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Home My WebLink About189-088XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I ~ q "0~g File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~Bren Vincent Nathan Lowell [] TO RE-SCAN Date'S' fi 'O~'s/ ~ Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd tm - o--e 2 -\ t3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 7, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Correlation Log: 2K -14 SCANNED MAR 2 7 2,013 Run Date: 6/6/2012 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 2K -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20112 -00 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.wood@halliburton.com Date: koia Signed: Kit (4 Rrt ,gq -oss Regg, James B (DOA) To: Brooks, Phoebe L (DOA) Subject: RE: Notice of BOPE usage on 2K -14 (PTD# 189 -088) (Sundry# 312 - 129)... Thanks. Yes, these should be coming to me as well. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 ,.. 3 U1Z 907 -793 -1236 JUL d From: Brooks, Phoebe L (DOA) Sent: Monday, June 04, 2012 9:54 AM To: Regg, James B (DOA) Subject: FW: Notice of BOPE usage on 2K -14 (PTD# 189 -088) (Sundry# 312 - 129)... Hi Jim, I wasn't sure if you needed to be Cc'd on this too. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 -276 -7542 From: Ferguson, Victoria L (DOA) Sent: Monday, June 04, 2012 9:17 AM To: Brooks, Phoebe L (DOA) • Subject: FW: Notice of BOPE usage on 2K -14 (PTD# 189 -088) (Sundry# 312 - 129)... From: Nelson, Erik Q [mailto:Erik.Nelson @conocophillips.com] Sent: Tuesday, May 29, 2012 3:40 PM To: Ferguson, Victoria L (DOA) Cc: Gober, Howard Subject: Notice of BOPE usage on 2K -14 (PTD# 189 -088) (Sundry# 312 - 129)... Ms. Ferguson, As per AOGCC Industry Guidance Bulletin No. 10 -003, I am following up my verbal notification of BOPE usage on Doyon 141 with a written report. Date, Time of BOPE Use: 29 May 2012 at — 0815 and — 1200 hrs Well Location / API# / PTD #: 2K -14 Kuparuk River Unit (Sundry # if applicable) API# - 50- 103- 20112 -00 PTD# - 189 -088 V Sundry# - 312 -129 1 • S 'Rig Name: Doyon 141 Operator Contact: Erik Nelson 907 - 263 -4693 - Erik .Nelson(c�conocophillips.com Operations Summary: The rig was tied into the polish bore receptacle with a spear and was attempting to fish the upper selective from the well. While circulating 9.8 lb /gal brine it was noted that we had crude oil and a slight amount of gas in the returns. Pumping operations were shutdown and a small amount of flow was observed coming from the well. At 0815 hrs the annular was closed to divert flow to the choke line. BOPE Used: Annular and choke manifold valves 3, 5, and 6. Reason for BOPE Use: Control flow of fluids from the wellbore due to reservoir differential. Actions Taken / To Be Taken: The rig crew circulated and weighted the brine system up to 9.9 lb /gal brine down the drill pipe taking returns from the annulus until returns were clean. The annular was opened to observe the well for flow. It was noted there was still some flow from the well so the annular was closed again — 1200 hrs and the system was circulated and weighted up to 10.0 lb /gal. After getting 10.0 lb /gal circulated around the annular will be opened once again in order to monitor the well to confirm it is static. The drill pipe will then be tripped out of the well. Once on surface, we will set a test plug and test the BOPE components that were utilized before continuing operations. , Let me know if you have any comments and /or questions. Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 2 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record /Radial Cutting Torch: 2K -14 Run Date: 5/30/2012 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 2K -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20112 -00 ' AUG (1 3 niz 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.wood @halliburton.com Date: 1 t Signed: lZ� 67' 21.0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 2K -14 Run Date: 5/25/2012 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 2K -14 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20112 -00 ..I; AU6 U 3 me: 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.wood@halliburton.com Date: — 1 v 1(11— Signed: ' i f l�, • \<(;°I-O" (:)/0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool /Plug Setting Record/Radial Cement Bond Log: 2K -14 Run Date: 5/21/2012 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 2K -14 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20112 -00 Radial Cement Bond Log 1 Color Log 50 -103- 20112 -00 20041) AUG -`` 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.wood@halliburton.com Date: C-7 \ Signed: M ' _ . I1 n9.- DNO WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 21, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 2K -14 Run Date: 5/19/2012 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 2K -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20112 -00 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.wood @halliburton.com Date: 7141-- Signed: i.� �i� i� Z∎ SCZ. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2K -14 Run Date: 5/7/2012 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 2K -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20112 -00 54,ANNEDJUN 2, 0 LUIZ 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.wood @halliburton.com Date: ( i Signed: r'49 -aZS`S • • 2►sS l WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 2, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 1 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Cement Bond Log: 2K -14 Run Date: 5/1/2012 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 2K -14 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 103 - 20112 -00 Cement Bond Log 1 Color Log 50- 103 - 20112 -00 5UOINED JUN S 0 LOI2 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.wood @halliburton.com Date: Signed: 0 ai74 I��Lt Z IL - 14 Pry 65o 6So Regg, James B DOA 99� (DOA) From: Schwartz, Guy L (DOA) : Wednesday, May 16, 2012 11:09 AM Sen t y, y , To: Regg, James B (DOA) Subject: FW: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Guy Schwartz P S Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Nelson, Erik Q [mailto: Erik. NelsonOconocophillips.com] Sent: Wednesday, April 25, 2012 6:51 PM To: Schwartz, Guy L (DOA) Subject: RE: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Guy, SLANNED . � . 1 2012 1 was reminded by Howard today that at this point in the procedure we'll have allowed the 7" csg to grow and have it landed on slips thus we'll be testing against the 9 -5/8" csg. The most pressure the 9 -5/8" has seen previously is a passing MIT -OA last September. As you know our MIT -OA standard test pressure is 1800 psi. What I've written up in my procedure is that after we NU the BOPE we'll test the break to 250/1500 psi. At this point I have a plug in my tailpipe isolating me from the A -sand and a competent selective isolating me from the C -sand. I've also got a positive pressure test on an RBP set — 500 ft below TOC. After I've removed the 7" csg I'll be changing the lower rams out of the BOPE from 7" to VBRs. At this point I'll return to the 250/3000 psi PT against a test plug to verify the rams are good. Again I would like to get your acknowledgment of this. Let me know if you have any questions and /or comments. Thank you in advance for your assistance. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@ alaska.gov] Sent: Friday, April 20, 2012 8:27 PM To: Nelson, Erik Q Subject: [EXTERNAL]Re: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... 1 • • Erik, My oversight ... 3000 psi approved for BOP test against lower casing flange. Guy Sent from my iPhone On Apr 20, 2012, at 8:14 PM, "Nelson, Erik Q" < Erik.Nelson @conocophillips.com> wrote: Guy, I notice you noted a 3500 psi BOPE test requirement on your Sundry Approval. As noted in my procedure outline once we move towards removal of the damaged 7" casing string we will be nippled up to the 11" 3M csg head and thus will only be able to test to 3000 psi. All of our other BOPE tests will be to 3500 psi as directed. This is normal for our subsidence -type RWOs but I wanted to get your acknowledgment of this situation so our rig supervisors can have this e-mail handy if there are any questions from the AOGCC inspectors if they choose to witness the tests. Thanks in advance for your help. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #1590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 2 • Page 1 of 2 • Schwartz, Guy L (DOA) From: Nelson, Erik Q [Erik.Nelson @conocophillips.com] Sent: Tuesday, May 15, 2012 3:25 PM To: Schwartz, Guy L (DOA) Subject: 2K -14 (PTD #189 -088) (Sundry #312 -129) cement info... Guy, We have two cement operations on 2K -14: 1st is to cement the 7" x 9 -518" annulus above previous TOC in the same annulus - Typical properties of Arctic Set 1 - Cmt Req'd: 15.7 ppg ArcticSet 1 0.93 ft3lsk 5100AMED ' 2012 Estimated existing TOC = 2300 ft MD 72 bbl volume 1. Cmt Pump Schedule (exact volumes will be adjusted according to actual TOC): a. 5 bbls freshwater b. 69 bbls neat 15.7 lb /gal ArcticSet) c. Launch closing plug d. Displace w/ 3 bbl neat 15.7 lb /gal ArcticSet) e. 5 bbls freshwater f. XX bbls heated seawater (- 90° F) to bump plug NOTE: If milling was performed for clearance in the 9 -5/8" csg and resulted in holes in the 9 -5/8" csg then we need to include CemNET in the slurry. 2nd cement operation is to cement in the 4 -1/2" scab liner - Assuming we get cleaned out down to PBTD (8063' MD) 1. Spot and RU SLB cmt equipment. PT all lines to 4000 psi. Cmt Req'd: 15.8 ppg Class G w/ D600G 1.16 ft /sk 15 bbl volume 2. Hold PJSM to discuss cmt pumping operations. 3. Circulate at 5 bpm to condition fluids. Record PU and SO weights, reciprocate as needed. NOTE: Do not exceed 1000 psi circulating pressure w/ out consulting on -site Baker rep. 4. Pump cmt as per SLB pumping supervisor. 5. Clear lines of cmt to insure no cmt is on top of DP wiper plug. Drop the DP wiper plug and continue w/ displacement w/ 9.1 lb /gal brine utilizing SLB cmt pump. 6. Prior to plug bump stop reciprocating and place pkr element of lnr top pkr at - 7550' MD. Bump plugs and pressure up to 3500 psi. SO lnr weight plus 50K lbs to insure hgr is set. Bleed off DP pressure to 0 psi in order to check floats. 5/15/2012 • Page 2 of 2 7. Rotate - 12 turns to the right (at the tool) to release from the Inr. I'm hoping this is what you were looking for. Let me know if you want to discuss further. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 5/15/2012 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 26, 2012 9:34 AM To: 'Nelson, Erik Q' Subject: RE: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Erik, I get it now.. you will be testing against the 7" X 9 5/8" OA with an open shoe. 1500 psi is adequate to check the flange break. You are isolated from the reservoir with multiple barriers as outlined below. Make sure the rig has a copy of this email chain in case the inspectors have questions. Step #4 under 7" Csg Replacement will read Test break to 250/1500 psi Regards, Guy Schwartz 6 a Senior Petroleum Engineer MAC' 2 3 Z AOGCC 793 -1226 (office) 444 -3433 (cell) From: Nelson, Erik Q [ mailto: Erik.Nelson @conocophillips.com] Sent: Wednesday, April 25, 2012 6:51 PM To: Schwartz, Guy L (DOA) Subject: RE: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Guy, I was reminded by Howard today that at this point in the procedure we'll have allowed the 7" csg to grow and have it landed on slips thus we'll be testing against the 9 -5/8" csg. The most pressure the 9- 5/8" has seen previously is a passing MIT -OA last September. As you know our MIT -OA standard test pressure is 1800 psi. What I've written up in my procedure is that after we NU the BOPE we'll test the break to 250/1500 psi. At this point I have a plug in my tailpipe isolating me from the A -sand and a competent selective isolating me from the C -sand. I've also got a positive pressure test on an RBP set 500 ft below TOC. After I've removed the 7" csg 111 be changing the lower rams out of the BOPE from 7" to VBRs. At this point I'll return to the 250/3000 psi PT against a test plug to verify the rams are good. Again I would like to get your acknowledgment of this. Let me know if you have any questions and /or comments. Thank you in advance for your assistance. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #1590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - 1535 Cell (907) 903 - 7407 • • 4/26/2012 • Page 2 of 2 • From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, April 20, 2012 8:27 PM To: Nelson, Erik Q Subject: [EXTERNAL]Re: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Erik, My oversight ... 3000 psi approved for BOP test against lower casing flange. Guy Sent from my iPhone On Apr 20, 2012, at 8:14 PM, "Nelson, Erik Q" < Erik.Nelson@conocophillips.com> wrote: Guy, I notice you noted a 3500 psi BOPE test requirement on your Sundry Approval. As noted in my procedure outline once we move towards removal of the damaged 7" casing string we will be nippled up to the 11" 3M csg head and thus will only be able to test to 3000 psi. All of our other BOPE tests will be to 3500 psi as directed. This is normal for our subsidence -type RWOs but I wanted to get your acknowledgment of this situation so our rig supervisors can have this e-mail handy if there are any questions from the AOGCC inspectors if they choose to witness the tests. Thanks in advance for your help. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 4/26/2012 . .. . - um • p a N. v_ ,- 3 „8-50,',0 ,8-35) r ;;'Tv�- i S`t� D +( 0i =111 - - -- AICi La IL -, 1 IC I .( 7 17/6 /5-45) non g 101 - i ' - 1 ®1 MS I _ III 1M I. 1L4II �u / � al 'um ll' _ 4111 0111°- ■ ' 41. rill INI 1 (iii ill : A ■ • CI I al I / • � L -3007 15 -53) 4' �L 1 L 1165 L' ff L 9�5 a I C ' I a s � I; i I S. 1 • ihr �tf 1 1 ' ill � r..,40,/ ,,, , 1 , , , NI . ; , , ,,, I j_ i 4-1- 1 ' - i i ,, 1 ,, , f ,) 7 I 3.20 ■ 5.21 Z , r . v� DIVERT ER HEAD '9 -109 -23: f I 1 �‘ o' CD l 2 -9 5/8 OD C79 ` - 7" OD CSG I ` 3 1/2 - 785 ARCO ALASKA INC. ( KUPARUK ]FIELD' 17E311 PART 14138ER II DESCRIPTION I 7 13 1 4 0 -60C LANDING SING, 16' S.J. LET I2-130 -379 SA53 Hf.N13FR —9- 0 — 3 13- 3C3--i4■A CA011N0 HD 4331 C -29 II 3/4'6 CSO X _ 0 II -31: A/ 2 I'16 -3K ST03 63T O 4 12- 090 -177 SLIP 937.1. ADDY, II >. T - REF: H _ 5 33- 600 -627A 056■113 HD AS01. TC'A -ET, 3' BR 0 11-38 5 7 1/16-58 64 2 1 -54 037'0 6 83-160 -321 REDLCER 6538100 ASS6 9 X 7 S2 - -2'.6 84IIGE8 TC IA -EN. i 1/ 16 x 3 1 FUE. �> A VI EELHE ND SYSTEM. "" v im _. I 0 O 8 32 -01 634 ADAPTER, A -a,T I /I5 -51. X 3 lit; --5h YJ/ C UIY, e I V K IPAR'L.I� I v B71/ PREP F/ 5.495 E5 `L'CK R13 _ . 3 12-140 -:12 P148OFF A -70.11 x 7 EOJ r> I I:�IEI� t,„7,7!, 3 -19 -9 `n.... a. -.. : "� ce re s 0000 1490,2643 Page 1 of 2 • • Schwartz, Guy L (DOA) From: Nelson, Erik Q [ Erik.Nelson @conocophillips.com] Sent: Wednesday, April 25, 2012 6:51 PM To: Schwartz, Guy L (DOA) Subject: RE: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Guy, I was reminded by Howard today that at this point in the procedure we'll have allowed the 7 csg to grow and have it landed on slips thus we'll be testing against the 9 -5/8" csg. The most pressure the 9- 5/8" has seen previously is a passing MIT -OA last September. As you know our MIT -OA standard test pressure is 1800 psi. What I've written up in my procedure is that after we NU the BOPE we'll test the break to 250/1500 psi. At this point I have a plug in my tailpipe isolating me from the A -sand and a competent selective isolating me from the C -sand. I've also got a positive pressure test on an RBP set 500 ft below TOC. After I've removed the 7" csg I'll be changing the lower rams out of the BOPE from 7" to VBRs. At this point I'll return to the 250/3000 psi PT against a test plug to verify the rams are good. Again I would like to get your acknowledgment of this. Let me know if you have any questions and /or comments. Thank you in advance for your assistance. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 MAY 2 j die Fax (907) 265 - I535 Cell (907) 903 - 7407 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, April 20, 2012 8:27 PM To: Nelson, Erik Q Subject: [EXTERNAL]Re: 2K -14 PTD# 189 -088 Referencing Approved Sundry #312 - 129... Erik, My oversight ... 3000 psi approved for BOP test against lower casing flange. Guy Sent from my iPhone On Apr 20, 2012, at 8:14 PM, "Nelson, Erik Q" <Erik.Nelson a conocophillips.com> wrote: Guy, 5/16/2012 Page 2 of 2 • • I notice you noted a 3500 psi BOPE test requirement on your Sundry Approval. As noted in my procedure outline once we move towards removal of the damaged 7" casing string we will be nippled up to the 11" 3M csg head and thus will only be able to test to 3000 psi. All of our other BOPE tests will be to 3500 psi as directed. This is normal for our subsidence -type RWOs but 1 wanted to get your acknowledgment of this situation so our rig supervisors can have this e-mail handy if there are any questions from the AOGCC inspectors if they choose to witness the tests. Thanks in advance for your help. Q Erik Q. Nelson Workover /Wells Engineer ConocoPhillips Alaska, Inc. Office #I590 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Fax (907) 265 - I535 Cell (907) 903 - 7407 5/16/2012 4110 IP k‘ 9 - 2Y WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 17, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED ElAR 2 7 2U13 RE: Radial Cutting Torch Record: 2K -14 Run Date: 4/13/2012 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 2K -14 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20112 -00 SCANNED MAR 2 7 Z013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:' _ M Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 5 / z i 71 Signed: UR,' 1 • • 4 , r� As 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 Erik Nelson Welts Engineer ConocoPhillips Alaska, Inc. Q d 0 L P.O. Box 100360 0 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -14 Sundry Number: 312 -129 Dear Mr. Nelson: NOE APR a 20 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, T _‘,1c L Cathy . Foerster Chair DATED this /D day of April, 2012. Encl. • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 3/23/2012 0- . 9 - //0 6/ OF ALASKA + \ A OIL AND GAS CONSERVATION COMMI N E ! 1/ ED AP FOR SUNDRY APPR 17 20 AAC 25.280 P 0 1. Type of Request: Abandon r Plug for Redrill P • Perforate New Pool r Repair well rAleskaCeEtrggw@r Pr Sion Suspend r R Perforations rforations r Perforate r Pull Tubing r• rT Tp,F tension r Operational Shutdown R - enter Sus Well OP p St imulate r Alter casing O ther: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r 189 -088 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20112 -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 W 2K -14 - - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25588 • 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): 8202 6608 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 3138 9.625 3173' 2935' PRODUCTION 8117 7 8147' 6560' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7682'- 7696', 7761' -7801' 6174'- 6185', 6236 3.5 J - 7764 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB RETRIEVABLE PACKER MD= 7653 TVD= 6152 PACKER - BAKER FB -1 PERMANENT PACKER MD= 7734 TVD= 6215 SSSV - CAMCO TRDP -1A -SSA MD =1797 TVD =1791 12. Attachments: Description Surrmary of Proposal I✓ 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/18/2012 Oil r Gas r WDSPL r Suspended Sri • 16. Verbal Approval: Date: WIND r 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: Erik Nelson © 263 -4693 Printed Name Erik Nelson Title: Wells Engineer Signature / Phone: 263 -4693 Date /4,-- zel Commission Use Only Sundry Number:51 Z-- 11, Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test ey Mechanical Integrity Test .r Location Clearance r Other: Subsequent Form Required: / 0 _ LI f O 7 APPROVED BY Approved by: 4C.--4.6.4------ COMMISSIONER THE COMMISSION Date: - -/D - l --z__- Form 10 -403 Reviled d 1/2010 � mit in 1.Z,./2_ R N DMS APR . 1 1' /` � 4 07,2/ a t • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 30 March 2012 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2K -14 (PTD 189 -088). Well 2K -14 was drilled October 1989 and completed as a producer in April 1990. 2K -14 currently has significant tubing damage in the 700 -800' measured depth (MD) interval which is thought to be subsidence related. In addition this well is scheduled for Coiled Tubing Drilling (CTD) / development and requires changes to the existing completion in order for that to occur. The purpose of this workover is to remove the existing completion, inspect and possibly repair the 7" production casing, and install a 4 - %" scab liner in order to facilitate future CTD development. This 4- liner will be cemented in place effectively isolating both the A- and C -sands and a 3 -'/" gas lift completion will then be run to surface. ��► � �( 4 If you have any questions or require any further information, please contact me at 263-4693. �Y Regards, rik Q. on' Wells Engineer CPAI Drilling and Wells • • 2K -14 Capital Rig Workover PTD #: 189 -088 Current Status 2K -14 is currently on production awaiting pre -RWO well work. Scope of Work ♦ Cut and pull 3 -W J -55 tbg above Baker HB retrievable pkr (7653' MD) ♦ Run 7" csg scraper to TOP and evaluate 7" csg condition and perform 7" csg repair if necessary ♦ Pull remaining completion to Baker FB -1 permanent pkr (7734' MD) if 7" csg condition allows ♦ Mill and retrieve Baker FB -1 pkr (7734' MD) and remaining tailpipe assembly ♦ C /out run through A -sand perfs ♦ MU and TIH to set and cement 4 -W scab lnr assembly w/ lnr hgr and lnr top pkr ♦ MU and TIH w/ new 3 -Y" L -80 GL completion to surface General Well info MASP: 2178 psi Reservoir pressure/TVD: 2800 psi / 6219' TVD Using SBHP measured on 24 February 2012 of 2304 psi at 7780' MD (6251' TVD) and 2264 psi at 7669' MD (6164' TVD) gives a pressure gradient of 0.46 psi /ft. Mid -perf between A- & C -sands is -7740' MD (6219' TVD). This equals a measured SBHP of -2289 psi at mid -perf. However; this was measured after a SI period of only 5 days so we are going to utilize a modeled SBHP for planning purposes. This represents a SBHP after a longer SI period and gives us -2800 psi SBHP. Wellhead type /pressure rating: FMC Gen IV / 7- 1/16" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: TIFL passed 02 July 2005 MIT -IA passed 25 December 2008 MIT -OA passed 16 September 2011 Well Type: Producer ConCtir, eofi 44) arm I ©Q Estimated Start Date: 18 April 2012 PredvC S 00®- fqr pe�r� Production Engineer: Chris Ruff bee" (eyy Rv0 e'�►�� 60., AGra. Development Engineer: Drew Huck fr �� /l� WI i-`6' RWO En 7 Ge GI N e Engineer: Erik Q. Nels �° K 'T g f 7 l �l i�` Work: 263 - 4693 u(d /or her Cell: 903 - 7407 r feeti v 'i ink rate �k � to E -Mail: Erik.Nelson @conocophillips.com fr ��' J we lt for CV V NO could be- „t ro rtoi M Q Q n7' d i " rr /�% I V ! + Z-' • • Proposed RWO Procedure: Pre -Rip Well Work 1. S/I well and allow for 5 days pressure buildup MIRU HES SL 1. Insure Camco TRDP -1A SSSV is mechanically locked in the "open" position 2. Obtain updated SBHP data w/ Panex gauges run to tbg tail (7764' MD) w/ gradient stop at 7637' MD 3. MU and RIH w/ plug for 2.813" XN (2.750" No -Go) nipple profile (7752' MD) 4. RIH w/ catcher sub and set on top of plug 5. Dummy off GLM #s 1 - 3 and pull OV from GLM #4 and leave open 6. Drift tbg to catcher sub w/ dummy RCT gun assembly as specified by HES E -Line supervisors MIRU HES E -Line 1. MU and RIH w/ RCT assembly setup for 3 -%2' 9.3# tbg a. Cut tbg at -7624' MD (mid jt in 1 full jt above PBR) 2. PT tbg and csg packoffs and FT LDSs 3. Set FMC Type 'ISA' BPV ✓ RU,Test, Pull Tbg, and Evaluate 7" Csg 1. MIRU Doyon 141. Accept Rig, take on fluids, pull FMC Type 'ISA' BPV, circulate and bullhead KWF,.. and insure well is dead. 2. Install FMC Type 'ISA' BPV, ND tree, NU 13 -5/8" 5M BOPE, install blanking plug, function and PT BDPE..ta..'5013500_psi and .annula r„to., 250/350Q psi. i. 3. Pull blanking plug & FMC Type 'ISA' BPV. Screw in landing jt, BOLDS's, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/ 3- J -55 EUE -Mod IPC tbg. 5. MU and TIH w/ csg scraper and "pulled pkr" drift assembly on 4" XT -39 DP. RU HES E -Line for . Memory Caliper w/ Gyro log. a. If BHA drifts to the top of Baker HB pkr then proceed to "Pulling Selective Completion" b. If BHA does not drift then TOOH and proceed w/ 7" csg replacement 7" Csg Replacement 1. RU HES E -Line for CAST -M (or RCBL) and string shot runs. RDMO HES E -Line. f / 2. MU and TIH w/ RBP or IBP and set below TOC. PT to 3000 psi and draw down test same. Dump sand on top of plug. 3. ND 13 -5/8" BOPE and tbg head. Spear and re -land 7" csg in tension. Cut off 7" csg "growth ". NU 13 -5/8" 5M BOPE on 11" 3M csg head. 4. ]t break to 250/3000 psi. 5. Cut 7" csg with multi- string cutter on drill pipe above TOC. Circ 9 -5/8" x 7" annulus clean. 6. Spear and TOOH laying down 7" csg. 7. Run 9 -5/8" csg scraper to top of 7" stub. Circ clean. 8. RU HES E -line and run gyro w/ GR and memory caliper log. RDMO E -line. 9. Run tandem string mill assembly to gauge csg for installation of new 7" csg string. Make dummy run for 7" csg and Halliburton ES cementer. 10. TIH w/ back off tool and back off csg stub. TOOH. 11. TIH w/ spear and recover csg stub. TOOH. 12. C /out lower BOP ram to 7" and test ram to 250/3500 psi. 13. TIH with new 7" csg and Halliburton ES cementer. Screw into top of 7" csg. Pressure test csg to 3000 psi. 14. Open ES cementer and pump cement (calculated plus - 25% excess) into 9 -5/8" x 7" annulus. After obtaining cement circulation to surface close cementer. / 15. WOC. ND BOPE and land 7" on slips. Cut 7" csg and install packoff. NU tbg head. 16. NU 13 -5/8" 5M BOPE and test break to 250/3500 psi. // 17. Drill out cement and plug. Pressure test csg to 2500 psi. TOOH. ---� C L 4 ((`' - 18. TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH. • • . 19. TIH with wash shoe and circulate out sand on top of RBP. TOOH. TIH w/ retrieving tool. Release RBP /IBP and TOOH. Pulling Selective Completion 20. MU and TIH w/ Fishing Assembly w/ Overshot for 3 - %" tbg stub in Baker PBR. Locate and overshot tbg stub. TOOH w/ tbg stub. 21. MU and TIH w/ PBR Retrieving Assembly. TIH to retrieve selective completion above Baker FB -1 pkr. TOOH and lay down same. 22. MU and TIH w/ Baker FB -1 pkr Mill /Retrieve Assembly. Mill up and Retrieve Baker FB -1 pkr. TOOH and lay down same. Running 4 - Scab Lnr and 3 -%" GL Completion 23. MU and TIH w/ 7" Csg Scraper w/ RCJB. Cleanout to PBTD and TOOH. 24. TIH with new 4 -%2' scab Inr, Inr hgr, and Inr top pkr w/ seal assembly. Cmt Inr in place w/ pkr -7550 ft MD. 25. Set Inr top pkr and unsting from seal assembly. Circulate out green cement at max rate. 26. TOOH sideways w/ setting tool. 27. TIH with new 3 - %" L -80 GL completion. Load tbg and IA with diesel. tab al assembly into seal bore and space out. PT tbg and IA to 2500 psi. �r ' c sd . ( 5 `' 28. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 29. Pull 2 -way check. Freeze protect well. Set FMC Type 'ISA' BPV. 30. RDMO Doyon 141. Post -Rig Work: 1. Handover to Ops to wait on Nabors CDR -2AC for CTD sidetrack. / • KUP • 2K -14 Conoc il Well Attributes Max Angle & MD TD A;.15 a Inc Wellbore API /IJWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (1D(B) 501032011200 KUPARUK RIVER UNIT PROD 47.90 , 6,950.00 8,202.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date - -- SSSV: TRDP 38 10/5/2011 Last WO: 40.29 10/8/1989 Well Confiq'. - 2K -14 2/26/2012 9 AM - Schematic - Actual Annotation Depth (ttKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,813.0 12/27/2011 Rev Reason: GLV C /O, NOTE ninam 2/26 /2012 Casing Strings Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED ■ HANGER, 31 - Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 91 SURFACE 998 8.921 3 5.0 3 2 ,934.9 36.00 J - 55 BTC I Casing Des cription String 0... Stri ID ... Top (RKB) Set Depth (f Set De pth ( ... String Wt... String ... String Top Thrd PRODU 7 6 29 8 6 26.00 J -55 BTC Tubin Strings Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 31.1 7,764.6 6,239.0 9.30 J -55 EUE -MOD Completion Details Top Depth (TVD) Top Inc! Nomi... CONDUCTOR, 1 Top (ttKB) (RKB) r) Item Description Comment ID (In) 36 - 115 31.1 31.1 -0.20 HANGER FMC GEN IV TUBING HANGER 3.500 i 1,796.8 1,791.4 15.44 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 + 7,639.7 6,140.9 38.92 PBR BAKER 80-40 PBR w/ 10' STROKE 3.000 SAFETY I VL 7 i t o 1 7,653.5 6,151.5 38.59 PACKER BAKER HB RETRIEVABLE PACKER 2.890 I I I 7,686.0 6,177.0 38.45 BLAST RINGS CARBIDE BLAST RINGS 2.992 GAS LIFT, 7,725.4 6,207.9 38.05 SLEEVE -C OTIS XA SLIDING SLEEVE, CLOSED 12/25/08 2.992 2,390 7,733.2 6,214.1 37.75 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 R, 7,734.2 6,214.9 37.71 PACKER BAKER FB-1 PERMANENT PACKER 4.000 Q 7,737.5 6,217.5 37.58 SBE BAKER 80 -00 SEAL BORE EXTENSION 4.000 7,752.5 6,229.5 37.38 NIPPLE OTIS XN NIPPLE NO GO 2.750 7,763.8 6,238.4 37.19 SOS BAKER SHEAR OUT SUB 2.992 SURFACE, .1 I l Perforations & Slots 353,173 Shot Top (TVD) Btm (TVD) Dens GAS LIFT, Top (ttKB) Btm (ttKB) (ttKB) (RKB) Zone Date (eh ... Type Comment 4,780 - 7,682 7,696 6,173.8 6,184.8 C-4, UNIT B, 4/17/1990 8.0 IPERF 4.5" HSC; 180 deg ph -. 2K -14 GAS LIFT. r. 7,761 7,801 6,236.2 6,269.5 A -4, 2K -14 4/17/1990 4.0 IPERF 4.5" HSC; 180 deg ph 6.580 Notes: General & Safety End Date Annotation __.. 11/3/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2/24/2012 NOTE: "SHORTY" FUSIBLE CAP NEEDED ON SAFETY VALVE GAS LIFT, 7,595 P09, 7,640 PACKER, 7,653 I 7 GAS LIFT, 7,670 II IPERF. 7,682 -7,898 0 IIII MI SLEEVE -C, 7,725 SEAL ASSY, 7,733 PACKER. 7,734 : " SSE, 7,738 ill NIPPLE, 7,753 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Site TRO Run Stn Top(ISKB) (RKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date COT... 1 2,390.0 2,335.6 29.66 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,417.0 1/2/2009 2 4,779.6 4,106.9 43.25 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,345.0 1/2/2009 SOS, 7,784 3 6,560.0 5,372.1 43.28 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,335.0 1/2/2009 7,761 - 7.801 4 7,594.8 6,106.0 39.59 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.188 0.0 1/1/2009 5 7,669.8 6,164.3 38.52 CAMCO MMG 1 1/2 PROD DPHFCV RKP 0.000 0.0 2/24/2012 PRODUCTION, 304,147 TD, 5,202 2K -14 Proposed RWO Completion ' - 3 -1/2" SLB TRMAXX -CMT SSSV @ 1800 TVD I 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 16" 62# H -40 shoe @ 115' MD �a9h� 3 -1/2" Camco gas lift mandrels @ 9 -5/8" 36# J -55 shoe @ 3173' MD 1 — 3 -1/2" HES 'X' @ —7510 ft MD (2.812" min ID) » approximately 30' above seal assembly to allow room for CTD liner top and wireline access to nipple ' Baker 3 -1/2" Seal assembly @ —7540 ft MD • ______ Baker ZXP packer @ —7550 ft MD Flex -Lock hanger C -sand perfs 7682' - Baker 80 -40 SBE 7696' MD— KOP @ 7735' MD A -sand perfs 7761' • _ - _ 7801' MD — — • = 7 — - 4 -1/2" cemented scab liner 7" 26# J -55 shoe @8146'MD • • V V~~~ ~OL~ '~ ~. 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/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~.~;>`~~,~~e-:,y i~R~ ~ ~v 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907 245-8952 1) Caliper Report 28-Dec-0B 2K 14 1 Report / EDE 50-1 03-201 1 2-00 2) Caliper Report 28-Deo-08 2T,208 2 dS -!~~ ~ 1 ~ 3~so Signed Print Name: 1 Report / EDE 50-103-2051 &00 - - ~ ~~ ,ve . ;~ ~ ,,~~ ~~ .~' ., Date PROACTIVE DIAGNOSTIC SERVES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanc~aor~tle(~raae~aaor;~i® .~ar~ WEBSRE: vrwn~v.rne~raear~rice~.c~laa {~ C:\Documents and Settings\Owner\Desktop\Transmit_Cmioco.doc~c ' Memory Matti-Finger Caliper S Log Results Summary ~. Company: ConocoPhillips Alaska, Inc. Well: 2K-14 Log Date: December 28, 2008 Field: Kuparuk Log No.: 8727 State: Alaska Run No.: 1 API No.: 50-103-20112-00 Pipet Desc.: 3.5" 9.31b. J-55 EUE-MOD Top Log Intel: Surtace Pipet Use: Tubing Bot. Log Intel: 997 Ft. (MD) Inspection Type : Restriction /Buckling Assessment Inspection COMMENTS ' This caliper data is tied into the top of the 3.5" tubing at surface. This log was run to assess the condition of the 3.5" tubing to determine potential sources of obstruction. The caliper recordings indicate severe buckling near 700' and slight buckling near 200'. A 3-D log plot of the raw/off-center and centered caliper recordings is included in this report. No significant wall penetrations, areas of cross-sectional wall lass or I.D. restrictions are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED WALL PENETRATIONS ' No significant wall penetrations (> 12%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 5%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS Although slight buckling was recorded near 200' and severe buckling near 700', the caliper recordings indicate no significant I.D. restrictions throughout the tubing logged. Field Engineer: K. Miller Analyst: M. Lawrence Witness: 5. Ferguson ', ^ ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (2$i) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com t Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 /~~~~~ ~~~3G!J 1 PDS Multifinger Caliper 3 D Log Plot ~,. `- - " Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2K-14 Date : December 28, 2008 Description : Detail of Caliper Recordings Across Severe Buckling at 700' PDS Report Overview ^~. S. Body Region Analysis Well: 2K-14 Survey Date: December 28, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 217182 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. 3.5 ins 9.3 f -55 EUE-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ®metal loss body 30 20 10 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of'oints anal se d total = 35 pene loss . 1 23 11 21 14 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /puss pitting corrosion conosion conrosion ible hole Number of 'oints llama ell total = 0 0 0 0 0 0 Damage Profli a (% wall) ~ penetration body metal loss body 0 50 100 0 9 19 29 Bottom of Survey = 33 Analysis Overview page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf J-55 EUE-MOD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 2K-14 Kuparuk ConocoPhillips Alaska, Inc. USA December 28, 2008 Joint No. Jt. Depth (FtJ I'~~n. IJpsc~t (lrn.) Pen. Body (Ins.) I'en. % :Metal loss °~: Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 1 c) 0 00 1 I 2.98 PUP 1 5 ~ ~ 0.01 ~ 1 2.92 1.1 36 ~~ 0.02 7 I 2.90 PUP 2 42 ~) 0.03 11 ~ .91 3 74 U 0.03 I 1 2.91 4 104 O 0.03 II I 2.92 5 35 t) 0.01 (~ 2.92 6 165 t) 0.01 4 1 2.90 7 195 U 0.03 11 l) .9 8 226 U 0.03 12 1 2.92 9 2 7 a 0.03 1 1 ~~ 2.93 10 286 U 0.03 12 I 2.94 11 317 ~ I 0.02 ~ I 2.92 12 347 u 0 02 ' ~ I 2.92 1 37 U 0.02 ~) I 2.91 14 409 ~ I 0.02 7 2.94 15 440 a 0.03 1O 2 2.91 16 471 U 0.01 5 ' 2.92 17 502 U 0.01 5 U 2.90 18 532 ~) 0.01 4 2.92 19 561 ~) 0.02 7 I 2.93 2 592 a 0.0 1I ~ 2.92 1 624 U 0.02 ~) I 2 92 22 655 U 0.03 1 U 2.91 2 6 6 t) 01 5 2.9 24 717 O 0.01 5 ~' 2.91 745 0 0.02 ~) 1 2. 2 26 776 U 0.03 12 ~ 2.92 27 806 O 0.03 1 ~ I 2. 2 28 836 c~ 0.01 ~ ~ 2.93 29 868 !) 0.01 5 I 2.93 30 899 c) 0.03 I Z 1 2.91 1 30 ~ ~ 0.02 ti 1 2.92 32 959 U 0.02 ~> ? 2.91 33 990 U 0.01 4 I 1 Penetration Body Metal Loss Body Page 1 ConocoPhillips Alaska, Inc. KRU 2K-14 ~ m-~4 API: 501032011200 WeII T : PROD A le TS: 39 de 7681 SSSV T TRDP Ori Com letion: 10/8/1989 An le TD: 31 de 8202 Sssv Annular Fluid: Last W/O: Rev Reason: TAG set CV (1787 1798, 00 3 500 Reference Lo Ref Lo Date: Last U date: 7/31/2004 . : ) Last Ta : 7770 TD: 8202 ftKB Last Ta Date: 7/21/2004 Max Hole An le: 47 de 6800 Casin Strin -ALLSTRINCiS Gas Litt , Descri ion Size To Bottom TVD Wt Orade Thread andreWalve CONDUCTOR 16.000 0 115 115 62.50 H-40 1 ' SURF CASING 9.625 0 3173 2931 36.00 J-55 (2390-2391' PROD CASING 7.000 0 8147 6556 26.00 J-55 Tubi Strin -TUBING Gas lift Size To Bottom TVD Wt Orade Thread arMreWaWe 3.500 0 7765 6235 9.30 J-55 EUE-MOD 2 Perforations Su mma (4780.4781, Interval TVD Zone Status Ft SPF Date T Comment 7682 - 7696 6169 - 6180 G4 UNff B 14 8 4/17/1990 IPERF 4.5" HSC' 180 d h 7761 - 7801 6232 - 6263 A-4 40 4 4/17/1990 IPERF 4.5" HSC' 180 de h Gas Lirt andrewalve pas Lift Ma ndrels Nalves 3 (ssso-s561, St MD TVD Man Mtr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2390 2333 Merla TMPp GLV 1.0 BK 0.156 1417 3/13/2000 2 4780 4103 Merla TMPD GLV 1.0 BK 0.188 1345 1/20/2000 Gas Lift 3 6560 5368 Merla TMPD GLV 1.0 BK 0.188 1335 1/20/2000 andr°Walve a 4 7595 6102 Camco MMG-2 OV 1.5 RK 0.156 0 1!20!2000 (7595-7588 Prod uction MandrelsNalve s , St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt PBR 5 7670 6160 Camco MMG CV 1.5 RKP 0.000 0 7/22!2004 psaa7sal, Othe r lu s ui .etc. - JEWELRY oD:3.soo) De h TVD T Descri ion ID 1797 1791 SSSV Camco TRDP-1 A-SSA. REQUIRES SHORT FUSIBLE CAP FOR WELLWORK OPERATIONS 120/2000 2.812 PKR 7640 6136 PBR Baker'80-40' w/ 10' Stroke 3.000 (76537654, 7653 6147 PKR Beker'HB' Retr. 2.890 oD:6.151) 7717 6197 SLEEVE Otis'XA' Slidin Sleeve Closed 830-95 2.813 7734 6210 PKR Baker'FB-1' Perm 4.000 7753 6225 NIP Otis'XN' Ni le 2.813" x 2.75" NO GO 2.750 7764 6234 SOS Baker 2.992 Production 7765 6235 TTL 2.992 andreWalve 5 (76747671, Pert (7682-7696) SLEEVE (7717-7718, 00:4.440) TUBING (0.7765, 00:3.500, 10:2.992) P KR (7734-7735, 00:6.151) NIP (77537754, 00 3 600 : . ) SOS (77647766, 00:3.500) Pert (7761-7801) Scbtunlbe,gep Ii) ';7 (,:ë' '. NO. 3887 , -fi'" >.<:'\Ì~""¡;":~ ;, ;J;.~Ú^·~~;'~ ...J.....~. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I ~Cì -ò~1) Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD r{o ,:,) 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07117/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 US IT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-2i 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1D-101 N/A INJECTION PROFILE 06/27/06 1 2Z-13' 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 ' 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 20.00 P M C:LO~LIvLIX)C E L E W A T E R IA L U N D E TH IS M ARK ER R ARCO Alas.., Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Mark E. Eck Wells Superintendent Kuparuk Production NSK-69 Phone: 659-7226 Fax: 659-7314 August 23, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr, Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) on the following Kuparuk wells. Well Form Action 2K- 14 10~404 Stimulate 2%10 10~404 (Other) Conversion 2V-15 10-404 Stimulate 3G-05 10-404 Perforate 3G-05 10-404 Stimulate If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Attachments Well Files (attach only) File: FTR 082396 (w/o attach) AUG 3 1 1995 OiJ & Gas Cons, Commission Anchora0(l ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 94' FNL, 94' FEL, SEC. 11, T10N, R8E, UM At top of productive interval 1360' FNL, 1448' FWL, SEC. 11, T10N, R8E, UM At effective depth 1386' FNL, 1236' FWL, SEC. 11, T10N, R8E, UM At total depth 1390' FNL, 1165' FWL, SEC. 11, T10N, R8E, UM 6. Datum elevation (DF or KB) RKB 1 54 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-14 9. Permit number/approval number 89-88 10. APl number 50-103-20112 11. Field/Pool Kuparuk River Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical Effective depth' measured true vertical 8202' feet 6630' feet 8063' feet 6507' feet Plugs (measured) NONE Junk (measured) NONE Casing Length Size Structural 8 0' 1 6" Conductor Surface 31 38' 9 Intermediate Production 81 1 6' 7" Liner Perforation depth: measured 7682'-7696', true vertical 6169'-6180', Tubing (size, grade, and measured depth) 3.5" 9.3#J-55 @7765' cemented Measured depth True vertical depth 115' 115' 5/8" 1000 SX AS III & 31 73' 2935' 500 SX CLASS G 225 SX CLASS G 81 4 6' 6 5 3 5' 7761'-7801' .,.,,,ED 6231'-6263' AUG 5 1 1995 Gas Cons. Commission Packers and SSSV (type and measured depth) '.~c[10[agt~ '" BROWN HB PKR @ 7653', BAKER FB-1 PKR @ 7734', CAMCO TRDP-1A-SSA SSSV @ 1797' 13. Stimulation or cement squeeze summary Fracture Stimulate A Sands Intervals treated (measured) 7761 '-7801 ' Treatment description including volumes used and final pressure 6.0 Mlbs 20/40, 98.1 Mlbs 16/20 & 11.3 Mlbs 12/18. 14. Max pressure 5233 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 224 490 2 920 240 Subsequent to operation 6 5 7 9 7 6 2 7 1 3 4 0 15. Attachments 16. ~atus of well classification as: Copies of Logs and Surveys run __ /Water Injector __ / Daily Report of Well Operations Z JOil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 245 Service Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, In( Post Offic~ =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 27, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive- Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~<~-~qq 2A-13 Stimulate ~c.~_ ~.._ 2H- 12 Stimulate ~:~--~ 2K-14 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RECEIVED S EP 2 9 199,~ Alaska Oil & Gas Cons. Commisslo,', Anchorage ARCO Alaska, Inc. is a Subsidiary ct AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA ' ~'-'" ALASKA OIL AND GAS CONSERVATION COMML.,,ON REPORT OF SUNDRY WELL OPERATIONS 1 . Operations Performed:' Operation Shutdown __ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other . 5. Type of Well: 6. Datum elevation (DF or KB) X feet 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic _ Service 4. Location of well at surface 94' FNL, 94' FEL, SEC. 11, T10N, RSE, UM At top of productive interval 1228' FNL, 1452' FWL, SEC. 11, T10N, R8E, At effective depth 1271' FNL, 1227' FWL, SEC. 11, T10N, R8E, At total depth 1272' FNL, 1157' FWL, SEC. 11, T10N, R8E, 12. Present well condition summary Total Depth: measured true vertical 8202' 6630' UM (approx) UM (approx) UM (approx) RKB 1,54 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-14 9. Permit number/approval number 89-88 10. APl number 5o-103-20112 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet NONE Effective depth: measured 8 0 6 3' true vertical 6507' feet Junk (measured) feet NONE Casing Length Structural 8 0' Conductor Surface 31 3 8' Intermediate Production 8 1 1 6' Liner Perforation depth: measured 7682'-7696', true vertical 6169'-6180', Tubing (size, grade, and measured depth) 3.5" 9.3#J-55 @7765' Packers and SSSV (type and measured depth) Size 16" 9 5/8" 7" Cemented 1000 SX AS III & 5OO SX CLASS G 225 SX CLASS G 7761 '-7801 ' 6231 '-6263' Measured depth 115' 3173' 8146' True vertical depth 115' 2935' 6535' RECEIVED S E P 2 9 199) Alaska 0il & Gas Cons. L;0mmissto~' Anchorage BROWN HB PKR @ 7653', BAKER FB-1 PKR @ 7734', CAMCO TRDP-1A-SSA SSSV ~ 1797' 13. Stimulation or cement squeeze summary Intervals treated (measured) C4B Sand 7681'-7694' MD Treatment description including volumes used and final pressure 3,000 # OF 12/18 LWP in formation, final pressure 7950 psi 14. Rearesentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 550 240 Subsequent to operation 0 0 0 500 260 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. S~atus of well classification as: -- /Water Injector __ X /Oil X Gas Suspended Service 17. I hereby/~ertify that t~ foregoing is true and correct to the best of my knowledge. Si~ned "~~'~~- ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of AUantic Richfield Company WELL SERVICE REPORT WELL IPBDT ITRACTOR FIELD · DISTRICT - STATE OPERATION AT REPORT TIME JDA~'S DATE REMARKS r_zL: 998z~37 . tO'lO SE'r ~'T~~V6j?- r_uP5 ~ 1~ Z,5 Put, aP u4 ~ Z. 51..~ ~ri'~ 2.0 6P~ ~ 8s~ - 5~,~'r Ps~ SF p 2 9 !99~ Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ AL,L, · ' STATE OF ALASKA 0 ~ ~ '~ ALASrtA OIL AND GAS CONSERVATION COMMISSION ' ' _ WELL COMPLETION OR RECOMPLETION REPORT AND LOG J 1 Status of Well Classification of Service Well OIL [--~ GAS r'"l SUSPENDED r-"] ABANDONED ['"1 SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-88/9-924 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~;-- . ..... ~ 50-103-20112 4 Locatior[ gf well at surface L(~T,,ATIO'~ 9 Unit or Lease Name 94' F~L, 94' FEL, SEC 11, T10N, R8E UM :~ VT:~IFIED KUPARUK RIVER At Top Producing Interval ~TE ,~~ 10 Well Number 1360' FNL, 1448' FWL,SEC 11, T10N, RSE UM!...~r~~_.y./....~~. !iL I~~ 2K-14 At Total Depth :! ~.F.~'I,-F.I~.q -~' i ' 11 Field and Pool 1390' FNL, 1165' FWL, SEC 11, T10N, RSE UM L ~"',~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation ai~d Serial No. KUPARUK RIVER OIL POOL RKB 154'J ADL: 25588 ALK: 2674 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 10/1/89. 10/6/89. -4Y'~e/~J~. NA feet U SLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost 8202' MD & 6484' TVD YES~X[X[X~ NO ~ 1797' feet MD 1400' APPROX MD & 6603' TVD 8042' 22 Type Electric or Other Logs Run D IL/S FL/GR/SP/FDC/CN L/CAL/CBI_/GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 110 SX AS II 9 5/8" 36# J-55 SURF 3173' 12-1/4" 1000 SX AS II1~ 500 SX CLASS G ... 7" 26# J-55 SURF 8146' 8-1/2" 225 SX CLASS G ,,, 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ..... 3-1/2" 9.3#, J-55 7765' 7653' 7682' - 7696' W/4-1/2" @ 8 SPF MD 6169' - 6180' TVD 7761' - 7801' W/4-1/2" @ 4 SPF MD 6232' - 6263' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached addendum 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I ,,, Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO ! TEST PERIOD ~- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .on t £CEIVED OCT u Fractured 8/20/90 ~chora9'~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7681' 6168' NA KUPARUK C BOTTOM 7715' 6195' KUPARUK A TOP 7873' 6322' KUPARUK A Bo'FrOM 7996' 6426' 31. LIST OF ATTACHMENTS GYRO, Frac addendum, Daily Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~J,(.~ ~.,~~ _~.~-~~~-~_ ~ Title AREA DRILLINGENGINEER Date -./'/~'~' ~/~'/~-t - - INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL 2K-14 8/20/90 Frac Kuparuk "A" sand perfs 9912'-9948' 180 deg oriented 164 deg ccw in seven stages as follows. Stage 1: Stage 2: Stage 3: Stage 4: Stage 5: Stage 6: Stage 7: Stage 8: Pmp 100 bbls Gel H20 w/YF240 @ 20 bpm 6900-4230 psi 45 bbls Gel H20 w/YF240 @ 15 bpm 3650-3780 psi 30 bbls Gel H20 w/YF240 @ 10 bpm 3320-3720 psi 66 bbls Slick H20 flush @ 20 bpm 4350-3850 psi 200 bbls Gel H20 w/YF240 @ 20 bbls 3800-4224 psi 20 bbls Gel H20 w/YF240 w/2# 16/20 Carbolite @ 20 bpm 4224-3990 psi 26 bbls Gel H20 w/YF240 w/4#16/20 Carbolite @ 20 bpm 3990-3777 psi 24 bbls Gel H20 w/YF240 w/6# 16/20 Carbolite @ 20 bpm 3777-3923 psi 30 bbls Gel H20 w/YF240 w/8#16/20 Carbolite @ 20 bpm 3923-3790 psi 30 bbls Gel H20 w/YP240 w/10# 12/18 Carbolite @ 20 bpm 3790-6800 psi Fluid to recover: 598 bbls Sand in zone: 5,500 lbs Sand in csg: 13,974 lbs Avg pressure: 4800 psi Dpervisor Date RECEIVED Oil & Sa:',,, ~". ARCO 011 and Gas Company 0 Insffuctlons: Prepare and submit the "l#~.j;RellelT' on the ,flint. Wednesday after a well is spudded or workover operations are started. Dally work prior to spuddlrlB ~ltould be summanzea on the form giving inclusive dates only. District ] County, parish or borough ARCO ALASKA INC. ] NORTH SLOPE Fietd Lease or Unit KUPARUK RIVER UNIT ADL: 25588 ALK: 26754 Auth. or W.O. no. ITM AK3692 I COMPLETIONS Well History - Initial Report - Dally IState AK K~ell no. 2 -14 Operator IARCO WJ. ARCO I 55.8533 SpuddedsPuDOr W.O. begun IDate 10/01/89 IHOur 00100 IPrior status if a W.O. Complete record for each day reported NORDIC #1 Date and depth as of 8:00 a.m. 04/18/90 ( TD: 8202 PB: 8042 SUPV:DB 9) 04/19/90 (10) TD: 8202 PB: 8042 SUPV:DB MU PERF GUN FOR C SAND 7"@ 8147' MW:10.3 NaCl MOVE RIG FROM 2K-13, ACCEPT RIG 1830 4/17/90, ND DRY HOLE TREE, NU HOPE AND TEST TO 3000 PSI, RIH W/ 6 STDS DC, CIRC. DIESEL OUT OF HOLE, POH, RU HLS E-LINE, TEST LUBR., RIH GUN #1, PERF 7781-7801, POH, ASF, RIH W/ GUN #2, PERF 7761-7781, POH, ASF, RIH W/ GUN ~3, PERF 7682-7696, POH, GUN MISFIRED, RELOAD GUN #3 DAILY:S27,745 CUM:$868,164 ETD:S868,164 EFC:$1,317,000 RELAND TBG/ RILDS 7"@ 8147' MW:10.3 NaCl MU GUN #4(REWIRE OF GUN %3), RIH, PER~"ORATE 7682-7696 AT 4SPF, POH, ASF, MU GUN #5, RIH, PERFORATE 7682-7696 AT 4SPF, (EFFECTIVE 8SPF ACROSS INTERVAL), POH, ASF, RIH W/ 5-7/8" GR/JB TO 7816, POH, MU PERMANENT PKR AND TAILPIPE ASSEMBLY, RIH, SET PKR AT 7720' WLM, POH, RD E-LINE UNIT, MU AND RIH W/ 3-1/2" SINGLE SELECTIVE COMPLETION ASSEMBLY, MU CONTROL LINE TO SSSV AND TEST, CONT. RIH W/ COMPLETION, STAB INTO PERM PKR, VERFIY POSITION, SPACE OUT 1' ABOVE PERM PKR, MU TBG HGR & CONTROL LINE, LAND TBG, RILDS, DROP BALL, PRESS TBG TO 2500 PSI TO SET PKR, PRESS ANNULUS TO 1000 PSI, BLEED ANNULUS , BLEED TBG TO 1200 PSI, BOLDS, PU & SHEAR PBR, BLEED TBG PRESS, RELAND TBG, RILDS CUM:$929,955 ETD:S929,955 EFC:$1,317,000 The above is co~r.~ect Signature ~f i For form preparation d IstHbutlon. Drilling, Pages 86 and 87. Date / / · cd INumber all dally well history forms consecutively as they are prepared for each well. Page no. 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. I Accountlng cost center code District County or Parish IState ARCO ALASKA INC. I AK NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 ITitle COI~LETIONS Well no. 2~--14 KUPARUK RIVER UNIT Auth, or W.O. no. AK3692 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Old TD 04/20/90 (11) A.R.Co. W.I. Date 55. 8533 10/01/89 Complete record for each day reported NORDIC #1 TD: 8202 PB: 8042 SUPV:DB Iotal number of wells (active or inactive) on thisI ost center prior to plugging and I bandonment of this well our I Prior status if a W.O. I 00:00 RELEASE RIG 7"@ 8147' MW:10.3 NaC1 FINISH RILDS. PRESSURE ANNULUS & TBG TO 1000 PSI. CLOSE SSSV & BLEED ABOVE TO 500 PSI, TEST OK. REPRESSURE TBG & OPEN SSSV. PULL LJ, SET BPV. ND BOP NU FMC GEN IV 3-1/2" 5000 PSI TREE. TEST PACKOFF & TREE. PULL TP & TEST ANNULUS TO 2500 PSI FOR 15 MIN. HOLD ANNULUS & PRESSURE UP ON TBG, SOS SHEARED @ 3800 PSI BLEED OFF PRESSURE, REVERSE CIRCULATE 6 BBLS DIESEL CAP INTO ANNULUS. INJECT 2 BBLS DIESEL INTO TBG @ 1/2 BPM & 1700 PSI, CHECK VALVE HELD. SHUT IN AND MONITOR TBG PRESSURE. DOWN TO 300 PSI AFTER 10 MIN & FALLING. RD LINES AND SECURE WELL. RELEASE RIG @ 10:30 4/19/90. DAILY:S153,998 Released rig CUM:$1,083,953 ETD:S1,083,953 EFC:$1,317,000 Classifications (oil, gas, etc.) Producing method New TD PB Depth Date Kind of r g Type completion (single, dual, etc.) Off c a reservoir name(s) Potential test data Welt no. Date Reservoir Producing Interval Oil or gasTest 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 T. he above is co/~t IDat~/,..~ / ¢O ~ Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvl~/on of AtlantlcRIchflaldCompanY SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ORIGINAL ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN DATE OF SURVEY: 11/6/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 100 100.00 200 200.00 300 300.00 400 400.00 -154.00 0 0 -54.00 0 10 46.00 0 16 146.00 0 18 246.00 0 13 N .00 E .00 .00 .00 N 27.40 E .18 .14N .07E N 37.30 W .26 .47N .00W N 55.90 W .10 .82N .38W N 53.20 W .08 1.09N .76W .0O -.11 -.14 .11 .39 500 499.99 600 599.99 700 699.98 800 799.97 900 899.95 345.99 0 26 445.99 0 49 545.98 0 45 645.97 0 58 745.95 1 8 N 39.50 W .22 1.51N 1.17W N 59.30 W .43 2.17N 2.02W N 63.50 W .09 2.83N 3.23W N 55.80 W .25 3.59N 4.51W N 50.60 W .19 4.70N 5.98W .65 1.26 2.20 3.19 4.25 1000 999.93 845.93 1 23 1100 1099.89 945.89 1 31 1200 1199.86 1045.86 1 34 1300 1299.82 1145.82 1 34 1400 1399.69 1245.69 4 13 N 51.00 W .25 6.10N 7.69W N 47.80 W .16 7.76N 9.62W N 48.10 W .04 9.57N 11.63W N 50.10 W .06 11.37N 13.71W N 86.70 W 3.10 12.46N 18.44W 5.45 6.78 8.14 9.56 13.73 1500 1499.18 1600 1598.08 1700 1696.56 1750 1745.52 1800 1793.92 1345.18 7 16 1444.08 9 35 1542.56 10 21 1591.52 13 1 1639.92 15 59 S 84.00 W 3.18 12.01N 28.41W S 79.60 W 2.41 9.85N 42.90W S 81.00 W .80 6.94N 59.96W S 79.10 W 5.41 5.17N 69.93W S 76.90 W 6.02 2.54N 82.18W 23.35 37.81 54.94 64.98 77.44 1900 1889.57 2000 1983.61 2100 2075.32 2200 2165.22 2300 2254.49 1735.57 17 54 1829.61 21 46 1921.32 25 10 2011.22 26 45 2100.49 26 48 S 75.90 W 1.94 4.32S 110.51W S 78.40 W 3.96 11.80S 143.61W S 75.70 W 3.56 20.79S 182.40W S 76.40 W 1.62 31.34S 224.89W S 77.60 W .54 41.47S 268.79W 106.50 140.30 179.98 223.66 268.55 2400 2341.96 2500 2426.78 2600 2508.46 2700 2585.89 2800 2659.66 2187.96 31 8 2272.78 32 47 2354.46 37 37 2431.89 40 52 2505.66 44 2 S 74.50 W 4.58 53.23S 315.76W S 73.40 W 1.76 67.88S 366.63W S 71.30 W 4.98 85.41S 421.54W S 70.10 W 3.33 106.34S 481.24W S 70.00 W 3.17 129.37S 544.68W 316.86 369.78 427.42 490.66 558.10 2900 2731.71 3000 2804.35 3100 2877.53 3200 2951.22 3300 3025.06 2577.71 43 46 2650.35 43 3 2723.53 42 52 2797.22 42 11 2871.06 42 37 S 70.20 W .30 152.98S 609.88W S 70.80 W .82 175.92S 674.67W S 70.80 W .19 198.34S 739.03W S 70.60 W .69 220.68S 802.83W S 70.10 W .55 243.36S 866.34W 627.41 696.10 764.24 831.82 899.22 ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 11/ 7/89 DATE OF SURVEY: 11/6/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3400 3098.90 2944.90 3500 3172.73 3018.73 3600 3246.37 3092.37 3700 3320.05 3166.05 3800 3393.67 3239.67 COb-RS INCLN DG MN 42 11 42 37 42 31 42 33 42 37 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. S 69.70 W .51 266.53S 929.66W S 68.90 W .70 290.37S 992.75W S 68.80 W .13 314.78S 1055.85W S 68.70 W .08 339.28S 1118.86W S 68.20 W .34 364.14S 1181.81W 966.60 1033.96 1101.50 1169.00 1236.53 3900 3467.21 3313.21 4000 3540.04 3386.04 4100 3612.20 3458.20 4200 3684.53 3530.53 4300 3757.13 3603.13 42 43 43 43 43 42 47 49 30 24 S 68.00 W .16 389.42S 1244.68W S 69.90 W 1.70 414.01S 1308.62W S 69.70 W .14 437.92S 1373.59W S 69.80 W .33 461.82S 1438.37W S 69.50 W .23 485.74S 1502.86W 1304.13 1372.53 1441.70 1510.69 1579.41 4400 3829.10 3675.10 4500 3900.56 3746.56 4600 3972.31 3818.31 4700 4044.45 3890.45 4800 4116.96 3962.96 44 44 44 43 43 31 16 1 37 26 S 71.90 W 2.01 508.66S 1568.36W S 72.30 W .38 530.16S 1634.94W S 71.70 W .48 551.69S 1701.18W S 71.50 W .43 573.54S 1766.88W S 71.10 W .33 595.62S 1832.12W 1648.78 1718.74 1788.40 1857.64 1926.50 4900 4189.34 4035.34 5000 4261.04 4107.04 5100 4332.44 4178.44 5200 4403.95 4249.95 5300 4475.50 4321.50 43 44 44 44 44 48 34 18 23 14 S 71.10 W .37 617.97S 1897.40W S 71.30 W .77 640.43S 1963.38W S 71.00 W .33 663.06S 2029.64W S 70.80 W .16 685.93S 2095.70W S 70.40 W .32 709.13S 2161.59W 1995.49 2065.18 2135.18 2205.07 2274.91 5400 4546.12 4392.12 5500 4615.88 4461.88 5600 4685.87 4531.87 5700 4756.18 4602.18 5800 4826.95 4672.95 45 45 45 45 44 53 39 30 7 46 S 72.30 W 2.13 731.75S 2228.65W S 72.30 W .24 753.54S 2296.91W S 72.10 W .20 775.37S 2364.92W S 71.90 W .41 797.34S 2432.54W S 71.80 W .36 819.35S 2499.68W 2345.67 2417.33 2488.75 2559.85 2630.51 5900 4897.83 4743.83 6000 4968.59 4814.59 6100 5039.29 4885.29 6200 5109.97 4955.97 6300 5180.88 5026.88 44 44 45 45 44 56 59 1 2 37 S 71.60 W .21 841.50S 2566.65W S 71.20 W .29 864.04S 2633.63W S 71.20 W .03 886.83S 2700.57W S 70.80 W .28 909.86S 2767.46W S 70.50 W .46 933.22S 2833.99W 2701.04 2771.70 2842.41 2913.15 2983.63 6400 5252.39 5098.39 6500 5324.38 5170.38 6600 5396.30 5242.30 6700 5467.87 5313.87 6800 5537.40 5383.40 44 43 44 44 47 4 49 12 24 28 S 70.20 W .60 956.73S 2899.82W S 70.00 W .28 980.35S 2965.08W S 70.00 W .37 1004.12S 3030.37W S 69.70 W .29 1028.17S 3095.94W S 69.00 W 3.12 1053.52S 3163.17W 3053.50 3122.86 3192.29 3262.08 3333.84 SPERRY-SUN DRILLING SERVICE~ ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/6/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6900 5605.03 5451.03 47 24 S 68.90 W .10 7000 5672.68 5518.68 47 26 S 68.70 W .15 7100 5740.61 5586.61 46 58 S 68.40 W .51 7200 5810.58 5656.58 44 13 S 66.60 W 3.04 7226 5829.21 5675.21 44 12 S 66.60 W .11 1079.98S 3231.92W 3407.39 1106.61S 3300.57W 3480.91 1133.45S 3368.87W 3554.15 1160.76S 3434.88W 3625.35 1167.96S 3451.52W 3643.40 7300 5882.20 5728.20 44 20 S 66.90 W .35 7400 5954.60 5800.60 42 52 S 68.90 W 2.02 7500 6029.08 5875.08 40. 50 S 72.80 W 3.29 7600 6105.30 5951.30 39 50 S 75.60 W 2.07 7700 6182.97 6028.97 38 15 S 78.80 W 2.57 1188.35S 3498.98W 3694.83 1214.31S 3562.87W 3763.60 1236.23S 3625.86W 3830.28 1253.87S 3688.13W 3894.95 1267.85S 3749.53W 3957.68 7800 6262.51 6108.51 36 19 S 80.40 W 2.15 7900 6344.53 6190.53 33 27 S 83.00 W 3.23 8000 6429.33 6275.33 30 33 S 87.50 W 3.75 8100 6515.44 6361.44 30 33 S 87.50 W .00 8200 6601.55 6447.55 30 33 S 87.50 W .00 1278.80S 3809.11W 4017.74 1287.11S 3865.69W 4074.15 1291.58S 3918.47W 4125.75 1293.79S 3969.26W 4174.78 1296.01S 4020.06W 4223.80 8202 6603.27 6449.27 30 33 S 87.50 W .00 1296.06S 4021.08W 4224.79 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4224.79 FEET AT SOUTH 72 DEG. 8 MIN. WEST AT MD = 8202 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 252.14 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/6/89 JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 1000 999.93 845.93 2000 1983.61 1829.61 3000 2804.35 2650.35 4000 3540.04 3386.04 .00 .00 .00 6.10 N 7.69 W .07 .07 11.80 S 143.61 W 16.39 16.31 175.92 S 674.67 W 195.65 179.26 414.01 S 1308.62 W 459.96 264.31 5000 4261.04 4107.04 6000 4968.59 4814.59 7000 5672.68 5518.68 8000 6429.33 6275.33 8202 6603.27 6449.27 640.43 S 1963.38 W 738.96 279.00 864.04 S 2633.63 W 1031.41 292.46 1106.61 S 3300.57 W 1327.32 295.90 1291.58 S 3918.47 W 1570.67 243.36 1296.06 S 4021.08 W 1598.73 28.06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. DATE OF SURVEY: 11/6/89 2K-14 KUPARUK JOB NUMBER: AK-BO-90130 ALASKA KELLY BUSHING ELEV. = 154.00 FT. COMPUTATION DATE: 11/ 7/89 OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 .00 .00 .00 54 54.00 -100.00 .02 N .01 E .00 .00 154 154.00 .00 .30 N .12 E .00 .00 254 254.00 100.00 .68 N .17 W .00 .00 354 354.00 200.00 .98 N .61 W .00 .00 454 454.00 300.00 1.25 N .95 W .00 .00 554 554.00 400.00 1.84 N 1.48 W .01 .00 654 654.00 500.00 2.55 N 2.69 W .02 .01 754 754.00 600.00 3.17 N 3.87 W .03 .01 854 854.00 700.00 4.13 N 5.28 W .04 .01 954 954.00 800.00 1054 1054.00 900.00 1154 1154.00 1000.00 1254 1254.00 1100.00 1354 1354.00 1200.00 5.40 N 6.84 W .06 .02 6.94 N 8.72 W .09 .03 8.73 N 10.70 W .13 .04 10.55 N 12.74 W .16 .04 12.12 N 15.65 W .22 .06 1454 1454.00 1300.00 1555 1554.00 1400.00 1656 1654.00 1500.00 1758 1754.00 1600.00 1862 1854.00 1700.00 12.43 N 23.25 W .53 .30 11.15 N 35.66 W 1.31 .79 8.16 N 52.31 W 2.74 1.42 4.78 N 71.91 W 4.71 1.98 1.52 S 99.36 W 8.62 3.91 1968 1954.00 1800.00 2076 2054.00 1900.00 2187 2154.00 2000.00 2299 2254.00 2100.00 2414 2354.00 2200.00 9.43 S 132.43 W 14.26 5.64 18.42 S 172.87 W 22.52 8.26 30.00 S 219.39 W 33.43 10.91 41.42 S 268.55 W 45.45 12.02 55.17 S 322.77 W 60.07 14.62 2532 2454.00 2300.00 2658 2554.00 2400.00 2792 2654.00 2500.00 2930 2754.00 2600.00 3067 2854.00 2700.00 73.18 S 383.96 W 78.70 18.63 97.28 S 455.88 W 104.26 25.56 127.52 S 539.59 W 138.17 33.91 160.21 S 629.97 W 176.87 38.70 191.15 S 718.41 W 213.90 37.03 3203 2954.00 2800.00 3339 3054.00 2900.00 3474 3154.00 3000.00 3610 3254.00 3100.00 3746 3354.00 3200.00 221.52 S 805.21 W 249.76 35.85 252.42 S 891.38 W 285.33 35.58 284.16 S 976.67 W 320.54 35.21 317.31 S 1062.37 W 356.35 35.81 350.63 S 1147.91 W 392.10 35.74 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA KELLY BUSHING ELEV. COMPUTATION DATE: 11/ 7/89 OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH DATE OF SURVEY: 11/6/89 JOB NUMBER: AK-BO-90130 = 154.00 FT. NORTH/SOUTH VERTICAL EAST/WEST DIFFERENCE CORRECTION 3882 3454.00 3300.00 384.85 S 1233.38 W 428.03 35.93 4019 3554.00 3400.00 418.61 S 1321.19 W 465.34 37.31 4157 3654.00 3500.00 451.81 S 1411.17 W 503.89 38.56 4295 3754.00 3600.00 484.70 S 1500.09 W 541.70 37.80 4434 3854.00 3700.00 516.27 S 1591.63 W 580.92 39.22 4574 3954.00 3800.00 546.13 S 1684.38 W 620.54 39.62 4713 4054.00 3900.00 576.43 S 1775.51 W 659.19 38.65 4851 4154.00 4000.00 607.00 S 1865.36 W 697.05 37.87 4990 4254.00 4100.00 638.21 S 1956.81 W 736.11 39.06 5130 4354.00 4200.00 669.91 S 2049.54 W 776.13 40.01 5269 4454.00 4300.00 702.11 S 2141.86 W 815.99 39.86 5411 4554.00 4400.00 734.22 S 2236.39 W 857.31 41.33 5554 4654.00 4500.00 765.40 S 2334.03 W 900.52 43.20 5696 4754.00 4600.00 796.66 S 2430.46 W 942.90 42.39 5838 4854.00 4700.00 827.73 S 2525.18 W 984.11 41.21 5979 4954.00 4800.00 859.34 S 2619.82 W 1025.38 41.27 6120 5054.00 4900.00 891.57 S 2714.50 W 1066.81 41.43 6262 5154.00 5000.00 924.36 S 2808.97 W 1108.23 41.42 6402 5254.00 5100.00 957.26 S 2901.29 W 1148.25 40.02 6541 5354.00 5200.00 990.08 S 2991.80 W 1187.06 38.81 6680 5454.00 5300.00 1023.46 S 3083.20 W 1226.59 39.53 6824 5554.00 5400.00 1060.01 S 3180.07 W 1270.56 43.97 6972 5654.00 5500.00 1099.22 S 3281.61 W 1318.38 47.81 7119 5754.00 5600.00 1138.72 S 3382.07 W 1365.52 47.14 7260 5854.00 5700.00 1177.53 S 3473.64 W 1406.57 41.06 7399 5954.00 5800.00 1214.11 S 3562.35 W 1445.19 38.61 7532 6054.00 5900.00 1242.61 S 3646.45 W 1478.94 33.76 7662 6154.00 6000.00 1263.12 S 3726.94 W 1508.96 30.02 7789 6254.00 6100.00 1277.76 S 3802.93 W 1535.43 26.47 7911 6354.00 6200.00 1287.82 S 3871.84 W 1557.31 21.88 8028 6454.00 6300.00 1292.21 S 3933.02 W 1574.65 17.34 8144 6554.00 6400.00 1294.79 S 3992.01 W 1590.78 16.13 8202 6603.27 6449.27 1296.06 S 4021.07 W 1598.73 7.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-14 KUPARUK ALASKA COMPUTATION DATE: 11/ 7/89 DATE OF SURVEY: 11/6/89 JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3173 2931.21 2777.21 214.65 S 7681 6168.08 6014.08 1265.50 S 7715 6194.75 6040.75 1269.66 S 7873 6322.11 6168.11 1285.18 S 7996 6425.89 6271.89 1291.48 S 785.72 W 9 5/8" CSG 3737.97 W TOP KUPARUK C 3758.64 W TOP KUPARUK A 3850.78 W BASE KUPARUK A 3916.43 W BASE KUPARUK C 8000 6429.33 6275.33 1291.58 S 8063 6483.58 6329.58 1292.97 S 8146 6555.05 6401.05 1294.81 S 8202 6603.27 6449.27 1296.06 S 3918.47 W SURVEY DEPTH 3950.47 W PBTD 3992.63 W 7" CSG 4021.08 W TD ARCO ALASKA, INC. 2K-14 STRATIGRAPHIC SUMMARY BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 94FSL 94FEL SEC 11 T10N R08E 9 5/8" CSG TOP KUPARUK C TOP KUPARUK A BASE KUPARUK A BASE KUPARUK C 3173 2931.21 2777.21 214.65S 785.72W 7681 6168.08 6014.08 1265.50S 3737.97W 7715 6194.75 6040.75 1269.66S 3758.64W 7873 6322.11 6168.11 1285.18S 3850.78W 7996 6425.89 6271.89 1291.48S 3916.43W PBTD 8063 6483.58 6329.58 1292.97S 3950.47W 7" CSG 8146 6555.05 6401.05 1294.81S 3992.63W TD 8202 6603.27 6449.27 1296.06S 4021.08W COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE DATE OF SURVEY: 11/6/89 COMPUTATION DATE: 11/ 7/89 JOB NUMBER: AK-BO-90130 KELLY BUSHING ELEV. = 154.00 FT. 2K-14 KUP ARUK ALASKA 11/6789 SPENN Y~-'~ U N HORIZONTAL PROJECTION START FINISH TVD = SCALE IS 700 TVD - 0 6603.27 FEET/IN DEPARTURE 4200 3500 2800 2100 1400 700 0 I I I I I '700 1400 2100 2800 3500 4200 2K-14 KUPARUK ALASKA 11/6/89 VERTICAL PROJECTION START FINISH TVD - SCALE IS 1000 TVD - 0 6603.27 FEET/IN 1000 2000 3000 4000 5000 6000 7000 _ 82( 4224.79 i 1000 2o~o 3o~o ~o;~o VERTICAL SECTION DZRECTZON = O. O0 5000 6o~o PEP~T ~ ~ - UMI-'LD i IUI~I U,~ I r ~ VCELL NAME ~'/, I'"~I ~ CO. CO,%,"-"'ACT · ! ........ AOGCC GEOLOGICAL MATERIAL[; INVENTORY LIST [ check off or listrdata as it is re.r~eived ~ '"~07 ! /-///~. drilling histo~ ~ so~.y ! ~ well t.s,~ ! ~re desri~tion I ~red inte~als core anai~is d~ ditch inte~als digital da~ ,, ,~7, ~.~~ LOG TYPE RUN INTERVALS SCALE NO. mai ~ ~ 21 ,,, I ,, ,.F" 4] /' i:;1 i- ~! ,,'Cc,,,,.., ~ ~=e. / ,~,d Z,,~ I ,..,-~/? '- J~,,/,'.., ' :" , "i'll 12j ' , , ,,, l~j ........ .... .~ ~! 17l .... ,,, GAS CO/,'SgRW, TIOil C(,HHI.$Slpll B,O.P.g. InspecCion gepotc RECEIVED APR 1 8 t990 - - ................. ~ L - Location, Gen~ra~~ell Visuai~ Audio Pump incr. clos. pros. 200 psig Full Cl,arse Pressure Actained:_.~mifl_..__seco ~. ~.~, .,_--- . ~ -- ConCtole: Haste~ ' Remoc~ Bl~zids s~[it.ctt., cover. Kelly and FlOor Safety Valvea ~_l L _ --' i~ · . -- ; Annular Preventer Blind Rams Choke Line Valves II.C.g. Valve Rill Line Valves Cl}eck,Valve ~es t__~ rr. essu~.e_ ~0 _ ?g~./e Upper Kelly Test Presvur%. _, ............ Test ~re~sure Ball Type_ ....... _ Inside BOP Test Pressure gi~oke Ha.i[old~~es~ [ressure ....... .. No. Valves~_ _.,, ' . ...... __ No. [lenses ....... Adj.atable Chokes ...,~ ..... T~.st Result:s; Failures _- Repair o~ Replacenen~ o~ fai!ed-equlpm.n~ ~o be made ~tthin days at~d It,cpeetor/ Co~iss/on o~ice noCi~/ed. , z _ , , , ..... -; . . .- ~ ~_ __. r i .., · il --- orig, - AO&GCG e: - Operaco~ cc - Supervisor ARCO Alaska, Inc. Date: February 14, 1990 Transmittal #: 7666 RETURN TO: ARCO Alaska, Inc. Attn' Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 4 Electromagnetic Wave Resistivity 1 0 - 6 - 8 9 7 3 1 2 - 8 2 0 2 Dual Gamma Ray Receipt Acknowledged' RECEIVED DISTRIBUTION: D&M Drilling State of Alaska(+sepia) NSK ARCO Alaska, Inc. Date: February 14, 1990 Transmittal #: 7665 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 4 Dual Gamma Ray Compensated 1 0 - 6 - 8 9 7 3 1 2 - 8 2 0 2 Neutron Porosity Simulation Formation Density RECE Receipt Acknowledged: DISTRIBUTION: D&M Drilling State of Alaska(+sepia) ARCO Alaska, Inc. Date: February 8, 1989 Transmittal #: 7662 RETURN TO: ARCO Alaska, Inc. Altn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed cop~ of this transmittal. ,~1<.~ 5' - ¢,-/o ,../- (2- O- 1o~ 2 K - 2 5 LIS Tape and Listing 1 - 3 1 - 9 0# 9 0 - 0 1 - 002AK 2 K - 1 4 LIS Tape and Llsling 1 0 - 1 7 - 8 9 8 9 - 1 0 - 0 2 2 Receipt Acknowledged' DISTRIBUTION: RECEIVED ........ Dale' , ~l~$!,','a ('iii & GaS Cons. ColltlTIJSSJO. ll A~chorage Lynn Goetlinger Stale of Alaska ARCO Alaska, Inc. Date' January 5, 1990 Transmittal #: 7640 RE'iqJRN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 03 ' Acoustic Cement Bond Log 9 - 26 - 89 6894 - 8742 2 K - 04 Acoustic Cement Bond Log 1 1 - 04 - 89 9000 - 10703 2 K - 14 Acoustic Cement Bond Log 11 - 05 - 89 5019 - 8042 2K-17 CBT 1 2-25-89 7245-9018 2K-20 CBT 1 2-24-89 7889-9698 2K-22 CBT I 2-24-89 7923-9708 Receipt Acknowledged- - ................ ~ Date: DISTRIBUTION; NSK Drilling RECEIVED JAN ! 2 ],0,,-10 ~State of A aska(+sepia) :~ Alaska 0il ~ (3as Cons, C0mmissi~ Anchorage ARCO Alaska, Inc. Date: October 18, 1989 Transmittal #: 7577 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO-1152 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. ,.'2K-14 2" Dual Induction- SFL 10-6-89 3175-8188 2K-14 5" Dual Induction- SFL 10-6-89 3175-8188 ~2K-14 2" and 5" Raw FDC 10-6-89 7465-8162 ~ 2 K - 14 2" and 5" Porosity FDC 1 0 - 6 - 89 7465 - 81 62 ~ 2K-14 Cyberlook 10-6-89 7500-8150 Receipt Acknowledged: DISTRIBUTION: D&M Drilling ............................. Date: ~"~'--~~E~~ ~ -~/v OCTI~L[~ ~ // ;-~iaska 0il & Gas Cons. C0m~issi0r~ Fr Anchorage anzen ~(vendor package) An~ NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: October 18, 1989 Transmittal #: 7574 RETURN TO: ARCO Alaska, Inc. Attn: Brianna C. Knettle CPF-3 Engineering Aide ATO-1152 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. ~ 2K-11 2K-13 OH Edit Tape and Listing OH Edit Tape and Listing OH Edit Tape and Listing Please acknowledge receipt and return 9-18-89 #73482 9-29-89 #73498 10-6-89 #73509 Receipt Acknowledged: DISTRIBUTION: ~ /Alaska Oil & (~s Co~s. Commissio~ Craig Suchland State o"f-A-ffiska STATE OF ALASKA A~-~SKA OIL AND GAS CONSERVATION COMr' 'SION APPLICATION FOR SUNDRY AP --,'IOVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown X~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 4. Location of well at surface 94' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1228' FNL, 1452' FWL, Sec. 11, T10N, R8E, UM (approx) At effective depth 1271' FNL, 1227' FWL, Sec. 11, T10N, R8E, UM (approx) At total depth 1272' FNL, 1157', FWL, Sec. 11,T10N, R8E, UM /approxl 8202' feet 6630' feet Plugs (measured) None 12. Present well condition summary Total Depth: measured (approx) true vertical RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-14 feet 9. Permit number ~9-88 10. APl number 50-103-20112 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Effective depth: measured (approx) true vertical Casing Length Structural 8 0' Conductor Surface 31 38' Intermediate Production 81 1 6' Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 8063' feet 65 07' feet Size 16" · . 9 5/8" 7" Junk (measured) None Cemented 1000 Sx AS III & 500 Sx Class G 225 Sx Class G Measured depth 115' 31 73' 8146' (approx) True vertical depth 115' 2935' 6555' RECEIVED oct ! F lg Lg ,i: :, aste Oil & cons. commtsstm Anchorage 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. Estimated date for commencing operation October, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service 17. I here_by certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~t c~ ,..T, ~c.~ Title Area Drillincj Encjineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C. SMITH 10-/)-~fJ~ Commissioner IApproval No. ,, . ~'_,opy - Ih ., Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company g~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a wail is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3692 ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25588 AKL 2674 Title DRILLING State AK 2K-14 JWell no. Operator ARCO ARCO W I. 55.8533 Prior status ! a W.O. Spudded or W.O. begun JDate Hour SPUD J 10/01/89 01: 00 Date and depth as of 8:00 a.m. 10/01/89 (1) TD: 0'( 0 SUPV:TM 10/02/89 (2) TD: 3009'( 3009 SUPV:TM 10/03/89 (3) TD: 3185'( 176 SUPV:TM 10/04/89 (4) TD: 5544'( 2359 SUPV:TM 10/05/89 (5) TD: 7312'( 17681 SUPV:TM 10/06/89 ( 6) TD: 0' ( 0'~ SUPV: TM 10/07/89 ( 7) TD: 8202'( 8202] SUPV:CD Complete record for each day reposed DOYON 14 PU BHA MW: 0.0 VIS: 0 MOVE RIG FROM 2K-13, ACCEPT RIG 0300 HRS 10-1-89, NU DIVERTER SYSTEM, PU BEA, FUNCTION TEST DIVERTER SYSTEM DAILY:S19,000 CUM:$19,000 ETD:S19,000 EFC:$1,317,000 DRLG F/3009 MW: 9.2 VIS: 88 LD 6-3/4" DC, CONT. FUNCTION TEST DIVERTER SYSTEM, CIRC., DRILL F/115-3009 DAILY:S58,652 CUM:$77,652 ETD:S77,652 EFC:$1,317,000 TESTING BOPE 9-5/8"@ 3185' MW: 9.2 VIS: 58 DRLG F/3009-3185, CIRC, SHORT TRIP TO HEVI-WALL DP, CIRC, DROP SS, TOE, LD BHA, RU & RUN 80 JTS 9-5/8" CSG, WASH 50' TO BTM, CIRC, RU & CEMENT WITH 1000 SX ASIII FOLLOWED BY 500 SX CL G, GOOD RETURNS TILL END OF JOB, THEN PARTIAL RETURNS, BUMP PLUG, FLOATS HELD, LD LANDING JT, RD DOWELL, ND DIVERTER, DO TOP JOB, ASIII NEAR SURFACE, NU SPEEDHEAD, NU BOPE, TEST BOPE DAILY:S215,094 CUM:$292,746 ETD:S292,746 EFC:$1,317,000 DRLG F/5544 9-5/8"@ 3185' MW: 9.3 VIS: 36 INSTALL W/B, PU BEA, TIE, TAG FC @3090, TEST CSG TO 2000 PSI, DRILL FLOATS AND 10' NEW HOLE TO 3195, DISPLACE WATER TO 8.4 PPG MUD, PERFORM LEAKOFF TEST TO 12.5 PPG EMW (OK), DRLG F/3195-5544 DAILY:S65,791 CUM:$358,537 ETD:S358,537 EFC:$1,317,000 MU BHA W/RLL MWD 9-5/8"@ 3185' MW: 9.4 VIS: 33 DRLG F/5544-5768, REPAIR WASHPIPE ADAPTER & SWIVEL PACKING, DRLG F/5768-7312, CIRC, DROP SS, TOE TO CSG SHOE, CBU, PERFORM OE LOT TO 10.8 PPG EMW, TOE LD BHA, PU ROT. BHA W/RLL MWD DAILY:S82,375 CUM:$440,912 ETD:S440,912 EFC:$1,317,000 DRILLING @ 8157' 9-5/8"@ 3185' MW:10.3 VIS: 36 PU NEW BIT & BAROID RLL MWD TOOL. TIH & DRILL TO 8157' DAILY:S66,616 CUM:$507,528 ETD:S507,528 EFC:$1,317,000 POE LD DP 9-5/8"@ 3185' MW:10.3 VIS: 39 DRLG F/8157-8202, CIRC, 15 STD SHORT TRIP, CIRC, DROP SS, SPOT DIESEL PILL, RU SWS, LOG OPEN EOLE, RD SWS, TIH, REAM 8162-8202, CIRC, SPOT DIESEL, POE LDDP DAILY:S114,128 CUM:$621,656 ETD:S621,656 EFC:$1,317,000 The above is correct sFe°~ fp°r%~e%%erp~dsa~tio'n 1;,distributiOn.''''-'- JDate / ~ Drilling, Pages 86 and 87. AR3B-459-1 -D RECEIVED OCT l 1989 . ~iaska 0il & ~as Co~s, l;ommlssio.~:. Annhnmnn Number all dally well history forms consecutively as they are prepared for each well. jPage no. 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 ARCO ALASKA INC. Lease NORTH SLOPE Field or Unit KUPARUK RIVER UNIT ADL: 25588 AKL 2674 2K-14 Auth. or W.O. no. T t e AK3692 DRILLING Operator ARCO Accounting cost center code Slato AK IWell no. Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. A.R.Co. W.I. 55.8533 Date 10/01/89 Complete record for each day reported 10/08/89 ( 8) TD: 8202 PB: 8147 SUPV:CD Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data DOYON 14 Iotal number of wells (active or inactive) on thisI ost center prior to plugging and bandonment of this well our Prior status if a W,O, 01:00 RIG RELEASED 7"@ 8147' MW:10.3 NaC1 CONT. POH LDDP, PULL W/B, RU & RUN 203 JTS 7" CSG, CIRC, ATTEMPT TO RECIP., PACKING OFF, CIRC, RU DOWELL, TEST LINES, PUMP 10 BBL CHEMICAL WASH, 35 BBL SPACER 3000, 46 BBL CL G CEMENT, DISPLACED WITH 10.3 BRINE, PLUG WOULD NOT HOLD, NO CASING TEST, FLOATS HELD, ND BOPE, SET SLIPS ON 7", NU TBG SPOOL, TEST PACKOFF, RIG RELEASED 0430 10-8-89 DAILY:S218,763 CUM:$840,419 ETD:S840,419 EFC:$1,317,000 RECEIVED ocr 1989 ":iaska Oil,& Gas Cons. Commission, Anchorage - New TD PB Depth Date Kind o r g Type completion (single, dual, etc.) Off c a reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date I~,e For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. I DIvlNon of AtlantlcRIchfleldCompany uc~-~d-'U~ U'/:40 ID:DOYON RIG 14 TEL NO: 659-7693 ALASKA OIL AND GAS CONS£RV^TIOti COHbIISSlON 1~786 PO1 Gonerml housekeeping ~ Rig ~ l~esarve pit -. Rig le I Rep BOPE ETACK~ Annulet preven~eP Pipe rams BI(nd r~ml Choke line valves HCR valve K~11 11ne valves Check vetve :z®o,?_ ACCUHULATOR Full chargs pressure . PreJl after closure -.-: Pump tncr elo~ press ~00 pslg Full eherg¢ press attained mJn O. mSn , , i . ~_~ ~ ~.~L~Y AND FLOOR ~AF~Y VkLVE~ .. I.L , ..... i Upper Ke11~ .... I Lo.er keTly _.~ Ball type [ Inmtde BOP ~ Choke Number v~1ve~ ..... /~'-____ _ ....... . .......... _ .... Nu,~, ~,n~e,. ?_~_ ....... . ..... Hydr~ul t'eel ly operm~ed ~hoke ~T~S? R~SUkT_~_, ~ .--_-_- ..... _,_ _ Repair or repl~eemen~ of f~fled equipment ~o be m~de within · , i Il __~lg ............ ._ Orlg -- AOOCC e ,. Operato~ C,O0~ (~ev 03/17/89) August 16, 1989 Telecopy: (907)276-7542 Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2K- 14 ARCO AlaSka, Inc. Permit No. 89-88 Sur. Loc. 94'FNL, 94'FEL, Sec. 11, T10N, RSE, UPI. Btmhole Loc. 1380'FNL, ll30'FWL, Sec. 11, T10N, R8E, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 oi the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chai~n o~ Alaska Oil and Gas Conservauion Co~ission BY O~ER OF ~E CO~iSSION dlf Enclosure cc: Depart~nt of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill __ J lb. Type of Well Exploratory __ Stratigraphic Test ~ Development Oil ._X. Re-Entry ~ Deepen mI Service 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc, RKB 154. Pad 11~' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL2~.,<'~c$ ALK.,?.~,~. ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 94' FNL, 94' FEL, Sec. 11, T10N, R8E, UM Ku.Daruk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1320' FNL, 1320' FWL, Sec. 11, T10N, R8E, UM 2K-14 #U630610 At total depth 9. Approximate spud date Amount 1380' FNL, 1130' FWL, Sec 11, T10N~ R8E, UM 8-23-89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-9 8136' MD 1130' @ TD feet 185' at 1000' feet 2560 6499" TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1300'feet Maximum hole anc~le 44 ° Maximum surface 1657 ps~At total depth (TVD) 3379 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity/ of cement Hole Casin~ Weight Grade Couplin~ Length IVD TVD IVD TVD (include stac~e dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 1 15' 115' +200 CF 12.25 9.625 36.0# ~111~-55 BTC 3148' 35' 35' 3183' 2927' 1000 Sx AS III & ~'~ HF-ER¥ 450 Sx Class G 8.5 7" 26.0# J-55 BTC 8102' 34' 34' 8136' 6499' 200SxClassG ,,,, HF-ERV Top 500' above Kuparuk 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. Attachmenls Filing fee X~ Property plat __ BOP Sketch Drilling tluid program X~ Timevs depth plot __ Refraction analysis ,,, 21. I hereby certify that the foregoing is lrue and correct to the best of my knowledge Si~Ined ~ '~ ~ Title Area Drilling Engineer Date ~','/) ~' Commission Use Only Permit~n,be~,,~ I APl number I Approval date I See cover letter for 50-/o ,~- ,~..o//~ 08/].6/89 other re,iu~rements Conditions of approval Samples required ~Y e s-'~, N o Mud Icg required~ Ye s ~-,~'N o Hydrogen sulfide measures ~ Y e s ~ N o ~;)irectional survey required ~'Yes ~ N o Required working pressure for BOPE ~,,~2M; .~[.3 M; ~ 5 M; ~ 1 0 M' ~ 1 5 M L :',~~ by order of Approved by ( ~' ~' ,, Commissioner the commission Date Form 10-401 R~4-89 triplicate ARCO ALASKA, !no. Pad 2K, Wel I No' 14 Revised Proposal Kupar'uk Field, North Slope, Alaska 0 _ RKB ELEYATION~ ! 000. 2000 3000 _ 4000 _ 5000. 6000 _ ?'000 KOP TVD=13;00 TMD=1300 DEP=O B/ PERMAFROST TVD=1424 TMD=1424 DEP-4 g T/ UGNU SNDS TVD=154:3 TMD=1544 DEP=16 15 BUILD 3 DEO PER I O0 FT 21 k:27 T/ W SAK SNDS TVD=2159 TMD=2191 DEP=204 "~ 9 5/8 CS13 PT TVD=2927 TI'ID 318:3 DEP 824 17'3 TMD=3524 DEP=1061 "~ TVD=4540 TMD--541 9 DEP"2:37:3 AVERAGE ANGLE 43 E D G 5O MIN TARGET CNTR TVD 6292 TMD ?'848 DEP 4056 B/ KUP SNDS TVD=6:355 TMD=T9:36 DEP=4116 TD (LOG; PT) TVD=6499 TMD=81:36 DEP=4255 I I I I . 0 1 000 2000 :3000 4000 5000 VERTICAL SECTION HOR I ZONT ^L PROJECT I ON SCALE ! IN. = 1000 FEET TAROET LOCAT!ON ~ 1320' FILL. 1320' FWL SEC. 11. TION. R8E TD LOCATION' 1380' FNL. !!30' FWL SEC-!!. T!ON. RSE ARCO ALASKA. !ne. Pad 2K, Well No, 14 Revised Proposal Kuparuk Field, North Slope, Alaska 1 000 1000 2000 _ 3000 _ WEST-EAST 5000 4000 3000 2000 I I I TARGET CENTER TVD~292 TMD=7848 I)E:P=44)~ SOUTH I~ WEST 3866 1000 0 I I S 72 DEG 24 MI N W 4056' (TO TARGET) 1000 I SLH~FACE LOCATION' 94' FNL, 94' FEL SEC- II. TION. RSE 300 250 200 1 50 1 O0 50 0 50 1 O0 50 _ O ~ 100 I I I I I I I I I 100 _ I I 150 I 200 _ 3OO I 250 1000 ~'"'" 1 000 ~ --'Tsoo I 200 800 t 1 000 / / ! ~4oo / / 150 I 100 I I I 100 100 _ 5O _0 _ 5O _ 100 _ 150 _ 200 DRILLING FLUID PROGRAM (2K-14) Spud to 9-5/8" Drill out to Weight up surface casino weight up to TD -- Density 8.8-9.0 8.7-9.2 10.0 PV 15-30 5-15 1 1-16 YP 20-40 8-12 8-12 Viscosity 70-80 35-40 35-50 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-1 5 10- 20 6 pH 9- 1 0 9.5-10.5 9.0-10.5 % Solids 10 +/- 4-7 12-15 Drilling Fluid System' - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and 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 using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-14 is 2K-9. This well is 185' away at 1000' which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. OEGASSER MUD CLEANER SHALE STI STIR STIR SHAKERS TYPICAL MUD SYSTEM SCHEMATIC EJ i i 6 5 4 3 2 l DI~ #1 13-5/8' 5000 PSI R~ BOP STACK _ I. 16' - 2000 1:"3I ~. I1'- ~~I X I~'-~~I ~~~ 4. 1~/8' - ~ KILL 7. )~8~ - ~~I ACCLMJLATCR CAPACITY T~ST I. C}-ECt( ~ FILL ACOJM,LATOR RESERVOIR TO PRO:~R LEVEL WITH HYDRALLIC FLUID. 2. ~ THAT ACCLM.LATCR PRESSLI~ IS ~X)C) PSI WITH 1500 P~I DCIt~iSTRF_4M CF T~ REGLLATOR, :5. CI~SERVE TII~F,, TFEN ~ AL/. UNZ'P3 SIMJLTAI~EOUSLY AN:) RE~ THE TII~ AN3 PRESSURE EEIvRINING AFTER ALL UNITS /kqE CZ.I:~.D WITH O,IARGZNG ~ CFF. 4. RE~ ON ~ REPORT. ~ ~ABL.E LCI~R LIM/T IS 45 SE~ CLOSlI~ TII~ AI~ 1200 PSI REMRINZNG I~,-'-5/8" BOP STACK TEST I. FILL BCP STAO( AI~ CHCK~ MtNZFOLD WITH ~IC D/E~ 2. ~ ~T ~L L~ ~~ IN ~~ ~LY ~T~ ~T TEST ~ ]N ~ V~S ~ ~ ~ ~ ~ 4. ~~ ~TO~~] ~~F~ I0~ ~ ~~ TO~~X ~~~ I0~ ~ED ~~ TO 0 ~. ~ KI~ ~ ~ ~ ~ TO~~] ~~~] ~ IN~4. 7. ~I~ ~1~ ~ V~~ LI~ ~ ~S ~ A ~ ~[ L~~~~] H)~ ~5T ~ IN 8. Cl:rcN TC~ PIPE RAh~ AN) CLOSE 801'TOB PIPE TEST BOTTOM PIPE RAIv~ TO 250 PSl ~ ~ PSI. 9. CI:EN BOTTOM PIPE RAHS, BAa( OUT ~NG JT AJ~D I0, CLOSE BLIND RAMS ~ TEST TO 250 PSI AN) PSI. II. CI:~N BLII~D RA/v~ ~ RETRIEVE TEST PLU~ )4~KE ~FCLD AN~ LII~.S ARE FLU. CF ~ING FLUID. SET ALL VALVES IN DRILLING POSITI~ 12. TEST STAFZ3~IPE VALVE-q, IdYll yo KELLY CCXCX~ DRILL PIPE SAFELY VALVE° AI~ liPIDE B~ TO 2~43 PSI ~X30 PSl. FORM, SIGN, AI~ ~ TO DRILLING kf. EKLY THE]~AFTER FLNCTICNALLY OPERATE ~ C~ I KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC .I L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTRO~!FD TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat- 2K Pad /~/ (Wells 1 - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM' hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & Gas Cons. Cornmissiml Anchorage GRU13/010 AflCO AI`1sN~, Inc. is ,1 Subsidiary o! All`1nl cFI ch! eldC,m~p`1n¥ o ~-J' WELLS 1-12 ARE LOCATED IN ~' ; SECTION 2 T. ~0 N., R. 8 E., ss ~ $' ~. UMIAT MERIDIAN. WELLS 13-24 ARE ~CATED IN . .~ " UMIAT MERIDIAN. ~THIS ~URV~ tie .-- II ~ 12 7 ~ , m~RACTED~ VI~I~ITY MAP I"= Imi~ I ..ts SECTION CORNER ~tes: ~ , ~ I. CO0~INATES ARE ~SE ZONE 4. . ~SECTION II II=19 I SECTION fa ~. ALL DISTANC~ SHOWN ARE TRUE. " , ~t ~ 3, ELEVATIONS ARE B.P.M,S.L. tZ:zS I MONUMENTS PER ~NSBURY & A~OClATES. / DEC 1 ~ 1988 ~.~."e'erence, ~9, o~ ~ oo.F~uO .oo~: u .~-~,.~. Well ,Y ASP's 'x' ~lns¥.SUit & ~.3~ Cd't,:~. ~[cdo~ Disf ' Dlst. O.G." I ~d ~ ' ~M~I ~NGITUDE F.S.L. EEL. ~ Elev. Elev._ I 5,9~8,600.18 4~8,310.17 70°14'36.519" 150°00~49.135'' '2~6'" 94' 114.0 ' "il8.5 4 5~938~5~5.4G 498~310.OG 70014. 55.784" 150o00'49.136" , 2~' 113.8 : 5 i 5 938,500.19 498 310.1Z ~ 70 °14, 35. 536 " 150°00'a9.134 I I 9 ~',. I I 3 ' 8 6 ~ 5'938'475'!4 498'310'33 ~ 70014,35'289'' 150000'49.1~8" 17 113'8 7 5,938,450'36 498,310'36 7001 35'046" 150000'49'!Z~'' 146' ~ 113'8 4' ' i 8 5~938,425'30 498~310'18 ~ 70014,34'799'' 150000~49'138'' 121 113'8 I 9 5~938~400'30 498~309.98 ~ 7001 34'55~'' i 150000'49'137'' 96' , 113'8 I0 5,938,375'19 498,310'!4 70014'34'~06'' [150000'49'133'' ~ 71' 113'9 ' I I 5~938~350.22 498~310'14 ~ 70O14' 34'061 " 150000'49'133" 46' I ~ 113'9 12 5~938~325'20 498~310'17 70014'33.815'' 150000~49.131'' ' 21~ ; 94~ 113'9 ~ 118'5 ! ' FN.L. 13 5,958,235.31 498,310.37 70° 14' 32.930" 15o°0o'49.1~5'' 69' 94' 113.7 ~ 118.5 14 5,938,210.14 i 498,310.16 7o °14' 3~.683'' 1500 00' 49.131" 94'_ 113.7 15 5,938,185.1z 498,31o 16 70o14'32.437" 150°00'49.131" 119' 113.8 I ii I 16 ! 5,938,160.11 . 498,310.20 70°14'32.191 il50°00 49.130" ~44' 113.8 I II I , ~ 17 5,938~ 135.21 498,310.18 70°14'31.946 150°00 49.130" 169' i 113.9 i 19 5,938,085.20 ~ 498~310.27 70°1w 31.454" 150°00'49.127'' 21~ ~ 114.0 ' i 20 5,938,060.14 498,310.~2 70°!4'31.207'' 150° 00'49.128'' 244' ! 114.1 '~ 21 5,9 38,035.16 498,310.16 70°14' 30.96Z'' 150°00'49.130'' 269' 114.0 , , 4' ~ 114.0 ~ 5" I Z4 5~937,9~0. Z9 49~ 310.0~ 70°14'30.~Z 150~00'49.13~" j 344'... 9 113.9 11~.5 J~ I HEREBY CERTIFY THAT I Am ~~.'""'. J PROPERLY REGISTERED AND LICENSED ~." ~'''%~ "-" '-" AnCO AbSk , TO PRACTICE LAND SURVEYING IN THE~--~TH~ ~ ~.~ ~~~ ~,~ ~ C. STATE OF ALASKA AND THAT THIS po..,... ................... ~ " ' BY ME OR UNDER MY DIRECT SUPER- · DRILL SITE Z.K viSION AND THAT ALL DIMENSIONS i.~.. ' .'~ CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT~ .. ~-6~9 ~,,, , ,~l , dj J ,,, ,~ m ii J ,,, '1' ' ,,~' , ,,, , , ,, , Wel ASp's Alas¥,a uit & C,~.~ Gut'is. c;0~ ,,-~;;;;v:: Dist Dist. O.G." Pod N~ 'y' ,X, L/~MID, I~ LONGITUDE F.S.L. EEL. Elev. Elev. ,,, I 5,938,600.18 498,310.17 70°14'36.519" 150°00'49.133'' '2c~6''' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70°14' 36.273" 150 °00'49.130'' 271' J 113.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150 °00'49.128" 246' 113.8 4 5,938,52_5.46 498,310.06 70o14' 35.784" 150°00'49. 136'' 222' 113.8 5 5,938,500.19 498,310.1Z 70°14' 35.536" 150°00'49.134'' 196' 113.8 6 5,938,475.14 498,310.33 70o14' 35.289" 150°00'49.128" 171' 113.8 7 5,938,450.36 498,310.3G 70°14'35.046'' 150°00'49.127'' 146' 113.8 4' ' i 8 5,938,425.30 498,310.18 70°14,34.799" 150°00'49.132'' 121 113.8 9 5,938,400.30 498,309.98 70° 14, 34.553" 150°00'49.137'' 96' ~ 113.8 I0 5,938,375.19 498,310.14 70°! 34.306" 150o00' 49.133" 71' 113.9 I I 5,938,350.22 498,310.14 70°14'34.061 " 150°00'49.133'' 46' I 113.9 12 5,938,325.20 498,310.17 70°14'33.815" 150 °00' 49. 131'' 21' 94' 113.9 118.5 ! EN.L. 13 5,938,235.31 498,310.37 70° 14' 32.930" 15o o0o' 49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 i 498,310.16 70o14'32.683" 150o 00' 49.131" 94' 113.7 15 5,938,185.12 498,31o.16 7o Ol4' 37_..437'' 150o 00'49.131" 119' 113.8 16 5,938,160.11 . 498,310.20 7OOl4' 32. 191'' 150o 0o' 49. 130'' ~44' 113.8 17 5,938, 135.21 498,31o.18 70o14' 31.946" 150ooo'49.130" 169' 113.9 18 5,938,110.19 498,31o.29 70Ol4'31.700" 150o00'49.127'' 194' 114.o 19 5,938,085.20 ! 498,31o.27 70014' 31.454" 150o0o'49.127" 219' 114.o 20 5,938,060.14 498,310.z2 70o!4' 31.207'' 150oo0'49.128" 244' 114.1 21 5,938,035.16 498,310.16 7oo 14' 30.962'' 150° o0'49. 130'' 269' 114.o 22 5,938,01o.4o , 498,3~o.19 70°14'30.718'' 150°00'49.129" ?.941 94' 114.o 23 5,937,985.3zt 498,310.13 70Ol4'3o. 471'' 150o00'49.130'' 319' 95' 114.0 'r , 5 It 24 5t937,960.29 498 310.08 70°14'30.22 150°00'49.132" 344'... 9 I 113.9 118.5 5' Company CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE YES (1)' Fee ~C ~7~./~? 1. Is the permit fee attached .......................................... (2) Loc ~~--~--~-~-~ 8~~_~ 2. Is well to be located in a defined pool ............................. _ "' 3. Is well located proper distance from property line ..... 4. Is we~.l located proper distance from other wells ....... 5. Is suz~iCient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ... 7. Is operator the only affected party .................... ~.~ ~-?~-~9 8. Can permit be approved before fifteen-day wait .......... (8) (3) Admin~_.f~ ~/~'~. 9. Does operator have a bond in force .................................. (9 thru 13) 10. Is a conservation order needed ...................................... ~_ ~,~7~./x'~: g~.~'%~ 11. Is administrative approval needed ................................... ~ ~_ (I0 and 13) 12. Is the lease number appropriate ..................................... ~_ 13 Does the well have a unique name and number ......................... (4) Casg ~~.~ ~./z./-~ (14 thru 22) 14. Is conductor string provided ........................................ 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 16.:,Is enough cement used to circulate on conductor and surface ......... 17'~ Will cement tie in surface and intermediate or production strings ... 18. 19. 20. 21. 22. 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 ............................ Lease & Well No. ~ NO 23. 24. 25. 26. 27. 28. (~3 thru ~8) Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate /~ Are necessary diagrams and descriptions of diverter and BOPE attached. '~. Does BOPE have sufficient pressure rating - Test to ~ ~D psig .. ~ Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ii (6) OTHER (29 thru 31) (6) Add: ~,___~~ Geology ..' En~ineerin~: .cs ~ C~ ~ ~iii ~~ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. (NOTE: ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 89/10/17 ORIGIN OF DATA: MWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 89/10/17 ORIGIN OF DATA: 2K14 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** JCJ OFILHED ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 2K14.DAT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 89/10/17 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRA RLL AAPI 0 0 0 0 1 4 0 1 68 GRB RLL AAPI 0 0 0 0 1 4 0 1 68 GRC RLL AAPI 0 0 0 0 1 4 0 1 68 NFO RLL CTS 0 0 0 0 1 4 0 1 68 NFl RLL CTS 0 0 0 0 1 4 0 1 68 NN0 RLL CTS 0 0 0 0 1 4 0 1 68 NN1 RLL CTS 0 0 0 0 1 4 0 1 68 EWR RLL OHMM 0 0 0 0 1 4 0 1 68 ROP RLL FT/H 0 0 0 0 ! 4 0 1 68 FXE RLL HOUR 0 0 0 0 1 4 0 1 68 GRCC RLL API 0 0 0 0 1 4 0 1 68 CAL RLL INCH 0 0 0 0 1 4 0 1 68 DRHO RLL G/C3 0 0 0 0 1 4 0 1 68 NPS RLL P. U. 0 0 0 0 1 4 0 1 68 RHOB RLL G/C3 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS ~ TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT GRA RLL GRB RLL GRC RLL NF0 RLL NFl RLL NN0 RLL NN1 RLL EWR RLL ROP RLL FXE RLL GRCC RLL LOG TYP CLS MOD NO, LVL CODE FT 0 0 0 0 ..1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 CAL DRHO NPS RHOB RLL RLL RLL RLL INCH G/C3 P.U. G/C3 68 68 68 68 ** DATA VERIFICATION (every DEPT GRA GRB NN1 EWR ROP NPS RHOB 100 FT) GRC FXE 715 -99 -99 0.000 9.250 9.250 -99 -99 -99 9.250 -999.250 9.250 -999.250 9.250 -999.250 -999.250 720 -99 -99 0.000 9.250 9.250 -99 -99 -99 9.250 -999.250 9.250 -999.250 9.250 -999.250 -999.250 730 239 4 0.000 6.797 3.408 13 7.597 146.292 3.271 -999.250 2.036 141.945 -999.250 740 290 3 0.000 5.372 6.165 14 9.024 149.013 3.243 50.977 2.426 149.018 1.096 7500 2406 41 .000 108.238 96.360 .109 2.708 62.603 .882 2.560 102.299 .914 7600 2360 48 .000 .757 .665 96.825 95.828 1.652 67.792 2.431 96.327 .844 7700 2991 30 .000 .602 .721 75.848 64.064 4.920 30.913 2.506 69.956 .847 7800 2930 31 .000 .859 .530 55.163 58.778 7.870 80.133 2.359 56.970 .746 790 269 3 0.000 6.842 9.167 81.561 85.136 3.476 49.424 2.474 83.348 .969 800 246 4 0.000 2.434 6.769 82.757 74.969 2.624 51.977 2.431 78.863 .949 8100 2559 39 .0O0 .798 .925 80.517 89.690 2.648 45.167 2.569 85.103 1.128 8200 -999 -999 .00O .250 .250 -999.250 -999.250 -999.250 42.105 -999.250 -999.250 -999.250 8300.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 154 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 2K14.DAT SERVICE NAME: RLL VERSION #: V 2.40 NFO GRCC -999.250 -999.250 -999.250 -999.250 700.852 170.334 838.719 178.822 710.357 122.759 597.854 115.592 677.990 83.947 710.728 68.364 651.976 100.018 619.679 94.636 657.818 102.124 -999.250 -999.250 -999.250 -999.250 7150.00 TO NFl CAL -999.250 -999.250 -999.250 -999.250 705.682 9.410 859.416 8.690 696.346 9.240 611.474 8.690 678.260 8.630 702.082 8.590 647.832 8.780 646.526 8.700 682.007 8.920 -999.250 8.500 -999.250 -999.250 8300.00 FT NN0 DRHO -999.250 -999.250 -999.250 -999.250 2432.130 .008 2950.789 -.007 2435.082 -.002 2277.334 -.018 2986.010 .012 2913.066 -.013 2639.476 -.016 2483.500 -.006 2536.808 -.003 -999.250 .000 -999.250 -999.250 DATE: 89/10/17 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 89/10/17 ORIGIN OF DATA: 2K14 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 89/10/17 ORIGIN OF DATA: MWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT bis Tar>,e verification I.,istj~lq $cblu{~berger AlasKa Co.~putirtg Center 11-(.)CT-1989 2(;):23 ib}C.,F. UPAR[JK,2A - 14,50'103'20112 **;*. TAP~: HEADEi{ DATF: : 89 i011.1 TgP~. MANE; : 735()9 ,II}OS TAPE CDM.~EN : A~Ct} ALASKA, 114,50-103-20112 FILE NAME : EDIT .001 5ERV'tCE iD.A T ~ : 89/ !AX REC SIZE : 1024 hAST FII~E PAGE: ihiC, LF)CA2ION: g'l' F't':t, & 94' FEI: I:C.G ~.iEASURLD F'~((.t~',; kgLi 15,.i A!.StJ!/i5 RANGE: 8E I 1-OCT-I989 20:23 PAGE: i)F: 153' LOGGED 8202' C~SI'ag 1.' 9 5/E" 47 bB fa DRILLER DEPTH OF 371,73' 4,07 ~ 65 3.27 ~ 65 LOGGIi'~G DIfT~ICT: WITNESS: u. ~ARaER bOgEN/DIXON DIS-EC 1131 PGS-I{B 508 I~:~-aD 1347 OlC-DA 417 PCC-OA 1041 6GC-OC 262~ 5bM-BC 1338 FIEI,D REb, ANKS: I 1/2" STNAt)OFFS AND A 2' HOLE FINDER USED ON THE blb. ~ATRiX DEX&ITY : 2.65 G/CC., FLUID DENSITY : 1.0 G/CC, aEI]TRO~ MATRIX : SAND, l!obg C08RECTION : CALIPER, DATE JOB STIaTE!); il-OCT-a9 jOB REFERENCe!; hO: 73b09 bDPtA~,tA: R. ****************************************************************************** FILE - KDIT.O01 "~,!AI;.~ Pi~SS bOG DATA" tDAI:A SAt"~.P[,ED EVERY -.5()ilo FEET 'I DO!, E X TE;'~51 ['~ r'~ TU(]L bis TaF, e 'Verii:lcation I..,istlF~q 6chlu~ber~er AlasK. a Computinq Center 11-0CT-1989 20:23 PAGE: 3 IABL[ 1Yi, E : CON~ CN ARCO AbAaKA, INC, ~'L 94' ?'N~ a 94' TOw~ 10~. COU~ NO~TH 5LOPE 8TAT AbASKA LATI ~iTN bOgEN/DIXON PDAT £PD FT L~F APO FT 154, LDF FT 153, EGI, FT 11~. TDC Vt ~202. Field bocation Section ownstlip ange County state or Province ation ~atitude Longituae Engineer's Name ~itiless's name Service ~rder Number Permanent datum bog ~easured From Time Clrculatioh Stopped Time Logger At Bottop~ m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm# UFP'T t.)~',PTH CHANr,;~:I.: NA~g lid ]. 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E 666- 'lI(]~dg.. bt~]r'lslq uo!:.'leo!.J-f./oA ode£ LIS ~ape Schlu!aberger AlasKa CompLltincj Center i I,.OCT-1989 20:23 18 -999,2b0 11~!~}, O I ~ -999:,250 -999'250 TENS, [)I£~ -999.250 . . 250 G~aFDC '999 -999'250 CALl FDC 1999,2~0 RFb'~D,FD~ -999 ;250 RCNT. C~L -999.250 RCFT,CNL :999 ~.~. ~:o ~.c~h -~9~.~o ~,~,~8.c,~ 999 205; oo0 250 ' ~' "F )' END FILE F,!A~ME Eul ,uol 5ERV 1C~ ~ FhlC VERS~Oi'~ : O01A02 : 89/10/:11 DATE .... l~' "z' N~X aEC S .... ZE : 102i ;'I " ' ;' : LIST FiLE : ,~¢** FILE BEADEF, FILE NA~E : EDIT ,O02 8ERV ICE : FLI'C VERSIOi~ : O01A02 PATE : 89/10/1 MAX aEC &IZE : 1024 L3ST FILE * FILE - FDI'I'.002 , "HIGh RESL]bUIIJJi~ PASS" * [.}ATA Sgt,~t'lo~D EVERY -.lOgO FEET , L.}ATA I~'~CLI,IDEi) - * T O (.31 E: X I' E i~ S I O H T u O b * TYPE USED NAMZ , * FDC .F[)H F(3R~ATIC]~ bEaSiT~ * C [.II-Al !J/i-t .C~k COaPe;NSAI'E~ Tape Yeri~lca[ion t,Jistisg $ChlU~nberqer AlasKa Co~:PutiDq Center i 1-0CT-1989 20:23 PAGE: 19 VA1,U D~ I ~ ~;;'''''''''any Na~e ......... ARC[) ALASKA, laC O- 12, t f: APl Serial Number b: 103'201 94' FNb & 94 ,r ;b Field Location i ! ~ec~ion 10~ roWnshi, p 8E ~ange ~O~TH SLOPE] County or Province ~Sb~S~A ongltu e Englnee{'s Name witness s'name b4~'/40 ~ Lo~ ~easure~ From 15~, 15~, 153, 113, ~202, 40. TYPE : COR~ DFPT DEPT[{ CHAi'~NEI,, NAME DPhI Density Porosity i~OB Bulk Density DRNO Delta rho FFDC Far FOC Count Rate ,~FDC Near F[JC Coopt kate RNFD Raw ~.,~ear YDC Count Rate RFFD Raw Far FDC Count Rate Ct, L] Cali~er (;~ Gamr, a Ray TE~S Tensl on 7~NPh THFiR~A[.~ NF;UIRUN PUROSITY ~q ~ R RAW 7 riEt~'~ AL F LIS Taoe verifica[ion Listinr.~ $chlu~berqer AlasKa Computinq Center 20:23 PAGE: 2O 8PECIFICAT:IO~ RECORD SE'!' TYPE: TYPE ~EPR 1 6~ 0 2 6~ 0 3 73 ~ 6t~ 1 5 6~ ~ 73 7 65 8 6g 0~099 9 65 F~ 11 12 68 1,3 6o 14 65 FT lb 6o 16 66 0 6{) I SET TYPE - CHiN DMDER ~ b{JG 'FYPf:: I)EPT FT 54~ / 4:0 uO 000 O0 L', P [-: l FDH pi.', 548740 OO ~{Jl{ Fi.)}t G/C3 5~,8'140 O0 000 O0 DRH[) FL:,tt G/C3 548740 O0 000 O0 FFDC gbh CPS 5~'7~o O0 000 O0 o i~FOC FDr~ CFb 5~8 '/40 uo OOC, O0 5NFD f" i~ B CPS 548740 O0 GO0 ~f'D FDH CFb 5q~'140 O0 000 uO CgbI FOB J.N 548't40 G~ F DH t;~Pl 548740 NPhl CNH pl., 5q8740 O0 000 0 L MB NUMB SIZE REPR PR CPi6 I.) NUM~8 6AMP AhEM COD£ (HEX) Z 1 1 4 u8 O000oOO000 2 1 1 4 o8 0000000000 2 ! 1 4 68 0000060000 2 1. 1 4 68 0000000000 ~ 1 i 4 08 UOOUOOUO00 2 1 1 4 08 0000000000 2 I 1 4 08 0000000000 2 1 1 ~ 68 O0000OO000 2 1 I 4 b~ o000000000 2 I 1 4 ~8 0000000000 2 1 i 4 08 UOOO00000O 2 1 I 4 68 OOOO000000 bis Tare veriilcaticn~.~ l.~istino. ~ ~cbl~m~erqer Alaska Computin~ Center 11-0CT-1989 20.23 PAGE: 21. TNRA CNE 5~}~740 RTNR Ct~F 548740 R C NT C t~: $ C F ~ 54 ~ '740 ~ C Fq)Chh CP6 5%B740 CN'rC CNB CPS 5q8740 *.* DATA D EPT, 8206, b99 ~FDC.FDH 948,000 N~ DC,F'DH CA' FDH '7, ~(,~q GR,FD~ [!j'NP;~, CNH 40,1 I 4 TNRA RCN~ [i~H 1.983,302 RC GP'C;<~W 112 6~B TENS CNt~: 24,721 784;500 RNFD, fi OH 1.!2,6~8 TENS, ~:DH ' 3,392 RTNR. CNH 534,'/29 CNTC,CNa 585,000 12,3/2 RHO~.FUH 6~b. OOO RNFD.FDa 94.000 TLN6,FDa 3,405 RTNR,CN~ 520,b92 C~TC.CNh 4332.000 009.500 RNFD,FDa 9b,003 TENS,FDH 3,549 RTNR,CNa 441,5'71 CNTC,CNn 13,1M7 RfiOD.FDM 609,500 RNFi),FDn 90.125 3'ENS,FOn 3,1U4 RTNR.CNfi 52'!,8~7 CNTC.CNtt 4288°000 2,242 ORM[,FDH 1520;'000 RFFD'FDH lb8~,O()O NPHI,CNH , ,b57 NPG[{~CNH 2024,141 CF/C,Cii~ 2,242 ORHO.FDH lb20,oo0 ~F~ .[O~ 2834,o00 NPHI,CNH 2024.14! CF~C.CNH 2,qq6 D~MU,FDH 1217,U00 RFFI.).FDH 4332°000 NPhI CNH 3.]33 NP~R:CaB 1995,07'I CFI'C,CNH 2.402 DRHO,FDH 1368,000 RFFD,FDM 40q4,000 NPHI,C~H 4 000 1846:134 CFTC,CNH 2,432 DRHO,FDM 120'!,000 RFFD,FDH 428B,000 NPHI,C~H 3.13~ NPOW,C~H 2129.9bl CFIC,CNh 0 08'7 1930 000 42 286 40 llq 606,980 0 087 1930 000 42 286 40 !14 606 980 0,054 1070,000 41,275 ~1,218 b03,932 0,065 12~3,000 43'88~ 42,225 538,289 0,031 9B6,500 35,054 36,566 b8i,974 LIS Ta[~e ?er/t/cat.ion Listinq $chtutr~berqer AlasKa Computil'~O Center 20:23 PAGE: 22¸ 0 ~: P'T. ? 700.000 [)'P H i. F i) ~ FFDC, FDH 49 '150 NFDC, FD.n ~NPB,CNa 2 939 I,.RA, "' RC'~TiCf~H 262 ~920 ....... RC~'".,...CNi~ . ,,. *~ ~ GR. CiX~ 6~, 25 T~NS,CNH DE:PT,t;. "t6OO,O00 DFH~,Fb~i FFOC. '[7:H 7141500 CAhI,FDH 9 07~ G~,FI)h RCN~ 'CNN 1O9b,~20 RCF'I;. CN~ GE~CNH 70 g'13 ' ~ . .rENo i C N h DBPT. CAbI .FOB 7500. u ('! 0 I:) P M ~ 42, ~S5 1695. ~20 RCFg'. CFtc! 13~, 250 TENS 11712~40 DRHO,FOH O00RFFD"FDH 4(t10'000 2570. b61 C~C.CN'H 2,34! ~RHO.FDH 1315.0(:)0 FFDiFD}I ~ 000 NPHIeCNh ]b8 :"111 NPOR'CNH 1721,~1 CFTC.CNH 151 033 RHUB, FDH b22 500 RNa'D, f'Dn 1.36 250 TENS. Fi)h 3 '1~6 RTN~,CNH 431 802 CNTC,CNM 3620. 000 2.435 DRHO.FDH 1.2Ob,gOO RFFD,FDH 3~21..)*000 NPHI.C~'H 4,300 ~POR,CNH 1820.081 CFTC.CNM i4,304 6mi'500 RNFD,FDfi l~'l,2bO 3.6~3 RTNR,C~ 475,2t2 CNTC,C~n 3710.000 0,039 1o02;5oo ~25,3~9 23,00~ 0.018 1013~000 ,567 472,043 0.041 0,041 1148,000 44 03 540,704 ** EhL~ OF DATA **** FILE TRAILER FII.,F NANE : EDII .002 SE~V i. CE : F~IC VFRSI(]N : O01A02 D ~ T E'; : 89/10/11 ~'~AX RE:C SIZ~ : lO2'i ~'ILE T~PE : I..O L~$7 FiLE : LIS Tape verlflcat, iot, $chium~er%~er AlasKa Computing Center 11-0CT-1989 20:,23 PAGE: 23 o EVICE NAiL ; EDIT t) ~I'F : 89/10/11 r)-~EViOtjS TAPE : - I4t50-103-201!2 ~,..~VtCE ah~E , E~II DAT~7 ; 89/10/11 ORIGIN : f'hlC REEI~ ~,~'A~E : 73509 C[: N~I N U,A [ iON PREVIOiJS REEL CO~i~ENT : ARCO AbASK~, !kC,,EUPARtJE,2t', - 14,50-i03-20t12