRIER VLV is NOT a safety valve;it does not fail to closed position • 1/2/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 IPERF;7,482.0.7,486.0-- • IPERF; ,482.0.7,486.0- IPERF;7,496.0.7.520.5 I I PRODUCTION;28.5-8,071.0 Brooks, Phoebe L (DOA) rcr IeQ.(030 From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday,June 23, 2015 4:16 PM To: Brooks, Phoebe L (DOA) Subject: RE: Recent KRU MIT-IA's Attachments: image001.png; 1H-04.pdf Phoebe, 1H-04 wellbore schematic is attached. SCANNED ;UL 0 2 2O1',) Regards, Jan From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Tuesday, June 23, 2015 3:45 PM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: Recent KRU MIT-IA's Jan/Dusty, Will you send me the well schematic for 1H-04? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617Caconocophillips.com] Sent: Saturday, June 20, 2015 10:05 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L(DOA); Wallace, Chris D (DOA) Subject: Recent KRU MIT-IA's All, Attached are state witnessed MIT-IA's recently performed in Kuparuk. Thanks. Regards, 9 KUP PROD 1H-04 ConocoPhillips , . & Well Attributes Max Angle&MD TD Alaska, xWellbore API/UNA Field Name Wellbore Status ncl(°i MD(ftK8) Act Bin,(RKB) Caax ,p,p,, 500292077000 KUPARUK RIVER UNIT PROD 41,78 4,100.00 8,086.0 •.. Comment H2S(ppm) Date Annotation End Date KBGrd(ft) -Rig Release Date 1H-04,5/25/20153:34:35 PM SSSV:NIPPLE Last WO: 10/21/2014 35.00 7/23/1982 Vertical schematic(actueQ `Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,586.0 11/18/2014 Rev Reason:GLV C/O lehallf 5/28/2015 HANGER,24.1 1:=1 al m Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,aaa u CONDUCTOR 16 15.060 31.0 110.0 110.0 65.00 H-40 WELDED K. ua,Cuing Description 0D(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 28.7 2,191.0 2,190.8 45.50 K-55 BTC Casing Description OD(in) ID lin) Top(RKB) Set Depth(RKB) Set Depth(TVD)...'Wt/Len(I...Grade 'Top Thread I -' .i.WINDOW L1 7 2.800 7,435.0 7,443.0 6,542.5 CONDUCTOR;31.0-110.0 Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(1...Grade 'Top Thread I PRODUCTION 7 6.276 28.5 8,071.0 7,069.6 26.00 K-55 BTC NIPPLE;511.6 TubingStrings g Tubing Description String Ma...ID(in) Top(ttKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014- 3 112 2.992 24.1 7,3415 6,4570 9.30 L-80 EUE 8Rd Upper Completion Details Nominal ID Top(RKB) Top(ND)(ttKB) Top not(") Item Des Corn (in) SURFACE:28.6-2.191 0 24.1 24.1- 0.07 HANGER TUBING HANGER 2.992 514.8 514.8 0.13 NIPPLE CAMCO"DS"NIPPLE 2.875 GAS LIFT:2,523.7 III 4,504.5 4,212.4 41.17 BARRIER 'BH,ORBIT BARRIER VALVE 2.890 If VLV 11 7,073.0 6,228.8 31.11 SEAL ASSY BAKER 80-40 SEASL ASSEMBLY(spaced out 7.70') 2.990 GAS LIFT;3,547.4 7,080.7 6,235.4 31.08 PBR BAKEAR 80-40 20'PBR 2.990 7,103.8 6,255.2 31.03 PACKER BAKERr 4782 FHL PACKER 2.930 2.992 7,175.5 6,316.4 31.54 Blast Joint 4.5"Blast Joint 20#/h Top of joint @ 7175'length=72' BARRIER VLV;4,509.5 7,257.3 6,385.9 32.17 SLEEVE-C BAKER CMU SLIDING SLEEVE,run in the closed 2.813 poskion.BX PROFILE 7,286.2 6,410.3 32.39 Blast Joint 4.5"Blast Joint 20#/ftTop of joint @ 7287'Length=40' 2.992 7,332.6 6,449.4 32.53 LOCATOR BAKER LOCATOR 2.950 GAS LIFT;5,087.6 L 7,333.4 6,450.1 32.53 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY(spaced out 1') 2.980 Tubing Description String Ma...ID(In) Top(RKB) Set Depth(ft..Set Depth( D)(...Wt(112/ft) Grade Top Connection TUBING WO 2014- 5.97 5.050 7,333.5 7,455.0 N6,552.6 14.00 H-40 STC GAS LIFT;6.024.0 Lower Completion Details Nominal ID Top(RKB) Top(ND)(ttKB) Top Incl(') Item Des Com (in) I 7,333.5 6,450.2 32.53 PACKER BAKER 85-40 F-1 PERMANENT PACKER 4.000 GAS LIFT;6,647.6 7,336.8 6,453.0 32.53 SBE BAKER 80-40SBE 4.000 7,347.4 6,462.0 32.54 NIPPLE CAMCO"X"NIPPLE 2.812 7,410.6 6,515.2 32.63 WLEG 5 1/2"148 J-55 STC w/WEARSOX with WLEG Btm of 5.050 GAS LIFT;7,017.1 Joint:7455' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(RKB) (RKB) (°) Des Corn Run Date ID(in) SEAL ASSY;7,073.0 - 7,430.0 6,531.5 32.72 WHIPSTOCK 5.5"Gen II Delta Whipstock.Set at 0 deg.Two pip 11/25/2014 5.050 PBR;7,080.7 tags installed in whipstock at 7437.35'RKB. PACKER;7,103.8 Perforations&Slots Shot Dens Top(ND) Bins(ND) (shotaR PRODUCTION,7,156.4 Top(ftKB) film(1(8) PM (RKB) Zone Date t) Type Com lip 7,180.0 7,242.0 6,320.3 6,372.9 C-4,C-3,1H- 12/30/1985 4.0 IPERF 120 Deg.PH Geo-Vann 04 5" (PERF:7,leD.0.7,292.0 7,291.0 7,324.0 6,414.4 6,442.2 1-1,UNIT B, 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann r 11 7,482.0 7,486.0 6,575.2 6,578.6 A-5,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann SLEEVE-C;7.257.3 5" ® 7,496.0 7,520.0 6,587.0 6,607.1 A-4,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann III 5" Blasi Joint;7.2862 - Mandrel Inserts IPERF;7,291.0.7.321.01 St ati IS en Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (8K8) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com LOCATOR;7,332.6 { 2,523.7 2,523.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 '.. PACKER;7.333.5 2 3,847.4 3,717.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 SEAL ASSY;7,333.4 = - 3 5,087.6 4,652.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 SBE;7,336.8 ,it 4 6,024.0 5,361.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 421/2015 NI 5 6,647.6 5,867.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/21/2015 MI NIPPLE;7.397.4 6 7,017.1 6,181.0 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 5/16/2015 111 7 7,156.4 6,300.1 CAMCO MMG 11/2 PROD DMV RK 0.000 0.0 11/6/2014 ilk" Notes:General&Safety End Date Annotation - 9 w -- 12/30/1985 NOTE:WORKOVER SLOTS;7,370.1.8559.81_" LINER L1A1;7,369,3-9,600.0 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/21/2014 NOTE:WORKOVER WLEO;7,410.6 III 11/17/2014 NOTE:BARRIER VLV control lines/system stem Wellhead marked O en/Close WHIPSTOCK;7,430.0 Y @ P WINDOW LI.7.935.0-7,443.0 n 11/172014 NOTE:BARRIER VLV is NOT a safety valve;it does not fail to closed position 1/2/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 IPERF;7,482.0-7.4860- IPERF;7,496.0-7,520 0-. PRODUCTION,285-8,071.0 • I//7, 4, THE STATE Alaska Oil and Gas °fALASK A Conservation Commission 333 West Seventh Avenue • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 LAS Fax 907.276.7542 0 5 7J3 '.) www.aogcc.alaska.gov SatN� Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 11-1-04 Sundry Number: 315-315 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this w day of May, 2015 Encl. STATE OF ALASKA A. .,KA OIL AND GAS CONSERVATION COMMIS, of APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate E Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Prod to WINJ 2 Operator Name: 4.Current Well Class 5.Permit to Drill Number ConocoPhillips Alaska, Inc. ' Exploratory r Development ry 182-103-00 3.Address: Stratigraphic�"•' Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20770-00 • 7.If perforating, What 8.Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r NO r / KRU 1 H-04 - 9.Property Designation(Lease Number): .214, 10.Field/Pool(s): ADL 25639 ALK 464 Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft). Plugs(measured): Junk(measured): 8086 • 7082 • 7600' 6674' ' None None Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 110' 110' SURFACE 2162 10.75 2191' 2191' RECEIVED WINDOW L1 8 2.375 7443' 6542' PRODUCTION 8043 7 8071' 7070' MAY 2 2 2015 bThS SOC CC Perforation Depth MD(ft): Perforation Depth ND(ft) Tubing Size: Tubing Grade: Tubing MD(ft): 7180-7242,7291-7324,7482-7486,7496-7520. 6320-6373,6414-6442,6575-6578,6587-6607 3.5 L-80 7342 Packers and SSW Type:, Packers and SSSV MD(ft)and.TV.B(ft) , SEAL ASSY-BAKER 80-40 SEASL ASSEMBLY(SPACED OUT 7.7r MD=7073 TVD=6229, PBR-BAKEAR 80-40 20'PBR MD=7081 TVD=6235 • PACKER-BAKERR 4762 FHL PACKER MD=7104,ND=6255 , LOCATOR-BAKER LOCATOR MD=7333 TVD=6449' SEAL ASSY-BAKER 80-40 GBH-22 SEAL ASSEMBLY(SPACED 0 MD=7333 TVD=6450 TRDP-CAMCO TRDP-1A-NC MD='1798 TVD=1798 12 Attachments: Description Summary of Proposal 13. Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 171 14 Estimated Date for Commencing Operations. 15 Well Status after proposed work. 5/30/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval Date: WAG r GSTOR r SPLUG E GAS r Op Shutdown r Abandoned Commission Representative. GINJ E E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Darrell Humphrey/Bob Christensen Email ni"I 39Aconocophillips.com Printed Name Darrell Humphrey Title NSK Production Engineering Specialist Signaturei•-• \..y 1 Phone 659-7535 Date J•21D, /S Commission Use Only Sundry Number Conditions of approval' Notify Commission so that a representative may witness 316-31€ Plug Integrity f BOP Test r Mechanical Integrity Jt Locationn/Cllearance r l' Other: In,e,cAho� `I'ro t1C In a CCo brAi(. c...) ! Alo 2 C . fa, tc til./%z55 t'd / r— i A- re- (i,`v-z-c/ Gi ti-r !4 6,i�. 7 Spacing Exception Required? Yes❑ No LJ Subsequent Form Required: /6 — 4 U 4 / ‘i41 G r f I I n' APPROVED BY — Approved by: / 7 �J COMMISSIONER THE COMMISSION Date: 5•Z8-i-5 Appr I lA li fo 12 month f om a grate of approval. Submit Form and Form:10-403 Revised 5/2015 a._ �� � I� L S�; SZ4/I� Attachments in Duplicate yr - 51Z-t/!,g % '44 , RBDM JUN - 3 016 �w �lz�l�n,. �' 2 Darrell Humphrey/Robert Christensen Production Engineering Specialists. NIPV Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhil I i ps Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 May 20,2015 RECEIVED MAY 222015 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission AOGCC 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit wells 1H- 04, 1H-04L1, 1H-04L1-01, from Oil Production to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1H-04, 1H-04L1, 1H-04L1-01, (PTD#'s 182-103, 214-186, 214- 187). If=you have any questions regarding this matter, please corlact myself or Bob Christensen at 659-7535. — Sincerely, Darrell Humphrey Attachments Sundry applications Area Map Well schematics 1H-04 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1 H-04 and its associated laterals from Oil Production service to Water Injection service. Converting well 1H-04 to injection will provide water injection support to the Kuparuk producers 1G-10B, 1G-12 and 1H-06 in the immature A-Sand patterns. Area of Review: An AOR was completed on the PTD's. The top of the Kuparuk C sand was found at 7178' and/6319' tvd. The top of the Kuparuk A sand was found at 7470' and /6565'tvd. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1 H-04 is good and classified as a "Normal Well"with the C Sands currently isolated. A State-witnessed MIT-IA will be performed once well 1 H-04 is converted to water injection, online, and stabilized. The CBL, dated 7/20/1982, identified a cement top of approximately 5800' RKB. The CBL was run to a depth of approximately 8000' RKB and indicated good cement for the interval from 5800' to 8000' RKB. The injection tubing/casing annulus is isolated via a Baker 4762 FHL packer at 7103.8' RKB and a Baker 85- 40 F-1 Permanent packer at 7333.5' RKB. The 16" Conductor was cemented with 274 sx AS II. The 10.75" Surface casing (2191' and/2191' tvd)was cemented with 1000 sx AS III &250 sx AS II. The 7" Production casing (8071' and/7070'tvd)was cemented with 1145 sx Class"G" &250 sx AS II. CBL and interpretation of the cement quality: The CBL interpretation was completed on the PTD's. co4c /', we�� w.9.1feWor&�,' � (0'?I"' ro "co I-0 �'Grrfl� leOr t,:( Ore.Syv✓•e ok d De C7'Q ‘).J' P' " /s del nj ✓e fvi,'erg ;r c f"or' ce vi C . 11111114 KUP PROD 1H-04 I.- ConocoPhillips Well Attributes Max Angle&MD TD Alaska,(nC. Wellbore APIIUWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) rt.aa;kaair. 500292077000 KUPARUK RIVER UNIT PROD 41.78 4,100.00 8,086.0 ••• • Comment H2S(ppm) Date Annotation End Date KB•Grd(fl) "Rig Release Date 1 H4/4,4/22/20152:02:50 PM SSSV:NIPPLE Last WO: 10/21/2014 35.00 7/23/1982 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- -- --...-....Last Tag:SLM 7,586.0 11/18/2014 Rev Reason:GLV C/O lehallf 4/22/2015 HANGER;24.1 .211-1 i • Casing Strings Casing�a CONDUCTOR 16 OD(in) 10 Q1�060 To 'ftK31.0 Set Depth(ftKB) Set Depth 110.0 Wt/Len 65,00 Grade0WELDED H-40 WELDED lY.Casing Description OD(in) ID In TopftKB Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ��. �� SURFACE 103/4- 9.950 28.7 2,191.0 2,190.8 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T7D)... WtlLen(I...Grade Top Thread ,J4.WINDOW LI 7 2.800 7,435.0 7,443.0 6,542.5 CONDUCTOR;31.0-110.0 . Casing Description OD(in) 'ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 28.5 8,071.0 7,069.6 26.00 K-55 BTC NIPPLE;514.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection • • TUBING WO-2014- 3 1/2 2.992 24.1 7,341.5 6,457.0 9.30 L-80 EUE 8Rd Upper • Completion Details Nominal ID Top(ftKB) Top(ND)(fte13) Top Incl I') Item Des Com (in) SURFACE;2E6-21910 24.1 24.1 0.07 HANGER TUBING HANGER 2.992 514.8 514.8 0.13 NIPPLE CAMCO"DS"NIPPLE 2.875 GAS LIFT,zsz3.7 4,504.5 4,212.4 41.17 BARRIER BH,ORBIT BARRIER VALVE 2.890 VLV 7,073.0 6,228.8 31.11 SEAL ASSY BAKER 80-40 SEASL ASSEMBLY(spaced out 7.70') 2.990 GAS LIFT 38474 - 7,080.7 6,235.4 31.08 PBR BAKEAR 80-40 20'PBR 2.990 7,103.8 6,255.2 31.03 PACKER 'BAKERr 4782 FHL PACKER 2.930 7,175.5 6,316.4 31.54 Blast Joint 4.5"Blast Joint 206/ft Top of joint @ 7175'length=72' 2.992 7,257.3 6,385.9 32.17 SLEEVE-C 'BAKER CMU SLIDING SLEEVE,run in the closed 2.813 BARRIER VLV',4,5045 .l:j1.. position.BX PROFILE 7,286.2 6,410.3 32.39 Blast Joint 4.5"Blast Joint 20#/ftTop of joint @ 7287 length=40' 2.992 7,332.6 6,449.4 32.53 LOCATOR BAKER LOCATOR 2.950 GAS LIFT,5087 6 -- 7,333.4 6,450.1 32.53 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY(spaced out 1') 2.980 M I. Tubing Description 'String Ma...'ID(in) 'Top(RKB) Set Depth(ft..1 Set Depth(ND)(...IWt(lb/ft) (Grade 'Top Connection al# TUBING WO2014- 5.97 5050 7,333.5 7,455.01 6,5526 14.00 H-40 STC GAS LIFT;6.024.0 #. Lower Completion Details Nominal ID Top(RKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,333.5 6,450.2 32.53 PACKER BAKER 85-40 F-1 PERMANENT PACKER 4.000 GAS LIFT;6.647.6 7,336.8 6,453.0 32.53 SBE BAKER 80-40 SBE 4.000 7,347.4 6,462.0 32.54 NIPPLE CAMCO"X"NIPPLE - 2.812 7,410.6 6,5152 32.63 WLEG 5 1/2"14#J-55 STC w/WEARSOX with WLEG Btm of / 5 050 . GAS LIFT;7,017.1 Joint:7455' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) iftKB) (°) Des Com Run Date ID(in) SEAL ASSY;7,073.0 7,430.0 6,531.5 32.72 WHIPSTOCK 5.5"Gen II Delta Whipstock.Set at 0 deg.Two pip 11/25/2014 5.050 PBR;7,000.7 { tags installed in whipstock at 7437.35'RKB. PACKER;7,103.8 Perforations&Slots Shot Den I Top(TVD) Btm(TVD) (shots# PRODUCTION;7.156.4 Top(ftKB) Btm(ftKB) (ftKB) _ (ftKB) Zone Dale t) Type Com 7,180.0 7,242.0 6,320.3 6,372.9 C-4,C-3,1H- 12/30/1985 4.0 IPERF 120 Deg.PH Geo-Vann 04 5" (PERF;7,180.07,242.0-y = 7.291.0 7,324.0 6,414.4 6,4422 C-1,UNIT B, 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann 1H-04 5" 7,482.0 7,486.0 6,575.2 6,578.6 A-5,1H-04 12/30/1985 12.0 IPERF '120 Deg.PH Geo-Vann SLEEVE-C;7,257.3 5" 7,496.0 7,520.0 6,587.0 6,607.1 A-4,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann • I I 5" Blast Joint;7,286.2Mandrel Inserts (PERF;7,291.07.324.0 St ati :. on Top(TVD) Valve Latch Port Sloe TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type_ Type (In) (psi) Run Date Com LOCATOR;7.332.6 I. fi 2,523.7 2,523.4 CAMCO 'MMG 1 12 GAS LIFT GLV RK - 0.188 1,222.0 4/21/2015 PACKER;7.333.5- - ' 2 3,847.4 3,717.2 CAMCO MMG 1 12 GAS LIFT GLV RK 0.188 1,225.0 4/21/2015 SEAL ASSY;7,333.4- - 3 5,087.6 4,652.1 CAMCO MMG 11/2-GAS LIFT OV RK 0250 0.0 4212015 SBE;7.336.8 I 4 6,024.0 5,361.6 CAMCO MMG 1 12 GAS LIFT DMV RK 0.000 0.0 4/21/2015 NI ra 5 6,647.6 5,867.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4212015 1111 NIPPLE;7,347.4 6' 7,017.1 6,181.0 CAMCO MMG 112 GAS LIFT DMV RK 0.000 0.0 4/20/2015 7 7,156.4 6,300.1 CAMCO MMG 112 PROD DMY RK 0.000 0.011/6/2014 II Notes:General&Safety i End Date Annotation 12/30/1985 NOTE:WORKOVER SLOTS;7,370.1-9.5898- 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/21/2014 NOTE:WORKOVER WLEG;7.410.6 WHIPSTOCK 7.4300 1 11/17/2014 NOTE: BARRIER VLV control lines/system @ Wellhead marked Open/Close WINDOW LI;7,435.0-7,443.0 11/17/2014 NOTE:BARRIER VLV is NOT a safety valve;it does not fail to closed position LINER L7-01;7,369.39,600.0 1/23/2015 NOTE:ADD LATERALS L1(off main wellbore),L1-01 IPERF;7,482.0-7,486.0- I I (PERF;7,496.0-7,520.0- PRODUCTION,28.58,071.0 -- I r \ ,,y o� 1H-04L -01 , ,40 yV '� t{ sN O 1. 1H-07 2.-1H-12 :off f' ;j-21N-1 : 1H'-06 tz`£ 1 --31H-10- 5H an --.3. -„,-...2,5_ �oH�1i,Sg,7z1 _1H-13 _ (11.111...1 H-04 pgs1H'OA�1-01 ti y'6' ri gam. s 1 H-04L1 1,,0 Legend Well Surface Location Pad Mean Center ConocoPhillips Wells Within 1/4 mile radius Alaska, Inc. 1/4 Mile Injection Radius Q1H-04 Injection Swap Analysis 1H-04L1 1H-04, 1H-04L1, 1H-04L1-01 D1H-04L1-01 N STATUS,WELL_TYPE, FLUID_TYPE n o 0.25 0.5 Pmriiir-or nii `\ Miles STATE OF ALASKA AL A OIL AND GAS CONSERVATION COM,....,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate rOther Change Status Atter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r'Operat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development For Exploratory r 182-103 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20770-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639 KRU 1H-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8086 feet Plugs(measured) none true vertical 7082 feet Junk(measured) none Effective Depth measured 7600 feet Packer(measured) 7104 true vertical 6674 feet (true vertical) 6255 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 SURFACE 2162 10.75 2191 2191 PRODUCTION 8043 7 8071 7070 ,cANNE© fry ��� RECEIVED FEB 022015 Perforation depth. Measured depth: 7180-7242, 7291-7324, 7482-7486,7496-7520 AOGCC Vertical Depth: 6320-6373,6414-6442,6575-6579,6587-6607 AOGCC Tubing(size,grade,MD,and TVD) 3.5"x 2.875",J-55, 7408 MD,6512 TVD 5.5", H-40, 7455' MD and 6553'TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL PACKER @ 7104 MD and 6255 TVD PACKER-BAKER F-1 PACKER @ 7334 MD and 6450 TVD NIPPLE-CAMCO DS NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze was performed during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil Gas r WDSPL r Daily Report of Well Operations GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt none Contact Cody Pohler , 265-6435 Email Cody.J.Pohlerconocophillips.com c) P Printed Name Cod Pahl- Title CTD Engineer Signature ,` e/��_ Phone:265-6435 Date r�4 ( i - vr'- 2(51 Lc- RBDMS FEB - 4 2015 Form 10-404 Revised 10/2012 r Submit Original Only KUP INJ 1H-04 ConocoPhillips O° Well Attributes Max Angle&MD TD Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(nK8) Act Mtn(f168) ,-gym 500292077000 KUPARUK RIVER UNIT INJ 41.78 _ 4,100.00 8086.0 ••• Comment 1/25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 111414.1.GS20151021;50 AM SSSV:NIPPLE Last WO: - 10.21/2014 35.00 723/1982 Vertical schematic(actual) Annotation Depth MB) End Date Annotation -Last Mod By End Date Last Tag:SLM 7,5860 11/182014 Rev Reason:ADD LATFRAL.S 1_1,L1-01 smsmith 123/2015 HANGER;24.1 .f- • 1 Casing Strings 1-1 ,. Casing Deaerlptlon OD(In) ID(In) Top(ttKB) Set Depth(ttKB) Sat Depth(TVD)...Wt/Lan(1...Grade Tap Thread CONDUCTOR 16 15.060 31.0 110.0 110.0 65.00 H-40 WELDED L : n,n.Casing Description OD(in) ID 11n) Top(nKB) Set Depth(KKR) Set Depth(TVD)...WULen(i...Grade Top Thread • UI III SURFACE 103/4 9.950 28.7 2,191.0 2,190.8 45.50 K-55 BTC Caning DescriptionOD(In) ID(In) Top(nKB) Set Depth(ttKB) Set Depth)TVD)...Weil.(I...Grade Top Thread ,WINDOW LI 7 2.800 7,435.0 7,443.0 6,542.5 CONDUCTOR:31.0.110.0 I • Casing Description OD(In) 'ID(in) Top(ttKB) Set Depth(nKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 28.5 8.071.0 7,069.6 26.00 K-55 13T0 •NIPPLE;514.8 Tubing Strings Tubing Description String Ma...10(In) Top(008) Set Depth(ft...Set Depth(TVD)( Wt(Ibm) Grade Top Connection TUBING WO-2014- 3 12 2.992 24.1 7.341.5 6.457.0 9.30 L-80 ELLE 8Rd I I Upper { Completion Details ( Nominal ID I. Top(nKB) Top(TVD)(ttKB) Top Incl(°) Item Des Com (In) SURFACE;28.6-2,791.0 24.1 24.1 0.07 HANGER TUBING HANGER 2.992 L 514.8 514.8 0.13 NIPPLE CAMCO TS"NIPPLE 2.875 OAS LIFT:2.523.7 • 4,504.5 4,212.4 41.17 BARRIER BH.ORBIT BARRIER VALVE 2890 VLV 7,073.0 6,228.8 31.11 SEAL ASSY BAKER 80-40 SEASL ASSEMBLY(spaced out 7.70) 2.990 GAS LIFT;3,e/?,4 7,080.7 6,235.4 31.08 PBR BAKEAR 80-40 20'PBR 2.990 fr 7,103,8 6,255.2 31.03 PACKER BAKER/4752 FHL PACKER 2.930 7,1755 6,376.4 31.54 Blast Joint 4.5"Blast Joint 208/3 Top d joint 7175'length=72' 2.992 EA;�1.eR 1.1V a Sas I 7,257.3 6,385.9 32.17 SLEEVE-C BAKER CMU SLIDING SLEEVE.run In the closed 2.813 position 7,286.2 6,410.3 32.39 Blast Joint 4.5"Blast Joint 204411-op of 101st Cd 7287'length=40' 2.992 7,332.6 6,449.4 32.53 LOCATOR BAKER LOCATOR 2.950 GAS LIFT;5,087.0 7,333.4 6,450.1 32.53 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY(spaced out 1') 2.980 Tubing Description (String Ma...ID(in) Top(ttKB) Set Depth(II,,Set Depth(TVD)(...WI(lb/ft) Grade (Top Connection TUBING WO 2014- III 5.97 5.050 7.333.5 7.455.0 6,552.6 14.00 H-40 STC GAS LIFT.8,024.0 Lower Completion Details Nominal ID Top MKS) Top(TVD)(nKB) Top Incl(°) hem Des Corn (in) 7,333.5 6,450.2' 32.53 PACKER BAKER 85-40 F-1 PERMANENT PACKER 4.000 OAS LIFT,6,6416 7,336.8 6,453.0 32.53 OBE BAKER 80-40 SBE 4.000 7,347.4 6,462.0 32.54 NIPPI F CAMCO'X"NIPPLE 2.812 5.050 7,410.6 6,515.2 32.63 WLLG 5 1,2"144 J-55 STC w/WEARSOX with WLEG Btm of GAS LIFT.7or.1 .faint 7455' Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ttKB) )ttKB) (°) Des Corn Run Date ID On) SEAL AS.,,7,073 0 = 7,430.0 6,531.5 32.72 WHIPSTOCK 5.5"Gen 11 Delta Whipstock Set at 0 deg.Two pip 11/25/2014 5.050 Pe:7.500 7 t. itags Installed In wtllpstock at 7437.35'RKB. TACKER,7.115 9 - Perforations&Slots Shot Dena Top(ND) Blm(TVD) (shotolf PRODUCTION:7,156.1 Top(RKB) Btte(IIKB) (nKB) MB) Zone Gale 1) Type Com 7,180.0 7,242.0 6,320.3 6,372.9 C•4,C-3,1H- 12/30/1985 4.0 (PERF 120 Deg.PH Geo-Vann 04 5" IPERF.7.100.0-7,242.0- 2291.0 7.324.0 6 414.4 6,4422 C-1Hi-04 UNIT B. -12/3071985- 12.0 (PERF 120 Deg.PH Geo-Vann 5" 7,482.0 7,456.0 6,575.2 6,578.6 A-6,IH-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann BLEEVE-C;7,257.3 II J 7.496.0 7.520.0 6,587.0 6,807.1 A-6,1H-04 12/30/1985 12.0 IPERF 120 Deg.PH Geo-Vann 5" ebst.lalm;7,27.6 2 Mand rel Inserts (PERF;7,297.0.7.321.0, � 91 ati NTop(TVD) Valve Latch Pon Sine TRO Run Top(ttKB) )nKBj Mahe Model OD(in) Sery Type Type In) (pai) Run Date Corn LOCATOR,7,332.8 _ 1 2,523.7 2,523.4 CAMCO MMG 1 112 GAS LIFT DMY RK 0.000 0.0 1116 2014 Alit 2 3,847.4 3,717.2 CAMCO MMG 1112 GAS LIFT DMY RK 0.000 0.0 11/6/2014 PACKER;7,3335-. SEAL ASSY;7,333.1- 3 5,087.6 4,652.1 CAMCO MMG 112 GAS LIFT DMY RK 0.000 0.0 11/62014 WE;E;7,3365 7�• 4 6,024.0 5,361.6 CAMCO MMG 112 GASLIFT DMY RK 0.000 0.0 1176/2014 5 6,647.6 5,861.2 CAMCO MMG I 1%2 GAS LIFT DMY RK 0.7x)0 0.0 106/2014 NIPPLE;7.34.4 - 6 7,017.1 6,181.0 CAMCO MMG 1 02 GAS LIFT DMY RK 0.000 0-0 11/11/2014 7 7,156.4 6,300.1 CAMCO MMG 1 02 PROD DMY RK 0.000 0.0 106/2014 Notes:General&Safety I.'T 1�iEnd Date Annotation IJ12.30/1985 NOTE:WORKOVER SLOTS'7.370.1-9.589.8 11.-.1 9/23/2010 NOTE:View Schematic w/Alaska Schemaoc9.0 w1CO3 7,410.8 �. 10/21/2014 NOTE:WORKOVER WHIPSTOCK 7,40.0 WINDOW LI'.7,435.0.7,443.0 k! 11/17/2014 NOTE:BARRIER VLV control llnes/system(LD Wellhead marked Open/Close i :1 11/17/2014 NOTE:BARRIER VLV Is NOT a safety valve;It does not fall to closed position LINER Lt-01:7369a8,6005 -- 1/23/2015 NOTE:ADD LATERALS LI(off main wellbore),L 1-01 IPERF 7 482.0-7.486.0 IPERF;7,496.0.7.520.0 PlGcuc/I//.,LI.1-8 0,1.C.- . � STATE OF ALASKA ♦" A. ,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other iv CTD Set-up Alter Casing r Rill Tubing 1 Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. _ Development r Exploratory r 182-103 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20770-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639 V,..1,1_) 1H-04 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8086 feet Plugs(measured) None true vertical 7082 feet Junk(measured) None Effective Depth measured 7600 feet Packer(measured) 7104 true vertical 6674 feet (true vertical) 6255 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 SURFACE 2162 10.75 2191 2191 PRODUCTION 8043 78071 ' 0 Q,._ RECEIVED Perforation depth: Measured depth: 7180-7242, 7291-7324, 7482-7486, 7496-7520 NOV 2 5 2014 True Vertical Depth: 6320-6373,6414-6442,6575-6579,6587-6607 Tubing(size,grade,MD,and ND) 3.5", L-80, 7341'MD,6457'TVD AO CO 5.54", H-40, 7455'MD,6553'TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7104'MD and 6255'TVD PACKER-BAKER F-1 PACKER @ 7334'MD and 6450'ND NIPPLE-CAMCO DS NIPPLE @ 515'MD AND 515'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): No stimulation or cement squeeze was performed during this operation. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3000 1100 2300 Subsequent to operation 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service rd Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt: 314-548 Contact Ray Oakley Email Raymond.Oakley@contractor.conocophillips.com Printed Name Ray Oakley#_______ Title Workover Engineer Signature Phone: 263-4759 Date (f/2 S /2 0 lc( vr- 3/1q// MEWS DEC 10- Form 10-404 Revised 12/20121/ � Submit Original Only - KUP INJ 1H-04 ConocoPhillips g Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crons,,,Joj.jhr, 500292077000 KUPARUK RIVER UNIT INJ 41.78 4,100.00 8586.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1H-04,11/20/2014 7 54 51 AM SSSV:NIPPLE Last WO: 10/21/2014 35.00 7/23/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.SLM 7,610.0 11/11/2014 Rev Reason:WORKOVER,GLV C/O,PULL haggea 11/19/2014 HANGER;24.1 illeLii PLUG,TAG Casing Strings _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I Grade Top Thread 'i F CONDUCTOR 16 15.060 31.0 110.0 110.0 65.00 H-40 WELDED ` Caning Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread - ■oe SURFACE 10 3/4 9.950 28.7 2,191.0 2,190.8 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 28.5 8,071.0 7,069.6 26.00 K-55 BTC CONDUCTOR;31.0-110. IIII0.Tubing Strings ° Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO-2014- 31/2 2.992 24.1 7,341.5 6457.0 9.30 L-80 EUE 8Rd NIPPLE,,514 8 Z Upper Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top net(°) Item Des Corn (in) 24.1 24.1 0.07 HANGER TUBING HANGER 2.992 514.8 514.8 0.13 NIPPLE CAMCO"DS"NIPPLE 2.875 SURFACE;28.6-2,191.0 x 4504.5 4,212.4 41.17 BARRIER 8H,ORBIT BARRIER VALVE 2.890 VLV 7,073.0 6,228.8 31.11 SEAL ASSY BAKER 80-40 SEASL ASSEMBLY(spaced out 7.70') 2.990 GAS LIFT;2,523.7 7,080.7 6,235.4 31.08 PBR BAKEAR 80-40 20'PBR 2.990 7,103.8 6,255.2 31.03 PACKER BAKERr 4782 FHL PACKER 2.930 7,175.5 6,316.4 31.54 Blast Joint 4.5"Blast Joint 20#/ft Top of joint @ 7175'length=72' 2.992 GAS LIFT;3,847.4Olt 7,257.3 6,385.9 32.17 SLEEVE-C BAKER CMU SLIDING SLEEVE,run in the closed '-2.813 position 7,286.2 6,410.3 32.39 Blast Joint 4.5"Blast Joint 20#/ftTop of joint @ 7287'length=40' 2.992 _ 7,332.6 6,449.4 32.53 LOCATOR BAKER LOCATOR 2.950 BARRIER VLV;4,504.5 7,333.4 6,450.1 32.53 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY(spaced out 1') 2.980 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2014- 5.54 5.050 7,333.5 7,455.0 6,552.6 14.00 H-40 ScT GAS LIFT;5,087.6I. Lower Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB( Top Incl(°l Item Des Com (in) 7,333.5 6,450.2 32.53 PACKER BAKER 85-40 F-1 PERMANENT PACKER 4.000 GAS LIFT;6,024.0IN 7,336.8 6,453.0 32.53 SBE BAKER 80-40 SBE 4.000 7,347.4 6,462.0 32.54 NIPPLE CAMCO"X"NIPPLE 2.812 7,410.6 6,515.2 32.63 WLEG 5 1/2"146 J-55 STC w/WEARSOX with WLEG Elm of 5.050 GAS LIFT;6,647.6 Joint.7455' Perforations&Slots I Shot (TVD) Den GAS LIFT;7.017.1 Top(ftKB) Btm(ftKB) Top (ftKB)) Btm(ND) (sh'ts/f Type Com ( ) (ftKB) Zone Date t 7,180.0 7,242.0 6,320.3 6,372.9 C-4,C-3,1H- 12/30/1985 4.0 IPERF 04 7291.0 7,324.0 6,414.4 6,442.2 C-1,UNIT B, 12/30/1985 12.0 IPERF SEAL ASSY;7,073.0 1H-04 PBR;7,080.7 7,482.0 7,486.0 6,575.2 6,578.6 A-5,1H-04 12/30/1985 12.0 IPERF PACKER;7,103.8tHilli 7,496.0 7,520.0 6,587.0 6,607.1 A-4,1H-04 12/30/1985 12.0 (PERF Mandrel Inserts PRODUCTION;7.156.4 St at! on Top(ND) Valve Latch Port Size TRO Run _ N Top(ftKB) (ftKB) Make Model OD(in) Sean Type Type (in) (psi) Run Date Com IPERF;7,180.0-7,242.0- 1' 2,523.7 2,523.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/6/2014 2- 3,847.4 3,717.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.011/612014 a 3_ --5,087.6 4,652.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 111612014 SLEEVE-C;7,257.3 I ,t 4 6,024.0 5,361.6 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/6/2014 5 6,647.6 5,8672 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/6/2014 6 7,017.1 6,181.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/11/2014 elastJoim;7,286.2 11 - 7 7,156.4 6,300.1 CAMCO MMG 11/2 PROD DMY RK 0.000 0.0 11/6/2014 IPERF;7,2910-7.324.01 -- _ - Notes:General&Safety End Date Annotation 12/30/1985 NOTE:WORKOVER LOCATOR;7,332.6 an 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;7,333.5 Q=n 11/17/2014 NOTE:BARRIER VLV is NOT a safety valve;it does not fail to closed position SEAL ASSY;7,333.4 - 11/17/2014 NOTE: BARRIER VLV control lines/system Wellhead marked Open/Close SBE;7,336.8 Y @ P NIPPLE'.7,3474 WLEG 7,410 6 ," IPERF;7,482.0-7,486.0- IPERF;7,496.0-7,520.0 PRODUCTION;28.5-8,071.0 % ConocoPhillips Time Log & Summary Weliview Web Reporting Report Well Name: 1H-04 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 10/22/2014 2:30:00 PM Rig Release: 11/7/2014 4:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/21/2014 24 hr Summary RDMO 2V-11. Move Camp, Pits, Shop&misc. loads to 2H-04 well. Mobilize Rig sub from 2V-11 &begin roading rig to 1H Pad. 07:30 12:00 4.50 MIRU MOVE DMOB P 'Demob rig. R/D Interconnect. Drain prep all equip for move. Split Pit module from Rig Module. Load out Shop. 12:00 16:30 4.50 MIRU MOVE MOB P Caravan Pit Module, Camp&Shop from 2V Pad To 1H Pad. 16:30 18:00 1.50 MIRU MOVE MOB P Move Rig sub from 2V Pad to CPF-2. 18:00 00:00 6.00 MIRU MOVE MOB P Crew Change. Con't to Mobilize Rig sub from CPF-2 to 1H-Pad. Passing A access road @ 2400 hrs. 10/22/2014 MIRU. Take on kill fluid. Pull BPV. Begin well kill. 00:00 06:00 6.00 MIRU MOVE MOB P Continue to Mobilize Rig Sub to 1H Pad. 06:00 08:00 2.00 MIRU MOVE MOB P Lay Herculite and Plywood. Move and spot the sub Base over 1 H-04 Well Slot. 08:00 09:00 1.00 MIRU MOVE RURD P Raise Derrick. 09:00 12:00 3.00 MIRU MOVE RURD P Spot Rig Pits. Lay Mats. Spread Herculite. 12:00 14:30 2.50 MIRU MOVE RURD P Tie in the Pit Complex to the Rig. Get steam going in the Pits. Berm up Rig, Pits, Cutting Box, and Fuel Tank. Ready to take on fluid in Pits. Accept the rig at 14:30 hrs. 14:30 18:00 3.50 MIRU MOVE RURD P Bridle down. Photograph tree. R/U Tiger tank, choke house&lines to kill well. R/U Floor. Begin taking on 10.5 ppg NaBr-NaCI kill fluid. 18:00 20:30 2.50 MIRU MOVE RURD P Con't to take on kill fluid. Prep cellar &wellhead. Install secondary annulus valve. 20:30 22:30 2.00 MIRU WELCTI.MPSP P Hold PJSM. P/U Lubricator&test to 3000 psi. Test Good. Lubricate BPV out& L/D same. SITP-700 psi, IAP - 1000 psi, OAP-20 psi. R/D lubricator. Page 1 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 MIRU WELCTL RURD P R/U circulating lines for kill operation. PJSM. Pressure test lines to 3000 psi. Page 2 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment Page 3 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment Test lines to 3000 psi. 23:30 00:00 0.50 MIRU WELCTI KLWL P Open well&bleed off IA to 900 psi. Open Tbg&bleed off to 400 psi. Pump down IA, 2BPM for 20 bbls to recover Diesel Freeze protect. Swap valves to kill well down tbg. 10/23/2014 Finish killing well. Monitor. Install&test TWC.. N/D Tree. N/U &test BOPE. Truble shoot leaks in system. Pull completion. 00:00 02:30 2.50 MIRU WELCTI KLWL P Kill well as follows: Pump 2 BPM @ 740 psi. Pressure dropped as 10.5 brine filled tbg. Then slowly increased to 3 BPM @ 160 psi.After tbg filled w/brine pressure increased from 200 psi to 750 psi. Pumped total of 240 bbls. as per schedule. Checked returns&con't to pump add'I 37 bbls until clean 10.5 brine returns.287 bbls as per schedule. Final pump press-755 psi. OAP- 300 psi. IAP - 125 psi. S/D pump& closed in IA. Bullhead 10 bbls of 10.5 brine into wellbore. Pumped 1 BPM. Final pressure 712 psi after 10 bbls. 02:30 03:30 1.00 MIRU WELCTI OWFF P Allow well to bleed down after bull heading. Open well to atmosphere on both sides&monitor well for 30 min. Well went on slight vacuum &then died.Well static. 03:30 04:30 1.00 MIRU WHDBO MPSP P Installed 3" "H"type TWC. Pressure test TWO from bottom by pumping down IA©2 BPM. Took 4.5 bbls to catch fluid&pressure increased to 880 psi after pumping total of 20 bbls. Charted test. Reported results to engineer. 04:30 06:30 2.00 MIRU WHDBO NUND P Bled off control line. N/D tree. Inspect tubing hanger threads, good. Screw in Pup Joint 10 1/2 turns to confirm make-up,good. Page 4of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 10:00 3.50 (MIRU WHDBO NUND P Nipple up BOP Stack. (SIMOPS...load and process 3 1/2" Drill Pipe in the Pipe Shed). 10:00 12:00 2.00 MIRU WHDBO RURD P Prep Cellar and Wellhead. Rig up test equipment. Fill stack. Make-up XOs for the test joint. 12:00 17:00 5.00 MIRU WHDBO BOPE P Function test all BOPE. Perform a shell test at 250/3,000 psi. Notify the AOGCC Field Inspector, J. Jones that we are ready to begin the initial BOPE test. He said that he would be on his way to location. However, to continue with the testing. Perform the initial BOPE test at 250/3,000 psi per ConocoPhillips/AOGCC requirements at 250/3,000 psi.with a 3 1/2"test joint. Perform Gas Alarm checks...good. 17:00 18:00 1.00 MIRU WHDBO BOPE T Trouble shoot for leak. Drain stack. Check LDS, all tight. Pull Dart. Inspect same. Found damaged"0" ring. Replace"0"ring. Re-install dart back into BPV. 18:00 20:00 2.00 MIRU WHDBO BOPE T Attempt to pressure test. Close annular&Ck valve 14&8rd TIW valve in test jt. No leaks observed at surface. Noted water build up on lower ram block.Would not test. Pull test jt. . 20:00 21:00 1.00 MIRU WHDBO BOPE T Open Lower Ram door off drill side. Inspect&change out door seal. Close&tighten same. 21:00 23:30 2.50 MIRU WHDBO BOPE T Drain stack. Pull dart valve in inspect same. "0"ring good. Notify engineer &update testing problems. Discuss pulling TWC&barrier policy. Pull TWC&inspect same. Found very fine sand in plug. Fill tbg w/17 bbls. Completely disassemble, clean& redress plug. Reinstall BPV&dart into hanger. 23:30 00:00 0.50 MIRU WHDBO BOPE T Fill stack. Close Valve 14, Man Kill& blind rams. Pressure up&attempt to test. Still leaking. 10/24/2014 Complete the inital BOPE test. RU E-Line to cut tubing.RIH w/string shot Could not get below 6968'. POOH w/string shot. 00:00 04:00 4.00 MIRU WHDBO BOPE T Found drip on valve#14. &greased same.Attempt retest. still leaking. Inspect entire system¬ed a leak on DSA. P/U&spit stack. Remove ring gasket&inspect same. No damage. Check flanges¬ed a stamping on spool: RX-46. R-46 was installed. Called for RX-46. Tool House found one. Page 5 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 MIRU WHDBO BOPE T Install RX-46 ring Gasket&set stack back on Spool. Tighten up bolts. Inflated riser doughnut. 05:00 06:00 1.00 MIRU WHDBO BOPE T P/U 3 1/2"doughnut test jt&Make space out marks for testing. Set down same. Fill stack&test stack. 06:00 08:00 2.00 MIRU WHDBO BOPE T Resume BOPE pressure testing. Obtain a 250 psi x 5 miniutes/3,000 psi x 5 minutes straight line test. Call AOGCC Field Inspector, J. Jones and tell him that we are ready to resume official testing. As per his request...He will return to location to witness the remainder of the testing. 08:00 10:30 2.50 MIRU WHDBO BOPE P Resume the official initial BOPE test as per ConocoPhillips/AOGCC requirements at 250/3,000 psi using a 3 1/2"Test Joint. Perform the Koomey draw down test. Test witnessed by J. Jones,AOGCC Field Inspector. All pressure tests recorded on a chat. 10:30 11:00 0.50 MIRU WHDBO RURD P Rig down test equipment. Fill hole present fliod loss=3 bbls/hr. 11:00 11:30 0.50 COMPZ WHDBO MPSP P Pull Dart and BPV. 11:30 13:00 1.50 COMPZ RPCOM PULL P Pick-up Landing Joint. BOLDS. Attempt to pull the Tubing hanger to the floor. Saw Tubing Hanger pull off seat at 60K. Worked/cycled J-55 grade tubing meany times up to 80% joint yield (114K+30K Blocks= 144K). Tubing appears not severed at 6,978-ft elmd. Total streatch= 7.7-ft. 13:00 15:00 2.00 COMPZ RPCOM ELNE X Call out HES E-line. Read Floor for E-line operations. 15:00 18:00 3.00 COMPZ RPCOM ELNE X HES E-Lline Unit arrived on loction. Spot Unit. Ready logging tools and lubricator. 18:00 20:30 2.50 COMPZ RPCOM ELNE X Finish R/U E-Line equip. P/U& assemble Lubricator. Load String shot tool. Pressure test Lubricator 1000 psi, OK. 20:30 23:00 2.50 COMPZ RPCOM ELNE X RIH w/String Shot. Tools went to 6960 w/CCL&bottom of String Shot @ 6968'. Would not go deeper. POOH w/string shot& L/D same. 23:00 00:00 1.00 COMPZ RPCOM ELNE X M/U Radial Torch Cutting tool. Could not get steady current to function properly. Check equip for problem. 10/25/2014 RIH&cut Tbg. Clear ice from derrick. Pull hanger&R/U to pull completion.POOH&L/D completion. M/U BHA#1 Overshot Assy&RIH. 01:00 01:30 0.50 COMPZ RPCOM ELNE XT Con't to work on electrical short problem.line equip. Replaced swtch in equip. Page 6of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 04:00 3.50 COMPZ RPCOM ELNE X P/U lubricator&RIH w/Radial Cutting Torch tool. Tagged up @ 6960'. Same spot as String Shot. P/U&had to jar off. Tool came free. Discuss plan w/engineer. P/U to 6945' (middle of 1st full jt above restriction). Fire RCT&had good indication of cut. POOH&stand back lubricator. RCT fired. 04:00 05:00 1.00 COMPZ RPCOM SFTY T Several chunks of ice fell from derrick. Perform derrick inspection& knock ice from derrick. 05:00 07:00 2.00 COMPZ RPCOM ELNE X Finish securing lubricator. R/D Sheaves. Set back E-line equipment. Pulled Tubing free at 85K with no drag.. Complete E-line rig down and clear floor. Release E-Line Unit. 07:00 08:00 1.00 COMPZ RPCOM CIRC P Reverse circulate tubing volume at 3.0 bpm/418 psi. total volume reversed 100 bbls. Returns clean. Loss rate 3 bbls in 2.7 bbls returned. 08:00 08:30 0.50 COMPZ RPCOM OWFF P Monitor Well on slight vacuum. Blow down lines. Rig down circulating equipment. 08:30 09:00 0.50 COMPZ RPCOM RURD P Rig up Schlumberger Spooling Unit. Rig up GBR tubing handling equipment. 09:00 10:30 1.50 6,945 6,325 COMPZ RPCOM PULL P Lay down Landing Joint and Tubing Hanger. Single down the 3 1/2" completion to the"cut". Number, tally, and kick out Tubing and GLMs as needed. 10:30 11:00 0.50 6,325 6,325 COMPZ RPCOM EQRP T Stop to repair the Kicker Ram on the Pipe Skate. 11:00 11:30 0.50 6,325 6,325 COMPZ RPCOM SVRG P Inspect Top Drive. 11:30 13:00 1.50 6,325 5,147 COMPZ RPCOM PULL P Resume operations. Continue to single down the 3 1/2"Completion from 6,325-ft to the SSSV. Recovered 34 SS Bands(expected 36 per the old Tubing Running Summary). Lay down the SSSV. 13:00 13:30 0.50 5,147 5,147 COMPZ RPCOM RURD P Rig down the Schlumberger Spooling Unit and clear from the floor. NORM the recovered Control Line...0K. 13:30 16:00 2.50 5,147 2,884 COMPZ RPCOM PULL P Resume operations. Continue to single down the 3 1/2"Completion from 5,147-ft. POOH to 2884'. P/U Wt-50K. 16:00 17:30 1.50 2,884 2,884 COMPZ RPCOM PULL T Replace leaking hose on Skate. Page 7of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 21:00 3.50 2,884 0 COMPZ RPCOM PULL P Cont to POOH&L/D 3 1/2" Completion. POOH from 3884 to surface. Recovered 225 jts+ 1 Cut off jt(16.21'), +7 GLMs, + 1-SSSV, +23.88' Pups+ Hanger&Pup. Note: From Jt#212 corrosion increased markedly. Jts 215&217 had pitting in collars&on tubes. Cut looked good&in gauge., no flare. 21:00 22:00 1.00 0 0 COMPZ RPCOM RURD P Clear&clean rig floor. R/D tubing tools &power tongs. R/U floor to P/U BHA#1 & DP. 22:00 23:00 1.00 0 COMPZ RPCOM RURD P P/U&install Wear Bushing. RILDS. L/D running tool. Wear Bushing ID= 6.25". 23:00 00:00 1.00 0 210 COMPZ RPCOM PULD P P/U&M/U BHA#1 as follows: Cut Lip Guide, Overshot, Overshot Extension, Top Sub, Bumper Sub, Oil Jars, 9-4 3/4" DCs,X-Over TL= 300.65'. 10/26/2014 Finish P/U BHA&RIH. P/U DP& RIH to—6855'. Cut&slip line. Engage fish @ 6945' Pull fish free. Displace to filtered Brine. POOH w/fish. M/U BHA#2. RIH. Fish Tbg stub&PBR. Monitor well. 00:00 00:30 0.50 210 301 COMPZ RPCOM PULD P Finish M/U& RIH w/BHA#1. 00:30 00:45 0.25 301 301 COMPZ RPCOM SFTY P Hold D1 drill: Kick while tripping. Well shut in in 42 sec. All personnel in position&reported in 76 sec. Held AAR. 00:45 06:00 5.25 301 6,009 COMPZ RPCOM PULD P P/U 3 1/2"DP&single in hole w/ BHA#1. In the hole w/181 jts. Stop to slip and cut drilling line. 06:00 07:30 1.50 6,009 6,009 COMPZ RPCOM SVRG P Slip and cut 102-ft of Drilling Line. Inspect Drawworks. Inspect Deadman Brass. 07:30 09:30 2.00 6,009 6,927 COMPZ RPCOM PULD P Continue to single in with BHA#1 on 3 1/2"Drill Pipe. Tagged the top of the 3 1/2"Tubing stump at 6,927-ft. 09:30 10:30 1.00 6,927 6,927 COMPZ RPCOM FISH P Establish parameters as follows: Up weight= 150K. Down weight= 105K. Pump rate=3.0 bpm/400 psi. Free Torque= 15 RPMs/6,000 ft/lbs. RTW= 120K. Re-tag the top of the 3 1/2"Tubing stump. Plant Overshot. Load Jars at 190K...straight pull up to 245K. Tubing free. (however, it appeared the way the Drill Pipe jumped that it is quite possible that the tubing came free at the original cut at 6,978-ft and not the Seals pulling free from the HB-1 Packer). 10:30 12:00 1.50 6,927 6,922 COMPZ RPCOM CIRC P Displace the Wellbore over to clean filtered(2 micron) 10.5 lb/gal Brine from 6,922-ft at 3.0 bpm/490 psi. Page 8of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:30 3.50 6,922 25 COMPZ RPCOM TRIP P Trip out with BHA#1, standing back the 3 1/2" Drill Collars in the Derrick. Rack back the 4 3/4" Drill Collars. 15:30 16:00 0.50 25 0 COMPZ RPCOM PULD P Pull BHA#1 and Fish to surface. As anticipated the tubing parted at the original Pre-RWO Chemical cut. The cut was in gauge. Approximately 70%of the tubing was severed by the chemical cutter...the remaining tubing wall was pulled free during the fishing operations. 16:00 17:30 1.50 0 0 COMPZ RPCOM PULD P Break out&L/D Fish&BHA. Fish is 35.67' Consisting of Cut jt, Merla TP DX, cut jt. 17:30 19:30 2.00 0 311 COMPZ RPCOM PULD X Redress Overshot&M/U& RIH w/ BHA#2 as follows: Cut Lip Guide, Overshot, Overshot Extension, Top Sub, Bumper Sub, Oil Jars, 9-4 3/4" DCs, Intensifier,X-Over, TL= 311.12'. 19:30 22:00 2.50 311 6,935 COMPZ RPCOM TRIP X Trip in hole w/BHA#2 from 311 to 6935. P/U 2 singles& M/U Top Drive. 22:00 23:30 1.50 6,935 6,904 COMPZ RPCOM FISH X P/U Wt- 150K, S/O Wt- 100K. Rotate @ 15 RPMs&slowly go down over fish @ 6963'. Bottom out @ 6967'w/15K down wt. P/U & begin working pipe up to 250K,then begin jarring.Jar w/60-75K over to 225K.After 15th jar Fish came free. P/U Wt- 157K. L/D 2 jts DP. 23:30 00:00 0.50 6,904 6,904 COMPZ RPCOM OWFF X Fill hole w/5 bbls. Monitor well for 30 min. Fill hole w/5.6 bbls. 10/27/2014 Perform post jarring&derrick inspection. POOH w/BHA#2. Break out& L/D fish&BHA#2. M/U BHA #3.Tool would not function. L/D BHA#3. M/U BHA#4&RIH. Fish Pkr& Blast jts. POOH &begin L/D Fish. RIH&fish completion. 00:00 01:00 1.00 6,904 6,904 COMPZ RPCOM SFTY X Perform post jarring inspection& derrick inspection.. Inspect Top Drive. 01:00 04:30 3.50 6,904 311 COMPZ RPCOM TRIP X POOH w/BHA#2. 04:30 05:00 0.50 311 25 COMPZ RPCOM TRIP X Break out& L/D intensifier.POOH& stand back 3 stands of DCs. 05:00 06:30 1.50 25 0 COMPZ RPCOM PULD X P/U, Break out& L/D fish& BHA#2. Fish recovered as follows: 3 1/2"Cut Joint=20.0-ft and the SBR= 22.85-ft 06:30 08:00 1.50 0 327 COMPZ RPCOM PULD P PJSM. Inspect RatPack Tool Screen...clean. Make-up BHA#3 as follows: Cut Lip Guide, Overshot Bowl w/4 1/4"Grapple, Extension, Top Sub, Drilling Safety Joint, Drain Sub, RatPack Impulse Tool, Bumper Sub, Oil Jar, Pump-Out-Sub, 9 ea 4 3/4"Drill Collars,XO. Page 9 of 21 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 08:00 09:00 1.00 327 327 COMPZ RPCOM CIRC T Test RatPack Tool with 2 micron filtered 10.5 lb/gal Brine at 1 bpm/80 psi,2 bpm/500, 2.5 bpm/775 psi, 3.0 bpm/1,050 psi. Unable to start Tool. Reverse circulate to clear Tool. Attempted a second time to start Tool as before. No-Joy. 09:00 09:30 0.50 327 0 COMPZ RPCOM PULD T Lay down RatPack Tool#1. (ship to Baker Fishing Shop for inspection and re-build) 09:30 10:00 0.50 0 328 COMPZ RPCOM PULD T Make-up BHA#4 with the back-up RatPack Tool#2. 10:00 10:15 0.25 328 328 COMPZ RPCOM CIRC P Test RatPack Tool#2 at 1.0 bpm/1,200 psi. Tool working great. 10:15 15:30 5.25 328 6,982 COMPZ RPCOM TRIP P Trip BHA#4 in on 3 1/2"Drill Pipe from the Derrick. Lightly tag top of the Slick Stick at 6,982-ft dpmd. Fill the Tubing with 2 micron 10.5 lb/gal Brine. 15:30 16:30 1.00 6,982 6,982 COMPZ RPCOM FISH P Establish parameters as follows: Up Weight= 150K. Down weight= 105K. Pump rate= 1.0 bpm/1,075 psi. RTW= 120K. Free Spin Torque =6K/15 RPMs. Plant Overshot and swallow down to 6,987-ft. Bring Pump on line at 1.5 bpm/1,285 psi. Tool started up. Pull string up to 215K and allow Tool to"rattle". Observe slow bleed off of the string weight. Gradually work string weight up to 225K. String jumped free. Pulled up hole. Might has gained a small amount of string weight? Set back down and tagged at the same spot. No overshot bite. Either we have a Fish or the Overshot stripped off. 16:30 17:00 0.50 6,982 6,982 COMPZ RPCOM OWFF P Monitor Well...still taking 5-8 bbls/hr. 17:00 21:00 4.00 6,982 328 COMPZ RPCOM TRIP P POOH w/BHA#4&fish. P/U Wt- 150K, S/O Wt-105K. Had up to 50K overpull&worked thru tight spots 1st 2 stands off bottom. 21:00 21:30 0.50 392 51 COMPZ RPCOM TRIP P Fill hole w/ Monitor well 10 min. Con't to POOH w/1 stand of DP&3 stands of DCs. 21:30 00:00 2.50 51 0 COMPZ RPCOM PULD P Break out&L/D BHA#4. Begin laying down fish.Recovered: Cut Jt, HB-1 Pkr, 4 Jts 3 1/2 Tbg,2-Merle TPDX GLMs. Pull Jts to surface w/ Blast rings. R/U Pesi &begin to L/D Blast jts. 10/28/2014 Finish L/D Fish. M/U BHA#5. RIH&fish completion.Circulate Hole Clean.TOOH. Stop Trip and condition system to 10.2 ppg viscosified brine. Losses for the day—410 bbls. Page 10 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 COMPZ RPCOM PULL P Break out&L/D 3 jts 3 1/2"tbg w/ Blast rings, &Cut pup Jt.. L/D Blast jt handling tools. Sleeves& connections on blast jts difficult to uncover&break. P/U Overshot& Break out tbg stub.. 03:00 04:30 1.50 0 415 COMPZ RPCOM PULD P Redress Overshot&M/U BHA#5. as follows: Cut Lip Guide, Overshot,Top Sub, Drilling Safety Jt, Drain Sub, RatPack Impulse Tool, Bumper Sub, Oil Jars, Pump Out Sub, 9-4 3/4" DCs, XO. TL=325.50. RIH w/BHA + 1 stand. Test RatPack Impulse Tool. Tested Good. 04:30 06:00 1.50 415 2,140 COMPZ RPCOM TRIP P RIH w/BHA#5 from 415 to 2140'. 06:00 10:45 4.75 2,140 7,261 COMPZ RPCOM TRIP P Crew change. Continue to trip in with BHA#5 on 3 1/2" Drill Pipe from 2,140-ft. Tagged the top of the next fish at 7,261-ft dpmd. 10:45 12:00 1.25 7,261 7,258 COMPZ RPCOM FISH P Establish parameters as follows: Up weight= 150k. Down weight= 108k. RTW= 120k at 15 RPMs. Free Spin Torque=6,000 ft/lbs. Attempt to plant/rotate Overshot over the top of the fish, several times with No-Joy. Bring Pump on line at 1.0 bpm/1,115 psi and start the RatPack Tool. Rattled over the top of the Fish. Continue down to Overshot swallow depth at 7,264-ft dpmd. End rattle. Bleed pressure. Plant Overshot with Much-Joy. Pull up 225k. Bring Pump on line at 1.5 bpm/1,220 psi. Observe slight weight bleed off. Increase pump rate to 2.0 bpm/1,350 psi. Pull up to 250K and increase pump rate to 2.5 bpm/1,575. Continue to rattle and observe small increments of weight bleed-off. Continue to keep pulling back up to 250K/260k and allow RatPack Tool to work. Continue to make slow progress. Present net gain at 12:00 hrs=3-ft. 12:00 13:30 1.50 7,258 7,257 COMPZ RPCOM FISH P Continue to work RatPack Tool at 2.5 bpm/1,600 psi Pull up to 265K. Made one more foot then any further progress stalled out. However, RatPack Tool continues to work. Cycle the Jars x 5 hits and the fish came free. 13:30 15:30 2.00 7,257 7,257 COMPZ RPCOM OWFF P Monitor well...still taking fluid at a rate of 4-6 bbls/hr. (SIMOPS: Perform a complete Derrick and Top Drive inspection due to the vibration from the RatPack Tool during the fishing operation). Page 11 of 21 , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 7,257 7,163 COMPZ RPCOM TRIP P Start to Trip out. Observe swabbing with the first stand. (Stop to monitor. Observe slight flow). 16:00 17:00 1.00 7,163 7,163 COMPZ RPCOM CIRC P Still observe sight flow. Drop ball and open the Circulating Sub. Bring the Pump on line at 5.0 bpm/1,005 psi. 17:00 18:30 1.50 7,163 6,665 COMPZ RPCOM TRIP P Trip out of hole from 7163'to 6665'. 18:30 19:00 0.50 6,665 6,665 COMPZ RPCOM OWFF P Monitor well. Loss rate 40 bph. SIMOPS: Clear Ice from Derrick. 19:00 21:00 2.00 6,665 4,293 COMPZ RPCOM TRIP P Trip out of hole from 6665'to 4293'. Observed tight spot at 6652,40k overpull,worked through.Continue filling hole every 10-15 minutes. Fluid losses leveled at—40-50 bph. SIMOPS: Contact CPAI Engineer about fluid losses. Decision to stop trip.Adjust active system to 10.2 ppg and Viscosify system and circulate well at current depth to new weight to slow losses. 21:00 00:00 3.00 4,293 4,293 COMPZ RPCOM COND T Condition Active System to 10.2 ppg viscosified Brine. 10/29/2014 Circulate 10.2 ppg fluid into hole. Continue TOOH and LD BHA#5 and fish. PU and RIH with BHA#6(packer burn shoe). Circulate hole to uniform 10.2 ppg. Losses for the day—345 bbls. 00:00 03:00 3.00 4,293 4,293 COMPZ RPCOM COND T Condition Active System to 10.2 ppg Viscosified Brine. 03:00 04:15 1.25 4,293 4,293 COMPZ RPCOM CIRC T Circulate in 10.2 ppg Viscosified(60 Vis)Brine. Observed 15 bbls lost during circulation.220 bbl pumped, 5 bpm @ 500 psi. 04:15 04:45 0.50 4,293 4,293 COMPZ RPCOM OWFF T Monitor well. Static after 10 minutes. at 10-15 bph loss rate after 25 minutes. 04:45 09:30 4.75 4,293 326 COMPZ RPCOM TRIP P Trip out of hole from 4293' . Continue filling hole every 10-15 minutes. Fluid losses began at—35 bph, now at—13 bbl/hr. 09:30 10:00 0.50 432 106 COMPZ RPCOM PULD P BHA#5 at surface. Lay down same. 10:00 13:00 3.00 106 0 COMPZ RPCOM PULL P Fish#2 at surface. Lay down the HB-1 Packer. Install table to handle the Blast Ring Joints. Lay down 2 Joints of Blast Rings. Remove table. Lay down the Sliding Sleeve Assembly. Lay down the Seal Assembly. Total length of Fish recovered 105.88-ft. Also recovered the Bowen Center Spear and the"KB Snap Latch Bait Profile section of the Tubing Patch. (Note:the Spacer Joint and the Seal Unit from the Tubing Patch remain in the next Packer Fish). 13:00 15:00 2.00 0 0 COMPZ RPCOM PULD P Clear and clean Floor. SIMOPS: Break out packer from BHA#5 overshot. 1____ Page 12 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 0 363 COMPZ RPCOM PULD P Make-up BHA#6 as Follows: Metal Muncher Burn Shoe,2 wash pipe extensions, Boot Basket, Oil Jar, Bumper Sub, 9x Drill Collars, XO. Total Length 363' 16:30 21:30 5.00 363 7,289 COMPZ RPCOM TRIP P RIH w/BHA#6 from 363'to 7308' where it took weight. Pull up to 7289'. Up Wt= 165k, Dn Wt= 110k. 21:30 22:30 1.00 7,289 7,289 COMPZ RPCOM CIRC P Circulate BU (+). Once consistent column take SPRs and establish parameters. Up Wt= 150k, Dn Wt= 100k; Rot Wt= 125k; 80 rpm, TQ= 6k; 5 bpm @ 870 psi SPRs @ 6422'TVD: #1: 2 bpm @ 300 psi; 3 bpm @ 460 psi #2: 2 bpm @ 310 psi; 3 bpm @ 470 psi 22:30 00:00 1.50 7,289 7,370 COMPZ RPCOM WASH P Wash Down to 7370'. Have to rotate while washing from 7380'to 7370'. No problem going over top of fish sticking up from packer. 80 RPM. 10/30/2014 Mill Packer and push to bottom. Pump out of hole. LD BHA#6. Losses for the day— 150 bbls(only 8 bbls for last 6 hours). 00:00 06:00 6.00 7,368 7,369 COMPZ RPCOM MILL P Mit Packer. Packer top spinning beneath Burn Shoe. Vary pump rates (0 bpm dry milling-5 bpm), WOM (7k- 17k)and RPM(20-100)to help milling of packer. 06:00 10:00 4.00 7,396 7,374 COMPZ RPCOM MILL P Continue to Mill on"Spinning Packer". Continue to vary WOMB (15-20K). Pump rate, 2.0 bpm/542 psi. Occasionally pick up off of Packer...re-tag and dry mill. Very slow progress. 10:00 13:30 3.50 7,374 7,488 COMPZ RPCOM MILL P Packer started moving down hole. Continue to rotate and push as needed. Continue on down and encountered fill at 7,512-ft dpmd. Set down 5K. Present depths. End of Fish#3 Paker/Tailpipe=7,512-ft. Packer depth at 7,488-ft. Top of the Tubing Patch Spacer Joint sticking above the Packer=7,469-ft. 13:30 14:15 0.75 7,488 7,488 COMPZ RPCOM OWFF P End Pump. Blow down Top Drive. Monitor Well...static. 14:15 15:00 0.75 7,488 6,467 COMPZ RPCOM TRIP P Up weight= 165K. Trip out with BHA#6 and 10 Stands of Drill Pipe. Observe swabbing due to thick viscosified 10.2 lb/gal Brine. 15:00 16:00 1.00 6,467 6,467 COMPZ RPCOM OWFF P Monitor Well. Fluid level falling very very slowly. Bring Pump on line at slow rate to verify hole fill. (Took 5 bbls to gain circulations). End Pump. Monitor Well static once again. Page 13 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 22:30 6.50 6,467 363 COMPZ RPCOM TRIP P Continue to trip out while pumping with BHA#6 and 3 1/2" Drill Pipe. 22:30 23:00 0.50 363 363 COMPZ RPCOM OWFF P Monitor Well. Well showing losses of —4-5 bph. 23:00 00:00 1.00 363 0 COMPZ RPCOM PULD P Lay Down BHA#6. Boot Basket and Extensions show significant wear. --1 lb of metal, carbide and rubber fragments recovered from boot basket. 10/31/2014 PU and TIH with BHA#7 to fish milled packer and tail pipe. Pump out of hole. LD BHA#7 and fish. Fish was 2.08"spacer joint, packer and tailpipe with total length of fish as 44.20'. Losses for the day--75 bbls 00:00 01:15 1.25 0 0 COMPZ RPCOM RURD P Clean and Clear Rig Floor. 01:15 01:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM Picking Up BHA#7 with all rig hands involved. 01:30 02:30 1.00 0 310 COMPZ RPCOM PULD P Pick Up BHA#7(Overshot with Grapple 2 1/16"). Overshot/Grapple, Pump Out Sub, Bumper Sub, Jars, 3 stands of Drill Collars. Total Length 310.07'. 02:30 06:30 4.00 310 7,215 COMPZ RPCOM TRIP P Trip in hole with BHA#7. 06:30 08:00 1.50 7,215 7,215 COMPZ RPCOM SLPC P Stop to slip and cut(76-ft) Drilling Line. 08:00 08:30 0.50 7,215 7,215 COMPZ RPCOM SVRG P Adjust Brake Bands. Service Top Drive. Service Crown. 08:30 10:00 1.50 7,215 7,438 COMPZ RPCOM TRIP P Continue to trip in with BHA#7 on 3 1/2" Drill Plpe from the Derrick. Wash down the last 2 1/4 Stands at 2.5 bbpm/1,015 psi. Establish parameters as follows: Up weight= 158K. Down weight= 112K. Free Spin Torque at 17 RPMs=6K ft/lbs. RTW= 130K. 10:00 10:30 0.50 7,438 7,470 COMPZ RPCOM FISH P Reduce rate to 1.0 bpm/417 psi. Ease in hole very slowly looking for the top of the 2"Spacer Joint (expected depth=7,469-ft.). Tagged at 7,467-ft dpmd with 1K. Also noted and increase in pump pressure to 650 psi. Shut down Pump. Bleed off pressure and slip over the top of the Fish with no problem. Swallow down to 7,470-ft dpmd. Set down 5K. Pick-up and observe no over pull. Set back down with 5K. Pull back up with same results. Bring Pump back on line at 1.0 blm/420 psi. Set back down on bottom with 5K...pump pressure did not increase much. Pull 1 Stand. Observe swabbing thick viscosified fluid. Also observed a 10k- 15K overpull with Fish going by the first Casing Collar. Stop to monitor Well. 10:30 11:00 0.50 7,470 7,376 COMPZ RPCOM OWFF P Monitor Well x 30 minutes. Fluid level remains static. Page 14 of 21 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 22:30 11.50 7,376 354 COMPZ RPCOM TRIP P Continue to trip out while pumping with BHA#7 and 3 1/2"Drill Pipe. Saw a 10K overpull going through the perforations(good sign that we may have a double Fish...). Continue to trip/pump out with the fish hanging up every once in a while. Tripped out final ten stands on elevators without pumping. 22:30 23:00 0.50 354 354 COMPZ RPCOM OWFF P Monitor well at last stand prior to bringing BHA components into stack.Well taking fluid. 23:00 00:00 1.00 354 44 COMPZ RPCOM PULD P Lay Down BHA#7. 11/01/2014 BOPE Test. Change out Savor Sub. PU and TIH with BHA#8(scraper/cleanout). Cleanout and scrape past perfs to 7600'. Circulate hole clean. Losses for the day—30 bbls 00:00 00:30 0.50 44 0 COMPZ RPCOM PULL P Lay down fish and remove grapple from fish. Fish consisting of 2.08" ID spacer joint(19.76' long)and packer with tail pipe(24.44' long). Total length of fish is 44.20'. SIMOPS: Clean and clear rig floor. 00:30 02:00 1.50 0 0 COMPZ WHDBO WWWH P Remove Wear Ring and jet stack and wellhead with stack jetting tool to clean of any debris from milling and fishing operations. 02:00 03:00 1.00 0 0 COMPZ WHDBO RURD P Rig Down from Washing Stack. Run and set test plug. Rig Up testing equipment. 03:00 11:00 8.00 0 0 COMPZ WHDBO BOPE P Test BOPE as per ConocoPhillips/AOGCC requirements at 250/3,000 psi with a 3 1/2"Test Joint. Perform Koomey draw down test. All pressure tests recorded on a chart.. Right to witness test waived by AOGCC Representative Chuck Scheve. Note: Actual BOPE test=6.0 hours. Continue to perform the Annual Choke and Kill Line test both to 5,000 psi. as per ConocoPhillips requirement. Good test. Recorded on chart. 11:00 12:00 1.00 0 0 COMPZ WHDBO RURD P Rig down test equipment. Drain Stack. Blow down lines. Pull Test Plug. Install Wear Bushing. 12:00 14:30 2.50 0 0 COMPZ WELLPF SVRG P Install new Savor Sub on Top Drive. Service Iron Roughneck. Clear Floor 14:30 15:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM. Making up the new BHA 15:00 17:00 2.00 0 362 COMPZ WELLPF PULD P Pick-up BHA#8...Clean-out Assembly as follows: 6 1/8"Junk Mill, 4 ea Boot Baskets, Bit Sub, 2 ea 6 1/8"String Mills, 7" Extreme Clean Casing Scraper, Extreme Clean MAgnet, Grabitz Magnet, Bumper Sub, Oil JAr, Pump-Out Sub, 9 ea 4 3/4"Drill Collars,XO. Page 15 of 21 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:00 3.00 362 7,169 COMPZ WELLPF TRIP P Trip in hole with BHA#8 to 7169'. Up Wt= 150k, Dn Wt= 105k. 20:00 22:30 2.50 7,169 7,600 COMPZ WELLPF WASH P Move through perf areas with concave mill and scraper to clean casing of any obstructions and to clean fill from 7512'to 7600'. Up Wt = 153k, Dn Wt= 110k, Rot Wt= 125k, 60 rpm, Free TQ=6k, 5bpm @ 1050 psi.WOM =2k-6k, TQ =6k ftlb. Tagged fill bridge at 7512', worked through with rotation and pumps easily. No other areas of note down to 7600'. Some sand and fill observed at bottoms up but nothing of note. SPRs@6548'TVD, MW= 10.2 ppg: #1 2 bpm =530 psi, 3 bpm =650 psi #2 2 bpm =530 psi, 3 bpm =640 psi 22:30 23:00 0.50 7,600 7,600 COMPZ WELLPF CIRC P Circulate BU+with old Vis'd up 10.2 ppg mud. filthy 10.2 returns observed with traces of sand. 5bpm @ 1060psi. Continue to circulate well clean and offload old Brine in preparation to swap to new Brine. 4 bpm @ 960 psi. 23:00 23:15 0.25 7,600 7,600 COMPZ WELLPF SFTY P PJSM for displacement to new 10.2 ppg brine system.All hands and third party support present. SIMOPS: Monitor well,well slows from slight flow to STATIC over 3 minutes. 23:15 00:00 0.75 7,600 7,600 COMPZ WELLPF CIRC P Circulate well over to new 10.2 Brine. Take returns to Tiger Tank via choke shack. SIMOPS: Clean out cuttings bin. Load Storm Packer to pipe shed. Clean Pit 4 and Trip Tank for use with new 10.2 Brine. 11/02/2014 Trip out of hole to above perfs. Monitor hole. TOOH pumping out. PU and hang off Storm packer and PT same. Nipple Down BOPs and Nipple Down Gen 3 head and Nipple Up new Gen 4 tubing head. Losses for the day—60 bbls 00:00 00:30 0.50 7,600 7,600 COMPZ WELLPF CIRC P Continue to circulate well over to new 10.2 Brine. Take returns to Tiger ,Tank via choke shack. 00:30 00:45 0.25 7,600 7,600 COMPZ WELLPF OWFF P Monitor while lining up to pump from pits. STATIC. 00:45 01:45 1.00 7,600 7,080 COMPZ WELLPF TRIP P Pump 6 stands out of hole to observe well above top perfs. 01:45 02:15 0.50 7,080 7,080 COMPZ WELLPF OWFF P Monitor well. Well taking fluid. estimate of 2-3 bbls loss rate for 30 minutes(5 bph loss rate). Page 16of21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 10:45 8.50 7,080 1,212 COMPZ WELLPF TRIP P Trip out of the hole. Loss rate increases from 4 bph at start of trip to 14-15 bph after 15 stands tripped. Continue tripping out of hole while pumping out with Vis'd up clean 10.2 ppg Brine. Stop trip with 9 stands and BHA still in hole for—27k lbs to be hung off under storm packer. Blow down the Top Drive. NOTE:The time for this trip is 1 hour shorter than actual time to reflect time being set back for Daylight Savings Time. 10:45 11:00 0.25 1,212 1,212 COMPZ WELLPFSFTY P PJSM...Pick-up Baker7"Storm Packer. 11:00 12:30 1.50 1,212 1,212 COMPZ WELLPF MPSP P Pick up Baker 7"Storm Packer. Run in on 1 stand of Drill Pipe. Set per the Baker Packer Service Hand at—94-ft below Rotary Table. Set back 1 Stand. Lay down Setting/Retrieving Tool. 12:30 13:00 0.50 1,212 1,212 COMPZ WELLPF PRTS P Pressure test Storm Packer from above at 1,000 psi x 5 minutes. Record on chart. Good. 13:00 14:30 1.50 1,212 1,212 COMPZ WELLPF NUND P Nipple down the BOP Stack and set back on the stump. 14:30 21:00 6.50 1,212 1,212 COMPZ WELLPF NUND P Nipple down the McEvoy Gen 3 Tubing Head(Note: Controlled Casing growth with long studs. (7" Casing growth=3 1/4"). Replace old packoff with new packoff. PU spear and spear 7"stub and stretch 14",will not stretch far enough to set emergency slips under Hanger. Use spear to push down setting weight down with top drive on stub.Work 20+times.7"stub needs to compress 3/8"in order to run in lockdowns.While working 7"stub with spear rig up PESI Hydratight. Release spear and bring to rig floor. Utilize Hydratight tool to compress 7"in order to Run in Lock down screws. Nipple Up New Gen 4 McEvoy Tubing Head. 21:00 22:00 1.00 1,212 1,212 COMPZ WELLPF PULD P Lay down spear. SIMOPS: Rig down Hydratight. 22:00 22:30 0.50 1,212 1,212 COMPZ WELLPF PRTS P Test void 250/5000 psi for 10 minutes each. Good test. 22:30 00:00 1.50 1,212 COMPZ WELLPF NUND P Set test plug. Install secondary Annulus valve. Set DSA. 11/03/2014 NU BOPE.Test breaks. Retrieve Storm Packer.TOOH and LD BHA#8. PU and RIH with Lower Completion on DP. Rig Up HES E-Line. Losses for the day -47 bbls 00:00 02:30 2.50 1,212 1,212 COMPZ WELLPF NUND P Nipple Up BOP stack. Install riser, turnbuckles. Page 17of21 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:15 0.75 1,212 1,212 COMPZ WELLPF BOPE P Test Break on Tubing head and BOP stack to 250/3000 psi. 03:15 04:00 0.75 1,212 1,212 COMPZ WELLPF RURD P Rig down testing equipment. Pull test plug. Install 6 3/8"wear ring. 04:00 04:15 0.25 1,212 1,212 COMPZ WELLPF SFTY P PJSM for releasing and retrieving storm packer. 04:15 05:00 0.75 1,212 1,212 COMPZ WELLPF MPSP P Pick up setting tool and 1 stand and make up to Storm Packer, Close Annular, open equalization port, release packer. No pressure observed on DP or Annulus. Blow down top drive. Observe well on vacuum. 05:00 05:30 0.50 1,212 362 COMPZ WELLPF TRIP P Trip out of hole with BHA#8. 05:30 08:00 2.50 362 0 COMPZ WELLPF PULD P Lay Down BHA#8(including 9-4 3/4"Drill Collars). Clean Magnets. Dump Boot Baskets. Total recovery = 24 pounds of metal shavings. 08:00 10:00 2.00 0 0 COMPZ WELLPF WWWH P Wash Wellhead and BOP Stack. Clean and clear Floor 10:00 11:00 1.00 0 0 COMPZ RPCOM RURD P Lay down rig handling equipment. Rig up GBR tubing handling equipment. 11:00 12:00 1.00 0 0 COMPZ RPCOM SFTY P PJSM/Operation Meeting for running the Lower completion. Review running order and perform the final jewelry inspection. 12:00 14:45 2.75 0 150 COMPZ RPCOM PUTB P Pick-up the Lower Completion components as follows: 5 1/2"Mule Shoe Wearsox Joint w/WLEG, 5 1/2" Wearsox Joint(note both joints have Wearsox bands every 3-ft), 5 1/2"x 3 1/2"Vent/Ported XO, 3 1/2"Pup Joint 2 ea 8-ft 3 1/2"Space-Out Pup Joints, 3 1/2"x 2.813"X-Nipple Assembly, Baker 80/40 SBE, Baker 85/40 F-1 Permanent Packer.All connection below the Packer are Baker-Lock'd. Make-up Baker B-2 Hydraulic Setting Tool,XO, Handling Pup Joint. 14:45 15:15 0.50 150 150 COMPZ RPCOM RURD P Rig down GBR tubing handling equipment. Rig up floor equipment to trip 3 1/2"Drill Pipe. Loss rate at 6 bph. 15:15 23:30 8.25 150 7,455 COMPZ RPCOM RCST P Trip in with Lower completion on Drill Pipe(77 stands and 2 pups: 14.96', 4.97')to 7455'. Break Circulation. Set in slips. Up Wt= 145k, Dn Wt= 115k 23:30 00:00 0.50 7,455 7,455 COMPZ RPCOM ELOG P Rig Up E-Line for correlation run. 11/04/2014 Correlate depth with HES E-Line. Set Packer with Packer top at 7333'. POOH laying down DP. PU and RIH with Upper 3.5"completion. Losses for the day—56 bbls 00:00 02:00 2.00 7,455 7,455 COMPZ RPCOM ELOG P Rig Up HES E-Line to run correlation log for Lower Completion. Pressure test lubricator to 1000 psi. Page 18 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 05:00 3.00 7,455 7,455 COMPZ RPCOM ELOG P RIH with Gamma Logging Tool. Make 3 passes to tie into Gamma Ray signatures from original logs. Correlation confirms depth is good for setting Packer. POOH. Contact CPAI Engineer and review logs and confirm hole location and setting depth is correct. 05:00 06:15 1.25 7,455 7,455 COMPZ RPCOM FLOG P Rig Down HES E-Line. SIMOPS: Drop 1.44"ball for packer setting @ 05:30. 06:15 07:30 1.25 7,455 7,333 COMPZ RPCOM PACK P Set Fl Production Packer(and Lower completion)with top at 7333' and bottom of wearsox at 7455'as per Baker Rep. 07:30 14:30 7.00 7,333 0 COMPZ RPCOM PULD P Lay Down 3.5"Drill Pipe coming out of hole. Lay Down Packer Running tools per Baker Rep. 14:30 16:30 2.00 0 0 COMPZ RPCOM RURD P Pull Wear Ring. Clean and Clear Rig floor. Rig up completion running equipment, change elevators, organize pipe shed for completion running order. 16:30 17:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM for running completion with all involved workers. 17:00 18:00 1.00 0 35 COMPZ RPCOM PUTB P Pick up seal assembly and make up to blast joint. CREW CHANGE 18:00 18:30 0.50 35 35 COMPZ RPCOM SFTY P PJSM for running completion with all involved workers after crew change. 18:30 19:30 1.00 35 15 COMPZ RPCOM PUTB P Pick up second blast joint and make it up to first. Threads galled with 5 threads still showing and less than 2000 Ft/lbs of torque. Break apart and inspect threads. damaged threads on pin end of second blast joint and box end of first blast joint. Lay down joints, contact materials for replacement joints to be sent to machine shop, threaded and sent to rig. 19:30 21:00 1.50 15 15 COMPZ RPCOM RURD P Mobilize HES spooling units to the floor. 21:00 00:00 3.00 15 15 COMPZ RPCOM PUTB T Waiting on Blast joints. Note: Blast joints were hauled to Baker Machine, threads cut for 3 1/2' EUE Mod, and hauled back to rig. 11/05/2014 RIH with Upper 3.5"completion. Corrosion inhibit around packer and set packer. Losses for the day—90 bbls 00:00 01:30 1.50 15 15 COMPZ RPCOM PUTB T Waiting on new Blast Joints. 01:30 21:00 19.50 15 7,331 COMPZ RPCOM PUTB P New blast joints made up with no issues. Make up CMU Sliding sleeve, Baker FHL packer assembly, and continue RIH with completion as per detail with GLM's. 21:00 21:30 0.50 7,331 7,331 COMPZ RPCOM RURD P Pull air slrips. Pull stripping rubber. R/U circulating hoses. Page 19 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 7,331 7,331 COMPZ RPCOM HOSO P Roll pumps to observe seal going into SBE, 1 bpm @ 150 psi. Fully locate. Measure for 1'space out. Up Wt=93k; Dn Wt=76k 22:00 22:30 0.50 7,331 7,331 COMPZ RPCOM CRIH P Circulate 20.5 bbls Corrosion Inhibited 10.2 ppg Brine. Chase with 61 bbls of 10.2 ppg Brine. 3 bpm @ 250 psi. 22:30 00:00 1.50 7,331 7,342 COMPZ RPCOM PACK P Drop Ball and Rod. Make up connection and locate string with 1' space out. Once ball on seat, pressure up to set packer observe good indication of set at—1800 psi. Hold 3000 psi for 5 minutes. 11/06/2014 Shear out, space out, hang off completion. Test tubing/IA. Shear SOV. Test Orbit valve. Pump corrosion inhibited brine. Set TWC. Nipple Down BOP. Nipple Up Tree. Freeze protect. 00:00 02:00 2.00 7,342 7,101 COMPZ RPCOM PRTS P Pressure test IA/Packer to 2500 psi for 15 minutes. Good test. Sensator malfunctioned during test. 0 psi lost over 15 minutes witnessed by CPAI Edward Oglesby, NAD David Guess, BH Bruce Stephens.After good pressure test,with 2700 PSI on the Tbg, Shear Seals from PBR at 8K over weight. Fully locate in PBR and measure 7'space out. Up Wt=89k; Dn Wt=73k 02:00 03:30 1.50 7,101 7,093 COMPZ RPCOM HOSO P Lay down 2 joints. Space out is 7.70'. Pick-up 2 space out pups: 6.21', 6.22'. Put space out pups under joint 219. Make up Hanger, control lines, and landing joint. Make up circulating equipment on landing joint. Roll pumps and observe seals enter PBR. Land Hanger and RILDS. Clamps run: 143 full clamps and 7 half clamps used in completion. 03:30 05:30 2.00 7,093 0 COMPZ RPCOM PRTS P Pressure test tubing to 2500 psi. Bleed to 1500 psi. Pressure test IA to 2500 psi. Charted. Shear SOV and check flow both ways. 05:30 07:00 1.50 0 0 COMPZ RPCOM PRTS P Function check Orbit valve per BH Rep. Pressure check from above and below to 3000 psi. Good test, charted. Open valve and confirm open flow path. 3 bpm @ 384 psi. 07:00 08:00 1.00 0 0 COMPZ RPCOM CRIH P Pump 190 bbls Corrosion Inhibited 10.2 ppg Brine down IA taking returns out tubing. 08:00 08:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor well. STATIC 08:30 10:00 1.50 0 0 COMPZ RPCOM RURD P Blow Down and Rig Down circulation equipment. Lay Down landing Joint. Rig Down power tongs and control line spools and equipment. 10:00 11:00 1.00 0 0 COMPZ WHDBO MPSP P Set TWC and test to 1000 psi from below for 10 min. Good test. Page 20 of 21 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 0 0 COMPZ WHDBO SVRG P Clean under rotary table and pipe racks with steam in preparation for rig move. 12:30 14:30 2.00 0 0 COMPZ WHDBO NUND P Nipple Down BOPE. Release air boot, pull riser, and turnbuckles. pull control lines through stack. Stand back BOP stack on stump and secure. 14:30 17:15 2.75 0 0 COMPZ WHDBO NUND P Nipple Up tree. Remove DSA, clean around hanger and TWC valve. SIMOPS: Cameron, Halliburton and Baker Hughes hands work on control lines. 17:15 17:30 0.25 0 0 COMPZ WHDBO PRTS P Pressure test tubing head adapter. 250/5000 psi. Good test. 17:30 19:30 2.00 0 0 COMPZ WHDBO NUND P Install Manifold for Orbit control valves on tree.CPAI 1H Drill Site Operator confirms tree orientation. 19:30 21:30 2.00 0 0 COMPZ WHDBO PRTS P Pressure Test tree 250/5000 psi for 5 min. Good test. 21:30 21:45 0.25 0 0 COMPZ WHDBO SFTY P PJSM with all hands involved for pumping freeze protect. 21:45 00:00 2.25 0 0 COMPZ WHDBO FRZP P Pump 70 bbls freeze protect Diesel down IA taking returns through tubing. 70-bbls pumped, 70 bbls returned. Set jumper hoses for U-Tube and allow to U-tube. 11/07/2014 Install"H" BPV. RDMO. Final pressures: OA=20 psi; IA=300 psi; Tbg =300 psi RIG RELEASED @ 04:00 00:00 00:30 0.50 10 0 COMPZ WHDBO FRZP P Continue to U-Tube Freeze Protect. 00:30 01:30 1.00 0 0 COMPZ WHDBO RURD P Rig Down U-Tube lines and blow down to Cuttings tank. Clean pits and prepare rig and pits for move. Disconnect interconnects. 01:30 03:00 1.50 0 0 COMPZ WHDBO MPSP P Lubricate in"H" BPV. 03:00 04:00 1.00 0 0 DEMOB MOVE RURD P Take off auxiliary Annulus valve. put on gauges on tree and wellhead. Blow down all connections. Complete cleaning pits and cutting tank. Final pressures: OA:20 psi; IA= 300 psi ; Tbg =300 psi. RIG RELEASED @ 04:00 Page 21 of 21 1 H-04 WELL WORK SUMMAR` DATE SUMMARY PRE-RIG WELL WORK 9/16/2014 STAGE EQUIPMENT UNABLE TO PERFORM WELL WORK DO TO DSO CHANGE OUT. LRS MIT IA TO 2500 (PASS). IN PROGRESS. 9/17/2014 BRUSH n' FLUSH TBG TO PATCH @ 6912' RKB, CLOSURE TEST ON SSSV CONFIRMED VLV FUNCTIONING, PULLED UPPER ER PATCH ASSEMBLY © 6912'-6952' RKB. IN PROGRESS. 9/18/2014 LOCKED OPEN TRDP-1A-ENC @ 1797 RKB; PULLED DV FROM PROD MANDREL © 7059' RKB; ATTEMPT TO PULL C-SAND KB STRADDLE PATCH @ 7257' RKB. IN PROGRESS. 9/19/2014 (PRE-RWO) : FT ALL LDS (ALL GOOD EXCEPT OC LDS @ 2 0 CLOCK IS SEIZED), POT-OC (PASSED), PPPOT-OC (PASSED), POT-IC (PASSED), PPPOT- IC (UNABLE TO TEST), POT-T (PASSED), PPPOT-T (PASSED), MIT-OA(PASSED)TO 1800 PSI. 9/20/2014 PULLED C-SAND KB STRADDLE PATCH © 7257' RKB; ATTEMPT TO PULL BAKER 35 KB STRADDLE PACKER PATCH © 7358' RKB. IN PROGRESS. 9/21/2014 FISH ER ELEMENT FROM FN OF PATCH © 7358' RKB; PULLED UPPER SECTION OF KB STRADDLE @ 7358' RKB (SNAP LATCH HAS MODERATE FLOW CUT & COLLETS ARE FLOW CUT OFF (1"W X 5.5" L X .125"THICK); ATTEMPT TO PULL LOWER SECTION OF STRADDLE @ 9/22/2014 ATTEMPT TO PULL LOWER KB STRADDLE @ 7353' RKB ER (PT SLIPPING OUT OF FN AFTER 30 MIN. OF JARRING/APPEARS FN IS DAMAGED); SET BAKER RELEASABLE SPEAR IN PATCH & JARRED UP FOR 1.25 HOURS W/ NO MOVEMENT. IN PROGRESS. 9/23/2014 JARRED UP ON LOWER KB STRADDLE PATCH @ 7353' RKB FOR 4 HOURS (NO MOVEMENT); PULLED DV @ 6958' RKB. IN PROGRESS. 9/24/2014 JARRED UP ON LOWER KB STRADDLE PATCH © 7353' RKB FOR 1 HOUR W/NO MOVEMENT; PULLED BAKER RELEASABLE SPEAR (SPEAR MISSING 3 COLLATES), ATTEMPT TO RECOVER W/MAGNET(NO SUCCESS). SET 3 1/2 BAIT SUB & BOWEN 2.33" CENTER SPEAR IN KB PATCH © SAME; JARRED UP ON PATCH FOR 40 MIN W/ NO MOVEMENT. READY FOR CTU PENDING PROCEDURE. IN PROGRESS. 9/28/2014 RIH AND LATCH FISH. HIT 25 JAR LICKS BUT DOES NOT COME FREE. PUMP OFF FISH AND POOH. *JOB IN PROGRESS* 9/29/2014 RIH WITH WFT FISHING BHA, 14 JAR LICKS JARS STOPPED WORKING, POOH, PUT NEW SET OF JARS ON, RBIH, JARRED FOR 14 LICKS AND SLIPPED OUT OF FISH NECK. WAS NOT ABLE TO RE LATCH INTO FISH, POOH RIG DOWN. ****TURN OVER TO SLICK LINE**** 10/2/2014 CONFIRMED INTEGRITY OF BAIT SUB FISHNECK © 7326' SLM. JARRED ON PATCH FOR 1 HOUR WITH NO MOVEMENT. MEASURED BHP © 5909' RKB: 2877 PSI. DRIFTED TBG WITH 2.78" DUMMY WRP TO 7326' SLM. JOB SUSPENDED. 10/5/2014 FIRED 8' STRINGSHOT FROM 7274'-7282' RKB. JOB IN PROGRESS. 10/6/2014 UNABLE TO PASS GLM AT 6958' RKB WITH SRINGSHOT. JOB POSTPONED. NOTE:STRINGSHOT RETURNED TO SURFACE MISSING 1' OF DETCORD. 10/13/2014 UNABLE TO MAKE IT PASSED ST#8 © 6958' RKB W/STRING SHOT BRUSH SHOT INTERVAL 6950'-7000' RKB. CHEM CUT TBG @ 7278' RKB, ** HOLE IN CHEMICAL TUBE, SEVERING HEAD PISTON WAS PUSHED DOWN INTO BULLNOSE INDICATING CHEMICAL CAME OUT SEVERING HEAD, BUT UNKNOWN IF ENOUGH TO CUT THE TBG, LOG OVER CUT W/CCL, SHOWED CCL SHIFT @ CUT DEPTH, INDICATING TBG IS CUT** IN PROGRESS 10/14/2014 CHEM CUT TBG @ 6978' RKB. READY FOR BPV. RECEIVED DEC 10 2014 AOGCC Imas ~ject Well History File' Cover .ge XHVZE This page identifies those items that were not scanned during the initial prodUction scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. [_(~o~- ~_ ~ ~_ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other. No/Type [] Poor Quality Originals: [] Other: NOTES: OVERSIZED (Scannable) ru Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL VIAR~ '_OWELL DATE: . Isl Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: Scanning Preparation ~ x 30 = q(~ + · BY: BEVERLY BREN VINCENT SHERYL~LOWELL Isl Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,.. Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ' ~ YES (~G ~ COM~E~ AT ~IS ~ UN~ S~C~ A~ENT~N ~ RE~ED ~ ~ ~BN~AL PAGE ~S~ ~E TO ~,~Y~ ~ C~ "~S) /~~ YES JNO NO RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd . ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1 H-04 Run Date: 6/29/2009 August 28, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1H-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20770-00 ~ ' ' ~. d ~ ~ ~w ur '~ .?.., - ~ - - *~ ~-~ ~` PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.b arreto@halliburton. com ~~~ ,~~ t~ ~ ~~ ~- Date: a ,' ~~~ ~~~ ~`9 S igned: ~ ~;;~~~ %~ ~ g ~- ~~ ~.u ,~> ~ ~ . ~~ ~~.~~~ ~. STATE OF ALASKA '~, , ' °<~. ~ ~4 ;~`; ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION3~~~"~ '~" ~ ~ ~ `~ '~ ~~~~~'~"~`~'~~~~~~ 1. Operations Performed: Abandon ^ Repair Weil ~• Plug Perforations ~ Stimulate ~ Other ' J~ S2f'Patch Alter Casing ^ Pull Tubing ^ PerForate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~aveta~~ne;nt ^ Explcratory ^ 182-103/ • 3. Address: Stratigraphic ^ Service Q• 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20770-00 • 7. KB Elevation (ft): 9. Well Name and Numbet: RKB 85' ~ 1 H-04 . 8. Property Designation: 10. FieldlPool(s); ADL 25639' ALK 464 Kuparuk River Field / Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 8086`• feet true verticai 7082' ' feet P(ugs {measured; Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural - - CoNDUCTOR 110` 'In" 110' 110' SURFACE 2106` 10-3/4" 2191' 2191' PRODUCTION 798~' 7" 8071' 7070' . °t ..'~~ ..., . . !~~i~~s Pertoration depth: Measured depth: 7180-7242, 7291-7324, 7482-7486, 7496-7520 true vertical depth: 632Q-6373, 64146442, 6575-6579, 6587-6607 Tubing (size, grade, and measured depth) 3 9!2", 2 7;8", d-55, J-55, 7373", 7408" MC?. Weafherford 1.55" ID Patch fram 6912' - 6956' i~P!-~ Packers & SSSV (type & measured depth) 8rovdn'HB-1' PI4fZ, Brntwn'HB-1' PKR, Bro~rrn '1 B' PKR PICR = 7022' l~Ci, 7282' MC3, 7384` M[3 Camco TRDP-1 A-NC SSSV = 1798' MD 12. Stimulation or cement squeeze summary: ~1JCLt~ ~G.S~" o~c~1~.~~i`~c.~ Intervals treated (measured) Alot Applicabte q~ ~ ~ ~~ ~~~~ -- \ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA IVA NA NA -VA Subsequer~t to operation NA NA NA fUA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Explorafory ^ Development ^ Service ~~ Daily Report of Well Operations 7t 16. Well Status after 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 ff C.O. Exempt: 309-231 contact Brent Rogers/Martin Walters Printed Name Martin Walters Tit(e Problem Wells Supervisor ~~~~~~~ Phone: 659-7224 Date 08/17/09 Signature `~~ i~ ~ Pre ared b Martin Walters 659-7229 ~ ~+ ~~~. 5~" ~~ `~ L00~ a ~~ ~~ ~~ a%. ~~3 Form 10-404 Revised 04/2006 ~r"d1~f~~mit Original Only • 1 H-04 ~ DESCRtPTiON OF WORK COMPLETED SUMMARY Date Event Summary 7/15/20 SET WEATHERFORD PACK BASED ON CORRELATION READY FOR SLICKLINE. 7/30/2009 8/14/2009 CMIT ON LOWER ER PKR @ 6953' RKB.SET WEATHERFORD JJ TIEBACK PATCH ASSY @ 6953' RKB OAL=31' 8" CMIT TIEBACK ASSY.SET UPPER ER PKR PATCH ASSY OAL=10' 9" TOP 6912' RKB.DRAWDOWN IA. ' 1 H-04 State Witnessed (Bob Noble) MITIA- passed; Initial T/I/0= 1950/550/380; Pressured up', IA to 2680psi. with 2.2 bbls. of diesel T/I/0= 1950/2680/480; 15min. reading T/I/0= 1950/2600/480; 30min. reading T/I/0= 1950/2600/480; Bled down IA fluid 5min. Final T/I/0= 1950/125/340 ~ MEMORANDUM TO: Jim Regg ~~~ ~'1~t6~~ P.I. Supervisor FxoM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 17, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 H-04 ~rn~uic xTV urnT ~ x-oa Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~.~ Comm Well Name: KUPARUK RIV LTNIT 1H-04 API Well Number: 50-029-20770-00-00 Insp Num: mitRCN090815095538 Permit Number: 182-103-0 ,,. Rel Insp Num: Inspector Name: Bob Nobie Inspection Date: 8~14/2009 Packer Depth Pretest Initi~l 15 Min. 30 Min. 45 Min. 60 Min. ~,e~~ ix-oa Type Inj. W TVD biss Iq sso z6so ,~ z6oo 2600 ~ P.T.D 1821030 TypeTest SPT i Test psi ~ 2680 QA 380 480 480 480 Interval I~T^I- p/F P " Tubing ~9so t9so i9so t9so Notes' MITIA post tubing patch h1`~~ ~ re jc~ ~'s~. P~S~~ ~~4~~; ~? "t(i ~. ~ +,a, V~~t ~°~ ~1;, r _ _ ~ ;~ Monday, August 17, 2009 Page 1 of I ~ `i~~'y,~~ T,~~' ~'P~~~i'Ijj~~Il"l':I~\_'-{, T~o %laska ~il and ~as ~~nserva~i~n ~~r~rs±a 1~t~n.: ~hris~in~ i~~hnk~~ 33~ ~zl~s~ 7i~ Aii~,~u~, ~uiiy ~ ~~ ~n~horag~, ~lasAc~ ~95~~ RE: Packer Setting Record: 1 H-04 ~~~1~ 77, ~~09 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 l i~-04 Digital Data in LAS format 50-029-20770-00 ~~~ 1 ~~ - io3 ~~3 ~~s ~ `e, ; , r ~~ ~il~!e` . '}~C '~~ ~S~~i+ '=itJ 4. _ .:a ~,T ~;: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton. com Date: ~ ~ :/ Signed: • ,,-,., ' . .~~ • ~~I~".L~ L~~~P~~lT~l/I~'?'1~~~. '~'~~ ~las~ca ~il and ~as ~~~serva~ti~r~ ~Corn~. ~~~n.: Christin~ 1~/I~hnk~n 333 ~i~I~s~ 7~h ~q~~~u~, ~~a~~s 1~0~ ~~ch~~ag~, ~laskca ~9~~~ RE: Leak Detection Log 1I-I-04 .~~~y 2~~9 ~.0~9 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 ~I-04 Digital Data in LAS format 1 CD Rom 50-029-20770-00 a. 'ti. a;~'~' t=;,t ~.a :~ ~~ ~)(,?`; 'U~ C l`~~ ' 103 ?~s3°~ I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton. com ~ I )atc: - - - Signed: ~ ~ , ~. ~ ~'3 I ~t 1' 4 t~ t Y~ ~ ¢ ~ '~ '. '~ ~'~1" ~`~ r~ k l r f ~~ ~` 1 ~ \ ~~ E r ~ Y v ~ ~ ~ ° ~ ~~ ~~ ~ ~ ~ ~ ~ p y~~ ~ ~ :~' ~ L P~ %~ ~ ~ ~ ~ ~ ~t ~~~ ` ~ k ~ q ~ " F tc ~ ~ ~ .. ~ ~,z-~-F .n k k . C r ,~ . ,~ ~ ~.~. _€ _ ~S~ ~~ ~ ~ COI~TSERQA'1`I011T COMAIISSIOI~T Mr. Brent Rogers Problem Well Supervisor ConocoPhilli s Alaska Inc. ~' ~ ~h ~ P ~ ~'c~~~a~~~~~+ ~ `~J'w ~ , ~, ;i~ P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 H-04 Sundry Number: 309-231 Dear Mr. Rogers: • SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~O~ ` ~' t~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Comrnission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such furth~r time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Corrunission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ;~ Chair DATED this ~ day of July, 2009 Encl. • ~ ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2009 Mr. Jim Regg Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Regg, ~ ~.EC~o~~r~- ~~~ a ~ ~~~~ ~laska Oil $~ Gas Cot~s, G~mmissiar- Anchorage Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1H-04 (PTD 182-103). The request is for approval to patch a tubing leak above the top packer. Please call Martin Walters or myself at 659-7224 or M J Loveland / Perry Klein at 659- 7043 if you have any questions. Sincerely, ~~~ /.~ Brent Rogers Problem Well Supervisor Attachments , ~1~ ~~9 , .~.~ • ~~~..~~~~~ STATE OF ALASKA ,JUL ~ ~ ~OQ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~r~ APPLICATION FOR SUNDRY APPROVA~~Ska Qii & Gas Cons. Commissi~n 2O AAC 25.2HO A_, _ L___ __ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ~ Other Alter casing ^ Repair well ~/ ~ Plug Pertorations ^ Stimulate ^ Time Extension ~ ~ti~ ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ ~~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. oeve~opment ~ Exploratory ^ 182-103 - 3. Address: Stratigraphic ~ Service ~, 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20770-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ~ 1 H-04 , 9. Property Designation: ADL 25639 ~ ALK 464 10. KB Elevation (ft): RKB 85' - 11. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8086' - 7082' - Casing Length Size MD ND Burst Collapse CONDUCTOR 110' 16" 110' 910' SURFACE 2106' 10-3/4" 2191' 2191' PRODUCTION ~gg6' 7" 8071' 7069' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7180-7242, 7291-7324, 7482-7486, 7496-7520 6320-6373, 6414-6442, 6575-6579, 6587-6607 3 1/2~~, 2 7~8~~ K-55, K-55 7373~~, 7408~~ Packers and SSSV Type: Packers and SSSV MD (ft) Brown'HB-1' PKR, Brown'HB-1' PKR, Brown'16' PKR PKR = 7022' MD, 7282' MD, 7384' MD Camco TRDP-IA-NC SSSV = 1798' MD 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~^' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat July 8, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ~^ ' WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers/Martin Walters Printed Name Brent Ro @I'S Title: Problem Well Supervisor Signature ~ Phone 659-7224 Date 07/02/09 Commission Use Onl '~\ ~~ o~.~;~ S`~ `~ /` -p`1 '1~"( Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~,,,~(~~ v APPROVED BY ~ ~ 7 / ~ Approved by: MISSIONER THE COMMISSION Date: ~ Form 10-403 Revised 06/2006 v~ ~ ~7 I I V H L Submit in Duplicate ~l~ • • ConocoPhillips Alaska, Inc. Kuparuk Well 1H-04 (PTD 182-103) SUNDRY NOTICE 10-403 TUBING REPAIR 07/02/09 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1 H-04 (PTD 182-103) with a tubing patch. On May 18, 2009, the AOGCC was notified of TxIA communication due to a failed MITIA. Subsequent diagnostics have identified a tubing to IA leak in the tubing at 6952' MD (7' above GLM #8). The plan is to set a retrievable patch over the mandrel, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 3.5" retrievable patch over gaslift mandrel @ 6959'. 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10-404 post-repair. NSK Problem Well Supervisor • WELL LOG TR4NSM/1TAL o,. PaoAClive D'uynostic SEmices, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 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 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 26-May-09 2] 1 H-04 1 Report / ~ 50-029-20770-00 ~~C /~S2 -~03 /~o~ ~Jl~~ ®3 20i,~3 Signed : Date ~c~ ~i@ ~ 0 C~~. ~~id~:or Print Name: ~~c~'e PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~sanchoraaseCa~memoryloo.com WEBSITE : w~vu.memorVlocs.com C:\Documeents and Seltings\Owner\Desktop\Tiansmit_Conoco.docac IVlemory Multi-Finger GaliRer Log Results. summary Company: GonocoPhillips Alaska, inc. Well: 1H-04 Log Date: May 26, 2009 Field: Kuparuk Log No.: 10555 State: Alaska Run No.: 2 API No.: 50-029-20770-00 Pipet Desc.: 3.5" 9.21b. J-55 BTC AB-MOD Top Log Intvll.: Surface Pipet Use: Tubing Sot. Log Intuit.: 7,252 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS This caliper data is tied into the top of Injection Mandre/10 ~ T,130' (Driiier's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged is in good condition, with the exception of a 28% wall penetration recorded at an isolated pit in joint 233 (7,225'). No significant areas o#cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a PDS caliper has been run in this well and the 3.5" tubing has been logged. A comparison of the current and previous tog (June 5, 2007) indicates an increase in corrosive damage, appearing as isolated pitting from 3,200' to -5,500', during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRA710NS Isolated pitting (28%) J#. 233(.c0' 7,225 Ft. (MD) No other significant wall penetrations (> 19°l0) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No s~nificant I.D. restrictions are recorded throughout the tubing logged. w' Field Engineer: G. Etherton Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staf=ford, TX 77497 Phane: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~amemoryfog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (9C7) 659-2314 vSca c~ -do3 ~~6~d ~ ~ Maximum Recorded Penetration ~, ~ Comparison To Previous Well: 1 H-04 Survey Date: May 26, 2009 Field: Kuparuk Prev. Date: June 5, 2007 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 218370 Country: USA Tubing: 3.5" 9.2 Ib 1-55 BTC AB-MOD C~vP rlav Max. R ec. Pen. (mils) 0 SO 10 0 15 0 20 0 25 0 0.1 7 17 27 37 47 57 66 76 85 95 105 `v E 115 Z 125 c 'o ^ 134 144 154 163 173 182 192 201 210 219 227 233 ^ M ay 26, 2 009 ^ June 5, 2007 Difference Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (16.6' - 7233.0') Well: 1 H-04 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 26, 2009 ^ Ap prox. T ool De viation ^ Ap prox. B orehol e Profile 45 765 1519 2293 GLM 1 3056 p Y 3808 s ~. GLM 2 v 4575 GLM 3 5349 Gl_M 4 GLM 5 6114 GLM 6 GLM 7 GLM 8 6895 lla~ 1 234 7233 0 50 100 Da mage P rofile ( % wall) /Tool Deviatio n (degr ees) Bottom of Survey = 234 1 25 50 75 100 `v I_ Z 125 'i5 150 200 PDS Report Overview ~ ~µ Body Region Analysis Well: 1 H-04 Survey Date: May 26, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.2 ppf )-55_ BTC AB-MOD 2 992 ins 3 5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body tsr~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of 'oints anal sed total = 239 pene. 37 176 25 1 0 0 loss 238 1 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 4 4 0 0 0 0 Damage Profile (% wall) ~ penetration body ~:: metal loss body 0 50 100 GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 INJ 9&10 Bottom of Survey = 234 Analysis Overview page 2 PDS REPORT JOINT TABU Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: CATION SHEET 1H-04 Kuparuk ConocoPhillips Alaska, Inc USA May 26, 2009 Joint No. Jt. Depth (Ft.) P~~n. t Ils~~t (Ins.) Pen. Body (Ins.) Pc~n. °/, Metal I os~ °'~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 17 U 0 0 ~ t) 2.96 UP 21 U .01 5 1 .93 PUP 3 U .01 ' u 2.96 PUP . .4 35 a 0.01 2 I 2.93 PU 1 45 t) 0.01 I 2.95 2 76 U 0.01 a 1 2.96 3 106 t) 0.01 I 2.95 4 135 ~ ~ 0.02 t3 i ~ 2.94 5 166 ~? 0. 1 ' 1 2.95 6 97 t) 0.01 I .96 7 228 a 0.01 ~ I .94 8 258 U 0.00 1 U .94 288 t) 0.01 (, 1 2.96 10 319 I) .00 I t 3 11 349 t) 0.01 ' 1 2.96 1 381 U 0. 1 2 I .93 13 410 U .00 1 u 2.9 14 440 U 0.01 i 1 .9 1 472 t) 0.00 I I 2.98 16 501 U 0.01 ~' 1 2.96 17 530 U 0.01 ~> t? .96 18 562 a 0.00 I I 2.95 1 591 t) 0.00 1 u .93 20 620 U 0.00 ~ I 2.95 65 (? 01 ' 1 2. 3 22 680 t 1 0.00 1 I 2.94 23 708 t) 0.01 2 1 .94 24 73 O 0.00 I t l 2.93 25 765 a 0.0 _' a 2.9 26 795 ll 0.00 I I 2.94 27 824 U 0 1 Z U .94 28 855 U 0.01 2 U 2.95 29 885 U 0.01 5 t ~ 96 30 916 U 0.01 2 I 2.93 31 ll 0.01 4 I .96 32 978 t~ 0.01 ~ ~ 2.95 33 1008 a 0.01 2 u .94 34 1037 (~ 0.00 1 (~ 2.93 35 1 68 u 0 03 12 t 2.9 36 1098 a 0.00 1 t) 2.92 37 1127 U 0.01 ' U .95 38 1159 U 0.00 1 1 2.95 9 1188 t) 0.00 1 t ~ .95 40 1218 t) 0.01 4 I 2.94 41 1249 ~) 0.01 4 1 2.9 42 1279 a 0.01 2 I 2.96 43 1311 ~ ~ 0.00 1 I 2.94 44 1341 t) 0.00 1 I 2.94 5 1 70 l) 0. 1 2 1 .94 46 1399 t) 0.01 2 I 2.93 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 H-04 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 26, 2009 Joint No. Jt. Depth (Ft.) I'e~n. Upset Ilna.) Pen. Body (Ins.) I'cn. `~~~ ~IE~t~il I ~x, ,~- Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1429 tl ,00 I tt 2.93 48 1459 a 0.01 ~' I 2. 3 49 1489 a 0. 1 ? ~ 2.95 50 1519 a 0.01 ~' 1 2.96 51 1551 t t 0.01 _ t t 2 96 52 1583 t t 0.01 ? I 2.93 53 1613 t ~ 0. 1 4 I 2.93 54 144 t ~ 0.03 1 3 t ~ 2.96 55 1676 t ~ 0.02 £3 ~. ~ 2.94 56 1705 tt 0.01 -' I 2.93 57 1736 tt 0.01 ~ !~ 2.92 57.1 1767 t 1 0 l ~ t ~ 2.81 C mco TRD -1 A-NC S SV 58 1779 l~ 0.02 £i tt 2.94 59 1807 t ~ 0.01 _' I 2.93 6D 1837 tt 0.03 1tl a 2.92 61 1866 (1 0. 2 9 t! 2.93 62 1897 a 0.02 ~> I 2.93 63 1927 tt 0.01 :~ tt 2 9 64 1959 U 0.01 4 1 2.91 65 1989 t 1 0.01 ' 1 2.93 66 2018 t~ 0.01 a 1 2.95 67 2050 It 0. 1 ? I 2.93 68 2080 U 0.01 b i ~ 2.93 69 2110 t ~ 0.02 ~~ ~ 2.93 70 141 t) 0. `) 1 2.9 71 2171 a 0.00 ~ ~ 2.92 72 2202 l~ 0.01 5 I 2.92 73 2232 tl 0.01 2 t~ 2.93 74 2261 U 0.02 £i I 2.94 75 2293 11 0.01 5 u 2.95 76 232 U 0.02 8 1 2.92 77 2351 tt 0.02 8 I 2.93 78 2380 t~ 0.01 4 1 2.92 79 2411 U 0.01 (i 1 2.96 80 2440 l ~ 0.01 2 t t 2.90 81 2469 t) 0.01 4 I 2.92 81.1 2498 U 0 U u N A GLM 1 tch ~ 9:00 82 2505 t~ 0.02 6 U 2.91 83 2535 a .03 13 1 2.9 84 2564 t~ 0.02 9 1 2.93 85 2593 t t 0.00 1 U .93 86 2622 t~ 0.01 4 I 2.97 87 2653 a 0.01 6 tt 2.92 88 2683 t t 0.03 1 t) I 2.95 89 2714 a 0.02 ~) 1 2.95 90 2745 a 0.01 1 1 2.93 91 2777 ct 0.00 1 1 2.95 92 2809 ~~ 0.02 8 1 2.94 93 284 t t 0.01 a U 2.93 94 2873 tt 0.01 ? t> 2.93 _ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABU Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: CATION SHEET 1H-04 Kuparuk ConocoPhillips Alaska, Inc USA May 26, 2009 Joint No. )t. Depth (Ft.) P~~n. llpsc~t Ilns.l Pen. Body (Ins.) I'cn. %, ~tct~~l Loss 44, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 95 903 t) 0.01 3 I 2.93 6 2936 U .O1 > ~ ~ .91 97 2967 tJ 0.01 ~ iJ 2.96 98 2997 t> 0.01 (~ I 5 99 30 7 U 0.01 ~ t) .91 100 3 56 tl 0.01 ~' iJ 2.93 101 3085 U .01 Z I 2.9 102 311 c. 0.01 i. 2.95 103 3142 ~) 0.00 1 i J 2.91 1 4 72 t) 0.02 ti i1 2.94 105 3200 ~) 0.02 ~~ i J 2.90 Lt. a osits. 106 3231 U 0.03 1) U 2.91 107 3260 t) 0.0 _' I 2.9 10 32$9 tJ 0.03 11 I 2.92 109 3319 i~ 0.01 ~' I 2.95 110 3351 U 0.01 4 I 2.92 111 3381 a 0.01 l i ~ 2.96 112 3412 t) 0.01 2 t~ .92 113 2 u 0. 1 4 I .93 11 3473 lJ 0.01 4 ~ ~ 2. 6 115 3503 l) 0.00 1 ! ~ 2.93 116 3533 U 0.02 9 I .92 117 3563 n 0.01 ~ tJ 2.92 118 3593 U 0.01 2 I 2.95 6 ) 11 I 9 120 3655 tJ 0.01 ' (J 2.93 1 1 3687 (J 0.01 ~ t J 2.93 122 3717 t) 0.03 1 U 1 2.92 Lt De osits. 123 3 47 t) 0.01 I 2.94 124 3776 t~ 0.03 12 1 2.95 Lt. De osits. 1 5 3808 t) 0.03 1U 1 2.9 126 3838 U 0.00 1 u 2.92 127 3866 O 0.01 ~ U 2.9 128 3895 t) 0.00 1 1 2.96 1 9 3925 t) 0.00 1 I .96 130 3956 tJ 0.02 ~) t 2.94 13 3987 t J 0.0 ~ I 2.92 132 4018 tJ 0.02 ti I 2.93 132.1 4049 t~ 0 0 0 N A G M 2 atch ®10: 0 133 4054 t! 0.02 f3 1 2.90 13 40 5 U 0.03 1 1 i~ 2 92 135 4113 tt 0.03 11 iJ 2.92 136 4144 ti 0.02 9 I 2.86 Lt. De osits. 137 4174 t~ 0.01 5 U 2.93 138 4 02 U 0.02 ~~ I 2.93 139 4233 tJ 0.03 t3 1 2.94 140 4265 i ~ 0.0 ~) i J .91 141 4296 U 0.02 ~) I 2.93 14 4 7 U 0. 3 13 1 2.95 143 4357 ~J 0.00 1 u 2.97 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 H-04 Body Wall: Upset Wall: 0.254 in 0.254 in Field: Company: Kuparuk ConocoPhillips Alaska, Inc. Nominal t.D.: 2.992 in Country: USA Survey Date: May 26, 2009 Joint No. Jt. Depth (Ft.) N~~n. tJtx~~t (Ins.) Pen. Body (Ins.) Pen. %> ~tc~t,~l I cuss `;~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 144 4388 U 0.04 1 ti U 2.90 Isolated ittin . 145 4420 tJ 0.01 4 1 2.93 146 4450 ~) 0.03 1~ tJ 2.89 147 4482 t l 0.02 t ~ 2.94 148 4514 t J 0.03 1 ~ I 2.91 Lt. a osits. 149 4544 U 0.01 Z I 2.92 150 4575 tl 0.05 19 U 2.94 I lated ittin . 151 4607 tJ 0. 2 ~J 1 2.93 152 4637 l1 0.02 8 U 2.91 153 4667 tJ 0.01 ! 1 2.91 154 4699 U 0.04 1' I 2.94 Isolated ittin . 155 4729 (J 0.02 'J I 2.94 156 4762 t t 0.01 ~ ~ ~ 2.95 157 4794 t J 0.01 4 I 2.92 158 4825 U 0.01 2 tJ 2.94 159 4855 U 0.00 1 t 1 2.91 160 4886 t ~ 0.03 13 I 2.91 Lt. De osi ts. 161 4916 U 0.01 4 1 2.93 162 4946 tJ 0.02 ti 1 2.94 163 4977 tJ 0.01 4 u 2.93 163.1 5008 U 0 U tJ N A GLM 3 Latch ~ 5: 0 164 5014 ~~ 0.02 ~J t~ 2.93 165 5045 U 0.01 ? t J 2.92 166 5077 it 0.01 (~ U 2.93 1 7 5107 t1 0.01 4 t) .94 168 5138 t~ 0.01 4 tJ 2.92 169 5170 t ~ 0.02 7 U 2. 170 5197 { 1 0.01 i 1 2.93 171 522 t) 0.02 ~J U 2.89 172 5256 lJ 0.02 9 U 2.90 Lt. De osits. 173 5 87 t1 0.01 2 I 2.96 174 5319 tJ 0.02 ~) 1 2.91 Lt. De osits. 175 5349 U 0.01 2 I 2.92 176 5381 t J 0.01 4 I 2.95 177 5412 i J 0.00 1 i ~ 2.93 177.1 5443 t~ 0 0 tJ N A GLM 4 Latch ®3:30 178 5449 U 0.03 13 U 2.90 t. De sits. 179 5478 tJ 0.01 2 U 2.93 180 5510 t ~ 0.00 1 t ~ .9 181 5539 tJ 0.01 2 I 2.93 182 5571 t J 0.00 1 t J 2.90 183 5601 U 0.02 ~) ~ ~ 2.92 184 5630 U 0.02 9 I 2.91 185 5659 t J 0.03 10 t J 2.90 186 5688 U 0.01 2 U 2.92 187 5718 tt 0.01 2 U 2.91 188 5747 t t 0.00 1 u .92 189 5777 U 0.01 2 tJ 2.90 190 5808 U 0.02 t3 U 2.89 191 5837 t1 0.02 8 tJ 2.92 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: 1 H-04 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: May 26, 2009 Joint No. Jt Depth (Ft.) Pr~n. Upset (Ins.l Pen. Body (Ins.) Pen. °~~> ~1~~t,!I I uss ~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 192 5866 t1 0.01 1 I 2.92 192.1 5898 tt 0 t) u N A GLM 5 Latch ~ 5:30 193 5904 tl 0.01 4 I 2.92 194 5934 t I 0.00 I 1 2.94 195 5965 U 0.01 ~1 U 2.91 96 5995 U 0.01 i I 2.94 197 6025 t? 0.01 I 2.91 198 6052 t 1 0.0 ti U 2.91 199 6082 U 0.01 _' I 2.9 2 0 6114 !I 0.01 -1 t~ 2.92 01 6145 U 0.01 ~' I 2.93 20 6175 l1 0.02 ~~ ~1 2.93 03 6205 U 0.04 1-1 I 2.94 204 6236 t~ 0.02 9 I 2.9 204.1 6269 tl 0 U ~! N A G M 6 Latch ~ 1: 0 205 6275 a 0.0 12 I 2.93 206 6306 U 0.01 4 u 2.92 207 6335 U 0.00 1 tt 2.91 208 6367 t ~ 0.00 I t I 2.92 209 6397 U 0.03 11 1 2.93 10 6428 U 0.03 12 l1 2.90 Lt. De osits. 211 6458 t I 0.01 5 1 2.91 212 6487 U 0.01 ~ 1 2.92 213 6517 0 0.00 1 t I 2.92 214 6548 U 0.01 ' I 2.91 215 6579 tl 0.00 1 I 2.93 216 6611 l1 0.01 1 I .94 217 6641 i ~ 0.00 1 U 2.92 217.1 6673 t_I 0 U tl N A GLM 7 Latch ~ 9:00 218 6679 t~.u7 0.02 9 I 2.94 219 6711 t! 0.00 1 u 2.90 220 6742 tl 0.01 -1 I 2.91 Lt. De osits. 221 6771 tl 0.01 ~ I 2.94 22 6803 U 0.01 2 1 2.93 223 6833 U 0.01 ~ 11 2.87 L De osits. 224 6864 h 0.00 1 1) 2.91 225 6895 U 0.02 9 (I 2.93 226 6927 U 0.01 (~ I 2.91 2 6 1 6957 +t 0 O U N A LM 8 Lat h~ 6: 0 227 6967 a 0.03 I2 I 2.94 22 1 6996 t) 0 t) tl 2.81 Brown SBR 227.2 6999 U 0.03 12 I 2.96 PUP 227.3 7021 U 0 t) U 3.00 Brown'HB-1' Packer 228 7027 ~? 0.01 2 l1 2.94 228.1 7059 t1 0 U tl N A M el 9 Latch ~ 3:00 229 7068 (I 0.02 9 I 2.89 Lt. De osits. 230 7098 it 0.01 4 U .90 230.1 7130 u 0 ll U N A In ection Mandrel 10 Latch ~ 8:00 231 7140 ! i 0.02 9 U .89 232 7171 !? 0.01 ' I 2.97 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABS Pipe: 3.5 in 9.2 ppf J-55 BTC AB-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: CATION SHEET 1H-04 Kuparuk ConocoPhillips Alaska, Inc USA May 26, 2009 Joint Jt. Depth I'~~n. Pen. Nen. :~1c~l,il Min. Damage Profile No. (Ft.) Ul,;~~i Body °/> lu~~ LD. Comments (%wall) UnS.) (Ins.) ~~~~ (Ins.) 0 50 100 233 7203 ~) 0.07 28 ~~ 2.97 Isolated ittin 234 7233 n 0.04 14 I 2.93 _ Penetration Body Metal Loss Body Page 6 PDS Report Cross Sections Well: 1 H-04 Survey Date: May 26, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc, Tool Size: 1.69 Country: USA Iv'o. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf J-55 BTC AB-MOD Anal st: C. Waldro Cross Section for Joint 233 at depth 7225.144 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 °~ Tool deviation = 29 ° Finger 1 Penetration = 0.07 ins Isolated pitting 0.07 ins = 28% Wall penetration HIGH SIDE = UP Cross Sections page 1 ~-~~ KUP 1 H-04 r COnOCOPh116p5 r ; wen Amibut~ "^ax A le s, "'° T D ~ ~a 1D I ~ ,', I, r....L 111 ~ 500292 077000 KUPARUK RIVER UNIT INJ 41.78 4,100.00 8,086.0 C SSSV: TR DP Ip ata Artlo Last WO: ate 12/30/1985 -CM IDl 35.00 9 Re ase e 7/23/7982 Die __- _ _ Amnotatlon DepUl Last Tag: SLM 7,575.0 a 523!2009 Rev Reason: TAG prastwr 5/242009 Cesin Stri s CONWC70RO {{ 9 Caskg (x salp8on Pnl _ PM T QIICI) set Deph (~B) sa 1 IRKeI 6tmrg ro~ f7'tle TLIM { CONDUCT OR 16 15.060 0.0 110.0 110.0 65.00 H~40 ~ SURFACE 10 314 794 9 0 0 2 191.0 2,190.8 45.50 K-55 s4FErv vLV. o, . . , 1,7se PRODUCT ION 7 6.151 0.0 8,071.0 7,069.6 26.00 KS5 SURFACE ! Tubi 5trt 7,191 ~ OD Sat Depttl 4et D1p111 sntlp To~9 tl esad MI Iml (ItKel IRKBI rosnq tiraoe Tap mra ~ASUFr, 2 527 TUBING 3 12 2.992 0.0 7,373.0 6,483.5 9.20 J35 BT CAB-MO . TUBING 2 7/8 2.441 7,373.0 7,408.0 6,513.5 6.50 Jb5 BT C AB-MOD Other In Hole A ll Jew s . Tobin Run S Ratrie+reb Flsh etc. OAS LIFE, oP 4 07o ND ( ) ltectsl Top ma rl oa Camme4a Rut Data p ~ l 1,798 1,797.9 1.05 SAF VLV Cameo DP-IA-NC 12130 11985 2.813 s o2s 2,52 2,526.5 4.84 GAS LIFT CAMCOIKBUd1/DMYB KI// Commern: STA 1 1/121 7 2 .875 4,070 3,8822 41.81 GAS LIFT dKBUd1/DMYB K/!I Comment: TA 2 1/12/ 1992 2.875 ens uFT, s ess 6,025 4,604.7 40.80 GAS LIFT AMCdKBUGtt/DMVB K///ComrrenT STA3 124/ 1992 2.87 . 5,456 4,931.0 40.38 GAS LIFT CAMCdKBUGIi/DMYB K/// Camnent: STA 4 1/12/ 199 2.875 5,909 5,273.3 40.59 GAS UFT AMCdKBUG/1IDMVB ROKE/// Caminnt BROKEN 121/ 1992 2.875 cAS uFT, s.so9 LATCH (121/92) STA 5 6,25 5,560.2 36.88 GAS LIFT CAMCdKBUd1/DMY/B K//ICam~ent: A6 1/12/ 1992 2.875 6,677 5,891.9 32.81 GAS LIFT CAMCdKBUGl1/DMYIB KI//Commem: STA7 1/411 992 2.875 cASLIFT, 6 959 131 4 6 31 56 GASU MERLA/TPDX/7.5JDMYl RM/I/CamnentSTAB &14! 1992 2.875 6,275 , . , . 6,999 6,165.5 31.40 SBR Brown 12!30 !1985 2.813 oh 7,022 6,184.6 30.44 PACKER Brown'HB-1' PACKER 12/30 11985 3.000 s is 7,059 6,216.6 30.70 INJECTION MERIAlTPDXl1.6/DMV NV//Cmanent: A9 17/12 17995 2.8 5 7,130 6,277.5 31.22 INJECTION MERLA/TPDX/1.5/D / RNV// Comment: STA 10 12/7? J1995 2.875 cAS LIFT 7,257 6,385.7 32.47 PATCH ONE-RUN KB STRADDL E COMPLETION PATCH set 3/20 2008 1.550 s.ss9 3202008 7,264 6,391. 32.47 1NJE TION MERLA/TPDXII.5IDMYA 2M/p Comment: ENDE KG 7/131 200 .875 STA 11 SIW. 6999 7,282 6.406.8 32.49 PACK Bmwn'HB-1'PACKER 1 011 6 3.000 7,377 6,481.8 32.56 NIPPLE Ohs BPL Pored Nipple 999 2.750 vACrcER 7 ox2 7,371 6,481.8 32.56 SLEEVE-C Ran 2.75' O~ OPLN ISO Sleeve set an 12 ) 12 7 2.250 , , - - 7,384 6,492.8 .57 PACKER Brorm'18' PACKER 12/3 Ut1985 3.000 7.397 6,503.8 32.58 NIPPLE Camco'D' Nipple. NO GO 17/3 011985 2.250 IN,ECI'ION, 7 406 511 9 6 33 42 SOS Brown 12/3 0/19 2.441 7.059 . . . . 7,407 6,512.7 33.41 TTL El1a1D TTL ~ 7392' PER IPRRF 1?lJ N7985 2441 IN.ECTION PaAore tjons b $IOtf . i.13o sna Top ITVD) Dm4I1VW Der1s TaP tom/ ~m I~el IDILG Irene Date I+h- t~aanle4 t IPERF, 7,180 7,242 6,320 .2 6,373.0 C 4, G3, 1H 12/30!19 85 4.0 IPERF 7.1eo-i 24z 7,291 7,324 6,474 4 6.442.2 C -1, UNIT B, 12!3011985 12.0 IP RF 1 H-04 7,482 7,486 6,575 .3 6,576.6 A -6, 1H-04 127 19 5 12.0 IPERF IN.~ECnoN. 7,496 7,520 6,58 7.0 6,607.1 A i, 1H-01 12130119 85 12.0 IPERF 7.284 PATCH,? 157 PACKER.i187 IPERF, 7291-7,324 NIPPLE. 7,371 SLEEVEL. 7 371 PACI'.ER, 7,384 NIPPLE. 1,397 SOS, 7106 ~ TTL. 7 d07 IPERF, 7,462-7,486 IPERF, T e96->szo i PROWCTION, 6,071 TD.8088 1H-04 (PTD 182-103) Report of~ed MITIA Regg, James B (DOA) • Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, May 18, 2009 10:32 AM ~~~ ~~~-4~2~%~ To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: NSK Problem Well Supv Subject: 1 H-04 (PTD 182-103) Report of failed MITIA Attachments: 1 H-04 90 day TIO piot.jpg; 1 H-04 schematic.pdf Jim, Tom Kuparuk water injector 1 H-04 (PTD 182-103) failed a diagnostic MITIA on 05/17/09 and has been added to the monthly MIT report. The TIO prior to the test was 1700/21~7 (~( .~e well had been previously shut in since 04/13/08 and was recentiy just brought on injection on 05/14/09. Following the failed MITIA the well was shut in and freeze protected. The plan forward will be to troubleshoot the leak and repair if possibie. The appropriate paperwork will be submitted prior to the repair if needed. Attached is a schematic and 90 day TIO plot. ~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 e a' ~ t~~.j~3 ~~. »~,{i;},..m~ a~, ~ y { ~ . ~. ~~~ °~ «1 H-04 90 day TIO plot.jpg» «1 H-04 schematic.pdf» 8/24/2009 KRU 1 H-04 PTD 182-103 5/18/2009 TIO Pressures • • ~ ~ ; G~~r~~~P~~I1~~~ A~~s~a, 1n~. KRU 1 H-04 ~ ~ ~^~ r ~ `5•'r ,~ ~~ :l~ 7't M. . ~IA ` _ . ~ -~ ~~ i t1~ r ~ ,~a `_ ti, n, '~=` „ J F =r ~_) t N ~ ,~" ~ tir ~ ~.~`6, API. 500292077000 Well T e: INJ An le TS: 32 de 7179 SSSV T e: TRDP Ori Com letion: 7/23/1982 An le TD: 33 de 8086 SSSV Annular Fluid: Last W/O: 12/30/1985 Rev Reason: Pull old Patch, set (179a-179s, Straddle Patch OD:3.5o0) Reference Lo : Ref Lo Date: Last U date: 3/26/2008 Last Ta : 7619' RKB TD: 8086 ftKB Last Ta Date 6/2/2007 Max Hole An le 42 de 4100 I ~ ~ ~~~ ~ :_. ~' ~ `Gd - i' i -V .,. ~' ~`'__ 5~ ~~i'F ~ A~i~ ~" Y ~ iP ~ ~ ~ " ~~ ~ ~ ~ ~ _ e tia ii I v'/ z iv `_~ I ',A :I~ -~"r'...~ '~ ~ //Ai~'1~i. ~ ~ Descri tion Siz Bottom ND Wt Grede Thread e To CONDUCTOR 16.000 0 110 110 65.00 H-40 SUR. CASING 10.750 0 2191 2191 45.50 K-55 D. CASING PRO 7 000 0 8071 7070 26 00 K-55 +~*'~ { ~... . , ~ ~ ~; ~ ~_ .a` ~. .~ '~ 1 -'` ~~ 3t' ~ y ~ •. ~ ~ 1~ F M~{~. ~~W I ~ ~ ~ j'= u y . ,5 : G~ ~, e ~,~ i~, ~ Size To Wi Grade Thread Bottom ND - 3.500 0 7373 6484 9.20 J-55 BTC AB-MOD 2.875 7373 7408 6513 6.50 J-55 BTC AB-MOD ;~~i~~ ,.r E~ ~ ~ ~ ~ _ tii~ ~ ~ - ' ~y,ti i ~` ~ _ _ _ ; ;~,. y, ~~ 41 ~+$~ +~: ~ ~ T e Comment Status Pt SPF Date Interval TVD Zone 7180 - 7242 6320 - 6373 C-4 C-3 62 4 12/30/1985 IPERF 7291 - 7324 6414 - 6442 C-1 UNIT B 33 12 12/30/1985 IPERF 7482 - 7486 6575 - 6579 A-5 4 12 12/30/1985 IPERF 74 96 - 752 0 6587 - 6607 A-4 24 1 2 12/30 /1985 IP ERF ~ ~~ ~ ~ ~ ~ A' i' ~ ~~ ~ ~' ~ ~ ' ' t' ` ~~ r" '~ il„ F ~~ 8~ ' 1 f ~ , , r ~C~ , ~~s, o . ~ C ~~ ~;i. _ _xi 91~ ~ ~ ~ ~ A~ .~ St MD TVD V Mfr V Type Man Mfr Man Type V OD Latch Port TRO Date Run Viv ~ Cmnt 1 2527 2527 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 2 4070 3887 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 3 5025 4605 Camco KBUG DMY 1.0 BK 0.000 0 1/24/1992 4 5456 4931 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 5 5909 5273 Camco KBUG DMY 1.0 BROKE 0.000 0 1/21/1992 1 6 6275 5560 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 7 6677 5892 Camco KBUG DMY 1.0 BK 0.000 0 1/4/1992 ~ ' 8 6959 6131 Merla TPDX DMY 1.5 RM 0.000 0 8/14/1992 1. Broken Latch 1/21/92 ~ -- ' ~ ~ ~~~~ ryk._= „4, ~~54 _ II ~iafi _ ~~ ~ ~ _ 9 - ~1 ' `~E ~~ ~ i „ ~i ~ i p~ _ 5...ht~"~e=,. t.~'~~P~; ~~ V OD V Type St MD TVD Man Mfr Man Type V Mfr Latch Port TRO Date Run Vlv Cmnt SsR 9 7059 6217 Merla TPDX DMY 1 5 RM 0.000 0 12/1211995 (ss9s-7ooo, 10 7130 6278 Merla TPDX . DMY 1.5 RM 0.000 0 12112/1995 OD:3.5oo) 11 7264 6391 Merla TPDX DMY 1.5 RM 0.000 0 7/13/2007 1 1. EX TENDED PKG PKR C~ 8~r ~ -~ .'n~~G. `+_ , F_~ :~~ `€., .~ E~: ~ ~ P._ _ ~ ~iiia~ i ~ .;'' (7oz2aozs, De th Descri tion ND T e ID oD:s.~5s) 17gg 17g8 SSSV CamcoTRDP-IA-NC 2.813 6999 6165 SBR Brown 2.813 7022 6185 PKR Brown'HB-1' 3.000 7257 6386 PATCH ONE-RUN KB STRADDLE COMPLETION PATCH set 3/20/2008 1.550 7282 6407 PKR Brown 'HB-1' 3.000 ~ 7371 6482 NIP Otis BPL Ported Ni le 2J50 7371 6482 SLEEVE-C Ran 2.75" Otis OPLN ISO Sleeve set on 1/25/2007 2.250 7384 6493 PKR Brown '1 B' 3.000 7397 6504 NIP Camco'D' Ni le NO GO 2.250 -- - -- 7406 6511 SOS Brown 2.441 7407 6512 TTL ELMD TTL 7392' PER IPROF 5/23/O6 2.441 PATCH (7257-7277, - ~ OD:3.500) PKR (7282-7283, -- OD:6.156) SLEEVE-C (7371-7372, OD:2.750) PKR I (7384-7385, OD:6.156) . NIP (7397-7398, ~ OD:2.875) i SOS (7406-7407 , OD2.875) ? ~ ~=~ I Perf p482-7486) ...__...._ ._ .... _...._.._. _......._ Pert ----- .._ -- .... ~- ........... -.- '~.. ~ (7496-7520) -- - - - -... ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEfVE~ APR 1 5 2008 REPORT OF SUNDRY WELL OPERATIC>a Oil ~ Gas Cons. Commission ~- , 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ et Patch Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhlllips Alaska, InC. Development ^ Exploratory ^ 182-103 / ' 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20770-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 85' 1 H-04 d 8. Property Designation: 10. Field/Pool(s): ADL 25639 ? Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8086' feet true vertical 7082' ~ feet Plugs (measured) Effective Depth measured 7619' feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 78' 16" 78' 78' SUR. CASING 2167' 10-3/4" 2191' 2191' PROD. CASING 8057' 7" 8071' 7069' ~~N~D MAY ~ 2008 Perforation depth: Measured depth: 7180'-7242', 7291'-7324', 7482'-7486', 7496'-7520' true vertical depth: 6320'-6373', 6414'-6442', 6575'-6579', 6587'-6607' Tubing (size, grade, and measured depth) 3.5" x 2-718", J-55, 7373', 7408' MD. Packers &SSSV (type & measured depth) pkr-- BROWN 'HB-1' ; BROWN 'HB-1' ; BROWN 'HB-1' pkr- 7022' ; 7282' ; 7384' Camo TRDP-1A-NC SSSV= 1798' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable ~~- ~'i~)` /r ~ ~QQQ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 5100 ~ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ' Daily Report of Well Operations _X 16. Well Status after 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: none contact John Peirce @ 26 5-6471 Printed Name John Peirce ~ Title Wells Group Engineer ~~ ~ ~ Q Signature Q ( Phone: ~ 265-6471 ~ Q Date Z5 (mil ~ Pre red b h ron Allsu Drake 263-4612 Form 10-404 Revised 04/2006 ~s`~ Sub//milt Original Only 7J / ~~G Sy 1 H-04 Well Events Summary DATE SUMMARY ~ • 3/1/08 WEATHER-DELAYED START. PULLED UPPER BAKER KB PACKER WITH 20' SPACER PIPE @ 7257' RKB. IN PROGRESS. 3/2/08 PULLED LOWER BAKER PKR @ 7257' RKB. PKR MISSING 1 ELEMENT. ATTEMPTED FISH ELEMENT WITH 3-1/2" WIRE BRUSH AND GRAB, NO RECOVERY. READY FOR E/L. 3/19/08 B&F PROPOSED PATCH AREA @ 7257' AND 7277' RKB. RAN 2.78" DMY PATCH DRIFT TO 7290' SLM W/ NO PROBLEMS. JOB COMPLETE. 3/20/08 SET BAKER ONE-RUN KB STRADDLE COMPLETION ACROSS INJECTION MANDREL #11 FROM 7257' - 7277'. (PATCH ID = 1.55") READY FOR PE INJECTION TESTING. y--~. '~~ ~o>r~t~~~-~hilti~ ,l~lask~, ~~'IC~ 1 H-04 API: 500292077000 Well T e: INJ An le m TS: 32 de da 7 i79 SSSV T e: TRDP Ori Com letion: 7/23/1982 An le TD: 33 de 8086 SSSV Annular Fluid: Last W/O: 12/30/1985 Rev Reason: Pull old Patch, set (1798-1799, 3 500 OD Straddle Patch . ) : Reference L Ref Lo Date: Last U date: 3/26/2008 Last Ta : 7619' RKB TD: 8086 ftKB Last Taq Date fi/2/2007 Max Hnl? AnglP• 42 d?g t7 4100 _ _ Casing Strin4 -ALL STRINGS _ _ Descri lion Srze To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 SUR. CASING 10.750 0 2191 2191 45.50 K-55 PROD. CASING - 7.00(1 0 R071 _ _ - 7070 26.00 -- K-55 __ _. Tubing String -TUBING Size Top Bottom TVD VJt Grade Thread Sp4 0 7373 t 4 :4 1.2(1 J SS _ C3TC B rnOD 2.875 ,.,,., --- 7-108 t`13 SO J ~£~ BTC AC L1UD Perforations Summary _ Interval TVD Zone Status Ft SPF Date T Comment 7180 - 7242 6320 - 6373 C-4 C-3 62 4 12/30/1985 IPERF 7291 - 7324 6414 - 6442 C-1 UNIT B 33 12 12/30/1985 IPERF 7482 - 7486 6575 - 6579 A-5 4 12 12/30!1985 IPERF 7496 - 7520 6587 - 6607 A-4 24 12 12!30/1985 IPERF i.1G~ St Llll IY/QiIYI G MD ND IA/Y41VCJ j Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2527 2527 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 2 4070 3887 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 3 5025 4605 Camco KBUG DMY 1.0 BK 0.000 0 1/24/1992 4 5456 4931 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 5 5909 5273 Camco KBUG DMY 1.0 BROKE 0.000 0 1/21/1992 1 6 6275 5560 Camco KBUG DMY 1.0 BK 0.000 0 1/12/1992 7 6677 5892 Camco KBUG DMY 1.0 BK 0.000 0 1/4/1992 8 6959 6131 Merla TPDX DMY 1.5 RM 0.000 0 8/14!1992 1 Rmkun I aMh H M4/091 Injection _MartdrefsNalves St ~ MD TVD Man Mfr ~ Man Type ~ V Mfr ~ V Type ~ V OD ~ Latch ~ Port ~ TRO ~ Date Run ~ _Vlv ~ SBR (6999-7000, OD:3.500) PKR (7022-7023, OD:6.156) PATCH (7257-7277, OD:3.500) PKR (7282-7283, OD:6.156) SLEEVE-C (7371-7372, OD:2.750) PKR (73847385, OD:6.156) NIP (7397-7398, OD:2.875) SOS (7406-7407, OD:2.875) Perf (7482-7486) ~~- ~_ - I 1. EXTENDED PKG Other (plu~c s, equip., etc.) - COM_ PLETION De h TVD T e Descri 1798 1798 SSSV Camco TRDP-IA-NC 6999 6165 SBR Brown L-- 7022 6185 PKR Brown'HB-1' 7257 6386 PATCH ONE-RUN KB STRADDLE COMPLETION F 7282 6407 PKR Brown'HB-1' 7371 6482 NIP Otis BPL Ported Ni le 7371 6482 SLEEVE-C Ran 2.75" Otis OPLN ISO Sleeve set on 1/2 7384 6493 PKR Brown'1B' 7397 6504 NIP Camco'D' Ni le, NO GO 7406 6511 SOS Brown 7407 6512 TTL ELMD TTL ~ 7392' PER IPROF 5/23/06 • KRU 1 H-04 Pert (7496-7520) • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~E ~i~,R ~ ~ 20~ Dear Mr. Maunder: i ~~ ~ d 3 1~ Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me or Perry Klein at 907-659-7043, if you have any questions. Sincerely, -- ~P ~~ /~ M.J. veland ` VVV ConocoPhillips Well Integrity Projects Supervisor • cEw'~~ ~E BAR .~ $ ~p08 & Gay CASmiss A~ ~ ~x • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Repor# of Sundry Operations (10-404) Kuparuk Field Date 3/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103- 23" NA 23" NA 4.5 2/2/2008 1H-06 182-068 28' 3.2 5" 1/17/2008 5.5 2/2/2008 1H-07 182-084 9' 3" 1 11" 1/17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1E-31 .197-138 4'10" NA 4'10" NA 21 3/8/2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 198-213 20" NA 20" NA 4.5 3/8/2008 ~,~n. NO.4356 Schlumberger -ACS ~ ~ ~ ~'~~~.~Y 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ '~ ZQ~~ Attn: Christine Mahnken ATTN: Beth NO~ 333 West 7th Ave, Suite 100 ~''~~" Anchorage, AK 99501 Field:. Kuparuk Well Job # Log Description - `Date BL Color CD 11 /02/07 1D-103 11837528 INJECTION PROFILE 10127/07 1 1L-28 11839680 PRODUCTION PROFILE 10128107 1 2N-310 11839674 DDL ~ - 10/30107 1 1C-190 11837524 INJECTION PROFILE (_J= ~~'- Q.' 10/20107 1 2V-16 11837526 PRODUCTION PROFILE - '~~' 10/24107 1 1H-04 11837527 INJECTION PROFILE 10/25/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . . WELL LOG TRANSMITTAL u_ __. _ __ _..,,__ .......__ --~------'" ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MlT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AI< 99518 Fax: (907) 245-8952 1 Report / EOE 1H - 04 Caliper Report 05..Jun-07 1) 2) 3) 4) 5) 6) 7) 5GANNED JUN 2 0 2007 U::LC--I1fif-103 it r51&}Co ,. Signed: O-.jj~ .,¡ 1 Z007 .- ~~ Print Name: C. btrl-'Š.f-¡IAR mD.1A IA /LPA1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?DSANCHt.JRÞ.G¡;(ê¿~VìEf\i1CR./L;:¡G.<:;QNI WeBSITE : ;jV~JÌJ1.N.¡ii1EM{J,R··tL¡;;'G~CorJl D:\Master _copy _ 00_ PDSANC-2iJJ<x1Z _WordlDistnòutìon\Transmittal_ Sheets\Transmit_ Original. doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary ConocoPhillips Alaska, Ine. June 5, 2007 7168 1 3.5" 9.3 lb. J-55 Tubing 2.875" 6.5 lb. J-55 Tubing Well: 1 H..o4 Field: Kuparuk state: Alaska API No.: 50-029-20770-00 Top Log Intvl1.: Surface (MD) Bot. Log IntvI1.: 7,356 Ft. (MD) Top Log Intvl1.: 7,356 Ft (MD) Bot. Log Intvl1.: 7,392Ft. (MD) Company: Log Date: Log No. : Run No.: Pipe1 Oesc.: Pipe1 Use: Pipe2 Oesc.: Pipe2Use: Inspection Type : COMMENTS: This Caliper data is tied into the TTL @ 7,392 ft. (Driller's Depth). Corrosive & Mechanical Damage Inspection This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing is in good to fair condition. A maximum wall penetration of 43% is recorded in pup joint 236.1 (7,353'). Wall penetrations in excess of 20% are recorded in 4 of the 255 joints logged. The damage is recorded in the form of General Corrosion and Isolated Pitting. No significant areas of Cross-sectional wall loss or 10 restrictions are recorded in the 3.5" tubing. The caliper recordings indicate that the 2-7/8" tubing is in good condition, with no significant areas of Wall Penetration, Cross-sectional wall loss or 10 restrictions are recorded in the 2.875" tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" TUBING· MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 43%) Jt. 236.1 @ 7,353 Ft. (MD) Isolated Pitting ( 35%) Jt. 235 @ 7,280 Ft. (MD) Isolated Pitting ( 33%) Jt. 232 @ 7,177 Ft.."LMD}. . .....<... .... Isolated Pitting ( 32%) Jt. 236 @ 7;334'"Ft: (MD) 3.5" TUBING· MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: ",:--.,"'1 No significant areas of cross-sectional wall loss (> 15%) are recorded. 3.5" TUBING· MAXIMUM RECORDED ID RESTRICTIONS: 5'~ JUN 1 4 2l)t)7 No significant 1.0. restrictions are recorded. 2.875" Tubing· MAXIMUM RECORDED WALL PENETRATIONS: No significant areas of wall penetration (> 20%) are recorded.', ~4' 2.875" Tubing. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: RE0EiVEO No significant areas of cross-sectional wall loss (> 15%) are recorded. JUN 1 1 Z007 2.875" Tubing - MAXIMUM RECORDED 10 RESTRICTIONS: No significant 1.0. restrictions are recorded. Alaska 01\ & Gas Cons. eommission Anchorage I Field Engineer: W McCrossan Analyst: J. Thompson & Bin Qi Witness: J. Brake ProActive Diagnostic Services¡ Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 (.):r:.c.. 115;) -10'3 :ttJ S-J'7ç,. I I Pipe 1 Pipe 2 I I I I I I I I I I I I I I 2280 GlM 1 3043 .. Q) ..Q 3792 Ii GlM2 E !:: z 4558 GlM 3 GlM4 5332 GLM5 GLM6 6095 GlM 7 GlMS 6875 GlM9 GlM10 GlM 11 3.5 in (7.2'- 2.875 in I Bottom of Su rvey '" .6 I I Correlation of Profile Well: Field: 1 H-04 Kuparuk ConocoPh¡lips Alaska, Inc. USA June 5, 2007 Country: Survey Date: Tool Deviation Approx. Borehole Profile 36 755 1508 7392 100 50 Damage Profile wall) I Tool Deviation I I I We!!: Field: Company: Country: 1H-04 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread -55 I Penetration and Metallos!> wall) I metal loss I 250 200 150 100 50 0 o to 1% 1 to 10 to 20 to 40 to over 10% 20% 40"1" 85% 85% I I I o o I Damage Configuration ( body) 10 I I I o isolated general line ring pîtting corrosion corrosion corrosion I o I I I I DS Report Overvi n An s Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom. 10 2.992 ins June 5, 2007 MFC 24 No. 021119 1.69 24 B. Nom. Upset 3.5 ins Upper len. 6.0 ins Damage Profilt'! wail) o o metal loss 50 GlM 1 GLM2 GLM3 GLM4 GLM5 GLM6 GLM 7 GLM8 47 ri ...iO r.¡ M 10 GLM 11 Bottom of Survey = 236.2 Analysis Overview page 2 Lower len. 6.0 ins 100 JOINT 3.5in 9.3 0.254 În 0.254 in 2.992 in j-55 Well: Field: 1 H-04 Inc. USA June 5, 2007 Survey I I I I I I I I I I I I I I joint jt Depth Pen, Pen. PerL ¡'vlel,,! Min. Profile No. ~::::r;1 (%:s !.D. Comments (Ins.) (IllS. ) 0 50 100 ,1 7 0 () ¡ 2.95 PUP m () ;1 2,<:¡4 PUP () PUP n PUP 2 68 0 3 97 " 4 125 0 5 157 =t=+ 6 ~~ 7 .01 _'93 2.95 10 ~ 11 340 1 12 371 () ~lli 2.92 13 400 () ~ I 2.94 14 411 0])1 2. .'5 1'1 462 ¡ I ~~: 16 491 001 17 521 =*552 0 9 582 () 0.01 20 611 0 0.01 2.94 ?1 640 0.01 ?Q? 22 670 0.01 I I 2.93 23 698 0.01 2.93 24 727 0.01 2.92 25 755 it 2.91 26 785 2.93 27 814 0.01 "o!: I 28 844 0 0.01 2 2.94 79 1'175 () 0.01 7.'15 30 905 () 0.01 2.93 31 936 () 2.% 32 968 0 2.95 33 998 0 2.93 34 2.93 35 1058 4 2 2.94 36 1088 ( =+=t 2.92 37 1117 ( 2.94 38 1148 ( 2.94 1'1 3'1 1177 ~ 2.94 40 41 1238 42 1268 0.0 Ä. 43 1300 ( 0.01 2.94 44 1330 () I 0.01 I 2.94 45 1358 () ±fgt ±tlÎ 46 1388 0 ( I I II I I I I I I I I I I PDS 3.5 in 9.3 J·55 0.254 in 0.254 in 2.992 in Well: Field: 1 H..o4 Alaska, Inc. Survey Date: USA June 5, 2007 I I I I I I Joint Jt. Depth Pen Pen. Pen !vletal Min. n"m"qp Profile No. 1.0. Comments (0/0 wail) 0 50 100 47 '48 49 1478 .. 50 1508 2 .94 51 1540 t; 1 .9" 52 1571 om , 2 :ft 5'1 1602 I 0 I 0.02 \ } 54 16''12 I n I 0.03 n .94 55 56 ')7 1725 1 1.91 57.1 1755 0 2.81 SSSV 58 1767 ¡ 0 I } 2.93 59 1795 ! 0 I 2.94 2.90 .92 62 1 5 .92 63 1914 0 om 2 .92 64 1946 0 OJI1 4 1 .93 65 1976 ( om 3 .94 66 2006 001 S 2.95 67 2038 0 2.93 68 2067 0 2.92 69 2098 2.95 70 2129 2.91 71 2158 om " 2,91 U. Deoosits. 72 2189 , 2.92 73 2219 0 ¿ 2.92 74 2248 0 I 2.94 75 2200 2.96 76 2310 2.92 77 2338 2.93 ~ 2.93 J 2 2.97 00 2427 J om I 2.90 81 2456 0 0,02 2.92 81.1 2AR5 I 0 N/A r,¡ M 1 Hatch @ 10:30) 82 2491 ( 0 2.99 83 2521 0.04 2.93 Shallow oitfin2. 84 2551 =±it 4 2.93 85~ 2.93 86 2,95 87 2640 2.92 88 2669 0.02 9 =I 89 2701 0.03 \ 90 27.'12 I om 91 2764 ( 0.02 92 2795 ( om 2.94 93 I 285(D - ~ 94 - 2 I PDS REPORT JOINT TABULATION SH I Pipe: Body Wail: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in WeD: Field: Company: Count¡y: Survey Date: 1 H-04 Kuparuk ConocoPhiUips Alaska, fne USA June 5, 2007 I I I Joint Jt. Depth Pel L Pen. PerL = Min. Damag e Profile No. (Fl.) (~:~:(;I Body 1.0. Comments (% wall) (Ins.) (Ins.) 0 50 100 95 2890 n 0.01 2 2.94 96 292? 0 0.01 2 2.92 97 2952 I 0.01 ) 2.95 98 2982 ( 0,01 1 2.94 99 3013 1i±' 2.93 100 3043 ( 0.01 2.90 101 3071 ( 0.00 2.92 102 3100 ( 0.D1 2.92 103 3129 0 0.02 a 2 2.93 104 3158 0 0.02 ß I 2.95 ~ (~ 2.92 3217 o .02 B 2.93 0 2.92 108 3275 o 0 2.92 109 3305 ±t]t01 2.95 110 3336 o .01 t 2.93 111 3367 ( 0.01 2.95 112 3398 ( O.O? 2.93 113 3428 ( 0.00 2.95 114 3458 í 0.01 2.96 IIi 115 3489 í 0.01 2.94 II 116 3519 0 t!Is 2.94 IIi 117 3549 0 2.94 118 3578 0 2 2.95 II 119 3610 0 0.01 2 2.94 120 3641 0 0.D2 2.94 III Pl 3672 0 0.01 I 2.93 122 3701 í 0.01 2.93 123 3732 í 0.02 2.95 124 3761 ( 0.01 2.95 125 3792 í 0.02 2.94 126 3823 0 0.01 I 2.92 127 3852 0 0.01 2.93 128 3881 0 0.02 ( 2.95 129 3910 n 0.01 2.95 130 3941 0 0.01 2.91 131 3972 0 0.04 ¡ 2.90 Shallow oitting:. 132 4003 0 =+ 2.91 132.1 4033 0 ( N/A GLM 2 lIatch @ 10:30\ 133 4039 0 ¡ 2.93 134 4069 0 0.01 , 2 2.92 II 135 4098 0 0.02 2.94 II' 136 4129 0.01 2.93 ll. DeDosits. 137 4159 0.01 2.94 138 4186 O.O? 2.86 U. Denosits. !'iI 139 4218 í 0.01 2.94 140 4249 ( 0.D2 ~ 141 4200 0 0.00 1 142 4310 0 0.03 10 !'iI 143 4341 0 0.00 1 2.89 I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I I JOINT TABU LA TION Pipe: Body Wall: UpsetWa!!: Nominal 1.0.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in Joint Jt. Depth PPII Pen. PerL ,'yleldl Min. No. Upset Body Loss 1.0. (Ins.) (Ins.) (Ins.) 144 4373 O~. 297 145 4404 0 146 M35 I) 0.01 147 4466 0.01 :2.87 148 44(}¡ 0.02 I 2.88 149 4528 0.01 2.92 150 4558 0.01 2.93 151 4589 ~i 7.9< 152 4620 I) ---W1!:U- ~ 153 46<;1 I) 0.01 .54 II 0.02 I ;1 155 0.02 1'2 1 . 0.031 II ;1! 2.85 1 0.02 (1Ij:90 4808 0.01 Ii ;1 7.M 159 4839 ¡¡m 2M.- 11'\0 4870 I 2..:00... 161 4899 I 2.85 162 4930 0 0.01 2.86 163 4959 0 0.02 . 163.1 4990 n 0 164 '1001 0 2.99 165 5028 ~i 2.85 166 5059 i 2.88 167 smo 168 5122 2.87 169 5151 0 0.02 i -2 I'2ß8 170 5181 0 0.01 3 ~ 171 5211 0.01 2.84 172 5239 0.02 2.82 173 5270 0.02 2.86 174 5301 0.01 2.85 175 '>332 0 0.01 2.89 176 5363 0 0.01 . =r::L 2.83 177 5194 ( 0.01 ~ 2.76 177.1 5421 0.01) 2.89 177.2 5426 0 NiÄ 177.3 5430 0 2.99 178 5434 0 7.9Q 179 5461 0.02 ? li1 180 5493 2.85 181 5521 2.83 182 5554 0 286 183 5583 6 -:1 2.81 184 '1111< 0.01 ( -;z]]L 185 SM1 0.01 .b2L 186 5670 0.02 I 2.82 187 5701 0.01 2.87 1M 5729 0.01 ( 7.83 1 li9 5758 0.01 I I 2.83 WeD: Field: Survey 1 H.o4 Kuparuk ConocoPhilips Alaska, loe. USA June 5, 2007 Comments GLM 3 (¡at"+' @ 4:301 PUP GLM 4 Hatch @ lO:OOì PUP 4 Profile o 50 100 : ¡ ¡III! II! I I I JOINT Wan: Upset Wall: Nominal 1.0.: 3.5 in 9.3 0.254 in 0.254 in 2.992 in J-55 Well: Field: 1 H-04 Kupa !Uk Alaska, Ine. USA June 5, 2007 I Joint Jt. Depth Pen Pen. Pen ¡vlelal Min. I Jam""p Profile No. 1.0. Commenl$ "" -'" I'" """1 (Ins.) (Ins.) 0 50 100 190 i 2.84 191 <¡818 2.81 192 5847 192.1 5875 0 PUP 192.2 5878 n 9:30) 193 3M7 n 0 2.99 19418 2.78 195 5946 0 2.84 196 HID 197 ( 2.84 It. IJeno<:it<:. 1 CjR 6034 0 199 6063 0 0.04 200 6095 n 0 2.81 201 6126 2 2.89 ~ I 2.91 203 87 '} I 204.1 6249 0 I ca M h Hatch @3:00) 205 6256 0.03 1 206 6287 f¡ { 2.81 207 h317 0 7 208 h,4-q ( 2 ¡ 2.87 209 hUH 7 210 6408 It. Deoosits. 211 fi4'i9 ¡ .212 6468 ) )1'1 6498 4- 'J 214 6529 !ß Shallow oiUiO\l. U. Oeoosil$. 215 6562 I 001 216 6592 I 0.01 0 0.01 i ~ 0 i NA GLM 7 (N/A) 217.2 6660 0.02 2.85 PUP ¡ii!I 218 666.2 . 1 2.76 219 6h91 I 277 . 220 6723 ~ !II 221 6751 " .222 6782 271 6RB om 1 (1 4 2.81 224 6845 0.01 I 2.76 225 6875 0.02 11 2.M 226 om 111 !fill 221'..1 6q33 0 226.2 6936 0 0 GlM 8 íiatch @ 12:(0) 22F.3 6944 (I 0.02 PUP 227 6947 i 0.02 It Oeoosits. . 227.1 hQìR { 0 SBR 227.2 6981 ¡ { 2.86 PUP !II! ?27.3 6995 I ( I -1Jjf I PUP P 227.4 7001 0 0 ( ( I I PACKER I I I I I I I I I I I I I 5 I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 H-04 Kuparuk ConocoPhillips Alaska, Inc. USA June 5, 2007 I I Joint Jt. Depth iIi PerL \Aelal Min. Damage Profile No. (Ft.) Body Loss W. Comments (% wall) (hi':) Ins. (Ins.) 0 50 100 227.5 7007 4 2 2.81 PUP er ß I 2.85 034 n , 1 2.68 PUP 703R 0 N/A GLM 9 (latch @ 3:30) 7046 I 0.02 2.64 PUP 729 7049 I 0.02#= 2.81 Lt. Deoosits. 230 7079 I 0.D1 2.81 230.1 7106 I 0.02 7 2.78 PUP 230.2 7110 I 0 * N/A GlM 10 (latch @ 6:30) ~ 230.3 7119 I 0.01 =±± .75 PUP 711 7122 I 0.02 Lt. Deoosits. 232 7151 () 0.08 ,"1'1 I 13 !:~~ Isolated nittin~ It. Deoosits. 233 7183 () 0.D1 .82 Lt. Deoosits. 234 7213 () 0.D1 2.76 r 234.1 7243 0 0.02 2.93 PUP I 234.2 7246 n 0 ( N/A GlM 11 (N/Aì 234.3 7255 n 0.02 2.94 PUP Denosits. I 234.4 7264 () 0 N/A PACKER 234.5 7270 () 0.01 {) 2.95 PUP 235 I 7276 0 0.09 35 2 2.92 Isolated nittin~ 236 7307 n nOR 17 3 2.93 Isolated o¡ttin~ 236.1 7319 I) 0.11 ¿n {) 2.64 Corrosion. DelJOSits. 236.2 7154 () 0 r () 2.2') I SO Sleew I I Body Me1a1 loss Body I I I I I Page 6 ----- Well: Field: Company: Country: Tubin : 1 H-04 Kuparuk - ------- - .. s rt ross S USA 3.5 ins 9.3 f ,55 Alaska, Inc. Date: Type: Too! Size: No, of Anal st: June 5, 2007 MFC 24 No. 021119 1.69 24 B. i 15 it Corrosion .11 ins'" 43% Wall Penetration HIGH SIDE UP Tool '" 52 Nominal 10'" 2.992 Nominal 00'" 3.5 Tool deviation'" 36 0 Cross Sections page 1 - - - .. s - -- .. - ------- - - -- - .. Wen: 1H-04 Field: Kuparuk Company: Alaska, Ine USA Turnn : 3.5 ins 9.3 f ,55 Tool '" 52 Nominal ID '" 2.992 Nominal OD '" 3.5 Tool deviation'" 29 0 joint 235 at PDS rt s Survey Date: Tool Tool Size: No. of Fingers: Anal st: June 5, 2007 MfC 24 No. 021119 1.69 24 B. i 153 ft Isolated Pitting .09 ins'" 35% Wall Penetration HIGH SIDE '" UP Cross Sections page 2 I I I Well: Field: Company: 1 H-04 Alaska, ¡ne. I USA I Nom.OD 2.875 ins Weight 6.5 f Grade & Thread -55 I Penetration ami Metal Loss (% wall) penetration metal loss 10 I I I 0 o to 1 to 20 to 40 to over 1% 10% 40% 85% 85"/" 0 0 0 0 I I Configuration ( body) 10 I I I o isolated general line ring hole I poss pitting corrosion corrosion corrosion iblê hole I o I I PDS Survey Date: Too! Too! Size: No. of Fingers: Anal .t: Nom.lD 2.441 ins Regi Nom. Upset 2.875 ins penetration Analysis June 5, 2007 MFC 24 No. 021119 1.69 24 B. Upper len. 6.0 ins Profile (0/" metal loss body 50 Bottom of Survey = 0.6 Analysis Overview page 2 I I Lower len. 6.0 ins 100 I I I I Joint No. I I I I I I I I I I I I I I I LATION JOINT J-55 Well: Field: Company: 1H-04 2.875 in 6.5 0.217 in 0.217 in 2.441 in USA June 5, 2007 Comments sits. Inc. Profile 100 I I I I I I I I I I I seton I 7392' PER ¡PROF 5123/06 PKR I I I NIP I Perf I (74112-7485) I KRU 1 H..04 Œ 04/05/07 Sc~.bel'g8P RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth APR 0 6 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ 011 & Gas Cons. Commission Anchorage SCANNED APR 1 0 2007 t) ...LC- l'lf'd - 1ô3 Field: Kuparuk WeU Job# Log Description Date BL Color CD 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02107 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02 11638845 GLS 03/21/07 1 2W-05 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-331- N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . Sc~lInbepgep ·(···~Ni\,\~ L -~u ~ ..' ";¡'_. ..;,;,;j ..., .. . . NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth I~d -lo3 u ..L~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description BL Color CD Date ~ '~/ 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04' 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-U 11249930 LDL 07/11/06 1 1D-106 NIA INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06129/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e Schlumbel'gep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # oc:: r'E" 1\}'" E.· 0 1\1.-1....1 l' ,¡ :\i r\ ,. '~'ìu""6 ; ; !_-~ , '~ ~.¡ ::j (J.;¡ ¡ ,'_,_."'~;,¡ ;,' ;>,,(-~r:: Cc{nm¡~n ....?<-~~\.;:¡:....:!¡ \1 '....caw _'\,.ot No. ~ 1~G:"<:!7:Ç e . 1 "Í q <ìnnfi " ' \' '<t:.~ì{"\" lìj¡t\) I Í<J [,vVJ (~f"'b.,\,-"t\., ,J ,,"~.. - :¡)\o.Iø,\> ,,; 'Ø .... Log Description Date NO. 3831 Company: Field: BL 06/02/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 O~ Anchorage, AK 99501 \ \ CfJ J: Kuparuk Color e CD 1 Y -12 ì"'i<'7.. -(',:)( 11235362 INJECTION PROFILE OS/20/06 1 1 L-06 i 'f!J./- I:Z:;: 11213748 PRODUCTION PROFILE WIDEFT 05/19/06 1 1 Q-24 } C; 5' -j,J ì 11213849 INJECTION PROFILE OS/20/06 1 1 H-04 11(::J -, ,-,-l., 11213752 INJECTION PROFILE OS/23/06 1 1H-08 }"x-:J-(-p 11213751 RSTIWFL OS/22/06 1 2Z-02 ¡~3 - ~";.,¿: 11235362 INJECTION PROFILE OS/28/06 1 1H-16 ¡c:'¡;J-¡:¿:¡ 11235365 PRODUCTION PROFILE W/DEFT OS/24/06 1 2A-04 17i« - è5""" 11213755 CROSS FLOW DETERMINATION OS/26/06 1 31-10 f¡{C, -t~l 11213759 PRODUCTION PROFILE WIDEFT 05/30/06 1 1H-19 ¡S;::J-!"Î'7é. 11320975 INJECTION PROFILE OS/29/06 1 2A-13 f ......-¿,- - iLI'-, 11320976 LDL 05/30/06 1 2Z-04 í *3 -c:~ 11213757 INJECTION PROFILE OS/28/06 1 2Z-12A 'ì,~- - ¡':'¡ff 1123568? GLS OS/27/06 1 3F-02 ¡ -S<S--.q~' . 11213758 PRODUCTION PROFILE WID EFT OS/29/06 1 - , 2-11 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e MEMORANDUM TO: Julie Heusser~ Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 6, 2001 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder JC~,,,n _.~,.~7 :'PhilliPsAlaska inc. P.I. Supervisor/,~' I' P-~'"--_~.....' 1H Pad ~o\..[\~',.~1, 1H-03, 1H-04, 1H-07, 1H-08, 1H-09 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I ITypelnj. I. ,'; .I ¥.V.D. 1'6~ I T6an~l '~ LI 25o0 1'25001 25O0 I~1 '4 I , IT~p~I 1551 lCfii 56O 1169O1 lr~Ol ~s40.1 P/F. I,_P .I P.T.o.I 18211,5O IType testl i~: p~T.o.I 482o84o ITypetesti P _IT~p~I 1606 ' Waq 1H-08 i P.T.O.I ~8209301Typetestl P .IT~p~I 1551 I .Ca~"~l I' W~! '~,-0~ IT~pe'~nj.I' _S. I T.V.b.'i'~,4~'_I'T'~ar~I 2.~0~1' 255O1 ~o' !.2~ I~"~v~!! 4' 193o29o ITypetestl P ITestPal 1617 I c~ngl s70 1179o1175o '! 174o I _P~F I P 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 Sun,~y D= Differential Temperature Test Interval != Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Tear's Details Friday, Jul_,/~ 2,001: I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed thc 4-year MIT's on wells 1H-03, 1H-04, 1H-07, 1H-08 and 1H-09. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summa.fy: I witnessed successful 4-year MIT's on PAI's wells 1H-03, 1H-04, 1H-07, 1H-08, and 1H-09 in the Kuparuk River Field / KRU. M.I.T.'s performed: 5_ Attachments: Number of Failures: 0_. Total Time during tests: 3.5 hm, C.C; MIT report form 5/12/00 L.G. MIT 1H Pad pg.2 KRU 7-6-01 JJ.xis 7116/01 STATE OF ~ ~ OIL AND G/~ CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing ~ Alter casing ~ Repair well Perforate Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 911' FNL, 1140' FEL, Sec 33, T12N, R10E, UM 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit 8. Well number 1 H-O4 At top of productive interval 1195' FNL, 1558' FWL, Sec 33, T12N, At effective depth 1048' FNL, 1123' FWL, Sec 33, T12N, At total depth 1036' FNLr 1094' FWLr Sec 33r T12Nr 12, Present well condition summary Total Depth: measured 8 0 true vertical 70 RIOE, UM RIOE, UM RIOEr UM 86 feet 8 2 feet 9. Permit number/approval number 82-1 03/92-6 10. APl number so-029-20770 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 8 0 3 0 true vertical 7035 feet feet Junk (measured) None Casing Length Structural Conductor 7 8' Surface 21 6 7' Intermediate Production 8057' Liner Perforation depth: measured 7180'-7242', true vertical 6320'-6372', Size Cemented 1 6" 274 SX AS II 10-3/4" 1000 SX AS III & 250 SX Class G 7" 1145 SX Class G & 250 SX AS I Measured depth True vertical depth 78' 78' 2191' 2191' 8071' 7069' 7291 '-7324', 641 4'-6441 ', 7482'-7486', 7496'-7520' 6574'-6578', 6587'-6607' RECEIVED S E P 2 8 1993 Representative Daily Average Production or Injection D~Sl~a Uil & t~as {.;0ns. L, ulli~IS$[U" OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Anci~a~ag0 Pressure Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 w/ tail @ 7408' Packers and SSSV (type and measured depth) PKR: Brown HB-I's @ 7021' & 7281', Brown lB @ 7384'; SSSV: Camco TRDP-1ANC @ 1797' 13. Stimulation or cement squeeze summary Converted well from oil producer to water injector on 3/7/92. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation I 100 950 1 1 00 1250 260 Subsecluent to operation 0 0 9 3 0 0 1000 2300 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Water Injector _X_.._ Oil _ Gas Suspended Service 17. I hereby/~,ertify that the foregoing is true and correct to the best of my knowledge. Si~ned/i '~~ /4~., ~ Title Senior Engineer :orm 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE W. Z S E O T L N A L E T 3 B PR & B PR 7 B PR 8 B PR TOTALS: W Z S E 0 T L N A L E T 4 B PW TOTALS: KDQS MORNINQ WELL REPORT FOR 03/07/92 DRILLSITE 1h PRODUCTION WELL STATUS GAS LIFT STATUS 7" 10" TP TT WC H2S CSG CSG PSI CHK DEQ % PPM PSI PSI SI CN QAS INJ AH TEMP METER VOLS LI D£G READING MBCF EB 125 176 54 18 140 175 108 0 130 176 29 1 130 176 118 27 30 1000 850 0 1450 340 0 54O 310 5 210 470 14 8393 1435 0 0 0 0 0 0 0 0 0 0 0 0 0 1435 0 INJECTION WELL STATUS INJECTION VOLUME ALLOW INJ PSI ACT 7" 10" INJ TT CSQ CSQ PSI DE9 CH½ PSI PSI 2500 1450 100 40 600 725 SWI: 0 + PWI: INJ INJ METER VOLS VOLS READING BBLS MMSCF 2~0 = 250 0.000 250 0.000 PAGE 1 S/I IMPACT C H M 0 R I D EPL S N E BBLS 0000 0 0 0000 0 0 0000 0 0 0000 0 0 S/I C H M 0 R I D S N E 1800 38 RECEIVED S E P 2 8 t99; Alaska Oil & Gas Cons. (.;ommisstor' Anchorage STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMIS~-~N~ REPORT OF SUNDRY WELL OPERATIONS ORIGINAL 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 911' FNL, 1140' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1195' FNL, 1558' FWL, Sec. 33, T12N, UM At effective depth 1048' FNL, 1123' FWL, Sec. 33, T12N, UM At total depth 1036' FNLr 1094' FWLr Sec. 33, T12N, UM 12. Present well condition summary Total Depth: feet feet 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R10E, R10E, R10E, measured 8 0 8 6' true vertical 7082' Plugs (measured) Effective depth: measured 8030' feet true vertical 7035' feet Casing Length Size Structural 7 8' 1 6" Conductor 21 67' 10 3/4" Surface Intermediate Production Liner Perforation depth: 8057' 7" measured 7180'-7242', true vertical 6320'-6372', Junk (measured) Cemented 274 Sx AS II 1000 Sx AS III & 250 Sx Class G 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-04 9. Permit number/approval number 82-103 10. APl number so-029-20770 ~ 11. Field/Pool I Kuparuk P~ye~ O_il_ Pool feet ( 'EIVED AUG 2 4 1992 /~,la$_~a .0JJ .& Gas Cons. Commission Measured depth T~C~I depth 78' 78' 2191' 2191' 1145 Sx Class G & 8071' 7069' 250 Sx AS I 7291 '-7324', 6414'-6441', 7482'-7486', 6574'-6578', 7496'-7520' 6587'-6607' Tubing (size, grade, and measured depth) 3 1/2" J-55 set at 7408' Packers and SSSV (type and measured depth) Brown HB-1 pkrs ~ 7021' & 7281'. 13. Stimulation or cement squeeze summary Convert well to water injection. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Brown lB pkr @ 7384', CAMCO TRDP-1ANC @ 1797' Tubing Prior to well operation 1060 1050 1100 1235 260 Subsequent to operation - 0 - - 0 - 9 0 0 0 9 2 0 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run -- I Water Injector X Daily Report of Well Operations )~. Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 2280 Signed C-(.~. ~ :orm 10-404 Rev 09/12/90 Title Date ~'/I c~ SUBMIT IN DUPLICATE W Z S E 0 T L N A L E T 3 B PR 6 B PR 7 B PR 8 B PR TOTALS' W Z S E O T L N A L E T 4 B PW TOTALS' KDQS MORNINQ WELL REPORT FOR 03/16/92 DRILLSITE iH PRODUCTION WELL STATUS GAS LIFT STATUS 7" 10" TP TT WC H2S CSG CSQ PSI CHK DEG % PPM PSI PSI SI CN GAS INJ AH TEMP METER VOLS LI DEG READING MSCF EB 125 176 54 18 140 176 108 0 130 176 44 1 130 176 118 27 30 1050 700 0 1410 280 0 800 280 5 220 530 14 8393 1435 0 0 0 0 0 0 0 0 0 0 0 0 0 1435 0 INJECTION WELL STATUS INdECTION VOLUME ALLOW INJ PSI ACT 7" 10" INJ TT CSQ CSQ PSI DEQ CHK PSI PSI 2500 2300 150 176 1000 800 SWI · INO METER VOLS VOLS READING BBLS MMSCF 0 8925 0.000 0 + PWI' 8925 = 8925 0.000 PAGE 1 S/I IMPACT C H M 0 R I D EPL S N E BBLS 0000 0 0 0000 0 0 0000 0 0 0000 0 0 S/I C H M 0 R I D S N E 0000 0 R'ECEiVED AU G 2 4 1992 AIaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. Post Office Box~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 7, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1 H-04 Cony. to Wtr Inj January, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) RECEIVED JAN 1 ,~ ~99~ Alaska 011 & 6as Cons. 6omm~sS'to~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3B-6003-C STATE OFALASKA 0 J{ I G IN A L 0IL AND G/~ ~SERVATION COMMi~o--1ON APPLIOATION FOR ,SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Abandon_ Suspend _ Alter casing _ Repair well_ Plugging'_ Change approved program _~_ Pull tubing _ 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Operation Shutdown Re-enter suspended well Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) Service 4. Location of well at surface 911' FNL, 1140' FEL, Sec.33, T12N, R10E, UM At top of productive interval 1195' FNL, 1558' FWL, Sec. 33, T12N, R10E, UM At effective depth 1048' FNL, 1123' FWL, Sec. 33, T12N, R10E, UM At total depth 1036' FNL, 1094' FWL~ Sec. 33~ T12N, R10E~ UM 12. Present well condition summary Total Depth: measured 8086' feet true vertical 7082' feet Effective depth: measured 8030' feet true vertical 703 5' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: RKB 85 7. Unit or Property name Kuparuk River Unit Plugs (measured) Junk (measured) Cemented 8. Well number 1H-04 g. ~rmit number 4~4~103 feet lO. APl number so-02~)-20770 11. Field/Pool Kuparuk River Field K~l~ar~k River Oil Pool f-.¢EIYED JAN 1 ,.,'I t992 .0ii & Gas Cons. Commission Measur~~..True vertical depth 78' 16" 21 67' 10 3/4" 8O57' 7" measured 7180'-7242' 7496'-7520', true vertical 6320'-6372', Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 7408' 274 Sx AS II 78' 78' 1000 Sx AS III & 21 91' 21 91' 250 Sx AS II 1145 Sx Class G 8071' 7069' 250 Sx AS II 4 SPF 90 degree phasing, 7291'-7324', 7482'-7486', 12 SPF 90 degree phasing 6414'-6441', 6574'-6578', 6587'-6607' TVD Packers and SSSV (type and measured depth) Brown HB-1 pkrs ~ 7021' & 7281'. Brown lB pkr @ 7384', Camco TRDP-1ANC @ 1797' 13. Attachments Description summary of proposal _ Detailed operation program _X__ BOP sketch Convert well from oil producer to water injector. (Wellbore schematic attached). 14, Estimated date for commencing operation 15. Status of well classification as: Januarv. 1992 Oil Gas 16. If. prop~)sal w~as vqrl~ally approved Ij.~/~/'/ mame oTapprover Date approved Service Water 17. I hereby ce~oing is true and correct to the best of my knowledge. Si~lned ~;. ~J~' Title OPERATIONS ENGINEER Date Suspended _ Iniector FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test ~ Subsequent form r~quire ~,pproved by order of the Commission :orm 10-403 Rev 09/12/90 ORIGINAL SIGNED B'v LONNIE C. $.N,11TH IApproval No. 10- ~ctb, ;-,~J Commissioner Date SUBMIT IN TRIPLICATE Well 1H-04 Conversion to Water Injection ARCO Alaska requests approval to convert Well 1H-04 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7180' and 7520'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and-every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED JAN 1 3 3992 Alaska Oil & Gas Cons. Commissior~ Anchorage Well: .I.H-4 sPud Date: 0 7 - 0 9 - 8 2 -- .' ~pletion Date: 0 7- 2 3 - 8 2 ,,.,~ximum Hole Angle: 41.5 Original Rig RKB: 28.5' ~,~-r' I# 50-029-20770-00 C Sand: OPEN A Sand: OR~N deg. @ 4100' MD All depth are RKB MD to top of equipment. Jewelry 1 2 3 4 5 6 7 8 Minimum W~-.~'ype: OIL Tree Type: MCEVOY GEN 2 5000~t Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 1 2 - 3 0 - 8 5 SSSV: CAMCO TRDP-1ANC @1797" SBR: BROWN PBR 2.813' ID @ 6999' PKR: BROWNHB-1 @7021' PKR: BROWN HB-1 @ 7281' PKR: BROWN lB @ 7384' NOGO: CAMCO ~' NIPPLE 2.25" ID @ 7397' SHEAR OUT: BROWN @ 7406' TUBING TAIL: @ 7407' ID: 2.25" Casing and Tubing Size Wel~_ ht Grade ToD Bottom 16" 65# H-40 0 110' 0.75' 45.5' K-55 0 2191' 7" 26# K-55 0 8071' 3.5' 9.2# J-55 0 7408' Information Valve Type Sz. Latch - . ? ~;LI/~ 1" e_v' I' DUMdY I" Cil~ 7 ~Zv~ 1" 1- I- CA~ ~OV 1.5" Gas Lift Depth St ne 2527' 1 4070' 2 5024' 3 5456' 4 5910' 5 6275' 6 6677' 7 6959' 8 CV 1.5" DUMMY 1.5" ORJFICE 1.5" OTIS BPL 'J" LOCK !! 7,8 7059' 1 7130' 2 7264' 3 7371' 4 Description CASING CASING CASING TUBING ~/~._.,~.~ AID~ Date Run -3-/-~e- ~/~ ?-/:~ -ee=o~'~ ~ '7-) 3 06-06-86 ?-/3-91 ~ ?-~.~- ~//-e6--e6=86 C234 06-1 9- 91 C234 12-29-85 1 6/64' C2~ 06-14-91 Cl ~MM. 05-22-91 ,lments: -. Perforation Data Interval SPF 7180-7242 4 7291-7324 12 7482-7486 12 7496-7520 12 Date Zone C o.m ~e(r~t ~ IV E D Cl-SAND A-SAND A-SAND JAN 1 992 .Alaska 0ii & Gas Cons. Commission Anchorage LASTTD: 7618' on 4-11-88 PBTD: 8030' PBTD,?~: LAST REVISION DATE: 0 6 - 2 8 - 9 1 ARCO Alaska, In Post Ofhce r~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one sigqed copy of this transmittal. Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis) KOE Buildup Analysis. KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis Kuparuk Well Pressure Report 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 100591H 7-15/19-87 6-10-87 7-28-87 6-]0-87 'C' Sand 6-]3-87 'C' Sand 6-14-87 Both Sands 6-17-87 Both Sands 6-18-87 Both Sands 6-14-87 Both Sands 6-11-87 'C' Sand ' 6-10-87 Both Sands 6-17-87 Both Sands 6-12-87 'C' Sand 6-9-87 Both Sands 11-3-87 Static Static Static IA' Sand Receipt Acknowledged: DISTRIBUTION: ~ a[~,~ Oil & Gas uons Commisslor~ Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany M EMORAN E oM Stat6. ,f Alaska ALASKA OIL ANiD GAS CONSERVATION COMMISSION TO: Lonnie C Smith-~¢~~ DATE: October 21, 1987 Commis s lone vR~ ~,~k¢ k~ FILE NO: D.BDF. 57 THRU: FROM: Michael T Minder ~i'Z~ Sr Petroleum Engineer Bobby Foster ,~ ~-~' Petroleum Inspector TELEPHONE NO: SU BJ ECT: BOP Test ARCO KRU 3H-4 Permit-No. 87-76 Kuparuk River Field Wednesday, September 2, 1987: The BOP test began at 10:45 a.m. and was 'cOmpleted at '1:15 p.m. As the attached BOP test report shows three items would be repaired/replaced and observed before drilling out the casing shoe. In summary, I witnessed the BOP test on ARCO's KRU 3H-4. Attachment 02-00 lA fRev. 8/85) 'O&O !~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator Date Representative Location: Sec /~ T/~RS~ M Drillin~ Contractor~ 0c4 O ~J Location, General Well Sig · General Housekeeping/~ Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Test Pressure Annular Preventer / Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve 1 Kill Line Valves Check Valve ~ -- q~Casing Set @ ~~7 ft. Rig t/ /~ Representative /q~)O ACCUMULATOR SYST~ Full Charge Pressure ~~ psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold~~ Test Pressure No. flanges Adjustable Chokes Hydrauically operated choke / mi~ sec. min~-O sec. Test Results: Failures ~ ~~~ Test Time ~ hrs. Repair or Replacement of failed equipment to be made within day~ and Inspector/ Commission office notified. Remarks: ~~ ~~~f~ ~~ ~7'~ ~ ;//~-/~~//~ O~ ~~ ~istribution orig. - AO&GCC c~ Z cc - Operator cc - Supervisor Inspe / ARCO Alaska, Inc. Post Office B~' ')0360 Anchorage, iL .-a 99510-0360 Telephone 90~'~76 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5805 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '_c ~_ Fi nal '-.3 x,~ lA_8 ..~-. '~1H-4 X R-3 "-.o A-[O C-[4 ~ ~- 3F-2 ~ ~ ~3J'~2' '"~ ~3J-3 ~ ~ ~3J-7 Prints- CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL 1-03-86 12-21-85 10-22-85 10-09-85 12-15-85 10-30-85 10-17-85 12-17-85 10-05-85 10-19-85 Run Run Run Run Run Run Run Run Run Run ~1 5600 - 6300 #1 4800' - 7521' #3 8490' - 8830' #2 6800' - 7406' #1 5496,- 6870' ~1 5350' - 8342' ~1 5925' - 7726' #2 8595' - 9110' #1 6624' - 8367' #1 5350' - 7527' Receipt Acknowledged- Di stri buti on' ~tate .of Alaska(+ ~ BPAE Chevron Mobi NSK Drilling Vault(1 film) SAPC Union · · ARCO AlaskL, inc. is a Subsidiary o! AtlanticRichlielclCompeny ARCO Alaska. I~,...~ "~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15-86 TRANSMITTAL ~ 5761 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run ~3 7585-8532 lA-14 .12-05'05 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt ..Acknowledged: Vault*films £ D Alaska Oil & Gas Cons. Commission ~¢horage Date: ~~ NSK Files*bl ARCO Alllka. Inc. is · Subsidiary of AtlenticRichfieldCompanY ATTACHMENT I I Drill lA Site Wel 1 No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date Drill Site Well No. .Log Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 '3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB lB-1 12/26/81 1B-2 6/25/81 lB-3 11/16-18/81 3112/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3184 Drill Site 1C Wel 1 No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 ' Log Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Lo9 Date 10 10-1 ~ 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 (~10-8 (WS-8) 5/i0/78 Oil & Gas Cr_,:~s ........ Page 2 Drill Site Well No. _Log Date 1H 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. ,Lo9 Date 1Q -~' lQ- 5 ~~. 12/1/85 Drill Site 1E Wel 1 No. 1E-!A 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Loo. Date 8/19/81 8/17/81 1/17/8~. 10/18/81 11/7/81 8/4/80 ~/2/81 11/5/81 10/27/81 !0/21/8! il/12/82 10/28/81 8/28/8i 1i/1/81 11/28/84. 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/!7/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/i6/82 Drill Site !G Well No. Loq Dase 16-1 16-2 16-3 16-4 16-5 16-? 16-8 Drill Site Well No. 9/7/S2 !F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 i0/13/82 1F-5 !1/12/82 1F-6 3/12/83 1F-7 !1/19/85 1/22/83 . LoQ Date 2/19/83 2/3/83 1/31/83 5/29/83 0/25/82 0/28/82 1/19/82 5/7/83 Attachment Page 3' JT Drill Site 1Y Well No. Log Date 1Y-1 6/6~83 10/21/83 1Y-2 6/10/83 3/4/84 ~-~3~ 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~1~ 5/10/83 ~._ 11/21/83 ~7t~8/8.~ 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. 2C Log Date 2C-4 2/19/85 2128185 2C-7 10/15/84 *~2C~!6~t2/~tt~5 Drill Site 2Z' Well No. Lo9 Date 12Z~ 7/10/83 2Z-2 *: 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg:O052 Alaska Oil & Gas Cons. Anchorage .... Dri 11 Si te 1H II Wel 1 No. 1H-3 ~1H-4 1H-7 ~1H-8 Lo9 Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA x.8/19/81 1E-Z '8/17/81'-) ~ _'~1/17/84// 1E-3 ~q_O/18/8I~. '-11/7/81/ ~- ",,8/4/80-'x, ..~ 1Ez4~\'le~ ~/~ 1E-5 - '-10/27/81_ 1E-6 '-10/21/81'"-> '--11/12/82.// '~1E-7 '~/28/81'<~ '~io/28/8i/Y ~ iE-8. '~8/28/81~> ~._ '""11/!/81/ 1E'12 ""11/28/84 1E-15 "-8/26/82 1E-16 '"8/29/82 1E-17 -"9/1/82 1E-20 '"~5/7/83 .1E-24 "-2_/17/83 1E-25 ~'1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/82 ~ ~ '~6/13/83 1E-29 '~10/18/8 ~2'~ ~ '-7/18/83 / /- 1E-30 "-10/16/82 Drill Site 1G Wel 1 No. "~IG-1 '"~1G-2 "~1G-3 ~1G-4 % 1G-8 Lo9 Date 9/7/82 9/25/82~,, 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F ~IF-1 2/19/83 %1F-2 2/3/83 ~IF-3 1/31/83 "1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82 '~ 1F,7 11/19/82x,, ~ 5/7/83 ~.-> R EC E FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office ' j00360 Anchorage, ~i~l~Ska 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports for the following well's' 1A-14 ,1H-4" 3A-2 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L147 Enclosures ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA Oli_ AND GAS CONSERVATION C~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-103 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20770 4. Location of well at surface 9. Unit or Lease Name 911' FNL, 1140' FEL, 5ec.33, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1195' FNL, 1558' FWL, Sec.33, T12N, R10E, UM 1H-4 At Total Depth 11. Field and Pool 1036' FNL, 1094' FWL, Sec.33, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 85' RKBI ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/09/82 07/18/82 07/23/82* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8086'MD,7082'TVD 8030'MD,7035'TVD YES~ NO [] 1798 feet MDI 1600' (approx) 22. Type Electric or Other Logs Run DIL/SP/SFL/GR/FDC/CNL/Cal, CBL, Gyro, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEiWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62,5# H-40 Surf 78' 24" 274 sx AS II 10-3/4" 45.5# K-55 Surf 2191' 13-1/2" 1000 sx AS Iii & 250 s:~ AS II 7" 26.0# K-55 Surf 8071' 8-3/4" 1145 sx Class G & 250 Dx AS II 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) 7180' - 7242' W/4 spf, 90° phasing 3-1/2" 7408' 7022', 7282' & 7384' 7291 ' - 7324' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7482' - 7486' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7496' - 7520' 7442' - 7444' 150 sx Class G 7286' - 7288' 150 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE "I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Rev. 7-1-80 Tubing was pulled & well was re-perforated & recompleted 12/29/85. CONTINUED ON REVERSE SIDE DAM/WCl~ubmit in duplicate 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS I' 30. FORMATION TESTS 31 LIST OF ATTACHMENTS Well Hi story (workover) 32 i MEAS. DEPTH Include interval tested, pressure data, all fluids ~ecove,,-ed arid gravity, 7179' 7322' 7469' 7587' TRUE VERT. DEPTH GOIR,and time of each phase N/A 6319' 6440' 6564' 6663' I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned Associate Engineer Title Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water ;njection, 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 !B-407 ARCO Oil and Gas Company Well History- Initial Report- Daily Inltmctlonl: Prepare and submit the "lnlllll Report" on the first Wednesday after a well is spudded or workover operations are started. Daily worx prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AR0570 ~r~S #1 ICounty. parish or borough North Slope Borough Lease or Unit ADL 25639 Title Recompletion IState Alaska IWell no. 1H-4 API 50-029-20770 O~rator:- ARCO w.I. AIU:O Alaska-,-. Inc;:.- - 56.24% 8~dde~ ~.be~u~.~?;,~* ..' ..... [Date. Hour. . P~or ~atus if a W.O. · '?.i'i. - [ 12/18/85 ' - 1 00 hrs. . i~?;~'.:~;~.~ ', "~"'.". ~'-'~ '*~ ~i~ "~-'~/': -,_~ ~" -~..-' ' . -. i '.;;;-~?~:; ',: :-. '.' i'~[~:~:~:...803~i'-~/'1~.~ mi: ~g- .- ~ ~""-~':~?' ;~.', ~. [' Agcep~:t~g· ~. 1100 hfs, 12/18/85~-_ "--~":~/."~ '-'ri?~?~'r:~.~' ." ~- ' itidsea~' ~i11_-C0. pe;~s, ' ' "..'~::~:?~': "'".-' ~ bcfne;. Sec BPoe;' ~ tree, ~..BOPE~ /'_-:-~ .- ~: ' ' .'-:- ' 12/20/'85:,, "~ .. 7"~ 8071t ' ' 8030~ PB~, POOR Co ch8 ouC coupltngs~"- I0.1 pp8 NaC1/~aBr- ';-- ~. & Cst BOPS. ACCe~ ~o shear. SBR~ ~ould. noc shear. RU DA~ R~B v/cb8 cutter, cuc cb8 ~ 7020',-POOB, ~DA. ~ull Cbg ~ree, P~ chg ouc couplings ~/3~" BTC ~o 3~P' STC~ Rod. 12/21/85- 7" ~ 8071~ ch~ 8030' PB~ E~. v/DP 12/23/85 10.1PP8 NaC1/N~r P~ FTA ~1, RIH, Cas-TOF btm. Tag TOF ~ 7459v, engage fsh w/OS, CBU~ POOR, raced fsh. AU SOS, m CE~ f/7527'-4800', 7529' vsh Co-7608~, CBO, POOH. EU SOS. Peri w/7442'-7444' SeC ~ZSV reCnc-'s ~ 7473' & 7320', ~ SOS. _R~B ~/sCtnger on DP, P~H,. RU SO~-RIH, perf 7286'-7288', POH. RIH w/EZSV, set 7250', POOH, ~ SOS. RIH w/stinger on DP. 12/24/85 7" ~ 8071' 8030' PBTD, Monitor 10-3/4" x 7" ann f/pressure 10.1 ppg NaC1/NaBr RIH w/stinger on DP, stab ~to EZSV ~ 7250'. Est IR ~ 1BPM, 2000 psi. Sqz perfs ~ 7286'-7288' w/150 sx C1 "G" w/.8% ~-28, .3% CD-31 & .1% D-6. Pull out of retnr, rev out, POOH. RIH w/ret~ BP, set ~ 6994', POOH. ~ BOPE. Bleed off press on 10-3/4" x 7" ann. 12/25/85 7" ~ 8071' thru 8030' PB~, Drl cmt 12/26/85 10.1 ppg NaC1/NaBr Fin bleed'g press off 10-3/4" x 7". ~ & tst BOPE Co 3500 psi. RIH w/DP, pull BP, POOH, LD s~e. RIH w/bit & JB, tag top of cmt ~ 7184', drl cmo to 7250', drl retnr ~ 7250'. DO 1st & 2nd EZSV to 7321' POH. RIH, drl junk on top of cmt, drl hard cmt The above Is correct Signature For form preparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pegee 88 and 87. ITitle Drilling Superintendent ARCO Oil and Gas Company Daily wei'l-'History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code State North Slope Borough Alaska Well no. ADL 25639 1H-4 District ICounty or Parish I Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Tit[e AFE AK0570 I · Recompletion WWS #1 API 50-029-20770 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Workover 12/18/85 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 12/27/85 12/28/85 thru 12/30/85 I otal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our l Prior status if a W.O. 1100 hrs. I 1730 hrs. 7" @ 8071' 8030' PBTD, Perf 10.1 ppg NaCl/NaBr Fin drlg cmt, tag btm EZSV @ 7473', CBU, POH. PU RTTS, RIH to 7400', set RTTS, tst sqz perfs to 2000 psi, POH, LD RTTS. RU Sehl, tst lubr. Rn CET log. RU & perf w/4" guns, 4 SPF, 90° phasing f/7210'-7242'. 7" @ 8071' 8030' PBTD, RR 10.1 ppg NaCl/NaBr Fin perf'g w/4" gun, 4 SPF, 90° phasing f/7180'-7210'. Perf w/5" gun, 12 SPF, 120~ phasing f/7291'-7324'. RD Schl. RIH, drl EZSV. Cont RIH to PBTD, CBU, POOH. RIH w/scrprs, CBU, filter brine, POE, LD DP. Make gage ring/JB run. RIH w/1-B Pkr on WL, set @ 7370' WLM, RD Schl. RU & rn 237 its, 3½", 9.2#, J055 BTC AB Mod tbg w/TT @ 7408'. Tst tbg, set pkrs, shear SBR, re-lnd tbg. Tst SSSV. ND BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. Tst orifice vlv. Set BPV. @ 1730 hrs, 12/29/85. HB-1 pkr @7022' & 7282', "D" Nipple @7397', lB Pkr @7384' @1798' , SSSV Classifications (oil, gas, etc.) O-Il New TO PB Depth 8030' PBTD Date K nd of r g 12/29/85 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas T~st time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR I Gravity Allowable Effective date corrected The above is correct Signature For form preparation an~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office B,,.~,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 30, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1A-7 1H-4 1H-8 If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L43 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 0TL AND GAS CONSERVATION COWlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L LXI~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of Well Surface: 911' FNL, 1140' FEL, Sec,33, T12N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 85 ' 12. I 6. Lease Designation and Serial No. ADL 25639 ALK 464 7. Permit No. 82-103 8. APl Number 50-- 029-20770 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment Other 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). Accepted rig ~ 1100 hrs, 12/18/85. Killed well. ND tree. NU BOPE & tested to 3000 psi - ok. Cut tubing ~ 7020' & POH. (Changed couplings from BTC to AB-MOD BTC.) Fished & recovered pkr. Ran CET f/7527' - 4800'. Perf'd f/7442' - 7444'. Squeezed w/150 sx Class G. Perf'd 7286' - 7288'; squeezed w/150 sx Class G. Tstd cs¢ to 3500 psi - ok. Tstd squeeze perfs to 2000 psi - ok. Perf'd the following intervals w/4 spf, 90° phasing: 7235' - 7242' 7225' - 7235' 7210' - 7225' 7180' - 7210' 7291' - 7324 Ran 3-1/2" completion assy w/SSSV ~ 1798', pkrs @ 7022', 7282', & 7384', & tail ~ 7408'. Tstd tbg & set pkr. ND BOPE. NU tree & tstd. Set BPV. Secured well & released rig ~ 1730 hfs, 12/29/85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ u~e )~lt_.~ Title Associate Engineer The space belov~or Commission s Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 RI0 CRU13/$N04 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells' 1A-7 2H-6 : 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 1H-4 2H-9 3A-16 3F-15 4-24 16-20 L3-/S 1H-8 2X-8 3F-11 3J-10 4-27 L2-2! If you have any Questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 ]986 Oil & Gas Cons. STATE Of ALASKA ALASKA GAS CONSERVATION CQI ISSlON MONTHLY REPORT OF DRILLING' AND WORK )VER OPERATIONS · Drilling well [] Workover operationXIX1 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-103 3. Address P, 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 911' FNL, 11~,0' FEL, Sec.33, T12N~ R10E, UN 5. Elevation in feet (indicate KB, DF; etc.) 6. Lease Designation and Serial No. 85' RKB ^DL 25639 ALK /+6/+ 8. APl Number 50-- 029-20770 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1H-4 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of December ,19 85 12. Depthatend of month, footagedrilled, fishingjobs, directionaldrillingproblems, spud date, remarks Accepted rig ~ 1100 hfs, 12/18/85. Killed well. ND tree. NU BOPE & tstd. Cut tbg. Pulled 3-1/2" tbg. Fished for pkr; recovered. Ran CRT. Perf'd f/74~2' - 7~'. Squeezed w/150 sx Class G. Perf'd f/7286' 7288', Squeezed~w/150 sx Class G. Drld cmt to 7~73'. Ran CET. Perf'd well. Set pkr & taflpipe assy. Ran 3-1/2" completion assy, ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured well & RR ~ 1730 hfs, 1.2/29/85. ~ : 13. Casing or liner rgn and quantities of cement, results of pressure tests 3-1/2" tbg, SSSV ~ 1798', HB-1 pkr ~ 7022', 1-B pkr 14. Coringresumeand briefdescription None 15. Logs run and depth where run CRT f/7527' - ~800' 16. DST data, perforating data, shows of H2S, miscellaneous data 7180' - 7242' w/4 spf, 90° phasing 7324' - 7291' w/5 spf, 120° phasing RECEIVED 17. I hereby certify that the foregoing is true and correct tc the best of my knowledge. SIGNED (~/~7)/IL/ ,~ TITLE Associate Engineer DATE J'/~'~ NOTE--Report this form ~s re~ aired 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 TENP3/NR16 Submit in duplicate STATE OF ALASKA ALASKAt:)'iL AND GAS CONSERVATION COwrMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well Surface: 99510 911' FNL, .1140' FF..L, Sec.5.~ TI~N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 85' I 6. Lease Designation and Serial No. ADL 25639 ALK 464 12. 7. Permit No. 82-103 8. APl Number 50-- 029-20770 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1 H-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~, Abandon [] Stimulation Repair Well ~ Change Plans [] Repairs Made Pull Tubing ~ Other ~ Pulling Tubing Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 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). ARCO Alaska, Inc., proposes to convert well 1H-4 to a selective single completion. The procedure will be as fol 1 ows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single~ 5. After the rig is released, an acid and/or frae job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally~-ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. RECEIVED Estimated Start: December 5, 1985 :~:~as~a 0il & Gas Cons. C0mmissi0~ Anch0ra~e 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ ~ Title Associate Engineer Signed The space below foryo"mmission use- - ~ate II-Zt "~'<' Conditions of Approval, if any: Approved by COMMISSIONER Approvea By Order of the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1 ~0 (JLQ) SN/11b~ and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Offic~ ,x 100360 ' Anchorage?-~laska 99510-0360 Telephone 907 276 1215 · I::: !iE C ;!i: I I::"f' A N D A. I"? (".' q lc; I... A S I< A, I N C:, ,. A T '1" N ' R Iii: C 0 R D ,'.j;~'-' ..... i I::. ..... I",' I,. / A 'i" 0 .... i i i '.5' B F:'.,O~ BOX i 007'.:60 ANCHC)F:eA[;E:, AK 99"?i0 ! ;!;'TA'F I (.; B~'IF' ~'~ ..... / q'' · A. ' ,.', L)I::., ,.., T ~.l'f ]: C aTATIC BHF:' ,S' 0 F... ,/,'S.; T A T ]: ..P.. STAT.T. C ).-'.',' !"1 I:' .S' 0 Ii!: / ,? T A "[' ]: C ,S"T iq. T :[ C !".',' H P sot: ." ~'r,':'.-, T ]: '-' .. ~; · ,? 1' A 'T .[ .... B H F' I) A T A DATA I) A '¥' A DA'f'A D A T'A DATA BI"IP DA"rA B I--I F' DATA BI..IP P F:'., 'FA ':"~.IF' DATA I::' 0 I... I....O 141 N 6;- C (.3 F:' Y 'C' SAND :1: 'F E M ,S'., F:' L_ E': A ,S' El A C I< N 0 W L. E D [-;. I":': OF Ti-II S... TF;.'.AN."';'HI T'f'AI.., F:EC.:E ! PT B., :.? !.! i:;: r:: :!: Ii..-. R C :..I I..'.: V 1.';.: (3 N I:: & H D I:;..' I I.. !... :[ f",! (::, 'W,. F' A S. I-'1!!-" R L.... ...." 0 I-.I N S T [) i",.' .r-...'. X X 0 H fi {) ...r'.',' :r !.. P I--1 :[ I_ L I F';:T (31 I... NS!".: [.'.L. EF.:I< J,. RATHHELL ARCO Alaska, Inc, is a Subsidiary of AtlanlicRichlieldCompany ARCO Alaska, inc. Post Offic~ ~× 360 Anchor~ge,~'~laska 99510 Telephone 907 277 5637 RETUR_N TO: Date: 2/05/85 Transmittal No: 4824 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P~O. Box 100360 . ~An~_horage, AK 99510 _T_ra~ns_m~itted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 Gearhart ---2Z-6/ 9/03/84 Otis 2X-6~' 8/16/84 Gearhart --- 2X-4/ 8/16/84 Camco ---2X-iF" 8/16,19/84 Camco --2V-5F'~ 8/16,19/84 Dresser ~2V-2~" 9/07/84 Otis ~2F-9J' 8/28/84 Otis / · ~--2F-8W~ 10/08/84 Camco --2F-7/ 10/07/84 Otis --2B-15/ 9/03/84 Otis ~2C-5 /~ 8/17/84 Otis .--1Y-i3/ 8/i6/84 Dresser ~lY-9~z 9/07/84 Camco ~--lY-5/ 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6.~ '8/25/84 Otis ~lH-4~ 9/04/84 Otis ~1F-12¥ 9/09/84 Otis -~lF-9~ 8/17,18/84 Camco <-lF-8z 8/16 17/84 Camco ~lE-8~/ 10/12/84 Otis ~-lD-5~ 10/07/84 Camco ~iA-4w~ 9/02/84 Otis ---1A--3~ 9/02/84 Otis Receipt Acknowledged: "~YP 232" "HP 233" 9/06/84 "SBI-IP" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure Falloff" DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Ratkmell Well Files ARCO Alaska, In,~ Post Offic~....~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4992 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. STATIC BHP REPORTS WSW #24 12/29,28/84 1H-4 '11/25/84 1C-4 12/05/84 lB-2 12/03/84 1D-8 12/06/84 /cat SEQUENCE OF EVENTS Static BHp 12/29,28/84 SBHP 11/25/84. Static 11/26/84 Statid BP3 12/05/84 Static BHP 12/03/84 Static BHP 12/06/84 Receipt Acknowledged: · B. Currier BPAE Chevron D&M · Drilling Geology DISTRIBUTION Date: W. Pasher 'G. Phillips Sohio Mobil Phillips Oil Union NSK Ops. J. Rathmell Well Files ARCO Aleska. Inc is a subsidiary of Atlanticqich~ieldCompany ARCO Alaska, Inc. Post Offic ox 360 Anchorage,'T"'Alaska 99510 Telephone 907 277 5637 Date: 12/20/84 · . Transmittal No: 4926 P,.ETURN TO: ' ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box.lO0360 T~r~n~~chorage, _~ 99510 itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 'P u su :v S : -- Camco iG-10 12/05/84 " 1F-9 . 12/04/84 " 1F-8 11/27, 28/84 " 1H-4 11/25/84' /cat Receipt Acknowledged: DISTRIBUTION Date: B. Currier BPAE Chevron D&M D~illing . Geology Mobil NSK Ops. W. ?asher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO A;ask,,.t, Inc. iS a subsidiary of Ah~nhcl=ichfieldCompa.y ARCO Alaska, Inc. ,, · r.) · ,- ; ;..__..~A:a~ k:~ 9~.f iC . .. ,. ~c-r.~ 9.0 -'77 5~.37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ~~aTransmitted herewith are the following items. nd return one signed copy of this transmittal. Please acknowledge receipt · PBU .SUR~S/PRESSURE ANALYSIS /lA-2 5/11,12/84 Torque Torn (Pressure & Temp Surveys) ................ --iA-6-... 7/06/84 Camco /1B-il" /lA-10 /lC-1 /1C-6 /%G-10- /1G-11 21G-2 '" l =8A ~-4 ~lY-5 ~lY-7 7/10,12/84 Camco 5/10/84 Otis 12/17/83 Otis Static 8/04/84 Otis 12/2%/83 Camco 12/23/83 Camco 8/11/84 Otis 5/21/84 Camco 5/13,14/84Torque Turn (Pressure & Temp Surveys) 6/26/84 Camco Static 6/30/84 CanrJ~ 5/26/83 Camco I-]P 8/11/84 Camco 6/28/84 Camco ·. 7/07/84 Otis 12/27/83..Otis Static 12/14/83 Otis 12/15/83 Otis 7/03/84 Otis 4/10/84 Camco Receip~ac~nowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D C. R. Smith Sohio Union Well Files Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: · . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~2B-~/' 5/28/84 2~Zi 11/09/83 " 2C-2 11/09/83 2C-6 11/08/83 2C7~7 11/08/83 ~2C.2'7 4/18/83 i~Z~',: 4/24/83 QC~47: 4/22/83 ~2e? 4/30/83 2_V-~3 4/28/84 "C2~> 4/29/84 [2v-3.:, 5/04/84 ~:5 5/06/84 2x-5 8/12/84 · ,.. 3C-6 Y/19/84 3C-6 5/17/84 .. Otis Lynes - -Lynes Lynes Lynes Camco Camco Camco Otis C~o Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis Camco Dresser Dresser Mini Drawdown & Buildup Survey /cat Receipt Acknowledged: Date: DISTRIBUTION B. Adams F.G. Baker P. Baxter BPD£ Chevron D & M W.V. Pasher C.R. Smith Drilling G. Phillips !~- ...... ,.~ ~ Phillips Oil Sohio Geology Mobil J.J. Rathmell Union R & D Well ~iles NSK Operations ARCO Alaska, Inc:. Post Office I~'~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Harch 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 1H-Pad Wells 1-8 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG6/L20'tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany LE'3END B, NOTES ",5"**'~4 PROTRACTED SECTION CORNER. ) FUTURE WELL LOC&TIONS. PERMANENT SURVEY lOCATION MONUMENTS. ,, ~ EXISTING WELt.HEAD FOUND THIS SURVEY. ~'~ a AS- BUILT SPOT ELEVATIOH. PAD DIMENSIONS SHOWN ARE MEANS TAKEN FROM AS-BUILT SURVEY NOTES. 2 ELEVATIONS SHOWN ARE REPRESENTATIVE ELEV- ATIONS TAKEN FROM AS-BUILT SURVEY NOTES. S. EkEVATIOHS ARE DA"3ED ON SOHIO-BP VERTICAL OATUM. 4 ALL COORDINATES SHOWN ARE ALASKA STATE PI. 4~NE COORDINATE 9YSTEM, ZONE 4. 5. SECTIO~ CORNERS SHOWN ARE BASED ON ALASKA PROTRACTION SYSTEM, THE ENTIRE AREA LIES WITHIN TI2N, RIOE, UMIAT MERIDIAN, 4d. ASKA. ALL AZIMUTH SHOWN &RE ALASKA STATE PL.&NE GRID AZIMU]H 7 ALL DiSTANC( SHOWN ARE TRUE DISTANCES N;5, Bel,3~O.440 J '. ~ .'..~. ,~.,o,~ '". " AS-BUILT DRILL SITE "I-H" ARCO Alosk , Inc. ~RCTIC ~vE~ING~ ANCH~A~[ . ALAtKA OAT(' &~L IS, INZ ii ,c~,, ,'. ~' · ~' NSK-3.2.1-1 · /+''° , ''° ' ''° + '~ ~ ~ ! / ~/ ,~-, '"-' '"? .5- ~* ~'-= * '-='.5o.o-; ........... ~u~ '~ -- - I~11'; , CONOUCTOR HOLE LOCATION5 WITHIN SECTION ~ELL I GEODETIC O~)nOINATE~ Nit. I LAIITUUE· LONGITUDE " I TO' 21' 2&B32'I 149' 3§' SI.SI," - ~"-i-Fo- 2,' '~ -~-%; ~i~ ~' i,,- .' ~,.o.' ·, j ,o- ;,' ~ ~9,"I ,.' ~s' ~.,;,' '~:! ,o-,' ;o,~1 ,.,-~' ~,.,,' ~ ,o-~,';Lz.,] ,~,'~ o,.",' ~ ,o'.' ;z,~:I ,~'~' o,.~,,' FNL . FE L "529I OO~ 549 I ?96 760 I TBB e6e I ~11 I 1140 ;~' I'"' ~ ri I 11~6 ,'ll~,h I ,, 33 .. Bill Sheffield Governor ALASKA OIL AND GAS CONSERVATION COMMISSION Permit No. _,~ c'~-- //~,_~ 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501';-3192 TEL EPHONE (907) 279.-'- 1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well ~.~hich our records indicated was completed _/9.~-~.{-._~ 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. Sincerely, Chairman I<UPA .q~JK F-3',Ui NEERi KG ll-<&~?, I -FI-AL #~ D. W. Bose/Shelby J. Matthews ' DATE: ¢_ '75o :~ ... 3.7 0¢.~ ,'/ELL Transmitted herewith are the folicmincj- PLEASE FDTE: BL- BLUELINE, S- SEPIA, F- _L p~ !~ LEASE P'ER-P,N RECEi PT TO: /~Z~'.'.'.'.'.'.'.'.'~) ALASKA, lb,E:. ::'-:' :' . :::~.:: .... ' AT]N: SI-lEi_BY J. /V~'l-l-[l~'.,5 - ATO/1115-B P. O, BOX 100360 AI~E]-IOP,/~E, AK. 99510 SCHLUMBE~...._,...-~ OFFSHORE SERVICES 5000 GULF FREEWAY, P.O. BOX 2175 HOUSTON, TEXAS 77001, (713) 928-4000 PLEASE REPLY TO 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 February 16, 1983 Dear Customer, We have discovered an error in the Library Tapes for the following well: COMPANY NAME: ATLANTIC RICHFIELD COMPANY JOB NUMBER: 65324 Enclosed are replacement* tapes for the above listed well. Please destroy the original tapes you have already received and replace with these enclosed. We apologize for any in- convenience this has caused. Thank you, S.E. K Log Analyst *To splice repeat section onto bottom of main log run. SEK:smm cc:distribution A DIVISION OF SCHLUMBERGER LIMITED TO: William VanAlen F~CM: D. ~Xansmitted herewith are the follcw/ng: PLF_ASENOTE: BL-~, S-SEPIA, F-F/IR~, ioC_PH~.. -_ -7~ 0 i-~''' ' -. A_~: ~ - AFA/311 Alaska 0ii a 6as Coa~_ (;oi~m~issior~ ~~, ~. 99510-- '~- . ARCO Alaska, Inc. Post Office F 360 Anchorage, ~,...~ka 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E-14 1H-8 1E-15 Very truly yours, $ '~ ' Area Operations Engineer slz Attachment cc: L. M. Sellers E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA,.,.._,, AND GAS CONSERVATION C .~..~.. ¢IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] sERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Znc. 82-103 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20770 4. bocation of well at surface 9i'i; FNL, ii40i FEL, Eec ~, liZN, N1Ub, UN 9. Unit or Lease Name Kuparuk River At Top Producing lnterval 1200' FNL, 1576' FWL, Sec 33, T12N, R10E, UN lO. WellNumber 1H-4 At Total Depth 1036' FNL, 1094' FWL, Sec 33, T12N, RIOE, UM 11. Field and Pool Kuparuk River F±eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKBI ADL 25639 ALK 464 Kuparuk River 0il Pool 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore ]16. No, of Completions 7/9/82 7/18/82 7/23/82] N/A feetMSL] 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8086' 7082' 8030' 7035' YES~X NO[]I 1881' feetMD 1600' (approx) 22. Type Electric or Other Logs Run DTL/SP/SFL/GR/FDC/CNL/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD iAMOUNTPULLED 16" 62.5# H-40 Surf 78' 24. 274 sx AS II 10 3/4" 45.55! K-55 Surf 2191' 13 1/2" 1000 sx AS III'& 250 sx AS II 7" 26# K-55 Surf 8071' 8 3/4" 1145 sx Class G Cmt & 250 sx AS II _ 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) 7180-72/42' ' 3 1/2" 71 02' 7070' 7482-7486' w/12 SPF 7/496-7520' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVALIMD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEsT Date First Production Method of Operation (Flowing, gas lift, etc.) 7/26/82 Flowing . · . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BB'L CHOKE SIZE GAS-OIL RATIO 8/15/82 18.83 TEST PERIOD I~ 1255 :23t4 -- 9 ¢, / ¢,/z Flow Tubing Casing Pressure CALCULATED OIL-BBL .: GAS-MCF_ .. WATER-BBL OILG~AVITY-API (corr) Press. ~80 __ 24-HOUR RATE I~ 1668 -~076 ---- 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water· Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Kuparuk River Form. Base Kuparuk River Form. GEOLOGIC MARKERS MEAS. DEPTH 7144' 31. LiST OF ATTACHMENTS TRUEVERT. DEPTH 6290' 6663' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, 7587' GOR, and time of each phase. N/A 32. hereby certify that the foregoing is true and correct to the best of my knowledge Signed ; _ , Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observatioh, 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". TO: William VanAlen ~: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: ,. P!.WASE NOTE , F- FTT~I, T- TAPE, PC- PHOTOCt)PY ARf)3 ALASKA, INC. A,,_ok~_ Oi! & Gas Cons. ATIN: LORIE L. JOHNSON - AFA/311 A-~.chora,q~ P. O. -BOX-360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TO: William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted her~qith are the following: P!.FASE NOTE: BL -.BLUELINE, S - SEPIA, F _ FILM, T - TAPE, - PHC~PY? ARCO ALASKA, INC. A%TN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 TO: William VanAlen FRCM: DATE: F/~/Y ,~ WE'd,T, NA~m: D. W. Bose/Lorie L. Johnson Transmitted herewith are the fo!lc~ing: ?I:I*~E NK)2~: BI',-.BIJ3EL~,rE~ S- S~PI.A~ F- FIJ./~I~ 2'- T32:~E~ (7- o ~~, :I:~C. ATIN: LORIE L. JOHNSON - AF.z~i/311 0il & ~%.'; (:,.,;-~.. C,.,,,~,~,[.~,.:ion P. O.-BOX'360 ANCHORAGE, AK. 99510 KUPARUK ENGINEERING TO: TRANSMITTAL DATE: ~//~-/S SL WELL NAME: m. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIPT ACKNOWLEDGED: ~~LEASE RETURN RECEIPT TO: DATE: .~::, ~:' , ,,.!!~ .'. ARCO ALASKA, INC. "'" ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. Post Office B;5"~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 11, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' ~ 1H-4 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyro- scopic survey for Kuparuk Well 1H-4. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. Van Duse.n District Drilling Engineer PAV/JG' llm Enclosures RECEIVED AUG 1 2 982 AI.~ska 0il & Gas Cor~s CommiSsion 4nchorag'~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA t~ ~ ! ~ ! II~ il~ [, ALASK,~,.__,,,,..r;L AND GAS CONSERVATION (..r,...,..~M ISSION WELL COMPLETION OR RECOMP'LF.,,TION REPORT AND LOO 1. Status of Well OIL [~'- GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-103 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 5o- 029-20770 Classification of Service Well 4. Location of well at surface 911' FNL, 1140' FEL, Sec. 33, .212N, Ri0E, UM ]LOCATIONS At Top Producing Interval / VERIFIED AtTotalDepth1195' FNL, 1558' FWL, Sec. 33, T12N, R10E, UM ~S~r~.__ ~ 1036' FNL, 1094' FWL, Sec. 33 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. 85' RKB ~ ADL 25639 ALK.464 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1H-4 I 1. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 07/09/82 07/18/82 I' 07/2.~/82 I N/A feetMSL I 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD)I 19. Directional Survey [ 20. Depth where SSSV set I 21'Thickness°fpermafr°st / I 8086'MD, 7082'TVI) 8030'lt©,T035_'.TVI] YES I~ NO [] 188:] feet MD I 22. Type Electric or Other Logs Run yro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 24" 274 sx AS II 45.5# K-SS 1000 sx AS III & 250 sx AS II 10-3/4" 7'~ 26.0# K-SS SETTING DEPTH MD TOP BOTTOM Surf 78 ' Surf 2191 ' Surf 8071 ' 13-1/2" 8-3/4" 1145 sx Class G & 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 7180'-7242' 7482'-7486' 7496'-7520' 12 spf 25. SIZE 3-1/2" 26. 250 sx AS II TUBING RECORD DEPTH SET (MD) I PACKER SET (MD) 7180' I 7070' ACID, FRACTURE, CEMENT SQUEEZE, ETc. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/^ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested Flow Tubing Press. Casing Pressure 28. tPRODUCTION FORI TEST PERIOD I~ CALCULATED I~ 24-HOUR RATE '-~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None /4U6 i 2 Alaska 0il & Gas Cons. Commissiot~ Anc.horage Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 30. FORMATION TESTS . 7179' 6319' 7322' ,I 6440' 7469' ~, 6564' 7587' il 6663' Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge - T,,.e Sr. Drilling EIlg~Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ' Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 KUPARUK 1H-4 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1230 hrs, 07/09/82. Drld 13-1/2" to 2212' Ran 51 jts 10-3/4" 45 5#/ft K-55 BTC csg w/shoe @ 2191' Cmtd 10-3/4" csg w/1000 sx AS III & 250 .sx AS II. ND BOPE. Performed 100 sx AS II top job. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 2000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new hole. Tstd form to 12.5 ppg EMW - ok. Change over XC Polymer mud. Drld 8-3/4" hole to 7838'. Ran DIL/SP/SFL/GR/FDC/CNL/Cal f/7838'-2191'. Cont drlg 8-3/4" hole to 8086' TD (07/18/82). Ran 174 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 8071'. Cmtd 7" csg w/1145 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS II, & 97 bbls Arctic Pack. Displace well to NaC1/NaBr. Ran gyro. Ran CBL. Drld cmt. Ran CBL. Drld cmt, FC & more cmt to 8030' PBTD. Ran 3-1/2" cOmpletion assy w/tail @ 7180' & pkr @ 7070' SSSV @ 1881' GLMs @ 2433' 4271' 5595' 6355' · · , , .~ , 6727' & 7010'. Bottom of Geo-Vann guns @ 7524'; spaced to perf f/7180'- 7242' 7482'-7486' & 7496' -7520' Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel· Set packer. Tstd tbg to 3000 psi for 15 min - lost 200 psi. Tstd 7" csg to 1500 psi - ok. Press. ann to 100 psi & press, tbg to 3000~ psi. Closed SSSV· Bled tbg to 500 psi to check SSSV - held ok. Open SSSV & press· ann to 1000 psi. Dropped firing bar - guns fired ok. Perf'd w/12 spf. Flow well to test tanks. Shut in well. Dropped tbg release ball. Closed SSSV. Instld BPV. Press 10-3/4" x 7" ann to 1000 psi & monitor for 1 hr - ok. Secured well & released rig @ 0500 hrs, 07/23/82. A~a~!(aOil & Gas Cons. ~: ' ~ uO~f~lS~lO~ Ant:borage F:'AGE 1. ,,., ,." 1 9., 1 - '" ...... '.-./ :::, .,::~ ~,. ~.,~ ..................... i ................................. ::::x::::~::: 8:::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ARC(] ALA:E;KA., INC, ' ........ ~ ............ ~:,~,'.R~:~ ~,"'"~"":~:"~'N":'"ii~'' ~9 '~'"'~ ......................................................................................................................... ~:D1~:~'~':t ..... ~: :..:~ ......... ~ ....... ; ............................ i .................................. . .=, (..) () (2 'i.':' 9::::~ '::[ /:., 9 .... '""' ''"'':''' t':.,, 9 '"' .,~,"':' :;' ':D. ,.,~. 1 .- .,:, ~-' ~; ' '''''~' ~,' W 2 . . .....o 1;=''=..,.., 87 W :l 4¢)'""':,o :"2:100 .... 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' OU.:, '~ ~' 7 ._ ,::, 7 /:,662.9 6577. ~ , · L . :,, ::, :,; :: ::: ::: :, :;: ::.::: ::::::::::::: ::;:. ::::: :,, ::; ::::::: ::::: :;:;;:;:::::;:: :::;:::; :::::::::::::: ::;:;:: ::::;:::: :: :;:;;: :: :::;;:::::,:: :;:::;::::;;:;: :;: :,. ;::: ::;: :: :;: :::;::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::: mx :: xm~, .:.tx_x:__+:.-b-+--~-x- + .: :+x+:, ;/ ) FRFiM LJ[NEAR F[XTRAF:'ClL(]~T~[(.]N BEL. O~ I"ll"i[J~'~F'l:!~$T ?"'";TATIClN. 2) C:()MF::'LITli:_-~R F:'ROC'iF'iAM '- ::'i; F::' L:.' J:;; F::~ Y :~i;l_iN "I"HF;:EE I:~Ii"IENSIFd~iAL RADIt.15S OF: C:IJF:;~VATURE. DATE OF' SLIRVEY dULY 19, 1982 C 0 H I:::' L.I"~"A T ~ 0 N D A T E ,_IULY 20, !'782 dOB NUMBER BOSS-160:38 C ARCO Alaska, Inc. Our Boss Gyroscopic Job No. Boss-16088 Well: #lH-4 (SEC33 Kuparuk Field North Slope, Alaska Survey Date: July 19, 'Operator: John Coogle Scale: 1" = 500' ~ I -3500. O0 · .~.,:,, . TRUE ',¥'?:,.. ., :, -, ;,,.!.,.,,i,,,:',,t .~,,,,. ,, , >;.~!~, ~ Surface Location ·-,,~.' "' (911~ 1140~) ":, ~j ,, , , _ ~ 3048.61' 0 SS~:~'3B'~ ...... .~.. ,.',.l:?.. 5..'. ,' · ~,,~...2 - ~. . . ~ ~,~ . ~... v , . NORTH --500. O0 ARCO Alaska, Inc, Our Boss Oyr~pic Survey Job No. Boss-16088 Well: #1H-4 (SEC33 T12N R10E) Kuparuk Field North SLope,' Alaska Survey Date: 'July 19, 1982 Operator: John-Coogle Scale: 1" = 2000' ' 4000. 00 6000.00 S87° 38'W ~ 8086 8000.00 ! 2000.00 ! 4000. O0 VEnTICFtL PROJECTION Suggested form to be inserted in each "Active" well folder to c~eck for timely compliance with Our regulations. ' Operator, We~ Name and Number Reports and Materials to be received by: ~_r ~ ~- ~.~ Date Required Date Received Remarks -- ...,Cc~pleti°n Report Yes Well History Yes C/ Core ~scription / Registered S~oyPla~L~ -~:~..~ r. , ~; -... ,~ -._ .,.~ ... [ " Inclination Surety /~ ~ .. , Dire~ional ~ey ~3 ..... P ,Drill St~., Test Re~s /~ Z?~ ~> '~/ , Alaska~ Inc. Post Office Bc ;0 Anchorage, Alaska 99510 Telephone 907 277 5637 August 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for July on these drill sites- 2-25 13-25 18-3 2-26 13-30 1E-15 6-17 13-33 1H-3 6-18 14-21 1H-4 6-19 18-2 Also enclosed are three subsequent sundry reports for KUparuk 1H-5 and completion reports for: 13-21 15-1~ 13-24 18-1 13-26 1E-14 14-17 1H-5 14-22 The gyroscopic survey for DS 2-22 needs to be reran; a com- pletion report for this well will be submitted when the approved survey is received. Sincerely, P. A. VanDusen Regional Drilling Engineer PAV/JG' sm Enclosures RECEIVED AUG 1 O19B~ 0~ & Gas cons. Commlssio~ Anc~0rag~ GRU1/L61 ARCO Al,~s~a i,-,c ~q ,~ ,.~:[)~,¢',ia~¥ of Al:,tnli¢tlic!:fleld,r-'o'~ 13,:!~¥· STATE OF ALASKA ' M--NTHLYO ALASKA GAS CONSERVATION CC,_ /IISSION REI ORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well E~ Workover operation [] 2. Name of operator ARCO Alaska~ Inc. 3. Address P. O. Box 4. Location of Well at surface 911 ' FNL, 360, Anchorage, AK 99510 1140' FEL, Sec. 33,.T12N, R10E, UM 5. Elevation in feet (indicate KB, DF, etco) 85' RKB 6. Lease Designation and Serial No. ADL 25639 ALK 464 7. Permit No. 82-103 8. APl Number 50- 02.9-20770 9. Unit or Lease Name lO. v~&t-Na.---7 1H-4 - 11. Field and Pool Kuparuk River Fie'Id -t(uparuk River Oil Pool For the Month of. July ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1230 hrs, 07/0'9/82. Drld i3-'1/2" hole to '2212"; ran, cmtd & tstd 10-.3/4" csg. Drld 8-3/4" hole to 7838'; ran logs; continued' drlg to 808'6' TD. Ran, cmtd, & tstd 7" csg. Ran gyro & CBL. Ran' 3-'1/2" comp1 :assy. Perf'd well.' SecUred well & released rig @ 0500 hrs, 07/23/82. See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#, H-40, conductor set @ 78'. Ontd w/274 .sX AS II. 10-3/4", 45.5#, K-55, BTC csg W/shoe @ 2191'.: Cmtd w/10'00 sX AS III & 250 sx AS II. 7", 26.0#, !(-55, BTC csg w/shoe @ 8071'. Qntd W/li45sx Class G. See Drilling' ItistOTy 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/SFL/GR/FDC/CNL/Cal CBL f/7838'-2191' ,16. DST data, perforating data, shows of H2S, miscellaneous data 7180'-7242' 12 spf 7482'-7486' 12 spf 7496'-7520' 12 spf AUG i o 1982 Aiaska 0il & Gas Cons, Comrnissior~ Anch0raqe 17. I hereby certify that the fqregoing is true and correct to the best of my knowledge. NOTE--Rep¢ o~tt~is l~rm is required for each calendar month, regardless of the status of operations, and must be Filed ih,duplicate with the Alaska Oil and Gas~onservation Commission by the 15th of the succeedin9 month, unless otherwise directed. Form 10-404 Submit in duplicate KUPARUK 1H-4' DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1230 hrs, 07/09/82. Drld 13-1/2" to 2212'. Ran 5i jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2191'. Cmtd 10-3/4" csg w/1000 sx AS III & 250 sx AS II. ND BOPE. Performed 100 sx AS II top job. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 2000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new hole. Tstd form to 12.5 ppg~ EMW - ok. Change over XC Polymer mud. Drld 8-3/4" hole to 7838'. Ran DIL/SP/SFL/GR/FDC/CNL/Cal f/7838'-2191'. Cont drlg 8-3/4" hole to 8086' TD (07/18/82). Ran 174 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 8071'. Cmtd 7" csg w/1145 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS II, & 97 bbls Arctic Pack. Displace well to NaC1/NaBr. Ran gyro. Ran CBL. Drld cmt. Ran CBL. Drld cmt, FC & more cmt to 8030' PBTD. Ran 3-1/2" completion assy w/tail @ 7180' & pkr @ 7070'. SSSV @ 1881'. GLMs @ 2433', 4271', 5595', 6355', 6727' & 7010'. Bottom of Geo-Vann guns @ 7524'; spaced to perf f/7180'- 7242', 7482'-7486' & 7496'-7520'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 ps'i - ok. Disp well to diesel. Set packer. Tstd tbg to 3000 psi for 15 min - lost 200 psi. Tstd 7" csg to 1500 psi - ok. Press. ann to 100 psi & press, tbg to 3000' psi. Closed SSSV. Bled tbg to 500 psi to check SSSV - held ok. Open SSSV & press, ann to 1000 psi. Dropped firing bar - guns fired ok. Perf'd w/12 spf. Flow well to test tanks. Shut in well. Dropped tbg release ball. Closed SSSV. Instld BPV. Press 10--3/4" x 7" ann to.1000 psi & monitor for 1 hr - ok. Secured well & released rig @ 0500 hrs, 07/23/82. Alaska Oil & Gas Cons. Co~nrni~,,bn /~nchora9e ..... KUPARUK ENGINEERING TO: TRANSMITTAL D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FII~, T~- TAPE~ PLEASE RETURN RECEIPT T-' /-- AiaskaOJl & (.]~,s Ooris. C. omrrli$~ort O: . - ARCO ALASKA., INC. ~nch0ra~0 ATTN: LORIE L. J.OHNSON - AFA/~ll P. O. BOX 360 ANCHORAGE, AK 99510 MEMORANDUM TO: THRU. - FROM: Staze of Alaska ALASFA 0~. A~D GAS cONSERVATION COMMISSION C. V~ ~t~erton DATE: July 12, 1982 chai~n--,J / y~/ FILE NO: 108A/i Lonnie C. Smith7~j'D~j '- Commi ssione r Edgar W. Sipple, Jr.~__ Petroleum Inspector TELEPHONE NO: SUBJECT: W~tness BOPE Test on ARCO's Kuparuk l-H-4 Sec. 33, Ti2N, R10E, MUPJ Permit No. 82-103 Parker Drilling Co. Rig No. 141 Saturday, Ju_ly 10.,...1982 - I left Anchorage via Alaska Airlines for Prudhoe Bay. I arrived at ARCO's Kuparuk l-H-4 at 5:30 p.m. Parker Drilling was in the process ce~nting the casing. Sunday,~ July 11, 1982. - The BOPE test commenced at 5:10 a.m. and ~,~s concluded at 6:25 a~m. There were no failures. I filled out the A.O.G.C.C. BOPE test report which is attached.. In summary, I witnessed the BOPE test on ARCO's Kuparuk l-M-4 Parker Drilling Rig No. 141. There ~re no failures, all 'systems tested satisfactorily. 02~001A (Rev. 10/79) STALE OF 'ALASKA £ CAS CO[]SERVA'r'.[~ ': ~ ,..:CMt, iISS~i(~N B.O.P.E. Ins'pe~tion R%~rt Location: Sec ~il linq ~n~a~or ~tion, ~neral Wel 1 Sign ~ Cenera 1 Ho~e~ing ~ese~e pit_ BOPE stack Pipe Blind l~am$. ~.- unoKe Line Valves Test Pressure Date .A~U?J~'_I.A_~R SYSTEM ~'11' CJ~a rgc Pres sure_ Pressure After Closure Pu~l) incr. clos. pres. 200 psig Results: Failures - ~'~ Repair or Replac~nent of failed equipment to be' made within.--~-- days ~nd Inspector/Ccmmi~ion office notified. Remarks: .-/--~ ~ psig psig. / rain/ sec. Full Chalxje Pressure Attained:.' ~_min~ sec. Kelly and FlOr Safe~ Valves . ~nr Kell]~O k Test ~es~e_ Choke ~nifold ~ Test ~essure No. flanges,.., 7 ~ I~draui~l ly operate, choke b±stribuE ion orig. - cc - Operator cc - SUpervisor Ins~pcto~ ~;~ ~LL July 2, 1982 f,:~r. Jeffrey [~. iiewin Senior Drilling Engineer ABCO Alaska, Inc. P. O. 'Box 360 Anchorage, Alaska 99510 Re: ~uparuk River Unit 1H-4 ARC~ ^laska, Inc. Permit No. 82-10 Sur. Loc. 9Ii'FNL, Ii40'FEL, See. 33, T12N, R10E, ~tmhole Loc. l157'-r~NL, 819'F~, Sec. 33, TI2N, Dear ~r. Kewin: Enclosed is the approved revised application for ~it t° drill the above referenced well. The provisions of tt~e cover letter, dated June 29', t9~2, accompanying the original approved permit are in effect for this revision. Very truly, yours, ..._ /, ? ..'./ ~';" :://-~-> .- , :.>"f /. :..' :;,d:.-',,/'",-. .>' . \ / / .'. ,, ..' -..- . . C. V. Chattertoni~Y ORDEr{ .G~ THE COi~MISSiON Chai rman o f Alaska Oil and ~as ~nse~ation ~ission Erie 10 sure cc: Department of Fish ~ Game, Habitat section ~/o encl. Department of ~i~nvironm~ental Conservation w/o enel. CVC: be ARCO Alaska, Inc. Post Office B~,~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 1, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Drill Site 1H-4 Application for Permit to Drill (Revised) Dear Mr. Chatterton: Due to a change in the bottomhole location, we are resubmitting our application for Permit to Drill well 1H-4. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter'system and the BOP equipment. : Since we estimate spudding the well,on July'2, 1982,.your earli- est approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kew in Senior Drilling Engineer JBK/JG'llm Enclosures GRU1/L41 RECEIVED Alaska Oil & Gas Cons. Comrnission ^nc.borage ARCO /'~la,,J.,~ "~, ;-~ a ':u,')(id~;~ry of AllanlicRichlieidCornpany STATE Of ALASKA C,~ ALASKA AND GAS CONSERVATION ISS ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~( lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL ~] DEVELOPMENT OIL [] SINGLE ZONE [] ' DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, ]'nc. RECEIVED :3. Address P. O. Box,, 360, Anchorage, AK 99510 JUL - ! 1982 9. Unit or lease name 4. Location of well at surface 911' FNL, 1140' FEL, Sec. ~, T12N, RIOE, U~jaSka0il&GasC0ns. C0m ~i~l~a~uk Unit At top of proposed producing interval Anchorage 1-O?ffell number 1120' FNL, 1320' FWL, Sec. 3~, T12N, R10E, UN 1H-4 At total depth 11. Field and pool 1157' FNL, 819' FNL, Sec. 3~, T12N, RIOE, ,UN.. "~:-', · Kuparul< Rive]: Field 5. Elevat'ion in feet (indicate KB, DF etc.) L~' Lease designation and seC'iai no. Kuparuk River 0il Pool 85' RKB AD 25630 ALK 12, Bond information (see 20 AAC 25,025) I' ederal 'Insurance Co. Type S~ af, ewide Surety and/or number 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed :~0 Miles NW Deadhorse re,es 911' FNL at. surface feet 1H-Swell 360' surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8238'MD, 7058' TVD feet 2560 06/29/82 19. If deviated (see 20 AAC 25.050) o 20. Anticipated pressures ; . 2817 psig@80OF Surface KICK OFF POINT 2500 feet. MAXIMUM HOLE ANGLEb, 1 (see 20 AAC 25.035 (c) (;~,?::. ':' . .;~,.2a~psig@(3~..7_,~ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD J MD BOTTOM TVD (include stage data) 2~*" 16" 65t~ H-Z*O PEB 80' 30'l 30' 110" 110' + 200 cf 13-1/2 10-3/4 ~5.5~ K-55 BTC 2170' 30'~ 30' 2200'1 I I 2200' 950 sx AS III ' I 250 sx AS II 8-3/4 7" 26¢f K-55 BTC 8210' 28'Ii 28' 8238'1 7058' 1000 SX "G" cml ' I I 22. Describe proposed program: ARCO Alaska, Inc., propose8 ko drill a Kuparuk River Field developmenk well to approx 8238' MD (7058' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/~" surface pipe. It will be tested upon installation and weekly thereafter. Test .pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is .2812 psig, Pressure calculations are based on virgin reservoir pressure. 'Surface pressure calculated wi~h unexpanded gas bubble at surface including ~empera[ure effec[s. Selec[ed intervals will be logged. The well will be completed wi~h 3-1/2", 9.2~f, 3-55 bu~ress ~bg. Non-freezing fluids will be lef[ ~n unce~nen[ed annuli ~hrough [he permafros[ inkerval. Selected in[ervals will be perfora[ed within ~he Kuparuk f_.o~m+a~+on..~a.n~....re~..o~.r~d+.o..n..s..u~s¢~]..ue~m~.repor~s. A doWnhole safe~y valve will be installed Samples required Mud log required Directional Survey required APl number []YES ~iO.N 0 []YES ~NO ~YES []NO 50- ¢)?~- Permit number ' _ Appj;~yal date SEE COVER LETTER FOR OTHER REQUIREMENTS by order of the Commission Form 10401 CRA1/B1 ~ Submit in triplicate ~, 7.1.~ , : . ! : : - : i · i 13-5/8" 5000 PSI RSRRA BOP STACK Se e 16" Bradenhead 16" 20,00 PSI x 10" 3000 PSI casing head lO" 3000 PSI tubing head lO" 3000 PSI x 13-5/8" 5000 PSI . adapter spool 13-5/8" 5000 PSI 13-5/8" 5000 PSI and kill lines 13-5/8" 5000 PSI 13-5/8" 5000 PSI. 9. 13-5/8" 5000 PSI .F--q 9 ' - BLIND RRH$ 8' . (). . - ') ( ~, , , L PiPE'RRHS L] 5 -4 TBG ( ) - 4~ 10. 11. 12. pipe rams -drilling spool w/choke ": ' ~8'2 SURE I'I~tIFOLD Ah'D · JUL'~i ' DIESEL A~;D ALL VALYES ARE SET iN DRJLLII:G .. - POSI TI 0~I. - -: .'~ ~'-:::-: '-:' ..Aia~q~. Oil & Gas Cons:-C;oi-l~Ibis~r~ir STA,qDPIPE VALVES TO 3000 PSI. .: :::_:.]:->:-._ -: .- -: :" tmcborage-- 14,, TEST KELLY COCKS N~D INSIDE BOP TO 3'000 PSI .-- .... :.~-L :::_~ ..... ' ';: __ . - - __:. ___r-C ' ~ -...: - 15. RECORD TEST .. - - - . .-_ - .: - TEST FODq SIGN AND SDiD TO DRILLI;;G SUPER- . :-;~;_'-..-_- 1. FILL BOP STACK N;D N~IFOLD 14ITH ~RCTIC DIESEL." 2. D4, ECK l%~T ALL HOLD D~,¢N scRD4s ARE ~LLY RE- TP. ACTED. PP~DETE~qII;E D~TH THAT T~ PLUG ~ILL S~T AIID S~T IN ~E~.D. RU~ IN LOCK ~N SC~,IS IN HEAD. 3. ~E ~'C'(U~.R PREVEh~ER ~(D ~OKES ~ BYRES Y~!VES ~'t I'L~qlFOLD. ~. T~T ALL ~4PONENTS TO 2~ PSI ~D F~D FOR lO MINUTe. -. 5. II{C~E PR~SURE TO 1~ PSI ~(D H~ FOR lO HI'NUTES. BLEED TO ZERO PSI. 6. OP~{ '~N~R PP~V~ER ~SD CLOSE TOP S~ OF PIPE ~. 7. IN~E~E-PR~SURE TO 3~ ~I' ~D H~ FOR lO ~I~T~. 8. ~E V~V~ DIRELY U~ti OF ~O~S. ' B~ED ~(STR~4 PR~SUP~ TO ZERO PSI TO TEST VAlVe. T~T R~L~N!NG UNT~TED b~(IFOLD ~J, IF ~NY, ~I~ 3~ PSI UPST~N OF Y~ZYE ~(D Z~RO PSI ~NSTP~H. BLE~ SYST~I I0 ZERO PSI. OPgJ TOP S~ OF PIPE ~ ~D CLOSE S~ OF PIPE F~5. iNCR~E PRESSURE TO 3~ PSI ~JD HOLD FOR lO ~I~JTES. B~ED TO ZERO PSI. O~EI~ BO~O~ S~ OF PIPE ~S. BACK OFF RUN- l;II~ JOI~ ~;D PULL O~ OF HOLE. ~OSE BLIND ~:~6 ~JD i~T TO 3~ ~I FOR-lO B~ED TO ~RO PSI. OPEN BLIliD P~HS ~D REC~'~ lEST PL~. Y~KE t3-5/8' BOP STACK TEST - _ .. --_ ~ :_-; - --.~ _~ . ACCL~-IULATOR CAPACITY"T£ST _ ._ ; t-_--' '_'_- .:: ..-_ .... ,:. .-i?_-_:;-:¥w. ?; :-_ :- :'- - . ~qECK ~,'D FILL ACCI~IULATOR P?S_SERVOIR 70 PROPER -' }- :-" Lr_~'E[ WI?r{ HYDZAULIC FLUID; ' - -- ' ASSURE THAT ACCiZ-iLIL. ATOR PP,.ESSURE IS 3000 PSI -- WITH: 1500 PSI D0¥/ISTRF_~ OF THE REGttLATOR. O-3SERVE TINE T~EN CLOSE tALL UNITS Si,~2JLTANE- OUSLY Arid RECORD T~L_F TIP£ AND PRESSURE REi~IN- '. -- Ih~ AFT~ ALL UNITS APJE CLOSED ~ITH ~-zIARGING PD4P OFF. - RECORD ON Ig~C REPORT. ~ g. CCEPT~.~LE LC~4ER LIHIT IS 45 SECO:{DS CLOSI}~ -[Ili, E AND 1200 PSI R~qINII~ PRESSURE. - Surface Divert~r Ssstem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20,' bell .~ipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. ' - '2. Close annular preventer and blow air through diverter lines every 12 hours. 3~ Close annular preventer in the event that gas or fluid flow to sur. face is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under an~ circumstances. 16" Conductor . _ ._ Alaska Oil & Gas (~ons~ O0mmissto, June 29, 1952 ,'qr. Je f frey ~.. Ke,~i n Senior I~rllling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit DS i~t-4 ARfYJ Alaska, Inc. Pem~'~tt No. 82-103 Sur. Loc. 911'~NL, It40'FEL, See. ]~tn~hole Loc. 1392'~L. 820'F~7~, See. Desr Mr. t{ewin: Enclosed is the approved application for permi~ to drill the above referenced well. h'ell sanples and a mud 1o~~ are not required. A continuou~ directional survey is required a~ per 20 AAC 25.0§~(b)(§). If available, a talVe containing the-digitized log information shall be ~ubmttted on all logs for copying except e:/~,eri~nental log~, velocity-~urvey~ and diameter Many river~ in Alaska and their drainage systems have been classified as important for the spawning or migration of anadro~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulations pror~ulgated thereunder (Title 5, Alaska Administrative Code). Prior to conm~nel~ operations you ~y 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 ~egulatton$ promulgated thereunder (Title 18, Alaska Administrative Code, ~napter 70) ~nd by the Federal ~:ater Pollution Control Act, as amended. Prior to c~nmencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in schedulin~ field work, we would appreciate your notifying this office ,tthin 48 hours after the ~ell is spudded. We would also like to be notified so that a representative of the Con~nission may be present to witne~ ~'lr. Jeffrey B. Ke~in Iiuparuk River Unit DS 1H-4 -2- June 29, 1982 testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chai rman o f Alaska Oil and Gas Conservat-ion Com~ission Eno 1 o sure cc: Department of Fish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o encl. CVC:be ARCO Alaska, Inc. Post Office Anchorage, Telephone 907 277 5637 June 24, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Drill Site 1H-4 Application for Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill well DS 1H-4 and the required $100 filing fee. Attachments include a drawing of the proposed wellbore, and a drawing and description of.~both the surface hole diverter system and the BOP equipment, including anticipated reservoir pressures. Since we estimate spudding this well June 29, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/CLC:llm DS 1H-4 CLC1/:.L1 I £CEIV£D JUN 2 s 1982 Alaska 0il & Gas COns. COmmission Anchorage ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA C~,L AND GAS CONSERVATION CO,~lVIISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I_~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Al'aska, Inc. RECEIVED 3. Address P. 0. Box 360, Anchorage, AK 99510 JUN2 51982 4. Location of well at surface. 911 ' FNL, 1140' FEL, Sec. 33, T1 2N, R10~la~ 0il & Gas Cons. C0mmJssk At top of proposed producing interval Anchorage 1320' FNL, 1320' FWL, Sec. 33, T12N, R10E, UN At total depth 1392' FNL, 820' FWL, Sec. 33, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. ,85' RKB IADL 25639 ALK 464 12. Bond information (see 20 AAC 25.025) Federal Insurance Co. Type St atewide Surety and/or number 8088-26-27 9. Unit or lease name ~nKuparuk Unit 10. Well number 1H-4 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 Miles NW Deadhorse miles 16. Proposed depth (MD & TVD) 8253'MD, 7159'TVD feet 14. Distance to nearest property or lease line 911' FNL at: surface feet 17. Number of acres in lease 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2500 feet. 21 MAXIMUM HOLE ANGLE41 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 1H8 we~ 360' surface feet 118. Approximate spud date I 06/29/82 2812 psig@80° F surface 322_ 0 psig@6775 ft. TD (TVD) SIZE Hole 2/4" 13-i/2 Casing 16" 10-3/4 Weight 65# 45.5# i 8-3/4 7" 26# CASING AND LINER Grade Coupling H-40 PEB K-55 BTC K-55 BTC _~ 22. Describe proposed program: Length ' SETTING DEPTH MD TOP TVD 30'1 30' 30' ~ 30' MD BOTTOM TVD 110'! 110' 2200, Ii , 2200 I QUANTITY OF CEMENT (include stage data) + 200 cf 950 sx AS III ~ 250 sx AS II I 8225' 28'1 28' 8253'1 7159' 1000 sx "G" cmt fARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx 8253' MD (7159' TVD). A 20", 2000 psi annular diverter will be installed on [he 16" :.conduc[or while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be fins[ailed on the 10-3/4" surface pipe. It will be tested upon installation and weekly ithereaFter. Test pressure will be 3000 psig (1800 psi flor annular). Maximum expected !surface pressure is 2812 psig. Pressure calculations are based on virgin reservoir ',pressure. SurFaoe pressure calculated with unexpanded gas bubble at surface including "[emperature effects. Selected intervals will be logged. The well will be comple[ed with 3-1/2", 9.2#, 3-55 buttress tbg. Non-Freezing Fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk .Formation_and repor[ed on subse.quen[ reports A downhole safety valve will be installed ! ~3'~. I ~'~'~eWo~'~ti~/~i~ tl~J~{~g~r~t~e~d~d ~r~J~-ect~t~l~n'e best of my knowledge S~I_~_GNED ;--T' ' TITLE Senior Drilling Engr. DATE .n e space oel~fo r/~rKm iss~q~ use CONDITIONS OF APPROVAL Samples required Mud Icg required [~YES ~klO []YES [~O Permit number Ap~p__(,oval date Form 10-401 ~ Directional Survey required APl number i~YES [-INO 50-- O-b~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE June 29, 1982 by order of the Commission Submit in triplicate ..... RRCO-RLRSKR,--'tNC'- ..... ~-':--'-~-t ..... :--~. '--~-~~~~-~-~-~-.'~--~t-~-~-~-.-~ ~ !!~il ~ ~- ' ~J~;~'2~: ,~ 7 : :-~ ~ ' ; ~ ~ ; : ; ; ~ ~ ; ~ l'': : : ~ : ~ ~ ~~~~E~~~~' ' : ' ~ ~ ~ ; ~ "' "; ; ~ :: :N ~ ~ ~ ~ ~ : ~ ~ ~' .,__:.~L ...... ~ ....... ~...z_~ .... *~ ...... r_'__2_.~. ~.. _~_~_1 ; ~ i ~_~ ~ :: ~ L ; .... ~: ' ; '. :~l ' ~ ~ : ~ : ,_~ ~ :, : ~. .. -~ ..... ~-!'~--~'~ .... '"--t-~--r-~-r-~~'-~-~-r~- ! 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O. · Surface Divert- -~ystem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- V cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~nipple. Maintenance & Operation ~- 1. Upon initial installation close annular i preventer and verify that ball valves ! - have opened properly. ' · I 2. Close annular preventer and blow air ~ . through diverter lines every 12 hours. t 3~ Close annular preventer in the event that gas or fluid flow to sur_face is · detected. If necessary, manually over- ride and close ball valve to upwind Do not. shut in well diverter 1 ine. under anx circumstances. 16" Conductor ]3-5/8" 5000 PSI ~RSRRA BOP STACK 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head ' ,F~ 3. 10" 3000 PSI tubing head . [ ~NNUL,qR 1 4. 10" 3000 PSI x 13-5/8" 5000 PSI .. adapter spool -:' p~ p,E¥.9ENTO,q~ -. 5. 13-5/8" 5000 PSI pipe rams - _ · - 6. 13-5/8" 5000 PSI drilling speol w/choke '~.] 't[ ' ~CCL~IULATOR CAPACITY TEST . -) t.' ::. -' .... : ] 1. CHECK ~-';D FILL ACCU/4ULATOR RESERVOIR-[O BROPER -' - ' ' LL~'E[ WITFJ HYDRAULIC FLUID; _ -- PIPE RRHS 2. ASSURE TFAT ACCL~-D~TOR PP~ESSURE IS 30~ PSI ---- . _ OUSLY ~;D RECORD THE TI'~ AND PRESS~ ~'~IN- P~ OFF. LItlIT IS 45 SECON~ CLmING liME AND ~200 PSI 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND H~NIFOLD NI~ 2~C DIESEL r ~ =. ~ECK =d=T ALL HOLD D~,~N SCR~S ARE ~Y' RE- TP~CTED. PREDETE~-:tNE DEPTH ~HAT T~ ~L~G ~) ( ~'I~ S~T AND S~T IN WEL~D. R~ ,, LOCK 3.~e $'~';U~.R PREVENTER AND ~OKES ~ BYP~S Y~VES ON I.~NIFOLD. . .. C ~ . :h ] R~rr~v~-' ~o ~INUTES. BLEED TO ZERO PSI. _ . - 4 8 V~V~ DIRELY BLEED ~'NSTR~ PRESSUP~ lO ZtRO ~I l~ TEST ' ' J ~ ~k~ 0~i.&'G~s Cons. C0mmBs~on- v~v~. lEST R~4A!d!NG" UN~IED F~NIF'~ . ' OPEN TOP S~ OF PIPE ~ ~iD CLOSE BO~O~.I ' ' HIt~JTES. BLEED TO ZERO PSI. : - . ' ' 11 OPEN DO.OH S~ OF PIPE ~4S. BACK OFF ~UN- - ' ' '- Nil? JOI~ AND PULL O~ OF HOLE. ~OSE BLIND -]: -' - DIESEL ~iD ~L VALY~ ARE SET 'IN DRILLING .-- _ '! ' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITeM APPROVE DATE (1) Fee (2) Loc ('~ thru 8) (3) Admin (9,/thru" 11 ) (4) Casg ~_ ,~_.~,.~ (12 thru 20) (21 thru 24) (6) Add: ~.~. ~. · · 3. 4. 5. 6. 7. 8. 1 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ...... "'''''~27_~ Is well to be deviated and is well bore plat included ........... ' Is operator the only affected party ................................. Can permit be approved before ten-day wait ..... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is 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 10-40'3 ............ Is adequate well bore separa2ion proposed ........................... Is a diverter system required ....................................... <f~f Are necessary diagrams of diverter and BOP equipment attached ....... ~ Doe's BOPE have sufficient pressure rating -.?est to _~m psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirement · Additional Remarks: R~MARKS ' ~,/.7 ~t5 ,..~! ,~', c. Geology :. Engineer~ng: nWK K WVA~. JKT /'~ --R~AD ~ JAL ..... MTM' ~ rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE CHECK LIST ~OR NEW I~ELL PERMITS Company Lease & Well No. ITeM APPROVE DATE (1) Fee ~g~C ~ g:'~l- 1. Is / (2) Loc ~-£ ~ '~J-4~ /~2 thru 8) YES NO 2. Is 3. Is 4. Is 5. Is 6. Is 7. Is 8. Can permit be approved before ten-day wait the permit fee attached ........................................ well to be located in a defined pool .............................. well located proper distance from property line .................. well located proper distance from other wells ................... sufficient undedicated acreage available in this pool well to be deviated and is well bore plat included .. operator the only affected party ................................. REMARKS (3) Admin ~ g~ .~ thru 9. Does operator have a bond in force .................................. ~ 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................ ' ................... · 3. 14. 15. 16. 17. 18. 19. 20. (4) Casg~~ '-- - ~2 thru 2,0) ~"~21 thqu 24) 2 2 2 (6) Add:~ Is conductor string provided ............................. Is enough cement uSed to circulate on co~ductg~ and gur~age . Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ........... - Will surface casing protect fresh wate'r 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 well bore separation proposed .......... 1. Is a diverter system required ...................................... ~ 2. Are necessary diagrams, of diverter and BOP equipment attached .... ~__ 3. Does BOPE have sufficient pressure rating -T. est to ~oz~ ~ig . · 4. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 5. Additional requirements ............................................. Additional Remarks: Geology: Engi~? e~ving: WVA _ / rev: 01/13/82 INITIAL GEO. UNIT oN/O'FF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. o. bib TAPE VERIFICATION bISTING ,VP O10,H02 VERIFICATION LISTING PAGE :* REEL HEADER ** ;ERV'ICE NAME ~SERVIC lATE :83/02/15 )RIGIN : [~EL NAME :REEL ID :ONTINUATION # 'REVIOUS REEL :OMMENTS :REEL COMMENTS ~* TAPE HEADER ** {ERVICE NAME )ATE t83/02/15 )RIGIN ~6532 ~APE NAME ~ONTINUATION # ~REVIOUS TAPE ~OMMENTS :TAPE COMMENTS ********** EOF *****.***** ~* FILE HEADER ** ~ILE NAME :SERVIC,00! ~ERV'ICE NAME IERSlON # )ATE : 4AXiMUM LENGTH : 1024 ".ILE TYPEF ~E ~REVIOUS I INFORMATION RECORDS ~NEM CONTENTS ~N : ATLANTIC RICHFIELD COMPANY ~N I IH~4 PN : KUPARUK {ANG: IOE ~0WN: ,0UN $'bO ~TAT~ ALASKA .TRY: U,S,A. 4NE,N CONTENTS ~RES~ DIL'OO1E ** RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE 000 000 026 065 000 000 004 06:5 000 000 008 065 00 000 003 065 00 000 003 065 000 000 002 065 000 000 012 065 0~ 000 006 065 0 000 006 065 UNITTYPE CATE SIZE CODE 000 000 007 065 ,VP OJ0,H02 VERIFICATION LISTING PAGE 2 ** RECORD TYPE 047 ** ** RECORD TYPE 047 ** COMMENTS ** SCHLUMBERGER AbA, MKA COMPUTING CENTER :OMPANY ;ELL ~IELD :OUNTY ;TATE ATLANTIC RICHFIELD COMPANY IH-4 KUPARUK NORTH SbOPE BOROUGH AbASKA NUMBER AT ACC: 10707,65324 tUN #1, DATE bOGGED: 17 OUb 82 ~OTTOM DEPTH FOP DEPTH lAMING ½IT SIZE ~YPEFbUID )ENSITY IISCOSITY 7829 FT, 2194 FT, 103/4 8 1/2 PObYMER 10,3 LB/G 46 S ,VP OlO.H02 VERIFICATION LISTING PAGE 'LUID LOSS :M AT BHT 9 6,0 C3 2,880 OHMS ~ 52 DF 3,500 OHMS ~ 52 DF 1,089 OHM ~ 149 DF IATRIX SANDSTONE DATA FORMAT RECORD ** ;NTRY BLOCKS TYPE SIZE REPR COOE ENTRY 4 ! 66 ~ 4 73 6O 9 4 65 ,lin 0 i 66 0 )ATUM SPECIFICATION BLOCKS ~NEM SERVICE S~RVlCE UNIT API APl APl API FILE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO. )EPT FT 0 0 0 0 0 4 ~FLU D IL OHM~ 7 0 0 0 0 4 [L~ DIL OHM~ ~ 0 0 0 0 ~ [LD DIb OHM 12 46 0 0 0 0 0 4 ~R DIL GAPI 3~ 0 0 4" ~..I FDN 68 2 0 0 4 )RHO FDN 44 0 0 0 4 ~HOB FDN 35 912 0 0 4 tCNL FDN 34 0 0 4 "CNb FDN 0 ~ I ~ALI FDN 0 ~R FDN 0 0 4 ~RAT FDN 0 0 4 ~NRA FDN 4:2 0 0 0 0 4 LEVEL CODS 0 ! 68 0 1 68 0 0 I 68 68 0 ! 68 0 1 68 0 0 I 68 68 0 1 6~ 0 I 68 0 ~ 0 I 68 0 i 68 DATA ** ,VP OlO,H02 VERIFICATION LISTING PAGE 4 IEPT 7862 0000 SFLU 2 iP -33:5313 Gl{ *HOB 2: 3750 NCNb 1245, ;R 51 0313 NRAT 3. 7480 IbM 0313 NPHI 0000 FCNb 1719 RNRA ~EPT 7800,0000 SFLU 3, ;P '31,5625 GR 84. :HOB 2,5195 NCNb 2456 ;R 84,6875 NRAT 3: 4004 6875 NPHI 0000 FCNL 0195 RNRA IEPT 7700,0000 SFLU 2 ;P -45.3125 GR 89: IHOH 2.5078 NCNb 2332, ;R 89.6875 NRAT 3, 8047 IbM 6875 NPMI 0000 FCNL 0840 RNRA )EPT 7600 0000 MFLU 3, ;P -45:2813 GR 86, ~HOB 2:4629 NCNb 2284, ;R 86 9375 NRAT 3, 1465 IbM 9375 NPHI 0000 FCNL 2109 RNRA )EPT 7~00,0000 SFLO 12, ;P 58,2813 GR 53, tHOM 2.2344 NCNb 2922, ;R 53.0000 NRAT 2, 9141 IbM 0000 NPHI 000 FCNL 836 RNRA 8750 IbM 6875 NPHI 0000 FCNb 0410 RNRA 7200,0000 SFLU 8~,5:000 GR ,3359 NCNb 52,5938 NRAT 42,9687 IbM' 52,59i38: NPH! 2798,0000 FCNL :3,0000 RNRA )EPT 7200,0000 SE L J ~P -84,5625 GR ~HOB 2,6172: NCNb ;R 38.8125 NRAT 8125 NPHI .351~ 0000 :FCNL 3066 RNRA )EPT 5~' 0 7100 000 SFLU ~HOB , I'R 118,9375: NRAT 1,3760 118:,:9375:. NPHI 781:0000 FCNL : 8:61:3 RNR:A 2.2656 38,2813 359.2500 3,4656 3.0918 34.1309 701,5000 3,3864 2,5000 33,9355 717.0000 3,3114 2 9570 35:6445 619,0000 3,5143 11.8281 28,6133 1033.0000 2,7730 .o :iooo 115 26,1719 32,6660 885,0000 3,2337 19,6094 21'9727 138~i0000 ,4037 1,5010 ::'.999:,2500 415'5000 4,2932 3P -54,5000 GR 119,6250 NPHI , 500 ~:HOB 129, 3164 NCNb:,*: I875, O( O0 I~ CN ;R ! .6250 NRAr 3;7813 RN~ 0626 3,1621 IbM 1974'0000 FCNL, ::3:.:8574 RNR:A )EPT 6~00,0000 8FLU 5P 58,6875 ~[{OB '999,2500 NCNb iR 181,8750 NRAT 2 5215 46 .0000 -999,2500 IUD ORHO CALl IUD DRHO CALl IUD DRM0 CAbI lbo DRHO CAUl IUD DRHO CALI DRHO CAUl IUD DRHO CALI IhD DRHO CAbI ILl) :DRHO CAbI I:b:D DRHO CALl D:RHO CALI 2,5742 -0,0562 8,5000 2,9512 0,1812 ~,9844 2,4844 0,0894 9,9062 3 0078 0:1089 10,2969 14,3594 0,0557 8,9609 O. 10,0547 29,8594 '0.001:0 9,5078 19 3281 0 0405 7 ~ 9 422 1.633g 0,0552 11,5547 1,9%39 0,0244 10;6250 2,4766 -999,~500 10,789! ,VP OlO,H02 VERIFICATION LISTING PAGE 5 ,EPT 6800 0000 SFLU ,P '56,2500 GR :HOB -999,2500 NCNL ;R 196.6250 NRAT ~EPT 6!00.0000 SFt, U ~P 65,3125 GR ,. 10B,5000 NRA )EPT 6600,0000 SFLU ;P -58,7500 GR IHOB -999,2500 NCNL ;R 125,1875 NRAT )EPT 6500. 0000 SFLU ;P "62 5000 GR tHOB -999: 2500 NCNL ;R 106,2500 NRAT )EPT 6400 0000 SFLU ~P '51' .5000 GR ~HOB '999,2500 NCN[~ ;R 110,6250 NRAT )EPT b300,000() SFLU )P ''53,0313 GR ~HOB 999;2500 NCN.L ;R 104,1875 NRAT oooo ,P '73,0000 {HOB ..999,2500 NCNL ;R 125,5625 NRAT )EPT 6100,0000 SFLU {P ' 68, ~.HDB -999, iR 181,7500 :NRAT )EPT 6000,0000: oooo ~P -59, N {HOB -999,25:00 iR 146,0000 NRAT ( )EPT 5900, )000 SFLU 1, {P .-6o;oooo GR~ , ~.HOB 999,2500 NCNL 25 18, = 152,0000 NEAT :: 3, ~p -61; 71 ~ (,~ , " ~HDB 2,386 ? NCNb 26]84 2,8047 ILM 196,6250 NPHI 1964,0000 FCNL 3.7754 RmRA 3,1074 IbM 108,5000 NPHI 2116,0000 FCN[. 3,1914 RNRA 2 8496 IL~ 2o9 :oooo 2109 RNRA 3,9004 ILM 106,2500 NPHI 224~,0000 FCNL · ,0723 RNRA 2,4238 11026250 NPHI 1905,0000 FCNL 3.7031, RNRA 2,1895 IbM 2104'1875 NPHI 42;0000 FCNL 3,0410 RNRA 2~,0:273 oooo: 836 RNRA 3.0547' ILM 181,'?5:00NPHI 2120,0000FCNL ! 3'46:4:8: RNRA 2.2461 -g99,2500 436.5000 -999.2500 2.8008 -999,2500 593,0000 '999,2500 2,4824 -999,2500 637,0000 '999,2500 3,3066 -999,2500 669,0000 -999,2500 1 8760 -999:2500 459,7500 -999.2500 1.8447 -99~,25()0 61 ,5000 -999,2500 , 00 595,)'000 '999, 500 2,9492 -999,2500 5~8,0000 -9~9,2500 ~2:85:ILM )000 :NPHI ~ N O000~CL 507 5703 RNRA -999 5439 IL,N 1 0000 NP:HI ":999 0000 FCNL 653 584'0 RN:RA: '99:9 73:05ILM 3~ O000NPHI' 0000: : FC:NL 826 000 5OO ,7148 ,2500: ,,0000 ,2500 ,9980 ,1758 ,0000 DRHO CALl ILD DRHO CALl ILD DRHO CALI ILD DRHO CALl IbP DR, HO CALI ILD DRHO CALI CALI ILD DRHO CALl ILD DRHO CALl ILD DRHO CALl ILD DRHO CALl 2,1855 -999 2500 10~4141 2,8262 '999,2500 11,4766 2 4531 -999:2500 ~0,6719 3,3223 '999,2500 11,8516 1,8926 '999,2500 10,390b 1,9502 -999,2500 1.0,6464 .99~ ,9492 ,2500 12.7109 3,0801 -999,2509 11,0469 2,0625 -999,2500 9.7422 1,9629 -999,2500 10.1562 3,0547 0,0566 10,6719 VP 010,H02 VERIFICATION LISTING PAGE 6 82,0000 NRAT 2.9316 RNRA ,EPT 5700.0000 SFbU iP -64.7500 GR :HOB -999 2500 NCNL ;R 90:3750 NRAT 2,1074 ibm 90.3750 NPHI 2296 0000 FCNL 3:3984 RNRA 5600 0000 SFbU -21,8750 GR -999.2500 NCNb 88.0625 NRAT 2.0391 IbM 88.0625 NPHI 2402,0000 FCNL 3.4102 RNRA ~EPT 5500 0000 SFLU '8750 GR ~P -20. [HUB -999,2500 NCNb ;R 89,8750 NRAT I 9258 89:8750 NPH! 2144 0000 FCNL 3:1055 RNRA )EPT 5400,0000 SFbU ~P -27,4063 GR [HOB -999,2500 NCNb ;R 112,9375 NRAT , 1797 IbM 11 .9375 NPHI 2300,O000 FCNL 3.1738 RNRA )EPT 5300 ~HOB ;R 105 0000 SFLU 0 NCNL 4375 NRAT 3.2070 IbM 105.4375 N'PHI so ':oooo .0879 RNRA )EPT 5200 iP -23 ,ti'OB -999 mR 94 ,0000 SFLU ,4063 GR ,2500 NCNb .8750 NRAT 2.6211 IbM 94,8750 NPHI 2222,0000 FCNL 3;3672 RNR~ )ePT 5100 0000 SFLU )P -.,23:6250 GR {.HOB 999,2500 NCNb ;R 98,2500 NRAT 2,6270 IL~4 98,2500 :oooo ~,HOB -9:99,2500 NC'N~ ;R 93,3750 NRAf 0000 SFLU 3P)EPT 4900,~ NPHI ~ IbM 306.6 RNRA )EPT 480:0 3P -26 0000 SFbU :2,8027 IbM 6094 GR 91,8750 NPHI ,2500 NCN')~ 2682.,.0000 FCN~ 8750 NEAT 3. 0938 RNR A )EPT 470Q,0000 SFLU 3 -27.8594 GR 95 3.1478 2.2793 -999,2500 DRHO 623,0000 CALI -999,2500 2,0996 -999.2500 DRHO 635,5000 CAbI -999.2500 2,0586 '999,2500 DRHO 613.0000 CALI -999,2500 3,2129 IbP '999,2500 DRHO 648,5000 CAb! -999,2500 3,2422 IbD -999,2500 DRHO 700,0000 CALI -999.2500 ,7283 -99'92. 50~OR HO 657,5000 C A b I -999 ' 2500 2,6094 ILD 9:99,2500 DRHO .635,5000 CALi 999,2500 -9929; 9199 250'0 D R H 0 '635"5000 CAL! 999,2500 2,4434 IbD :-999,,2500 DRHO 657.,5000 CALI '999'.2500 99~'9297 lb[) ,2500 DRHO 782:, 0000 C,A,L:I 99.2500 3,1348 ILD -999,2500 DRHO 2.3242 -999.2500 11.0625 2,1465 '999,2500 11,1172 2,~250 '999, 500 11,3516 3,3457 -999,2500 12,7344 3 4199 -999i2500 I 1 9687 ,25 11,4531 .991'7129 ,2500 11,9844 ~,0605 -99 , 2500 11,5781 2,6191 .8047 11. 8047 3.4883 0.0625 ~VP 010,H02 VERIf'ICATION LISTING PAGE 7 3516 NCNL 95:1875 NRAT 2560,0000 3,1602 FCNI, RNRA )EPT 4600,0000 SFLU ~P -27.6250 G~ tHOB 2.3438 NCNb ;R 98,1875 NRAT 2,~234 98, 875 2358.0000 3,2266 IbM NPHi FCNb RNRA )EPT 45000000 SFLU ~P -27:8594 GR {HOB 2,2402 bJCNb ;R 82.6875 NRAT' 1 9150 82!6875 2037 0000 3,5605 IbM NPHI FCNL RNRA )EPT 4400.0000 SFLU ~P -33,6250 GR ~HOB 2.3047 NCNL ;R ' 102,1250 NRAT 2,9609 102,1250 231~,0000 ,3477 IbM NPHI FCNL RNRA )EPT 4300.0000 SFLU ~P -3~,3438 GR ~'HOB ,3047 NCNb ~R 84.5000 NRAT 38184 84[5000 23040000 3.246! ILM NPHI FCNL RNRA )EPT 4~00,0000 SFLU 3P 5~,1250 GR ~HOB ,1855 NCNb iR 85,3750 NRAT 10,9922 3750 26~5'0000 ILM NPHI FCNL RNRA )EPT 4100,0000 5FLU SP 36,3438 GR ~MOB ~ 2734 NCNb gR 8:7500 NRAT 2,8340 ,0000 3'~762 ILM NPHI FCN[. RNRA DEPT 4000.0000 ~FLU 5P '39.1250 GR RHOB ~:.26i~ NCNb GR 8 .812 NRAT DEPT 3900,0000 SFLU SP -:45,4063 RHOB 8~.3242 NCNb ~R. .6250 N:RAT: 8~::7617 8125 2:,44~48240000 4 9258 8:2: 2090 3 'CNb NRA I bM 44:92RNRA DEPT 3800 5P -53 6: )000 SFLU 3438 NC:Nb 1875 NRAT ~5 NPHI FCNL 813 RNRA DEPT 7 0000 SFLU 3.00, ,, R SP 5~,6250G!, RMOB ,3301 NCNb GR 76.3750 NEAT 5.1250 IbM 76,3750 NP:HI 2010.0000 FCNb 3.5547 :RNRA DEPT 3600.000:0 SFLU 9.9453 IbM 743.0000 CALl 3,4071 2.6758 IbD 34.6680 DRHO 651.5000 CALl 3.6429 1.9922 ILD 40,6738 DRHO 573.5000 CALI 3.9396 3,4277 ILD 36.6699 DRHD 652.5000 CALI 3.6405 3.9199 ILD 35,0098 DRHO 676.0000 CALI 3,5438 11,7891 32,7637 DRHO 739.0000 CALI 3.4905 3.0859 ILD 4~ 9668 DRHO 55 ~0000 CALI 3,9096 ' DRHO 0000 CALI 5,1367 ILD 38,5'254 D:RBO 586,5000 CALI 3,6:604 3594 8887 DRHO 5,8047 IbD 41,0645 DR,O 53~:00009420 CALi 7.5508 11,9219 2.8809 0.0566 12.1484 2.3262 0 0498 12:o313 3.7441 0,0586 12.4375 40547 0~0757 12,0469 11.5625 0.0425 11.1172 3,3496 0,~737 406 5,0508 0.0293 11,234'4 5,6797 ii~ '0957 ,4219 .08 11.5~91 6.6680 1~,0728 ,0781 8,6875 ,vp O10,H02 VERIFICATION LISTING PAGE 8 iP -54°5625 GR 70. :HOB 2 3848 NCN.L 2186' ;R 70:8125 NRAr 3. 8125 NPH! 0000 FCNL 0566 RNRA ~EPT 3500 0000 SFLU 4 ;P -136:5000 GR 63: IH00 2 2441 NCNb 1918 : ;R 63:2187 NRAT 3 5352 IbM 2187 NPHI 0000 FCNL 6172 RNRA )gP? 3400.0000 SFbU 5 ;P -135,3750 GR 56: IHOB 2.1738 NCNb 2238 ;R 56.5938 NRAT 3: 6914 5938 NPHI 0000 4570 RNRA )EPT 3300,0000 SFLU 8, ~P '134,1250 GR 74, tHOB 2,2422 NCNL 2150, ;R 74,1875 NRAT 4609 IbM 875 NPHI 000 FCNL 6953 RNRA )EPT 3200 0000 SFLU 59 71562 IbM {P ..107~3750 GR 42i 188 NPHI ~HOB 2.0801 NCNb 22303 0000 FCNL ;R 42.7188 NRAT .3340 RNRA )EPT 3100,0000 SFLU {P '121,4375 GR 54, ~H[)B 2,1211 NCNb 2178, ;R 54,7188 NRAT 3. 2031 IbM 88 NPHI 70A00 FCNL 5117 RNRA .5625 NRAT :R 9.68~ !bM 562 N?HI 0000 FCN5 4512 RNRA 0000 SFLU 3,9609 )gPT 2900,6 : 80,8750: NPH! ~P '8 , 875 G~' ~HOB ,1914 NCNb 1736" ~R 80,8750 4, 0000 FCNL i328 RNRA ~P ,2 .{HOB 45 ,()000 :B~LU ,'8~,'28 3750 G 4~3,38 PHI o~4o NCN~ ::: 2o~,,:o,o:00: 3438 NRA7 . 3281 RNRA DEPT ~700. SP 'gO, ~HOB 24' 0000 SFLU 11 6953 IbM 937~: GR' : 54 3750:: NPHI 2348 NCNb 1836 0000 FCNL 3750: NRAT : ii: ::3,2:559 ,:R:NRA ' T 2.600, 5P 100, ! 0000: $:FLU: :: 1:0,4141 ! 1250 GR t 53,4688 NPHI 0996 NCN~: I775' 0:0:00: FCN~ 4688 NRA~ 3,4766 :RNR 31,2988 DRHO 645,0000 CALI 3,6480 4 8867 ILD 42:2852 DRHO 531,0000 CALI 3,8585 7,2070 39.4043 DRHO 593.5000 CALf 3.7461 7.7656 ILD 44,4336 DRHO 543.5000 CALI 3,9460 43,0000 37,0605 DRHO 626,5000 CAbI 3.6295 8,8984 41,0156 DRHO 601,0000 CALI 3,8509 ,7969 3~:,3066 RHO 538.0000 CALl 3.7987 50, 8 3 DRHO 419.~5~0 CALI 4.3257 8,0469:: I5D 37,5488 DRHO 52~,0:0:00 :CALl ,5378 8,3594 'ILD 35,4980 DRHO 508.5000 CALI 3'5547 10 39 ~"0703 I:hP ,4043 DRHO 7500 CALl .8794 0 0771 12:5938 5,3672 0.0488 10,8906 7,9883 0,0444 10,8125 8,5469 0,0371 10,2344 67,5000 0.0376 11,0859 9,7656 0,0225 10,3359 9,8828 0,0454 10,8437 5,5313 O' 27 I O, 4297 9 1406 10 0044 I 4375 11' ,5391 VP OlO,H02 VERIFICATION LISTING PAGE 9 ,EPT 2500 0000 SFLU .,93!8750 GR 10 75OO 47i6250 1674 0000 3,6641 IbM NPHI FCNL RNRA 'EPT 2400.0000 SFLU iP -79,1250 GR [HOB 2.1660 NCNb ;R 69,8125 NR. AT 5 1641 69:8125 1570,0000 4.0586 IbM NPH! FCNL RNRA }EPT 2~00,0000 SFbU ;P 86,6250 GR [HOB 2,0762 NCNb ;R 64,1250 NRAT ~,5000 64,1250 1664.0000 3.9219 NPHI FCNL RNRA )EPT 2200 0OO0 SFLU ;P -59:3438 Gl{ tHOB 2,0469 NCNb ;R 47,0000 NRAT 13 0000 47:0000 1707,0000 3.9922 IbM NPHI FCNL RNRA )EPT 2175.0000 SFLU {P -36,12.50 GR ~HOB 1,9727 NCNb ;R 33,1875 NRAT 2000,0000 33,1875 1500.0000 4,6211 NPHI FCNL RNRA FILE TRAILER ~Ibf NAME IMERVIC,O01 {ERVICE NAME )ATE : ~ILE TYPE ~EXT FILE NAME ~* TAPE TRAILER )ATE :83/ ~APE NAME 2DNTINU:A~ION { ~01 iEXT TAPE NAME ~OMM£NTS {TAPE COMMMNT8 10 42 414 3 5 49 358 4 9 47 367 40 47 384 4 2000 61 282 ,8359 ,7246 ,0000 ,9432 ,7031 .8535 ,5000 .4695 .2422 168 :o ooo ,4077 .9375 .3145 ,0000 .2992 ,0000 ,0840 ,7500 .9898 IbD DRHO CALI ILD DRHO CALl ILD ORHU CALl IbD DRHO CALl DRHO CALl 13 7891 0i0278 11 7656 7 0820 11,6953 11,5859 0,0244 12,0313 57,1875 0,0205 14,5625 115,1875 ~0,4854 0,2422 JVP O10,H02 VERIFICATION LISTING PAGE 10 IEXT REEL NAME : :OM~ENTS ~REELCO~4MEi'~T$ ********** EOF ********** EOF
