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186-081
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3N-13 KUPARUK RIV UNIT 3N-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3N-13 50-029-21584-00-00 186-081-0 W SPT 6255 1860810 1564 2680 2680 2680 2680 120 130 130 130 4YRTST P Bob Noble 8/25/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3N-13 Inspection Date: Tubing OA Packer Depth 380 1990 1930 1920IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240827113652 BBL Pumped:1.1 BBL Returned:1.1 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 999 9 9 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:55:28 -08'00' MEMORANDUM TO: Jim Regg f� -Tf !3!Ze-z i P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3N-13 IInsp Num: mitBDB210821163930 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3N-13 KUPARUK RIV UNIT 3N-13 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21584-00-00 Inspector Name: Brian Bixby Permit Number: 186-081-0 Inspection Date: 8/21/2021 ✓ Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well :Type T— �-- -- PTD 1860810 Type Testi W TVD 625s Tubing 2740 2740 2740 - 2740 3N 13 Type In g SPT "fest psV 1564 IA 360 2010 1945 1930 ' I BBL Pumped: j 1.2 BBL Returned: 1.2 OA 225 — 230 - 230 230" Interval] 4vRTST p/F P Notes: Wednesday, August 25, 2021 Page 1 of 1 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, September 22, 2016 3:05 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: KRU injector 3N-13 (PTD# 186-081) update 9-22-16 Attachments: MIT KRU 3N-13 diagnostic MIT-OA 8-22-16.xls Chris, KRU injector 3N-13 (PTD# 186-081)was initially reported for an anomalous IA pressure decrease. Diagnostic testing including tubing and inner casing pack offs and an MIT-IA all passed (10-426 provided in previous email 8/20/16). During the initial 30 day monitor period the OA exhibited an anomalous pressure decrease and a 30 day extension was requested for the monitor period subsequent a passing MIT-OA(see attached 10-426). The 30 day extension has been completed and the well has exhibited no signs of annular communication. As such CPAI plans to return the well to 'normal' status. If further pressure anomalies are exhibited in the future they will be reported to the AOGCC at that time. Please let us know if you have any questions or disagree with the plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 %1. 1 ; JAN 1 7 2017 ift:ELLS TEAM Co,«oPhasos 1 L.1..1 V h co U! Z W 73 I W < 0 w r- o UJ r-- N a U_ o 7---• o to -t s, w CO CV 49 Ce Crr Lri r 1:- -0 -0 o v y `w mtea (r1 C w Ca a I- I- to rj o w N N N CV — N N CO CO G J CO1 M J w ...p D c•-, ,d Bap. CJCJ CJ CJ CJ C-J CJ w tC� CI, 0.� M1- CC. 11.1) V' C 1 C! 1.-.1 ICI _ i i i I r r I I w o n W ,(- 1111m v C os To" 16 1 C 0 co Ri C` 441 E 0 UII I L III R PIP O C = C I Q tC. ` 1.L1 7 I I CD CO M a p M N N i CD m Q. iso ( I I m CLry, ❑ c d 8 S ii1 cJJ u I ❑ WI d Yi $ iCiJ i V. el n n .. tcn r7 0 N (-J C. CdIE'C113A CD 0 T. isd 5N cA ❑ w • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p•••-, DATE: Monday,August 08,2016 c P.I.Supervisor 1�``t( �( (IO SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-13 FROM: Bob Noble KUPARUK RIV UNIT 3N-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J e NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-13 API Well Number 50-029-21584-00-00 Inspector Name: Bob Noble Permit Number: 186-081-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801173613 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 3N-13 Type Inj 1 W- TVD 6255 - -[Tubing 2825 - 2825- 2825 - 2825 - PTD 1860810 - Type Test' Test psi IA 1050 2000 -- 1950 - 1940 - Interval 'WRIST yp I IP/F P '/I OA 60 60 - 60 - 60 - Notes: SCANNED MAY I_ 9 2017 Monday,August 08,2016 Page 1 of 1 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, July 21, 2016 5:09 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: Kuparuk injector 3N-13 (PTD#186-081)IA pressure anomaly Attachments: 3N-13 90 Day TIO plot.JPG; 3N-13 MIT-IA 15 July 16.xls; 3N-13.pdf Chris- Kuparuk injector 3N-13 (PTD#186-081) has shown an unexplainable decrease in the IA pressure. The IA was pre tested prior to the upcoming state witnessed MIT pad testing. The MIT-IA passed and the IA was bleed down. Since the test and bleed were completed,the IA has shown a constant decrease in pressure. CPAI intends to perform initial diagnostics with the well still on water injection. If it passes the MIT-IA again the IA will be left with an elevated pressure and monitored for 30 days for pressure fall off. If the MIT-IA fails the well will be shut in and secured for further diagnostics. Please let me know if you have any questions or disagree with the plans. Attached is the wellbore schematic, 90 Day TIO plot and MIT form for the diagnostic MIT-IA that was performed. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 ;WELLS TEAM ConocoPhillips SGAtiKO NOV 1 8 2016', W • V „ cc w cn 0 (II Q U N Lu <Y a u: a O N w a .1) d y w El N Ct n. CL f- In w F Co J J w a tCr-i -� cui 7 dBap t] U tCJ <, w tt ri i 6 77 IL' 1 1 I I 1 1 1 I Ri `- - 'n .y r1 (O (7 v- toillip,. .kN C alcui cn C o l4 - G co v 4 4 O c E o V L illI3 O 1 M O C Z C Q t,- co 2 CO CO M O O M N N 4q et r• `+ SSO tO E :'. A: I ' i0 O 0 a C.3 1-] (:1 u u I i c3 4 n < c l Ca CJ O C7 CJ (U r. .. i n I 177 C-1 0.0 (! V �1 d U isd Syvlow • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,September 12,2013 TO: Jim Regg P.I.Supervisor 'Ref/ II°7/1 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-13 FROM: Jeff Turkington KUPARUK RIV UNIT 3N-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-13 API Well Number 50-029-21584-00-00 Inspector Name: Jeff Turkington Permit Number: 186-081-0 Inspection Date: 9/8/2013 Insp Num: mitJAT130908172150 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-13 - 1Type Inj , w 1 TVD I 6255 • IA 1 440 1 2100 •I 2045 1 2035 1 PTD 1860810 • Type TestI SPT-1 Test psi 1564 - OA 9 -■ 7S 77 . " 77 [ i Interval IINITAL P/F P ."' Tubing 1275 - 1275 1 1275 1 1275 • I- L _L , Notes: Post Rig WO. 1.1 bbl diesel to fill. - SCM*ED DEC 1 0 2013 Thursday,September 12,2013 Page 1 of 1 • w w \ THE STATE Alaska Oil and Gas F�%,0'" 1.1 °fl 1L1 is Conservation Commission S � GOVER SEAN PA 333 West Seventh Avenue p �, Anchorage, Alaska 99501 -3572 4LA5� Main: 907.279.1433 Fax: 907.276.7542 John Peirce joi 2 3 2413. Wells Engineer SOWED ®C4 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -13 Sundry Number: 312 -469 Dear Mr. Peirce: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Commissioner DATED this 1 day of December, 2012. Encl. STATE OF ALASKA AV 11 I A.KA OIL AND GAS CONSERVATION COMIISION A • APPLICATION FOR SUNDRY APPROVALS Vif 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Install Tubing Patch P'• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 - 081 3. Address: Stratgraphic r Service p' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21584 - 00 • 7. If perforating, 8. Well Name and Number: � What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 3N - • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25520 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): • 7875 6668 7792' 6604' 7371' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3737 9.625 3774' 3628' REC EMVEC PRODUCTION 7845 7 7873' 6666' DEC 112012 AOGGC Perforation Depth MD ( 7485 - 7505, Perforation Depth ND (ft): 6370 -6386, Tubing Size: Tubing Grade: Tubing MD (ft): 7557 - 7571, 7580 - 7603, 7606 - 7607, 7621 - 7654 6425 -6436, 6443 -6460, 6463 -6463, 6474 -6499 2.875 J -55 7404 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BROWN HB PACKER MD= 7333 ND= 6255 SSSV - BAKER FVL SSSV MD =1784 TVD =1784 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic r Development r Service • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/26/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John .W.Peirceffconocophillios.com Printed Name John Peirce Title: Wells Engineer Signature ) Phone: 265 -6471 Date I 2/1412_ c Commission Use Only Sundry Number: 5 2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test I/ Location Clearance r Other: �,{ AS[ MS DEC 14 20 Spacing Exception Required? Yes El No L7J Subsequent Form Required: /6- Yb l A // APPROVED BY / 2_0 Z / J/ Approved by: COMMISSIONER THE COMMISSION Date: ✓ O RriG4 NiAL012 Appr•ved application is valid for 12 A � months from the date of approval. ti �L f' \ Submit Form and Attachments in Duplicate �o' L �l z \� .. • 0 3N -13 Tubing Patch Installation 3N -13 was completed July 1986 as a C & A sand well with 2 -7/8" tubing. 3N -13 was an injector until June 2011. It was converted to a producer to reduce reservoir pressure for CTD of 3N -07A producer. 3N -13 produced Nov 2011 to Jan 2012. When 3N -07A CTD completed, 3N -13 was converted back to an injector to support 3N -07A, but 3N -13 now has an annular communication leak to be repaired before it can be returned to PWI service. An 8 -9 -08 LDL noted a leak anomaly at 7330' RKB around the top of the packer. The PBR is immediately above the packer. On 6 -5 -12, a plug was set in the tubing tail and an MIT -T to 3000 psi passed. On 8- 24 -12, an MIT -T to 3000 psi and DDT -IA passed, but the DDT -T was inconclusive, and a MIT -IA to 3000 psi failed (LLR -IA of 0.088 gpm), indicating a 1 -way tubing leak in the Packer /PBR area. The 1 -way tubing leak will be repaired per the following procedure. Procedure: Slickline 1. Run dummy patch drift simulating top run dimensions of tubing patch to 7350' RKB. 2. RIH & pull the 2.25" CA -2 Plug from the Camco D Nipple at 7371' RKB. 3. RIH & Brush & Flush 3.5" tubing at 7280 - 7360' RKB in the area to be patched. Digital Slickline or E -line 4. RIH with a 2.29" run OD Retrievable Packer for a tubing patch and set it at 7346' RKB. This puts the packer near the top of a 2- 7/8" full joint just below the Brown HB Packer. Set a test plug in the packer. Due to the direction of the 1 -way leak, we cannot CMIT to test the lower packer. Perform a MIT -T to 2500 psi to verify packer integrity. Note, since 3N -13 leak diagnostics indicate the leak to be patched is a 1 -way leak from IA to Tbg, we should be able to obtain a passing MIT -T. However, if the MIT -T fails it may not necessarily mean the packer lacks integrity, since a failed MIT -T could mean we also now have Tbg to IA communication through the leak. Pull test plug. Digital Slickline or E -line 5. RIH with tubing patch assembly #2 consisting of (top to bottom) 2.29" OD Packer for set in 2 -7/8" tubing, crossover, telescoping expansion joint, blank spacer pipe, and an Anchor Latch Seal Stinger. Sting Anchor Latch into Packer at 7346' RKB. Shear up to shear pin and stroke out the telescoping joint about half way ( -6' of PU) then set the upper Packer of the patch at 7303' RKB. POOH with setting tools. This sets the top patch packer near the bottom of a 2 -7/8" full joint above a 4' pup made up to the top of the PBR to complete the patch at 7303' - 7346' RKB. Set test plug in Packer at 7303' RKB and perform MIT -T to 2500 psi to verify good set integrity of upper packer. Pull test plug. Perform MITIA to 2500 psi to verify integrity of tubing patch. RD. Return 3N -13 to PWI. JWP 12/7/2012 KUP • 3N -13 Conoc 011 Well Attributes Max Angle & MD TD • .117 ; Wellbore API/UWI Field Name Well Status 'noi (°) MD (ftKB) Act Btm (ftKB) 500292158400 KUPARUK RIVER UNIT PROD 44.33 3,900.00 7,875.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date wen co rp 3N131o;aorzolz ezt3z AM . SSSV: TRDP Last WO: I 39.49 4/27/1986 Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 7,746.0 11/16/2011 Rev Reason: WELL REVIEW osborl 10/30/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 35 £ SURFACE 95/8 8.921 37.0 3,774.0 3,627.7 36.00 J - 55 BTC 1 ;a ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd PRODUCTION 7 6276 27.4 7,872.9 6,666.5 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd TUBING I 27/8 I 2.441 35.0 I 7,404.5 6,308.7 I 6.50 J-55 I EUE 8rd ABM coeou Completion Details 38 -715 Top Depth (TVD) Top Inc! Nomi... r r O r---7 I Top (ftKB) (ftKB) (°) Item Description Comment ID (In) SAFETY VLV, 1,784 JL 35.0 35.0 0.19 HANGER FMC TUBING HANGER w/ PUP 2.875 e _ 1,784.2 1,784.0 0.87 SAFETY VLV BAKER FVL SAFETY VALVE 2.310 7,316.5 6,242.0 40.70 PBR BROWN PBR 2.890 7,333.1 6,254.7 40.64 PACKER BROWN HB PACKER 2.890 ‘ „...{' 7,371.3 6,283.7 40.51 NIPPLE CAMCO D NIPPLE NO GO 2.250 IA't t M 1^,1•J J 7,403.5 6,308.0 40.16 SOS BROWN SHEAR OUT SUB 2.441 SURFACE, J Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT. (TVD) Top Inc' 7,273 _,. at Top (kKB) (ftKB) (°) Description Comment Run Date ID (in) II I r1 p y � • 7,371.3 6,283.7 40.51 PLUG 2.25" CA -2 PLUG 6/6/2012 0.000 Perforations & Slots Shot Top (TVD) 131m (TVD) Dens PBR, 7,316 ` Top (MB) Btm (ftKB) (RKB) (ftKB) Zone Date (sh -. Type Comment .� 7,485.0 7,505.0 6,370.3 6,385.6 C UNIT B, 10/6/2000 4.0 APERF 180 deg ph; 2 1/8" EJ PACKER, 7.333 L6 3N - p aV 7,557.0 7,571.0 6,425.3 6,436.0 A-3, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ NIPLUGPPLE, 7,371 hy{/ (A l 7,563.0 7,564.0 6,429.9 6,430.7 A-3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II . 7,371 S- �� ® 7,566.0 7,567.0 6,432.2 6,433.0 A-3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,568.0 7,569.0 6,433.7 6,434.5 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II SOS. 7.404 7,570.0 7,571.0 6,435.3 6,436.0 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,580.0 7,603.0 6,442.9 6,460.3 A -2, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ 7,591.0 7,592.0 6,451.3 6,452.1 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II APERF, 7,465 - 7.505 7,595.0 7,596.0 6,454.4 6,455.1 A-2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,599.0 7,600.0 6,457.4 6,458.2 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,601.0 7,602.0 6,458.8 6,459.6 A-2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,606.0 7,607.0 6,462.6 6,463.4 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,621.0 7,654.0 6,474.1 6,499.4 A -1, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II - Notes: General & Safety IPERF, End Date Annotation 7,583 - 7,564 6/22/1994 NOTE: WAIVERED WELL: T x IA COMMUNICATION RPERF, 7,557 11/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 _ 11/30/2010 NOTE: Mandrel @ 7273 - SET EXT PKG (AVA SEALS) 1/8/99 7,56&i 567 - - 10/30/2012 NOTE: PROD CSG/TUBING RKB DISCREPANCY DUE TO RIGS' RKBs IPERF, 7,588 -7,569 IPERF. 7,570 -7,571 1--' RPERF. 7 l\ ,580.7,603 \ ® m PER -, 7,591 -7,592 o IPERF. 7,595 -7,598 4-4. = PER -. 7,599 -7,600 IPERF. - a� 7,601 -7,802 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (106) (°) Make Model (in) Sery Type Type ('n) (psi) Run Date Com... IPERF, 1 7272.9 6,209.1 40.84 MMH FMHO 1 GAS LIFT DMY RK 0.000 0.0 11/8/1999 7,606 -7,607 PER -, 11 III PRODUCTION, 27 -7,873 N__Al TD, 7,875 • IP • w \���� �jj� s � THE STATE Alaska Oil and Gas ��4 - '� °fA LA KA Conservation Commission ,ffrf.i _= 1 GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0.0, * 572 ALA Anchora 9 e, Alaska Main: 907.12 SCANNED JAN 2 5 2013 Fax: 907.276.7542 Darrell Humphrey 4g.-- �� NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -13 Sundry Number: 312 -455 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 day of December, 2012. Encl. STATE OF ALASKA - AllOICA OIL AND GAS CONSERVATION COMOION I, AV (64/1( APPLICATION FOR SUNDRY APPROVALS I ti • 20 AAC 25.280 T. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend f j Rug Perforations r Perforate r Pull Tubing r Time Extension Operational Shutdown r Re -enter Susp. Well r Stimulate I Alter casing g r Other:Convert Prod to INJ r • . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development • . Exploratory r 186 - 081 • f 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 2158400 • - 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? p �' Will planned perforations require spacing exception? Yes r No 3N -13 • _ !' 1 9. Property Designation (Lease Number): 10. Field /Pool(s): " 1 1 al 1 z, ADL 25520 • - Kuparuk River Field / Kuparuk River Oil Pool • . DEC 0 3 2012 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (meas jAOGCC 7875 • , 6668 • 7792' 6604' 7371' - Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3737 9.625 3774' 3628' PRODUCTION 7845 7 7873' 6666' Perforation Depth MD ( 7485 -7505, Perforation Depth TVD (ft): 6370 -6386, Tubing Size: Tubing Grade: Tubing MD (ft): 7557 -7571, 7580 -7603, 7606 -7607, 7621 -7654 6425 -6436, 6443 -6460, 6463 -6463, 6474 -6499 2.875 J - 7404 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN HB PACKER MD= 7333 TVD= 6255 • SSSV - BAKER FVL SSSV • MD =1784 TVD =1784 12. Attachments: Description Summery of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service I' ' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/15/2012 • Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ 17 • • GINJ IT WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen / Darrell Humphrey Email: n1139aconocophillips.com Printed Name Bob Christensen / Darrell Humphrey Title: NSK Production Engineering Specialist Signature ).-- Al. J Phone: 659 -7535 Date / 1 - Zq • / 2._ Commission Use Only Sundry Number: '312, Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: / L ;o yt d w G±rGG. 5 r- (4) �U Z 4-W\ Spacing Exception Required? Yes ❑ No [7f Subsequent Form Required: /6)— y y FI O t* DE C 0 6 2012 10 � / APPROVED / � Approved by:( g ( � �j / -- COMMISSIONER THE COMMISSION Date: 12— to — l Approved application is valid for 12 months from the date of approval. ; Form 10 -403 (Revised 10/2012) j •( in Duplicate S ubmit Form and Attachments 'V . 2 . e . �DRIGINAL ' g% fV -\,1. • 3N -13 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3N -13 (PTD 186 -081) from Oil Production service to Water Injection service. Resevoir depressurization activities for CTD have been completed in this area. W'S Li/' ' Vi rl /1/4 can T r em y fro b t, reeve c f(i f e5sv !e fo j' rvlOserl ' 01;141, c%r6h'✓, rS T. a. %,' ©, % otef e.y tor s 'zy,7 el /5 Co", fiellre, 5'O vt,e I rf 19, l374 CAA/ to i n Di',4t ( se/ 'ce • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. / Greater Kuparuk Unit , NSK -69 Y PO Box 196105 ConocoPhi H l i ps Anchorage, AK 99519 -6105 Phone: 907 659 -7535 Fax: 659 -7314 November 29, 2012 Dan Seamount RECEIVED AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 3 2012 33 W. 7 Ave. Ste. 100 AOGCC Anchorage, AK 99501 VV Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 3N -13 from Oil Production to Water Injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3N -13. (PTD 186 -081). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659 -7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic - _ ..-- p1,• i KUP • 3N -13 + ConocoPhillips 0 Well Attributes Max Angle & MD TD Alaska Inc. Wel!bore API/UWI Field Name Well Status Inc! ( °) MD (WEI) Act Btm (ftKB) . cnocoPlwapc 500292158400 KUPARUK RIVER UNIT PROD 44.33 3,900.00 7,875.0 -A ' Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date ••• Well Conflp: - 3N -13, 10130/2012 9:27:32 AM SSSV: TRDP Last WO: 39.49 4/27/1986 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 7,746.0 11/16/2011 Rev Reason: WELL REVIEW osborl 10/30/2012 d Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd HANGER, 35 i SURFACE 9 5/8 8.921 37.0 3,774.0 3,627.7 36.00 J BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 27.4 7,872.9 6,666.5 26.00 J -55 BTC l Tubing Strings 1 Tubing Description ' 0... String ID ... Top (ftKB) Depth (f... Depth (NO) ... String Wt... String ... String Top Thrd TUBING 1 2 7/8 2.441 I 35.0 I Set 7,404.5 'Set D 6,308.7 I 6.50 I J -55 I EUE 8rd ABM CONDUCTOR, Completion Details 3 8-115 Top Depth (TVD) Top Inc! Noml... SAFETY VLV, Top (RKB) (RKB) (1 Rem Description Comment ID (In) 1,784 / 1 ° 35 35.0 0.19 HANGER FMC TUBING HANGER w/ PUP 2.875 1,784.2 1,784.0 0.87 SAFETY VLV BAKER FVL SAFETY VALVE 2.310 7,316.5 6,242.0 40.70 PBR BROWN PBR 2.890 1 41 1 7,333.1 6,254.7 40.64 PACKER BROWN HB PACKER • 2.890 7,371.3 6,283.7 40.51 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,403.5 6,308.0 40.16 SOS BROWN SHEAR OUT SUB 2.441 SURFACE, Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, } I (ND) Top Inc! 7.273 Top (810) (ftKB) C) Description Comment Run Date ID (in) H 7,371.3 6,283.7 40.51 PLUG Perforations & Slots 2.25" CA -2 PLUG r 6/6/2012 0.000 Shot Top (ND) Btm (TVD) Dens PER 7.318 Top (RKB) Btm (RKB) (RKB) (ftKB) Zone Date (sh Type Comment PACKER, 7,333 -- 7,485.0 7,505.0 6,370.3 6,385.6 C-1, UNIT B, 10/6/2000 4.0 APERF 180 deg ph; 2 1/8" EJ 3N -13 la 7,557.0 7,571.0 6,425.3 6,436.0 A-3, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ NIPPL E, 7,371 / � � , , a ; y 7,563.0 7,564.0 6,429.9 6,430.7 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet I I PLU 7,371 t 7,566.0 7,567.0 6,432.2 6,433.0 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,568.0 7,569.0 6,4337 6,434.5 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 505, 7,404 . w . 7,570.0 7,571.0 6,435.3 6,436.0 A-3, 3N -13 7/19/1986 ' 1.0 IPERF 120 ph; 4" Jumbo Jet II J APERF, 7,580.0 7,603.0 6,442.9 6,460.3 A-2, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ 1111 _ _- 7,591.0 7,592.0 6,451.3 6,452.1 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,485-7,505 7,595.0 7,596.0 6,454.4 6,455.1 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,599.0 7,600.0 6,457.4 6,458.2 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,601.0 7,602.0 6,458.8 6,459.6 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,606.0 7,607.0 6,462.6 6,463.4 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet 11 7,621.0 7,654.0 6,474.1 6,499.4 A -1, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II Notes: General & Safety IPERF, End Date Annotation 7.563-7.564 -- 6/22/1994 NOTE: WAIVERED WELL: T x IA COMMUNICATION RPERF, 7,557 -7.571 11/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 11/30/2010 NOTE: Mandrel @ 7273 - SET EXT PKG (AVA SEALS) 1/8/99 IPERF, 7,566 -7,567 10/30/2012 NOTE: PROD CSG/TUBING RKB DISCREPANCY DUE TO RIGS' RKBs IPERF, _ 7,568 -7,569 IPERF, - 7,570 -7,571 - RPERF, 7,580 IPERF, -7,603 \ 7,591 -7,592 - IPERF, 7,595 -7,588 IPERF, - 7,599 -7,600 - IPERF, 7,801 -7,802 Mandrel Details Top Depth Top Port (NO) Intl OD Valve Latch Sire TRO Run Stn Top (RKB) (RKB) (1 Make Model (In) Sery Type Type (In) (psi) Run Date Com... IPERF, 1 7,272.9 6,209.1 40.84 MMH FMHO 1 GAS LIFT DMY RK 0.000 0.0 11/8/1999 7,606 -7,607 IPERF, 7,621 -7.654 PRODUCTION. 27- 7,873 ' TD, 7,875 • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPh ' ps Anchorage, AK 99519 -6105 Phone: (907) 659 -7535 Fax: 659 -7314 November 29, 2012 Dan Seamount RECEIVED AOGCC Commissioner DEC State of Alaska, Oil & Gas Conservation Commission 3 2012 33 W. 7' Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 3N -13 from Oil Production to Water Injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3N -13. (PTD 186 -081). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659 -7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon n Repair well fl Rug Perforations f ( Stimulate [j Other n Converting WINJ P Tubing to Producer Alter Casing � g ❑ Perforate New Pbol ❑ Waiver r Time Extension Change Approved Program r Operat. Shutdow n ❑ Perforate fl Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development in Exploratory r - 186 -081 3. Address: 6. API Number: Stratigraphic r Service pi P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21584 - 00 " a) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 25521,25520 3N -13 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7875 feet Plugs (measured) None true vertical 6668 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 7333 true vertical 0 feet (true vertucal) 6255 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3737 9.625 3774 3628 PRODUCTION 7845 7 7873 6667 5 0k0E0 , A?R b '612 RECEIVED Perforation depth: Measured depth: 7, 485 -7, 505;7, 557 - 7,571;7,580- 7,603;7,621 -7,654 MAR 2 7 2012 True Vertical Depth: 6, 370 -6, 385;6, 425 - 6,436;6,442- 6,460;6,474 -6,499 Alaska Oil & Gas Cons. Commission Tubing (size, grade, MD, and TVD) 2.875, J -55, 7404 MD, 6308 TVD Anchorage Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB PACKER @ 7333 MD and 6255 TVD SSSV -BAKER FVL SAFETY VALVE @ MD =1784 TVD =1784 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1805 2809 2845 Subsequent to operation 4 0 2138 944 655 13. Attachments 14. Well Class after work: - Copies of Logs and Surveys run Exploratory ❑ Development 0 • Service ❑ Stratigraphic r 15. Well Status after work: Oil 0 Gas [1 WDSPL Daily Report of Well Operations )000( GSTOR r WINJ [ WAG r GINJ [J SUSP ❑ SPLUG r 16. 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: 311 -345 Contact Darrell Humphrey / Bob Christensen Printed Name Robert D. , risten : n Title Production Engineering Specialist Signature ` / ' �/ —Phone: 659 -7535 Date i'34®, / l/ 7,r!. z-r6.c i � � 0// Form 10-404 RevlsL @QM) 0 APR 0 2 2012 Submit Original Only • 3N -13 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/16/11 TAG BTM © 7528' SLM. EST 92' OF RATHOLE, MEASURE SBHP @ 7570' = 4340 pis, RKB JOB COMPLETE. 11/16/11 TURNED WELL TO PRODUCTION I KUP 3N -13 ConocoPhillips °- Well Attributes • Max Angle & MD TD Wallbore APIIUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (f68B) - "n.,sf,.laps 500292158400 KUPARUK RIVER UNIT PROD 44.33 3,900.00 7,875.0 Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date "' . SSSV: TRDP Last WO: 39.49 4/27/1986 Well Confip. - 3N -13 1222011 300.16 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation (Last Mod ... End Date Last Tag: RKB 7,746.0 11/16/2011 Rev Reason: TAG ninam 12/2/2011 Casing Strings • Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (1686) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,774.0 3,627.7 36.00 J - 55 BTC • . Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 35 ' PRODUCTION 7 6.276 27.4 7,872.9 6,666.5 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (TVD) ... String Wt... String ... String Top Thrd • a " ..: ' TUBING 2 7/8 2.441 35.0 7,404.5 6,308.7 6.50 J -55 EUE 8rd ABM Completion Details Top Depth (TVD) Top Inc! Noml... CONDUCTOR, Top (6186) (ftKB) ( °) Item Description Comment ID (In) 38 115 35.0 35.0 0.19 HANGER FMC TUBING HANGER w/ PUP 2.441 c--- 1,784.2 1,784.0 0.87 SAFETY VLV BAKER FVL SAFETY VALVE 2.310 SAFETY 1VLV: I p 1 l 7,316.5 6,242.0 40.70 PBR BROWN PBR 2.500 1 I i 7,333.1 6,254.7 40.64 PACKER BROWN HB PACKER 3.000 7,371.3 6,283.7 40.51 NIPPLE CAMCO 0 NIPPLE NO GO 2.250 7,403.5 6,308.0 40.16 SOS BROWN SHEAR OUT SUB 2.441 Perforations & Slots • Shot Top (TVD) Btm (TVD) Dens T op 8!166) Btm (ftKB) (ftKB) (rtKB) Zone Date ("-ii Type Comment s 3 RFA 77i 7,485 7,505 6,370.3 6,385.6 C-1, UNIT B, 10/6/2000 4.0 APERF 180 deg ph; 2 1/8" EJ 3N -13 GAS LIFT, 7,557 7,571 6,425.3 6,436.0 A-3, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ 7,273 7,563 7,563 6,429.9 6,429.9 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet 11 7,566 7,566 6,432.2 6,432.2 A -3, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,568 7,568 6,433.7 6,433.7 A -3, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4 "Jumbo Jet II [ ..___I 7,570 7,570 6,435.3 6,435.3 A -3, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II PBR, 7,316 } l ] 7580 7,603 6,442.9 6,460.3 A -2, 3N -13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ 7,591 7,591 6,451.3 6,451.3 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II PACKER, 7.333 , 7,595 7,595 6,454.4 6,454.4 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,599 7,599 6,457.4 6,457.4 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,601 7,601 6,458.8 6,458.8 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II NIPPLE, 7,371 7,606 7,606 6,462.6 6,462.6 A -2, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,621 7,654 6,474.1 6,499.4 A -1, 3N -13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II Notes: General & Safety SOS, 7,404 i End Date Annotation 6/22/1994 NOTE: WAIVERED WELL: T x IA COMMUNICATION 11/30/2010 NOTE: Mandrel @ 7273 - SET EXT PKG (AVA SEALS) 1/8/99 II II 11/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 APERF, 7,4167,505 IPERF, 7,563 - RPERF, 7357-7371 IPERF, 7,566 IPERF, 7,568 IPERF, 7,570 IPERF, 7591 RPERF, 7,560 -7,603 IPERF, 7,595 i IPERF, 7.599 IPERF, 7,601 Mandrel Details Top Depth Top Port (TVD) Inc] OD Valve Latch Sire TRO Run IPERF, 7,606 - Stn Top (ftKB) (MO) ( °) Make Model (in) Seto Type Type (in) (psi) Run Date Cont.. 1 7,272.9 6,209.1 40.84 MMH 2.875 x 1.5 1 GAS LIFT DMY RK 0.000 0.0 11/8/1999 IPERF, 111 II 7,821- 7,654 PRODUCTION, 27-7,873 N.„.___.& • T0, T875 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 02, 2011 9:28 AM To: 'NSK Problem Well Supv' Subject: RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 Kelly, If 3N -11 will be sidetracked /redrilled (becoming 3N -11A) then 3N -11 will cease to exist and the AA can be cancelled. If no injection is planned prior to the plugging, then you can request that the AA be cancelled. Tom From: NSK Problem Well Supv [maiito:n1617 @conocophillips.com] Sent: Friday, December 02, 2011 9:08 AM To: Maunder, Thomas E (DOA) Subject: RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 • Tom, Just so I'm clear- you mentioned that unless something physically changes, the AA will continue to apply. Since 3N -11 will be sidetracked, that sounds like a physical change to me. So that one will need a cancellation and a reapply? Thanks a ton Brent Rogers / Kelly Lyons Problem Wells Supervisor r -� ; t ! • t L, i ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 01, 2011 2:38 PM To: NSK Problem Well Supv • Cc: Dethlefs, Jerry C Subject: [EXTERNAL]RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 Kelly, I believe it is appropriate to view the AA's as suspended. They apply to the wells' operation while injecting. If the wells are returned to injection service, unless something has been physically changed in the wells the AA's should continue to apply. I hope this helps. Only thing to remember is to submit sundries to convert the wells back to injectors and provide verification of integrity. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ maiito :n1617 @conocophillips.com] Sent: Thursday, December 01, 2011 11:08 AM To: Maunder, Thomas E (DOA) 12/2/2011 Page 2 of 2 Cc: Dethlefs, Jerry C Subject: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12- 01 -11 Tom, Kuparuk wells 3N -11 (PTD 186 -077, A10 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) recently received approved sundries to temporarily produce these service wells in order to depressurize the formation in prep for CTD workovers. Since these were injectors that operated under variances, I would appreciate direction on how to handle the wells before they are put back on injection, following their temporary production period. Should I ask for an official cancellation of the AA's and resubmit applications for new ones when they are ready to be brought back on injection? Or is it sufficient to view the current AA's simply as suspended? It is my understanding that 3N -11 will be sidetracked, however 3N -13 will not be worked over (only depressurized to assist in the planned 3N- 07 CTD workover) and the time line for each is listed in the email below. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 rL ember 22, 2011 1:16 PM c -11, & 13 producers Jerry The plan as I understand it now is: 1) 3N -11 is scheduled for a workover in about a month - we would like to flow it until then to get the pressure down so it can be worked over and not have to use more expensive brine 2) 3N -13 we would like to flow for 1 to 2 months, get a pressure and then flow another month or 2 Both wells have been shut in for 5 or 6 months, but are not dropping pressure very fast. We have been in a vicious cycle - can't schedule the CTD because the psi is too high, but can't get priority to flow back and get the psi down because the wells are so far out on the schedule! Lamar 12/2/2011 • • LIF "TOE 0[F / jj\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell Humphrey Production Engineering Specialist v ConocoPhillips Alaska, Inc. P.O. Box 100360 ` Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -13 Sundry Number: 311 -345 • 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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 - weekend. Sinc- '4 , . om I is .. ner DATED this day of November, 2011. Encl. } TATE OF ALAS 1� L CL t t ALASKA OIL At�AS CONSERVATION COMMISSION i / APPLICATION FOR SUNDRY APPROVALS tt 20 AAC 25.280 1. Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: WINJ to Prod. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -081 3. Address: 6. API Number: Stratigraphic "r Service F , P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21584 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No n 3N -13 • 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25520 ALK 2556 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 TVD (ft): Plugs (measured): Junk (measured): 7875 ' 6668 . 7792' 6604' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR (QC) 78 16 115' 115' SURFACE (QC) 3737 12 3774' 3627' PRODUCTION `• 7845, 7 • 7873' 6665' Perforation Depth MD (ft): Perforation Depth TVD (ft): ` Tubing••Size: Tubing Grade: Tubing MD (ft): 7505, 7557 -7571, 7580 - 7603,7606, 7621 6370 -6385, 6425 - 6436,.6443 - 6460, 6462, 6474 2.875 J - 7404 Packers and SSSV Type: " Packers and SSSV MD (ft) and TVD (ft) RECEIVED' PBR - BROWN PBR MD= 7316 TVD= 6242 PACKER - BROWN 'HB' PACKER MD= 7333 TVD= 6255 NIPPLE - CAMCO 'D' NIPPLE NO GO MD= 7371 TVD= 6283 NOV 04 2011 SOS- BROWN MD= 7404 TVD= 6309 SSSV = TRDP - BAKER 'FVL' MD= 1784 TVD= 1784 Alaska Oil & Gas Cons. Canarission 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: A?)t:ili g"0 Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: November 15, 20111 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR T SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey Printed Name Darrell Humphrey Title: Prod. Engineering Specalist Signature •-y�taiX { ",___ S >`,1 Phone: 659 -7535 Date (l . 2_ t i Commission Use Only ! Sundry Number):/ I -/� ) Conditions of approval: Notify Commission so that a representative may witness ��ll ✓ 7 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /C — • APPROVED BY ���e_ // Approved by: ������11�� OMMISSIONER THE CO Date: / Form 10 -403 Revise�i`'i!�(J14lS lidiri, NA ]' '` ll �/ S ubmit in Duplicate / ,r, I • 3N -13 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3N -13 from Water Injection service to Oil Production service . The 16" Conductor was cemented with 247sx CS II (115' and / 115' tvd). The 9 -5/8" Surface casing (3774' and / 3627' tvd) was cemented with 1100sx AS III and 300sx Class G. The 7" Production casing (7873' and / 6665' tvd) was cemented with 320sx Class G and 175sx AS I. The top of the Kuparuk C was found at 7470' and / 6359' tvd. The top of the Kuparuk A was found at 7543' and / 6414' tvd. 7/8/10 (WC) MITT- passed; CMIT- passed (State witnessed Chuck Scheve) Initial T /I /O= 1860/1640/0; Pressured up T to 3000psi. with .5bbls. of diesel T/I /O= 3020/1670/0; 15min. reading T /I /0= .2840/1680/0; 30min. reading T /I /0= 2770/1690/0; Pre -test Initial T /I /O= 2770/1690/0; Pressured up IA to 3000psi. with 1 bbls. of diesel T /I /O= 2960/3010/0; 15min. reading T /I /O= 3140/2960/0; 30min. reading T /I /O= 3160/2950/0; Bled IA & T. Final T /I /O= 500/500/0 fee / L / _ / av7 ai" kip 44e iv fed c€ fe ervO►'r f/YISXte" iA 7` 3 Grel . O!'q/!Y lb eS614' 1‘. Cr' 0pe /oh:903 0 Q' 4444 l P 3N -13 • ConocoPhillips 1a Well Attribute Max Angle fit TD Al itik,t, r1�. Wellbore APIAIWI Field Name Well Status Inci (°) MD (RKB) Act Btm (RKB) canocoH.ltips 500292158400 KUPARUK RIVER UNIT INJ 44.33 3,900.00 7,875.0 • " Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date . - -- SSSV: TRDP Last WO: 39.49 4/27/1986 Well Couto - 3N -13, 101302010 11.02 - .38 AM '�� . Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 7,736.0 10/13/2010 Rev Reason: TAG Imosbor 10/30/2010 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description (in) (in) Top (RKB) (RKB) (RKB) (Ibeltt) Grade String Top Thrd CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H -40 iim , y - SURFACE 95/8 8.765 0.0 3,774.0 3,627.7 36.00 J -55 PRODUCTION 7 6.151 0.0 7,872.0 6,665.8 26.00 J -55 coNOUCro s Tubing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Tubing Description (in) (in) Top (RKB) (MB) (RKB) (Ibsm) Grade String Top Thrd SAFETY VLV, f o 1 TUBING 2 7/8 2.441 0.0 7,404.0 6,308.4 6.50 J - 55 EUE 8RD ABM 1,784 Other In Hole (All Jewelry: Tubinf Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Inc! Top (MB) (RKB) ( °) Description Comment Run Date ID (in) 1,784.0 1,783.7 0.87 SAFETY VLV Baker'FVLTRDP 7/20/1986 2.310 SURFACE, • 3.774 7,273.0 6,209.1 40.84 GAS LIFT MMH/2 7/8 X 1.5/1 /DMY /RK/ // Comment: SET EXT. PKG 11/8/1999 2.347 (AVA SEALS)1/8/99 STA 1 GAS LIFT, c .5 7,316.0 6,241.7 40.70 PBR Brown PBR 7/20/1986 2.500 7,273 7,333.0 6,254.6 40.64 PACKER Brown'HB' PACKER 7/20/1986 3.000 7,371.0 6,283.5 40.52 NIPPLE Camco'D' Nipple NO GO 7/20/1986 2.250 7,404.0 6,308.4 40.16 SOS Brown 7/20/1986 2.441 7,404.0 6,308.4 40.16 TTL 7/20/1986 2.441 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens PBR, 7,315 Top (MB) Bbn )RKB) (MB) (RKB) Zone Date (sb... Type Comment 7,485.0 7,505.0 6,370.3 6,385.6 C-1, UNIT B, 10/6/2000 4.0 APERF 180 deg ph; 2 1/8" EJ 3N-13 ` 1 � 7,557.0 7,571.0 6,425.3 6,436.0 A -3, 3N-13 10/7/1988 4.0 RPERF Zero deg ph; 21/8" EJ �` 7,563.0 7,563.0 6,429.9 6,429.9 A-3, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II PACKER, 7,333 7,566.0 7,566.0 6,432.2 6,432.2 A-3, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II J 7,568.0 7,568.0 6,433.7 6,433.7 A -3, 3N-13 7/19/1986 1.0 IPERF 120 ph: 4" Jumbo Jet II 7,570.0 7,570.0 6,435.3 6,435.3 A -3, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,580.0 7,603.0 6,442.9 6,460.3 A -2, 3N-13 10/7/1988 4.0 RPERF Zero deg ph; 2 1/8" EJ 7,591.0 7,591.0 6,451.3 6,451.3 A -2, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet 11 I 7,595.0 7,595.0 6,454.4 6,454.4 A -2, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4 " Jumbo Jet II NIPPLE, 7s71 -- 7,599.0 7,599.0 6,457.4 6,457.4 A -2, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II 7,601.0 7,601.0 6,458.8 6,458.8 A -2, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4 " Jumbo Jet II 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II /1 7,606.0 7,606.0 6,462.6 6,462.6 A-2, 3N-13 7,6210 7,654.0 6,474.1 6,499.4 A -1, 3N-13 7/19/1986 1.0 IPERF 120 ph; 4" Jumbo Jet II Annotation Notes: General & Safety End Date 6/22/1994 NOTE: WAIVERED WELL: T x IA COMMUNICATION TTL, 7.T4 ll sos. � 400 APERF, 7,47,505 <_? IPERF, 7,563 RPERF, 7,557 -7,571 IPERF, 7,566 -- • IPERF, 7,568- • • IPERF. 7.570 - • IPERF, 7,591 - RPERF, --- 7,580-7.603 - --:± IPERF, 7,595 IPERF, 7,599 IPERF, 7,601 IPERF, 7,606 - - -- IPERF, M 7,621 -7,654 PRODUCTION, 7,672 N TO, 7,875 • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhul l i ps Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 November 2, 2011 RECEIVEly Dan Seamount NOV 04 ?Oil AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission Aaka Oil & GeS COOS, Cor e 33 W. 7 Ave. Ste. 100 Ancnurogo Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3N-13 from Water Injection Service to Oil Production service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3N -13 (PTD 186 -081). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey Attachments Sundry application Well schematic 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 10, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3N -13 Run Date: 10/26/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -13 Digital Data in LAS format, Digital Log Image file, Interpretat an Report 1 CD Rom 50- 029 - 21584 -00 Injection Profile Log 1 Color Log 50 -029 - 21584 -00 tMNEE) NOV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton. woodC&, hal lihurto n. com Date: - Signed: g t., � p • MEMORANDUM TO: Jim Regg P.I. Supervisor ~~ 7~2/~.Ilo FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA II1C 3N-13 KUPARUK RIV UNIT 3N-13 Src: Inspector N(1N-CnNFiDENTIAL ~~ Reviewed By: P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV UNIT 3N-13 API Well Number: 50-029-21584-00-00 Inspector Name: Chuck Scheve mitCS100711171009 Insp Num: Permit Number: 186-081-0 Inspection Date: 7/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-13 ~ Type Inj. N TVD ~ 6254 IA 1640 ~I 1670 1680 1690 P.T.D 1860810 •~ TypeTCSt i SPT i TCSt psl ( ~ 1563 ~A I 0= 0 0 0 ~ p/F' Interval REQv -~P Tubing' ls6o 3020 28ao 270 Notes: MITT with a plug set in the tubing tail and the tubing pressured up to 3000 psi, the pressures indicated tubing x IA comunication as is stated in thee AA. .~ r r~ 4 r. u'~, `~RI't ~r "~4K~A ,. Wednesday, July 14, 2010 Page 1 of I MEMORANDUM To: Jim Regg P.I. Supervisor I 7' ~~' `l a FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-13 KUPARUK RIV LIMIT 3N-13 Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3N-13 API Well Number: 50-029-21584-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100711171915 Permit Number: 186-081-0 Inspection Date: 7/8/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-13 . Type Inj. ~ TVD I 6254 i IA 1690 3010 - I 2960 2950 P.T.D. 1860810- TypeTest i SPT Test psi 1563 ~ QA ~ 0 0 0 0 Interval REQvAR p/j+' P 'Tubing 2"T70 2960 3140 ~ 3160 Notes: CMIT T x IA, with a plug set in the tubing tail and the tubing pressured up to2770 psi, and the IA pressured to 3010, results indicated IA x Tubing comunication as is stated in the AA. ~ ~-- , U ~ -~ F{) tf, I .. Wednesday, July 14, 2010 Page 1 of 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocaPhi{lips Alaska Inc. Kuparuk /KRU / 3N 07/08!10 Colee /Phillips - AES Chuck Scheve Packer Pretest Initial 15 Min. 30 Min. We11 3N-13 T In. N 7VD 6,255' Tubi 1,860 3,020 2,840 2,770 Interval V P.T.D. 1860810 T test P Test 3000 Casi 1,640 1,670 1,680 1,690 P/F P Notes: MITT per AIO 26.038 (amended} OA 0 0 0 0 CA-2 u set 7371' Well 3N-13 T In". N TVD 6,255 Tu " 2,770 2,960 3,140 3,160 Interval V P.T.D. 1860810 T test P Test 3000 Casi 1,690 3,010 2,960 2,950 P/F P Notes: CMIT TxIA per AIO 28.038 (amended} OA 0 0 0 0 CA-2 u set 7371' Well T In'. TVD Tu#>i Interval P.T.D. T test Test Casi P/F Notes: OA Wefl T In . TVD Tubi Interval P.T.D. T test Test i Casi PiF Notes: OA Well T In". TVD Tubi Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radaective Tracer Survey A =Temperature Arwmaly Survey D = Differential Temperature Test ~ <<~. INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 3N-1307-08-10.x15 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [nl617 @conocophillips.com] Sent: Monday, July 05, 2010 2:08 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3N -13 (PTD 186 -081) Request for delay in compliance testing Attachments: 3N -13 schematic.pdf Jim, Tom, Guy Kuparuk water injector 3N -13 (PTD 186 -081) is due for the AA compliance testing to be completed by 07/06/10. ConocoPhillips has attempted to set the TTP for the compliance testing for a week. There has been several delays due to a rig move off of 3N pad, the availability of the well, and the pad stability following the rig leaving location. Currently slickline is on the well setting the TTP. The well will remain SI with the plug until the testing has been completed. Once the plug has been set and the well pre - tested to verify the plug is holding, the North Slope inspectors will be contacted to arrange the witnessed testing. Attached is a 90 day TO plot and a schematic. 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 CHOKE — FTP - - - - -- FTF IAP OAP TIVO Plot - 3N -13 2500 200 2000 ........................................................................................................................ ............................... 150 1500 ........................................................................................................................ ............................... E W U) 100 Y 0 1 000 ...................................................................................................... ...........I................... L v 50 500 ............................................................................................. ............................... 0 0 05- Apr -10 18- Apr -10 01- May -10 14- May -10 27- May -10 09- Jun -10 22- Jun -10 Date NOV 1 52010 11/15/2010 Injection well3N-13 (PTD 186-081, AA AIO 26.038) • • Regg, James B (DOA} From: Regg, James B (DOA) i Sent: Thursday, February 12, 2009 9:17 AM ~ ~ ~f t~'I?~~ To: 'NSK Well Integrity Proj' Subject: RE: Injection well 3N-13 (PTD 186-081, AA AIO 26.038) Page 1 of 3 Based on my Last email (12/24/08), it appears I dropped the ball. I agreed to work on a revised admin approval for 3N-13 to allow IA pressures up to 3000 psi with installation, maintenance and testing of OA HPP. I'll get on that; don't think i need anything more. Thank you for being proactive in installing the OA HPP. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~- ~ , ~ ~~~_ : ~.,~ ~a From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday, February 06, 2009 9:45 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: FW: Injection well 3N-13 (PTD 186-081, AA AIO 28.038) Jim, We proactively installed an OA HPP on 3N-13 to trip at 1000 psi and intend to allow IA pressure to equalize with tubing pressure (vs. the current self limiting 2000 psi). Do we need to modify the AA to implement our intentions? Attached is a recent TIO. Please note OA was bleed 12/19/08 from 1000 to 500 psi. Please Advise MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: NSK Well Integrity Proj Sent: Friday, December 19, 2008 3:54 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Injection well 3N-13 (PTD 186-081, AA AIO 26.038) Jim, Thanks for the speedy response. 2/12/2009 Injection we113N-13 (PTD 186-081, AA AIO 26.038) Page 2 of 3 • • We believe the OA trend is purely thermal in nature. The well was SI for several months and was fluid packed from the MITOA and was brought on line 11/24/08. In the original request the IA pressure was and is still maintainable below 2000 psi. The tubing and the IA track as expected. The header pressure is 2800 psi, if the well was opened up to full choke the IA would track. Since the IA and the tubing are stable just below 2000 psi any choke move would affect the IA pressure of the well. In the past the Commission has requested an OA HPP on similar injection wells where the IA would exceed 2000 psi. We were just proactively recognizing that fact. The request for 3000 psi is based on a round number close to the header pressure. The leak is still a "one way leak" as the MIT wi11 pass but the DD test fail as in previous test. As the mechanical condition has not changed on the well our intent was to recognize that on OA HPP should be installed if the IA was to exceed 2000 psi. Currently the well is meeting injection requirements with out any choke moves. As previously requested we would like to leave the well online, instal{ the OA HPP and revise the AA to reflect the change. MJ Loveland Well Integrity Project Supervisor CanocoPhillips Alaska, inc. Office {907} 659-7043 Cell {907} 943-1687 From: Regg, ]ames B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 19, 2008 3:19 PM To: NSK Well Integrity Proj Cc: NSK Problem Well Supv; Maunder, Thomas E (DOA) Subject: RE: Injection well 3N-13 (PTD 186-081, AA AIO 28.038) Not sure 1 agree with your assessment (i.e., mechanical condition has not changed}. Seems there is something going on in the OA that was not taken rota account in AIO 28.038. There is a clear trend of increasing pressure once the well was put on injection, and there appears to be repressurization following a recent bleed event. Can you confirm what is causing OA to repressure? From what you have just provided, it appears that the Commission's approval may need to be reconsidered. As noted, AIO 26.038 does not set pressure limits; 2000 psi in the IA is CPAI's internal limit - we do not recognize pressure limits except these established by the Commission as a condition of approval. There was no question when we reviewed the original request that tubing and IA were going to equalize. What was not evident in CPAI's original request was the pressure at which CPAI intends to operate 3N-13. Do you know in fact that the IA and tubing are going to equalize? And, what is the reason for 3000 psi? RIO 26.038 supports CPAI"s assessment o€ a 1 way leak (fA to tubing} based on diagnostic MITs. However, that does not seem to explain the source of increasing IA pressure and repressurization following what appears to be an IA bleed event on or about December 1 (as shown on TIO plot}. The black background does not allow for the plot to be copied and laserfiched for our electronic files; can you adjust the backgraund color in the future before sending TIO plots? 2/ 12/2009 Injection we113N-13 (PTD 186-081, AA AIO ZB.038) Page 3 of 3 Look forward to CPAI's assessment of 3N -13. If you have a plan for diagnostics, I'd appreciate a timeline. Otherwise, based on Rules 5 & 6, KRU 3N-13 should be shut in. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Friday, December 19, 2008 1:12 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Injection well 3N-13 (PTD 186-081, AA AIO 26.038) Jim, ConocoPhillips requests a modification to the AA (AIO 26.038) on well 3N-13 (PTD 186-081). The mechanical condition on the well has not changed. However, the self prescribed operating conditions require the IA pressure to be maintained below 2000 psi and ConocoPhillips would like to increase the IA pressure maximum to not exceed 3000 psi. If the maximum allowable operating pressure (MAOP) increase is acceptable a high pressure pilot can be install (if required) on the OA within 30 days of notification from the AOGCC. A TIO plot is attached. Note the well was brought on line Nov 24, 2008. «3N-13 TIO.jpg» Please let us know if the change is acceptable. We will keep the well online in water only injection service with the IA less than 2000 psi until notified otherwise. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 2/12/2009 KRU 3N-13 PTD 186-081 2/6/2009 TIO Pressures Tillt~ F"I~t - 3N-13 2500 2000 ~ 1500 1000 500 0 01-Dec-08 01-Jan-09 01-Feb-09 Date 200 150 a~ 100 ~ 8 50 0 KRU_3N-13_requestJ4IO26-023_amendment_2008-1224.txt Injection well 3N-13 (PTD 186-081, AA AIO 2B.038)From: Regg, ]amen B (DOA) sent: Wednesday, December 24, 2008 10:14 AM To: 'NSK Well Integrity Proj' Subject: RE: Injection well 3N-13 (PTD 186-081, AA AIO 26.038) Thank you for clarifying the oA pressure; I'll keep a watch on that with the monthly report. Back to your original request, I am working on a revised admin approval to allow for IA pressure up to 3000 psi conditioned on CPAI installing, maintaining and testing automatic well shut in equipment tied to the oA pressure. Tim Regg AOGCC 333 w.7th Avenue, suite 100 Anchorage, AK 99501 907-793-1236 -------------------------------------------------------------------------------- From: NSK well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Wednesday, December 24, 2008 5:03 AM TO: Regg, James B (DOA) Subject: RE: Injection well 3N-13 (PTD 186-081, AA AIO 28.038) Tim, Here is a photo of the latest TIO plot. sorry about the black ba ground, the other programs doesn't load data until 10 am. I'll be here until 11:30 am. MJ ---------------------------------------------- --------------------------------- From: Regg, lames B (DOA) [mailto:jim.regg@a ska.gov] sent: Tuesday, December 23, 2008 1:50 PM To: NSK Well Integrity Pro subject: RE: Injection wel~ 3N-13 (PTD 6-081, AA AIO 26.038) I'll be out this afternoon and will~all you tomorrow Tim Regg AOGCC 333 w.7th Avenue, suite 100 Anchorage, AK 99501 / 907-793-1236 ----------------- -------------------------------------------------------------- From: NSK Well tegrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday December 23, 2008 12:08 PM To: Regg, Ja es B (DOA) Page 1 3N-13 (PTD 186081) Request to monitor WHP's for stabilization Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, December 01, 2008 4:00 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 3N-13 (PTD 186081)) Request to monitor WHP's for stabilization Jim, Page 1 of 1 An IA DD test was performed on 3N-13 following the well being returned to injection with approval from AIO 28.038. The results from the DD test were as follows: Initial T/I/0=1800/1750/760 Start IA DD T/I/0=1800/800/650 30 min T/I/0=1800/840/650 60 min T/I/0=1800/880/650 90 min T/I/0=1800/930/650 -24 hours later T/1/0=1665/1050/600 ~~~~~% ~~ ~: ~ 2Q~ Per our phone conversatf"on, ConocoPhillips will continue to monitor the WHP's to verify if the IA pressure climb is due to thermal effects or if the leak path is a two way leak an no onger just one way as identified from previous diagnostics. The AOGCC will be updated with results and if any appropriate changes for continued injection will be requested at that time. '~- Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 12/1/2008 ~/ . • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~ ~ ~~ ~3 _` i ~~` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). 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 October 19, 2008 and the corrosion inhibitor/sealant, was pumped October 21, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,~ MJ La eland ConocoPhillips Well Integrity Projects Supervisor ~~~~-~~~ ~1~~~ ~.: ~~ 200 ~r • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~+e 10/22/2008 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 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4" 2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 /, -~~ ~~~ i„~, i Schlumberger -DCS "' " `' `' 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~~ ~~.~ ~ Zd~~ ATTN: Beth _ _ Well Job # Log Description NO.4792 Company: Alaska Oii & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07!24/08 1A-06 12080402 INJECTION PROFILE ~ ~ - ( 07/06/08 1 1 3C-17 11964626 SFRT $- 07/12/08 1 1 tY-04 12096505 INJECTION PROFILE - - ~ 07/13/08 1 1 1 G-06 12061729 INJECTION PROFlLE a ~ 07/13/08 1 1 1 F-06 12096506 PRODUCTION PROFILE - ~ 07/14!08 1 1 3M-08 12096516 SBHP SURVEY - 07/21/08 1 1 3M-09 12096515 SBHP SURVEY !0 07/21/08 1 1 3N-13 12096517 SBHP SURVEY 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFlLE .iS = 07/16/08 1 1 1F-06 12096510 PRODUCTION PROFILE ( -/C( 07/17!08 1 1 2A-02 12096511 INJECTION PROFILE 07/18/08 1 1 3J-17 12096514 SBHP SURVEY ' g /~(s D7/20/OS 1 1 3J-07A 12097409 ~ SBHP SURVEY O 1-L> ~~S A~Co~~ 07/20/08 1 1 3C-15A 12097406 - _ USIT I / •~ 07/17/08 1 1 2A-05 12096512 SCMT - 07/19/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 3N-13 failed MITIA Page 1 of 1 • Regg, James B (DOA) ~ ~~~-~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, June 07, 2008 12:01 PM ~I~i+ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~ ~~ Subject: 3N-13 failed MITIA Attachments: 3N-13.txt; 3N-13 TIO Plot.png; MIT State 3N-13 06-05-08.x1s Jim /Tom, Injector 3N-13 (PTD# 186-081) failed an MITIA on 6/05/08. The T/I/O prior to the test was 2300/1960/20 and the T/I/O after the test was 2300/1600/20. A file containing the results is attached. The immediate action to be taken is to shut the well in and perform diagnostic testing. Depending on the outcome of the diagnostics, ConocoPhillips will fol owT up witTi a 10-403 for repair or a AA request for continued injection. A 3 month TIO plot and a well schematic are attached. Russ PWS ~ -~ «3N-1 » «3N-13 TIO Plot.png» «MIT State 3N-13 06-05-08.x1s» ~~~N~~ ~llG ~~ 2~~~~~ 7/31 /2008 KRU 3N-13 PTD 186-081 TlllO Plot - 3N-13 2500 2000 a 1500 1000 500 0 ~~ 1 i1 01-Apr-08 01-May-08 D ate 01-Jun-08 JO 150 a 100 m 0 r V 50 0 • ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. ~ ~ 3~ ~~,~ FIELD /UNIT /PAD: Kuparuk /KRU / 3N-13 ~ ~~ DATE: 06/05/08 OPERATOR REP: Bates /Ives AOGCC REP: N/A Packer Dep Pretest Initial 15 Min. 30 Min. Well 3N-13 T pe Inj. W ND 6, 5' Tubing 2,300 2,300 2,300 2,300 Interval P.T.D. 1860810 Type test P Test psi 564 Casing 1,960 3,000 2,935 2,860 P/F F Notes: 45min TI0=2300/2800/20 OA 20 20 20 20 Pressured up IA with 1 bbls diesel. Pressured back up with 15 gal. diesel, for a calculated LLR of .25 GPM. Well T pe Inj. ND Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well T pe Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well T pe Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waist M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Waistewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9/1!05 2008-0605 MIT KRU 3N-13.x1s ~LL L T"R.~4/tl~l1~//1~~4L ProActive Diagnostic Services, Inc. To: ABC 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 tfiis transmittal fetter to the following ProActive Diagnostic Services, fnc. Attn: Robert A. Richey ~ ~~~ ~ 20~$ 130 West International Airport Road Suite C Anchorac,~:, AK 99518 Fa~c (907) 245-8952 t~q N- t1 } q 1J 2) Signed MTT Log 01,1u1-*08 1 &14 1 Report Caliper Report 06,Ju1-08 3N-13 1 Report / EDE 11~~ - o i l r s G ~~ 50-029-22452-00 50-029-212854-00 Date Print Name: PROAGTNE DU-GNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUPiE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: {907)245.88952 E-MAIL: -__- ,_ WEBSITE . , , C:\Docwnenfs and SetGngs\Owner\pesktop\Tratumit_Conoco.doc • Memory Multi-Finger Caliper S Log Results summary Company: ConocoPhlllips Alaska, Inc. Well: 3N-13 Log Date: July 6, 2008 Field: Kuparuk Log No.: 7715 State: Alaska Run No.: 1 API No.: 50-029-21584-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 7,404 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the SOS / TfL @ 7,404' (Drilier'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 2.875" tubing is in good to fair condition with respect to corrosive damage, with the exception of a 47% wall penetration in joint 191 (5,990'). Recorded damage appears in the form of isolated pitting, at times in a line. No significant areas of cross-sectional wall loss (> 12°~} or I.D. restrictions are recorded. The caliper recordings indicate buckling from 6,400' to 7,350'. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pitting (47%) Jt. 191 @ 5,990 Ft. (MD) Isolated Pitting (24%) Jt. 171 ~ 5,342 Ft. (MD} Isolated Pitting { 24°~) Jt. 50 ~ 1,555 Ft. (MD) Isolated Pitting (24%) Jt. 155 ~ 4,858 Ft. (MD) Isolated Pitting (22°~) Jt. 133 C~ 4,152 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 12°~ ) are recorded. ' MAXIMUM RECORDED ID RESTRICTIONS ' No significant I.D. restrictions are recorded. ~~~N~~ ~U~ ~ ~ ~~~$ ~ ~~'G Us'cr-o~ 1 ~ /65~ 9 ', t Field Engineer: J. Halvorsen Analyst: M. Lawrence Witness: J. Hansen PraActive Diagnostic Services, Inc. / P.Q. 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 II • • Correlation of Recorded Damage to Borehole Profile ® Pipe 1 2.875 in (25.5' - 7403.8') Well: 3N-13 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 6, 2008 A pprox. fool Ue viation ~ n pt~ro~_ I>orehol c° Prc,lil ~~ 29 i7f> 1.144 2343 3122 Y 3898 s o. v 4674 5457 6239 7023 GLM 1 235.1 7404 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 235.1 1 25 I, 50 75 100 a`, ~ 125 z c 'o 150 175 200 225 • • PDS Report Overview ~ Sw Body Region Analysis Well: 3N-13 Survey Date: July 6, 2008 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: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ,;:~w metal loss body 0 20 150 0 1 0 50 0 0 to 1 to 10 to 1% 10% ZO% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 237 gene. 0 110 117 loss 52 179 6 9 1 0 0 0 0 Damage Configuration (body ) 50 no o 20 10 0 isolated general line ring hole /puss pitting corrosion corrosion corrosion ihle hole Number of "oints dama ed total = 49 49 0 0 0 0 Damage Profile (°,6 wall) ~ penetration body _ metal loss body 0 50 100 n GLM 1 Bottom of Survey = 235.1 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 Well: 3N-13 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) I'~~n. lll~u~t (Im.) Pen. Body (Ins.) Nen. °io Met,~l I ~~ss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 5 t) 0.0 Z I 1 _' 2.45 PUP Isolated it in . 1 9 (~ 0.0 8 ti 2.41 2 61 i? 0.0 1? I_' .40 3 91 i t 0.01 ~1 v 39 4 1 3 it 0.01 b t; .41 154 l) 0.01 b ~ ~ .41 f ~ 6 185 t) 0. 2 i t 1 _' 2.42 7 17 O 0.03 1~ to 2.4 8 t) 0.01 3 4 2.41 279 a 0.0 6 1u .41 10 3 0 l) 0 02 10 (~ .40 11 340 U 0.02 11 2.41 1 37 i) 002 is lit 2.41 13 403 a 0.01 E, is 2.42 14 4 5 U 0.01 3 ~I .43 15 466 U 0.0 10 t3 2.40 496 U 0.01 6 9 2.42 17 527 U 0.01 ~ 7 .41 18 8 U 0.01 6 1 U .4 19 590 a 0.01 4 10 2.42 0 6 0 U 003 1Z 2.41 21 651 l) .03 1 ~1 I i ~ 2.41 2 68 U 0.03 11 1 i) 2. 1 23 713 a 0.01 o rs 2.40 4 744 U .0 11 tS 2. 25 776 ~) 0.01 1 i> 2.39 26 07 U 0.02 ti tS .4 27 838 U 0.02 II 1 u 2.41 8 869 i) 0.02 10 2.40 29 900 a 0.01 ~ Iii 2.39 3 93 a 0.0 ~~ ~ .41 31 96 c) 0.03 12 1 t) 2.41 32 992 O 0.01 ~ i .38 33 1024 tt 0.01 4 (> 2.41 34 1054 t) 0.01 (i I n .42 35 1086 tt 0.02 10 ~~ 2.39 3 11 5 i) 0.0 1t) 2.39 37 1137 U 0.02 1n II 2.42 38 1168 a .0 1t) I 2.39 39 1199 a 0.02 ~~ 5 2.41 40 1 1 tt 0.01 4 ~ 241 41 1262 U 0.02 11 ~) 2.41 129 U 0.05 ' t 240 I ate ittin . 43 1325 U 0.02 1I 7 2.40 44 1 6 U 0.01 7 2.39 45 1387 i) 0.02 10 t, 2.41 46 1419 a 0. 2 8 is .39 47 1451 t! 0.02 f3 ~ 2.40 48 1482 0.01 V I i t 2.40 49 1513 0.03 12 i ~ ~ 2.40 Lt De osits. _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 Well: 3N-13 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) P~~n. ; if>sc~i (In~.J Pen. Body (Ins.) Pen. % Mel.rl I Usti ">~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1544 a 0.05 24 t. 2.40 Isolate ittin . 51 1575 ~ ~ 0.01 4 I I 2.3 52 1606 (~ 0. 1 1 ~~ 2.39 53 1636 U 0.0 <) 11 .40 54 1668 U 0.03 14 ~i 2.39 55 1699 U 0. 3 15 b .40 Shallow ~tti 56 1731 U 0.03 14 I U 2.40 56.1 1762 U 0 0 U 2.31 SSSV 57 1780 U 0.03 12 5 .40 58 1811 t~ 0.01 3 7 2.40 59 1842 U 0.03 12 1 U .40 60 187 t ~ 0.02 1 1 ~ ~ 2.39 61 1905 U 0.02 ~i -1 2.40 193 U 03 1 ~' 2.39 63 1968 U .02 11 ~i 2.39 64 1 99 U 0.03 14 ~ 2.40 6S 2031 U 0.04 2U (~ 2.39 Isolated ittin . 6 2062 U 0 I1 t~ 2.3 67 2094 ~ i 0.03 1 5 l 2.39 Shallow ittin . 68 1 5 ~~ 0.02 11 2.39 69 2157 i ~ 0.01 6 2.39 70 2188 ~ ~ 0.03 I (; !, .38 Shallow ittin . 71 2219 U .03 1 Z 2. 72 2250 U 0.02 11 ~ 2.38 73 22 0 (~ 0.02 lU b 9 74 2312 U 0.02 9 is 2.39 75 2343 U 0.02 11 2.39 76 2374 U 0.02 11 (~ 2.38 77 2405 U 0. 1 b ~ 2 38 78 2436 U 0.01 U ~ 2.39 79 2467 ~ 1 0.02 ~! -1 9 80 2499 t ~ 0.02 1 1 -3 2.38 81 53 n 0.02 1 U (, .38 82 2561 U 0.03 11 ; 2.38 Lt De osits. 83 259 U 0.02 11 (, 2. 8 84 2624 U 0.02 11 =1 .39 85 655 U 0.02 ~ i 2.3 86 2686 U 0.02 1 I 4 2.38 Lt. De sits. 87 2718 U 0 02 ~3 4 .37 88 2749 U 0.02 11 6 2.39 89 2780 ~ ~ 0.02 ti ~ 2.39 90 2811 i~ 0.02 ti I 2.39 91 2843 U 0.02 1 U 2.38 92 2874 r ~ 0.02 I 0 ~ 2.38 93 2906 a .02 1 U - 2.39 94 2937 a 0.02 tU ~~ 2.41 95 2967 U 0.0 1I s 2.38 96 2998 ~~ 0.02 ti (~ 2.42 97 3029 i ~ 0.0 12 ~ 2.38 98 3060 r 1 0.01 ~ 2.40 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf J-55 Well: 3N-13 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~~c~t (In>.) Pen. Body (Ins.) I'c~n. "/~, V1c~tal last ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 99 3091 U 0.0 1 ; ~ 2.38 100 312 t) 0. 1 6 3 .3 101 3153 [~ 0.02 11 t~ 1 10 318 a 0.01 4 -1 2.38 103 3214 a 0.03 I ~' t, 2.40 104 3246 l) 0. II .41 105 327 U 0.01 E~ 2.41 10 33 7 U 0.0 I I -t .40 07 3338 t 1 0.01 4 E~ .40 108 3 7 tl 0.01 6 3 .39 10 3 1 U 2 11 i .41 110 3431 U 0.02 I U i s 2.41 111 3463 lJ 0.03 L5 -1 .40 Shallow itti 112 3494 1) .04 'U ~ .38 Isolated ittin . 1 3 3 5 tl 0. I ~) t ~ 2.41 Shallow ittin . 1 4 3557 a 0.04 ,'u ~, 2.43 Iso ated itti 115 3588 ~ ~ 0. 4 1 £; I 2.41 Shallow it 'n . 1 6 3 19 a 0.03 13 .40 117 3650 a 0.04 -'U 5 2. Isolated ittin . 118 3681 U 0.01 4 2.39 1 371 a 0.0 1 ~ - 2.39 1 3743 a .0 14 a 2.3 121 3774 U .04 ~ 1 23 .41 I laced 'ttin . 122 3805 E1 0.04 17 2.41 Shallow ittin . 1 383 1 0 I< 124 3867 l1 0.03 14 7 2.41 125 3898 t~ 0.04 1 ~~ 2.41 Sh II w 'ttin . 1 6 3929 it 0.03 1? 5 2.41 127 3959 U 0.04 I t3 _' 2.41 Shallow itti 128 3991 U 0.03 15 E, 2.39 Shallow it6n . 129 4022 (1 0. 3 15 -1 2.4 Shallow i 'n . 130 4053 t~ 0.03 14 _' 2.40 Shallow ittin . 31 4084 t ~ 0.03 12 s 2.40 132 4114 a 0.04 17 r, 2.39 Shallow ittin . 1 3 4146 U 0.05 ~'Z 2.38 Isolated ittin . 134 4177 U 0.03 1 ' '~ 2.41 135 4206 ll 0.04 16 _' .39 Shallow ittin . 136 4238 t1 0.02 11 2.39 137 4268 (1 0.0 14 t; .41 138 4298 a 0.03 11 1 2.40 139 43 9 U 0.04 ? I 3 2 39 I laced ittin . 140 4360 t? 0.03 1 i ; 2.38 Shallow ittin . 141 439 n 0.03 16 ~ 2.38 Shallow itt"n 142 442 3 t) 0.03 14 Z 2.38 Lt. De sits. 143 44 4 u 0. 4 'll 1 .39 Isola d itti 144 4486 t) 0.03 14 2.38 145 4517 t~ 0.03 14 I 2.38 146 4548 ti 0.04 ' 1 5 2.38 Isolated it6n . 147 4580 ~' 0.04 !" ~ 2.40 Sh Ilow ittin . 148 4611 0.04 2.39 Isolated ittin . Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 Well: 3N-13 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) Pen. I lhx~t (In>.) Pen. Body (Ins.) Pen. °~~ ~~tc~t.~l foss ,~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 149 4642 (~ 0.04 20 ; 2.39 Isolated itti 150 4674 U 0.04 17 2.38 Sh• Ilow ittin . 151 4705 ~ J 0.0 17 1 2.38 Shallow ittin . 152 4737 U 0.03 15 I 2.38 Shallow ittin . 153 4768 O 0.04 17 1 2.38 Shallow ittin . 154 4799 tJ 0.03 16 2.39 Shallow ittin . 155 4831 (~ 0.05 24 _' 2.37 Isolated ittin . 1 6 4862 a 0.03 16 2.38 Shallow it in . 157 4894 O 0.03 14 2.37 158 4925 (J 0.03 1 ~ 1 .37 Shallo ittin . 15 4956 U 0.03 1 ~' (, .38 160 4987 U 0.04 18 2.39 Shallow ittin . 161 5019 0 0.03 14 4 2.39 162 5050 t~ 0.04 17 I 2.38 Shallow ittin . 16 5081 (J 0.03 13 ) 2.37 164 5112 t) 0.04 17 _' 2.39 Shall w ittin . 165 5144 (~ 0.04 1 t3 1 2.37 Shallow ittin . 166 5175 0 0.02 10 3 2.38 67 5207 0 0.02 1 u 2.37 168 5238 U 0.02 11 3 2.38 169 5270 0 0.03 15 3 2.38 Shallow ittin . 170 5301 U 0.03 1 ~ 1 2.38 171 5332 U 0.05 .'4 -1 2.38 Isolated ittin . 172 5364 0 0.03 15 i 2.38 Shallow ittin . 1 9 t~ 0. 1 - 1 .38 174 5426 U 0.02 11 a 2.38 175 5457 U 0.02 11 ~ 2.38 176 5489 U 0.03 I , 2.37 177 5520 l) 0.02 f3 I 2.37 178 5552 a 0.02 1 U 4 2.38 179 5584 ±~ 0.02 t3 (, .38 180 5615 O 0.02 10 I 2.38 181 5646 U 0.02 8 U .37 182 5678 tI 0.02 ~~ U 2.38 183 5709 U 0.02 l t) -1 2. 8 184 5740 t) 0.02 ti 2.37 185 5771 tJ 0.02 ;~ ~ 2.37 186 5803 0 0.02 9 2.39 187 5834 tI 0.02 8 5 2.38 188 5866 (~ 0.04 19 1 2.39 Shallow itti 189 5897 a 0.01 7 t i 2.38 190 5928 t~ 0.02 1(J 2.38 191 59 0 l) 0.10 =l t, 2.38 Isolated ittin . 192 5991 a 0.02 1 t~ 2.37 193 6021 0 0 02 ti (J 2.37 194 6052 l) 0.03 i3 1 2.39 195 6083 t ~ 0.02 1 t) 2.39 196 6115 tJ 0.02 Iu ~ 2.37 197 6146 i ! 0.02 ri I 2.38 198 6177 0.01 ~ ~ ~ 2.38 Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABULATION SHEEP Pipe: 2.875 in 6.5 ppf )-55 Well: 3N-13 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: July 6, 2008 Joint No. Jt. Depth (Ft.) I'en. t Il~set (Inti.) Pen. Body (Ins.) Pen. °i~ ,Metal I ~_~ss ,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 199 208 t) 0.01 7 I 2.37 00 6239 U 0.02 i 1 > 2.38 201 6271 U 0.03 1 ! a 2.38 202 302 t) 0.02 11 I .36 203 6333 t) 0.02 F3 1 2.37 204 6365 l) 0.02 1 U 1 2.37 205 6396 l) 0.03 14 i 2 38 Lt. a osits. Sli ht B c in . 206 6427 a 0.01 b tt .38 207 6458 tl 0.02 11 I 2.37 OS 648 U 0.02 8 I 2.37 209 6520 i) 0.01 6 U 2.40 210 6552 t) 0.03 13 I .38 Sli ht Bucklin . 211 6583 t ~ 0.01 ) 1 2.40 21 6615 ~~ 0.01 6 ~) .40 213 6646 tr 0.03 13 I 2.37 214 6678 t ~ 0.01 6 t ~ 2.39 215 6709 t ~ 0.01 6 n 2.39 216 6740 ~ 0.01 4 t) 2.39 Sli t B c 'n . 217 6772 O 0.01 S U 2.38 218 6803 U 0.01 ~ U 2.39 19 6834 t) 0.02 11 -t 2.38 220 6865 t~ 0.02 ti a 2.37 221 6897 tl .02 1 I 1 2 37 222 6928 t) 0.01 7 u 2.39 23 6960 U 0.02 ll) U li u kli 224 6991 (1 0.02 11 ~ 2.38 Bucklin . 2 5 7023 t~ 0.02 ll) 1 2. 6 226 7054 t~ 0.01 (~ 2.37 27 7086 t) 0.01 t> I 2.37 Bu klin . 228 7117 rJ 0.02 ti I 2.37 229 7148 U 0.03 I3 a 2.37 230 7180 tt 0.03 14 U 2.37 Bucklin . 231 7211 a 0.02 1(t ~ .37 232 7242 t) 0.03 14 4 2.36 232.1 7273 t) 0 t) l) N G M 1 Latch ~ 3:00 233 7281 ~ 0.02 1(t ~ 2.39 Bucklin . 233.1 7313 t) 0.01 I 2.41 PUP 233.2 7317 t) 0 u u 2.50 PBR 233.3 7332 t) 0 t) ti 3.00 acker 234 7340 t) 0.03 I -~ I 2.37 234.1 7372 U 0 U U .25 D Ni le 235 7373 a 0.04 1 t3 1 2.37 Shallow ittin . 235.1 7404 (~ 0 u l) .37 SOS TTL Penetration Body Metal loss Body Page 5 ~~u ~~ PDS Report Cross Sections Well: 3N-13 Survey Date; July 6, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: l4 Tubin 2.875 ins 6.5 f 155 _ _ _ Analyst: M. Lawrence Cross Section for Joint 191 at depth 5989.783 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 98 Tool deviation = 44 ° Finger 10 Penetration = 0.101 ins Isolated Pitting 0.10 ins = 47% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 PDS Report Cross Sections Well: 3N-13 Survey Date: July 6, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 2.875 ins_ _6.5 ppf J-55 Analyst M. Lawrence Cross Section for Joint 171 at depth 5342.354 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 97 Tool deviation = 39 ° Finger 14 Penetraton = 0.053 ins Isolated Pitting 0.05 ins= 24°h Wall Penetration HIGH 51Df = UP • • Cross Sections page 2 ConocoPhillips Alaska, Inc. KRU 3N-13 ~ 3N-1S API: 500292158400 Well T INJ le TS: 40 de 7470 SSSV T TRDP O ~ Co letion: 4/27/1986 le TD: 40 de 7875 sssv Annular Fluid: Last W/O: Rev Reason: Pull CA-2 Plug (1784-1765 5/30/04 , OD:z.875) Reference Lo Ref L Date: Last U ate: 4/30/2005 Last Ta : 7748 TD: 7875 ftK6 Last Ta Date: 10/3/2000 Max Hole An le: 44 de 3900 Casi Strin -ALL STRINGS Descri ion Size To Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 7872 6666 26.00 1.55 SUR. CASING 9.625 0 3774 3628 36.00 1-55 Gas Lift ~ dreUDummy ~ CONDUCTOR 16.000 0 115 115 62.50 H-40 veNe ~ Tubin Strin -TUBING (7273-7274, Size To Bottom TVD Wt Orade Thread OD:5.500) 2,875 0 7404 6309 6.50 J-55 EUE 8RD ABM Perforations Summer Interval TVD Zone Status Ft SPF Date T Comment 7485 - 7505 6370 -6386 G1,UNIT B 20 4 10/6/2000 APERF 180 deg ph; 2 1/8" EJ PBR (7316-7317 7557 - 7563 6425 -6430 Ati3 6 4 10/7/1988 RPERF Zero de - 2 1/8" EJ , OD:2.875) 7563 - 7563 6430 -6430 A-3 0 5 10/7/1988 RPERF Zero de • 2 1!8" EJ 7563 - 7566 6430 -6432 A-3 3 4 10/7/1988 RPERF Zero de • 2 1/8" EJ 7566 - 7566 6432 -6432 A~ 0 5 10/7/1988 RPERF Zero de • 2 1/8" EJ 7566 - 7568 6432 -6434 A~ 2 4 10/7/1988 RPERF Zero de • 2 1/8" EJ 7568 - 7568 6434 -6434 A-3 0 5 10!7/1988 RPERF Zero de • 2 1/8" EJ 7568 - 7570 6434 - 6435 A-3 2 4 10/7/1988 RPERF Zero de ' 2 1/8" EJ 7570 - 7570 6435 -6435 A-3 0 5 10/7!1988 RPERF Zero de ~ 2 1/8" EJ PKR (7333-7334 7570 - 7571 6435 -6436 A-3 1 4 10/7/1988 RPERF Zero de • 2 118" EJ , OD:fi.fSt) 7580 - 7591 6443 -6451 A-2 11 4 10/7/1988 RPERF Zero de ' 2 118" EJ 7591 - 7591 6451 -6451 A-2 0 5 10/7/1988 RPERF Zero de • 2 1/8" EJ 7591 - 7595 6451 -6454 A-2 4 4 10/7/1988 RPERF Zero de • 2 1/8" EJ 7595 - 7595 6454 -6454 A-2 0 5 10/711988 RPERF Zero de - 2 1/8" EJ 7595 - 7599 6454 -6457 A-2 4 4 10/7/1988 RPERF Zero de ~ 2 1/8" EJ 7599 - 7599 6457 -6457 A-2 0 5 10!7/1988 RPERF Zero de ' 2 1/8" EJ 7599 - 7601 6457 -6459 A-2 2 4 10/7/1988 RPERF Zero de ' 2 118" EJ NiP (7371-7372 7601 - 7601 6459 -6459 A-2 0 5 10/7/1988 RPERF Zero de ' 2 1/8" EJ , oD:z.a75) 7601 - 7603 6459 -6460 A-2 2 4 10/7/1988 RPERF Zero de • 2 1/8" EJ 7606 - 7606 6463 -6463 A-2 0 1 7/19/1986 IPERF 120 h• 4" Jumbo Jet II 7621 - 7654 6474 -6499 A-1 33 1 7/19/1986 IPERF 120 h' 4" Jumbo Jet II Gas Lift Mandrels'Vatves TUBING St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv (o-7aoa, Mfr Run Cmnt OD:z.675, 1 7273 6209 MMH 2 7/8 X 1.5 DMY 1.0 RK 0.000 0 11/8/1999 1 iD:2.4at) 1. Set Ext. Pk AVA seals 1/&/99 1TL Other u ui .etc. - JEVVELRY (7404-7405, 00:2 875) pe th TVD T Descri 'on ID . 1784 1784 SSSV Baker'FVL' 2.310 7316 6242 PBR Brown 2.500 7333 6255 PKR Brown'HB' 3.000 7371 6283 NIP Camco 'D' Ni a NO GO 2.250 Pert 7404 6309 SOS Brown 2.441 (7563-7563) 7404 6309 TTL 2441 General Notes Date Note 612 21 1 99 4 WAIVERED WELL: T x IA COMMUNICATION Perf (/566-7586) Perf (7591-7591) Pert (7595-7595) Pert (7580-7603) Pert (7621-7654) �,v - vim �i i L i o-r i ��v� �ia�c vvi�iiw�cu lvu i vr� yci r�iv ��.v i•r r ago i vi J Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MAOP %IYP AA # 2C -07 7" 26 ppf K-55 4980 3000 60% AIO 28.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 28.014 3A -06 7" 26 ppf J -55 4980 3000 60% AIO 28.008 3A -11 7" 26 ppf J -55 4980 3000 60% AIO 213.022 3A -14 7" 26 ppf J -55 4980 3000 60% AIO 213.026 3H -09 7" 26 ppf J -55 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA —>3 3N -13 7" 26 f J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 2B.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor t ConocoPhillips Alaska, Inc. NOY 1 8 Office 907 - 659 -7224 Cell 907 - 943 -1720 N Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 213.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 /-NJ - V-.l 11 1L LU - TIJ7V f OMLU, VV Ll1VJJVU 1V1111J'J> IJVl A1lJ Z-".V 1 1 ap., G Vl J 0 • The AIO 26.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPA[ to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 213.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 /-U - VJ lr 11J 10`FIJYV) Otani vv1U1GJ5GU 1V111 ti1V G13.VI - t V1 J Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 26.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AID 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 26.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xis>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 l~ulraiun iu~c~~i~ii vv cu nc~viiui• • Y1~e 1 OI 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] ,~ Sent: Tuesday, February 19, 2008 1:34 PM ~~~ ~ ~1~~ (~-`~% To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk Injection Well Reporting Jim, Per our phone conversation, here is a list of injection wells that we are in the process of pursuing AA's for A1026. Each of these wells have been waivered under ConocoPhillips Well Operating Guidelines and reported to the State as a group on a spreadsheet in June 2007. They also may have been reported individually at the time of the waiver or in the first group report submitted 10/08/03. Up until this time ConocoPhillips has assumed that we had implied AOGCC consent to continue water injection in each well in its current condition. The purpose of this email is to ensure that we do indeed have consent for water injection and to notify the State that AA applications are in progress. 1A-12 - 181-178 - IAxOA communication 2V-02 - 183-161 -Minor IAxOA communication ~~~~~ ~~~ ~ ~~~~ 3N-12 - 186-079 -Slow TXIA .~3N-13 - 186-081 -Slow TxIA i 1C-10 - 182-193 - x~munication Wells 1A-12, 2V-02, 3N-12, and 1C-10 were added to the Monthly injector report this month. 3N-13 is already on the report. Please let me know if you have any questions or if additional reporting or action (other than the AA applications} is required. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/13/2008 o~_~ '~~. Schlumberger Roo- -E- rEIVFI) " v I -~ NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ("ire Ç¡ 1 zon; tJL'::' v·j Company: ~ Cil & Gas Cons. C-cíf;fr~-3;-cn Anchc-rag.e Field: Well Job # Log Description Date BL 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1Y-27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 2D-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 Î 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE WIDEFT 09/10/05 1 1 Q-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 lal4-~\ 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12/02/05 1 38-16 N/A INJECTION PROFILE 12/08/05 1 1 Q-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1Q-101 11144044 MDT 11/24/05 12/20/05 tC60-DC¿¡j Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 SIGNED: õ>'"\.tF'Af!\..IME~ 'f\ t\.¡ ~ f1 ?noCo ~1V(r---t;~~"\16µ J~\!~ r;) d ='" 0 DATE:&~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MIT KRU 3N-13 06-02-05.xls ) ) Subject: MIT KRU 3N-13 06-02-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 03 Jun 2005 09:48:55 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim_regg@admin.state.ak.us>, bob _ fleckenstein@admin.state.ak.us \ .. /0%\ ~¥J «MIT KRU 3N-13 06-02-05.xls» MITIA data on 3N-13 (PTD 1860810). MITIA was completed for internal waiver compliance. This well passes an MITIA and a BUR. It will be kept on our yearly MIT list. Please let me know if you have any questions MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCA.NNED JUN 1 4~ 20Œ) Content-Description: MIT KRU 3N-13 06-02-05.xls KRU 3N-13 06-02-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 6/6/20057:59 AM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRUI 3N 06102/05 Brakel Rogers - AES c(,\ (}J. .. ..kf 0 \\J Packer Depth Pretest Initial 15 Min. 30 Min. Well 3N-13 Type Inj S T.V.D. 6255 Tubing 2500 2500 2500 2500 Interval 0 P.T.D. 1860810 Type Test P T est psi 1564 Casing 2500 3100 3070 3070 P/F P Notes: Diagnostic MIT IA for internal waiver compliance Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: SCANNED ,JUN 1 4 2005 TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3N-13 06-02-05.xls 6/6/2005 i Subject: Re: Kuparuk Injection Well 3N-13 Failed MIT From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 20 May 2004 09:59:57 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: "Jim Regg AOGCC (E-mail)" <jim_regg@admin.state.ak.us> ~ ~ ~~ ~~ ~.~ ~ 3 ~ Y ~3 Jerry, Not sure if anyone got back to you. Your diagnostic plan is acceptable. On your tests, it doesn't appear that there is a lot of differential between the tubing and IA. I guess with the pressure losses you show and not much differential that you likely shouldn't have a problem locating the leak. Keep us informed of your determinations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Kuparuk water injection «MIT KRU 3N-13 05-15-04.x1s » well 3N-13 (PTD 1860810) failed an MIT on 5/15/04. The well has been internally waivered for minor T x IA communication and the MIT failed during the scheduled compliance test. The MIT data is attached. CPAI proposes the following plan: 1. Keep the well on water-only injection while diagnostics are performed; 2. Add the well to the monthly failed MIT report; 3. Set a tubing plug and perform leak rate tests to determine if tubing or packer leak; 4. Perform video leak detect log if appears to be tubing leak; 5. Submit 10-403 with repair or variance plan as needed depending on diagnostic results. Please let me know if you approve of our plan and let me know if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 8/2!2004 4:12 1' NOV 0 8 1995 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Meu-'henica{ Integrity Test Gas Cons. Commission ~chorage OPERATOR: ARCO Alaska Inc.. FIELD t UNIT 1 PAD: I~,Ft KRU, DATE: ! 1/6/95 1~ M I DIESEL 7,8~ 7~ 2~, K-~ 3.5 ~ 2.~ f, 7~ f, 755 ~7~ 7~ P~ Z~O ' COMMENTS WITNESS ~O $N-12 P I DIESEL 7.~f 7~ 2~l j~5 2.875 ~ ~ 1~ f~5 f~O 12!5 P ~ C~ENT$ ~NES$ ~D ,, , , , COMMENTS: D!S.PO~L N DIE~L 28~ 7; ][, )~ I 2.875 I~ 1~ 1~ 1575 157E . fO~ P COMMEN~: ~U~IING INJECTION FLUID: ANNULAR FLUID: P.P,G. G tad. WELL TEST: P = PRODUCED WATER INJ. nESEL 6.9 6.36 Inili~ S = SALT WATER 1N,J GLYCOL J O. 0 0 4 - Year X M = MISCIBLE INJ. SALT~TER J O. 00 Work~er I = INJECTION DRILUNG MUD j O. 00 Other N=NOTINJECTI.GSCANNED DEC l 9 ~00~ oJ.a I o. oo c-O~,'Jl~r c-T~p RI~ File AOGCC REP SIGNATURE OPERATOR REP SI~TU RE Page I WVD BY J HERRING ER.lC L. ZUSPAN~ MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other g 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 68 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service x Kuparuk Unit 4. Location of well at surface 8. Well number 1561' FSL, 105' FEL, Sec. 29, T13N, R9E, UM (asp's 518293, 6013800) 3N-13i At top of productive interval 9. Permit number / approval number 1390' FNL, 1800' FWL, Sec. 28, T13N, R9E, UM (asp's 520186, 6016135) 186-081 At effective depth 10. APl number 50-029-21584 At total depth 11. Field / Pool 1158' FNL, 1951' FWL, Sec. 28, T13N, R9E, UM (asp's520336, 6016368) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7875 feet Plugs (measured) Tagged PBTD (10/3/00) @ 7748' MD. true vertical 6668 feet Effective depth: measured 7748 feet Junk (measured) true vertical 6571 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 247 Sx CS II 115' 115' SURF CASING 3706' 9-5/8" 1100 Sx AS III & 300 G 3774' 3628' PROD CASING 7804' 7" 320 Sx Cl G & 175 AS I 7872' 6666' RECEIVED Perforation depth: measured 7485 - 7505'; 7557 - 7571'; 7580 - 7603'; 7606'; 7621 - 7654' 2 7 2001 true vertical 6370 - 6386'; 6425 - 6436'; 6443 -6460'; 6463'; 6474 - 6499' Alaska 011 & Gas Cons. Commissjor Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55, Tubing @ 7404' MD. Anchorage Packers & SSSV (type & measured depth) Brown 'HB' Packer @ 7333' MD. Baker 'FVL' @ 1784' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 1500 2900 Subsequent to operaUon 4800 2850 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service ~(Water Inj) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared'by John Peiroe 26,6-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~ 3N-13i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 10/3/00: RIH & tagged PBTD @ 7748' MD. 10/6/00: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Added perforations: 7485 - 7505' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf. POOH w/guns. Rigged down. Returned the well to Seawater injection and obtained a valid injection rate. 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level. Report Kuparuk Fluid Leyel Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk FlUid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Acknowledged: 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-0'1 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & u~as Cone. ....... ¢i~orag° Ccmmis~jo~; DISTRIBUTION: D&M State of Alaska -- Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-O7 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Kuparuk Well Pressure Re)ort Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuparuk Well Kuapruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku 3aruk Fluid Ku~3aruk Fluid Ku~aruk Fluid Kul3aruk Fluid Ku 3aruk Fluid Ku ~aruk Fluid Ku )aruk Fluid Ku )aruk Fluid Pressure Re )ort Pressure Re3ort Pressure Re )ort Pressure Re3ort Pressure Re 3orr Pressure Re 3ort Pressure Re 3ort Pressure Re 3ort Pressure Re 3ort Pressure Re 3orr Pressure Re 3ort Pressure Re 3ort Pressure Re 3ort Level Re ~ort Level Re )orr Level Re )ort Level Re 3ort Level Re 3ort Level Re3ort Level Re 3ort Level Re 3ort · Level Re3ort Level- Re 3ort Level Re 3orr Level Re 3ort Level Re 3ort Level Re 3ort Level Re~3ort Level Re 3ort Level Re 3ort 10-06-88 8-29-88 12-20-88 8-29-87 8-29-87 8-29-89 8-17-87 8-17-87 8-29-87 6-26-87 12-12-88 12-31-88 6-11-87 6-11-87 9-01 -87 5-O4-87 2-13-89 2-10-89 2-10-89 6-05-87 6-09-87 6-18-87 6-16-87 6-21 -87 5-08-87 8-18-87 8-24-87 6-05-87 6-2/3-87 8-5-87 6-5-87 9-8-87 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Commission3 Casing Anchorage Tubing Casing Casing ARCO Alaska, Inc. Post Office Bo .... 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fr~.ctures and Stimulations '3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-SA Failed MIT 1E-30 If you have any questions, please call me at 265-6840. Sincerely, ,. s " oo, Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KeEl .4-9 ATe 1478 ATe 1120 ATe 1130 3N-12, 3N- RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1, Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 1561' FSL, 105' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1390' FNL, 1800' FWL, Sec. 28, T13N, R9E, UM At effective depth 1218' FNL, 1912' FWL, Sec. 28, T13N, R9E, UM At total depth 1158' FNL, 1951' FWL, Sec. 28, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7875' MD feet 6667' MD feet 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-13 i~c~,o../ g. Permit number/approval number 7-204 10. APl number 5o-029-21584 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Effective depth: measured 7792' MD feet true vertical 6604' MD feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 115' I 6" 247 Sx CSII 115' MD 115' TVD 3735' 9-5/8" 1100SxASIII 3774' MD 3627' TVD & 300 SX Class G 7834' 7" 320SxClassG 7873' MD 6665' TVD & 175 Sx ASI measured 7566', 7568', 7570', 7591', 7595', 7599', 7601', 7606', 7621 '-7654' true vertical 6473'-6499' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, 7404' MD Packers and SSSV (type and measured depth) Baker "HB" Packer- 7333' MD; Baker "FVL" SSSV, 1784' MD 1' 3.' StimulatiOn or cement squeeze summary Intervals treated (measured) 6431', 6433', 6434', 6450', 6453, 6456', 6458', 6462', Treatment description including volumes used and final pressure RE£ iVED 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 581 537 0 200 130 Subsequent to operation 0 0 1365 1 1 00 1525 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas Suspended Service W~tter Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. feet ARCO Alaska, Inc~ 0 Subs~dian/of Atlantic Richfield Comp; ~ .~/~- I ~:) ~ jPBDT WELL CONTRACTOR FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT ~ ~.MARKS / ¢~;:0 - /8_ / G CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knott islgn'd ARCO Alaska, Inc: Post Office B~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 24, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil' and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are intent notices on Kuparuk Wells 1A-14, 3N-3, 3N-12 and 3N-13- Well Action Anticipated Start Date 1A-14 Failed Test March 30, 1987 3N-3 Conversion April 1, 1987 3N-12 Conversion April 1, 1987 3N-13 Conversion April 1, 1987 If you have any questions, please call me at 265-6840. .,1 ncerely, · ~ : h' ! G. B. Smallwood Senior Operations Engineer GBS'pg'0081 Attachments cc' File KOE1.4-9 ?-"h STATE OF ALASKA ALASk. OIL AND GAS CONSERVATION COMb,. SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved programX Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] Name of Operator ARCO Alaska, Inc 3. Address PO BOx 100360, Anchorage, AK 9951~0 4. Location of well at surface 1561' FSL, 105' FEL, Sec. 29 T13N RgE UM At top of productive interval ' ' ' 1390' FNL, 1800' FWL, Sec. 28, T13N, RgE, UM t_e_f,ect ive depth 218 FNL, 1912' FWL, Sec.28, T13N, R9E, UM At total depth 1158' FNL, 1951' FWL, Sec.28? T13N, RgE, UM 11. Present well condition summary Total depth: measured 7875' ND feet true vertical 6667' MD feet 5. Datum elevation (DF or KB) RKB 68 6. Unit or Property name KtJnaruk R.ivPr lin'if. 7. Well number 3N-13 8. Permit number Permit #86-81 9. APl number 50-- 029-21584 10. Pool Kunar,~k R.ivpr ~.il Pnnl _ _ ! Plugs (measured)None Effective depth: measured 7792' MD true vertical 6604' MD Casing Length XXX~](rX~]~NX~lXXXX X Conductor 115' Surface 3735' xxx~e~i~[te Production 7834 ' xxx~JaeZxxxx Perforation depth: measured feet feet Junk (measured) None feet . Size Cemented Measured depth 'TrUe Vertical depth 16" 247 SX CSII 115' MD 115' TVD 9-5/8" 1100 SX ASIII & 3774' MD 3627' TVD 300 SX Class G 7" 320 SX Class G 7873' MD & 175 SX ASI 7566', 7568', 7570', 7591', 7595', 7599', 7601', 7606', 7621 '-7654' truevertica16431,, 6433', 6434', 6450', 6453', 6456', 6458', 6462', 6473'-6499' Tubing (size, grade and measured depth) 2-7/8", 6.5#, 7404' MD Packers and SSSV (type and measured depth) Baker "HR" PRcl~c,r,- 7.'4~' Mil- R=~I,.--,,-"I~'VI" (:;(::(::V I?QA' MI'~ 12.Attachments Description summary of proposal ~ Detailed operabons program [] Convertinq a producer to a water in._iectinn w~ll 13. Estimated date for commencing operation April 1, 1987 6665' TVD BOP sketch [] 14. If proposal was verbally approved S~?~,?,:.,?,~,r'.' ,,w.:~;-;< ~..'..,,,,-~,_~ o~:~ Name of approver -?o.~zr. . /0_: 4,'~__0.~ F~¢!~;J//_/_? ..... Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .x~~--~/~"~ /~ ~._oT_~,l,e/,/~.S.[.?Operations Engineer Commission Use Only Date 3/24/87 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance *~r{t'[;f~'. Sit~l~ .- ' uomm,ss,oner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. Post Office E~,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal #5894 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3N-13 3N-14 3I-9 2X-7 2X-7 CET 5-15-86 6342-7768 CET 5-15-86 5882-7328 CET .5-5-86 7090-8949 CET 1-5-87 5995-7242 CET 1-8-87 5995-7011 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Date: State (+ sepia) BPAE Mobil SAPC Unocal Chevron ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska,' Post Office ,~ 100360 Anchorage, Alaska 99510-0350 Telephone 907 276 1215 RETURN TO- ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-08-86 TRANSMITTAL # 5791 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Fimal Prints: Schl: Open Hole: One * of each 3N-13 ~5" DIL/SFL-GR 04-26-86 Run #1 3773-7836 ~2",DIL/SFL-GR 04-26-86 Run #1 3773-7836 ~5" Den/Neu (poro) 04-26-86 Run #1 5800-7810 ~ 2" Den/~]eu (poro) 04-26-86 Run #1 5800-7810 - ~ 5"Den/Neu (raw) 04-26-86 Run #1 5800-7810 ~2"'Den/Neu (raw) 04-26-86 Run #1 5800-7810 ~yberlook 04-26-86 Run #1 7250-7800 2T-15 ~"x5" DIL/SFL-GR '~2" DIL/SFL-GR ~5" Den/Neu-GR (poro) '~2" Den/N~u-GR (poro) ~5" Den/Neu-GR (raw) "2" Der~/Neu-GR (raw) ~'- CyberloOk 04-21-86 Run #1 04-21-86 Run #1 04-21-86 Run #1 04-21-86 Run #1 04-21-86 Run #1 04-21-86 Run 04-21-86 Run #1 7128-7526 7128-7526 7128-7501 7128-7501 7128-7501 7128-7501 7128-7501 "-OCT 2 0 1986c----'' Alaska 011 & (~as Cons. Commission . Anchorage Receipt Acknowledged: NSK Files*bl ~ . D & M*bl Drilling*bl Rathmell*bl Vault*films Date: L. Johnston*Schl Pkgs. ARCO Alaska, in(:. ii, a Subl,i~iary of AllanlicRichfiel~Coml3an¥ , ~, ,"'"~,- STATE OF ALASKA '~ ~ ALASKAOIL AND GAS CONSERVATION (~U'MMISSION ~;3 WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... ,, .... 2. Name of ope'rater ............ 7. Permit,Number ARCO Alaska, Inc. 86-.81 3. Address' 8. APl' 'Number P. 0. Box 100:360, Anchorage, AK 99510 50- 029-21584 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 105' FEL, Sec.29, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. W'ell Number 1390' FNL, 1800' FWL, Sec.28, T13N, RDE, UM 3N-13 At Total Depth 11. Field and Pool 1158' FNL, 1951' FWL, Sec.28, T13N, RDE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk River 0il Pool 68' RKB ADL 25520 ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date comp., Susp. or Aband. ] i5. Water Depth, if off'shore i6. No. of Completions 04/21/86 04/26/86 08/18/86'I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.pl'ugBa'ckDepth(MD~TVD) 19. Directi'onalS'urvey I 20. Depth where SSSV set J 21. Thickness of Permafrost 7875'MD,6667'TVD 7792'MD,6604'TVD YES)~ NO [] 1784 feet MD 1700' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/CAL, FDC/CNL/GR, CET/GR/CCL, Gyro (GCT) , 23. CASING, LINER AND CEMENTING'RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 b" 6Z.5# H-40 surf '1 i'5' '2'/~i' 247 sx CS I I , -9-5/8" 36.0# J-55 Surf 3~4i '12-1'/4"' ' 1100 Ex'AS' Iii & 300 sx Class G 7" 26.0# J-55 Su~'f 7873" '' 8-1/2" 320 sx Class G ~ 175 sx AS'I , , , 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) See Attached "'2-7/8" 7404 ' 733~" 26. "~CID,'FRACTURE', CEMENT SQLJE'EZE, ETC. DEPTH INT'ERVAL"('MDi' AMouN'i' & KiND OF' MATERIAL USED See attached addemt.um'; dated 9/02/86', for fracture data , ,, 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours T~'sted PRODUCTION FOR oIL-BBL ..... GAS-MCF WA~'ER'-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ,.l~.. I Flow Tubi"ng Casin'g'Pressure ' CALI~ULATED '0iLIBBL .... GAs-Mc~ 'w/~T~'R-BBL ..... (~IL GRAVITY-APl ('c;rr) Press. 24-HOUR RATE 28. CORE DATA Brief'description o~'litholog'y, porosity, f'ractu'res, apparent dips and presence of oil, gas or water. Submit core chips. None ~:: :~P 1 9 1986 A-]a~<a Oil & Gas Cons. Oommissior~ Anchorage Form 10-407 * NOTE: Drilled RR 4/27/86. Perf'd well & ran tubing 7/20/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/112 Submit in duplicate 29. .. ' 30. [ ': ,':' . GEOLOGIC MARKER~"" MATION TESTS .. . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7446' 6340' NA Base Kuparuk C 7493' 6375' ='" ' Top Kuparuk A 7545' 6415' Base Kuparuk A 7687' 6524, · 31. LIST OF ATTACHMENTS Addendum (dated 9-02-86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge - Signed ~//~J~/X~ j~//~-- Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG (Cont'd) 3N-13 ITEM 24: MD -'~7566' 7568' 7570' 7591' 7595' 7599' 7601' 7606' 7621' - 7654' TVD 6431' 6433' 6434' 6450' 6453' 6456' 6458' 6462' 6473' - 6499' All perforated w/1 spf @ 90° phasing WCl:ll2b:dmr 9/15/86 ~7{? ! 9 1986 Alaska Oil & Gas Cons. Anchorage ADDENDUM WELL: 5/05/86 5/16/86 8/18/86 3N-13 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. Rn JB/6-1/8" gage ring to 7311'; unable to go deeper. Rn 5.992" gage ring/JB to 7774'. Rn CET/GR/CCL f/7774' WLM-6342'. Rn GCT f/7711'-surf. Frac Kuparuk "A" sand perfs 7566', 7568', 7570', 7591', 7595', 7599', 7601', 7606' & 7621'-7654' in 7 stages per 8/12/86 procedure using gelled diesel, 100 & 20/40 mesh sand. Press'd ann to 2300 psi w/diesel. Tst ins to 8300 psi; OK. Stage 1: Pmp 49 bbls gelled diesel pre-pad @ 20 BPM, 3300-4400 psi. Stage 2: 17 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM, 4440'-4400 psi. Stage 3: 158 bbls gelled diesel pad @ 20 BPM 4900-4740 psi. Stage 4: 38 bbls gelled diesel w/2576#, 20/40 sand @ 20 BPM, 4640-4680 psi (did not get to 3 ppg) Stage 5: 39 bbls gelled diesel w/6 ppg 20/40 @ 20.5 BPM, 4680-4650 psi Stage 6: 37 bbls gelled diesel w/8 ppg 20/40 mesh @ 20.6 BPM, 4650-4440 psi Stage 7: 46 bbls gelled diesel flush @ 20.2 BPM, 4440 psi Final ann press = 3020 psi, bled ann to 500 psi. Pmp'd 630# 100 mesh in formation leaving 735# 20/40 sand above top perfs in csg. Load to recover 384 bbls of diesel. hfs, 8/18/86. Job complete @ 1319 <: .... : :_91986 .~- -,,.~ 0it P~ Gas Gons. Drilling Supervisor Date SUB.$URFACE DIRECTIONAL SURVEY [~ UIDANCE F~ONTINUOUS ~]OOL Company Well Name _ Field/LOcation Job Reference No. 71503~ SALAZAR RECEIVED AUG- 1 1986 Alaska 0il & Gas Cons. Commission Anchorage ARCO ALAS~fA. I[~, ,, SURFACE: 3_N.-. 1_3 (1561' FSL, 105 ' FEL, SEC . 29 , T13N, R9E , UM) KUPARUKI NORTH SLOPE, ALASKA Date, 5/15/86 Comout~ By: KRUWELL GCT DIRECTI3NAL SURVEY :USTgMER LISTIN$ FOR ARC] ALASKA~ INS. 3N-13 KUP~RUK NORTH SLOPE.ALASKA SURVEY DATE=: 15-MA~-86' ENGINEER= S, SALAZAR METHODS O; CDMPUTATIOt TOOL LOCATI3N: TANSENTIaL- AVE~A~EO~ DEVIATI3N AND AZIMJTH INTERP]LATI~N: LINEAR VERTICaL:SECTION= 4DRIZo DIST..PROJECTED O~TO A TARGET AZIMUTH OF NORTfl 39 DES' 8 MIN EAST ARe ~0 ALASKA, INC. 3~-13 KUPARUK NORTH 5LOPEtAL~SKA COMPUTATION DATE: 1-J~N-8$. TRUE SJB-SEA CDURSE 4E~SUrRE~ VERTICAL VERTICAL DEVIATION AZIMUTH 3EPTH DEPT~ DEPTH 3EG MIN. DEG PAGE - I · DATE OF SURVEY: 15-M~Y-B6 <ELLY BUSHING ELEVATION: ENGINEER: $. SAL~ZA~ INTERPOLATED VAL~ES FOR EVEN 100 FEET' OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES ~3RIZ, DEPARTURE SECTION SEVERITY'NORTH/SOUTH EAST/WEST OIST,' AZI4UTH 0 0 0 15 0 21 0 26 0 23 0 30 1 Z 1 5 1' 5 1 ZO N 0 0 E S 28 39 E S 33 30 E S S 0 33 E S 16 4,Z E S 15 ZIE S 11 39 E $ 15 4,0 E $ 17 23 E 0.00 100.00 200.00. 300.00 400.00 500.00 500.00 700.00 BO0.O0 900.00 1 Z3 I 15 I 3 1 13 1 '16 1 5 0 50 68.oo FT' 2030.30 1999.71 1931.71 0 4,¢ 2100.00 2099.71 2031.7'1 0 38 2ZO0.O0 2199.70 2131.70 0 4,1 2300.00 2299.59 223[.69 1 13 2400.00 2399.55 2331.55 ~ ZB 2500.00 Z~gB.95 2~33.95 7 57 2630.00 2597.56 2529.56 10 56 2700.00 2695.21 2627.21 1~ 0 ZBO0.O0 2791,51 Z723.51 17 9 2900.00 2886.13. 2818.13 19 5Z S 1:~ 5B E $ 27 2~ E S' 39 55 E N 71 32 E N 52 ~Z E N ~B 0 E N 37 0 E N 31 50 E N 35 17 E N 39 12 E -20.71 -21.23 -21.59 -21.26 -1'6.32 -5.75 10.76 32.10 58.83 91.17 3000.00 2979.~7 2911.97 21 0 3100.00 3072.58 3004,.58 23 28 3200o00 3163.22 3095.22 26 3~ 3300.00 3251.33 3183.33 29 ~8 3400.00 3336.46 3268.~6 33 26 3530.33 3418.3B 3350.38 36 30 3600.00 3~97.23 3¢29.23 39 16 3700.00 3573.15 3505.15 ~1 52 3830.03 36¢6.26 3578.26 43 53 3900.00 3717.92 354,~.82 4~ gO N &O 11 E N 35 25 E N' 38 49 E N ~0 50 E N &l 51 E N ¢3 5 E N ~, ZZ E N ~5 22 E N ¢5 Z E N ~5 53 E 125.71 163.39 205.58 252.82 305.22 362.4k ¢23.72 ~80.46 556.22 625.55 .1330.3~ 999.89 931.89 1130.00 1099.36 1031.86 lZO0.O0 1199.95 1131,85 1300.00 1299.83 1231.83 1~00.00 1399.81 1331.81 1500.00 1499.78 1~31.78 1600.00 1599.76 1531.76 1700.00 1699.75 163[.75 1800'00 1799.7¢ 1731.74 19'00.00 1899.72 1831.72 0.00 -69-00 100.00 32.00 ZO0.O0 132.00 300'30 232.00 399.~9 331.99 599.98 53t.98 699.~6 531.96 799.95 73t.95 S 17~ 25 E -7.02 S 11"4,5 E -8.~0 S 9 23 E -9.64 $ I 9 E -10.98 S 7 k ~ -12.60 S 7 4,5 ~ S 10 52 W -15.26 S' 0' 57 W. -17,68 $ 5 55 E -18.81 S 3 4,4 E -19.90 899.92 831.92 0.00 -0.09 -0.2~ -0.52 -1.02 -1.53 -2.30 -3.~0 -5.76 DE~/IO0 0.00 0.04 0.13 0.10 O.OB 0.58 0.11 0'05 0.29 0.26 0.01 0.17 0-15 3.4Z 0-13 0.15 O.OB 0.15 0.24 0.3~ 0.15 0.13 0.15 3.75 2.91 3.35 4.OB 3.69 0.53 Z.3Z 3.20 3.68 3.60 3.09 3.2B 2.65 2.70 1.3~ 0.92 O. O0 N 0.19 S 0.64, S 1.26 S 1.99 S. 2.74 S &.lO S 5.90 S 7.72 S 9.79 S 0'00. E 0.10 E 0.40. E. O. 72 E: 0.8~ E O. 94, E 1.39 E 1,85 E Z.Z7 E · 2.90 'E 0.00 ~1. 0 0 E 0.22 S' 26 58 E 0,75 S 32 4 1.~,5 S' 29 57 2.16 S" 22 ~,8 Z.B9 S 18 51' E ¢.33. S 18 ¢¢ E 6,19 S'17 30. E 8.05 S 15 24 E 10'21 S 15 31 E 12.0¢ S 14.33 S 16.Z7 $ 18.13 S 20.11 S 22.2~. S 2¢. 32 S 25.97 S 27.k7 S 29.04 S 3.67 E 4.30 E ,~.89 E 4,.76 E 4,13 E 3.90 E 3,96 E 4.16 E 12*58 5 15 56 E 16.96 S 16 &Z E 16.94 S 15 1Z E 18.77 S 15 5 E 20.67 5 13 19 E 22'69 S 11 22 E 2¢.67 S 9 38 E 26.26 S 8 33 E 27.75 S' 8 12 E 29.34 S 8 8 E 30.33 S 31.~0 S 32.37 S 32.89 $ 29.7¢ S 22.76 S 10.75 S 7.26 N 29.59 N 54.99 N ~.47 E &. 96 E 5.58 E 5.73 E 10.69 E 18.B7 E 30.26 E 41.94, E 56.73 E 76.87 E 30.66 S B 23 E 31.79 5 B 58 E 32.a& S 9 46 E 33.57 S 11 34 F '~ 31.60 S 1:3 ~6 E 29.56 S 39 39 E 32.12 S 70 26 E 42.56 N BO 10 E 64,.03 N -62 22 E 9¢.51 N 56 25 E 81.52 N 98.99 E 128.2& N 50 31 E 111.Z0 N 1ZZ.Z1E 165.23 ~ 47 ¢2 E l~.B~ N 1~7.72 E Z06.88 ~ 45 33 E 1800~7 N 178017 E 253.95 ~ 44 33 E 220.35 N 21Z.80 E 305.33 N ¢~ 0 E 262.60 N 251.5& E 363.6~ ~ ~3 ~6 E 307.01 N 29~.05 E ~25.11 ~ 43 45 ~ 353.08 N 3&0.01 E 490.17 ~ 43 55 E ~00.56 N 388.89 E 558.36 N 4~- 8 E ¢~9o09 N ¢39.21 E 528.17 N &4 21 E FEET FEET: FEET ,FEET'.' DEG MI~ C3HPU'TATZ3N DATE: 1-JUN-86 2 ARCO ALASKAt IqC. DATE 3F SURVEY: 15-MAY-86 3N-13 K.LIPARUK N3RTH' 5LDPEtALASKA KELLY BUSHING ELE'f~ATIDN: ENGIqEER: S. SALAZAq $8.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET Or REASURED DEPTH TRUE SUB-SEA COJRSE VERTICAL DOGLEG RE:TAN~ULAR COORDINATES H)RIZ. DEPARTURE ~EASURED VERTICAL VERTICAL '3EVIATION AZ[RUT~ SECTION SEVERITY NORTH/SOUTH EAST/NEST DISTo AZIRUTH DEPTH DEPT~. DEPTH 3EG qIN' DEG H[N FEET DEG/IO0 FEET FEET FEET': DE~ H[N 4000.00 3789.56 37Zl.66 43 50 N ¢5 ) E 69~.68 &lO0.O0 3861.96 3793.96 43 ~2 N ~¢ 7 E 763.,5 ~200.00 3934.~5 .3866.25 '~3 ~3 N ¢3 33 E 832.31 4330.33: ~006.35 3938.35 '43'~7 N CZ 33 E 901.6¢ 4~00o00 ~078.99 ~010.99 ~3 3 N ~1 ~5 E 970.07 ~500.00 4152.25 ~08~,25 42 ~? N ~0 56 E 1038.08 4600.00 4225.74 ~157~7~ '42 ~2 N 40 27' E 1105.88 ~700.00 ~299.28 ~231.28 42 3~ N ~0 6 E I173.63 ~aO0.O0 ~372.85 G30G.85 42 G3 N 39 35 E 12kl.35 ~900.00 ~4~6.19 ~378.19 42 53 N 38 ~9 E 1309.33 0.53 1.07 0*70 0.27 0,21 0.56 ~,9.7.86 N ~,88.81 E $97.71 N 44 28 E 547.02 N 537.36 E 766.80 N 4~ 29 E 596.90 N 585.17 E 835.89 ~ ~,4 25 547.~8 N 63Z.54 E 905.17 ~ 4~ 19 698.~8 N 678.58 E 973.8~ N && 10 e 7~9.53 ~ 723.62 E 1041.83 ~ 43 59 E 801.01 N 767.77 E 1109.54 N 43 47 E 852.69 N 811.59 E 1177.18 ~ 43 35 E 904.65 N 855.03 E 1244.78 N 43 23 E 957.33 ~ 89~.01 E 1312.59 ~ 43 10 E 5000.00 5100*00 ~592.37 4524.37 43 6 5200.00 4665.~6 ~597.~6 42 53 5300.00 &~38.90 4570*90 42 36 5~00.00 4812.54 ~7~.64 42 Z4 5500.00 ~886.54 ~818.54 42 15 5600°00 ~960.53 ¢892.63 42 a 5700.00 503&o86 ~966o86 41 59 5800.00 5109.1~ 50~1.14 ~2 12 5900.00 5183.30 5115.30 41 59 ~519.36 ~451.36 43 3 N 38 3, E 1377°~9 N 37 23'E 1445.80 N 35 47 E' 151~.01 ~ 36 18 E 1581-81 N 35 ~5 E 15~9.26 ~ 35 15 E ~716.49 ~ 3¢ ¢7 E 1783o&7 ~ 36 10 E 1850.30 N 37 25 E 1917.23 N 35 58 E 198~.27 0.55 0.38 3.33 2.63 0.66 1010.72 N 940.37 E 1380.53 N 42 56 E 196¢.79 N 982.17 E l~&B.$O N 42 41 E 1119.23 N 1023.33. E 1516.5¢ ~ CZ 26 E 1173.76 N 1063.73 E 15'8~.06 N 42 11 E 1228.38 ~ 1103.~8 E 1651.23 N ~1 56 E 1283.23 ~ 11~2.59 E 1718.Z0 N 41 ~0 E 1338.24 ~ 1181.12 E 1784.91 ~ ¢1 25 E 1393.12 N 1219055 E 1851.51 N 41 11 E lk46.41 N 1260.10 E 1918.32 ~ ~1 3 E 1499.78 N 1300.73 E 1985.25 N ~ 56 E 6000.D0 5257.$9 5189°69 41 51 N 36 B E 2051o03 6100.00 5332.30 526~.30 41 ~0 N 35 2~ E 2117.50 6200.00 5407.02 5339°02 41 37 N 36 27 E 2183.81 6300.00 5~81.~3 5~13.~3 42 6 N 38 59 E 225~.59 6~30.00 5555.54 5487.54 42 9 N 38 15 E 2317.73 6500.00 5629.77 5561.77 42 1' N 37 33 E 2384o72 6630.00 5704.32 5636.02 ~2 6 N 37 8 ~ 2~51069 6700.00 5778.24 571~'24 41 59 N 36 40 E 2518.65 6800.00 5852.75 5784.75 41 40 N 36 l& E 2585.26 6300.00 5927.~6 585).46 41 41 N 35 5~ E 2651.65 0.82 3.01 0.57 0.52 0.25 0.52 0.70 1553o~7 N 1340.52 E Z051.89 q 40 47 E 1607.~8 N 1379o¢5 E 2118.23 N 40 38 E 1561.67 N. 1417092 E 218¢.~1 ~ 40 28 E 171~.08 ~ 1459.32 E 2251.15 ~ 40 2¢'' ~ 1766.54 N 1501.23 E 2318'27 ~ ~O 21 ~ · 1819.~1 N 15k2-39 E 2385.21 q ~0 17 E 1872.68 N 1583.03 E 2~52.12 q'&O 12 E 1926.26 ~ 1623.27 E 2519.02 ~ ~0 7 E 1979.89 ~ 1662.90 E 2585.58 ~ &O I E 2033.66 N'1702.01 E 2651.91 ~ 39 55 E 7000.00 $002.30 5934.30 4.1 19 7100.00 5077.54 $009.5~ 41 6 7200.00 5152.95 608~.95 ~1 0 7300.00 6228.56 $160.56 ~0 ~5 7500.00 $380.78 $312.78 40 10 7600.00 $457.19 6389.19 40 11 7700.00 6533.50 6465.50 40 11 7aO0.O0 6609.76 $541.76 ~0 19 7875.00 6666.93 $599.93 40 L9 N 35 l& E 2717.8~ N 3~ ~0 E Z783.55 N 3~ 7 E 2849.00 N 33 51 E 2914.17 N 33 ~ E 2979.03 N 33 23 E 30~3.31 N 33 10 E 3107.~9 N 32 52 E 3171.75 N 32 55 E 3236.05 N 32 55 E 328~.31 0.63 O.&3 0.36 0.31 3.77 0.41 0'39 1'45 0.00 0'00 2087.53 N 17&0.69 E 2718.0& N 39 &9 E 2141.&8 ~ 1778.49 E 2783.69 N 39 ~2 E. 2195.67 ~ 1815.58 E 2849.09 N 39 35 E 2249.9~ N 1852o15 E 291~.22 N 39 27 E 2304.05 N 1888.41 E 2979.05 N'39'20 E 2357.87 N 1924.10 E 3043.31 ~ 39 12 E 2~11.81 N 1959.51 E 3107.~9 ~ 39: 5 E Z466.01 N 1994.71 E 3171.76 N 38 58 E 2520.30 N 2029.86 E 3236.09 ~ 38 SO E 2561.05 N 2056'25 E 3284.38 ~ 38 ~5 E CDHPUTATI3N DA~E: 1-JJN-8~ PAGE A.~:O ALAS,(Ap 1,4C. DATE OF SURVEY: 15-M~Y~86 3~1-13 K LIPA R":J K' N3RTH SLOPEr AL~SK, A KELLY BUSHING ELEVATION: ENGI.~EER: So SALAZAR. 68.00 Fr" INTERPOLATED VAL~ES FOR EVEN 1009 FEET ~ HE~SURED DEPT TRUE SUB-SEA COURSE ~EASUREg VERTIC*L VERTICAL ~EVIATIDN AZINUTd DEPTH DEPTd DEPTH ~EG ~IN DE~ ~IN VERTI:AL DOGLEG . RECTANGULAR COORDINATES H3RIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET',' DE~ 0.00 0.00 -68.00 0 0 1000.00 999.89 931.89 I 23 ZO00.OO 1999.71 1931.71 0 ~ 3000.~0 Z979.97 2911.97 21 0 ~000.00. 3789.$6 3721.66 ~3 50 5000.00 ~519.36 ~&5~,36 &3 3 6000.00 $257.69 $189.69 ~1 51 7000o00~ 600Zo30 5936.30 ~1 19 7875°00 6666.93 6598'93 ~0 19 N 0 0 ~ 0.00 S 17 25 E -7.02 S 19 58 E -20.71 N &O 11 E 125.71 N ~5 9 E 69~.68 N 38 3 E 1377.~9 N 36 ~ E Z051.03 N 35 Z~ E Z717o8~ N 32 55 E 328~.31 0,01 0.15 Z.3Z .0.63 0.00 0.00 N 0.00 E 0.00 N 0 0 E 1Z.O~ S 3.67 E 1Z.58 S~16 56 E 30.33 S ,.,7 E 30.~6 S 8'23 81.52 N 98.99 E 128.Z, N 50 31 ~97.86 N ~88.81 E 597.71' ~'~ 28 1010.72 N 9~0-37 E 1380,53 ~ ¢2:56 1553.¢7 ~ 13~0°52 E 2051.89 ~'¢0 ¢7 2087.53 N 17~0.69 E 2'71B.0~ ~ '39 ~9 2561.05 fl 2056.25 E 328~°3~ fl 38 ¢5 ARCO 3N-13 KJPARJK NORTH SLOPEsALASKA CDqPUTaTION DATE: 1-JJN~8$ PAGE DATE OF S~RV'E¥: 15-H~¥-86 KELLY BUSHING ELEVATION: ENGINEER: S. SALAZAR INTERPOLATED VALUES FOR EVE~ 100 FEET OF SUB-SEA DEPTH $8.00 FT 0.00 0.00 -68.00 58.0~ 68.00 0.00 168.00 168-00 109.00 268.00 268.00 200.00 369001 368.00 300.00 ~68.01 ~68.00 ¢00.00 558.02 568.00 500.00 568.03 668.00 600.00 ?68.05 768.00 700.00 958.07 868.00 800.00 0 0 N 0 0 E 0 15 S 25 ~ E 0 ZO $ 35 5 E 0 Zk: .S 25 ~ E 0 25 $ 3 &5 E 0 27 $ 10 33 E 0 57 S 17 39 E I 4 S 12 53 E I 3: S 13 I 18 $ 17 4,2 E 958.10 968.00 900.00 1058.13 1068.00 1009.00 1168.15 1168.00 1100.00 1258.17 1268.00 IZ00.00 1368.19 1368.00 1300.00 1168.21 1¢68.00 1100.00 1558.2~3 1568.00 1500.00 1668.25 1668.00 1600.00 1768.26 1768.00 1700.00 1868.27 1868.00 1800.00 1 ZZ I ZO I 5 I 5 1 10 I 13 I 9 0 53 0 53 0 5*4 1968.28 1968.00 190~00 0 ~& 2068.29 2068.00 2000.00 0 37 2168.30 2168.00 2100.00 0 ~0 2268.30 2268.00 2200.00 0 ½6 2368.37. 2368.00 2300.00 3 31 2~68.79' 2~68.00 2400.00 6 50 2569.9~. 2568.00 2500.00 10 8 2572.01 2668.00 2500.00 13 0 2775.~5 2768.00 2709.00 16 21 2880.12. 2868.00 2800.00 19 ~ 2987.20 2968.00 2900.00 ZO ~ 3~95.9~ 3068.00 3000.00 23 19 3205.37. 3168.00 3100.00 26 ~ 3319.26 -3268.00 3200.00 30 30 3~38.09 3368.00 330~.00 3~ 3~ 3562.50 3¢68.00 3¢00.00 38 17 3693.10 3568.00 3500.00 ~1 ~2 3a30.29 3668.00 3600.00 &4 12 3969.93 3768.00 3700.00 43 ~7 4108.35 3868.00 3800.00 ¢3 ~3 0.00 -0.03 -0.19 -O-&O -O.Sa -1.38 -1~98 -3.02 -~-21 -5,35 $ 18 25 E -6.60 S 1~ 7 E -7.95 S 12 21 E -9.26 S 3 39 E -10.53 S 5 21 ~ -12.03 S $ 11 W' -13.83 S 10 52 W~ -15.72 S 5 3& 14 -17.30 S 2 7 E -18.~5 S 4, 20 E -19.5~ S 16 27 E S 26 ~7 E $ 35 16 E S 70 3 E N 50 31 E N 4,8 33 E N kl 27 E N 32 0 E N 3¢ 36 E N 39 ~ E -20.~9 -21.09 -21.50 -21.58 -18.&8 -9.72 5.28 25.62 51-80 8~, .60 121.18 161.40 208.02 262.a5 325.53 4,00.33 4,83.89 577.15 673.95 769.20 0.00 9~27 0.16 0.25 0.15 0.17 0.5~ 0.2~ 0.28 0.17 0.28 0.56 0.4,3 0.17 0.36 0.19 0.70 0.76 :),13 0.4,7 0.12 0.15 0.22 1.~8 3.09 3.91 3.59 3.51 3.59 1,27 Z.23 3.26 3.63 3.87 3.02 2.79 Z.6S 0.66 0.55 0.4,2 0.00 N 0.00 E 0.06 S 0.03 E 0.4.8 $ 0.29 E 1.03 S 0.63 E 1.76 S 0.83 E 2.4,9 S 0.87 E 3.56 S 1.23 E 5.31 S 1.74, E 7.15 S 2.12 E 9.09 S 2.69 E 0.00 ~ 0 0 E 0.07 S' 25 2 0.56 S 31 25 1.21 S 31 26 1.95 5 25 2.63 $ 19 23 E 3.77 5 19 5 E 5.58 S 18 6 E 7.4,6 $ 16 32 E 9.4,7 S 16 28 E 11.30. S 3.63 E 13.62 $ 4.15 E 15.69 S &.62 E 17.53 S *4.85 E 19.~5 S *4.84, E 21.56 S 4,.57 E 23.72 S *4.25 E 25.~9 S 3.92 E 26..98 S 3.93 E 28.55 $ .4.13 E 11.81 S 16 5.4 E 14,.2~ S 16 56 E 16.36 5 16 24, E 18.19 S 15 28 E 20.04, S 13 58 E 22.0*4 S 11 58 E 2.4.10 5 10 9 E 25.79 S 8 44 E 27.26 S 8 17 E 28.85 S 8 1¢ E 29.95 S ~.35 E 31.09 S &-80 E 32.07 S 5,35 E 32.90 S 6.2& E 31.09 S 8.9.4' E 25.4,3 S 15.86 E 15.00 S 26.80 E 1.71 N 38.50. E 23.9~ N 52.66 E 49.90 N 72.72 E 30.26 S 8 15 E 31.&6 S 8 .46 E 32.51 S 9 28 E 33.&8 S 10 .44 F ~ 32.35 S 16 2 E 29.97 S 31 56 E 30.71 S 60:46 E 38.53 ~ 87 27 E 57.85 ~ 65 33 E 88.20 ~ 55 32 E 78.07 N 96,05 E 123.78 N 50 53 E 109.59 N 121.0.4 E 163.28 ~ 4,? 50 E 146.73 N 1~9.27 E 209.31 ~ 45 29 E 188.25 N 18.4.~8 E 263.58 ~ .44,25 E' 236.17 ~ 227.12 E 327.66 ~ 43 52 E 290.16 N 277.70 E ~01.63 N .43 ~4 E 349.95 N 336.7~ E ~85.58 ~ 43 54 E ~15.29 N 40~.08 E 579.4,3 N .4~ 12 E .483.18 N .47~.00 E 676.86 ~ .4~ 27 E 551.16 N 54,1.38 E 772.57 N .4.429 E TRUE SJB-SEA COYRSE VERTICAL DO$LEG RE:TAN~ULAR COORDINATES HORIZ, DEPARTURE ~EASURE.D VERTICAL VERTI:AL ~EVI~TION AZIHUTd;, SECTION 'SEVERITY NDRTH/SO~TH EA$T/~EST DIST. AZIRUTH DEPTH'. DEPTH DEPTH DEG MIN' DES M[~, FEET DEG/IO0 FEET FEET FEET. DES MIN ARCO ALASKA, INC. 3N-13 KUPARLtK NORTH. SLOPEtALASKA ¢OMPUTATIDN DATE: 1-JJN-8'6 PAGE DATE OF SURVEY: 15-M~Y-86 KELLY 5USHIN~ ELE~ATIDN: ENGI4EER: S. SALAZA~. '[NTERPOLATED'VALJES mOR EVEN 100 FEET OF:SUB-SEA DEPTH 68.00 FT TRUE SUB-SEA C~jRSE 4EASURE~ VERTICAL VERTISAL 3EVIATION AZIMUTq DEPTH' DEPT.~: DEPTH DEG ~IN DE~ MI~ VERTICAL DOGLEG RECTANSULAR COORDI4ATESHDRIZ,~ DEPARTURE SECTION SEVERITY NDRTH/SOUT~,EAST/WEST DISTo AZIMUTH FEET DE~/IO0 FEET: FEET FEET: DEG MI~' 42~6.77 3968.00 3900.00 43 52 N &3 9 E $6~.60 438~.~7 ~068.00 ~O00.O0 43 7 N &t 53:E 959.83 4521.~ ~168.00 ~100.00 42 ~ 'N ¢0 45 E [052'63 4657.53 ~268.00 ~200.00 42 38 N ~O 1~ E 11~.91 ~733.3~ &368.~0 ~300.00 42 ~2 N 39 38 E ~236.87 ~929.77 ~468.00 ~¢00'00 ~2 55 N 38 3~ E 1329'59 5056.51 &568.00 ~500.00 43 6 N 37 36 E 1~.22.99 5203'~? &668.0'0 ~600.00 42 52 N 36 ~6 E 1516.37 5339.51 ¢768.00 ~700.00 ~2 30 N 36 6.E 1608.50 511~.9½ &868.00 ~800.00 42 18 N 35 21 E 169~.67 ,9.75 0-80 0.58 0.51 O..55 3,62 0.53 0.48 $20.~¢ Ni 607.~0 E 868.26 N 4~ 23 E 590.84 N 671~76 E }63.60. ~ 4¢ 11 E T60.55 N 733.12 E 1056.36 N 43 56 '% 830.75 N 793.06 E 1148.5! N 43 40] 901.20 N 852.17 E 1240.31 M:¢3 23 ~ 973.13 N 910.69 E 1,332.80 N'43 6 E 1046-68 N 96~.28'E 1~25.87 N ~2 46 .E 1121.12 N 1024,7~ E 1518.88 N'42 25 E 1195.33 N 1079.53 E 1610.65 N ~2 5 E 1269.~8 N 1132.B& E 1701.~4 ~'41 ~4 E 5609.9~ ¢968-00 ~900.00 42 7 57~&.57 5068.00 5000.00 42 1 5879o~1 5168.00 5100.00 ~2 0 6013.8~ 5268.00 5203.00 ~1 50 61~7.8~ 5368.00 5303.00 ~1 ~1 6281-90 5~68.00 5~00.00 42 ~ 6~16.80 5568.00 5500.00 42 7 6551.¢B 5658.~0 5600.00 42 4 6686.21 5768.00 570~00 CZ 1 6820.38 5868'30 5800..00 41 39 3~ ~:E 1790.13 37 15 E t880.08 37 9 E 1970.50 35 Z E ZO$O.Z~ 35 9 E 21~9.-28 3~ 55 E 2238.47 38 8 E 2329.01 .37 19 E 2¢19.18 N'36 &~* E 2509.~2 36 9 E 2598.77 0.31 0.95 3' 67 0.6~ 0.75 0,33 0.43 695~.27. 5968.00 5900.00 41 30 7087.3~. 5068.00 $000.00 41 B 7219.95 6168'00 6100.00 ~0 56 7352.02 6268.00 6200.00 40 39 7~83.28 5358.90 5300.00 ~0 9 751&.16 6¢68.00 6~03.00 ~0 l~ 77~5.22 5568.00 6500.00 ~0 19 7a75.00 6666.~3. 6598.93 ~0 19 N 35 ~0 E 2687.65 N 3& ~5 E 2775.25 N 3~ 2 E 2862,04 N 33 50 E 2947.95 N 33 25 E 3032.59 N 33 9 E 3116.59 N 32 55 E 3200.81 N 32 55 E 328~.31 0.57 0.47 0.29 0.35 0.3? 0.00 0.00 1343.72 N 118¢.92 E 1791.5& N ~1 24 E 1~16.91 N 1237.~9 E 1881.23 N 41 7 E 1~88.78 N 1292.½3 E 1971.51 N ¢0 57 E 1560.93 N 1345.9~ E 2061.09 N 40 ¢6 E 1633.50 ~ 1397.83 E 2149.9~ ~ ~O 33' E 170k.68 N 1~51.67 E 2239.0~ ~ ~0 25 E 1775.¢0 N 1508.21 E 2329.5~ ~ ~0 ZO E 18~6,79 N 1563.3~ E 2¢19.6~ ~ 40 1~ E 1918.85 N 1617.75 E 2509.80 ~ ~O B E 1990.80 N 1670.90 E 2599.07 ~ 40 0 E Z062.93 N 1723.08 E 2587'88 N 39 52 E 2134.53 N 1773.75 E 2775.~0 ~ 39 43 E 2206.52 N 1822.91 E 2862.12 N 39 33 E 2278.12 N 1871.03~E 29~7.98 ~ 39 23 E ~ 23~8.88 N 1918.17 E 3032.59 N 39 14 'E 2~19.¢7 N 196~.51 E 3116.59 4 39 ~ E 2~90.55 N 2010.59 E 3200.83 ~ 38 54 E 2561.05 N 2056.25 E 328~.38 4 38 45 E 3N-1 3 K UPA R LI.( N~3RTH SLOPE~AL~SKA MARKER TOP BASE TOP BASE ~BTD TD ~UP~RUK ~ KUP~RU~ C ~UP~RU~ A KYPARUK A CDMPUTATI~N INTERPOLATED VALUES FOR qEAS,~'RED DEPTH BELDN KB 7~6.00 7693.00 75~5.00 7687.00 7792.00 '7B75.00 DATE: 1-JJN-8$ 2HDSEN HORIZONS FROM KB S339.5& ~375.~3 6~15.16 5523.56 6603.66 5666.93 ORIGIn: 1561 S~B-SEA 5271.54~ $307.~,3 534,7.16 $~,55.56 6535.66 5598.~3 PAGE 6 DATE BF SURVEY: 15-MAY-B6 ~ELLY,BUSHINS ELE~'AT[DN: 6~.00 FT: ENGZ~EER:,So SAL~ZA~ FSLt S~RFACE gDCATION 105 FELs~:SEC· 29~ T13Nt! R9E~UM~ RECTANGDLAR COORDinATES NORTH/SDUT~i EAST~WEST 2328.80 N 190&,89' E 2354.11' N 1921.62 E 2382.1~ N 19~'0'05 E Z~,,58.95 N 1990,'16 E 25].5.95 N 2027.05 E 2551.05 N; 2055.25 E COMPUTATI3N DATE: 1-JJN-B$ PAGE 7 A R :',g ALASKAt 34-13 KBPAR~K N3RTH SLO'PEtALASKA MARKER TOP KUPARUK : BASE KUPARUK C TOP KUPARUK & BASE KUPARUK A PBTD TD ~,~***~**~ STRATIGRAPHIC ~EAS~RE~ DEPTH aELO~ KB 7~6.00 7~93.00 75¢5.00 7687.00 7792.00 7S75.00 D~TE DF SURVEY: 15-M~Y-85 KELLY BUSHING ELEVATION: $8,,,00 FT. ENGINEER: S. SALAZA2' FROM KB D:~IGI~= 1561 FSL~ TVO SUB-SEA 6339.5~ 6375.¢3 6~15.16 6523.56 5603.66 6.666.93 6271.5~ $307.~3 $3~7.16 S¢55.56 $535.56 S598..93 23Z8.80 N 190~.89 E 2354.11 N 1921o62 E 2382.1~ N 19~0.05 E Z~58.95 ~ 1990'15 E 2515.95 N' 2027.05 E 2561.05 N 2056.25 E FINAL WELL LgCATI3N TRUE qEASgRED t/'ERTICAL DEPTH DEPTH 7875.00 AT'TD: SJB-SEA VERTI:AL DEPTH S598o93 ~IORI ZI3NTAL 3EPARTU~E DISI'ANCE FEET :)E3 MI~ 3Z~3¢. 38 ~ 38 SCHLUMBERGER O l REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC WELL 3N- 13 F I ELD KUPARUK COUNTRY USA RUN 2 DATE LOOOEO 1S - MAY - 86 REFERENCE 000071S03 WELL: 3N-13 (SURFACE: 15 61 ' F~J~, 10 5 ' FEL, SEC. 2 9, T13N, R9E, HORIZONTAL PROJECTION 9000 25OO Z000 5OO 1000 ~00 ,SOUTH -500 NEST REF 00007 ! E;0:9 SCRLE = 1/500 !N/FT ~-, .'T-?i : i ii -~ .~--' "-:::t::t:~" .. "*.~ ~ ~ .'. '.. 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ScRLEo IN VER?ICRL OEPIHS HORIZ SCALE = 1/1000 IN/FT STATE OF ALASKA /""~ ALAS,,A OIL AND GAS CONSERVATION CON, .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdOwn [] Stimulate [] Plugging [] Perforate [~ Pull tubing [] Alter Casing [] Other I~ Complete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1561'FSL, 105'FEL, Sec.29, T13N, R9E, UM At top of Productive interval 1390' FNL, 1800'FWL, Sec.28, T13N, RgE, UM At effective deEth 1203'FNL, 1922'FWL, Sec.28, T13N, R9E, UM At s c.2 , u, 5. Datum elevation (DF or KB) RKB 68' 6. Unit or Property name Kyparuk River Unit 7. Well number 3N-13 8. Approval number 84 9. APl number 50-- 029-21584 10. Pool Kuparuk River Oil Pool Feet~ Gyro Date Submit in Duplicate 11. Present well condition summary Total depth: measured 7875' true vertical 6667' Effective depth: measured 7792' true vertical 6604 ' Casin.o conooctor Surface L~pth Size 16" 3737 ' 9-5/8" 7873 ' 7" Producti on feet feet feet feet Plugs (measured) None Junk(measured) Cemented 247 sx CS II 1100 sx AS III & 300 sx Class G 320 sx Class G ~' /75 ~x. A5 .T_ None Measured depth ll5'MD 3774'MD 7873'MD True Vertical depth ll5'TVD 3627 ' TVD 6665'TVD Perforation depth: measured 7566'MD 7568 ' MD true vertical 6431'TVD 6433 ' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7404' P~nkers 8 1784' FIB plkr ~nc)3'~V& (~V~L.e ~sns~ measured depth) 7570'MD 7595'MD 7601'MD 7591'MD 7599'MD 7606'MD 6434'TVD 6453'TVD 6458'TVD 6450'TVD 6456'TVD 6462'TVD 12. Stimulation or cement squeeze summary 7621'-7654'MD. 6473'-6499'TVD RECEIVED AUG- i i~oo N/A Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 011 & Gas Con~. Commission Anchorage 13. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion well History w/Addendum, dated 6/9//86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 TitleAssociate Engineer (DAM) SW0/082 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and Submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test. data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ]County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W,O. no. jTitle I AFE AK1207 Nordic 4 Operator ~ A.R.Co. W.I. ARCO Alaska, ;lac, Spudded or W.O, begun Date Complete Date and depth Complete record for each day reported as of 8:00 a.m. 7/19/86 thru 7/20/86 North Slope Borough ADL 25520 Accounting cost center code State Alaska Completion Well no. 3N-13 AP1 50-029-21584 rrotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% Jabandonment of this well I JHour J Prior status if a W.O. 7/19/86 ! 0830 hrs. I 7" @ 7873' 7792' PBTD, RR Diesel Aceep~ r.ig @ 0830 hrs, 7/19/86. ND tree, NU & tst BOPE. RU DA, perf @ 1SPF f/7621'-7654' & w/8 SPF @ 7591', 7595', 7599', 7601', 7606', 7566', 7568' & 7570'. Rn 235 its, 2-7/8", 6.5#, J-55 EUE 8RD AB mod tbg w/SSSV @ 1784', HB Pkr @ 7333', "D" Nipple @ 7371', TT @ 7404'. ND BOPE, NU & tst tree; OK. Displ well w/diesel. RR @ 0400 hrs, 7/20/86. Old TD / New TD I PB Depth Released rig Date I Kind of rig I 0400 hrs. 7/20/86 Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data RECEIVED AUG- 1 1986 Alaska 011 & 6as C~ns. C0mmission Anchorage 7792' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SpM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 5/05/s6 5/16/86 3N-13 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. Rn JB/6-1/8" gage ring to 7311'; unable to go deeper. Rn 5.992" gage ring/JB to 7774'. Rn CET/GR/CCL f/7774' WLM-6342'. Rn GCT f/7711'-surf. RECEIVED AUG- ! 1986 Alaska 011 & Gas Cons. Commission Anchoralie Drilling Supervisor Date STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMio,SlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend D Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension D Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate C Other 2. Name of Operator ARCO Alaska~, Inc. 3. Address P· O· Box 100360 Anchoraqe, AK 99510 4. Location of well at surface 1561'FSL, 105'FEL, Sec.29, T13N, R9E, UM At top of productive interval 1358'FNL, 1817'FWL, See.28, T13N, R9E, UM (approx.) At effective depth 1213'FNL, 1960'FWL, Sec.28, T13N, R9E, UM (approx.) At total depth 1169'FNL, 1990'FWL, Sec.28, T13N, RgE, UM (approx.) 5. Datum elevation (DF or KB) 68 ' RKB 6. Unit or Property name Ku.~0ruk River yqit 7. VVell number 3N-13 8. Permit number 86-81 9. APl number 50--029-21 584 10..Poo Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7875 true vertical 6667 feet Plugs (measured) None feet Effective depth: measured 7792 true vertical 6604 Casing Length Size Conductor 80 ' I 6" Surface 3737' 9-5/8" Production 7882' 7" (9' above rotary) _. Perforation depth: measured None feet Junk (measured) None feet Cemented Measured depth Conductor report 115'MD not available. 1100 sx AS I I I & 3774 'MD 300 sx Class C 320 sx Cl ass G 7873 'MD ~ueVerticaldepth 115'TVD 3631'TVD 6665'TVD true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Alaska Oil & ~;~s Cons. C0mmicsion 12 Attachments · Well' History Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~{~~ ~ Title Associate Engineer COmmission Use Only ( DAM ) SA/039 Date Conditions of approval Approved by ~' ~,~J~ ~, ~]]"~ Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner IAppr°val N°' ~j~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ~ ~ AR~O Oiland Gas cOmpany ~ ~ ~ . '- . Well History- Initial Report Dally Instn~ctiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough IState Alaska North Slope Borough I Field ILease or Unit Kuparuk River ADL 25520 Auth. or W.O. no. JTitle AFE AK1207 I Drill Doyon 9 Alaska JWell no. 3N-13 AP1 50-029-21584 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour Spudded 4/21/86 1400 hrs. Date and depth aa of 8:00 a.m. 4/22/86 4124186 4/25/86 Complete record for each day reported IARCO W.I. Prior status If a W.O. 56.24% 16" @ 115' 2296', (2181'), TIH Wt. 9.8, PV 24, YP 28, PH 9.0, WL 13.9, Sol 9 Accept rig @~1030 hfs, 4/21/86. NU diverter. 4/21/8,67 Dr1 co 2'296,. 16" @ 115' 3800', (15047), POOH:' to:~ rn' csg wt. 9.5, PV 14, YP 13, PH 8.5, WL..-t3.6, So~. ~,: Drl to 3800'% short: trip, POOB. '":2246', 1.2', S72,8E;~ 2245.70 T~,... 6.66.VS, 2610', 10.9'~, N36.0E,~ 2607.64 T~'~-<-~ 26.18 V8,. 2926', 20.0a, N39,1g" 2911.55 ~,. Ill.78 VS, 3145', 3770', 43.7~, N46.6g, 3627.83 T~, 545.65 Spud well @ 1400 hrs~ 23.29S~ 3.13S, 66.53N, 24.6', N37-.SE, 3114.50 TVD, 193.94 VS, 132,0§N, · 18,08~!P 45 95. 144.99R 389.61N, 385.7111 9-5/8" @ 3774' 3853', (53'), Chg top section of turbine Wt. 8.4, PV 2, YP 1, PH 9.5, WL 18.4, Sol 1 RU & rn 94 its, 9-5/8", 36# BTC csg w/FC @ 3692', FS @ 3774'. Cmt w/ll00 sxAS, III, followed by 300 sx C1 "G". Displ using rig pmps, bump plug. ND diverter. NU & tst BOPE. RIH to FC w/8½" BHA, ~ csg to 2000 psi. DO flt equip & cmt + 10' new hole. Condu¢~ formation cst to 12.5 ppg EMW. Drl 8½" hole to 3853', turbine locked up, POH. 9-5/8" @ 3774' 6392', (2539'), Drlg Wt. 9.2, PV 8, YP 5, PH 9.5, WL 8.2, Sol 6 Drl & surv 8½" hole to 6392'. 4094', 43.8*, N44.0E, 3861.90 TVD, 768.40 VS, 4971', 43.0", N38.9E, 4501.51TVD, 1367.74 VS, 5974' 547.21N, 544.96E 996.18N, 942.80E , 42.0°, N37.0E, 5241.40 TVD, 2044.32 VS, 1538.34N, 1348.49E The above is correct [ Date { Title For fd~'~ ~rep~tlon an~-dls~butlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling'Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth or W,O. no. AFE AK1207 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 4/26/86 thru 4/27/86 Old TD Released rig County or Parish Lease or Unit ITte North Slope Borough ADL 25520 Drill AP1 50-029-21584 Accounting cost center code State Alaska Well no. 3N-13 IA.R.Co. W.I. 56.24% Date 4/21/86 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well I our ~Prlor status If s W.O. 1400 hrs. 7" @ 7873' 7875' TD, 7792' PBTD, RI{ 9.9 ppg Brine Drl & surv 8½" hole to 7845', short trip, C&C, POOH. RU Schl, log DIL/SFL/SP/CAL f/8742' WLM - 3775' WLM. Rn FDC/CNL/GR f/7842' WLM-7200' WLM & 6000'-5800' WLM. Cont w/GR to 2000', RD Schl. RU & rn 191 its + 1 mkr Jr, 7", 26~, J-55 BTC csg w/FS @ 7873', FC @ 7794', mkr Jt @ 7549'. Cmt w/100 sx 50/50 C1 "G" w/8% D-20, .2% D-46, .5% D-65 & .5% D-112, followed by 220 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. ND BOPE, NU & tst tbg head. Instl adapter flange & vlv. RR @ 1215 hrs~ 4/27/86. 6317', 42.3°, N39.5E, 5495.70 TVD, 2274.47 VS, 1719.10, 1490.99 7845', 40.5°, N33.8E, 6643.78 TVD, 3280.73 VS, 2534.36, 2083.50 1215 hrs. New TD PB Depth Date 7875' TD IKndOfrg 7792' PBTD 4/27/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P~ Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ITitle Drilling Supervisor 'ARGO' Alaska. tnc~ Post Office Box 100360 Anchorage. Aia~#a 99S10-0360 Telel~one 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 05-13-86 TRANSMITTAL # 5658 Transmitted herewith are the following items. return one signed co, py of this transmittal. Please acknowledge receipt and Open Hole LIS Tapes Plus Listings: Schl: One of each Please note: 3N-12 ~3N-13 These tapes are both labeled as EDIT LIS Tapes--According to Schl. they are reEular Open Hole tapes since we have received no previous tapes. oz,- o-s6 This tape is a standard Open Hole LIS plus listing. ~3N-14 05-04-86 Run #1 t~ceipt Acknowledged: April 18, 1986 Mr. J. B. Kewin Regional Drilling Engineer AR~O Alaska, Inc. P. O. Box 1003.60 AnChorage, A!aska 995I~0-0360 -Telecopy: (907) 276-7542 Re: 3N-13 ARCO Alaska, Inc. Permit No. 86-81 Sur. Loc. 1561'FSL, 1~*~i, Sec. 29, T13N, RgE, UM. Btmhole Loc. l178'FNL, 19~.~, Sec. 28, T13N, RgE, UM. Dear Mr. Kewin: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface. casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment install~tion so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF TRE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION CO,v~-MISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Typeofwork 'Drill'l~ Redrill~l lb. Type of welI. Exploratory F~ StratigraphicTest [] ADevelopmentOil~ Re-Entry Deepen Service [] Developement Gas [] Single Zone~i~ Multiple Zone/E] 2. Name of Operator 5. Datum Elevation (DF or KB) ~10. Field and Pool ARCO Alaska~ Inc. RKB 68'~ PAD 3~' feet Kuparuk R~ver Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1561 'FSL, 105"FEL, Sec.29, T13N, PgE, UM Kuparuk R~ver Unit Statew~de At top of productive interval 8. Well number Number 1358,FNL, 1817'FWL, Sec.28~ T13N, PgE, UM 3N-13 ~8088-26-27 At total depth 9. Approximate spud date Amount 1178'FNL, 196~'FWL~ Sec.28~ T13N~ RgE~ UM 0~/21/86 $500~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7850 'MD 105' ~ surface feet 3N-12 ~'~ ~urface feet 2~n (~9'TVD~ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth23~1 feet Maximum hole angle~3 0 Uaximumsurface 2915 psig At total depth ~VD) ~2 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling ~ngth MD TVD MD TVD (include stage data) HF_FFw HF-EFW 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: - measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program~ Drilling fluid pro~ ~ Time vs depth plot 21.1 hereby c~i~y ~at the foreg~g is, t~ue and correct to the best of my knowledge -/ -/ . ' . Regional k /~ ~ / ~'' Permit Nu~ ' f I APl number ' i Approval date See cover letter ' ' 86-81 ~ 50- 029-21584 I 04/18/86 for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ~ No Requiredwo~~M; ~5M; ~10M; ~ 15M e~~ Other: by order of Approved by~ ~ ~ ( ~~~~ Commissioner the commission Dat -- ~ ....... Form 10-401 Rev.-l"~-78~ Sul: triplicate ii 'J 6 5 4 t 2 R c !VED APR ~ ~, 1986 ........ ,~",~ DIAGRAM ~1 13-5/8" ...3(~ PS] RSRRA BCP STACK ./ I. 16' - 2000 PSI T~ ST~TI~ ~ 2. 11' = ~ ~] ~]~ ~ 4. 1~8' - ~ ~Z P]~ ~ KI~ LI~ -:" ..ACCUVULATOR CAPACITY TEST 1, Q-EO< AND FILL ACO. M.I_ATQR RESERVOIR TO'PRCPER LEVEL WITH HYDRAULIC FLUID, 2. ASSL.I~ THAT A~TC~ P~ESSLJ:~ IS ~5CX~ P~I WITH 1500 PSI DONN~TRF_AM CF' T]-E I~GJLATCR. ~ 3. CI~SERVE TI~E, TH~N CLOSE ALL UNITS SII~I. TN~OJ~Y ALL UNITS ARE CLOEED WITH Q-tARGING ~ CFF. 4. RECO~ Cl~ NADC REPCRT, THE ACCE~'rAE~_E LC~ER LIMIT IS 45 SE~ CLOSING TIhE: AN~ 1200 PSI REh~AINI~ PRE~. 13-5/8" BOP STACK TEST !. FILL B(:P STACX AND Q-[3~ MANIFOLD WITH A~CTIC DIESEL. 2. OEO< THAT ALL Lex:3< EO~ S(3:E~ IN ~.~ ARE F1JU. Y ~-TRA~. SEAT TEST PLU~ IN W~,LHEAD WITH RUNNING Jt AN3 ~JN IN L~ LIN~ VALVES ADJACENT TO B(:P STAQ~ ALL OTt-ER 4. PRE~ UP TO 250~ FCR I0 MIN. IN- ~ PRE~ TO--AN:) H~L.D FC~ I0 MIN. BLEED PEE~ TO 5. CPEN AhNJLAR P~-VENTER AN:) MANJAL KILL AN:) Q-EXE LI~E VALVES. CLOSE TCP PIPE RAMS AhD HQ~ VALVES CN KILL AhD Q-O<E 6. TEST TO 250 PSI Ah~~A~ IN STEP 4. '/. (:X3NTI~ TESTING ALL~A~VESo LIAES, AN:)CNO<ES WITN A 250 PSI LCd/ AAD 3000 PSI HIGH. TEST AS IN STEP 4. DO NgT ~~ TE-~T ANY ~ T~T NOT A FI~_L CLOSIN~ POSITIVE SEAL O,O(E. QN, Y 8. (3:~N T(3~ PIPE RAMS AN:) CLOSE BoT'rcI~ PIPE TEST BOTTO~ PIPE RAMS TQ ~50 PSI AhD 3000 PSI. D. CPEN BOTT(3~ PIPE RNv~, ~(:X OUT RUNNING ,rr AN:) .10. O_OSE BLII~D RAMS Ah~ TEST TO 250 PSI ~ PSI. MANIF~ AhD LIt~ES AR~ FULL. CF NCN-FEEE'ZING. FLUID. SET All VALVES IN DRILLING TEST STAll, PIPE VALVES, KELLY° KELLY COCKS, DRILL' PIPE ~AF~ VALVE, AN:) INSID~ B(;P TO ~50 PSI A~D 3000 PSI. I~. RE~ TEST IN=CI~MATIC~ C]N BLC~ Pf~ TEST FC~to SIGN, AN:) SEN:) TO DRILLING SLPERVI~. 14. PERFO~ ~E BCi:~ TEST AF'FER NIPPL[NG UP AAD WEEXLY THEREAFTER ~]Ct~LLY CPERA~ ~ DA~LY. KUPARUK RI VER UNIT 20" DIVESTER SCHEMATIC DESCR ! PT ! ON I. tG. C~CTC~. 2. TAI',I,(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TAKKO LO~ER- OUICK-COh/,,ECT A$SY. 5. TAI'~I,(O UPPER CX.JI CK-C~CT ASSY. G, 20' 2000 PSI DRILLING SPOCI. W/lO' .OUTLETS. 7. I0' HCR BALL VALVES W/I O' 'DIVERTER LINES. VALVES OPEN AUTOMAT I CALLY UPON CLO~RE OF AI~'~L~AR PREVENTER. B. 20" 2000 PS! A~LAR PREVENTER. 7 6 7 MA)NTENANCE & OPERATION -2 I i , APR 1 6 i986 Alaska Oii& Gas Oons. Go~,~missi'o~ I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY TNAT VALVES HAVE OPENED' PROPERLY. 2. cLOSE AhaNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5,i CLOSE' AhINULAR PREVENTER IN THE EVENT"THAT AN IhFLUX OF WELLBCE~ FLUI DS OR GAS I S DETECTED. IF NECESSARY, MAI~JALLY OVERRIDE ANO CLOSE APPROPR I ATE VALVE TO ACHI EVE DO~I~I ND DIVERS I ON. DO NOT SHUT IN NELL UNDER ANY CIRCUMSTANCES. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco divglr~er system. 3. Drill 12¼" hole to_9-5/8,' surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. .~_ 5'. Install and. test blow out-preventer~ Test casing to 2000 °si~ 6. Drill out cement and 10' new hole. PerfoTM leakoff test. 7. Drill 8½" hole to logging, point according to directional plan. 8. Run open hole logs.~, Continue drilling.8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. - 10. Run and cement 7" casing. Pressure test to 3~0 pMi~g~ 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16o Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel and set packer. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. RECEIVFD APR 1 Alaska Oil & Gas Cons. Ancharage LWK4 / ih ,,, . , _ .. 'T'YPIC,~t I_ r'qUD S¥STEr,1 5CHEr,~RTIC Density PV YP 20-40 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10+ DRILLING FLUID PROGRAM Spud to =.~ 9-5/8"~ SUrface Casing 9.6-9.8 15-30 Drill out to Weight UP 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - -- -- -- -- -- Triple Tandem Shale Shaker 2-Mud Cleaners Centrifuge Degasser Pit Level Indicator (Visual & Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. LV~<3 / ih ARCO ALASKA~ - I NC-, .... ~. .......... · ..... PAD :3N,. 1,/ELL'- HO,~' 1:3 'PROPOSED ' KUPARUK F[ELD.--NORTH'SLOPE ALASKA : ·. .................... :.. ' ......... :.__i_: .... LL.~_?._LLL' :_:L ...... L'...__.L'_-~ ...... ~_L~L_~ .Wt~ST~.AB~r.:.~.~'_L_L_tL:~-_:_.'__:' ................ : ....... _. ' ......... ' 1000 0 .... ~1000._.:.' ' 2000 . ' . _ ~ ...... ~. .................................... ~ .... ~- ................. ~ ................. ~- ..................... ~ ............ i ........ ..... . .......... ~ ............................................ ~ ................... ~ ..... · , , __~ ................ , .............. TAR~r CR :i-i~R -" ~ -: "-:-::.~.-- -#-=---: --' .................. ....................... ' ................... TI"H)"7~"/'~ ...... : ............................. . : -~ ................ ~ '."i __ EAST ' 1952 .......... . ....... . _ : ....... ~. ~ ............. .- ......... .................. = ..................... : ........... ,-- . .- : ............... : ...................................... . ...................... ~-'- ..... gURFACE'-'LOCAT[O#, . . ......... TARGET---LOCAT. IOH, ......... .....: ....... .... .............. -: ....... ..... ...... .= -,=,,. ,,,,. ,.,,,. ,.,,,. 'r,_~,, n, cu:._.:..._: -~']---;-r---t----- -:'-'?'----'-'-- ' SEC. 28.'T~3#'. ~ .: ...... - .... ' " .... ~ ...... .: . . ~ - ~: ~ ~ ~,~ .... - ...... . - ! .............. . ..... ..... ! ................. , ..................... . ....................................... · ............... i ............. . .................. -: ........... ............. . ........................................ ................ :-- --~-' ................ 't .... ......... ~ ........................... ";" -' · ......................................... " ........................ ~'-:---;-::;':-,-~'-.--.?,-,:,.-~.~;~'~-'~mh-~'~°- -~ ......... .__1~ LOCAT.IO#~_.~..'-~':-: . ' _ ............... : - ~ ..... ~ ..................... ,---...- -,,,-~-,~,,t-,,,~ ..................... -, .............. 1178'.-.FNL. · '.19~4". - FWL ......... ........... _~ ..... _ _ . _~ ..... : ..... _:, ......................... ~ _.~ ..... ~ ........... -.~ ..... .,_~:__-.~,~'-,~-'.:.-'-T?'-- ..... -,'----.:-:- ..... :, ........... $E¢. - ~6,-.T 13#, .-R~E ...... ~ ....... ......................... ~, ...................... ? ...... : ............. -,- .............t- .......... 4 .............. ..... .............. ' , ........... . .................. ,t.- ............... ............. :, ...................... ~ ............... 3093~,:.:::.(T-0 TARGET:) - -"" ' ..... i ....... ', ...... : ......... ........... . ............:- ............... '-t .......... i ' ...... - ....................................... _ .............................. : ........ , .......... ! ........................ ~ - . .: ..................... : _ .................... j- ; i ' ~ . . i , "" ' l,:-.~.'- t ~..~ i : i I E t , ": ' ~ ' .--' I ' ' . ! ~ ' ' I'"'":' ! ~ ', :',! :'~I ;' '~1" i '''' ~' ''' · i ~ ~ ' ; .... , : '~ ~ , i · t : ' ~: ' ' : ' : I ~ ' ' ' ~ " ' ' ' .... ~ ~ ; ~ I , ~ I ~ ' ~ '~ ' ; I ' ~' ' , ' '' (' '. I ' "~ ' ~ ' . ~ ' I ' ~'~ .... ~ ......... ~ ; .... ~ .... :4 :--~...~ ' , ~,,, ~1~ '' ' ~ - , ,,, . I ; ;~. ~ ' ' ' ' '~36~7~ ': ',' i .... ~ :' ' ' ': ,' ~ . ....... ;..~ .... '....' ........ ~ ............ '.__: I .... :..;. i....i...... _ . ~'~' 'i"~'""~-I'"~'''~''''' ..... ~ .......... . ' : ~ ~~ ~ ~ · ",1 ' i '. ' ' : ' .... ~ ' :, ' , . ' ~ ' ' ' , ~ , ~ . ~ ' I · ~ ,~~: . : i. ~ ' ~ ,. ' : ', .... ~' ,. ' "i ~ ~'~ ~ ~'' ~", ', ~i , "' ~'~.'~'~ ~ ~ ' , ' ' '. ' ' : ·. ~ .... i':'~ · ' ~ ~ , t.' '~' ~ .... : i ~ ' -"~'"'K'r-'~- "'~' ........... r'"t"T",.""1' "~""I ..... ?'~ ...... ! .... 1 ...... ' , ' ~ ....~ ............. ~ ........ ' ..... ~ ...........'"'~ ............ ~-'~ .... P'i"':" ~ , .. ~ , . ~ ...... ,. i ~. ,,~ ....... ~-'i .I ' I I .% ~ : ~ , ' , ' ' .1 .... , t., ~ . ~ ' ' I '~ I" ,"' ~' : ~ ~ : ' I ' ~ ' ' ' . ' ' i : '~ ' ' 1' ; - , ' .. i ~' .~ ~ ~ i ' ' I ' ' '1 ,' I . ~ .... t' ; , ~'',' ~ ..... ' ' I .Y ~ ~, '., . , I.,~.~ ..... ~ , ,~ : ~. I ' I ' : :' : ' ' ~ '; i ~ I ' . ~ ' ' I ' , , 1 -......~.-:-.~,~: 'r.~..:.4~,,;.." ~:' '' ' " ' ' ';'; '~ ' ' ''''''.'~'' ' ~"~' ~ ' '~" ,' T ................... : ................... ' '. ..... ~'"-" , ........ ~ ..................... ,' ,, ...... ~ ....... ~-~ ......... ~.t ..... :,--'~-; ........ ~,-~ ......~ ,~ , , , , . ~ . , . ~ ' , , . ~, . , :, , .~ .... ;' "t ~ ................... l I ..... ~ ~ ' ........... ~ · , , ~' . , I ,'" ' { , ;' "' .... .... ~' I''~ .... ~ "~ ' s' : ' ' ..... ~' '~ ;, ~. . ' ' ... ~ ..... ~ .' : '' .~ ; ......... i ', t. ~ ~ ' ' ; ~ ' I :' ~ ' I. : '. . 1 ~. ~t~'"t';","t'~ '" I ~ 1'" ~' ~ .......... ,'i ...... ;',': .... ~ ' ' ; ...." " ' '~ ,..~.~.~. ~..~ ..... ;. i i ~..i.. ,., !. %~ ...' . ~ ' . ' ', '. ,'~ ,.. ;.1. ,.i..~. -i- : '. '. 1.. "-~--t ...... ; .... ~ .... ~--'+--I-~-..~ --~-~-.4.-.:.-;, - % ........... ; ........ :-.~..-: .......... : ..... ; .-i.; ....... :.--'.-' ~ .:--~ ..'~-4-;.~ ..... ~ ,._.~L_~_ .~: _; "! : '~'r'."~ ..... ~ ':' I i { %, ' ' ' ; : .' ~ I'" "~ i :'.~' "J ~ ' ' ..... i' '' ~. I ...... , , . w '. ..... ' . , ~ ~. I ~ :' "~' .~'~ .... '."'I .... :" ') ' ' ' % ' ~" :';']"I ...... : ~'' ~ : ! ~ :. ' '"' '~' ', "' ; I ' '!"t ' ; ', ~ I : ' i ' ' ~ '~ ; ' ~ .... ] ~ ..... " .~ ~ ~' ~ ~ ' , - t . ~" =.. ; I 'f ' ; . ~ , : : ~ ' · ( ' ~ , 't ' ; I : . , , , ' I . , . , , .. , ~ ~ ~ , , , ~ · , ...... ~ I , . , ' ' ~ ', : ~ ~ ' . ~ ' ' [ I ~ ~ ~ , , .i r ~ , , :' i"~ ',"~'~':; ..... '~','. ": '"',' 'i't",'~;t'~'",' .. ... r--;-..,~' "~"'!'"~'": ........ . ......i' ~ ": ..... F", ...... I 'FP' T'-~' ~ :' '"'+"~ -I"' i. 'I .... ~' I" ...... ~ ...... . , ,,. , . , , . , ; , . , , ] ~ ' ~ ~ ~ ~ ~ ] ~ '. : ' i : ~ ; '~ ~' ~ ~ ~ ~ "'~ ": ',,'~ ~ -"1"~'-~, ~ I.~...~.~ ]""~"1 ' ' ' 't" F ' ' ; , : i ; , ' ; ~ '- , ~"1 ; :.?, ~ i.I.I .;. ~ .. .... : : ' . ' . i ' , ~ : I , .I ; , ~.i. , . ' ~ ' , ~ ~ . · ~ : I ~ I ' · ' I ' i ' ' : ...... ~ · , ' · ~ ,. , , ~: ; .i..~ t ~ ~ .~ I I , . .... . ....... . ..... ;:. .... ~..~: ~-:---. ~..~ .... ..~ ~ . ; ? . ! ARCO ALASKA. INC. -PAB'3N. WELL NO: 13 PROPOSED ............ KUP ARUK .... ~!ELD.; __. N_OR T.H SLOPE.;__ _AL ASKA EASTHAN WHIPSTOCK. INC"- -- ~ ...... , .... ; .... -.. J ............ ,.. .... . ...... ,BASE' PERflAFROST~ ~ T~D~I 7i7----']'2~ ..... : .............. ; .................. :~.;:~~ - -_:-:-_:C:~- ~ :-.: ..... ;:.. ::._.::~':?'__' . .:.: ":~:-:-_:' ............. . ::. -- ..: ...... /- K0P~-- T.VD~2341 -'THD=2341 'DEp=0 .............. J ..... 3.IOP~ UGNU..SNDS ...... T. D_._248Z~_/HD 248 ..DEP 6 ..... ~000. 15 BUILD 3 DEO .... - -. . PER 100 FT, - TOP N SAK SNDS TVD=~187 THD=3217 DEP=198 . 27 ~ 3;3; K-12 TVD=3437 TMD=3508 DEP=346 39 EOC (9 5/8' CSO PT) TVD=3637 TMD=3765 DEP=507 ...... O 4000 ............................................................................... -I'q ~ AVERAGE ANGLE ........................ 42~ DEG 42 MIN R:CF~VED o ._ - . .......... APR1 6... !~86 ............. _ ,~ ] ]' . ] Alaska --K-5 ....... TVD=5517--THD=6323 DEP=2L:/'~m"':~;~ .................. ...... : .......... ~ ...... i T/ ZONE D TVD=6232 THD=7296 DEP=2901 ........ ~ .... ~ ....... T/ ZONE C TYD-6282 T~D-7364 DEP-2947 -- ; ........ ~ T/ ZONE A TVD=6387 THD=?50? DEP-3044 ................... ; ......... CNTR '~TVD=6440'THD=75?g DEP=3093 , _t ...... ~ ......... i ...... B/ KUP SNDS TVD=6492 THD=7650 DEP-314 .................. ~ .......... !.- '_]'.:..L ~.'/_ .... ...'-. .... :.TD (LOG PT) TVD=6639 TMD=7850 DEP=32' ................. I ..... I ........ I ............. I _ -:- o. :-;:.'_.::: ..... :'.~ ~ooo -' ~ooo ~ooo .. ~ooo ... ..... ' ........ SEC T ..................... ~ ............... d, ...... VERTtCAb; ............................................................... ~ _ ~ - [ ........ . ARCO Alaska, Inc./'''% Post Office Box 100360 Anchorage, AlasV, a 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Cruber ^ssociate £n§~neer d¢/t~ GRU13/L45 Enclosure If RECFIVrn_ ARCO Alas,~ ~ !nc. is ~ ~ ubsidiary of AtlanticRichfieldCompany LOCATED IN PROTRACTED SEC's 28 ~ ~TI3N, RgE,U.M. LOCATED IN PROTRACTED LOCatED SEC. 29, TI~N~ RgE~ U.M. 1 - Y " 6,013,799.67 LAT. 70~26'55.9615'' 10 - Y = 6,013,799.37 LAT. 70"26'55.9519" X - 517,946.19 LONG. 149~51'12.938" X - 518,221.07 LONG.149~51'04.865" . 454' FEL, 1562' FSL OG - 28.2 PAD - 33.7 179' FEL, 1561' FSL OG · 28.5 PAD · 34.0 2 - Y ' 6,013,799 65 LAT. 70026'55.9606" 11 - Y = 6,013,799.32 LAT. 70~26'55.9508" X = 517,971.21 LONG. 149o51'I2.203" X - .518,246.03 L~G.149~51'04.132'' 429' FEL, 1562' FSL OG · 28.2 PAD = 33.8 155' FEL, 1561' FSL OG ' 28.5 PAD · 33.8 3 - Y = 6,013,799.54 LAT. 70~26'55.9590" 12 - Y ~ 6,013,799.45 LAT. 70°26'55.9515" X = 517,996.25 LONG.149°51'll.468" - X 404' FEL, 1562' FSL OG = 28.4 PAD ~ 33.9 130' FEL, 1561' FSL OG 4 - Y = 6,013,799.50 LAT. 70~26'55.9580" 13 - Y = 6,013,799.41 LAT. 70~26'55.9505" X - 518,021.16 LONG.149~51'lO.736" X " 518,295.97 LONG. 149"51'O2.666" 379' FEL, 1562' FSL OG = 28 4 PAD = 33.7 ~ 105' FEL 1561' FSL ~ ' 28 5 PAD - 34.1 5 - Y = 6,013,799.~ LAT. 70026'55.9572" .~ 14 - Y - 6,013,799.33 LAT. 70~26'55.9491" X = 518,046.18 LONG. 149~51' 10.002" ~ X = 518,320.91 L~G. 149~51 '01. 934" 354' FEL, 1562' FSL OG = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL ~ ' 28.5 PAD · 34.0 , ~ ~ 55' FEL, 1561' FSL OG ' 28.5 PAD - 34.0 7 - Y = 6,013,799.44 LAT. 70~26'55.9556" o 16 - Y = 6,013.799.25 LAT. 70~26'55.9471" X = 518,096.21 . LONG. 149°51'08. 533" ~ O ~ ~ X = 518,370.74 LONG. 149"51'00. 470" 304' FEL, 1561' FSL 0G = 28.5 PAD = 33.9 U ~ ~ ~ 30' FEL, 1561' FSL 0G = 28.5 PAD - 34.1 8 - Y = 6,013,799.45 LAT. 70°26'55.9551" ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70~26'55.9466" X = 518,121.15 LONG. 149°51'07.800'' X = 518,395.63 LONG. 149'50' 59. 739" 279' FEL, 1561' FSL 0G = 28.6 PAD : 33.9 ~ ~ ~ 5' FEL, 1561' FSL 0G = 28.5 PAD = 34.1 9 - y = 6,013,799.42 LAT. 70~26'55.9542" X = 518,146.15 LONG.149o51'07.066" c) SEC. 28,TI3N, R9E, U.M. 254' FEL, 1561' FSL OG = 28.6 PAD = 34.0 ~ 18 - Y : 6,013,799.15 LAT. 70~26'55.9449" X : 518,420.80 LONG. 149~50'59.000'' NOTES 20' FWL, 1561' FSL 0G = 28.5 PAD I. ALL COORDINATES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE'TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD B ASSOC. 4. VERTICAL POSI.TIONS BASED ON MODULE PILES 3JOl-B ~ )JCl-4. 5. O.G. ELEVATIONS INTERPOLATED FROU S/C DRAWING CED-RIXX-3090 rev.~. , . ~EG~STERED ~ND LICENSED TO PRACTICE L~ND ~ ~ -- ~ m 8). (3) Admin (5) BOPE ~ · · (23 thru 28) (29 thru 31) ,da: Geology: ~g~n~g: J~ rev~ 04/03/86 2 IS.well to be located in defined pool 3. Is well located.proper distance £rom property line .................. 4. Is we~ located proper distance from other wells .................... $. Is sufiicient undedicated acreage available in this pool ............ 6. Is well to :~e deviated and is wellbore plat included ................ 7 Is operatorthe only affected party · eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 8 .Can permit.'-be approved before ten-day wait · eeeeeeeeeeeeeee·eeeeeeeee· · 10. 11. 12 Does operatorhave a bond in force Is a conservation order needed ...................................... 'Is administrative approval needed Is the lease number aPpropriate ......................... Does the well have a unique name and 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ ~ Will surface casing protect fresh water zones ....................... ~ Is enough cement used to circulate on conductor and surface ......... /l~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ................... :. Will all casing give adequate safety in collapse, tension and burst.. /~ Is this well to be kicked off from an existing wellbore ............. ' Is old wellbore abandonment procedure included on' 10-403 ............ Is adequate wellbore separation proposed ............................ .~ 23. 24. 25. 26. 27. 28. Is a diverter system required eeeeeoeeeeeeeeeeoee®eo·eeo®eeeee®ee®eee Is the drilling fluid program~schematic and list of equipment adequate z~L.' Are necessary diagrams and descriptions of diverter and BOPE attached.~ Does BOPE have sufficient pressure rating - Test to~_~_~_~_psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H25 gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. . POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. /l/b ON/OFF SHORE O ~O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically" ;. · .o organize this category of information. LIS TAO~ V~RIFIC~T'ION LISTIN'3 MlCl O LVo S!O.HO2 VERI~ICATi~DN LiSTIN.S oASE I SERVICE NAME :EDIT DATE JRISIN : REEL N~HE :1~930~ CONTINUATiSN m :01 PREViSUS COMMENTS :LIBRARY TAPE SERVICE NA~E :EDIT DATE ORISiN :0000 TAPE NAME :1441 CONTINUATION ~ :01 PRE~IOUS T~PE COMMENTS :LibRARY TAPE FILE N~ME :EDIT SERVICE NAME : VERSION ~ DATE : MAXIMUM L~NGTH : FILE TYPE : PREVIOUS ~ILE : · 00,1 1024 MNEM CONTENTS CN : ARCO ALaSKa, WN : 3N-13 FN : KUOARUK RANg: 9f TOWN: SECT: 29 COON: NORTH SLOP~ STAT: ALASKA CTRY: USA MNEM CONTENTS PR:.S: INS · I I I ! UN IT 000 000 000 000 000 OOO 000 000 TY ~f 000 C~T~ 000 O00 000 000 000 000 000 CAT~ 0 0 '0 SIZE I I ! I 0!$ O06 O08 002 00¢ 002 O 12 006 O0 1 CODE 0,55 065 065 065 065 065 055 0,5:5 065 CODE ~II 065 LV? 010.~0£ V~I~CaTICN LiSTINJ PAG~ 2 ALASKA COMPUTINg C~T-~ .,..~ .~..,..,. ~ :',: .,..~ ,,..,. ~. ~..,. ~..,- .~ -, ..... ,..,..~ .,..,. ~. -~ ~..,..,..~. ~ ..... ~ -,- ~ ...,..,. ,~ .,..,. C~MPANY = &RC2 AL&SKA WELL = 3N-13 FIr-LO = ~UP&RUK C~UNTY = NORTH SLSP~ 50ROJGH STATE : JO5 NUMBER AT ACC: RUN ~1, DATE LOGGED: LOP: RICK KRUWELL CASING TYPE FLUID DENSITY VISCOSITY PH FLJID LOSS MATRIX SANDSTON~ ...... ~ = 9.525" ~ 3774' - 8IT SIZE : 8.5" T!] 7845' : LSNS = 9.9 LB/G RM : 4,43 @ 56 De : 40 S ~F : 4.45 ~ 56 O~ -: 9.5 R~C : 4.15 @ 58 OF = ~.2 C3 RM AT 5HT = 1,9~3 ~ 139 Om THIS DATA HAS NOT qEEq~ DEmTH SHZF'T;D -OVSR~LAYS FIELD PRINTS _VP OlO.HO2 VS~IFiC~T!~3~q LISTiNi DA$5 3 SCHLU~SER'gER LOGS INrLUDCD.. -~. WITH T~iIS .h!~GNZTiC T~P~'. · DUAL iNDU~TiDN SPHERICALLY FSCUSED LOG (DIL) DATA AVAILAbLe: 7~35' TO 3773' ~ORMATiO~ D~NSiTY~ CO~D~NSAT~D~ . LOG (:~N)~ CDMPENSATED N~UTRDN LOG (FDN) 'X: DATA AVaiLABLE: 7810' TO 5800' ~:~ GAM~A RAY IN CASING (SR.CSG) DAT~ AVAILABLE: 3~0~' T~D !955' · ,--,- DAT~ EORMAT RECORD. ENTRY BLOCKS TYP~2 SiZE RED!~ CODE ~NTRY ~ 1 66 i S ~ 73 60 15 i 65 i D 1 66 0 )ATUM SPECTFiC'ATiJN 4NF-_',I SERVICE 3~RViC5 ID ORDER 3EPT 7855,5000 SFLJ SP -15.7324 GR RHOB 2.5803 3RH3 NP~I 36.8552 NCNL OEPT 7800.0000 SFLO SP -16.7920 GR RHDB 2.5567 ORH3 NPHI 38.3789 NCNL DEPT 7700°0000 SFLd SP -23.2295 GR RHOB 2.4512 DRHO NPHi 41.5527 NCNL DEPT 7500.0000 SFLO SP -26.2754 SR RHOB 2.3127 DR~3 NPHI 32,.0801 NCNL OEPT 7500.0000 SFLJ SP -25.7920 GR RH35 2,3987 DRHJ NPHI 32.3242 NCNL OEPT 7400.0000 S?LU SP -3~.3008 3R RH05 2.~92~ ORH3 NPHI 3.2.3242 NCNL APl AP1 AOl AP! LOG TYP5 CLASS 03 OOO O0 0 30 220 O1 O0 1ZO 45 O O0 IlO 44 O0 OlO O1 C O0 310 O1 O0 310 Ol 0 JO 2~0 Ol O O0 350 02 0 O0 ~56 Oi 0 O0 42O O1 3 O0 000 O0 O. 90 390 09 0 O0 330 3i O O0 330 30 0 O0 310 O1 0 4.8054 iLD 108.9023 GR 0.3485 NRAT 1739.6875 FCNL '3.16&3 IL3 192.8398 GR 0.2383 NR&T 1798.6875 FCNL 2.7307 ILO 97,2'773 GR 0.1113 NR~T 1819.61375 FCNL 25.4424 ILD 55.27'73 gR 0.0327 NRAT 2277,5000 FCNL !0.9395 ILO 72.4023 GR 0.0093 NR4T 2219,5000 FCNL 3.1~09 ILO 117.4023 1954.5875 FCNL FILE 0 0 0 0 0 O 0 0 0 O 0 0 0 SiZ~ SOL 4 1 55 4 ! 55 4 1 6:~ ~ ! 55 4 I 6:3 4 ! 4 i 4 i 4 1 4 1 63 4 I 63 4 ! 4 1 58 4 1 4 ! 53 2.8127 ILM 103.9023 CALZ 3.1545 RNR~ 511.6¢06 GR 2.9807 iLM 102.8398 CALl 3.2913 RNR& 512-8125 gR 2.7366 iLM 97.2773 CALl 3.4045 RNRA 516,3125 GR 17.8018 ILM 55.2773 CALl 2.9221 RNR~ 707.3125 GR 9.5035 ILM '72.4023 'ALI 2.9475 RNRA 717.9125 GR 4.3054 ILM 117.4023 CALl 2,9846 RNRA ,~,~'~.6. 3125 SR (3CTAL) 00000009000000 00000000000000 00000000000000 00000000000000 00000000000000 09003003000000 OOOOO000OO0000 00000000000300 00000000000000 OOOO0000000000 00000300000000 OOOgOO00000OO0 00000000000000 00000000000000 00000000000000 O0000000000000 4.3:171 8.5020 3.3987 -999.2500 3.0413 9.1504 3.508.1 -999.2500 2.7932 8.4316 3,5237 -999.2500 1'7.8174 9.0098 3.2190 -999.2500 - 99 9,3691 9.12'70 3.0901 9.2500 3.9905 9.5723 3.1721 9.2500 DEnT 7300 O00O SFLJ ~ 0588 ='" ~ ..... ~=J 1.8582 ,:LM 1.9171 SP 3EPT SP 3E,~T SP RH35 NPq! 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