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200-074
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-217A KUPARUK RIV U TABS 2T-217A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-217A 50-103-20334-01-00 200-074-0 W SPT 3007 2000740 1500 1500 1500 1500 1500 4YRTST P Adam Earl 6/21/2025 MIT-IA (monobore well) 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TABS 2T-217A Inspection Date: Tubing OA Packer Depth 510 2300 2220 2210IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625075951 BBL Pumped:2.8 BBL Returned:2.6 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T -217A KUPARUK RIV U TABS 2T -217A Sre: Inspector Reviewed By i/� P.I. Supry 03> Comm Well Name KUPARUK RN U TABS 2T -217A API Well Number 50-103-20334-01-00 Inspector Name: Brian Bixby Permit Number: 200-074-0 Inspection Date: 6/18/2021 Insp Num: mitBDB210619073610 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T -217A Type Inj W TVD p II 3007-li Tubing 884 884 884 - 886 PTD 2000740 T e Test Test psi -- SPT lsoo IA 2ao 1s10 � 17so -� 17ao BBL Pumped: 2.7 BBL Returned: 2.7 OA Interval i'I 4YRTST IP/F P Notes: Monobore Completion (no OA) V Tuesday, June 22, 2021 Page I of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,August 10,2017 P.I.Supervisor C l 'b Zil 17 SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA,INC. 2T-2I7A FROM: Chuck Scheve KUPARUK RIV U TABS 2T-217A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TABS 2T-217A API Well Number 50-103-20334-01-00 Inspector Name: Chuck Scheve Permit Number: 200-074-0 Inspection Date: 8/7/2017 Insp Num: mitCS170808073544 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-217A • Type Inj TVD 3007 - Tubing 794 - 796 - 798 • 800 - PTD 2000740 Type Test EilTest psi 1500 IA 140 1930 1910- 1905 - BBL Pumped: 2.8 • BBL Returned: 2.8 - OA Interval 4YRTST P/F P Notes: SCAINNEt r'Ei3 2 3 2;? ;x Thursday,August 10,2017 Page 1 of 1 • • • /Cl ZT—Z I!A Regg, James B (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Riff 6l'7((7 Sent: Wednesday,June 7, 2017 9:44 AM To: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); Regg,James B (DOA); DOA AOGCC Prudhoe Bay Subject: Recent MIT's performed at KRU Attachments: MIT KRU 2T PAD pg 1 06-05-17.xlsx; MIT KRU 2T PAD pg 2 06-05-17.xlsx; MIT KRU 2T-210 and 217 Non witnessed 06-05-17.xlsx Attached are the test forms of the recent MIT's performed at KRU. Please let me know if you have any questions. Brent Rogers/ Kelly Lyons _ &J-c evt NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. C L42e( Desk Phone (907) 659-7224 Cell Phone (907) 394-0402 AZELLS TEAM ConoaPhelips SEWS . 1 4 Z'U17 •o • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recloalalaska.gov AOGCC.Inspectorsaalaska.clov. phoebe.brooksCa alaska.gov chris.wallace0alaska.aov OPERATOR: ConocoPhillips Alaska Inc, e"--) 60/17 FIELD/UNIT/PAD: Kuparuk/KRU/2T Pad <r'f DATE: 06/05/17 OPERATOR REP: Phillips/Duffy AOGCC REP: Well 2T-210 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982030 Type Inj N Tubing 550 650 640 640 Type Test P Packer TVD 3009 BBL Pump 0.4 IA 260 2000 1940 1930 Interval 4 Test psi 1500 BBL Return 0,6 OA 350 575 550 550 Result P Notes: AOGCC inspector Lou Laubenstein waived right to witness Well 2T-217A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000740- Type Inj N ' Tubing 100 100 100 100 Type Test P Packer TVD 3007 - BBL Pump 7.6 - IA 0 1890 , 1820 - 1790 . Interval 4 Test psi 1500 - BBL Return 7.7 - OA N/A N/A N/A N/A Result P Notes: AOGCC inspector Lou Laubenstein waived right to witness ***single casing well*** Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE!NJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 2T-210 and 217 Non witnessed 06-05-17 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ,.~_~)- __O~_~' Well History File Identifier Organization {done) [] Two-Sided RESCAN .[2 ~lor items: v Grayscale items: [] Poor Quality Originals: Other: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: /7/ NOTES: ORGANIZED BY: BEVERLY BRE~SHERYL MARIA LOWELL Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BRE~SHERYL MARIA LOWELL Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VINCE~¢ MARIA LOWELL RESCANNEDBY: BEVERLY BRE~HERYL MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 70' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~y~~ M ~® ~~~ ~, E1 2010 Alaska ~ & Gas Cis. Carrxnission Rr-ctmrage aoo-o7`t aT~ a.19A Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRL7). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water~from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped July 11`t', 12~', 13~' 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor i ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 2t_ ~N von Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2T-22 50103202240000 1950860 8" n/a 8" n/a 3.8 7/12/2010 2l T23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010 2T-27A 50103202170100 2090900 7" Na 7" Na 1.7 7/12/2010 2T-32 50103202180000 1950490 36" n/a 36" Na 11.9 7/12/2010 2T-37 50103202270000 1951010 22" n/a 22" Na 2.5 7/11/2010 2T-38A 50103202290100 1972050 8" Na 8" Na 1.7 7/11/2010 2T-203 50103205200000 2051970 22" n/a 22" Na 5.1 7/13/2010 2T 208 50103205180000 2051870 13" Na 15" n/a 2.5 7/13/2010 2T-210 50103202730000 1982030 18" Na 18" n/a 5.1 7/12/2010 2T-217A 50103203340100 2000740 B" Na 8" n/a 1.T 7/12/2010 3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010 • MEMORANDUM To: Jim Regg / / P.I. Supervisor ~~ 1oI r ~'l~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-217A KUPARUK RIV U TABS 2T-217A Src: Inspector NON-CONFIDENTIAL Reviewed By: r P.I. Suprv Comm Well Name: KUPARUK RIV U TABS 2T-217A API Well Number: 50-103-20334-O1-00 Insp Num: mitJJ090608131313 Permit Number: 200-074-0 ~ Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 6/1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ zr-z17A YP J - T e In , w 'I'uD T 3006 Well i IA aoo 1700 _ 16ao ]620 - _ P.T.DT 2ooo7ao ~TYPeTest1s TP Test psi ]soo OA i __ Interval aYRTST p~ P ' _Tubing loco ~ __ loso __ ]oso ]060 Notes: 2.4 BBLS diesel pumped,. I monobore well inspected; no exceptions noted. .,,4,- ~~ '~r f}r~ ,.~ ~ i.f ~`: .2 3;T ,'... ~1 via Wednesday, June 10, 2009 Page 1 of 1 Page 1 of 1 • Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Wednesday, August 20, 20081:50 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K; Osborn, Louise Subject: RE: KRU 2T-217A (200-074) -Again Attachments: 2T-217A wellbore sketch 8-20-08.pdf Tom, As we discussed on phone this morning, the following 404 clarifications/corrections are: Effective Depth (PBTD}: 7700' MD, 3179' ND Plugs: Sand plug in OH 7700'-8190' MD, 3179'-3414' ND Junk: Fish obstructing completion in SC-1 R packer @ 7260' MD, 3032' ND 38' eline PPROF toolstring in screens below fish @ 7260' MD I've also attached an updated well sketch for better visualization. Please let me know if you need anything further. Jim Ennis jj.ennis@conocophillips.com (907)265-1544 (UV) (907)632-7281 (C) ~i~~ aUG ~ 2o0s From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 19, 2008 5:51 PM To: Ennis, J J Subject: KRU 2T-217A (200-074) -Again Jim, I was further reviewing the 404 you submitted. I am curious why the effec#ive depth is given as 4662' and and 2437' tvd? It would appear that the effective depth would be whatever shoe/float is on the bottom of the screens. Have a look and get back to me. Thanks, Tom Maunder, PE AOGCC 8/20/2008 C 2T-217A following Injection Conversion Current Wellbore 16" csg @ 121' 3.875" `DB' nipple @ 522' 4.5" tbg 7" `ZXP' liner packer @ 4815' ~ Window for 7" 4997'-5007' 9 5/8" csg @ 6214' 'CMD' sliding sleeve w/ 3.813"`DB'@7107' Premier pkr @ 7164' 3.75" `DB' nipple @ 7250' `SC-1 R' pkr @ 7260' b0 7" csg @ 7368' Top of screens 7418' 4" 12/20 Prepacked Screens Btm of screens 7643' 4° Liner @ 7695' Obstruction in completion, eline toolstring below 00 00 a~ o 0 o°oo o °o Plug @ 7700'-8190' Jim Ennis Driller's TD 8190' 8-20-08 Page 1 of 2 • Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Tuesday, August 19, 2008 8:36 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: 2T-217A (200-074) Tom, r: The plan is to purchase the lost eline toolstring & continue to inject into the Tabasco. The potential small benefit of eliminating the lower Tabasco injection for improved vertical sweep has been lost but the water injection is still necessary. Jim Ennis j j.ennis@conocophillips.com (907)285-1544 (VV) (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 19, 2008 8:14 AM To: Ennis, J J Cc: Regg, James B (DOA) Subject: RE: 2T-217A (200-074) Jim, Sharon did include the wireline work (IPROF) and fishing conducted from the end of April -early July. What is planned for the well now due to the lost fish? Tom Maunder, PE AOGCC From: Ennis, J J [mailto:J.J.Ennis@conocophitlips.com] Sent: Tuesday, August 19, 2008 7:00 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: 2T-217A (200-074) Good morning Tom, The 404 was submitted after the proposed post-rig cementing of the lower Tabasco completion was cancelled due to a fish lodged in the completion above the screens. My intention was to submit the 404 following the cement work to alter the Tabasco injection interval as submitted with the 403. Attempting to remove the fish for this work dragged things out. If we did not include the post-rig well work performed in the 404 submission, 1'll have Sharon send it over today. Please let me know if any additional info needed. Jim Ennis j.ennis@conocophillips.com (907)265-1544 (V{~ (907)632-7281 (C) 8/19/2008 Page 2 of 2 • • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 18, 2008 5:30 PM To: Ennis, J J Cc: Regg, James B (DOA) Subject: 2T-217A (200-074) Jim, I am reviewing the 404 for the workover on this well to remove the ESP and run a packer completion and convert to injector. The rig work was completed December 17, 2007 and from the injection report it appears that the well was placed on water injection about March 11. Why was there such a delay in submitting the 404? This report should have been received before the end of January. Call or message with any questions. Tom Maunder, PE AOGCC 8/19/2008 • • a~o_ ~~y ~" C=3ANICAL INTEGRITY :PORT BUD u..:.: (?PER ~ FIELD CP I~~- ~\Z~ \ G,C'r :...c r,.:.i,,~ ~~ . - 3--a00~ hiLL ~Ur~ER ~T \ ~r LL DAT~_ TD : ~ ~~1~ .?~.. ~\~'`T'VI) ; .PBTD : ~~~V PID ?'VT) Casing ti~ Shoe . ~tID ~ TVD ; liV . N Q ?~ -"r'ZrZ} ~_:,e:. ~I~ Shoe. ~b ~'_' '~ ~\~~ T~TD; ;GP:~~?•~ '~J u~-='~ y~~a Packer ~~`~*1} T`J7i ~ Set a~ `~'a~~ ole S~~e 4s`(~_ anti ~ ~~~ PerZs ~ti\.~s" ~o ~~ . SC.C~cn~~ ~ r~~~4 ~z:'r.~?~IC~?, INTEGRITY - P?_RT #? rnnuius Press Test: _? a~s ~5 nin. a~ ?,0 min ~~((,~ Cor~ents : `~+~ ~ ~ ~ 1'~'D '~'CHI~NIC~i, ZI~TEGRIT~ -PART ~ 2 ~ `~ S ~~t~ Cenent Volumes r x~snt. Liner ~ ~ ; Cs~ .~~SS~. DV ~y Cnt Jol to cover per~s lS' \n~,` ~~ ~~~~~ ~~~~ C.G.Si~c Shoe .~~o' ~ 3~ ~,~ ~, ~ ~ - =eore tical TOC ~~°, ~0~~ ~,~ ~' ~g©~ `1 ~ C., ca, O~~c W~ ~~ Gement Bond Log (Yes or No)~~,5 Zn ~i~.DGCC File-~'~~_ CBL Evaluation, gone above perfs ~} ~ Production i,og: Ty-ve Evaluation GON~LJSI^"`' ?art #1: ?ar~ jam: ~~~(~-~~ • i~ ~~ STATE OF ALASKA ~ ~ ~ ~ ~~ r ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ ~t> ,' REPORT OF SUNDRY WELL OPERAT(Ot. ~a~ ~ ~ ~ ~- -' ~ ~ ~ ~~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ •~ -' ^ ~OPverttowater ~niection Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Welf ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number. COnoCOPhlllips Alaska, InC. Development ^ Exploratory ^ 200-074 / ~ 3. Address: Strati ra hic g p ^ Service / ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20334-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 35' 2T-217A ~ 8. Property Designation: 10. Field/Pool(s): ADL 25548,~ALK 2662 Kuparuk River Field /Tabasco Oil Pool 11. Present Well Condition Summary: Total Depth measured 8190' ~ feet true vertical 3414' ' feet Plugs (measured} Effective Depth measured --~~o~4~iQ 2r feet Junk (measured) ~1-~~~~~Ra~~ truevertical r '3t''1~ 2~' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 82' 16" 121' 121' SURFACE 6178` 9-5/8" 6214' 2880' PRODUCTION 2553' 7" 7368' 3064' Perforation depth: Measured depth: 7418'-7643' `SC~~C~C~~' t~V~;~C-~`3GL`~ true vertical depth: 3080'-3158' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7258' MD. Packers & SSSV (type & measured depth) pkr- BAKER PACKER pkr= 7164 Baker DB-6 nipple 522' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 7800 - 14. Attachments 15: Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of WeII Operations _X 16. Well Status after work: Oil^ Gas ^ WAG [] GINJ ^ WINJ 0 WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if G.O. Exempt 307-364 contact Jim nnis @ 265-1 544. Printed Name ~S Title Wells Group Engineer Signature ~ Phone: 265-1544 ~} q ' Date ` ~ a ~U - - Pre ared b haron A su Drake 263-4612 0 R f'f ^~~ A L S ~~~ AUG 2 4 2DDD ~/, Form 10-404 Re ised 04/2006 I Submit Original Only / tC, • Corto~oPhi[iips Time Log & Summary ~~;~~~ ~Q~ Re~o~;n9 Report Well Name: 2T-217 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/9/2007 5:30:00 AM Rig Release: 12/17/2007 5:00:00 PM -- - _ -- Time Logs _ .Date _ From To Dur S. Depth E Depth_ Phase Code 5ub_c_o_de T Comment __ 12/09/2007 2a hrsummarv Mob rig over well. Rig Accepted this date 9 Dec 2007 @ 0530 hrs, Flush IA & Tbg w/ hot seawater. Set BPV, ND Tree, NU ROPE & re for test. 00:00 05:30 5.50 8,190 8,190 MIRU MOVE DMOB P Pull off we112T-203, moving onto well 2T-217A. 05:30 07:00 1.50 8,190 8,190 MIRU RPCOM OTHR P RU lubricator, pull BPV. 07:00 08:00 1.00 8,190 8,190 MIRU RPCOM RURD P Spot trucks, RU lines and Little Red Svcs Hot Oil, 08:00 11:00 3.00 8,190 8,190 MIRU RPCOM CIRC P PJSM, pump 200 bbls heated / filtered seawater down IA for flush. Pump 8 bbls do tbg, pressured up to 2500 si. Annulus on vacuum. 11:00 12:00 1.00 8,190 8,190 MIRU RPCOM CIRC T Repeat pump attempt down tbg, attem t to dia nose roblem. 12:00 14:30 2.50 8,190 8,190 MIRU RPCOM P Able to pump at 1/2 bpm & 2000 psi do tbg, Pump total 90 bbls filtered seawater do tb .Well stable. 14:30 15:00 0.50 8,190 8,190 MIRU RPCOM RURD P RD and release hot oil svc trk. 15:00 17:00 2.00 8,190 8,190 MIRU RPCOM RURD P Spot crane, swap out ESP cable s ools on ri floor. 17:00 18:00 1.00 8,190 8,190 MIRU RPCOM RURD P Assemble / re-install ESP spooler uards. 18:00 18:30 0.50 8,190 8,190 MIRU RPCOM RURD P Install BPV. 18:30 20:00 1.50 8,190 8,190 MIRU RPCOM NUND P NDtree. 20:00 00:00 4.00 8,190 8,190 MIRU RPCOM NUND P Install blanking plug. NU BOPE. 12/10/2007 Test BOPE, OK, witness waived by AOGCC Field Inspector Bob Noble. Tested all 250/2500 psi. POOH w/ LD tbg & and spool up ESP cable. All cannon clamps accounted for. Missing (2) full and (1) partial 6' flat- uards, 7 SS su er bands, & 5.85" OD motor centralizer. 00:00 05:30 5.50 8,190 8,190 MIRU WELCTL BOPE P PJSM. Test BOPE 250 / 2500 psi. RD test equipment. Witnessing of test waived by Bob Noble, AOGCC Field Ins ector. 05:30 07:30 2.00 8,190 8,190 COMPZ RPCOM NUND P PJSM, Pull BPV, BOLD's, RU heat traces ool & sheave. 07:30 11:30 4.00 8,190 8,190 COMPZ RPCOM PULD P Unseat hanser, PU 85 klbs, Cont POOH w/ laying do 4 1/2" tbg and reeling ESP cable, heat trace and cap tube. Strap and seal tubing prior to unload f/ pipe-shed. ESP spooling reel malfunctionin . 11:30 12:00 0.50 8,190 8,190 COMPZ RPCOM WOP P Monitor well P~q~ 1 of 6 r Time Logs Date From To Dur _- S Depth E. th Phase Code -- Subcode T _ _ Comment 12:00 22:00 10.00 8,190 8,190 COMPZ RPCOM PULD P Cont POOH w/ laying do 4 1/2" tbg and reeling ESP cable. Strap and seal tubing prior to unload f/ i e-shed. 22:00 00:00 2.00 8,190 8,190 COMPZ RPCOM PULD P Break out and LD ESP. Noted 1 _ partial and 2 missing cable flat uards 7 ss su er bands. Centralizer missing from bottom of motor. 12/11/2007 Load 3 1/2" DP workstring in pipeshed, strap all. PU fishing BHA #1, RIH slowly rotate w/ pumping f/ 4648' - 4775' w/ no returns due to depletion. Tagged sand at 4700', had gas & diesel to surface, SD pumps, close annular, bleed out gas. Well dead. Resume operations w/intermittent stops to let gas break-out fall off. Wash w/fishin tool U 4775' w/ no returns. TOH. 00:00 03:00 3.00 8,190 8,190 COMPZ RPCOM PULD P Strap and prep pipe f/ removal f/ pipe-shed. Count cannon clamps and package f/ removal. , omm w/ En in Anch office Re: Fishin . 03:00 04:00 1.00 8,190 8,190 COMPZ RPCOM RURD P Clear /clean floor, RD spooling equipment and sheaves. Order out fishin tools & hand. 04:00 04:30 0.50 8,190 8,190 COMPZ FISH RURD P Set test lu to test 3 1/2" pipe rams prior to PU 3 1/2" DP workstring in re f/ fishin 'ob. 04:30 06:00 1.50 8,190 8,190 COMPZ FISH FISH P Test 3 1/2" UPR's t 250/2500 psi. 06:00 07:00 1.00 8,190 8,190 COMPZ FISH RURD P Load out ESP line clamps pulled from well. 07:00 10:30 3.50 8,190 8,190 COMPZ FISH PULD P Rack /tally 3-1/2 DP workstring to i eshed. 10:30 12:00 1.50 8,190 8,190 COMPZ FISH PULD P Load fish tools to pipe shed, strap / record inventory. MU fish BHA, RIH same. 12:00 16:00 4.00 8,190 8,190 COMPZ FISH TRIP P Flow check, follow BHA with 3-1/2 DP to 3675 ft. 16:00 17:30 1.50 8,190 8,190 COMPZ FISH PULD P Crane arrival, PJSM, remove ESP e ui from ri floor with crane. 17:30 19:30 2.00 8,190 8,190 COMPZ FISH WASH P Cont RIH w/ 3 1/2" DP f/ 3356' - 4648'. PU 74 klbs, SO 75 klbs, Rot Wt 65 klbs. Drop ball, RU Top Drv, start wash w/ pump @ 8 bpm. Wash f! 4648' - 4689'. No returns / no fluid surface. 19:30 20:30 1.00 8,190 8,190 COMPZ FISH CIRC P Noted diesel bubbling at surface w/ sudden increase. SD pumps, SI well, SICP 10 psi, SIDP 0 psi. Circulate out 1 bbl diesel, bleed off gas /air. Let well stabilize, no flow / press 0. Open annular, flow check no fluid visible at surface, prep to continue wash on fish. 20:30 22:00 1.50 8,190 8,190 COMPZ FISH WASH P Cont wash /fish f/ 4689' - 4775' @ 6.2 bpm & 3150 psi. Intermittant stops w/ reduced pump rates to let foamed diesel subside in wellbore. No returns w/ um in . 22:00 22:30 0.50 8,190 8,190 COMPZ FISH OTHR P Monitor well w/ prep floor for TOH w/ fish BHA #1. ~' ( 1 ~~~ ~ ~ PacJe 2 c?f 5 ~... ~~ • Time Logs Date From To Dur S. Depth E. De th Phase Code Subco__de T_ Comment ___ ____ 22:30 00:00 1.50 8,190 8,190 COMPZ FISH TRIP P POOH f/ 4775' - 33'. 12/12/2007 Retrieve fish f/ BHA #1. Load out BAH #1, order out tools for BHA #2. PU and RIH w/ BHA #2. Wash & Fish to to ravel ack liner 7256' MD. Achieve artial returns, circ out diesel and sand. Start TOH. 00:00 00:30 0.50 8,190 8,190 COMPZ FISH PULL P _Disassemble RCJB, have 5 ESP flat guards in fish. C/U equipment w/ call to Anch Office. Revise fishing program, order out different e ui ment. 00:30 04:00 3.50 8,190 8,190 COMPZ FISH WOEQ P Monitor well w/wait on fishing e ui ment. 04:00 04:30 0.50 8,190 8,190 COMPZ FISH PULD P Recd new fish eq, MU fish BHA #2. 04:30 06:00 1.50 8,190 8,190 COMPZ FISH TRIP P TIHw/fish BHA#2. 06:00 09:30 3.50 8,190 8,190 COMPZ FISH CIRC P Mix /pump Hi Vis pill. Spot at top 7" liner hgr. 3.5 bpm / 1040 psi. Immediate results with 10% returns. 09:30 11:00 1.50 8,190 8,190 COMPZ FISH TRIP P POH top of Hi Vis pill for soak. 11:00 13:30 2.50 8,190 8,190 COMPZ FISH OTHR P Test kill line while wait on pill saturation. 13:30 14:30 1.00 8,190 8,190 COMPZ FISH CIRC P Fill hole. 15.7 bbl to fill. Calc previous fluid level at 230 ft. Well static. 14:30 18:30 4.00 8,190 8,190 COMPZ FISH TRIP P Rotate / re-tip past resistance at 7" liner hgr. PU singles 3-1 /2 DP. Intermittent hang up at 7" connections. Work free, cont RIH singles 3-1/2 DP f/ TOL - 7254. T,a~c Top GP kr 7256' Drlrs Dpth. Intermittent dra intervals noted. 18:30 20:00 1.50 8,190 8,190 COMPZ FISH CIRC P Pump 260 bbls hi-vis w/ 4 ppg nut plug pill to allow circ and clean-up. o in ill. 20:00 20:30 0.50 8,190 8,190 COMPZ FISH OTHR P Blow do top drv w/ monitor well and prep t/ pull 10 stds to get above viscous pill w/ Fish BHA #2. Fluid level in well dro ed off uickf . 20:30 21:00 0.50 8,190 8,190 COMPZ FISH TRIP P POOH f/ 7256' - 6320' (10 stds). 21:00 22:30 1.50 8,190 8,190 COMPZ FISH CIRC P Circulate, talc fluid level at 542'. Achieved 70 % returns on hole fill, circulate out remaining diesel and small amt of sand debris. 22:30 23:00 0.50 8,190 8,190 COMPZ FISH OTHR P Blow do top drv w/ monitor well and prep f/ TOH w/ Fish BHA #2. Fluid level in well dro ed off uickl . 23:00 00:00 1.00 8,190 8,190 COMPZ FISH TRIP P POOH f/ 6320' - 3998'. PU 65klbs, SO 55klbs. 12/13!2007 RIH w/ clean-out assy. stack out on obstruction at 7260' (top of 4" gravel pack liner packer). POOH, PU LIB, RIH, set down f/ im ression, POOH. 00:00 04:00 4.00 8,190 8,190 COMPZ FISH TRIP P TOH w/fish BHA #2. Brk out and LD fishing tools. Recovered (1) piece cut-right f/ JB lip, 3 pieces stainless Lip of Rev Circ Jnk Bskt dama ed. Page 3 e~f 6 i Time-ter- -- - ------- Date From To Dur S De th E. De th Phase Code Subcode T Comment 04:00 06:00 2.00 8,190 8,190 COMPZ FISH WOEQ P W/O 2 7/8" PAC clean-out string & handling eq. Loading 4 1/2" cmpltn strip in i eshed w/wait on tools. 06:00 09:00 3.00 8,190 8,190 COMPZ RPCOM PULD P Rack and tally 4-1/2 tbg while WO PAC i e. 09:00 10:30 1.50 8,190 8,190 COMPZ WELCTL BOPE P Test rams (State Required) after shut in /circ gas / diese rpm we . es 250 / 2500 10 min. All tests successful, no re-tests. Witness waived Mr John Cris AOGCC. 10:30 13:00 2.50 8,190 8,190 COMPZ FISH TRIP P PJSM, load PAC pipe to pipe shed. Rack /tally / PU muleshoe /fish BHA #3. RIH 11 ~ts 2-7/8 PAC i e. 13:00 16:00 3.00 8,190 8,190 COMPZ FISH TRIP P Follow PAC with 3-1 /2 DP to tag at 7260 ft to of 4" h r 16:00 17:00 1.00 8,190 8,190 COMPZ FISH FISH P Attempt drift through 4" liner hgr. Multi le attem is turning, re-cio strip .Can not a h 17:00 18:00 1.00 8,190 8,190 COMPZ FISH OTHR P Flow check, 70% returns while circ. Shut do pump, blow down top drive. Column drop to 250 ft. (Confirmed by hole fill POH for im ression block. 18:00 21:00 3.00 8,190 8,190 COMPZ FISH TRIP P POOH w/ c/o string f/ 7260' - 374'. 21:00 22:30 1.50 8,190 8,190 COMPZ FISH PULD P LD BHA #3, noted indentations on end of mule-shoe indicative of junk. PJSM, PU BHA#4 w/ LIB for'unk ID. 22:30 00:00 1.50 8,190 8,190 COMPZ FISH TRIP P / 6HA#4 and LIB.on 3 1/2" DP workstring f/ 26'- 3512'. PU 65 klbs, SO 55 klbs. 12/14/2007 Hit obstruction w/ C/O string, RIH w/ mill BHA. Mill fish on top of SC1-R packer, finish clean-out GP screen to 7603'. POOH f/ acker run. 00:00 02:00 2.00 8,190 8,190 COMPZ FISH TRIP P 02:00 05:30 3.50 8,190 8,190 COMPZ FISH TRIP P POOH w/ LIB on 3 1/2" DP. Examine same f/ Ian forward. 05:30 07:30 2.00 8,190 8,190 COMPZ FISH PULD P PJSM, LD BHA #4 w/ LIB. PU and RIH w/ 3-3/8 mill ass BHA #5 . 07:30 10:00 2.50 8,190 8,190 COMPZ FISH TRIP P Flow check, follow BHA with 3-1/2 DP to tag at 7257 ft. Liner hgr at 7261 ft. 10:00 10:30 0.50 8,190 8,190 COMPZ FISH MILL P Commence miluunk rPCtrirtinn 7~F,7 - 7265 ft. 2 b mat 380 si. 10:30 13:00 2.50 8,190 8,190 COMPZ FISH MILL P Cont mill /wash 7261 - 7603 ft. Stuck in hole briefly at sliding sleeve at 7345 ft. Regain rotation / reciprocation. Work free. Wellbore free all other depths. 3bpm / 700 psi. 70% return. Gas 350 units max. 13:00 15:30 2.50 8,190 8,190 COMPZ FISH CIRC P CBU 3 bpm / 700 psi. Trace metal cuttings to shaker. Copt circ shaker clean. 15:30 16:00 0.50 8,190 8,190 COMPZ FISH TRIP P Flow check, column dropping. POH 3-1/2 DP for com letion. 16:00 21:00 5.00 8,190 8,190 COMPZ FISH TRIP P POOH w/ BHA #5, f/ 7603' - 371'. Page 4 of S Time Logs Date From To Dur S. De th E De th Phase Code Subcod_ e__ T Comment ______ 21:00 22:30 1.50 8,190 8,190 COMPZ FISH PULD P PJSM, LD BHA#5 22:30 23:00 0.50 8,190 8,190 COMPZ FISH PULD P Clear /Clean floor, load out fishing tools. 23:00 00:00 1.00 8,190 8,190 COMPZ RPCOM PULD P PJSM, RU t/ run packer and logging tools. Brin remainin tools to floor. 12/15/2007 Make up packer, seal assy, &SCMT logging tool. RIH w/ assy on DP and set w! WEG @ 7256. Premium Packer @ 7160', Top SBR @ 7129' Drlrs depth. Pressure test csg 2500 psi f/ 30 min, OK. POOH w/ run DP conve ed CBL. Lo f! 7129' - 4718 w/ ullin stds. Cont POOH la in down DP. 00:00 01:00 1.00 8,190 8,190 COMPZ RPCOM PULD P M/U assy below packer, discover flaw in ball & rod assy, Order out re lacement. 01:00 04:00 3.00 8,190 8,190 COMPZ RPCOM WOEQ P Cont load & strap tubing in pipeshed w/ wait on replacement damaged ball & rod ass . 04:00 06:00 2.00 8,190 8,190 COMPZ RPCOM PULD P MU Baker "Premier" 7 X 4-1/2 packer. MU Schlumberger SCMT tool, set timer and RIH same. 06:00 09:00 3.00 8,190 8,190 COMPZ RPCOM TRIP P Flow check, follow PKR assy with 3-1/2 DP to tag liner hgr at 7257 ft. U 95 K, Dn 53 K 09:00 10:30 1.50 8,190 8,190 COMPZ RPCOM PACK P PJSM, RU /set pkr as follows: press ,.~ _ DP to 3000 psi, annulus open, no bleed back. Slack off to 40 K. Build press to 4150 psi. Pkr sheared and set. Bleed to 1500 psi, pull 170 K, shear locator from PBR. Flow check, no flow back. Bleed to "0" psi. WEG @ 7259 ft, Top PKR AT 7161.9ft, To SBE 7130.3 ft Drlrs De th. 10:30 11:30 1.00 8,190 8,190 COMPZ RPCOM DHEO P PJSM, test 9-5/8 X 3-1/2 ann and PKR to 2500 psi / 30 min. Test successful, no re-tests. Pull run tool from PBR, flow check. 11:30 15:00 3.50 8,190 8,190 COMPZ EVALWE DLOG P Commence CBL / DP conveyed. Log up 7256 - 6045 ft. RIH 6045 - 7036 ft. Lo u 7036 - 4718 ft. 15:00 22:00 7.00 8,190 8,190 COMPZ RPCOM PULD P PJSM, POH laying do 3-1/2 DP for 4-1/2 com letion f/ 4718' - 50'. 22:00 23:00 1.00 8,190 8,190 COMPZ RPCOM PULD P PJSM, LD seal assembly & logging tool. 23:00 00:00 1.00 8,190 8,190 COMPZ RPCOM TRIP P PJSM, TIH w/ remaining stands of 3 1/2" DP. 12/16/2007 PU, RIH w/ seal assy on 4 1/2" IBT Tbg. Space out, MU Hanger, displace well t/ seawater, circulate until clean returns, um 150 bbls inhibited SW, um 225 bbls diesel freeze rotect. Let fluid balance. 00:00 03:00 3.00 8,190 8,190 COMPZ RPCOM PULD P RIH w! 3 1/2" DP Stands, POOH laying down and removing from i e-shed. 03:00 04:00 1.00 8,190 8,190 COMPZ RPCOM RURD P Clearfloor, RD DP handling e ui ment, RU to run tubin . 04:00 14:30 10.50 8,190 8,190 COMPZ RPCOM PULD P PJSM, PU and RIH with seal assembl on 4 1/2" IBT Tb . ~a~ ~ ~~ s • Time Logs_ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 16:00 1.50 8,190 8,190 COMPZ RPCOM HOSO P Tag PBR, sting in, confirm sting in PBR. Calculate space out. MU pups, tbg hgr, Idg jt /running tool. Sting in, land hgr simultaneously, confirm correct space out. Pull hgr to floor flor well dis lacement. 16:00 17:00 1.00 8,190 8,190 COMPZ RPCOM RURD P PJSM, RU for displacement. 17:00 00:00 7.00 8,190 8,190 COMPZ RPCOM FRZP P Close annular, commence displace IA with 150 bbls corrosion inhibited seawater. Follow with 215 bbls for freeze protect (2000 ft TVD). Equalize tbg X annulus, allow fluids to balance. 12/17/2007 Freeze protect well, Ptest tbg U 2500 psi f/ 15 min, OK, Ptest IA t/ 2500 psi f/ 30 min, OK. ND stack, NU tree, test tree U 5000 si, OK. Set BPV, secure well. Ri released at 1700 hrs, 17-Dec-2007. 00:00 01:00 1.00 8,190 8,190 COMPZ RPCOM FRZP P Allow fluids in IA / tbg to balance. 01:00 02:30 1.50 8,190 8,190 COMPZ RPCOM DHEQ P RD lines, land tbg hngr, RILDS, RU to test IA & Tb . 02:30 04:00 1.50 8,190 8,190 COMPZ RPCOM DHEQ P Test tbg, t/ 2746 psi, press loss 110 psi / 20 min, OK. Swap lines, test IA U 2610 si ress loss 90 psi / 30 min OK. Tested tbg against RHC Ball & Rod left in tbg below packer 7250 ft. 04:00 05:00 1.00 8,190 8,190 COMPZ RPCOM NUND P Set 2-way check. Nipple down BOP. Start cleaning pits and flushing rig lines. 05:00 07:00 2.00 8,190 8,190 COMPZ RPCOM RURD P R/D circ and test lines, set TWC, drain stack. 07:00 10:00 3.00 8,190 8,190 COMPZ RPCOM NUND P ND BOP, set back in cellar. 10:00 12:00 2.00 8,190 8,190 COMPZ RPCOM PULD P Load tree in cellar, NU same. 12:00 15:00 3.00 8,190 8,190 COMPZ RPCOM SFEQ P PJSM, NU tree, test tbg hgr void 5000 psi, OK, Test tree 5000 psi, OK. 15:00 16:00 1.00 8,190 8,190 COMPZ RPCOM RURD P Pull TWC, set BPV. 16:00 17:00 1.00 8,190 8,190 COMPZ RPCOM RURD P Secure, well, move off well. Rig released this date 1700 hrs. f~a{~~ 5 cs# 6 2T-217A Well Events Summary DATE SUMMARY 2/21/08 PULLED 4 1/2" RHC PLUG @ 7251' RKB, DRIFT TUBING W/ 20' OF 3" DD BAILER WITH PUMP ASST. @ 2 BPM TO 6650' SLM, STALLED OUT DUE TO DEVIATION. 3/25/08 MITIA (STATE WITTNESSED BY JOHN CRISP) -PASSED - 4/20/08 T-POT PASSED; T-PPPOT PASSED; LDS- FUNCTIONAL 4/24/08 PERFORMED AN INJECTION PROFILE 7% OF THE INJECTION IS EXITING THE SCREEN AT 7520' - 7530' THE REMAINING 93% IS EXITING OUT THE BOTTOM OF THE SCREEN ASSEMBLY SHUT IN INJECTION AND MADE COOL BACK TEMP PASSES AT 2,3 AND 4 HOURS TAGGED BOTTOM AT 7685' STUCK TOOL AT 7296', HAD TO PULL OUT OF WEAK POINT (TOOL AT 7258' TO 7296') 4/26/08 ATTEMPTED TAG FISH @ 7296' WITH 3" LIB. SAT DOWN DUE TO 81 DEG DEVATION @ 6773' WLM. IN PROGRESS. 4/27/08 LIB'd & ATTEMPTED FISH E-LINE TOOLS @ 7235' WLM. IN PROGRESS. 4/28/08 ATTEMPTED FISH E-LINE TOOLS AND OTHER DEBRIS @ 7235' WLM. IN PROGRESS. 4/29/08 ATTEMPTING TO CLEAN UP OR PASS DEBRIS @ PACKER @ 7260' RKB ,LIB SHOW DEBRIS MOVING UNABLE TO GRAB ,JOB IN PROGRESS 4/30/08 ATTEMPTING TO CLEAR OBSTRUCTION AT 7260' RKB, METAL DEBREE POSSABLE BANDING FROM WORK OVER INCONCLUSIVE MARKS ON LIBS AND UNABLE TO PULL OR MOVE OUT OF WAY TO FISH E-LINE TOOLS DOWN HOLE 5/12/08 RAN VIDEO LOG WITH EXPRO DOWNHOLE VIDEO CAMERA UTILIZING GAS LIFT GAS. OBSTRUCTION OBSERVED IN TOP OF BAKER SC1-R PACKER AT 7260'. 6/13!08 RUN 3.12 LIB AND GET IMPRESSION OF OBSTRUCTION @ 7232' SLM. (SEE PIC IN WELLFILE). JOB COMPLETE. 7/1/08 RIH WITH 3.1/8" VENTURRI BASKET, JARS, MHA, IMPACT TOOL - DOWN TO 7271'CTMD TAGGED FISH/DEBRIS. START PUMPING @ 2 BPM, CYCLED CT, TAGGED FISH NUMEROUS TIMES, HIT WITH DOWN JARS. COULD NOT MAKE ANY FOOTAGE, POOH TO INSPECT BHA. FOUND 4 SMALL PIECES OF METAL DEBRIS THAT DO NOT LOOK LIKE THE PIECES SEEN ON DH CAMERA. P/U DOWN HIPP TRIPPER, TAGGED @ 7271' CTMD, HIT ON FISH FOR 1.5 HRS STARTED TO MAKE FOOTAGE BUT HIPP TRIPPER STOPPED WORKING (7273.6'). POOH, MARKS ON BHA 2" ID & 2.5" OD. PERFECT TUBULAR SHAPE - RESTART IN AM. 7/2/08 RIH WITH 1.75" BHA DOWN TO 7272' CTMD. HARD TAG, POOH. P/U 2.80" LIB, TAGGED 7272.3' CTMD, IMPRESSION LOOKS LIKE METAL DEBRIS AND POSSIBLE 2.5" MIN. RESTRICTION. P/U 2.125" NOZZLE, HIPP-TRIPPER & JARS, TAGGED @ 7272' WORKED DOWN TO 7274.5' COULD NOT MAKE ANY FURTHER. POOH, FREEZE PROTECT WELL, NO MARKS ON BHA, RIG DOWN CTU. IMPACT TOOL HIPP TRIPPER (2000 - 4000#) DOWN WEIGHT ON BOTTOM. . , ~ KUP fsL 1i C®~COt"t fllil~'1S _ ~ Well At ~ r`Ufi a~~a. ~~1- ~ , API/UWI `rill (13203 canment 0-12~- sssv,szz~- TUBING, 0 sLeEVE. ].1v] SEAL. ],128 PRODUCTION.- 4.815-],%8 Screen, _ ],418-],643 TUBING 3 7,132.0 PBR Seal Polish Bore Receptacle _a. 7,163.6 PACKER Baker Premier Protl uction Packer 7,250.4 NIPPLE 1 3.75" "DB-6" Nipple w/ "RHC" plug hotly installed. 7,257J~WLEG ~ ~.~_., r_ u..t~ r-r..__ _ 41/2"Wireline Entry Guide ..._ c._~ _._ t 2T-217A WaII Status Maximum Inclination (°( TOtaI Depth (ftK8( IIINJ ( 81-15 8,190.0 _ !Annotati... Entl Date _ KBGrountl Distance (ft) I Rig Release Date I Last WO:I 12/15/2007 40.54 5/14/20_0.0 nation ~ (End Date Reason: FISH IN HOLE@ - 7272' CTMD ~ 7/28/2008 Top (ftK8) Sel Depth (ft... Set Depth (ND( (ft... WI (Ibs/... Grade Top Connectii i2 0.0 121.0 1210 62.58 H-00 WELDED Top (ftK8) Sa[ Dap[h (ft... Sat Depth (ND) (ft... Wt (Ibs/... Gratle Top Connectir 7 0.0 5,213.0 2,591.6 40.00 L-80 BTCM Top (ftK8) Set Depth (ft... Set Depth (ND) (ft... Wt (Ibs/... Gratle Top Gonnectir 1 4.815.0 7.368.0 3.063.9 26.00 L-80 BTCM 13.30 Com ant -HT Screen 5 1/8" x 3 GRAVEL PACK, ],260-],695 8,190 ~ .. ~~ ~yy ~g ~~ ~ NO. 4678 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 `~~'~,~~~~~ ~AY ~ ~ ~~Q$ Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 04!30!08 3K-102 NA PRODUCTION PROFILE 04/08/08 1 1 1 E-04 11996622 LDL ~ 't D - ~{ 04/16/08 1 1 2U-13 11996617 PRODUCTION PROFILE - a~ y 04/10/08 1 1 2W-17 11996618 SFRT - 04/12/08 1 1 2L-330 11970662 PERF/SBHP U 1 04/19/08 1 1 3F-18 11970666 LDL - G` 04/23!08 1 1 1D-130 11964595 LDL C ~_ 04/23/08 1 1 1Y-07 11964596 INJECTION PROFILE - ~ / 'a 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE /(o (~ 04/24/08 1 1 1 F-05 11964597 INJECTION PROFILE / ~^-~ 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE _ ( 04/26/08 1 1 iL-09 11970669 PRODUCTION PROFILE _ c( 04/26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • l MEMORANDUM Toy Jim Regg ~ P.I. Supervisor ~~y~j ~~q ~~~ FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 04, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA Rv'C 2T-217A KUPARU'K RIV U TABS 2T-217A Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv ~/'~ Comm Well Name: KUPARUK RN U TABS ZT-217A Insp Num: mitJCr080403123220 Rel Insp Num: API Well Number: 50-103-20334-O1-00 Permit Number: 200-074-0 ~ Inspector Name: John Crisp Inspection Date: 3i25iz0o8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2T-217A jType Inj. j W I TVD 3007 '~ IA ~ 750 2505 i 2472 ~ 2465 ~ - ~ P.T. i 2ooo7a~TypeTest ' sPT Test psi ', os o ~ OA ~ i ~ - -- , ~ _ . I Interval ~TAL P/F P iso3 ~ t5os ~ -~ Tubingj t4s7 ~ __ Istz Notes' Post workover converted to injector from producer. 1.5~~bgb~l~'sppggpumpedrf~olr test. {gyp ~~`ks11d~~ JUZ.. 3 ~i ~Da$ Friday, April 04, 2008 Page 1 of 1 12/20/07 al~~~m~~~r~ Schlumber er -DCS t'''•~~''~ ~~~. ~ ~ ~~4~ g ~~,~. 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth - ~ ~~~"~ Well Job # Log Description NO.4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~y Field: Kuparuk r],,~} ~' ~~ -1 Date BL Color CD 1J-105 11837540 INJECTION PROFILE ~''~~-(~-_ 11/20/07 1 1A-06 11837542 RST WFL '8'~ _I~~ ; 11/22/07 1 10-05 11837537 LDL C - ( 11117107 1 1B-12 11970607 INJECTION PROFILE v't' 12/04/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (0 12/15/07 1 1D-132 11994588 SBHP SURVEY ~'~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION = 12/13/07 1 3N-02A 11970609 LDL $ - 12/05107 1 1C-125 11964553 INJECTION PROFILE - 12101/07 1 2M-15 N/A PRODUCTION PROFILE ~ ~ " 12/10/07 1 2M-11 N/A PRODUCTION PROFILE '~q .- ( 12/08/07 1 3A-03B 11970604 SGMT ~ ''-f - ( 12/01107 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27107 1 2L-330 11837544 SONIC SCANNER 11127/07 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Monday, December 17, 2007 3:06 PM To: 'Ennis, J J` Subject: RE: 2T-217A (200-074) Conversion Jim, do remember our conversation and you are correct that I did request the sundry in order to get it "in the system". As noted, there is an exemption regarding 403s for production wells and strictly the work conducted so far has not needed a sundry. It would seem from where 1 sit that submitting the whole package as done here would save us both some paperwork and time. It appears that the overall time got compressed here. Key item is that you planned to get the SCMT during the workover regardless of having a sundry or not. Since the log information looks good, it would appear that you have verified cement isolation to proceed with the conversion plans. Call or message with any questions. Tom Maunder, PE AOGCC From: Ennis, 3 ] [mailto:).).Ennis@conocophiliips.com} Sent: Monday, December 17, 2007 2:50 PM To: Maunder, Thomas E (DOA} Subject: RE: 2T-227A (200-074} Conversion Tom, Zipped SCMT file attached for your use. {~~~~ ~~ ~ ~ HOC? This is the well we discussed if, in the unlikely event that SCMT data collection was compromised, apost- rig injection waterflow log would suffice for zonal isolation verification. As outlined at the time of our discussion, my plan was to gather this data and then submit a 403 for injection conversion post workover. I believe we agreed this would be appropriate for a production well prior to obtaining approved service well status. At your request, I submitted the 403 earlier than planned so that the regulatory review process for conversion could begin. I assumed, perhaps incorrectly, that proceeding with the production well workover was OK and 403 approval would allow post-rig screen perforating and cementing to achieve upper zone injection as well as water injection itself. Should I have omitted the rig procedure from the 403 and only submitted post-rig plans to modify the sandface completion? Jim Ennis % j.ennis@conocophfllips.com (907)265-1544 (YY) (907)632-7281(Cj From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov} Sent: Monday, December 17, 2007 2:00 PM To: Ennis, J J Subject: RE: 2T-217A (2Q0-074} Conversion Jim, Yes I have the viewer. Help me here. You applied for a sundry that proposed to clean-out the well and run tubing and a packer to convert the well to an injector. I finished my review of the cement items you sent forwarded the 12/17/2007 • • Page 2 of 2 sundry for approval this morning. Do I understand that the rig is already on the well and the workover has begun? While sundries are not needed to pull tubing on production wells, it would seem that if you have the described activities attached to the sundry that beginning activities would have waited for the return of that sundry. I look forward to your reply. Tom Maunder, PE AOGCC From: Ennis, 3 3 [manta:3J.Ennis@conocophillips.com} Sent: Monday, December 17, 2007 1:54 RM To: Maunder, Thomas E (DOA) Subject: RE: 2T-217A (200-074} Conversion Tom, We acquired the 7" csg SCMT log this weekend and bond looks good. Do you have the PDS viewer software for SLB logs? If so, I can forward the file for your viewing pleasure. Jim Ennis % f.ennis@conocophiliips.com (so7~2ss-1~ awl (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder a~afaska.gov] Sent: Thursday, December 13, 2007 11:18 AM To: Ennis, 3 3 Subject: 2T-2I7A (200-074} Conversion Jim, I am reviewing the sundry to convert this we{I. Earlier in the month you sent the cementing records. Could you provide information as to any Weil that lies within %. mile radius of the weft trajectory referenced to both the top and battam of the Tabasco reservoir? This includes iCuparuk and Tabasco we{is. An assessment of the cementing across the Tabasco reservoir in any identified wells will also be needed. Call or message with any questions. Tom Maunder, PE AOGCC 12117/2007 Page 1 of 1 Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocoph'rfGps.com} Sent: Friday, December 14, 2007 1:37 PM To: Maunder, Thomas E {DOA} Subject: 2T-217A {200-074} Conversion AOR Attachments: 2T-217A 4uarter mile offsets.xls; 2T-217 PAA morning report 5-14-200f~.pdf Tom, Attachment shows only two wells within the AOR. Both wells are Tabasco w/ 2T-217 being the P&A'd motherbore for 2T-217A & 2T-208 a recently drilled active horizonl:al producer. 2T-217 P&A details in attached morning report. Jim Ennis Wc~~;~~-i~S S'r~ ~~rcn'~~C~ 1~~ ~,SSv j.j.ennis@conocophillips.com (907)265-1544 office 4 (~ (907)632-7281 cell ~~~` v ~ ~ ~~ ` G ~ ~~i S P~c~.v~~ From: Maunder, Thomas E (~A) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 13, 2007 11:18 AM To: Ennis, ] ] ~~~ D E C ~. $ 2007 Subject: 2T-2llA {200-074} Conversion Jim, I am reviewing the sundry to convert this welt. Earlier in the month you sent the cementing records. Could you provide information as to any well that lies within %. mile radius of the weft trajectory referenced to moth the top and bottom of the Tabasco reservoir? This includes Kuparuk and Tabasco wells. An assessment of the cementing across the Tabasco reservoir in any identified wells wilt atso be needed. Call or message with any questions. Tam Maunder, PE AOGCC 12117/2007 Closest in POOL Closest A roach: Reference Wetl: 2T-217 A Offset Well: 2T-208 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-} View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + NV - 26.24° Comments De th Incl. An le TRUE Azi. TVD E + MI -~ 26.24° Comments in s nce (727.83 ft) in POOL m istance (727.63 ft) in POOL (7445 - 7985 MD) to 2T-208 (2976 - (7445 - 7985 MD) to 2T-217A (2976 - 727.63 7838.8 82.34 67.94 3124.56 5975930.8 1841434 5989.77 3028.8 TVDss) 7654 88.64 52.33 3028.487 5Q75284.5 1641754 5532.126 3028.8 TVDss) Closest A roach: Reference Well: 2T-217 A Offset Welt: 2T-217 it. -- d Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subaea N(+)/S(-) Vlew VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + /W . 28.24° Comments De th Incl. An le TRUE Azi. TVD E + /V1(- 26.24° Comments POOL Min Distance POOL Min Distance (1325.47 ft) in POOL (1325.47 ft) in POOL (7445 - 7985 MD) to 2T-217 (2842 - 3104 (7445 - 7985 MD) to 2T-217A (2842 - 1325.47 7460.04 70.17 82.36 2978.89 5975786.4 1641116 5899.87 TVDss) 6984.35 72.86 7.89 2974.12 5975963.6 1839802 5277.84 3104 TVDSS) • 2T-217A Quarter mile offsets.xls 12/17/2007 9:20 AM r~ ~~ j I -__ ~ ConocoPhillips We!/vlew Web Reporting Daily Drilling Page 1 of 2 Report Printed: 12!14/2007 Re rt Header Well: Report Date: ob T e: Network: Resort # Daiiv Cost: Cum Cost: 2T-217 05/14/2000 ROT -DRILLING 14 Field: TABASCO Rift Name: Nabors Alaska Drilling Nabors Rig Supervisor; FRED HERBERT RiS1 Accept: 4/21/200012:00:00 AM Rift Release: 613/200011:59:00 PM 24 hr Summary: Summary Caa Rat Time: RIH W/ CIBP 24 hr Forecast: CUT WINDOW FOR SIDETRACK Time L From To Duration Phase Code Subcode Time Aviv` 00:00 01:30 1.50 CMPLTN TRIP P POOH 20 stds. Well Flowing (breathing). RIH slow. 01:30 03:30 2.00 CMPLTN CIRC P Circ ~ even mud out @ 9.3+ ppg. Monitor weft 03:30 08:00 4.50 CMPLTN TRIP P POOH to shoe. Blow down lop Drive, Monitor well. Continue POOH. 08:00 09:30 1.50 CMPLTN PULD P UD BMA, Download LWD in#o. Clear floor of excess tools. 09:30 13:00 3.50 CMPLTN TRIP P M/U T Cement ret. &RIH 13:00 14:30 1.50 CMPLTN P PJSM. set cement ret. (~ 6880`. Rlg up tines. 14:30 15:30 1.00 CMPLTN P Sting into retainer. Test to 1000 psi / 5 min. on annulus. OK.PT lines to 2500 psi. EST. injection rate 2 b m w/ 700 si 15:30 16:30 1.00 CMPLTN CEMENT SQEZ P Pump 13 bbls 15.8 ppg Gass G cement, 5 bbls H2O & displace w/ rig. Sting intot ret. & squeeze 8 bbls cement. Pull out of retainer & lay 5 bbls cement on top of ret. 125' . 16:30 18:30 2.00 CMPLTN CIRC P Pull 3 stds to 6590'. Reverse out 2 DP volumes. Circ 1 volume ton wa .Add lubetex. 18:30 21:30 3.00 CMPLTN TRIP P POOH UD running tool. 21:30 23:30 2.00 CMPLTN TRIP P M/U 9.625"" casing scraper & RIH to 5093' 23:30 00:00 0.50 CMPLTN CIRC P Circ Bttms Up ~ 5093' - _ ~_~~.~ ___~_~___________-~ ~_.~ ______.~._____ ~~.__ _.____.,M...__ --- Page 1 of Z _.___.___~..._,__.__.__..~.__._.__.w._._~_,__.__,..___..__....~._.__.._.._.__.~ • Maunder, Thomas E (DOA) From: Ennis, J J [J.J.Ennis@conocophillips.comj Sent: Wednesday, Deceml~r 05, 2007 9:29 AM To: Maunder, Thomas E (DOA) Subject: RE: 2T-217A (200-074) Attachments: 2T 217A 9.625 inch csg cementing detaits.pdf Tom, Page 1 of 1 Requested surface csg cementing info attached for your viewing pleasure. I think I'll have the 403 we discussed put together today. Jim Ennis j.ennis@conocophillips.com (SOT)265-1544 (Ui~ (907)632-728? (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Tuesday, December 04, 2007 3:47 PM To: Ennis,) 3 Subject: 2T-217A (200-074) Jim, t have looked at the file for this weft. Sort of confusing on the name changes. What is not confusing is that these is very tittle cementing informafion in the files. Could you please send me copies of the cementing reports far the surface casing in the original welE and the 7" finer in the sidetrack. Thanks in advance. Calf or message with any questions. Tom Maunder, PE AOGCC 12f 13/2007 • Maunder, Thomas E (©OA) From: Ennis, J J [J.J.Ennis@conocophillips.com~ Sent: Wednesday, December 05, 2007 7:28 AM To: Maunder, Thomas E (DOA} Subject: RE: 2T-217A (200-074} Attachments: 2T-217A Liner cementing detaifs.PDF Good morning Tom, Page 1 of 1 7" liner cementing info we have attached. 9.625" casing must be in a different file, probably due to the well name maze. I'll send when in hand later this morning. Jim Ennis j.ennis@conocophiliipa.com (907)265-1544 (W) (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aCaska.gov] Sent: Tuesday, December 04, 2007 3:47 PM To: Ennis, 3 J Subject: 2T-2f7A (200-074) Jim, { have {poked at the file for this weft. Sort of confusing on the name changes. What is not confusing is that there "rs very little cementing information in the files. Could you please send me copies of the cementing reports far the surface casing in the original well and the 7" liner in the sidetrack. Thanks in advance. Celt or message with any questions. Tam Maunder, PE AOGCC 12/13/2007 ~~ ''11~` ARCO Alaska. inc. Cementing Details Well Name: 2T-E'MT ~/ RepOn Date: 05/20/2000 Report Number: 1 Ri Name: Nabors 16E AFC No.: AK0092 Feld: Ku ruk-Tabasco Casing Size Hole Diameter. Angle thru KAU: Shoe Depth: LC Depth: %washout: 7" 6.5 78 7368 7247 Centralizers. State type used, intervals tousled and sparing Comments: tspiragliderlt first 12 Jts, 1splraglldeU3 Jts to hanger. Mud- Weigh: PV(pdorcond): PV(aftercond): YP(priorcond): YP(aftercond): Comments. 9.9 16 14 20 18 Gels before: Gels after. Total Volume Ciroulated: 8/17 7/15 1000 Wasti 0' Ty~~ Volume: W~pM: 'Comments: ARCO Waah 20 8.4 Spacer 0- Type: Volume: Weight: Comments:_ ARCO Spacer 30 11 Lead Cement. 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: 'Comments: G 70 508 15.8 1.16 Additives: .2% D46, .3 % D65, .5% S1, A% D167 Tail Cement 0 Type: Mix wV temp: No. of Sacks: Weight: Yieltl: Comments: Additives: Cisplacement 0 Raie(betore tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: ' 6 6 145 Reciprocation length: Reciprocation speed: Str. Wt. Down: - 15 15 130 Theoretical Displacement Actual Displacement: Str. Wt. in mud: 143 ]43 Calculated top of cement : CP: Bumped plug: Foats held: 4816 Date:5/20/00 yes yes Time:05:45 Remarks:Cementingllne started leaking after pumping slurry and 16 bbl water in displacement. Finished displacement w/ rig pump Cement Company: Rig Contractor: Approved By: DS NABORS G.R. Whitlock • ~, ' ~~I~1~IY '~~.23 - Z'ab~~a~r .~ ~g ~ ~`e~~~t~~ Job Administration Data Client Client Rep. Well Name Field Name Rig Name Rig Contractor Contractor Rep. Serv. Location Dowell Engineer Dowell Phone Acq. Front End Start Date End Date S1R Number Description' Channels Description ARCO Alaska Inc Guv Whitlock 2T - Zl?a Kuparuk Nabors 16E Nabors Alaska Drilling Prudhoe Bay Curtis Thompson 907-659-2434 1 JAB/Hybrid RDA -1 Cement Unit 05/24/200015:48:02 05/26/2000 09:10:34 20160253/0548/0550/0614 Sand Plug ~-C'hannc~l ~~~~~~_ D~wcripteon N ~~ ~_~.~ i~liuimtine ~ 11.a~titum ~ ii.Tni t~1:11tI1JIL7(1T1 711L1C~ ~ HG 1111,Y IlIIJ(I 11111C }Ji:~r~L000 17.411 1. ~ i~.~r <<v ~~iJU ~9 t19-~= CumV~l Cumulative Volmne ~ 0 72.95 bbl j' Ih~nsity _NiSicri~mot~on DS304S N[iI~O to 15ppg j '-625 12 29 ppo Elapsed "Circe Elapsed Time I 0 53.02 miu i l~zssu~z IJ1 ' V~atran500 Prsssure'lransdu~er l-2(hnA 0-l j kpsi ' -367 3315 )ti5i TotFlowrate Totall~'lowrate 0 4.93$ Acquisition Data lcqui it~on Time ('urol'~~I - Dcuyit~' ~ Elbpsu~ Tttue~, ~ Pr~~ti2'E>11 ~ "T©tF1crW!t'ufe _ _ .~___ .~ ._ _.._.~_ ~ , _ _. _,. bFtvvx~es _v. ,,r2;,_ ~ . 1x ~~ - - S"I ~~t I AG'QUIS~ .'1C~N ., o~i2ailor,~~ is:as 05 : i~ s 31s o a>> 4s79 t) t p - 8~9a' o>tz4~?~woi~?~~as ~o. : s3ia x:456 ~4s7s" ?o 05/21,%10(N) 15 5O 07 ) 8.318 ~a)b9 3 i.9 0. fl5Y2~/2(H)(1 33":J1.OR 0. + 8.318 3,F06 4>79 r -'Q 05/14/3000 li51.~9 ~ ~ ~ Start Himpin~ Water t75/24l2f?~t ?5:52 t)tl - O.nO] 8348 ~ 4.1 f~ ??.SZ 0 05,%24/2000 IS53 09 0-428 8.31 ~ 5.1 l7 3663 L477 USF2G/2Ek10T>:5,1:12 _ '2,t4j ~ 8.31 ~ 6:l61 4029" iR27 U>L4/^000 15.55 V3 - - ~ Presswe Test L.IRCS 0?1231:Ot~l~;>5~12 -3.tJ01 ~ 8.31 7_t73 103 ~ 0. 03/24/2000 li S6 1 + 3.Oli ` 83 t 8. ] 87 1328 0 4i/14f20t)01557IS :3:.029 s 331 9.211 3"s 13 CL 05/24/2000 ] 5.38 17 ' ..3.23 ~ 831 1027 380. 1.438 05/24/2000 15.>9 17 _ _ - -Start (~eit Spsccr 05~24l20001>:5917 i 0.481 b 8288 II26 5±1.1 1.536 05i2~i2W0 16;00.00 ~ - - _ 'Shirt Sand ~ltmv 05/24/2000 16:(~ IR 0.966 ` 11?6 12.26 47 L6 1.78 05124/2000 16;05 iff -'3-~65 11.3? 13 ~. 7 480;8 2.78 '. osiza~2~ao 1~:oi 20 ~ 6.6nz °: t ~ _3s 14.3 ~ ~6i ~ x.78 ©>t24/20001E.0± 13 - 9_d95 1223 ~ 15.34 4G2.> 276 05/24/2000 16-0425 1239 ~ 12.19 76.39 412.1 2.76 05124l200016fl430 ;'- - - ~ "itartUelPSpac~~r U~12~4f2000 16:05.26 ~ - - - ' i Start I'umpina Water 0~/z=1C200416:0~?7 "1:70L 334T 17:41 384:6 2.7.x} , 0~/24/20t70 16:06 29 4.598 8.326 18.45 ~ 439 6 2.397 t)]~2$/2l)Ul~ 16:06 5~ - - - '. - ~.. ~G17C 3~tlllip3llg iV(J7[l. 0/24/2000 16:0'' ~9 = 8A 1~ 9 257 19 45 497 4 4 918 ~~. , ~ ; . 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T~ - 8'1 38 ~ 3 05125f20O(t0332:52 6I 47 ' 8344 - L046 -4579' 0: ~ : ~ OS/25/2000 03:18.31 + - ~ ;' - s S Wrt Ytunpaig Water ~ISJ25120f>[103a8 53 ;'.0382 ~ ~ 8344 20f9 fX I~' ^.216 X525/2040 0:19 54 1 974 8 X44 ~ O8] ]00 7 0. )5/25120t?0 03.20 26 - - ~ - - ~ - - ; Piessuce Teri Linas OS/25J2000 0320 56 1.995 ' 8.349 4.1 ] 2 2779 = 0.039 - I}5125120C10 Q3~2.t:i7 s,-;t 9gS R.3=19 5.126 54.95 ~ 0. ~ 05/25/2000 0322 57 =` 2.989 8.349 ~ 6135 4 L2.1 '! 1.944 O5/?5/200L? 03:2 i~3~ ~ ~ _ _ _ Start UclLSPacet ` OS/2512(3(~03:23'~9 0.956 ? 8.104 ~ 7.i58 :476.2 :2.702 051251200403'.2421 `'Siart 8andSturry 05l25/2000(1325OU i I.75> 11.81 8182 :4531 2799 OJ25120p(?iY326,02 4h63 :11.9 - ~ 22I- 526b' s.'3.20$ ~ 05/25/2000 0327'04 '. 8.276 ` ll 9 ~ 1024 ~ 485.3 3.227 OSYL5I2000t?328:04 , 11 52 11.3 l t'4 425.8 i 3?~ OSf25/2000 03 29 07 ~ 14.92 ~ 11.67 12.29 361.7 ~ 2.974 ~ ~ ' 051'?3/200t3 fl3':3b (19 17 87 11.87 1332 ~ 3~7 f' ~' 2 916 y OS/2i/2000 03:,1 (2 120.99 1 LJ8 ~ 14.37 ;-I3.~1 2 99d I ' {IS/Z_51'Z(>{)003~32:t2 2382 ]I'73 ~ 15.38 302:2 2294 05/25/2000 03:33 13 25.7s ` t LE,3 ~ 16.;9 228 9 2.216 O~i2512(l(,r}fl3;;z4.lfi ~ 27.72 ~ 1L139; 17,4-1 ls5_7, n' 1.5.36 ~ 05/25/2000 03:3422 ' - - 'Start Ge[1 Spacer (1~/?SI200(} V3;35~ 18 i _1 8~t1 8.Q8? 1848 2i L33' 2.197 t35I25i2Gt?0 03:35:25 - - - - - ~ i Start Runping Water 05I2312Q0(?03r3b-19 .-4665 ~ 8.364 195,... 5723. 38-t9 0>/25/2000 03:37 U 1 - - 'Start Runpine AAud ~ OJ/2512(HlUf~3`.37~19 €8.64? 9.P43 ~ 20.5:. 6fi$.5 _ 'i.4R5 ~ ~ 45/252000 03 38 22 ~ 12.95 .9.013 21.54 7E,4-7 4.199 05E`75!20O(1 i)3:39 22 I7.17 9 ~~4;- 2eSti 742_F i 4 18 r 05125/200003:4024 2L5 9.15 ' 23.?8 ~ 8059 4.199 k 0 5/23/2000 9 3:4127 ~ 25 8R ' 9:I5S 24.62 ~ 7g2-i 4 1S tJ5.725/2(KK) 03:42.30 ~ 30.27 ~ 9148 ~ 25.67 .783. 4.199 0~/2~l20(rii03:4~.32 > 3467 9,1ff8 ~ .26.72 774.4 ;'.4.199 O~i25'2000 03:44 34 3R y8 219fi 27.7:1 1778.1 ' 4.19` rt)5125f2fNK7(13:45 35 43 22 _ <I 19fi ~ "-28.75 '757:5. ~ 4.799 ; 105/2512000 03:4635 ~ 4245 ~ 9196 29.76 ~ 77f3 4 418 US/25/200003:47.i4 :51.91 92196 30,42 983- 4199 " 05/2512(HYO 03:48 40 i 56.17 :1196 31.84 7>55 4.199 OSf25t2000 43-4E.t.42 59 gt 9 201> 32.88. 425 R = 2 138' ._ 05%25,'2000 03:SU 43 G2.1 220> ±349 485.3 2.08 . 05/?SCZ000 03:53 4'i - 64 21 ~ 9 2f1~ 34 9 : <t8r)9 ; ~ 2 I " 05i2in{)~i03:5244 FG38 9.20; 35.92 480.8 ? 2.177 05i25120C3n 03:5:46 E,8 61 9 203 36.94 476,2 2 177 I' 4 05/25/2000 03:59 48 ) 70.84 9203 ~ 37.97 ` 471.6 2.177 ~Si2>",2000 03:5 49 ~2.3~6 9?(12 _s 9. 33A:3 ii l 108 O>~25iZ0000i 56>: I T_.95 9.Ofi9 4Q~J8 4.579 1 0. 05!2 512 0 00 0 3`57 57 72.95 9 l 12 41:13 3579- 0 05/25/2000 03:57.59 - ~ - - Shutdown fl5125r"Z{k~ 03:53 12 ~t - - - - STOR' AO~LJISI'i K)iv 05/25/2000 09:02 ~6 - ~ - ;START ACQUISITION OSl2~12000 J9:02.57 T' 95 -6 25 0. -3567 `0. _ 7Q -7~w7 1 05/25/2000 09:03:58 0. 8.3 1 1.01 1 ' 68.68 z 0. 05/25/2000 09:[14 00 _ _ _ _ - Starcl'urnpiug Water US/ti/2000 09:(11 ~8 0.791 :8349 2-013 351.7 L691 0512512f)00€i9:05,44 '= - _' _ I'lessureTc~tLines ; 05/25/2000 09:05 59 2.025 8349 ~ 3.021 77.&1 0. 05125/20x)0 09;9659 3.034. 4355 4-023 3 L7 !). OS/25/2W0 09 OR 00 2 039 8.356 ! 5.0;2 ~ 32.05 0. ' 0~125i_+")Ci0 09:09.01 ' 4.087.. 8356 6.061 5495 3188 05/25/2000 O~l(l9 16 - - ~, St<ui Dell Spacer 051?5/200009.40A1 ~' 2.269 ~ 8, [R8 7.07E 5T2:8 3.(69 05/25/2000 09:10 21 - Start Sand Slurry f)5/25121Xi0 t>yai,U4 2.244 12. ~~ .4.12. 340.3. ? 3.24f- 05/25/2000 09:12 J6 !' 5.561 ~ 12-03 9 148 5082 ~ 3.227 0~I25i20000951307 S.F.31 12:01" 1iL36 462-~ ~~ 3.091 05/25/2000 09 14 08 12.01 1 198 1 1.18 416.7 1 3 169 a • ,,, ;. AcQwvtrunTime Cum~ul ' Uens~~ 1!'lapcCJ knee Prev.cei~>L.1 ` lut~`lowretc - -- tiAe«.egcs ---- V.;l~Jrstt,~s v9:i ~ vb > f~ 2 i i i 9 r2. i6 ~ ~i5.] 3.i~b 05!2512000 09: ] 6 08 15.4 11.86 13. ] 8 :345. = 3. I fifl 05f2f200E104:17:11 =-~L72 ` 1L76>' ~ 1.22 - 311 4- 3.208 3 05/25/2000 09:18 12 ~ 25.02 1 1.9 '~ 15.25 ~ 348. 3.227 0 512 512 00(?f~9:19r14 ~ 28.(F9 - 1197; 1h.28 25G4 _ ?, 3.Oi3-,, ` OS/25/20000920~14 ~ 31.12 11.19 17.28 ;' 224.4 ~ 2.935 05(25/ZOOOQ9~.2~1 16 ~~ 33.81 ~ `1.547 1&';I 265.6 ~-2.022 " 05/25/2000 0I.2L27 - ', `Start Gc11 Spacr~r ' 03P25%2W(5U9'.2Z:16 'L41[ ~ .' 8374 ~ 932 ! 293 ''- °-2147 05/25/2000 09:22.42 - !,~ - Stari Pumping Water 05!'>5t200009;?^-^s:17 ~-d.24 ,<< ft3?9~ 2033 :~ 62?_3'~ 34.218 :, . 05125Y2000 09:24 Ol ? - ~ - ', - Start Pumping Mud 05125,l20C1fl94:24;i5 __8_S1 ~ 8.936 ~ 21'_35. 68b.8 ,4.199 OS/25/20000925~19 12.78 :~ 8.906 i 22.:37 746.3 ? 4.199 05f23/Z000 09:2620 , =1fi.4$ 8 SFi& 2337 773 3 ; `4.199 Y 05/25/2000 09:2720 21.23 9.135 24.39 ~ 787.5 4.199 a OSf2'SI2004 E]9:28.22 25 55 9 i 19 ' 25'.42 X69 2 4 I9g '. 05!25/2000 09.29 25 '~ 29.94 ~ 9-IC,> 2G dG ~ 769.2 ~ 4.18 USf25/2000 0430 37 34 24 9 i ti5 2TS 764 7 " ` 4 I9'3 ~ 05/25/2000 09:31:30 ,: 3569 9.173 2855 17f>0.1 ' 4.18 O~r~~f2000U932.31 42,91 9173 ?4:56 773_$ 4,IIt1 s 05/25/2000 0933 32 ; 47.15 ? 9.173 3057 ', 760.1 ~~ 4.18 5J2~J2060 09:34 33 ~ SL41 ~ g.IB 3159 ~ 773 $, ~ 4.1'}9 n5i25,'20iri)0935 34 55J1 ).(8 ', 32E 1 733. d 18 n5/25/200009:3$:37 '58.43 '` 9.I8 ~ 33-b6 444.1'- .'.::2.114 s OSl2~'20000937 ;' 60.35 ` 9.18 3467 384.6 I' 1264 i, ;OS/25,~OO110435,38 _5135 407d_ 35°67 t09_r), ~r0 ~. ! 0~/25/20(H)09:3940 ?6138 8.448 36.71 ~! 4.579 ~0 ` 0>/25(200009~:3~1 j8 - _ ~ Shutdo«m -; DS/2S/2000 09:401X1 ~ ~ - _ S1'(~Y hCQL7IS1"LION 03I2~t20001h: 338 = _ _ _ :START't1GQIJIfiITION '= 05/25/2000 16-13 ~I l 61 :5 625 0_ ~ -3567 ~ 0 '~]~ - 7Q ~O ' ty5I25f2C1f10 I6:33 57 - ~ " - - - ' - ~;, Start i'turiPnS Water-' 05/25/2090 16:14 11 1.391 8.349 LOf l 352.6 2.1 ~~5L2~/20/)IF ; 6x5.4 ~ ..:1..979 .8.349' 263 54:95 ` 0 05/25/2000 ]6:16 44 2.003 8349 3.053 2507 ', 0. '. OS~LSf200(YI5:I65t) ~ - - ';' Pra,tire `l~~t Lroes 05i.25i2U~~E) 16:17.x» : 2.0; l 8.349 4.1)61 96.15 0.60. 05JZSl2000 16r48~46 ;.4.639 4 349 5,-096 508.2_ 4 3 072 05/25/3000 16 1R ~`t ~ - - :Start Gcll Spacer OSi2S1200t1 16;1:9 4; ~, 2-3I3 3.28 6.101 ~ 512-5 3.208 € 05/25/?000 I6.19.~1 ' ~ - Start Sand Slurry O5/25~"?060 16 2©.47 ;,.x,74 1 ~.(l~r 7,t 63 5r,7 8 3 227 r 05/ 51200016:21 45 s 6.214 '. 11.94 i 5.12I '. Sn8.2 3227 051251~001(i~:?2 i l ~ 4.;R4 1 i 97 4: Ib7 -157:9 ' =..3 208 U5/~5'^~(0 1623 >1 I2 3_' IZU9 ' 10.IS ' 425 4 3 2118 05/2512000 It;-24:53 °If 13 '~ 12':03 ~ f l.2 t 354.5 '--3.205 05,'25)200{1 16:25 55 - lei 42 11.94 122; .3.13-4 3 ?OA US/2~/20fJbifi 265 226f~ 1.1.82 L32>I 329:7 3327 d 05/25/2000 ] 6:27 5F 25 94 1 1.69 1426 306.5 3.246 05125f2000'I6:28.57 ?91' ! C1 J4 ~~ 15.?~~ 1969 299-# 05!251''000 1630 UO 32 45 11.)6 163; 311.4 3.149 0~'25/Otk;t6:31~(t3 "-357 ~ 1197 1735 302;2 -31'3 05r25i2000 ]632 Gl >8 9 10.4 1839 224 4 3.149 0~125I 0{H) i6:32~33 = - _ _ _ SiaftGellSpscer 05/25/2000 76-33 OS ~ 1.704 E 8.37] ~ 124 329.7 3.305 Oj,~512nU0 16~53~ 11 ~ - _ _ _ ! _ ~ Start Pazr7pmg ~~iatcr < 0/25/2000163406 = 5.648 8_356 20.42 590.7 4218 05,`2512000 1(,;24 32 - - - -' '- - Start T'umging ~Snd ` 05/25/20001(1:3500 ~ 1QU7 8.515 '1.47 627.1 4.218 E}512512tX>I116:a$.IO " 14.32 ~' 8.£;75 ~ 22.45 6685 '4.199 ' 05/2512000 1(:37 12 (8.7 9-104 235^_ 6RFi 8 d. (8 O~r2~i211<101E>i38:1? ~ 23.1 91I2 24.17 691.4 4199'.. 05/25/7.000 16:39 I S ~ 27 33 ': 9.104 ~ ^_SS8 682.2 ' 4.199 05i2512(?(NJ 26'.<t0.17 r 3 f 66 2127 ~ 26_ti t ~ 673.I '.4.194, 05/25/2000 10 41 18 ': 35 )2 ~ 9.127 2;-62 6Ab_8 4.199 OSf25/20CJ(1I6'42.I) =4015 9.142 "1.863 6868' `4.199 05/25/2000 16:43 19 44 i9 9.142 '264 7IR9 4.199 05/2512~>nlG.44 21 ~= 4R.b~ } 9:142 3q.67 60.4 348 OS/2S/2000 16.45 2. ~ SO 98 ` 9.142 ? LG8 370 9 L4Ei3 :05125/2000 I6 46:24 , >2 32 ` 9.02 3? 7> 413 i U ~ 05125/20(10 l6 47 2S 52 32 8 982 33 74 ..., 4 !58 t 0 .~ „, _ ~, .., • ~. ; ~ '' r; ~'R.3[~l~I~ ~2.~3 - T'abul~r ~e ~a ~ ~+e~~~~~ ,. y .. Ac u+s~lwn Time _ _ ('amYa[ .- . ~ Det#53 ~ ~~ ~'It1t$;',° y ~,1?ce 9it3'e 1J1 - j Put~9's4Ysfe iYlcs~ rats i ~ ;, ~ ~ L 1~:~IS.~O ..~.._ _ ~ _ ~iut~~ ~~~; 05/25/2000 16:48'09 - - - - - S'1~0Y ACQUISI"I~iON -0Sf2Gf20€)00C1Ofi.15 -. - - ~ S"FAKTAE:QTASI'FIL)N ~^; 05/262000 00:06 19 52.32 W625 0. 3 s~ 7 0 '~ - ~ 7 c~/~ OSt~6CTt>ot7 EH?;OI:ZO 0. = 8.341 ? L423 7053 0 e OS/2G/?000 00:08 2 f ! 0. 8.341 12.028 ! 105.3 0. 09262000 dO:D'3.22 '^ 0. 8 34.1.° 3a>47 :100.7 " '' 0. x 0526200400:10:23 '~~ 0, ' 8.34] 4.059 i 105.3 0 d~%25/2t)QOW;11:24 ~'0. ` ' 8.31' ~ 541f32 ~ .7.00,? 0 p OSi262000 00:12 01 - s Start Pumping Water s ~ Sf26l2004 Q0°1224 ;-4,511 8.341 5.44 119 %7.905 ~ i 052Ci1200000:1327 '2.577 8341 7.134 343.4 t 2.294 Oai26;t'L(~O OpI4.01 - z - ~ - i - ; Pcess~ue x'esY Lutes 05/26/2000 00:14 27 3.004 8341 .5.136 ! 68.68 0. Oti!?6F300000:7;529 '3.025' ~ R34I ~ 91-59 768" t`0 ~n 0>/262000 00: ] 6 2I '; 3.035 ~ 8.341 =- 10.17 2903 ~ 0_ fl5i2&I244000:i`7:32 ` 3:03 :8.341 ;' 17.22 ~" 503?':. ~ 0 OS/26200000:i834 3.035 8341 72.25 ~ 50.37 Q d5t26t200d 40:19:24 - - - - Strri Ge11 Spacer (112612004 00 i9 34 :0.58 ': 8.31 ° 13.25 4AO.A 3.1 I 052620004020 16 - i - - - - 5'Yarf S:rnilSl~trry 05/26/2000 0020 34 ~ 0.762 ~ 11.78 ~ 14.25 444.1 3.227 452fiI26(70 00?I 37 _'- 4.165 `= 11 R8 li 31 ' 4?I3 ~ 2~7 05/26/200000:22.40 7.541 ': I I-86 16.35 412.1 . 3-208 f)512fi2(>n000.23~44 ~~1d95 ~ 11,87` - i7.4i'' 366."1..•. 3.227 ` x Oa!2620U~J 00:24 44 1 1 ~ ' 1 `,' 1 1.75 ~, 18.42 2585 ~~ > ~ _'' ~` 05126/204(140;25 4G 1:7.53 11 6$ 19 Q5 174_ 3 227 ' 05262000 00:26 47 20.74 1157 s 20.46 , 302.2 ~ 3.052 0>l26~20U00027 50 ` 23 3S 1 1 7, 21.51 2198 1 2.43 05/26/2000 0028 50 25 84 1214 ? 22.52 ~~ 13Z4 ~ 2.43 t~526f20000029~51 ' 2831 12.x7_ ~ 23.53 155:7 ? 44H 0~'26f2(t 0 0030 54 30 86 12.04 24.58 1G2~} ~ _>. 43 052~iY20D04d=Ht SS . 33 39 1 108 = ', 256> 1'74: 2 WOK i 45/26/2000 00:32 21 - - - I - - -Start (ieH Spacer - 052G~2000'00:32.5& L57; R_34I Z6.b5 ~t62.5 <I218 1 05/26/2000 0033 07 - - - ~ - Sixut Pumping Water d5i'26/2000~:i.i4 5'.81n ~,~~ F ~G4 27fEi 549ti `~t.I99 ~: 0>126J?t700 (Nl.>d ~4 - ~ ~ Start I'umpuig Ntud Ci512620f)0 40: 14.54 ~-' IO 09 % 8 707 , ~ 28_b7 604.4 ''4.199 . O,n6;2000 0036 OI 14 39 r K )82 39.7 X54.8 ~ 199 0~2b200dCX3:37~01 '., 1862 ;. 8497 30.71 673_L ~ 4 199 05/26/2000 00:38 04 ,' 23 O1 v 89~td 31.75 663.9 r 4.199 ' OSt2e;,/2th)Q (N)3I OS ' 27 ?; > A 837 32:77- 654.8 ~ 199 05126T2UOt~ 00:40 U7 31 57 ''~ 9.119 3 "s3 79 ~ 654.8 ? 4.799 0512b120t30{J0:4-1 07 ~ 3~.R i~ 9 119 ;4.8;; (1543' .4.199 1 osn_r2oco on a2 n~ ' 4o rah ~ ~~ ~~ 1,~ 6Sy ` a.ls OSf26200000`_~13.11 44.44 9.719 36.86 6?4.8 '4.199 05/26;2000 Cr0.44 I ; 48 82 '; 9 135 ?7.9 Ol6 4.18 t7or2fi2000 OOi 15.1 t S3 07 9 i 35 " 48.92 71-'._3 ~t.15 05!26/2000 00.46 14 ~ 57 2R ~ 9.135 39.92 :718.9 ~ 4.199 0526200000:47. [5 ~ fit 5~ ~ 9.14, 10:94 7I~13 4 199 0526/2006 OQ48:16 6 6~.Su 9.li5 4191 512_R 3.169 ry 0~(25f2000i)0:4-9:17 h8.dd ',9it2 -t?9F =325:4 2158 ~ u~~z6rouu~oso 15 `: 7oSi 9iaz ~> <~<~ 73.26 os~3 452ov(h`7i3t3:5119 1051 9142.: ~ 45_ 9,Fa8 0 05/262000 OO:SI 15 ~ ~ Shutdonm t151?b200p 1)0:51 57 - - - - ` a"COP fiC~>UISITiC)N ~~ 0/262000 08:16 51 - - - - - START ACQUISITION 0526f^_EJOOOR 6 j 1 7i ~ 1 ~ -6 25 0 -356T ! 0 TA r17/1r ~ ' 051'262000 08:17 07 - - - - - Start Pumping Wafer 05/262000 U8 17 i2 U. 8226 I (111 , 4579.. 0 05/262000 0R 1 R 54 :0 5.257 2.042 4.579 '- 0 u526r200Jt18;1~7 54 0. 8,257 ~ 3.O~tR 4-579 U. OS/2612000 08:20 5~ ' 0 8.265 4.058 4.579 0. 0>/2G2U0~r052I56 _ 0. °~ 8265 5.07:, ~ 4.579 ` 0. OS/2b2000 0822 SG ~, 0- 3.265 6.082 4579 ~ U. 05t26/2000 08:23:57 0. s 8 265` 7.087 4:579 ~ '0.' ~ ~5262out~ o~2a ~7 ' v ~ x.272 x_o9 as,~~ ' ~ ~~;n~rzc,~c>~a:2>s~ , t~. s.2~2 ~ ~ 9.13.E ~4_~7~ ~ t). 05/26/2000 0827 O1 ' 0. ~ 82R 10.1E :4.579 0 g ~QS,'26/200008:28:04 ~ 0- 8.28 11.19 1 4.574 ~ 0. '- 0526/2000 OR 29:03 . .., >..,.v .,.. 0 8 28 12 19 4 579 0 ' • r~~ ~, __ PRI~~>~~` X2.23 - '~'abul~r ~ ~t t ~e.~n~~xtin ~.. ., . 4cqur~~hort T~mc ~' CumVnl ih`r~eih ~~R~`it1~ Prc~sgTC'fal_ _~~ 1`ntFJO'Wr+fr ~ ~ r•9ca~a~ey_ ~ 05/26/2000 08 3 1.06 0.22 8.333 14.24 338.8 t 1 75 ` 05J?6tZ000 ORi32.07 2.1 , 8463 1527 i 18.32 0 039 ~ 05/2612000 08:32.3; - - - - - ;Pressure Test Lmes 05126P20(H)0833:(19 : `2.123 8.433 i 1629 :489.9.: ` tl(1?8 ~ ) 05/26/2000 08:34 09 ~ 2.137 ~ 8.448 ~ 173 2940 0 ' f}SZ~f2(I0408:35:12 ~ .737 5.443:..: ~ 983> b4_} ~ 0 ~ ` + OS/26/200D 08:36:12 -1.653 ~ 8349 19.35 ~ 476.2 3.13 ' U5f'~~ii'2tMlt)UB:S&20 - - - - i . s'.arf bell Spacer ' C7526/2t70008:37:i3 ~.4)i ~ '88 20.35 4762 ~ 188 ' DSi26iZ000{)837 I4 ~ ~ - =_ - ~ S!arE SandSturrv - ° 05126200008:38.13 x.87 ~ 1;.71 ' 2].36 421.2 ~ t.93~ OS!?, 6P2000 05:39:13.. 5947 - 11.7 :22:4:.. 343 8 ; ;- 2 474 05/26/200008:40:17 x.008 11.62 23.43 ~: 35Z1 X2.974 057252000D8=~1~18 ;171 E 12.69 ~ 2Q 4-0 . 28R-5, 2586 OS/26/2(k)0 08:42:19 14.41 ( 1 1.87 :25.47 :, 251.8 2.644 d5126/20I?008:43:20 _f7.OS s = 1226 ~ ~ 20,47 274.7. =:2,62¢ f 05/262000 08:44 21 1 19.73 12.29 ~~ 2249 + 242.7 2.624 O~l?52006 0&45:21 2?.4 10A9 :: t 28.5 ` F 296 9 2.644 :_ 05262000 08:46 l I - - - ~ - - ~tirir• tell Spacer ) p3f~'G2f)(}J0R`~`6:22 , '1'34ci 8SSS ~y9S 196,9 2.624 , 03/262000 08:47'02 - - Start Runping Watcr 052bh(k3f)08~;:24 ;4.>61 8.349'` 30'c54 4945.:: 4218 . 0~2f,2000 08.48 08 ~ - - - ~ Star[ T'~impino Mud 03f2~12(}000RidR2a = `$.tKl~ 3 ~ 3 t'S~ 61R.I r 4 491 05126/200008:49:27 ' 73.43 ~.i~69 32.6 ~ 705.1 ' 4.607 ~' . 0~~6l200008»4.27 :;18.66 889 33.6 ~4LS -1.6=1b ,' 05/26/2000 08:51 27 22.71 9.033 34.6 760.1 :~_ 4.646 0~/26/20i>f3085228 27 39 ~ 9.035 ~ ;5.61. 7463 ~ 4 E~46 05262060 68:53 30 ~. 32.2 9.066 36.f ! 732.6 s 4.646 r s 05262000 08x54.31 ;.36.42 ' `9.074 ~ 37-65 723.4.;. '-'4 646 . 0>26i2tttYJ 08:55 ~2 4] (7 '~ 2681 38.68 7189 ~ 4.607 OSt26F20(lOb8:56'33 "_4Fi 33 ~ 9.OSt -;4:69 .714:3 ~ 4 b07 05126/200008:57 35 i 1 I4 > 9.081 40.73 714.3 ~ 4.607 4~ 2ii!2t'JODB_~8 =6 55 8 s 4:F)8i 41:_74 75J.9 •4.601 05/26/2000 08:59 36 ~ 60.43 ': 9.081 ~ 42.75 r 773, 8 ~~ 4.627 05t2h1200009;1NJ37 6316 ~ 408'1' d3-7? 325'7 °2177 05120/2Ct~0 09:01 40 66 t 3 9 OR l ~: 4.1.81 178.E :1.203 0 5/262 00 0 09.02.42 66 41 ': 8.58$ 45 S { 4 574 ' ~ 0 05/X,/2000 09:03 46 66 ~ ! 7 (77 46.9 ( ( (lil2€S12O;7t) 63s0-k -E6 ~bti ~ 8.562:.. .17.92' 4:579 . (3_ 0526/201)0 09.05.47 66 5 8.Fi3 I 48.93 4.579 0 fiii252(}(1F1f19;O6,48 ~ 655 R.84$ ~f9.94 4:ST) 0 05%26/2000 09-07 48 66.J '~ 8898 5095 ; 4.579 6. 03f2ti/ZOt)609:08~4R . 6fi.5 ' 8898'.. 51.95 ~ 0 0 ~ '~ 0526f2EXH)f}909.52 =: 665 8.9tK~ 53.1)2 4.179 1 ost?6nooao4anns ~ - - - _ - - Etid.~~>7 05/26/2000 09 10 34 ° - - - - STdP AGf~Uftt`I'K}N • Cementing Job Report pRlsnn• v2.2s ply ~ i Well 2T - 217a Client ARCO Alaska Inc Field Kuparuk SIR No. 20160253 Country US Job Date 5/24/2000 3:48:02 PM Time •• ® •• TotFkiwrate 05124/15:48:02 *""` "'°~ Pressure v7 ~~~ «as-. w.c pe . . t j$ 3 ~ ? ~ d 15:48:00 ( y ~ 1 's7ART AGI7lfl9ilON ' i ~ 15:52:00 4S k B ~ 1 ~ ~ 'SlartPumpmg Water • ~ ; ~ r, ~ ~ R i ' ~ i t ~ I 15:56:00 ~, # j '. k t 3 ~ i ~ I s ~ ~ 'Pressun: Test Lines ~ ` ~~, *an. 010 ~' . +~ ~+~° w"° ~ ~ ~ 3 : ...~ m: ~ , , ~ } i ~ ~ ~ ~ i # ~ t ~ s eCp f # i *Start Gall Spacer 16:00:00 ~ ...,~, is .. ~ ~ i r - 'Start Sand Slurry a• ~ ; ~ , ~ ~ $ ~ $ ~ 16:04:00 b ~ y ; # ~ 9 4 { ~ t 'Start Gall Spacer .. ,s # _ # m ~ $ 'Start W mping Water ~ ~ ~ # ~ ~ § ~' 1 P ~ i ~ J? ? - 3 ~ ~ 'Start Pumping Mud : I 3 ~ @ 16:08:00 i 's i ~ ~ r' ~ ~ ~ - ~ ~ ; ' ' ~ . ' ~ ~ [ ~ y # 16:12:00 ' " s _ '° - I 3 ~ ~'~ € r E ' 6 ~ : : r ~ ~ a; - 16:16:00 r - ' ~ a' yt #; ~ . r . ' ' - ; 16:20:00 t ~ !f € u ~ , #g ~ s t y I~ ' ~r I ~ ~ _ 5 ~ : ®~qi k 4 i ~ ~ ', M ' ~ 3 ~ 3 t , 16:24:00 ~ _ ~. 1 'Shutdown hh:mm:ss 0 ~~, ..,a , ~~ 5000 05/24/001623:59 ~ + ~ ~ hpr" 1D n 0 0 N 0 r 0 'Mark of Schlumherger Cementing Job Report PR1sM' v2.23 ~/~ ~ z Well 2T - 217a Client ARCO Alaska Inc Field Kuparuk SIR No. 20160253 Country US Job Date 5/24/2000 8:01:26 PM Time ° TotFlowrete ~ 05241W 20:01:26 '"'~ ....' Pressure ut oen~lty 3 ! , g I ~ ~, r - `sTART AC(]UISf710tJ am k 1 ~ { 2 `~ s ~ ~ i . `s S i 3, ! i j i ~ ~ 1 ~ ~ ? ~ I ' ~ ~ ~ ' t _ ~ 7 ; 20:10:00 > ~ i i i ~ k ~ } tl ~ i t . ~ ~ V ~¥ ~ ~ , ~ , zD:1s3o ! u i ~ ~ ~ j ' »'~ ~ ! ~ i a. ~ 'start Pumprrg water ~ r ~ ' H ~ ( 'PressureTest lJrres r ~ ~ ~ ~ 20:21:00 x ~ S y i ,~ . z ~ " i r i t 'Start cell Spacer ~.R • ~ S a i ; .. "Start Sand SFurry ~ • ~ - ~ ~ ~ i _ i ~'~ a ~ e ; ~ i j ~~ 20:26:30 3 ~ ~ § ~ S ~ , f f~: t ' 2D:32:00 } ~ ^~ ~ ~~ ~ ~ £ i ~ j `Start Gell Spacer ` ~ ~ ~ Start Pumping Warer • -~ ~~ : 'Start Pumping Mud ~ • "~ 4 i ': t s ~ i ~ ' . r 3 20:3730 ~ # o ~ i : ~ a ' t ® 1 -: , a ' s k i s ~ t a i ~ v _ € ! ~ ; zo:43:00 ~ t ~ ® ; ~'~' fi 20:48:30 ; a _ q ~ f ~ ~ i 'snumewn ~ ~ ~ € ~ ~ ~ x : ~ , ` k 20:54:00 L a F , i ~ , hh:mmas a ..=.-,_,._.:,, PPg 2; 0 "°4'" ~ psi 5000 05l24I0620:50:14 ~ ~ ~ bPm 10 N 0 0 •P- 0 N v> 0 • Mark of Schlumberger '~ Cementing Job Report ~RtsM• v2.2s e ~/u # 3 Wetl 2T - 217a Client ARCO Alaska Inc Field Kuparuk SIR No. 20160548 Country US Job Date 5/2512000 3:16:47 AM Time " '" • TolFlowrate 05/25/90 03:16:47 '~' --« Pressure ut ~ ~ Dens I l t : ' $ ~ ~ ~ ~ ; ! i ~ ! 'START AGGt11SffION . l 03:18:00 *.: ~ l l ~ ~ ~ ~ S 1 ~ 'Start PU water ~9 ~ « 3r . i ~ ~ £ { 1 i ! ~ y x « P ; v: ~ { _ _ 1 _ Y p ,.m ,~„ ,~ I § 3 sue. EgfR ~ ~ ~ £ t _ ^° ~ E ~C ~ '~""`°"'. ~y~s. •w ' ~ i ~ ~ i 'Pressure TesE tines 03:22:30 ~~ :. ,€ ~ ~ i . ' ~t ~~ a~3 5 ~ ~ ~ ! 'Start Gell Spacer ~ g4a.: ~ ~ ~ ~ ~ l 'Start Sand Slurry 'ep. s z; ` ~ sa 3 t l ( i l i 03:27:00 3 ® ~ ' R ' I I l ~ ? ° ~' 4 ; .~ I ~ : i ' , ~ ~ >~ a i . r ' : ,. ~' " ~ ~ ~ + 03:31:30 < s ~, ~ ~ i ; ; s •: ~ - ~ 3 i O ! I ~rtt f I ~ ~ ~ I 1 i Staft Gel) Spacer ~. pa Gy ~ ~ *'~ : ~ °' • ~ ~ - 'Start Pumping Water 03:38:00 ~ S ' t $ } ~ i ~ "~ ( . :' 6t : s i ~ 'Start Pumping Mud ~. , ~ a l r ~ . ~ a ° ~ ~ ` 03:40:30 ~ a § ~ ~ ~ { ~ " R # L ® : ~' : l 0 1 I ® d ~ i 3:45:00 s ~ ~ ® - ~ . 1 # 03:49:30 ~'" ~'« ~ m r S F t ~ : r i ~. t • F y 1 03:54:00 3' j}~ ~ £ l ~ : ~ } ` i . ~ j ~ ` ~ Shutdown 03:58:30 ~ 's i ~ ~ i . Z hh:mm:ss a <..~~.,.A ... pvq ~ o ~ ~ psi sooo 05/25!0003:58:12 ~ s s s bpm 10 N N U O n N O N I6 O 'Mark ofSChlumberger Cementing Job Report PRISr,M v2.23 ~~~ ~~ Well 2T - 217a Client ARCO Alaska Inc Field Kuparuk StR No, 20160548 country !aS Job Date 5/25/2000 9:02:56 AM Time TotFknwate o~rz5roo os:o2:5s ~- -» ,re ut : r '"~~ ~ ~ t ! - ~ ~ ~ 'START ACQUISITION _~ ~ ~ ~ 09:04:3D ~~""~~~ _ ~ ; ( 4 i 'Start Pumping Water ~ t $ . r~s • 4~ ~ ~ 4 `Pressure Test Lines 3 ~ ~m~s. p ' ~ _ ; ~ € j ' « ~ ~ _ i a ; a ~ ~ ~ ~ 'Start Getl Spacer g i ' ~ t R . „~~ssc„ v„ , ~ d i 1 I ~ ~ 'STart Santl Starry ~ ~._ . a""'~Rr~ j j I j r ' ~ } y i a • . • v ~ ~ ~ f ~ f { i 09:13:30 ; i ~ ~ 3 ! S ~ ~ • ~ :a ) ~ ~ [ ~~ ~ g~g + ~. Z t - 09:18.00 ~ ~ s g i } h ~ n . . ~ . P a : } • # ~ f ~ ' _ # € ~ i ; 'Start Gen spacer os 2 ' : z:3o ~ I ~'~. ~ . . ~ ~, ~ ~ a ' 'S~rt Pumping Water s.~ ~.~§ • ~ a i ~ ~ j : ~ 'Start Pumping Mud ? s ~ A 's t "3 s ~ i , ~ ~ Y "~ ® ~ ~ Q9:27:D0 • ~ ~ ~ ~ ® _ a j _ t i # ¢~ d A i 2 ~ h a ~ ~ ' { ~ . yg g > i' ~ 4 . i 09:31:30 S ~ : ~ . ~ ~ r a ' . s` ' ~ 09:36:00 , .e~ ,.i ~ Y ' ~`. ~ i ~ } ~`' ~ t ' ,~'~ ? t t ; ! - ~ _ 'Shutdown 09:40:30 i ~ ~ ~ . ~ ~ ~~ ~ z t ., i ~ 1 : hh:mm:ss a „-,.,~.-..,n, ppg zs o •~$, ~, pe; saoo 05/2510009:40:06 ~ ~ bpm f0 cv N O N 0 C n 0 ' Mark of Schlumherger ,_,_ Cementing Job Report PRls~n~ v2.2s !~ '~s WeR 2T - 217a Client ARCO Alaska Inc Fietd Kuparuk SIR No, 20160550 Country US Job Date 5!25!2000 4:13:38 PM 3 ~ ; ~ 'START AC.I]UISRION 16:16:00 :~,.: ~;~~, .~,~, _ Ss ~ ~""" 4 ~ ~ ~ ~ ' ~ ~ ~ j ~ r 'Stark Pumping Water k S o i$ ,,,,, , ~. ww ~ ! ~ i 7ressure Test Lines ~~~ ~ rd 4 { ~ i ~ ~ i ~ i ~ ~ 0 ~~~ 4l j ~ ~ ~, j13 ~ i 3 1, i ~ 'StHRGef1 u~LeT 16:20:00 ~~~.~~, £ ~ * ~ •SYart Sand Slurry (~ ~ ~ ~ 1 , ~ t , 3 3 ~ a ~ ~ 46:24:00 ~ ~ ~ a ~ , .. ~ _ 9 . ~ . ~ k ~ ~ ~ : : ® 5 ~ 1 ! .. ~ : 16:28:~ s s ; F ~ 1 ~a - n~ g ( ~ 5 ~ i I a S : I A ~ a ~ ~ r t 16:32.00 t # . 3 3 ~~ t t _ _ _ 'Start Gell Spacer ~''+ c ~ a s ~ 4 r ' t 'Start Pumping Water x ° ~ ~ 3 t1 ~ ~ ~ ~ ~ ~ ' ~ ~ i e ~ Start Pumping Mud ~ k S , + i + 16:36:00 ~ g i I ~ € i i 1 & + ~ : s s 4 r ~ a~ ? 16:40:00 ~ t ~ 'a j ` 1 : '~ ~ J 5 } ~ ~ r . ~ E • $ 16:44:00 + e~ S e. ~ t ~ : y ~ i . ~ § ~ ~ ~ ~ ~ .Shutdown 16:48:00 ~ ~ : 5 hh:mm:ss s ..,._~ ,,,,>~, pPS ~ o ~ °~° psi eooo 052510016:48:09 g ~ per, 10 t~ N m 9 O V N h O 0 N N a ' Mark of Schlumberger `" ^u 8 x Cementing Job Report Pwslnl= v2.2s Phu ~ Well 2T - 217a Client ARCO Alaska Inc Field Kuparuk SIR No. 20160614 Country US Job Date 5/26/200012:06:15 AM Time ° • TotFlawra[e 0526/00 00:06:15 °~ °... pressure ut DerisAy M~9es y ~ I t j t I 'STAR7 ACWISITION k ~- I i r ~ oo:laoo { ! ~ ; ,: ~ ~ i 'Start Pumping Water t A $ 3 ~ e~ ~ ~• ~ ° ' t 1 ~ f 'Pr05311M TaSt Lif105 00:15:00 » ~, +; .~,. _ E i 3 , ~ ~ . Yv' S i d ~. ~. 4 +++.a ~ i 'Start Gell Spacer 00:20:00 ~ , ~ ~~ ` ~ ~ i - I € • 'Start Sand Slurry o- ~ ~ ~ x ~~ 2 s ,. • ~; ~ ~ ~ ~ € • 00:25:00 a ~ '. ` z ~ ~ , j ' # ~@ ` 3 i $ ~~ ~ ~ ~ 1 ~ £ ~ y { i I 00:30:00 ~ ~ ~ 8 ~ , ~ s € ~ , , +~ ., ° ~ 'Start Gell Spacer < "Start Trumping Water !~ c ~ 00:35:00 ~ e € _ "Start Pumping Mud y 0 ~ - P i ; , ( F ~ i a s r ; ~ i i • ~ I ~ ~ i e ~ 00:40:00 ~ ~ F a e u a ~ ~ , , + a ~~ ; ' a ~ $ ~ i I 00:45:00 ; ~ i E ~ a ' s ! 1 9 ° w 3 ~~ e ~ ~ i , y ~, 3 V ~ - ~ 6 ° ~ "Shuttla.m ~ , t 4 a ~ ~ # ~ j hh:mm:ss 5 «_.,,.Y,_.~.a pPS ~ p +r ix, ,,.,R psi 5000 0526/0000:51:57 0 ° bpm t0 n N h D O V m N O C 0 " Mark of Schlumherger ~, . " ~ _~ Cementing Job Report t'RtsM* v2.2s Welt 2T - 21~a Client ARCO Alaska Inc Field Kuparuk SIR No. 20160614 Country US Job Date 5!26/2000 8:16:51 AM Time ° m • TotFlowrate 0526/0008:16:51 ~ ~+ PressureUt ~ ~~ ~,.ffi .Density a ~ 1 ~ ! i ~ ~ r I 'START AC(]UISIl10N 08:18:00 `~*z ' 9g ry ~ ~ ~ ~ ~ j ~ : I I - ~ 'Start Pumping Water ~ .*S~ i ~ k4 t ~ ~ i M ~ Dfi:za:oo ~ ~ ~ ~ , ~ ~ . ~ ~ ~ ~ , oa:so:ao i ~ - .. ~A w ~ • p ~ ~ £ ~ ~ ~ - ~ 1 . '~ $ ,~ ,~,~ ~ .. . i ~ I ~ ~ 'Pressure Test Lines a _. ~ a `°~ :awo ~:.s - w. diF'~" ' , . ' ~ , auu :~r~ , ~. . i s 0836:OD '~, " ~ ~ <' i ~ ~ •Start Gell spacer ~°£ p ~ ~ _ ~ i : 'Start Sand Sturry ~ S a 08:42:00 ~ s` ~ o ~ ~ ~ a : I . ~ 3 ~. [ 9 3 1 " . 0 ~ ". F :s"- i ~ rF ~ ~ ' ,,~ ~, ~ a •~A~ '' _ ~ . 'Start Gell Spacer ~m l , ~ ~ ,. „~ a 'Start Pumping Water 08:48:OD q '4 r ~ µ I 9 . 'Start Pumpng Mud i ~ ~ ~ a 3 ; r ~ I ~~ t i 08:54:00 ~ ~ ~ ~ s a ~ c t s ~ r , , ti ~ _ ~ 2 c ~ S} ~! { 4 09:00:00 ko~ ~ , e rq F . s ~ . ~ ~ i 'v - ~ - h . 4 ~ 1 .g 5 $ , . . j { ~ ~ F I I s ~ _ ~ 'End Job 09:12:00 e 3 ? , i hh'mm:ss s ...,.`~.,."' PPS zs 05/26/00 09:1034 ° ~"' to r N N [V S _r ' Mark of Schtumberger CASING TEST and FORMATION INTEGRITY TEST 2 l? A Well Name: 2T-,?~18'S pate: 5/21/2000 Supervisor: G.R. Whitlock p Initial Casing Shoe Test Reason(s) for test: ^ Formation Adequacy for Annular Injection ^ Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7", 26#, L-80, BTC-Mod Casing Setting Depth: 7,368' TMD Hole Depth: 7,388' TMD 3,063' TVD 3,069' TVD Mud Weight: 9.8 ppg Length of Open Hole Section: 20' EMW = Leak-off Press. + Mud Weight = 1,100 psi + 9.8 ppg 0.052 x TVD 0.052 x 3,069' EMW for open hole section = 16.7 ppg ~.. - - - - 4.~~N ~u.N~~ - v.~o•rv uN~ nulu rumpea = Z.'1 ppl 3.200 psl 3.100 psl 3,000 psi 2,900 PSI - '~.. 2 800 psi . z 7ooPS~ TIME IiJL , 2 600 Psi _ , 2,500 psl QNE '~. ~ I GJ l; : ~ TI ~~ F,>. 2,400 psl _ _ 2'~ Psi '~ -• L EAK -O FF T EST 2,200 psl 2aaopsi ~~CASINGTEST 2,000 psi . i,9oopsi ---%°--LOT SHUT IN TIME ~ i.aoopsi ~ 1,700 psi -+*-CASING TEST SHUT IN TIME ~+ ~'600ps1 -+-T ~++ 1,500 psi IME LINE per, 1,400 Psi 1,300 psi I,zoo psi i,ioo psi i 1.000 P51 900 psi 800 P5I i 700 psl ~ 600 Psi I 500 psi 40o psi 300 psi 200 psi i 100 psi ~ 0 Asl r N ~ u ~ ~ ~ ~ ~u v ~ ~ ~ ~ ~ P ~ S u ~ ... Q'n ~ ~ v ,_, Pn S w ~ .N,. to STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE __~ 0 stks ! 0 psi ! ' 2 stks ! ---------------~--- ---- -------~- 0 si ! -------p-------• !----------------~--- 4 stks---+ ~ 00 psi ~ --- ------- ' ~ 6 stks I 150psi I ! 8 stks ~ ------ 250psi ! -10 stks ! 350 psi ! I ~ 12 stks ! -- -- _ 450~si -- 14 stks _ ___ ____ _____~ ~ 550 psi ! - ~--- --- - --- --i--------- -------~ !-------=--------~-- 16 stks--+---650 psi---j ' ~ 18 stks I 750 psi ! __20 stks ! I--------------- -- - --•- 850psi-- -------- - _-________a_ _22 stks ~ 950 psi -- ' ! 24 stks _! 1,000 psi ! ' ! 26 stks ! ---------------~-- -------------t- 1 100 psi ! -- '------------- !---------------- _ ---------------f- ----------------i j----------------~--__-----------f- ----------------i _ ~ I ----------------+---------------r----------°-----+ ~ ~ ~ , , ~ , ' ---------------~--------------- t- i , , , ----------------• i !----------------i-------°-------f- ; ----------------i I I i ' ' ~~ ~ ~ ~~~ ! SHUT IN TIME ! SHUT IN PRESSURE ! 0,0 min ! ! -- -------------~----------------~- 1 100 si ! p ---=-- , ---- ---- !___1 Omin--A---------------t--1,050 psi-~ ---2.0 min---i------------ + 1,025 psi ---- - !-_-3 0 min I 1 --------;------------------ - - _~ 1,000 si ; ----------P---- ! 4.0 min ! ! 1,000 psi ; ~ - j----------- - ;-- 5.0 min ~ 1,000 si ! ' 6 0 min ! ~ 950 si -----=----------~---------------~------- P - ~ -- ---- 7 0 min ! 950 si i i________________ ' ----------------t---------~----- ~ 8.0 min ~ ;----------------j----------------+---950 psi---t !---9.0 min-------------------l- --950ps1---~ ! 10.0 min ! --! 950psi- ! NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY • • CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE Phillips Alaska Drilling • Cementing Details Wefl Name: 2T-217 Report Date: 04!27/2000 Report Number. 1 Ri Name: Nabors 16E AFC IJo.: AK0072 Reid: Ku aruk RNer abasco Casing Size Hole Diameter. Angle thru KRU: Shoe Depth: LC Depth: %washout: 9.625 12.25 74.9 6213 Centralizers - State type user!, intervals covered and spacing Comments: 1/Jt on tirst 15 jts 1/3 jts to surtace. lfjt on each side of port collar. 64 total htud Weight: PV(priorcond): PV(aftercond): YP(priorcond): YP(aflercond): Comments'. 9.8 32 22 46 21 Gels before: Gels after. Total Volume Circulated: 24/50 10/14 900 Wash 0 Type: Volume: Weigh: Comments: ARCO 20 8.5 Dropped bottom plug between preflush andspacer Spacer 0 Type: Volume: Weight: Comments- pRCO Spacer 50 10.7 t/2 gallon red dye in first 3 bbl of spacer Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: pS itl Lite 75 803 1D.7 4.44 Additives: 30°6 D53, .696% D46, 1.5°~ D79, 1.5 % S7, 50°k D124, 9 % D44 Tail Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 75 871 15.8 1.16 Addtives: .2% D46, .3% D65, .5% S7, .4% D167 Displacement 0 - Rate(before tail at shoe): Raie(tail around shoe): Str, Wt. Up: Comments: 5 5 150 Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 15 120 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 465 465 Calculated top of cement : CP: Bumped plug: Floats held: Surface Date:426/00 yes yes Time:15:23 Remarks:Hatl good returns throughout job. Circulated 360 bbl slurry, preflus, and spacer to surtace Cement Company: Rig Contractor: Approved By: DS NABORS G.R. Whitlock • Cementing Service Report ~OtYf211 Customer .Job Numtxr l',~- ARCO ALASKA 1NC ~ 26155120" Well ~ y~ r Location (tegaq _ powNl Location Job Start ~' U VARIOUS 1 cam` ' Prudhoe Bay, AK 4/26!00 Field ~ Formation NameJType Deviation Bk Size Well MD Well TVO PRUDHOE BAY 0 0 in Oft O ft County StatdProvince BHP BHST BFICT Pore Press. Gradient Beechey Point AK 0 psi 0 °F 0 °F - - 0 psl/ft _ __ Rig Name Drilled For Service Via EaRineiJ~itter NABORS 16E Oil Land ~Pth. tt size. m Weight, IWft Grade thread Offshore Zone Well Class Well Type Q Q Q New Development 0 0 0 __ DrilGngFluidType Max. Density PlasSclfiscosity_ - - Ttlblrl9/dT1ltPipe 0 Ib/gel Q Cp ~P~. Size, in Weight, Ib/Ft Grade Thread Service Line Job Type Q 0 - Q Cementing Cem Surface Casing 0 0 0 Max. Albwed Tubing Pressure Max. Allowed Ann. Pressure WeIlHead Connection Perfol"at10I1S/OpL+n Hole 0 pSl 0 pSl Top, tt Bottom, H ~ spf No. or Shots Total Interval Service Instnxtions 0 0 0 0 O ft ARCO ALLOCATION $33,424.00 0 0 0 Q Diameter MATERIALS + 5% $62,257.95 0 0 0 0 0 in TOTAL FIELD EST. $95,681.95 Treat Down i Displac ement pa cker Type Paclrer Depth 0212-13027 Casing 0 bbl 0 ft Tubing Vol. Casing Vol. Annular VoL OpenHole Vol 0 bbl 0 bbl 0 bbl 0 bbl CasinglTubing Secured ~ 1 Hole Valume Circulated prior to Cemen6ng^ Casing TOOis Squeeze Job Lift Pressure: psi - Shce Type: Squeeze Type Pipe Rotated ~ Pipe Reciprocated^ Shce Depth: Q ft Tool Type: No. Centralizers: Q Top lugs: Q Bottom Plugs: Q stage Tod Type: Too! Depth: 0 ft Cement Head Type: Stage Toot Depth: Q f t Tait Pipe Size: Q in Job Scheduled For: Arrived on Location: Leave Location: Collar Type: Tail Plpe Depth: Q ft 4/26/00 2:00 4126/00 16:00 Collar Depth: ft sqz Total Vol: 0 bbl Time( CumVof ~ [Jensfty Pressureul ~SfageVoEprne~ TotF(rnvrate i. Message 24 hr ~ i t ~ Jock bbl ~ ,.PP9 j Psf 1 bbl. 1 ~". `` ,I'. -. 11:02 0. 8.34 18.32 0. 0. j 0 0 11:02 0. 8.34 18.32 D. 0. 0 0 Start Pumping Preflush 3 bbl 11:03 I 0. 8.34_ 13.74 0. 0. 0 0 11:04 0. 8.34 13.14 D. 0. D D 11:05 0. 8.34 9.16 D. 0. 0 0 11:06 0.699 8.33 183.2 0.899 2.35 0 0 T T:07 3.1 8.33 41.21 3.1 0. 0 0 11:08 3.1 8.33 36.63 3.1 0. 0 0 11:D9 3.13 8.33 480.8 3.13 0. 0 D __ 11:10 3.15 8.33 3063 3.15 0.117 0 0 11:10 3.15 8.33 3063 3.15 0.117 0 0 Pressure Test Lines tt:T1 3.15 8.33 18.32 3.1.5 0. 0 0 11:1.1 3.15 8.33 18.32 3.15 0. 0 0 Finish Preflush 17 bbl 11:12 4.42 8.33 338.8 4.42 3.83 D D 11:13 9.75 8.33 j 673.1 9.75 6.21 0 0 11:14 16.75 8.33 833.3 16.75 7.07 0 D 11:15 20.1 8.34 j 5D.37 20.1 D. 0 D 11:16 20.11 8.21 54.95 20.11 D.039 D 0 11:17 20.12 9.2 73.26 20.12 6. 0 0 _ 11:18 20.12 9.2 73.26 20.12 D. 0 0 ~ 5tart Pumping Sp 50 bbi 11:18 20.12 9.2 7326 20.12 0. 0 0 Reset Volume i RIGS 97 Jl.1aSR Page 1 of 6 • • weti Field VARIOUS #1 PRUDHOE BAY 1 __. _ 1(1070 "i G~imYol ~ Densrty ~ureU S ge VINUtt1e TO&bwrafe ~a ,r ~ c,c:.k. b61 I ppg ' '. pgt bW bPm __ 11:18 20.12 9.2 73.26 20.12 0. - - _ Service Date Customer ~ Jon Numt~ar ARCO Ai.ASKA INC ~ X0155120 -- ~ ~ M@550ge _. ( ll.. ~ 0 D [Stage Volume]=20.18 bbi 11:18 20.72 10.33 128.2 0.338 1.77 ~ 0 0 11:19 24.04 1 D.7 416.7 3.66 4.18 0 0 11:20 30.17 1 D.25 650.2 f 9.79 6.12 D 0 11:21 36.91 10.3 801.3 16.53 6.93 D 0 11:22 43.71 10.53 746.3 23.33 6.38 0 0 11:23 49.59 1 D.4 554. ~ 29.21 5.25 0 0 11:24 54.92 10.49 554. 34.54 5.23 0 0 11:25 6D.25 10.41 563.2 39.87 5.25 0 0 17:26 63.5 10.78 512.8 43.12 4.99 0 0 11:27 63.5 .10.78 512.8 43.12 4.99 0 D Reset Volume 11:27 63.5 10.78 512.8 43J 2 4.99 0 D [Stage Volume]=44.42 bbi 11:27 63.5 10.78 512.8 43.12 4.99 D 0 17:27 69.27 10.75 760.1 4.37 5.89 0 0 11:28 69.27 10.75 76D.1 4.37 5.89 0 0 Start lead cement 11:28 75.32 i 0.61 709.7 i 0.42 5.92 D D 11:29 81.25 10.83 741.8 16.35 5.89 0 0 17:30 87.18 10.67 668.5 22.28 5.92 0 0 11:31 93.25 10.86 691.4 28.35 5.94 0 0 11:32 99.23 10.58 645.6 34.33 I 5.96 0 0 11:33 105.5 11.D9 677.7 40.65 ~ 5.89 0 0 11:35 111.5 10.66 627.3 46.66 ~ 5.96 D 0 11:36 7 7 7.8 10.74 659.3 52.87 5.98 0 0 71:37 123.7 10.77 627.3 58.83 5.96 0 0 11:38 129.7 10.81 65D.2 64.84 5.92 0 0 71:39 136. 10.7 609. 71.12 5.96 0 0 17:40 142. 10.76 641. ~ 77.7 3 5.96 0 D 71:41 148.1 10.73 627.3 83.15 5.9B 0 0 11:42 154.7 7 0.74 755.5 89.8 6.75 0 0 11:43 7 61.8 10.74 ; 741.8 96.85 6.75 0 0 17:44 168.6 10.74 764.7 103.7 6.75 D 0 11:45 175.5 10.76 769.2 110.6 6.72 0 D 11:46 182.3 10.71 769.2 177.4 6.75 D 0 11:47 109.2 1 D.79 750.9 124.3 6.75 0 i 0 I 11:48 196. 10.73 755.5 131.1 6.75 0 0 11:49 202.8 10.73 746.3 137.9 6.77 0 0 11:50 209.7 i 10.74 760.1 144.6 6.75 0 0 11:51 216.5 10.74 746.3 157.6 6.75 ~ 0 0 17:52 223.3 10.73 750.9 158.4 6.79 0 0 11:53 230.2 10.74 750.9 165.3 6.75 0 0 11:54 ~ 237. 10.74 773.8 172.1 6.75 0 D i 1:55 I 243.8 10.74 750.9 178.9 6.79 0 0 11:56 250.6 10.74 746.3 185.7 6.75 0 0 11:57 257.4 10.75 750.9 792.5 ' 6.79 0 0 11:58 264.3 10.73 732.6 199.4 6.79 0 0 11:59 271.7 10.72 747.8 206.2 6.77 0 D 72:OD 277.9 10.76 750.9 213. 6.79 D 0 7 2:Of 284.7 10.71 764.7 27 9.8 6.75 0 0 12:02 291.6 10.78 755.5 226.7 6.83 0 0 12:03 298.5 10.65 755.5 F 233.7 6.85 0 D 12:04 305.6 10.79 755.5 240.7 6.85 0 0 ------- 12:05 372.5 10.68 746.3 247.6 6.85 0 0 12:06 319.5 10.7 746.3 254.6 6.85 0 D Rios s~ Jz.taSR Page 2 of 6 • Wep Field VARIOUS #1 PRUDHOE BAY Time cumvo~ Density FressureUt iStagevoiume~ 7otFtowra[e clerk. I .bbl PP9 __~ t~ i BW ~ 6pm ~ ervice Date Customer Job lJUTt~er ARCO ALASKA INC 20155120 T f Message.. f _ _._ _. 12:07 326.4 10.77 769.2 261.5 6.86 0 0 12:08 333.6 10.74 796.7 268.7 6.83 0 D 12:09 340.5 10.74 750.9 275.6 6.83 0 D 12:10 347.3 10.74 764.7 282.4 6.85 0 0 12:11 354.2 10.74 732.1 289.3 6.83 0 0 12:12 361.1 10.74 773.8 296.2 6.85 D 0 12:13 368. 10.74 173.8 303.1 6.86 D 0 12:14 374.8 10.74 776.4 309.9 6.85 0 0 12:15 382.1 10.74 773.8 317.2 b.85 0 0 12:16 389. 10.74 778.4 324.1 6.85 0 0 12:17 -396. 10.81 760.1 331.1 6.83 D 0 12:18 402.9 10.82 778.4 338. 6.85 D 0 12:19 410.1 10.71 764.7 345.2 6.$5 0 D 12:20 417. 7 0.74 796.7 352.1 6.85 0 0 12:21 424. 10.73 783. 359.1 6.68 0 0 12:22 430.9 10.75 .801.3 _ 366. _ 6.85 0 0 12:23 433.9 10.71 769.2 373. 6.88 0 D 12:24 444.8 10.74 ~ 773.8 379.9 6.88 0 0 12:25 457.7 10.74 778.4 386.8 6.85 0 0 12:26 458.6 10.74 787.5 393.7 6.88 0 D 12:27 465.5 10.74 783. 40D.6 6.88 D 0 12:28 472.4 10.74 778A 407.5 6.85 ~ 0 D Preflush @ shoe 12:29 I 479.4 10.75 769.2 414.5 6.88 0 0 12:30 486.4 10.74 760.1 421.5 6.83 0 0 12:31 493.4 10.74 750.9 428.5 6.86 0 0 Spacer @ shoe 12:32 500.4 10.74 773.8 435.5 6.68 0 D 12:33 507.6 10.74 769.2 442.7 6.88 0 0 12:34 514.5 10.74 778.4 449.6 6.83 0 0 12:35 521.3 10.74 760.1 ' 456.4 6.88 D D 12:36 528.2 10.74 778.4 463.3 6.88 0 0 12:37 535.1 10.73 _ 769.2 470.2 6.88 0 0 Lead cmt @ shoe 12:38 542. 10.74 755.5 477.1 6.86 0 ' 0 12:39 549. 10.74 769.2 484.1 6.88 0 0 12:44 556. 10.73 787.5 491.1 6.88 ; 0 0 12:42 563.4 10.72 755.5 496.5 6.86 0 D 12:43 570.3 10.74 787.5 505.4 6.85 D 0 12:44 ~ 577.4 10.74 815. 512.5 6.86 0 0 12:45 584.5 10.73 773.8 519.6 6.85 0 D 12:46 597.6 10.74 783. 526.7 ' 6.88 0 0 12:43 598.6 10.74 773.6 533.7 6.88 0 D 12:48 605.5 10.74 787.5 540.6 6.65 0 0 12:49 612.4 10.72 778.4 547.5 6.88 0 0 12:50 619.3 10.73 783. 554.4 6.85 0' 0 12:51 626.3 10.4 810.4 561.4 6.83 0 D 12:52 633.2 10.74 787.5 568.3 6.83 D 0 12:53 640.1_ 10.74 819.6 575.2 6.85 0 0 12:54 647. 10.72 796.7 582.1 6.85 ! D 0 12:55 654. ~ 10.74 801.3 589.1 6.85 0 0 12:56 660.9 10.74 810.4 596. 6.85 0 0 1 Z:57 667.8 10.74 837.9 602.9 6.88 D D 12:58 674.7 10.74 805.9 609.8 6.86 0 0 12:59 681.6 10.75 819.6 616.7 6.85 0 0 13:00 688.5 10.71 792.1 623.6 6.88 0 0 RIGS 97 Y2.1aSR Page 3 of 6 • • Well Feb Service Date Customer ~ Job Number VARIOUS #S PRUDHOE BAY ARCO ALASKA INC i 20155120 Tlrll@ ~ CumVol Deneity ~' Prassure tYF ~a hr cxk, .~ bbl PP8 Psi ~Stage'Jalume ~ bbl. ~ TotflowratcT - ~ - ly1~g,~g f ~ bpm 13:01 694. 11.02 238.1 629.1 2.84 0 0 13:02 696.8 10.26 238.1 631.9 2.84 0 0 13:03 696.8 10.26 238.1 631.9 2.84 D 0 Reset Volume 13:03 696.8 10.26 236.1 631.9 2.84 D 0 jStage Volume]=634.6 bb! 13:03 699.8 12.03 251.8 0. 2.62 0 0 13:03 699.8 12.03 251.8 0. 2.62 0 0 Starttail slurry 13:04 703.3 11.78 485.3 3.54 4.44 0 0 13:05 707.8 13.72 563.2 8.02 4.42 0 D 13:06 712.5 15.24 412.1 12.77 5.06 0 0 13:07 717.7 15.57 1364 17.93 5.62 0 0 13:OB 723.5 15.97 1319 23.7 5.66 D 0 13:09 729.3 13.68 943.2 29.53 5.88 0 0 13:10 732.9 15.53 549.5 33.19 3.65 0 0 13:11 737.3 15.64 723.4 37.5 3.99 0 0 13:12 741.3 15.94 718.9 41.5 3.96 0 D 13:13 745.3 i 5.8 _696. 45.54 3.99 0 , 0 13:14 749.5 15.81 696. 49.73 3.99 0 0 13:15 753.7 ~ 15.74 700.5 53.92 3.99 D D 13:16 757.7 15.83 700.5 57.96 3.99 I 0 0 13:17 762. 15.92 718.9 62.21 3.99 0 0 13:18 766. 15.62 709.7 66.21 3.99 0 D 13:19 770.4 15.69 897.4 70.6 I 4.71 0 D 13:20 774.9 15.84 764.7 75.12 ~ 4.28 0 0 13:21 379.1 15.72 783. 79.37 4.25 D 0 13:22 763.7 16.1 961.5 83.94 4.47 0 0 13:23 788.2 16.01 783. 88.4 4.22 0 0 13:24 792.5 15.79 833.3 92.72 4.4 0 0 13:25 797. 15.81 860.8 97.24 4.44 D 0 13:26 807.5 15.82 ~ 647.1 ! 101.7 4.4 0 0 13:27 805.9 15.8 I 837.9 106.2 4.44 0 0 13:28 _ 61 D.5 15.74 847.1 11 D.7 4.44 0 0 13:29 815.1 15.78 833.3 115.4 4.44 0 D I 13:30 819.6 15.77 856.2 119.8 4.44 0 0 13:31 624.2 ! 15.87 879.1 124.4 4.38 D D I 13:32 828.6 ~ 15.9 879.1 126.8 4.4 0 0 13:34 833.1 15.87 660.8 133.4 4.46 0 0 13:35 837.6 15.$2 865.4 137.8 4.44 0 0 13:36 842.1 15.8 842.5 142.4 4.46 D 0 13:37 846.7 15.77 874.5 146.9 4.47 0 0 13:36 851.2 15.8 865.4 151.5 4.51 0 0 13:39 855.8 15.78 879.1 156. 4.51 0 0 13:40 860.3 15.78 870. 160.6 4.54 D 0 13:41 865. 15.81 883.7 165.2 4.51 0 0 __ _ 13:42 869.5 15.57 934.1 169.8 4.71 0 0 13:43 873.5 15.26 544.9 173.7 3.75 0 D 13:44 877.3 15.81 604.4 177.5 3.75 0 0 13:45 880.2 15.84 54.95 180.5 0. D D 13:46 880.2 8.42 50.37 180.5 0. D 0 13:46 680.2 8.42 50.37 180.5 D. 0 0 Drop top plug 13:46 880.2 I 8.42 50.37 180.5 0. 0 0 Reset Volume 13:46 880.2 B.42 50.37 180.5 D. I 0 D [ Staije Volume)=181 bbl 13:47 881.9 9.22 270.1 1.07 4.04 0 0 13:48 ~ 88$.1 8.52 558.6 7.24 6J2 0 D Ries s~ J2.taSR Page 4 of 6 Well Field Service Date -- Customer - Job Humber ' VARI OUS #1 PRUDHOE BAY ARCO ALASKA INC 20155120 Time cumvo! i oensalty P ressureuf StageVOSUme~ TotFlowl'ate I ' Message any F ~ ' cock ', 661 PP9 t Pu bbt ' ~ bpm i '. ' 13:49 895.1 _ ! 8.37 613.6 14.22 6.9 - D ~ -- D __ - 13:49 895.1 8.37 613.6 14.22 6.9 0 0 Start Displacement 13:50 902.1 8.33 604.4 21.18 6.93 0 0 13:51 906.9 8.33 274 7 26.03 -0 6t n n 13:52 911.5 8.31 265.6 30.6 4.49 0 0 13:53 915.4 8.31 54.95 34.55 1.28 0 D 13:54 917.5 9.37 393.8 36.66 5.48 0 0 13:55 923.6 9.77 663.9 42.75 6.08 0 0 13:56 927.3 9.84 265.6 46.38 3.25 0 D 13:57 930.7 9.84 261. 49.8 3.27 0 0 13:58 935.4 9.84 544.9 54.49 4.9 0 0 13:59 940.3 9.85 503.7 ~ 59.38 4.7 0 0 14:00 945.1 9.85 544.9 64.27 4.72 0 0 14:01 949.9 9.84 540.3 69.03 4.7 0 0 14:02 954.8 9.84 567.8 73.96 4.7 0 0 14:03 959.6 9.84 604.4 78.73 4.72 0 0 14:04 964.4 9.85 613.6 83.57 4.7 j 0 0 14:05 969.2 9.85 631.9 88.3 4.72 0 0 14:06 973.9 9.85 650.2 93.05 4.7 0 0 14:07 978.6 9.85 663.9 97.75 ~ 4.67 ~ 0 0 14:08 983.3 9.85 673.1 102.5 4.7 0 D 14:D9 988. 9.84 659.3 107.2 4.7 0 0 14:10 992.8 9.84 673.1 111.9 4.67 0 0 14:11 997.7 9.84 709.7 116.8 4.67 0 0 14:12 1003 9.84 792.1 ~ 121.9 5. 0 0 14:13 _ 1008 9.84 796.7 126.9 5. 0 0 14:14 1013 9.84 810.4 131.9 5.03 0 D 14:15 1018 9.84 833.3 137_ 5.03 0 0 14:16 1023 9.84 842.5 142.3 5. 0 0 14:17 1028 9.84 847.1 147.4 4.98 D 0 14:18 1033 9.84 5562 152.5 5. 0 0 14:19 1038 9.84 856.2 157.5 5.03 0 D 14:20 1043 9.84 851.6 162.6 4.98 0 0 14:21 1049 9.84 865.4 167.8 5. 0 0 14:22 1054 9.83 847.1 172.8 5.01 0 D 14:24 1059 9.83 860.8 178.5 5.01 D 0 14:25 1064 9.84 847.1 183.5 5.03 0 0 14:26 1 D69 9.84 856.2 ~ 188.6 5.03 0 0 14:27 1075 9.85 879.1 ~ 193.7 5.01 0 0 14:28 1 D80 9.85 865.4 198.9 5.01 D 0 14:29 1 D85 9.87 892.9 204.1 5. 0 D 14:30 109D 9.$4 352.6 208.8 0.25 ~ 0 0 14:31 1090 9.73 288.5 206.8 0. 0 ! D 14:32 1090 9.84 279.3 208.8 0. 0 0 14:33 1090 9.84 274.7 208.8 b. 0 0 14:34 1090 9.83 270.1 208.8 0. 0 0 14:35 1090 9.81 270.1 208.8 !, D. 0 0 14:36 1090 9.8 265.6 208.8 D. 0 0 14:37 1090 9.8 265.6 2D8.8 0. 0 0 14:36 1090 9.8 261. 208.8 D. 0 0 14:39 1090 9.8 ~ 261. 208.8 0. 0 0 14:40 1090 9.78 9.16 208.8 0.034 D 0 14:40 1090 9.76 9.16 208.8 D_034 0 0 E ngines died on cementer. ! raw ai vt.ta-Srt Page 5 of 6 • • Well Field Service Date Cusromer Job Number VARIOUS #1 PRUDHOE BAY ARCO ALASKA INC i 201.55120 Tlme ' CumVo1 ! Denyiry ;Pressure tJt Stage Volumer ToiFk>wrate I -- - -- - - - i--_~ ly}es~ye ~ ~4 hr ~ ~ ~ ~ c!eek ! ~ bbl P~ asp I ~ I 14:43 1090 9.78 9.16 208.8 0.034. 0 0 Rig to displace 15:25 Bumped plug, floats held. 16:13 Bumped plug, 16:14 End Job Post Job Sumrttary Average Pump Rates, bpm Volume of Fluid Injected, bbf Slurry N2 Mud Maximum Rate Total Slurry Mud Spacer N2 0 0 0 0 0 0 0 0 Treating Pressure Summary,'psi Breakdown Fluid Maximum Final Average Bump Ptug ro Breakdown Type Vdume Density 0 i 0 0 0 L 0 ~ 0 bbl ~ Olb/gal Avg. N2 Percent Designed Scurry Volume Displacement Mix Water Temp ~ Cement Circulated roSurface? Volume 0 bbl 0 ~ 0 bbl 0 bbl °F tt ~ L1 Washed Thru Perts ro 0 ft Customer or Autlforized Representative Dowell Supervisor GUY WHITIOCK Randy Jost ~ CirculationLost ~ Job Completed Rtcs9~ ~z.ia-sty Page 6:of6 Cementing Job Report PRISM* V2.23 Welt 2T ~~.,~ Client ARCO ALASKA INC Field KUPARUK SIR No. 20155120 Country USA Job Date 4/26!2000 8:02:21 AM Time 0426100 08:D2:21 Messages Density Pressure U1 TotFbwrate 1 I : i : 'START ACQUISITION ~ i ~ ~ ~ ~ _ ~ ~ 'PAUSE ACOUISflION t f I i j ~ ~ ~ j "START ACOUIS(710N 08;24:00 ~ [ 1 r i 1 ~ I 1 [ : •PAUSE AC(UISITION ~ 1 1 ~ [ i t 09:06:00 ; ~ J ` ' t ! I i ji t ~ t ~~ I ' ' ji 9:48.00 1 I [ ~ ~ i r ! t 1 _ 1 1 I 1 j j I I ~ 3 i ~~ i i 10:30:00 r ] 1 l ! 1 ` fl` i ~ i 1 { 1 t r I ~: ~ 1 ~. ~ I j E _ i. ~ I t ~ i - •RESTART AFTER PAUSE 11:12:00 ~ f ~ : ~ 'start Pumping Fluid t ~ *Pressure Test Lines ~ ~ ~ i ~ •Start Pumping Fluid 1 j 'Start Pumping Spacer -. - j j '[Stage Volume)=20.78 bb t ~ j ~ ~ I ~ ~ ~ t ' ~ r ~ ~ Rese[ Volume r ~ ~ I ~ 1 '[Stage Volume]=44.42 bb 11:54:00 ~ I _ j _ r i Reset Voume ~ ` _ ~ ~ ~ j ~ User defined message ( I c f f ~, ~ ~ i, j I ~ ,l Start Lead cement 2:36:00 ;, 't Il ~ ,, i s I .: is _~ i EE ~ k a r ~ I . '[Sorge Volume]=634.6 bb ~ Reset Volume 13:18:00 ~ I l E ~ i ~ I , I r ~ I _. i I Start tail slurry ~ r ~ I ~ f ~ f i ;: f ~ Drop top ptu i ' `[Stage VOlumept6i bbl 14:00:00 ' Reset Volume I ~ a t ~ r 3 ; Start Displacement 14:42:00 3 -~ I ~ ~ I I ~ i { -'~ i ~ i ~ ~, I ~ I ~ [ ~ 4 ~ j PAUSE ACQUISITION hh:mm:ss a Pp9 +a o psi 3500 o bpm s 0426/00 14:44:10 N r f` O 0 N v Mark of Schlumberger • i r ,r ~.~~'1.3 cam, i1~~'~.~ ~~.,~ ~~~ ALASSA OIL A1~TD GAS CO1~T5LRQATIOI~T COMl-II55IOrIT Jim Ennis Wells Group Engineer Conoco Phillips Alaska, Inc. PO Box 100360 ~' ~I>+9~~ ~~~;, ~. ~ ~~~'~ Anchorage, Alaska 99510 ~ "`' SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Tabasco Oil Pool, 2T-217A Sundry Number: 307-364 ~ ~ .v L ~~ Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ay of December, 2007 Encl. Qi n I~PYP~~7 • ConocoPhillips December 6, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval 2T-217A Dear Commissioner: • Jim Ennis Wells Group Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 an~,rc~~1`~ ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to convert well 2T-217A to a water injector. ~ If you have any questions regarding this matter, please contact me at 265-1544. Wells Group Engineer CPAI Drilling and Wells JE/skad 1~EC ~ ~ 200t .Alaska Oil ~ Gas l~~rt~. Cammissior~ Anchorage A ~ s 127 C~1~~~1-~7 STATE OF ALASKA ~ \'1 ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~~~~ DES Q G ?~~~ APPLICATION FOR SUNDRY APPR~V~41~'~ & ~~~ ~~~~ ~~~~~~$;~~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ aroer Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ convert to water infection Change approved program ^ Pull Tubing ^/ 'Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 200-074. 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20334-01 ' 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 Requires? YeS ^ NO ~ 2T-217A 9. Property Designation: ' 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25548, ALK 2662 RKB 35' Kuparuk River Field /Tabasco Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8190' ~ 3414' Casing Length Size MD TVD Burst Collapse CONDUCTOR 82' 16" 121' 1.21' SURFACE 6178' 9-5/8" 6214' 2880' PRODUCTION 2553' 7" 7368' 3064' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): pre-packed gravel pack screens 7418'-7606' 4-1/2" L-80 4685' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- BAKER SC1-R PACKER pkr= 7260' no SSSV 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat December 15, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~- WDSPL Commission Representative: 18. I hereby certify t the foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed a JI1'Tt Er1r11S Title: Wells Group Eng eer - Signature r Phone 265-1544 ~-7 Date r ~ ~ Q Commission Use Only Conditions of approval: Notify Commission so that a re resentative ma witness Sundry Number: ~ ~ - ~ ~~ p y Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other. ~s~pS ~ ~~ ~ ~~5~ ''~~ a ~~ I~Ei; ~ 2001 Subsequent Form Required: ~0 1 APPROVED BY A y~ '~ pproved by: COM SSIONER T O MI I N Date: Form 10-403 Revised 06/2006 Submit in Duplicate ~z.<a.o~ • Well 2T-217A Tabasco Producer Convert to water injection Sundry Procedure Pre-Riq Work: 1. SI ESP. Bleed off any tbg & csg pressure. Remove wellhouse and floor kit. Install BPV. Riq Work: 1. MIRU Nordic #3. Verify that pre-rig work has been completed. Ensure rig is centered over the well. RU air spooler on rig floor. 2. Pull BPV. Flush IA w/ 200 bbls hot seawater at max rate to clean tbg & ESP equipment.. Obtain SI wellhead pressures and verify well is dead (6 ppg needed, calculated from SBHP obtained on 10/15/07). 3. Install BPV. ND tree. Install blanking plug in lift threads. NU 11" BOP. Function and PT BOP rams, .annular and choke manifold to 250/2500 psi. (Call AOGCC 24 hours prior to testing at 659-2714 or pager 659-3607.) 4. Pull blanking plug and BPV. Make sure the hole is static. Screw into the tubing hanger with FMC pulling tool w/side port isolation extension on landing joint and mark the pipe at the rotary table. BOLDS on the tubing hanger. 5. Unland tbg hanger (max allowable pull 167M#) and pull to the floor. Measure and record the distance from the hanger to the mark on the landing joint, Lay down the hanger, etc. RU cable spoolers. Lay down the 4%2" tubing, remove all jewelry, spool up ESP cable. Account for all bands and clamps. Have all downhole equipment that leaves location NORM tested. Note external condition of 4%2" tbg with regards to corrosion. RD the cable spooler, etc. 6. Single in w/ the following on new 4.5", 12.6#, L-80, IBT Mod tbg to tag `SC-1 R' packer @ 7260' MD. a) 4.5" centralized wireline entry guide b) 10' 4.5" handling sub c) 3.75" `DB' nipple w/ `RHC' plug body installed d) 10' 4.5" handling sub w/ `RHC' ball & rod inserted e) 2 joints 4.5" tbg f} 3' 4.5" handing sub g) Baker Premier packer h) Baker 80/47 PBR (pinned 70M# shear) w/ seal stem muleshoe replaced by ported tbg sub, xover & centralized SLB memory SCMT sonde (SCMT sonde ~36' long) i) 10' 4.5" Handling sub j) 4%2", 12.6#, L-80 IBT Mod tubing to surface ]im Ennis Page 1 12/5/2007 • Rig Workover Procedure Well 2T-217A Tabasco Producer Convert to water injection.. 7. .Tag `SC-1 R' packer @ 7260' MD. Space WEG 1 foot above `SC-1 R'. Load tbg w/ seawater & pressure to 4000 psi to set Premier packer. Load IA w/ seawater & PT 2500 psi. 8. Shear PBR and and verify SCMT timer has begun data collection. RU SLB to drill floor depth recorder. POOH logging SCMT @ 30' per minute to 6900' MD. RIH for SCMT repeat pass @ 30' per minute to 7150' MD. POOH logging SCMT @ 30' per minute to 4700' MD (7" TOL @ 4815' MD). Do not attempt to run tools back into liner. Finish POOH w/ tbg. LD memory logging tools and verify data collected. If no data, a post rig RST log during water injection will be used to verify Tabasco zone confinement of injected water. 9. Install muleshoe btm on PBR stem. RIH w/ following 4.5" completion: a) Baker 80/47 PBR seal stem b) 10' 4.5" Handling sub c) 10' 4.5" Handling sub d) Baker `CMD' sliding sleeve (closed) w/ 3.813" `DB' profile e) 10' 4.5" Handling sub f) 4%2", 12.6#, L-80 IBT Mod tubing g) 3.875" `DB' nipple @ 500' (4.5" tbg above must drift 3.91") h) 4%2", 12.6#, L-80 IBT Mod tubing to surface 10. Close annular & load IA w/ 150 bbls corrosion inhibited seawater (1 % by volume Baker Petrolite CRW-132) followed by 215 bbls diesel (2000' TVD freeze protect) prior to stabbing into PBR. Equalize tbg & IA to allow fluids to balance. Open annular.. Tag locator on PBR & space out to land tbg 2' off bottom. MU tubing hanger and land tbg w/ FMC running tool w/side port isolation extension on landing joint. RILDS. RU chart recorder to tbg & IA. PT tubing to 2500 psi for 15 minutes. PT IA 2500 psi for 30 minutes. Back out the landing joint & LD. Install TWC. NDBOP. NUWH w/ new vertical tree oriented as shown on wellhead orientation diagram. Test tree to 5000 psi. Test the hanger void/packoff to 5000 psi. Replace TWC w/ BPV. RDMO. Turn well. over to Wells Group via handover form. Post-Rig Work:. 1. Reset wellhouse and floor kit. Install flowline rise for water injection. Pull BPV. 2. RU slickline. Attempt to retrieve ball/rod & `RHC' plug. If necessary, RD slickline & retrieve w/ CT. 3. Perf 4" Excluder screens 7418'-7500' MD. Jim Ennis Page 2 12/5/2007 • Rig Workover Procedure Well 2T-217A Tabasco Producer Convert to water injection 4. RU CT. Spot and down squeeze cmt 7450'-7500' MD to force water injection into top of Tabasco interval 5. If necessary, perform RST Jim Ennis Page 3 12/5/2007 . ~~_~ ! r ~ ~` Cc~n~aca~~~11i-~ A~~s~Ca~ ~r~~. 2T-217A - APL 501032033401 Well T e: TuaING SSSV Type: NONE Orig (o-4sas, OD:4.500, Com letion: ID:3ss3) - ~ Annular Fluid: Last W/O: SURFACE (0-6214, OD:9.625, Wt:40.00) GAUGE (4683-4684, OD:4.500) PUMP (4685-4703, OD:4.500) PUMP (4703-4711, OD:4.500) SEAL (4711-4725, OD:4.500) MOTOR (4725-4747, OD:4.500) 'RODUCTION (4815-7368, OD:7.000, Wt:26.00) PKR (7260-7264, OD:6.276) Gravel Pack Screens (7260-7695, OD:4.500) SLEEVE (7345-7346, OD:4.500) Perf (7418-7643) SCREENS (7418-7643, OD:4.500) i i k w ~~~ • KRU 2T-217A _~ An le TS: de a) Angle @ TD; 59 deg @ 8190 Rev Reason: CORRECT SCHEMATIC Last Ta : 4662' SLM TD: 8190 ftKB Last Tag Date: 9/5/2007 Max HaIP Angle: R1 dPn n 6ROR Casing String -ALL _ _ I floc.,ri n4inn - _ -. __ _V -r.,...__ I o..ee..... I rein.. _ _. - _ CONDUCTOR 16.000 0 .121 121 62.58 H-40 WELDED SURFACE 9.625 0 6214 2826 40.00 L-80 BTCM PRODUCTION 7.000 4815 7368 3064 26.00 L-80 BTCM laraV01 YBCK screens I 4.bUU I /Y(5U I 31 /8 I U.UU I 0 I /6yb I SLHT I Tubing String -ALL _ I Size _ ~ Top Bottom ND Wt I Grade _ Thread _ 4.500 ~ O ~ d;35 i - ~ ~ ~3 _ I 1 ? 6(~ 130 I NSCT Perforations Summary Interval TVD Zone Status Ft - SPF Date T e _ Comment - - 7418 - 7643 3080 - 3158 225 99 5{28/2000 Screen Prepacked SLHT Screen - 1 /8" x 3 9/16" I Gas Lift Mandrels/Valves i St MD TVD Man Mfr Man Type V Mfr V Type V OD -Latch Port TRO Date Run V1v Cmnt 1 1950 1690 CAMCO KBG2LS CAMCO DMY 1.0 BK 0.000 0 6/12/2000 Other~plu~s, eguip., etc - _ .) - COh4PLETlON, - - _ _ -- - -- - De th TVD T e Descri tion ID 3039 2008 HEAT HEAT TRACE 0.000 TRACE I 4725 12454 I MOTOR I CENTRILIFT 266 HP 2345V 69A 562 SERIES I 0.000 I SHOE (7693-7694, OD:4.500) • 2T-217A Proposed Injection Conversion Curren t Wellbore 16" csg @ 121' 4.5" tbg' Mtr btm @ 4747 ~ E S P Proposed Wellbore 3.875" `DB' nipple `ZXP' @ 4815' Window for 7" 4997'-5007' 9 5/8" csg @ 6214' `CMD' sliding sleeve w/ 3.813" `DB' profile Premier pkr @ 7170' 3.75" `DB' nipple `SC-1 R' pkr @ 7260' 7" csg @ 7368' Top of screens 7418' 4" 12/20 Prepacked Screens ~ ) Btm of screens 7643' 4" Liner @ 7695' ~; Sand Plug ~:,3<~~ ,: Driller's TD 8190' TOC @ ~7450'MD Screens perF'd 7418'-7500'MD • • Review of Sundry Application 307-364 ConocoPhillips Alaska, Inc. Kuparuk River Unit 2T-217A Kuparuk River Field, Tabasco Oil Pool AOGCC Permit 200-074 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to convert an existing development wellbore to water injection. Recommendation: I recommend approval of CPAI's proposed actions Discussion: CPAI proposes to convert well 2T-217A from development oil status to water injection service. On December 13, 2007, I called Mr. Jim Ennis with CPAI to discuss the proposed work. Mr. Ennis indicated that the conversion is intended to provide water injection lower on the structure than currently occurs to support production for other Tabasco wells. Additionally, water injection in the Tabasco pool slumps to the base of the formation rather quickly and CPAI plans to inject near the top of the formation in the subject well to hopefully provide better sweep efficiency for the upper portion of the formation. The well is currently producing about 150 BOPD with a GOR of about 300 SCF/STB and a 65% water cut. Although, the well is producing reasonably well conversion to water injection should improve recovery on a pool wide basis. Conclusion: Converting this well to WAG injection service should improve recovery from this pool. Therefore, it is prudent to authorize CPAI to perform their requested actions because of the future bene~fi~ts that should be achieved. D.S. Roby /L"~ Reservoir Eng' eer December T3, 2007 ~'"..(....., .,,¡. ., . . . . . .' .' . ", ~ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill No. 2000740 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. KUPARUK RIV U TABS 2T-217A Operator PHILLIPS ALASKA INC. MD 8190 TVD 3414 Completion Date 6/3/2000/'- Completion Status 1-OIL Current Status 1-OIL AP1 No. 50-103-20334-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Interval Data Digital Digital/,, Log Log Run OH / Dataset Type Media Format l~m,e Scale Media No Start Stop CH Received Number PEX/NEUT/3 Der D ~k"//GR/Res 'I'VD ~/ PEX/HRLA MD ,-~Hole Volume Log LIS Verification PEX/NEUT/3 Det D ~MWD LIS GR/Res MD - PEX/HRLA TVD ~ SRVY RPT Comments 5 comp 7368 8155 OH 1/3/2001 BL, Sepia 25 FINAL 4975 8190 CH 1/9/2001 BL, Sepia 5 FINAL 7368 8120 OH 1/3/2001 BL, Sepia O 1/3/2001 09849 7312-8155 C 2/22/2001 09901 4974-8145 2 FINAL 7368 8155 OH 1/3/2001 BL, Sepia FINAL 2/22/2001 LIS Verification Paper Copy 2 comp 7368 8155 OH 1/3/2001 BL, Sepia 1/9/2001 Verification Listing 25 FINAL 4975 8190 CH 1/9/2001 BL, Sepia 5 FINAL 7368 8120 OH 1/3/2001 BL, Sepia 84 8190 OH 6/8/2000 SPERRY 4976.. Well Cores/Samples Information: Name Start Interval Dataset Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ' Y~ Chips Received? ~ Analysis Received? ~ Daily History Received? (~N Formation Tops Receuived? (~/N Permit to Drill No. 2000740 DATA SUBMITTAL COMPLIANCE REPORT 5/13/2002 Well Name/No. KUPARUK RIV U TABS 2T-217A Operator PHILLIPS ALASKA INC. AP1 No. 50-103-20334-01-00 MD 8190 Comments: TVD 3414 Completion Date 6/3/2000 Completion Status 1-OIL Current Stares 1-OIL UIC N Compliance Reviewed By: PI-i "LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-217A (200-074) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation operations on the KRU well 2T-217A. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED OO 1' l 7 2CC1 /]la$1fa Oil & Gas Coas. Commismor AnChor~,e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 115 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 4523' FNL, 4723' FEL, Sec. 1, T11 N, RSE, UM (asp's 498945, 5970735) 2%217A At top of productive interval 9. Permit number / approval number 769' FSL, 2595' FEL, Sec. 36, T12N, R8E, UM (asp's 501071, 5976029) 200-074 / At effective depth 10. APl number 50-103-20334-01 At total depth 11. Field / Pool 4246' FNL, 1980' FEL, Sec. 36, T12N, R8E, UM (asp's 501685, 5976292) Kuparuk River Field/Tabasco Oil Pool 12. Present well condition summary Total depth: measured 8190 feet Plugs (measured) true vertical 3414 feet Effective depth: measured 7695 feet Junk (measured) true vertical 3178 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SURFACE 5098' 9-5/8" 803 sx AS III Lite, 871 sx Class G 5213' 2591' PRODUCTION 2553' 7" 5o8 sx C~ass G 7368' 3064' Perforation depth: measured 7418'-7606' pre-packed gravel pack screens true vertical Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 4685' MD. 4la$tcaOi/(~ Gas Packers & SSSV (type & measured depth) NoBAKERsssvSCI'R PACKER @ 7260' MD. .,~lip. h2Ofi$....,,u/~,qR 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 387 47 37 - 292 Subsequent to operation 753 73 53 305 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ X Gas m Suspended __ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed ,~¢( ~)dt¢~7~- /'0'7 /f~, //~,d",w~_ Title Staff Engineer Date Michael Mooney Prepared by Sharon A//sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2T-217A Event History 08/18/01 ACID STIMULATION COMPLETED PER PROCEDURE W/390 BBLS 7.5% HCL, 3% ACEDIC - 195 BBLS 3% ACEDIC, 760 BBLS 3% KCL WATER INCLUDING SURFACTANTS AND STABILIZERS, 3 NITROGEN FOAM DIVERTER STAGES AND 150 BBLS DIESEL FREEZE PROTECT - READY FOR FLOWBACK [OTHER STI Page 1 of I 9/7/01 Sch mberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 757 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 2T-'217a 202'3? .R~.,A/'PEX 000523 ......... 1 ........ 2T-217A 20237 PEX-HRLAMD 000523 I 1 2T-2~TA 20237 PEX-HRLATVD 000523 1 1 , 2T-217A 20237 PEX-CNL 3 DET DENSITY MD 000523 I 1 2T-217A 20237 PEX-CNL 3 DET DENSITY TVD 000523 I 1 2T-217A 20237 CEMENt/HOLE VOLUME LOG 000523 I 1 · , , , , DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 12/4/00 OO-0'7 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 14, 2000 RE: MWD Formation Evaluation Logs 2T-217A, AK-MM-00047 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2T-217A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103 a20334-01 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-103-20334-01 Blueline Folded Sepia Blueline Folded Sepia To; WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 26, 2000 MWD Formation Evaluation Logs 2T-217A, AK-MM-00047 1 LDWG formatted Disc with verification listing. API#: 50-103-20334-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: t[~/O] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas D Suspended BI Abandoned BI Service F1 2. Name of Operator '~V~ i, 7.~,.~ Permit Nu mber Phillips Alaska, Inc. 200-074 & 300-141 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-103-20334-01 4. Location of well at surface ~ ~;0¢?I ~?;; ..... ~ 9. Unit or Lease Name 755' FSL, 556' FWL, Sec. 1, T11N, R8E, UM ( ASP: 498944.8, 5970735) ~ ' '~ ''~' ~ Kuparuk River Unit FSL, 2595' FEL, Sec. 36, T12N, R8E, UM (ASP: 501070.6, 5976029) ~ ~L-~ 769' 2T-217A At Total Depth ~%~-~.~ ;' 11. Field and Pool 1032' FSL, 1981' FEL, Sec. 36, T12N, RSE, UM (ASP: 501684.5, 5976292) Kuparuk River Field 5. ~levation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. I , RKB 34 feet ADL 25548 & ALK 2662 Tabasco Oil Pool 12. Date Spudded 13. Date T.D. Reached ~14. Date Comp., Susp. Or Aband. ~ 15. Water Depth, if o~hore 16. No. of Completions April 21,2000 May 23, 2000 June 3, 2000 ~ WA feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickness of Permafrost 8190' MD/3414' TVD 7695' MD/3178'TVD YES ~ No ~~ N/A feetMD 1624' (approx) 22. Type Electric or Other Logs Run MWD/G~PWD, DP conveyed: T-combo w/laterolog 23. CASING, LINER AND OEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BO~OM HOLE SIZE CEME~ING RECORD[ AMOUNT PULLED 16" 62.5¢ H-40 Sudace 118' 24" 9 cu yds High Early 9.625" 40¢ L-80 Sudace 6214' 12.25" 803 Sx AS III Lite & 871 Sx Class G 7" 26¢ L-80 4815' 7368' 8.5" 5O8 sx Cla~ G 4.5" 7260' 7695' Screens 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 4747' 7260' 7418'-7606' Pre-Packed Gravel Pack Screens 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A .,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~, etc.) July 2, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OIL RATIO W21/2000 20.0 Test Period > 332 20 39 176~ 92 Flow Tubing Casing Pressure Calculated OIL-BBL 'GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Pre~. 296 psi N/A 24-Hour Rate > 378 35 48 N/A 28. CORE DATA Brief description of lithology, porosity, flactures, apparent dips and pressence of oil, gas or water. Submit core chips. WA Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Tabasco Base Tabasco GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 3089' 7445' 7984.5' 3310' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with dies 31. LIST OF ATTACHMENTS Summary of Daily Operations and Directional Survey 32. I hetby certify that the following is true and correct to the best of my knowledge. Signed ,~j ~ I/~I~,%/ ,~,,./ ~r"Title Drilling Team Leader Randy Thomas Questions? Call Tom Brockway 263-4135 INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, ~, ,,.:~ ~, .= ,~-.'~ Shut-in, Other-explain. ~"":'" ..... ?~ ~ .... i': ~'F'~ ~o...~ Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-217 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: WEST SAK SPUD:04/21/00 START COMP: __ RIG: NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20334-00 04/20/00 (D1) TD/TVD: 117/117 SUPV:G.R. WHITLOCK MW: 8.8 VISC: 295 PV/YP: 34/47 117) CHANGING AIRBOOT IN BELL NIPPLE APIWL: 9.2 prep rig for move. Move rig to 2T-218. NU diverter system. Accept rig $ 0900 hrs 4/20/00. Function test diverter and hold pre-spud meeting. 04/21/00 (D2) MW: 9.1 VISC: 220 PV/YP: 29/41 APIWL: 7.8 TD/TVD: 1169/1000 (1052) DRILLING $ 1650' SUPV:G.R. WHITLOCK Tag ~ 96' Fill hole. Airboot in bell nipple leaking. POOH. Change airboot. RIH. Drill from 96' to 1169'. 04/22/00 (D3) MW: 9.5 VISC: 205 PV/YP: 43/68 APIWL: 6.2 TD/TVD: 3333/2081 (2164) DRILLING $ 3900' SUPV:G.R. WHITLOCK Drill from 1169' to 3333' Pump sweep. Circ until clean. Short trip 10 stands to 2389' Tight $ 2768' and 2518'. RIH w/no problems. Circ after wiper trip. 04/23/00 (D4) MW: 9.8 VISC: 204 PV/YP: 33/49 APIWL: 5.4 TD/TVD: 5227/2081 (1894) DRILLING ~ 5700' SUPV:G.R. WHITLOCK Circ hole clean. Drill from 3333' to 4325' Well appears to be flowing on connections. Circ and increase weight to 9.8 ppg. Drill from 4325' to 5227' 04/24/00 (D5) MW: 10.0 VISC: 188 PV/YP: 32/46 APIWL: 5.0 TD/TVD: 6228/2881 (1001) SUPV:G.R. WHITLOCK Drill from 5227' to 6228'. Pump sweep and CBU. Pull 5 stands. Pump out of hole to 3811'. POOH to 2350'. RIH. Pump Sweep. Circ. 04/25/00 (D6) TD/TVD: 6228/2881 ( SUPV:G.R. WHITLOCK MW: 10.0 VISC: 65 PV/YP: 29/34 APIWL: 6.2 0) CIRC AND CONDITION MUD PRIOR TO CEMENTING Circ and condition mud for casing run. POOH. Backream to HWDP ~ 1077' Hold safety meeting. Run 9-5/8" casing. RIH to 3040'. Circ and condition mud. Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/26/00 (D7) TD/TVD: 6228/2881 SUPV:G.R. WHITLOCK MW: 9.8 VISC: 47 PV/YP: 19/19 0) N/U BOPE APIWL: 6.8 RIH w/9-5/8" casing. CBU ~ 4560'. RIH to 6213'. Circ and condition mud. Cement casing. Bump plug, floats, OK. ND diverter. N/U BOPE. 04/27/00 (D8) TD/TVD: 6228/2881 ( SUPV:G.R. WHITLOCK MW: 9.5 VISC: 44 PV/YP: 14/10 0) M/U BHA APIWL: 6.8 NU BOPE and test to 250/5000 psi. Top rams failed test, change out. Test floor valves, IBOP's, blinds to 250/5000 psi. RIH to 6000' Break circ. tag at 6085' 04/28/00 (Dg) MW: 9.4 VISC: 43 PV/YP: 14/14 TD/TVD: 6248/2881 ( 20) DRILLING ~ 6675' SUPV:G.R. WHITLOCK APIWL: 7.4 Wash and work magnet. POOH. Circ out thick mud. Hold pre-job safety meeting. Perform stripping drill. Trip in to 6080' Circ and condition mud. Test casing to 3000 psi for 30 min. OK. Drill cement and float equipment. Drill from 6228' to 6248'. CBU. Perform LOT to 16.1 ppg. perform PWD baseline test. 04/29/00 (D10) MW: 9.5 VISC: 47 PV/YP: 18/24 TD/TVD: 6975/3091 ( 727) RIH W/ 7" LINER SUPV:G.R. WHITLOCK 04/30/00 (Dll) TD/TVD: 6975/3091 SUPV:G.R. WHITLOCK APIWL: 5.2 Drill from 6248' to 6975'. Circ sweep around. Monitor well. POOH to 6173'. RIH. Circ sweep and add lubricants. POOH wet to shoe. Pump pill and drop rabbit. Safety meeting. MW: 9.6 VISC: 44 PV/YP: 15/17 0) RUNNING KILL STRING APIWL: 5.4 Safety meeting. RIH w/7" liner. CBU. Pump cement. Set liner hanger and liner top packer. Test casing and liner to 3000#, OK. 05/01/00 (D12) TD/TVD: 6975/3091 ( SUPV:G.R. WHITLOCK 05/11/00 (D13) TD/TVD: 6975/3091 ( SUPV:FRED HERBERT MW: 8.6 VISC: 0 PV/YP: 0/ 0 0) RIG RELEASED TO 2T-204. N/D XMAS TREE APIWL: 0.0 POOH. Safety meeting. Run 4.5" tubing. Freeze protect with diesel. Safety meeting. N/D BOP stack. N/U Xmas tree and test to 250/5000#, OK. Released rig ~ 2400 hrs. 5/1/00. MW: 0.0 VISC: 0) P/U DP 0 PV/YP: 0/ 0 APIWL: 0.0 Jack up rig, move to 2T-218. Spot rig over well. Rig accepted on 2T-218 ~ 1100 hrs. ND tree. NU BOPE. Pull 4.5" tubing. Test BOPE to 250/3000 psi. il~i!~?%~ ..... ~i~."i!~[[.~'~'~ Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/12/00 (D14) MW: 9.2 VISC: 49 PV/YP: 14/24 TD/TVD: 7028/3108 ( 53) DRILLING AHEAD @ 7370 SUPV:FRED HERBERT APIWL: 4.0 Test BOPE complete to 250/3000. PJSM. Tag cement stringers ~ 6730'. Clean out to 6750' Displace well w/9.2 LSND mud. Vac truck problems unloading mud. Clean out cement stringers from 6750' to 6846' Circ out cement contaminated mud. Test casing to 3000psi. Drill cement. Drill 20' new hole to 6995'. Circ for FIT. Perform FIT to 13.7 ppg. Displace well w/baradrill-n mud. Drilling from 6996' to 7028' 05/13/00 (D15) MW: 9.3 VISC: 51 PV/YP: 20/29 APIWL: 4.6 TD/TVD: 7930/3459 ( 902) POOH SUPV:FRED HERBERT Drilling from 7028' to 7930'. Circ sweep around, monitor well, pump slug. POOH to shoe. 05/14/00 (D16) MW: 9.2 VISC: 46 PV/YP: 12/21 APIWL: 9.2 TD/TVD: 7930/3459 ( 0) RIH W/ CIBP SUPV:FRED HERBERT POOH 20 stands. Well flowing (breathing). RIH slow. Circ & even mud out ~ 9.3+ppg. Monitor well. POOH to shoe. PJSM. RIH with cement retainer. Set ~ 6880' Sting into retainer. Pump cement. POOH. 05/15/00 (D17) MW: 9.2 VISC: 46 PV/YP: 12/21 APIWL: 9.2 TD/TVD: 7930/3459 ( 0) RIG RELEASED ~ 09:00 HRS F/ 2T-218 TO 2T-218A SUPV:FRED HERBERT/MOOSE CUNNINGHAM Hold PJSM. Circulate hole clean. Pick up bridge plug and RIH slow to 5014'. Drop ball. Pump ball to seat. Set bridge plug and check, OK. Release rig from 2T-218 ~ 0900 hrs. 5/15/00 WELL:2T-217A STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TABASCO SPUD:05/15/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: -- WI: 0% SECURITY:0 API NUMBER: 50-103-20291-01 05/15/00 (D1) MW: 9.8 VISC: 55 PV/YP: 21/30 APIWL: 6.4 TD/TVD: 0/3459 ( 0) CIRC FOR LOT SUPV:FRED HERBERT / MOOSE CUNNINGHA Hold PJSM. RIH slow with Whipstock, set @ 5015' Change over mud system to 9.8# mud. Cut window from 4991' to 4996'. Mills hung up, work pipe free while circulating sweep. Cut window from 4996' to 4997' Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 05/16/00 (D2) MW: 9.9 VISC: 48 PV/YP: 16/27 APIWL: 6.6 TD/TVD: 5262/2605 (5262 DRILLING ~ 5600' SUPV:G.R. WHITLOCK / MOOSE CUNNINGH Mill window from 4997' to 5007' Drill new hole to 5029' Circ sweep around. Perform LOT to 13.5 ppg EMW. Monitor well. Pump dry job. POOH. RIH to window. Orient to window and slide through w/no problems. Drill from 5029' to 5262' 05/17/00 (D3) MW: 9.8 VISC: 50 PV/YP: 18/29 APIWL: 5.8 TD/TVD: 6296/2842 (1034) CIRC ON BOTTOM BEFORE DRILLING AHEAD SUPV:G.R. WHITLOCK / MOOSE CUNNINGH Drill from 5262' to 5500' Circulate slow while changing shaker screens. Drill from 5500' to 6103'. Circ sweep around. Drill from 6103' to 6296' ECD's climbing to 11.4 ppg. Circ sweep around for short trip. POOH to window. Started to swab at 5650'. Pump out of hole every other stand to shoe. Circ at shoe to clean casing and lower ECD's. 05/18/00 (D4) MW: 9.8 VISC: 49 PV/YP: 17/27 APIWL: 5.5 TD/TVD: 7368/3065 (1072) RIH AFTER SHORT TRIP (CASING PT ~7368') SUPV:G.R. WHITLOCK / MOOSE CUNNINGH PJSM. TIH slow, break circulation slow, wash 90' to bottom. Pump sweep. CBU 2 times. Perform baseline ECD test. Drill from 6296' to 6776'. PJSM. Drill from 6776' to 7064'. Pump sweep, circulate sweep around. Drill from 7064' to 7368' Circulate sweep 2 times. POOH, start to swab ~ 6780' Circulate and pump out to 6690' Start to swab, start pumping each stand out to shoe slow. 05/19/00 (D5) MW: 9.8 VISC: 44 PV/YP: 15/20 APIWL: 5.8 TD/TVD: 7368/3065 ( 0) CEMENT 7"CASING SUPV:G.R. WHITLOCK / MOOSE CUNNINGH PJSM, back ream to shoe. Monitor well, OK. Circulate and reciprocate. Monitor well, OK. TIH, wash 90' to bottom, no problems, hole good. Pump sweep. PJSM. TOOH to shoe. POOH. PJSM. Run 7" casing. CBU. RIH. CBU ~ 4966'. RIH. 05/20/00 (D6) MW: 9.8 VISC: 42 PV/YP: 14/18 APIWL: 6.0 TD/TVD: 7368/3065 ( 0) CIRC PRIOR TO LEAKOFF TEST SUPV:G.R. WHITLOCK / MOOSE CUNNINGH RIH w/liner on 4" DP. CBU. Pump cement. Dropped plug. Set hanger, liner top packer and released from hanger. CBU. RIH. 05/21/00 (D7) MW: 9.2 VISC: 50 PV/YP: 14/28 APIWL: 4.2 TD/TVD: 7659/3612 (291) OUT OF HOLE BIT CHECK SUPV:G.R. WHITLOCK / MOOSE CUNNINGH PJSM. TIH to 7242', tag LC. Perform casing test. Drill on LC, cement, FC, FS and 20' new hole to 7388'. CBU for LOT=9.8 MW. Perform LOT (16.7). Drill from 7388' to 7485' PJSM. Drill from 7485' to 7659' Date: 06/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 05/22/00 (D8) MW: 9.2 VISC: 46 PV/YP: 11/25 APIWL: 4.6 TD/TVD: 8117/3377 ( 458) WIPER TRIP SUPV:G.R. WHITLOCK CBU. POOH to 7437' Take check shot survey. POOH. RIH. Drill from 7659' to 8117' 05/23/00 (D9) MW: 9.2 VISC: 50 PV/YP: 12/25 APIWL: 4.6 TD/TVD: 8190/3414 ( 73) R/D WIRELINE SUPV:G.R. WHITLOCK Drill from 8117' to 8190'. CBU. POOH to 6850'. Monitor well. RIH> CBU. POOH to shoe. Safety meeting. RIH to 7193' Safety meeting. 05/24/00 (D10) MW: 9.2 VISC: 44 PV/YP: 10/23 APIWL: 4.5 TD/TVD: 8190/3414 ( 0) POOH AND LET SAND SETTLE SUPV:G.R. WHITLOCK/M WINFREE/D.CUNN Run DP conveyed logs from 7365' to 8167' PJSM. RIH w/mule shoe to 8190', no fill. Circ BU. PJSM. RU to spot sand plug. Pump cement. Pull back to shoe and let sand settle. RIH to TD, no sand. Circ. RU to spot sand on bottom. Pump sand. Pull back up to shoe. CBU and let sand settle. 05/25/00 (Dll) MW: 9.2 VISC: 41 PV/YP: 9/21 APIWL: 4.7 TD/TVD: 8190/3414 ( 0) CIRC SUPV:G.R. WHITLOCK/M WINFREE/D.CUNN RIH and tag top of sand ~ 8138' PJSM. Pump sand plug. POOH to 6900'. Circ, recip, and rotate. RIH to 7967' and tag up on sand plug. PJSM. Pump sand slurry. RIH to 7840' tag sand plug. Wait on sand to settle. RIH and tag sand at 7768' POOH rotating to shoe. RIH tag sand at 7750'. 05/26/00 (D12) MW: 9.2 VISC: 42 PV/YP: 10/22 APIWL: 4.7 TD/TVD: 8190/3414 ( 0) CLEANING PITS SUPV:G.R. WHITLOCK/M WINFREE/D.CUNN Pump sand slurry. POOH. Trip in hole to 7636' tag sand plug screw into TD. Wash sand to 7680' Pump sand plug #8. POOH to shoe. RIH to 7666' and tag sand. Wash down to 7700' 05/27/00 (D13) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 ( 0) CLEANING PITS SUPV:G.R. WHITLOCK/M WINFREE/D.CUNN POOH to 7040'. CBU. RIH, tag @ 7700' POOH to 7325'. Pump mud from pits and clean. RIH to 7660'. Displace openhole w/brine pill. POOH to shoe. Pump brine and flush surface equipment. Da te: 06 / 23 / 00 ARCO ALASKA INC. ~k<~[ ([.~!~ .i~ ~ ~il.i.~i !3~ ~i.~:[~i~i~¥ i[~.?,~age: 6 WELL SUMMARY REPORT MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) RIH W/ PREPACKED SCREENS SUPV:G.R. WHITLOCK/M WINFREE/D.CUNN Clean pits. Circ caustic wash around. Circ and filter brine. R/U to pickle w/acid. Pickle drillpipe w/HC1 and reverse out RIH and tag sand at 7700'. POOH. R/U to run prepacked screens, 05/28/00 (D14) TD/TVD: 8190/3414 05/29/00 (D15) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 ( 0) RUNNING ESP AND 4-1/2" TUBING SUPV:G.R. WHITLOCK/M WINFREE/S. GOL RIH w/screens, inner string and packer. RIH w/screens. Set packer. Spot enzyme pill and wash screens. POOH. Run 4.5" tubing. 05/30/00 (D16) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 0) RIH W/ MAGNET TO RECOVER LOST BANDS. SUPV:FRED HERBERT / S. GOLDBERG POOH w/tubing. Run ESP completion. Megger every 10 stds would not megger ~ std 10. POOH w/tubing. Megger every 5 stds. Check out motor lead. Bad pothead. Begin repair lead. 05/31/00 (D17) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 0) M/U ESP ASSEMBLY AND SENTRY GAUGE SUPV:FRED HERBERT / S. GOLDBERG Repairing motor lead cable. Y block would not go past 20' Pull Y block out of hole. RIH with fishing tools. POOH with magnet. No band recovery. RIH with junk basket. Wash down. POOH with junk basket. No recovery. 06/01/00 (D18) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 0) POOH WITH REVERSE CIRCULATING JUNK BASKET SUPV:FRED HERBERT / S. GOLDBERG RIH with ESP to 1812' R/U to run heat trace cable. Attempt to megger power cable. Cable would not test. Change meters and retest without success. POOH with ESP assembly. Test each piece. Test all BOP components. RIH with reverse circulating sub on 4.5" tubing. 06/02/00 (D19) MW: 9.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 0) RUNNING ESP COMPLETION WITH HEAT TRACE SUPV:FRED HERBERT / S. GOLDBERG Continue running in hole with reverse circulating junk basket to 2340'. Wash down from 2340' to 2404'. Continue running in hole, wash down from 4720' to 4912', run in hole wash down from 5970' to 6065', RIH to 7124', wash down from 7124' to 7219' POOH. PJSM. RIH with ESP completion. 06/03/00 (D20) MW: 9.2 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8190/3414 ( 0) RIG RELEASED ~ 24:00 HRS FROM 2T-217A TO MOVE TO 2T-20 SUPV:FRED HERBERT / S. GOLDBERG PJSM. Run 4.5" ESP completion. ND BOPE. NU tree and test. Freeze protect well. Set BPV. Secure well. Rig released from 2T-217 @ 2400 hrs. 6/3/00. SURVEY CALCULATION AND FIELD WORKSHEET job No. 0.50-00031 No.' - m ~:i=/~-1~ Company PHILLIPS ALASKA, INC. Rig Contractor & No. NABORS 16E Field KUPARUK RIVER UNIT m~ ~-m~m~,,,~ Well Name & No. PAD 2T/217A Survey Section Name SPERRY MWD BHI Rep. R. BARNARD WELL DATA Target'l'VD (F-r) Target Coord. N/S Slot Coord. N/S 768.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS[~ Target Description Target Coord. EAN Slot Coord. E/W 556.00 Magn. Declination 26.350 Calculation Method MINIMUM CURVATURE ___ Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~] 10m[~ Vert. Sec. Azim. 23.48 Magn. to Map Corr. 26.350 Map North to: OTHER ............. ' SU,I=":.vFY DATA ....... Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool N(+)'/S(-) ' "Ei+)/W(-)-~ DL Build (+) Right (+) Comment Depth Angle Direction Length TVD Section Type (F-r) (DD) .. (DD) (FI'). (FT) . (FT) (FT) (Per ~00 F'r) Drop (-) Left (-) MWD 4986.00 72.78 7.63 I 2528.82 3530.02 3597.14 576.79 TIE IN POINT / . 16-MAY-00 MWD 4991.00 72.84 7.60 5.00 2530.30 3533.70 3601.87 577.42 1.33 1.20 -0.60 PROJECTED FROM WHIPSTOCK ,, , 16-MAY-O0 MWD 5007.00 74.00 8.75 16.00 2534.86 3548.49 3617.05 579.60 10.00 7.25 7.19 PROJECTED FROM WHIPSTOCK ..... 16-MAY-00 MWD 5029.00 74.30 11.01 22.00 2540.87 3569.06 3637.90 583.24 9,98 1.36 10.27 PROJECTED MILL BURY DEPTH .... 16-MAY-00 MWD 5109.59 74.01 16.02 80.59 2562.89 3645.39 3713.25 601.34 5.99 -0.36 6.22 GOOD SURVEY 16-MAY-00 MWD 5174.98 73.79 17.10 65.39 2581.02 3707.75 3773.47 619.25 1.62 -0.34 1.65 ...... 17-MAY-00 MWD 5271.14 74.15 20.54 96.16 2607.58 3799.85 3860.94 649.06 3.46 0.37 3.58 17-MAY-00 MWD 5371.07 74.11 21.15 99.93 2634.91 3895.87 3950.77 683.27 0.59 ,0.04 0.61 ...... 17-MAY-00 MWD 5467.73 74.96 21.39 96.66 2660.69 3988.96 4037.58 717.06 0.91 0.88 0.25 ............. 17-MAY-00 MWD 5563.11 76.27 22.25 95.38 2684.38 4081.31 4123.35 751.40 1.63 1.37 0.90 17-MAY-00 MWD 5655.05 77.54 26.13 91.94 2705.22 4170.83 4205.01 788.09 4.34 1.38 4.22 ............ 17-MAY-00 MWD 5750.46 77.42 . 29.85 95.41 2725.91 4263.67 4287.24 831.80 3.81 -0.13 3.90 ..... 17- MAY.O0 MWD 5848.90 77.69 37.40 98.44 2747.15 4358.21 4367.22 884.99 7.49 0.27 7.67 I ..... ~'- , 17-MAY-00 MWD 5944.32 77.64 43.21 05.42 2767.55 4447.40 4438.27 945.26 5.95 -0.05 6.09 17-MAY-00 MWD 6040.81 77.35 44.28 96.49 2788.45 4535.77 4506.33 1010.39 1.12 -0.30 1.11 17-MAY-O0 MWD 6135.39 - 77.06 46.07 94.58 2809.39 4621.46 4571.34 1075.81 1.87 -0.31 1.89 17-MAY-O0 MWD 6232.76 78.39 49.49 97.37 2830.10 4708.16 4635.26 1146.26 3.69 1.37 3.51 17- MAY-O0 MWD 6327.96 79.20 49.82 95.20 2848.60 4791.97 4695.72 1217.43 0.92 0.85 0.35 ...... ~ : ~---~----':- .. ~:~_._~ 17-MAY-00 MWD 6422.29 78.14 49.44 94.33 2867.13 4874.99 4755.62 1287.90 1.19 -1.12 -0.40 ~ '~,) ....... ~,,~? ~ ....... ~,~ )? ).~,~.~ ....... 17-MAY-00 MWD 6518.97 78.40 51.72 96.68 2886.79 4959.25 4815.73 1361.02 2.32 0.27 2.36 ........... H -H-- 17-MAY-00 MWD 6615.51 78.28 54.85 96.54 2906.30 5041.28 4872.24 1436.80 3.18 -0.12 3.24 U '-.~; L.. ...................................................................................................... 17-MAY-O0 MWD 6712.27 80.53 55.87 96.76 2924.09 5122.04 4926.30 1515.05 2.55 2.33 1.05 /~j ~ ~.:'.~ ~ '~ ' ............................................................................................................................................................. 17-MAY-00 MWD 6807.86 81.15 57.83 95.59 2939.31 5200.85 4977.90 1594.06 2.13 0.65 2.05 17-MAY-00 M 6905.35 80.35 57;75 97.49 2954.98 5280.32 5029.19 1675.47 0.82 . -0.82 -0.08 II i II i I I I iii ...... '" FIELD WO-KSHEE'R T .,: 'SURVEY CALCULATION AND Job No. 0450-00031 Sidetrack No. ~1_ ...... Page 2_ ........ of 2 . co..., a C. Rig Contractor & No. NABORS - 16E Field KUPARUK RIVER UNIT Well Name & No. PAD 2T/217A Survey Section Name SPERRY MWD BHI Rep. R. BARNARD ..... WELL DATA .., Target TVD (FT) Target Coord. N/S Slot Coord, N/S 768,00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SSI- Target Description Target Coord. E/W Slot Coord, E/W 556.00 Magno Declination 26,350 Calculation Method ~I_N. IMUM_ CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30m[~ 10m~] Vert. Sec, Azim. 23.48 Magn, to Map Corr. 26.350 Map North to: OTHER i i ii i ii i SURVEY DATA , , Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+)/S(-) ' E(+)/W(-) DL Build (+) Right (+) Comment Type (Fr) (DD) (DD) (FT) (FT) (F'T) (FT) (Per TOO FT) Drop (-) Left (-) 17-MAY-00 MWD 7002,54 79,53 57,86 97h 19 2971.96 5359.35 5080,18 1756,45 0.85 -0,84 0,11 , . 17-MAY-00 MWD 7096,06 77,11 58.46 93.52 2990,89 5434,66 5128.49 1834,25 2,66 -2,59 0.64 17-MAY-00 MWD 7190,19 75,34 59.27 94.13 3013.31 5509,20 5175,76 1912.49 2.06 -1,88 0,86 17oMAY-00 MWD 7286,34 73,09 60,54 96.15 3039,46 5583.64 5222.16 1992,54 2,66 -2,34 1,32 ..... 22-MAY-00 MWD 7385,04 71,94 61,62 98.70 3069,12 5658.23 5267,68 2074,93 1.56 -1,17 1.09 4-3/4' MACH 1X - 1.2 DEG AKO I " 22-MAY-00 MWD 7484,90 69,58 62.61 99.86 3102,02 5731,87 5311,78 2158,26 2,54 -2,36 0.99 .... 22-MAY-00 MWD 7577,08 69,64 65,54 92.18 3134,14 5797,47 5349,55 2235.96 2,98 0,07 3,18 ....... 22-MAY-O0 MWD 7668,72 67.79 66,31 91.64 3167,41 5860,48 5384.38 2313.91 2.17 -2.02 0.84 .. , 22-MAY-00 MWD 7763,80 64.56 66,47 95,08 3205.81 5924,18 5419,21 2393.60 3.40 -3,40 0,17 22- MAY-O0 MWD 7859,18 61,77 68.33 95.38 3248,87 5985.48 5451.93 2472,15 3,40 -2,93 1.95 22-MAY-00 MWD 7954,55 60,52 68.48 95.37 3294.89 6044,62 5482,67 2549.81 1.32 -1,31 0.16 ................................. 22-MAY-00 MWD 8052,63 59.94 , 68.52 98.08 3343.59 6104,80 5513,88 2629.03 0.59 -0,59 0.04 , 22-MAY-00 MWD 8126,64 59.18 68,40 74.01 3381.08 6149,94 5537,30 2688.38 1.04 -1.03 -0,16 22-MAY-00 MWD '8190,00 59.18 68,40 63.36 3413.55 6188.47 5557,33 2738.97 0,00 0,00 0.00 PROJECTED DATA - No Survey . .... · , .... .... ph, LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 July 27, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 2T-217A (200-074 / 300-141) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 2T-217A. If there are any questions, please contact me at 265-6830 or Tom Brockway at 263-4135. Sincerely, R. Thomas ~/ Kuparuk Drilling Team Leader Phillips Drilling RT/TAB/skad 07-Jun-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2T-217A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 4,976.84' MD 4,991.00' MD 8,190.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager JUN 0 8 2000 Attachment(s) Alaska 0il & Gas Cons. O0mmissior~ Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 2T 2T-217A Surveyed: 23 May, 2000 ~oo ORIGINAL SURVEY REPORT 7 June, 2000 Your Reft API-501032033401 Surface Coordinates: 5970734.97 N, 498944.82 E (70° 19' 52.5963" N, 150° 00' 30.8117" W) Kelly Bushing: 114.75ft above Mean Sea Level RECEIVED JUN 0 8 200(~ Alaska 0il & Gas Cons. Commissior,, Anchorage nRILLINII SERVICES SurveyRef:svy9229 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 2T-217A Your Ref: AP1-$01032033401 Surveyed: 23 May, 2000 Alaska State Plane 4 Kuparuk 2T Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) Dogleg Rate (°/100ft) Vertical Section (ft) Comment 4976.84 4991.00 5007.00 5029,00 5109.59 ,5174.98 5271.14 5371.07 5467.73 5563.11 5655.05 5750.46 5848.90 5944.32 6040.81 6135.39 6232.76 6327.96 6422.29 6518.97 6615.51 6712.27 6807,86 6905.16 7002.54 72.760 72.840 74.000 74.300 74.010 73.79O 74.150 74.110 74.960 76.270 77.540 77.420 77.690 77.640 77.350 77.060 78.390 79.200 78,140 78.400 78.280 80.530 81.150 80.350 79.530 7,760 7.600 8.750 11.010 16.020 17.100 20.540 21.150 21.390 22.250 26.130 29.850 37.400 43.210 44.280 46.070 49.490 49.820 49.440 51.720 54.850 55.870 57.830 57.750 57.860 2411.32 2415.51 2420.07 2426.08 2448.10 2466.24 2492.80 2520.12 2545.90 2569.59 2590.43 2611.12 2632.36 2652.76 2673.66 2694.61 2715.31 2733,81 2752.34 2772.00 2791.52 2809.31 2824.52 2840.17 2857.18 2526.07 2530.26 2534.82 2540.83 2562.85 2580.99 2607.55 2634.87 2660.65 2684.34 2705.18 2725.87 2747.11 2767.51 2788.41 28O9.36 2830.06 2848.56 2867.09 2886.75 2906.27 2924.06 2939.27 2954.92 2971.93 3588,54 N 575.63 E 5974323.43 N 499520.95 E 3601.95 N 577.43 E 5974336.83 N 499522.76 E 1.218 3617.12 N 579.62 E 5974352.01 N 499524.94E 10.001 3637.97 N 583,25 E 5974372.86 N 499528.58 E 9.976 3713.33 N 601.36 E 5974448.21N 499546.70 E 5.991 3773.54 N 619.26 E 5974508.43 N 499564.61 E 1.622 3861.01 N 649.07 E 5974595.89 N 499594.44 E 3.459 3950.84 N 683.28 E 5974685.71N 499628.65 E 0.589 4037.65 N 717.07 E 5974772.52 N 499662.46 E 0.911 4123.42 N 751.41 E 5974858,28 N 499696.81 E 1.628 4205.08 N 788.11 E 5974939.94 N 499733.52 E 4.336 4287.31 N 831.81 E 5975022.17 N 499777.23 E 3.808 4367.29 N 885.00 E 5975102.14 N 499830.44 E 7.494 4438.35 N 945.27 E 5975173.18 N 499890.72 E 5.948 4506.40 N 1010.41 E 5975241.23 N 499955.86 E 1,124 4571.41 N 1075.82 E 5975306.23 N 500021.28 E 1.871 4635.33 N 1146.27 E 5975370.14 N 500091,74 E 3.694 4695.79 N 1217.44E 5975430.59 N 500162,93 E 0.916 4755.70 N 1287.91 E 5975490.48 N 500233.40 E 1.191 4815.80 N 1361.03 E 5975550,58 N 500306.53 E 2.325 4872.32 N 1436.81 E 5975607.08 N 500382.32 E 3.178 4926,37 N 1515.06 E 5975661.13 N 500460.57 E 2.546 4977.97 N 1594.07 E 5975712.72 N 500539.59 E 2.126 5029.16 N 1675.32 E 5975763.90 N 500620.85 E 0.826 5080.25 N 1756.46 E 5975814.97 N 500702.00 E 0.849 RECEIVED JUN 0 8 Anchorage 3473.31 3486.13 3500.71 3521.02 3596.61 3658.54 3750.18 3845.87 3938.68 4030.79 4120.27 4213.35 4308.60 4398.98 4488.81 4576.05 4664.53 4750.22 4835.11 4921.34 5005.54 5088.62 5169.83 5251.66 5333.36 Tie-on Survey Window Point Continued... 7 June, 2000 - 11:28 - 2- DrillQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 2T-217A Your Ref: API-501032033401 Surveyed: 23 May, 2000 Alaska State Plane 4 Kuparuk 2T Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (~) (ft) (ft) (ft) (ft) (ft) (ft) (°/~OOft) Vertical Section (ft) Comment 7096,06 77.110 58.460 2876.11 2990.86 5128.56 N 1834.26 E 5975863.27 N 500779.80 E 2.663 7190.19 75.340 59.270 2898.52 3013.27 5175.83 N 1912.51 E 5975910.53 N 500858.05 E 2.058 7286.34 73.090 60.540 2924.67 3039.42 5222.23 N 1992.55 E 5975956.92 N 500938.10 E 2.663 7385.04 71.940 61.620 2954.33 3069.08 5267.75 N 2074.94 E 5976002.43 N 501020.50 E 1.564 7484.90 69.580 62.610 2987.23 3101.98 5311.85 N 2158.27 E 5976046.52 N 501103.84 E 2.542 7577.08 69.640 65.540 3019.36 3134.11 5349.62 N 2235.97 E 5976084.28 N 501181.54 E 2.980 7668.72 67.790 66.310 3052.62 3167.37 5384.45 N 2313.92 E 5976119.10 N 501259.50 E 2.165 7763.80 64.560 66.470 3091.02 3205.77 5419.29 N 2393.61 E 5976153.92 N 501339.19 E 3.401 7858.18 61.770 68.330 3133.63 3248.38 5451.66 N 2471.34 E 5976186.28 N 501416.93 E 3.439 7954.55 60.520 68.480 3180.13 3294.88 5482.73 N 2549.82 E 5976217.34 N 501495.41 E 1.304 8052.63 59.940 68.520 3228.83 3343.58 5513.93 N 2629.03 E 5976248.53 N 501574.62 E 0.592 8126.64 59.180 68.400 3266.33 3381.08 5537.35 N 2688.38 E 5976271.95 N 501633.98 E 1.036 8190.00 59.180 68.400 3298.79 3413.54 5557.38 N 2738.97 E 5976291.97 N 501684.57 E 0.000 5411.08 5488.08 5565.08 5642.34 5718.73 5786.96 5852.66 5919.13 5982.54 6045.09 6108.10 6155.35 6195.68 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.331° (07-Jun-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 26.237° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8190.00ft., The Bottom Hole Displacement is 6195.68ft., in the Direction of 26.237° (True). RECEIVED JUN 0 8 OOC Alaska 0il & Gas Cons. Commission Continued... 7 June, 2000.11:28 - 3 - Anchorage DriilQuest 1.05.05 North Slope Alaska Sperry-Sun Drilling Services Survey Report for 2T-217A Your Reh AP1-$01032033401 Surveyed: 23 May, 2000 Alaska State Plane 4 Kuparuk 2T Comments Measured Depth (ft) 4976.84 4991.00 8190.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2526.07 3588.54 N 575.63 E 2530.26 3601.95 N 577.43 E 3413.54 5557.38 N 2738.97 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) ~ 0.00 0.00 TO Measured Vertical Depth Depth (ft) (ft) 8190.00 3413.54 Survey Tool Description MWD Magnetic RECEIVED JUN 0 8 200('- Alaska Oil & ~as Co,~s. Cdm.._m_j$$Jon Anchorage 7 June, 2000.11:28 - 4 - DriilQuest 1.05.05 ~ce: z l -zi/A uonnngency Completion--PTD 200-074 Subject: Re: 2T-217A Contingency Completion--PTD 200-074 Date: Mon, 5 Jun 2000 08:45:40 -0900 From: "Jack A Walker" <JAWALKER~ppco.com> To: tom_maunder~admin, state, ak.us CC: "Thomas A Brockway" <TBROCKW~ppco.com>, "Chip Alvord" <CALVORD@ppco.com>, blair_wondzell~admin.state.ak.us, "Dobson&Jones" <N 1127~ppco.com>, "Patrick J Archey" <PARCHEY~ppco.com> Tom, Thanks again for the quick response. We were able to successfully run the 2T-217A ESP on the third try and do not plan to run the hydraulic lift completion. Jack Forwarded by Jack A Walker/AAI/ARC0 on 06/05/2000 08:42 Jack A Walker 06/02/2000 01:43 PM To: Tom Maunder <tom maunder@admin.state.ak.us> @ PHILLIPS cc: Thomas A Brockway/AAI/ARCO@ARCO, Chip Alvord/AAI/ARC0@ARCO, Randy L. Thomas/AAI/ARCO@ARCO, Stephen Bross/AAI/ARCO@ARCO, Dobson&Jones/AAI/ARC0@ARCO Subject: Re: 2T-217A Contingency Completion--PTD 200-074 (Document link not converted) Tom, If the 2T-217A ESP completion is not successful, Phillips Alaska contingency plans for 2T-217A include injection of corrosion inhibitor in the power fluid (produced water), corrosion monitoring of the flowline, and pressure testing the tubing/casing/packer. We will pressure test to 1500 psi after setting the packer. If the hydraulic lift contingency is required, Phillips will file a sundry on Monday. Thanks for quickly responding to our need. Jack Tom Maunder <tom maunder@admin.state.ak.us> on 06/02/2000 12:25:10 PM To: Jack A Walker/AAI/ARCO@Arco cc: Blair Wondzell <blair wondzell@admin.state.ak.us> -- Subject: Re: 2T-217A Contingency Completion--PTD 200-074 Jack, I have checked with Blair and a sundry approval is necessary for the proposed contingency work. The reasoning is that changing to a hydraulic pump is a major change of the previously approved program. As we just discussed, we do need information regarding the corrosion potential of the casing due to being exposed to the power fluid (produced water per our call). In response to this message, please send the information we discussed in the call regarding inhibitor use, corrosion monitoring and pressure tests. We did discuss pressure testing the annulus if the contingency completion is run. The test pressure 1 of 3 6/5/00 9:16 AM ,Ke: 21-217A Contingency Completion--PTD 200-074 should be a minimum of 1500 psi or .25 psi/ft to the packer depth. Based on our discussion, you have verbal approval to implement the contingency completion if needed. If the contingency is run, we look forward to receiving the sundry on Monday. Please call with any further questions. Tom Maunder Jack A Walker wrote: > Tom, > As we discussed on the phone today, the 2T-217A ESP system has failed twice > during installation. Phillips Alaska is planning one more attempt to install > it, but if it fails again we will not run the ESP, but plan to run a proposed > hydraulic lift system. The contingency hydraulic lift system would run with > power fluid (water) down the tubing and production up the annulus. Enclosed MS > Word files show the ESP completion being attempted per the approved as Permit to > Drill (No. 200-074), and the proposed contingency completion with hydraulic > lift. The decision to abandon or keep the ESP in 2T-217A will probably be made > late today, June 2, 2000. > > Please let me know if this contingency lift system can be run under the Permit > No. 200-074. > > Thanks, Jack > (See attached file: 2T-217A ESP Completion.doc)(See attached file: 2T-217A > Contingency Completion v4. doc) > > PS: Address book shows: jjfodor@ppco.com for James J Fodor and > mljones@ppco, com for Morgan L Jones. > > > (application/msword) Completion v4.doc > 2T-217A Contingency Completion v4.doc (application/msword) Name: 2T-217A ESP Completion. doc 2T-217A ESP Completion. doc Type: Microsoft Word Document Encoding: base64 Description: Mac Word 3.0 Name: 2T-217A Contingency Type: Microsoft Word Document Encoding: base64 Description: Mac Word 3.0 Tom Maunder <tom_maunderCb~,admin. state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 3 6/5/00 9:16 AM asCo 2T-217A Produ< [0P0sed Completion Schematic Dual Screen Pre-Pack 62.5# H~0 @ 80' MD -5/8" Port Collar fade BTC Threads 0' MD / 980' TVD) Depths are based on Nabom RKB Baker Bo~omTrip hor Whipstock Base set@ 4"MD /2538'TVD) /8" Bridge Plug 8' MD / 2539' TVD) PHILLll Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 4-1/2" FMC Tubing Hanger wi 4-1/2" L-80 IBT Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. FMC Tabasco Producer style horizontalwellhead system 125 amp penetrators 4-112" 12.6# L-80 IBT Spaceout Pups as Required for Heat Trace Raychem Heat Trace @ +/- 3000' MD 4-1/2" 12.6# L-80 IBT Tubing to Surface XO sub, L-80 4-1/2" IBT box x 3-1/2" IBT Special Clearance 3 jts, 3-1/2" 9.3~ L-80 IBT Special Clearance Tubing, 3.865" Special Clearance couplings Baker 'Sentry' BHP gauge, 3-1/2" clamp on style (suction) 3-1/2" Trico Y-block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on Ptube leg, 3-1/2" IBT Special clearance box on uphole end I-Tube Leq Components (as listed below) w/bottom set (D, +/-4866' MD 2-7/8" Trico 'X' landing nipple w/2,312" profile, EUE8RD XO sub, L-80 EUE8RD box x Hyddll 511 pin Swivel sub, 3-11/16" OD, 2,875" ID, Hydrill 511 4 its, 2-7/8" 6,5# L~80 Hydril1511 tubing 2-7/8" Wireline entry guide, 2.347" ID, Hyddl1511 - Motor Leq Components fas listed below) w/bottom set (~, +1- 4756' MD Spaceout pup, 3~1/2" x 10', 9.3# L-80 EUE8RD tubing Landing pup, 3-1/2" x 10', 9.3# L-80 EUE8RD tubing Centitifl Pump Discharge Centrilift ESP Pump: 82GC 2900 UT Centriliff Pump Unit: 15GCNPSH LT Centrilift Seal Assembly: GST3 4B HL PFS Centrilift Motor: 266 HP KMH 2345/69 - Liner Assembly frun on drillpipe), set ~,, +/- 4836' MD Baker 'C-2' tieback sleeve w/Iocator, 10' tieback extension Baker 9-5/8" x 7" 'ZXP' Liner Top Isolation Packer Baker 9-5/8" x 7" 'HMC' Hydraulic Liner Hanger 7" 26.0# L-80 BTCM casing run to intermediate TD kef 9-5/8" x 7" IZXP Liner Top edPacker Assy MD / 2816' TVD) 0.0# L-80 BTCM MD / 2871' TVD) Cement Plug ppg CtassG ~ Cement Retainer MD / 3057' TVD) ,0# L-80 BTCM MD / 3091' TVD) 0' Cement Plug .8 ppg Class G -- Intermediate Liner 7" 26.0# L-80 BTCM (+/-7420' MD / 3068' TVD) 4" x 4-1/2" Dual Screen Pre-pack TD < 40' below Tabasco base (< 8647' MD / 3487' TVD) - Pre-Pack Screen Assembly {run on drillpipe), set ~,, +/- 7270' MD Baker 7" Model SC-IR Gravel Pack Packer 4 its, Baker 4" blank tubing, Hunting Seal-Lock HT Baker Model C KOIV Baker 4" x 4-1/2" Dual Screen Pre-pack, 5.1" OD, Hunting Seal-Lock HT 3 its, Baker 4" blank tubing, Hunting Seal-Lock HT Baker GPV Set Shoe, 5,0" OD, Hunting Seal-Lock HT TAB, 5/16/00, v3 Tabasco 2T-217A Contingent Completion Schematic - Hydraulic Lift Hydraulic Lift 16" 62.5# H-40 ~ @ 80' MD TAM 9-5/8" Port Collar Stnd, Grade BTC Threads (+/- 1000' MD ! 980' TV'D) Depths are based on Nabors RKB P LIPS Alaska, lnc: A Subsidiary of PHILLIPS PETROLEUM coMPANy 4-1/2" FMC Tubing Hanger wi 4-1/2" L-80 IBT Pup Joint, xo to 3-1/2", FMC Tabasco Producer style horizontal wellhead system w/dummy penetrators 3-1/2" L-80 12.6# IBT Tubing Liner Assembly (run on drillpipe), set (~, +/- 4836' MD Baker 'C-2' tieback sleeve w/Iocator, 10' tieback extension Baker 9-5/8" x 7" 'ZXp' Liner Top Isolation Packer Baker 9-5/8" x 7" 'HMC' Hydraulic Liner Hanger 7" 26.0# L-80 BTCM casing run to intermediate TD Baker 3-1/2" sliding sleeve set @ 7100'- MD with Weatherford Trico jet pump with pump in/pump out retrievability 9-5/8" Baker Bottom Trip Anchor Whipstock Base set @ (+/- 5014" MD / 2538' TVD) 9-5/8" Bridge Plug (+/- 5018' MD / 2539' TVD) Baker 7" Model FHL Packer set @ 7100' +/- Baker 9-5/8" x 7" HMCIZXP Liner Top HangedPacker Assy (6003' MD / 2816' TVD) 9-5/8" 40.0# L-80 BTCM (6213' MD / 2871' TVD) 100' Cement Plug 15.8 ppg Class G 7" EZSV Cement Retainer (6880' MD / 3057' TVD) 7" 26.0# L-80 BTCM (6975' MD / 3091' TVD) 200' Cement Plug 15.8 ppg Class G intermediate Liner 7" 26.0# L-80 BTCM (+/-7420' MD / 3068' TVD) 4" x 4-1/2" Dual Screen Pre-pack TD < 40' below Tabasco base (< 8647' MD / 3487' TVD) Pre-Pack Screen Assembly (run on drillpipe), set ~, +/- 7270' MD Baker 7" Model SC-1R Gravel Pack Packer 4 jts, Baker 4" blank tubing, Hunting Seal-Lock HT Baker Model C KOIV Baker 4"x 4-1/2" Dual Screen Pre-pack, 5.1" OD, Hunting Seat-Lock HT 3 jts, Baker 4" blank tubing, Hunting Seal-Lock HT Baker GPV Set Shoe, 5.0" OD, Hunting Seal*Lock HT TAB, 5/16/00, v3 JW, 6/2/00, v4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .... ~i-:l-ype of request: ~n~on _ ' ..... Suspend _ Operati(~al shutdown _ ' ...... Re;enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance Perforate To re-name 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 35 feet ,,, 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service_ Kuparuk River Unit 4. Location of well at surface 8. Well number 755' FSL, 556' FWL, Sec. 1, T11N, R8E, UM 2T-218A At top of productive interval 9. Permit number/approval number 927' FSL, 2356' FEL, Sec. 36, T12N, R8E, UM 200-074 At effective depth 10. APl number At total depth 11. Field / Pool 1326' FSL, 1620' FEL, Sec. 36, T12N, R8E, UM Kuparuk River Field/Tabasco Oil Pool 12. 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 Conductor 82' 16" 9 cu yds High Early 117' 117' Surface 6178' 9-5/8" 803 Sx AS III L & 871 Sx Class G 6213' 2880' P 3065' u, NOTE: The attached May 22,2000 letter from our Steve Davies to your Thomas Brockway explains that: Perf, 2T-218 becomes 2T-217 with PTD 200-045, APl 50-103-20334-00, 2T-218A becomes 2T-217A with PTD 200-074, APl 50-103-20334-01 and APl 50-103-20291-01 is cancelled Tubing (d/z-e~-r~a~e, and measu red depth N/A ' ' ' Anchorage Packers & SSSV (type & measured depth) N/A '13. Attachments Description summary of proposal__ Detailed operations program__ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: May 22, 2000 16. If proposal was verbally approved Oil __X Gas __ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Br%kway Z63-4135 Signed a~nd~~.~..~.?~,~.~'3~ /~7~"-/*'~ Title: Drilling Team Leader Date andy Thomas Prepared b~' Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test__ Location clearance -- Mechanical Integrity Test__ Subsequent form required 10- ~! ©f{IGiNAL SIGNED BY .... ~plproved by or. der of the Commission D Taylor Seamount Commissioner Date ~" ,'/'~,'-~ ~) Form 10-403 Rev 06/15/88 · ~gproved GopY Returned SUBMIT IN TRIPLICATE ALASKA OIL AND GAS CONSERVATION CO~IMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 22,2000 Thomas Brockway Operations Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 RE: Change of Well Number and AP1 Number for Selected Kuparuk River Unit Pad 2T Wells Dear Mr. Brockway: To cleanly recover from several errors, please make the following changes to your files, databases and on all information transmitted, to the AOGCC for the following wells: AOGCC Revi'sed Well i Revised AP1 Obsolete Well I Obsolete APl Permit Name and Number Name andI Number NUmber Number Number 200-045 KRU 2T-217 50-103-20334-00 KRU 2T-218i Unchanged "' 200-074 KRU 2T-217A 50-103-20334-01 [ KRU 2T-218A 50-103-20291- AOGCC will reflect these changes in our weekly report that is posted to our website. Please accept my apology for any inconvenience that the mistaken API number may have caused. If you have any questions, please contact the undersigned at (907) 279-1433. Sincerely, Steve Davies Petroleum Geologist CC~ Robert Crandall Well File 200-045 Well File 200-074 PH"LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-6830 Fax: (907) 265-6224 May 23, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-218 and 2T-218A (Permit N°. 200-45 & 200-074) Dear Mr. Commissioner: Enclosed are two sundry applications to re-name 2T-218 and 2T-218A to 2T-217. If there are any questions, please call 265-6830. Sincerely, G. C. Alvord Drilling Engineering Supervisor Phillips Drilling GCMskad ALASi~A OIL AND GAS CONSERVATION CO~LSllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-t433 FAX: (907) 276-7542 May 22, 2000 Thomas Brockway Operations Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 RE: Change of Well Number and AP1 Number for Selected Kuparuk River Unit Pad 2T Wells Dear Mr. Brockway: To cleanly recover from several errors, please make the following changes to your files, databases and on all information transmitted to the AOGCC for the following wells: AOGCC Revised Well Revised API Obsolete Well Obsolete API Permit Name and Number Name and Number Number Number Number 200-045 KRU 2T-217 50-103-20334-00 KRU 2T-218 Unchanged 200-074 KRU 2T-217A 50-103-20334-01 KRU 2T-218A 50-103-20291- 01 AOGCC will reflect these changes in our weekly report that is posted to our website. accept my apology for any inconvenience that the mistaken API number may have caused. If you have any questions, please contact the undersigned at (907) 279-1433. Please Sincerely, Steve Davies Petroleum Geologist CC' Robert Crandall Well File 200-045 Well File 200-074 Re: 2T-218 / 218A Surface Location Discrepancy - - PTD #200-074 Subject: Re: 2T-218 / 218A Surface Location Discrepancy - - PTD #200-074 Date: Thu, 18 May 2000 16:06:32-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Thomas A Brockway <TBROCKW~ppco.com> Tom, Yes on the rename, Bob Crandall thinks its a good idea. I think you should make the request via a 10-403. Blair Thomas A Brockway wrote: Dear Blair, At 4:30 pm yesterday we received word that Nabors 16E may be rigged up over a different surface conductor than originally indicated on the 2T-218 and 2T-218A (Sidetrack) Permits To Drill (APD #'s 200-45 and 200-074). Further investigation has confirmed that the rig has been inadvertently positioned over an adjacent conductor slot, 2T-217, which is 12.5' south of the original planned 2T-218 location. Although the planned target and BHL coordinate's will not change for the affected original well and ongoing sidetrack, the positional surveys showing actual wellbore locations will need to be shifted by 12.5' to reflect this change in surface location. It should be noted that a complete proximity analysis has been performed on both the existing and planned wellbores from this revised 2T-217 surface location. The results showed that there were no close crossing occurrences with other pre-existing wells on 2T-Pad and no violations of the PAI Drilling Anti-Collision policy at any time during the drilling of either the original 2T-218 wellbore or subsequent 2T-218A sidetrack. I realize that this change to a different conductor location is bound to result in confusion from a paperwork and permitting standpoint and believe that the cleanest way to address this situation would be to rename the current 2T-218 / 218A wellbores to 2T-217 /217A. This would allow the wellbore nomenclatures to conform to existing surface as-builts and facilities documents. However, if you would prefer to address this in a different manner, please let me know and I will follow your lead. Also, please let me know what type of documentation that you will need and I'll be happy to expedite it to you ASAP. If you have questions or require any further information please contact myself or Chip Alvord (265-6120). Sincerely, Thomas A. Brockway Operations Drilling Engineer Phone: 263-4135 Fax: 265-6224 E-mail: trockwSppco, corn 1 of 1 5/18/00 4:07 PM ALASI~A OIL AND GAS CONSERVATION CO~L~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Randy Thomas Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2T-218A ARCO Alaska, Inc. Permit No: 200-074 Sur Loc: 768'FSL, 556'FWL, Sec. 1, T1 IN, RSE, UM Btmhole Loc. 1326'FSL, 1620'FEL, Sec. 36, T12N, RSE, UM Dear Mr. Thomas: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 65%3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH_~COMMISSION DATED this {G ~ day of May, 2000 dlf/Enclosurcs cc: Department of Fish & Game. Habitat Section ;v/o encl. Department of Environmental Conservation ,,v/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of~ork: ..... Drill I~1 R~lril, 'El { lb.'Type ofwel,. Exploratory U Stratigr'aphic Test ~-I I~eveloPme~t'Oil F~I Re-entry E] Deepen E]I Se~ice DevelopmenlG~ ~ SingleZone R Multiple Zone 2. Name o~rator 5. Datum elevation (DF or KB) 10. Field and Pool ~~ska, Inc.~ 35 feet ~ Addr~s 6. Proper~ D~ignation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25548 ALK 2662 Tabasco Oil Pool 4. Location of well at su~ace 7. Unit or prope~ Name 11. Type Bond (s~ 2o ~c 25.o251) 768' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive inte~al 8. Well number ~ Number 927'FSL, 2356'FEL, Sec. 36, T12N, R8E, UM 2~ ~T'~ ~ ~U-630610 At total depth 9. Approximate spud date Amount 1326' FSL, 1620' FEL, Sec. 36, T12N, R8E, UM May 15, 2000 $200,000 12. Distance to near~t proper~ line ~ 13. Distance to hearst well 14. Number of acr~ in proper~ 15. Proposed depth (MD and TVD) 927' G Target feet~ 2T-220 632.7' G 4986' feet 2560 8647 ' MD / 3487 ' TVD 17. Anticipated pre~ure (s~ 2o ~c 25.035 (e)(2)) Kickoff depth: 5014 MD M~imum hole angle 70 M~imumsudace 1441 At total depth CVD) 1719 psig 18. Casing program Seain~ Depth size Specifi~tions Top BoSom Quanti~ of Cement Hole Oasin~ Weight Grade Oouplin~ Length MD ~D MD ~D (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115' 115' 9 cu. Yds. High Early 12.25" 9.625" 40~ L-80 BTCM 6193' 35' 35' 6228' 2878' 705 sx AS III, 870 sx Class G 8.5" 7" 26~ L-80 BTCM 2584' 4836' 2485' 7420' 3068' 410 sx Cla~ G 6.125" 4"x4.5" 9.5~ L-80 HSLHT 1377' 7270' 3025' 8647' 3487' dual screen pre-pack 19. To be completed for Redrill, Re-ent~, and Deepen Operations. Pr~ent well condition summa~ Total Depth: me~ured feet Plugs (me~ured) true verti~, feetORIGINAL Effective Depth: me~ured feet Junk (me~ured) true verti~l feet C~ing Length Size Cemented Me~ur~ depth True Ve~ical depth Conductor Suda~ Liner Perforation depth: me~ured true verti~l ~,v ~,;~ 20. Attachments Filing fee ~ Properly Plat ~ BOP Sketch ~ D~erter Sketch ~ Drilling program D,..i.g,.iU,~o,,~m Time ~ U.p~ p~o~ ~R.~,o....~i~ ~ Se.~e, ,e,o. ~ ~0 ~ ~.0,0 ,~,ui,.~..~ 21. I hereby cefli~ that the foregoing is true and correct to the b~t of my knowledge Questions? Call Tom Brockway263~135 Signed ~ ~. ~ $~ ~. ~O~, Title: Drilling Team Leader Date Prepped ~ Sharon Al/sup-Drake Oommission Us~ Onl) Permit Number --~~ IAPl number ~J~' ~ ,for other requirements ~~ 50.~-- ~~~ f/ ~Appr0val date ' ISee c°ver le~er co.~i,o., o~..row, S~m¢~,~.uire~ M Ve~ ~' .o ~.~ ~o. r..uire~ ~ V.. Required working pr~sure for BOPE D2M; ~ 3M; ~ SM; D 10M;~ ~ ~~, Other: ORIGINAL SIGNED BY .,o.,e.o, Approved by Robe~ N. Christenson Commi~ioner the commi~ion Date Form 10-401 Rev. 12/1/85 · ~ f Submit in triplicate PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY May 15, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 1 6 200f Re: Application for Permit to Drill: KRU 2T-218A Sidetrack Surface Location: 768' FSL, 556' FWL, Sec 1, T11N, R8E, UM Target Location: 927' FSL, 2356' FEL, Sec. 36, T12N, R8E, UM Bottom Hole Location: 1326' FSL, 1620' FEL, Sec. 36, T12N, R8E, UM,(~ ARCO Alaska, Inc. hereby applies for a Permit to Sidetrack well KRU 2T-218 to a new location in the prospective Tabasco inte~al due to an absence of pay sands at the original 2T-218 target location. This sidetrack is designed to penetrate and develop the production potential of the eastern Tabasco sands in the vicinity of 2T pad. The well is designated as a producer and is planned to penetrate the Tabasco sands using the existing 9-5/8" surface casing, a 7" intermediate liner string and a dual screen pre-pack completion technique for sand control purposes. The well will be drilled and completed using Nabors 16E. Completion plans call for running a 4-1/2" production tubing string with an ESP and Y-block assembly, 2-7/8" I-tube, and heat trace. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following' 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) 6) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Steve Moothart, Geologist (20 AAC 25.071) 265-6965 Please note that the anticipated spud date for this well is May 16, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Thomas A. Brockway Operations Drilling Engine~,-d Attachments: cc: KRU 2T-218A Well File Randy Thomas Tom McKay Tom Brockway Jack Walker Larry Gipson Lewis Ledlow ATO-1038 ATO- 1060 ATO- 1040 ATO-1148 ATO-1146 ATO- 1063 General Procedure: SIDETRACK AND COMPLETE PROCEDURE TABASCO PRODUCER 2T-218A Sidetrack ;.<!AY 'i 6 2000, 1. Circulate and condition original 2T-218 wellbore with kill weight mud in preparation for setting cement retainer above the 7" liner shoe. POOH and lay down BHA. Note: MWD logs and cuttings samples show that no significant hydrocarbon zones are present below the 2T-218 7" liner shoe. 2. Pick up 7" EZSV cement retainer on 4" DP. Rill and set EZSV 100' above the 7" liner shoe (6875' MD). Pressure test liner to 1000 psi. 3. Spot 200' of Class 'G' 15.8 ppg cement below the EZSV. Release from EZSV and spot 100' of Class 'G' 15.8 ppg cement on top of the retainer. POOH 4. Pick up 9-5/8" casing scraper assembly and RIH. Scrape casing to +/- 5100' MD. POOH 5. Pick up 9-5/8" bridge plug on drill pipe and RIH to +/- 5018' MD. Set bridge plug. POOH 6. Pick up Baker Bottom Trip Anchor Whipstock and BHA and RIH. Install ditch magnets in troughs. RIH to +/- 4973' MD and establish string parameters. Continue in hole to ClBP, orient, and set base of whipstock at +/- 5014' MD. 7. Shear whipstock bolt and begin milling widow in 9-5/8" casing. Mill until +/- 30' of BHA is in the open hole. Circulate the well clean until no metal is seen in the returns. Perform formation integrity test not to exceed to 13.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW) 8. Directionally drill 8-1/2" hole to 7" intermediate casing point (+/- 7420 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. Run and cement 7" 26.0¢ L-80 BTCM liner with Baker liner top hanger and packer assembly. Bring cement back to the liner lap, displacing cement with mud. Hydraulically set hanger and packer +/- 150' above 9-5/8" casing window to provide appropriate liner lap. 10. Shut in BOP's and pressure test liner to 2500 psi for 30 minutes per AOGCC regulations. Record results. 11. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 14.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 12. Drill 6-1/8" hole to well total depth (+/- 8647') according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH. 13. Run open hole drill pipe conveyed logs as needed. 14. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 15. Pump caustic wash. Pump pickle job. Circulate brine. 16. Pump acid pill across formation. Reverse out with brine. POOH 17. Run in hole with 4"x4-1/2" Dual Screen Pre-Pack assembly. Set gravel pack packer. 18. Circulate well to non-freezing, clean completion brine. POOH 19. Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6¢ L-80 BTCM production tubing. 20. RIH with ESP assembly on 4-1/2" 12.6¢ L-80 BTCM production tubing with power cable and data gathering information wire attached to tubing. 2T-218A Page 1 TAB, 05/15/00, vl 21. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost. 22. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required. 23. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 24. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. 2T-218A Page 2 TAB, 05/15/00, vl DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Tabasco 2T-218A Sidetrack Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Drill out to 7" Intermediate liner 9.5 - 9.8 8-15 20-50 70-1 O0 8-12 10-25 5-7 8.5-9.5 4-6% Drill out to TD 9.2 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) 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: Maximum anticipated surface pressure for the surface casing window is calculated using an expected leak-off of 13.1 ppg EMW (0.68 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1441 psi. The leak off EMW was chosen based on an open hole LOT on 2T-204 taken to 13.1 ppg at 3108' TVD (0.68 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 2500 psi prior to drilling out of surface casing window. MASP = (2528 ft)(0.68 - 0.11) = 1441 psi Maximum anticipated surface pressure for the intermediate liner string is calculated using an expected casing leai(-ofr of 13.1 ppg EMW (0.68 psi/E) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1859 psi. The leak off EMW was chosen based on an open hole LOT on 2T-204 taken to 13.1 ppg at 3108' TVD (0.68 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 2500 psi prior to drilling out of the intermediate liner. MASP = (3067 ft)(0.68 - 0.11) Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are e~ected to be 1250 psi (0.40 psiRt). Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 8.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3081'. Well Proximity Risks: The nearest existing well to 2T-218A is 2T-220. As designed, the minimum distance between the two wells would be 632.7' at 4986' MD. Drilling Area Risks: Risks in the 2T-218A drilling area are limited to lost circulation, potential borehole instability, and below normal pressures in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Based on previous DS 2T drilling results, 9.5 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 9-5/8" surface casing window will be tested to leak off or a maximum equivalent mud weight of 13.0 ppg upon drilling out. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-218A 4-1/2" x 7" and 4-1/2" x 9-5/8" tubing annuli will be filled with kill weight brine and diesel after setting the 4-1/2" production tubing string and prior to the drilling rig moving off of the well. Tabasco 2T-218A lucer P[oposed Completion Schematic Dual Screen Pre-Pack Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16~' 62.5# H,40 @ 80' MD TAM 9-5/8" Port Cotlar Stnd. Grade BTC Tbreads (+/- 1000' MD / 980' TVD) Depths are based on Nabors 16E RKB 9-5/8" Baker Bottom Trip Anchor Whipstock Base set @ (+/- 5014" MD / 2538' TVD) 9-5/8" Bridge Plug (+/- 5018' MD / 2539' TVD) 4-1/2" FMC Tubing Hanger w/4-1/2" L-80 IBT Pup Joint, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. FMC Tabasco Producer style horizontal wellhead system. 125 amp penetrators 4-1/2" 12.6# L-80 IBT Spaceout Pups as Required for Heat Trace Raychem Heat Trace @ +/- 3000' MD 4-1/2" 12.6# L-80 IBT Tubing to Surface XO sub, L-80 4-1/2" IBT box x 3-1/2" IBT Special Clearance pin 3 its, 3-1/2" 9.3# L-80 IBT Special Clearance Tubing, 3.865" Special Clearance couplings Baker 'Sentry' BBP gauge, 3-1/2" clamp on style (suction) 3-1/2" Trico Y-block w/couplings, 3-1/2" EUEaRD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" IBT Special clearance box on uphote end t-Tube Leq Components (as listed below) w/bottom set @ +F 4866' MD 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD XO sub, L-80 EUEaRD box x Hydrit1511 pin Swivel sub, 3-11/16" OD, 2.875" ID, Hydril1511 3 its, 2-7/8" 6.5# L-80 Hydril1511 tubing 2-7/8" Wireline entry guide, 2.347" ID, Hydrit1511 - Motor Leq Components (es listed below/w/bottom set @ +F 4756' MD Spaceout pup, 3-1/2" x 10', 9.3# L-80 EUE8RD tubing Landing pup, 3-1/2" x 10', 9.3# L-80 EUEaRD tubing Centilift Pump Discharge Centrili[t ESP Pump: 83GC 10000 GPMTAR Centrilift Pump Intake: GPINTAR Ceetrilift Seal Assembly: CST3 CL-5 Centrilift Motor: 418 H P KMH 2610/98A Liner Assembly (run on drillpipe), set @ +/- 4836' MD Baker 'C-2' tieback sleeve w/Iocator, t0' tieback extension -- Baker 9-518" x 7" 'ZXP' Liner Top Isolation Packer Baker 9-5/8" x 7" 'HMC' Hydraulic Liner Hanger 7" 26,0# L-80 BTCM casing run to intermediate TD Baker 9-5/8" x 7" HMC/ZXP Liner Top HangedPacker Assy (6003! MD / 2816' TVD) 9-5/8'~ 40,0# L-80 BTCM (6213! MD / 2871~TVD) 100~ Cement PI 7'~ EZSV 7!' 26.0# L~80 BTCi~ (6975' MD/3091' TVD 200' Cement Plug 15.8 ppg Class G Intermediate Liner 7" 26.0# L-80 BTCM (+/-7420' MD / 3068' TVD) 4" x 4-1/2" Dual Screen Pre*pack TD < 40' below Tabasco base (< 8647' MD / 3487~ TVD) set @ +/- 7270' MD ;I SC-1R Gravel Pack Packer Baker 4'~ blank tubing, Hunting SeaFLo¢k MT ~IC KOIV 4-1/21! Dual Screen Pre-pack, 5~1 '!QD, Hunting Seal:Lock HT 3~ts~ Baker 4" blank tubing, Hunting Seal-Lock HT ]aker~PV Set Shoe, 5.0" OD, Hunting SeaPLock HT TAB, 5/15/00, v2 Pate plottedCreated: IS-MoX-2OOObY rixse Plot Reference ~ 218A Version ~2. iTrue Vertlcol Depths ore reference RKB (Nobors 23.48 AZIMUTH 5931' (TO TARGET) ***Plane of Proposal*** 1800 2100 2400 -'~ 2700 o-- 3000 E 3300 I 3600 - V 3900 PHILLIPS Alaska, Inc. Structure: Pad 2T Well : 218 A Field : Kuparuk River Unit Location : North Slope Alaska l East (feet) -> TD LOCATION: 1326' FSL, 1620' FEL SEC. 56, T12N, R8E 300 600 900 1200 1500 1800 21 O02400 2700 3000 3300 3600 i i [ t i ii ii ii i i [ a ii ai ai i 66O0 2T-2nn East Mod ~ 6300 j 4 Screen 6000 ~ TD -3487.00 Tvd, 5839.84 N, 3099.28 E / - Tvd, N, ~ C60 3458.00 5801.82 3029 i 5700 Cil - 3240.00 Tvd, 5516.03 N, 2502.90 ~ / Target-Mid Tabasco -¢ 3181.99 Tvd, 5439.99 N, 2362.84 E /' ~ ~ / ~ / I TARGET LOCATION:[ EOC - 30~1.00 Tvd, 5307.58 N, 2118.99 E...~/'~' I 9~2¢7¢' F~SRL'T21~5~6' FEL SEC 36 T12N RSE 7 Coslng Pt - 3067.70 tvd, 5289.49 N, 2085.89 E ~ 7 Liner I SEC. 36, T12N, Begin Drop & Turn - 2983.46 T~d, 5114.85 N, 1786.72 E ~ / 2922.77 Tvd, 4901.40 1440.47 E 4200 3900 Bose of West Sok - 2630.00 Tvd, 3923.61 N, 653.5 E 7!F -3600 9-5/8 Window Sidetrack Pt/Begin Build&Turn - 2528.82 Tvd, 3597.14 N, 576.80 E ISIDETRACK LOCATION: I 3300 915' FNL, 1136' PC/K SEC. 1, Tl lN, RSE 5400 5100 4800 4500 '"~"*'~~'~"--~..~.. Sidetrack Pt/Begin Build&Turn - 72.83 Inc, 4986.00 Md, 2528.82 Tvd, 3529.15 Vs ' '~_.~"'~..._ 72.86 - , ~ 73 61 Bose of West Sok - 73 73 Inc 5336 79 Md 2630 O0 Tvd 3859 16 Vs 9-5/8 Window ........ ""~"'---.,~..~ 74.78 DLS: 3.00 dog per 100 ft Loc --~051 651 05~~r~~;;727.6T6v~'11 8043 TARGET ANGLE 5712.3~-(2~' 2T 2nn East Mod LOC Target-M~8 9 Tvd, 5930.97 V~"-... C61 ~ 3240.00 vT d, 60,.5 .6 52"-V.s ~ 4 Screen C60 - 70.00 Inc, 8561.96 Md, 3458.00 Tvd, 6528.36 Vs TD - 70.00 Inc, 8646.75 Md, 3487.00 Tvd, 6591.12 Vs 2700 3000 3300 3600 3900 4200 4500 4800 51 O0 5400 5700 6000 6300 6600 6900 Vertical Section (feet) -> Azimuth 23.48 with reference 0.00 N, 0.00 E from slot #218 W'~%'.'~ i 6 2000 Date plotted: 15-May-2000 Plot Reference is 218A Version ~2. Coord~nofes ore ~n feet reference slot iTrue Ver{~cal Depths are reference RKB (Nobors 16E)J i N Ti,;Q PHILLIPS Alaska, Inc. Structure : Pod 21 Well : 218 A Field : Kuparuk River Unit Locofion: North Slope, Alosko i i i i i i i i i 7200 6900 6600 6300 6000 5700 5400 5100 - 4800- 4500- ~ 5900 4200 3900 ~ 3700 3600 3500 3300 3000 2,00 , ~7o~! 2400 .o East (feet) -> 600 300 0 300 600 900 12001500 1800 21 O0 2400 2700 3000 3300 5600 3900 4200 5300 ~' 5100 / / 5100 / 4900 / / / 4900 ~] / i /4700 /33oo / / /5900 4700 .* / / f59oo / 4500 ¢ /I / ~oo /i/;~oo ~oo/~;oo ' ¢/~oo // /~,oo i) / 31o0' / ~oo / -'7 / 4~°° / / / ~] / /410~/4900 ~ 2900 / ~ / ~,oo ~ / / ~,oo ~ / / ~oo /,~/ ~ / / /4700 ~oo / /~of / / / , ~o¢ / 44~oo ~' ~%too ,m°°/, 3500~ / '500 / Z4300 / ¢, zoo / ~ i~ / / ¢ 55oo¢~, , / ¢ ~5oo / i I/', 4~oo / ~ , . / 4100 ~ 4~oo~ / , i iii 4100 / / /.,. / oo/.oo ~9oo¢~;~oo / , ; 5~oo ¢ i ~ oo~ / /s7oo*'¢°~° ~ / i ~55oo /'~300 ~'~1 O0 7200 6900 6600 6300 60aa _ -5700 _ -5400 5mo 4800 45OO fi) fi) 42O0 3900 3600 3300 900i 5500 /3100 /3700 3000 ~3ooi ~ I / 37045300/3300/ / /100 i / / / 3500 2700 + 5100/3100 /2900 / 2¢/4900 - _2,00 600 900 1200 1500 1800 21 O0 2400 2700 3000 3300 3600 3900 4200 East (feet) -> r'U ;~ q :.; Dote plotted: l§-May-2OO0 Plot Reference Js 218A Versron ~2. Coordinates are in feet reference slot ~/218. 520 .510 29O 530 PHILLIPS Alaska, Inc. Sfrucfure : P~d 2T Well : 218 A Field : Kuparuk River Unif Locefion : Norfh Slope, Alesko 540 TRUE NORTH 350 0 10 2O 5O 4O 50 6O 7O 28O 80 270 90 26O 100 250 110 24O 25O 22O 210 Normal Plane Travelling Cylinder - Feet 2O0 190 180 1 70 120 1,50 160 150 140 All depths shown are Measured depths on Reference Well i,,.,:.; F 't 6 2000~ PHILLIPS Alaska, Inc. Pad 2T 218 A slot #218 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 218A Version #2 Our ref : prop3905 License : Date printed : 15-May-2000 Date created : 9-Mar-2000 Last revised : 13-May-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 52.725,w150 0 30.800 Slot Grid coordinates are N 5970748.059, E 498945.215 Slot local coordinates are 768.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North PHILLIPS Alaska, Inc. Pad 2T,218 A PROPOSAL LISTING Page 1 Your ref : 218A Version #2 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth Last revised : 13-May-2000 R E C T A N G U L A R Dogleg C 00 R D I N A T E S Deg/100ft Vert Sect 4986.00 72.83 7.74 2528.82 3597.14 N 576.80 E 0.00 3529 5000.00 72.86 8.18 2532.95 3610.39 N 578.65 E 3.00 3542 5100.00 73.06 11.31 2562.26 3704.61 N 594.83 E 3.00 3634 5200.00 73.31 14.43 2591.19 3797.92 N 616.16 E 3.00 3728 5300.00 73.61 17.55 2619.66 3890.06 N 642.56 E 3.00 3824 5336.79 73.73 18.69 2630.00 3923.61 N 653.54 E 3.00 3859 5400.00 73.96 20.65 2647.59 3980.78 N 673.98 E 3.00 3919 5500.00 74.34 23.74 2674.91 4069.83 N 710.32 E 3.00 4015 5600.00 74.78 26.82 2701.53 4156.98 N 751.49 E 3.00 4112 5700.00 75.25 29.89 2727.40 4241.97 N 797.37 E 3.00 4208 .15 Sidetrack Pt/Begin Build&Turn .04 .90 .98 .01 .16 Base of West Sak .74 .90 .23 .47 5800.00 75.76 32.94 2752.43 4324.58 N 847.83 E 3.00 4304.34 5900.00 76.32 35.98 2776.56 4404.58 N 902.74 E 3.00 4399.60 6000.00 76.91 39.01 2799.72 4481.76 N 961.95 E 3.00 4493.97 6100.00 77.53 42.01 2821.85 4555.89 N 1025.29 E 3.00 4587.20 6200.00 78.19 45.01 2842.89 4626.78 N 1092.59 E 3.00 4679.04 6300.00 78.88 47.99 2862.77 4694.23 N 1163.67 E 3.00 4769.22 6400.00 79.59 50.95 2881.45 4758.06 N 1238.33 E 3.00 4857.51 6500.00 80.34 53.90 2898.88 4818.10 N 1316.37 E 3.00 4943.67 6600.00 81.11 56.84 2915.00 4874.17 N 1397.58 E 3.00 5027.44 6651.40 81.51 58.35 2922.77 4901.40 N 1440.47 E 3.00 5069.51 EOC 7000.00 81.51 58.35 2974.21 5082.33 N 1733.97 E 0.00 5352.39 7062.66 81.51 58.35 2983.46 5114.85 N 1786.72 E 0.00 5403.23 Begin Drop & Turn 7100.00 80.43 58.63 2989.32 5134.12 N 1818.16 E 3.00 5433.44 7200.00 77.53 59.40 3008.44 5184.65 N 1902.30 E 3.00 5513.30 7300.00 74.63 60.19 3032.50 5233.47 N 1986.18 E 3.00 5591.50 7400.00 71.73 61.00 3061.44 5280.47 N 2069.55 E 3.00 5667.82 7419.68 71.16 61.17 3067.70 5289.49 N 2085.89 E 3.00 5682.60 7" Casing Pt 7459.68 70.00 61.50 3081.00 5307.58 N 2118.99 E 3.00 5712.38 EOC 7500.00 70.00 61.50 3094.79 5325.66 N 2152.28 E 0.00 5742.23 7754.97 70.00 61.50 3181.99 5439.99 N 2362.84 E 0.00 5930.97 Target-Mid Tobasco 7754.99 70.00 61.50 3182.00 5439.99 N 2362.85 E 0.01 5930.99 2T-2nn East Mod 7924.57 70.00 61.50 3240.00 5516.03 N 2502.90 E 0.00 6056.52 C61 8000.00 70.00 61.50 3265.80 5549.85 N 2565.19 E 0.00 6112.36 8500.00 70.00 61.50 3436.81 5774.04 N 2978.10 E 0.00 6482.49 8561.96 70.00 61.50 3458.00 5801.82 N 3029.26 E 0.00 6528.36 C60 8646.75 70.00 61.50 3487.00 5839.84 N 3099.28 E 0.00 6591.12 TD Ail data is in feet unless otherwise stated. Coordinates from slot #218 and TVD from RKB (Nabors 16E) (115.00 Ft above mean sea level). Bottom hole distance is 6611.30 on azimuth 27.96 degrees from wellhead. Total Dogleg for wellpath is 61.87 degrees. Vertical section is from wellhead on azimuth 23.48 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 2T,218 A Kuparuk River Unit,North Slope, Alaska Comments in wellpath PROPOSAL LISTING Page 2 Your ref : 218A Version #2 Last revised : 13-May-2000 MD TVD Rectangular Coords. Comment 4986.00 2528.82 3597.14 N 576.80 E Sidetrack Pt/Begin Build&Turn 5336.79 2630.00 3923.61 N 653.54 E Base of West Sak 6651.40 2922.77 4901.40 N 1440.47 E EOC 7062.66 2983.46 5114.85 N 1786.72 E Begin Drop & Turn 7419.68 3067.70 5289.49 N 2085.89 E 7" Casing Pt 7459.68 3081.00 5307.58 N 2118.99 E EOC 7754.97 3181.99 5439.99 N 2362.84 E Target-Mid Tobasco 7754.99 3182.00 5439.99 N 2362.85 E 2T-2nn East Mod 7924.57 3240.00 5516.03 N 2502.90 E C61 8561.96 3458.00 5801.82 N 3029.26 E C60 8646.75 3487.00 5839.84 N 3099.28 E TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2528.82 3597.14N 576.80E 4986.00 2528.82 3597.14N 576.80E 9-5/8"Window n/a 2528.82 3597.14N 576.80E 7419.68 3067.70 5289.49N 2085.89E 7" Liner n/a 2528.82 3597.14N 576.80E 8646.74 3487.00 5839.84N 3099.28E 4" Screen Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2T-2nn East Mod 501309.000,5976187.000,0.0000 3182.00 5439.99N 2362.85E 25-Feb-2000 PHILLIPS Alaska, Inc. Pad 2T 218 A slot #218 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 218A Version #2 Our ref : prop3905 License : Date printed : 15-May-2000 Date created : 9-Mar-2000 Last revised : 13-May-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is n70 19 52.725,w150 0 30.800 Slot Grid coordinates are N 5970748.059, E 498945.215 Slot local coordinates are 768.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-???'>,,204,Pad 2T PMSS <4135-4496'>,,207,Pad 2T MSS <4046-4427'>,,202,Pad 2T PMSS <853-4995'>,,220,Pad 2T PMSS <0-2140'>,,220PB1,Pad 2T PMSS <1664-4645'>,,220PB2,Pad 2T PMSS <5041-5752>,,220DO, Pad 2T PMSS <12144-13360'>,,38A, Pad 2T PMSS <650 - l1080'>,,37,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <380 - ll400'>,,31,Pad 2T PMSS <0-4749'>,,30,Pad 2T PMSS <4627 - 10686'>,,30A, Pad 2T PMSS <0-10570'>,,29,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T PMSS <0-9298'>,,27,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <893 - 12977'>,,23,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <0-12821'>,,21,Pad 2T PMSS <921-10235'>,,20,Pad 2T PMSS <0-9845'>,,19,Pad 2T PMSS <469-10632'>,,18,Pad 2T PGMS <0-7897'>,,3,Pad 2T PGMS <0-8445'>,,17,Pad 2T PMSS <5917-7957'>,,16A, Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PMSS <4757-6800'>,,12A, Pad 2T PGMS <0-6725'>,,12B,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PGMS <0-8250'>,,10,Pad 2T PGMS <0-8890'>,,2A, Pad 2T PMSS <1287-1725'>,,2,Pad 2T Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-May-2000 3997.1 6-Apr-1999 4147.8 26-Aug-1998 3130.2 3-Feb-1999 632.7 3-Feb-1999 2866.3 3-Feb-1999 649.1 5-Apr-1999 632.7 23-Jan-1998 4593.8 23-Jan-1998 4774.4 23-Jan-1998 4625.4 23-Jan-1998 1019.6 16-Ju1-1998 1358.4 16-Ju1-1998 1297.9 23-Jan-1998 2810.0 23-Jan-1998 942.5 23-Jan-1998 1968.8 23-Jan-1998 1442.3 25-Aug-1998 2232.5 23-Jan-1998 3996.3 29-Feb-2000 4834.3 23-Jan-1998 1663.3 23-Jan-1998 4603.3 21-0ct-1998 4703.1 26-Aug-1998 2651.0 23-Jan-1998 4757.0 23-Jan-1998 4755.0 23-Jan-1998 4755.0 23-Jan-1998 4755.0 23-Jan-1998 4337.3 23-Jan-1998 4337.3 23-Jan-1998 4337.3 23-Jan-1998 4424.2 26-Aug-1998 3493.6 26-Aug-1998 3888.8 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 7920.0 4986.0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 6921.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 7920.0 4986.0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986.0 4986.0 8020.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986 0 4986 0 4986 0 4986 0 8470 0 4986 0 PGMS <0-8160'>,,4,Pad 2T PGMS <0-7670'>,,5,Pad 2T PGMS <0-8208'>,,6,Pad 2T PGMS <0-6370'>,,9,Pad 2T PGMS <0-7650'>,,8,Pad 2T PGMS <0-7868'>,,13,Pad 2T PMSS <0-4175'>,,201,Pad 2T PGMS <0-8262'>,,14,Pad 2T PGMS <0-6789'>,,il,Pad 2T PGMS <0-6975'>,,7,Pad 2T PGMS <0-7625'>,,15,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A, Pad 2T PMSS <4410-4967'>,,215DO, Pad 2T PMSS <0-4082' Depth Shifted NIII>,,209,Pad 2T PMSS <4022-4690'>,,209D0,Pad 2T PMSS <0-5340'>,,210,Pad 2T PMSS <0-7930'>,,218,Pad 2T 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 26-Aug-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 23-Jan-1998 24-Feb-1998 29-Feb-2000 24-Feb-1998 6-Apr-1999 6-Apr-1999 6-Apr-1999 4-Dec-1998 15-May-2000 4069.0 2589.0 2677.4 3913.7 3915.7 4395.4 4426.2 4527.1 4287.1 4124.7 4626.3 2917.4 2917.4 2917.4 1226.1 1934.7 1687.0 1815.6 0.0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986.0 4986.0 4986.0 4986.0 4986.0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 4986 0 8265.0 4986.0 4986.0 8247.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 4986.0 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the PAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the PAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the PAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the PAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. 7. Bleed back mud from the well and compare with volume pumped on the test. Contact the PAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 TAB 05/08/00 Greater Kuparuk Area Formation Integrity Test Stand~rd Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the PAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the PAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off' check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. Contact the PAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 TAB 05/08/00 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors #16E 13-5/8" 5,000 PSI BOP COMPONENTS L 3" 5,000 psi WP OCT MANUAL GATE V VE 3" 5,000 psi WP Shaffer GATE VALVE L w/hydraulic actuator L_.i / J / BSA 13-5/8" 5,000 psi WP "~L x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple CHOKE LINE ~%~.~...~~~3.5,~0 psi wP OCT ~]~ MANUAL GATE VALVE M NE SITE · 220 25. O' -. --~ 210 ~ ' 209 ' ~' ~r ps-2X / ~ ~o8 I 207 : ' '5',0 0 ' · 28 ~ · 202 · 27 · 26 , VICINITY MAP Scole: 1"= 1 MileI · · 3 ~ , e 4 ~ 8 20lc · 9 · I0 e I ~8 · , · 14 ~ 2 1 · , o ~ 36e ~ 11~1 12 J; · ~ 7 ~< I · 18 · 19 (NO SCALE) I DRILL S I TE , · 2o i · ' : 2 T , I LEGEND SEE SHEET 2 FOR NOTES AND LOCATION INFORMATION o NEW CONDUCTOR LOCATIONS ~~ LOUNSBURY e EXISTING CONDUCTORS ~ & ASSOCIATES, INC. ~ENGINEERS P~NNERS SURVEYORS Subsidior7 of ~tlontic Richfield Comport7 CADD FJ'LE'NO. I ' ' ' i ORAWING NO: 1 OF 2 1 LK622~16 ,, ,,,CEA-D21X-~22OD!8 ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT P.O. Box 103240 Anchorage, AK 99,510-3240 PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE MAY 12, 2O00 *** VOID AFTER 90 DAYS *** 73-426 839 099033: The First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelby¥ille, Kentucky EXACTLY **********.100 DOLLARS AND O0 CENTS ¢**********'100.00 TRACE NUMBER: 249007926 ,'2hqoo?q2B,' m.'OP,~qoh2B2ml WELL PERMIT CHECKLIST FIELD & POOL L7/~/~z:~, COMPANY /~-'~,~"~ I I WELL NAME ,2"T'' 2./~/~ PROGRAM: exp INIT CLASS '~::) ~'V /'~.~//..-.. ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... DATE ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~,(~L~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. dev V/'redrll serv wellbore seg ann. disposal para req GEOL AREA ~ _~_) ...... UNIT# _(~,/./'/' ~o ~ ON/OFF SHORE ~N .(~N -'~ - o ~ ®N N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... (~)N 31. Data presented on potential overpressure zones ....... ,,,'t/"~ Y N 32. Seismic analysis of shallow gas zones ............. ,/u//,~ Y N IIA~,~.R DATE 33. Seabed condition survey (if off-shore) ............. A,,//,~ Y N [/~__ ~~)~) 34. Contact name/phone for weekly progress reports [exploratory onlY N 1A~A-~~AL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ,. _Z~j_~ TEMpi, t. CO C'/~'"'~I~,./' ' Comments/Instructions: Z 0 .....I Z .--4 '-r' c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Oct 24 15:15:55 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/10/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HED~DER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM M~L 0) KELLY BUSHING: MWD RUN 2 AK-MM-00047 P. SMITH G. WHITLOCK 2T-217A 501032033401 PHILLIPS Alaska, Sperry Sun 24-0CT-00 MWD RUN 3 AK-MM-00047 P. SMITH G. WHITLOCK 1 llN 8E 768 556 .00 Inc. MWD RUN 4 AK-MM-00047 P. SMITH G. WHITLOCK DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 114.75 80.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 110.0 9.625 4991.0 8.500 7.000 7368.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS A DIRECTIONAL ONLY RUN TO SET WHIPSTOCK AND IS NOT PRESENTED. 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 4 . DIGITAL MWD DATA IS TIED INTO THE PDC GR (MWD GR) LOG OF THE PARENT WELL 2T-217 WITH SAME KBE. MWD DATA IS PDC. THIS WELL KICKS OFF FROM 2T-217 AT 4991' MD, 2530' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1-4 REPRESENT WELL 2T-217A WITH API # 50-103-20334-01. THIS WELL REACHED A TOTAL DEPTH OF 8190' MD, 3414' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4974.5 8145.0 FET 4981.5 8152.0 RPD 4981.5 8152.0 RPM 4981.5 8152.0 RPS 4981.5 8152.0 FET 4981.5 8152.0 ROP 5029.0 8189.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4974 5 4978 5 4985 0 4987 0 4991 0 4992 5 4993.5 8189.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: GR 4974.5 4978.5 4985.0 4986.0 4989.5 4992.0 4994.0 8190.0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 4974.5 7368.0 3 7368.5 7660.5 4 7661.0 8190.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD M%rD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 4974.5 8189.5 6582 6431 ROP MWD FT/H 1.12 3196.61 136.444 6322 GR MWD API 37.84 149.47 94.8048 6342 RPX MWD OHMM 0.33 1994.69 20.553 6342 RPS MWD OHMM 0.33 2000 89.0173 6342 RPM MWD OHMM 0.57 2000 138.646 6342 RPD MWD OHMM 0.~09 2000 148.581 6342 FET MWD HR 0.13 62.08 2.49526 6342 First Reading 4974.5 5029 4974.5 4981.5 4981.5 4981.5 4981.5 4981.5 Last Reading 8189.5 8189.5 8145 8152 8152 8152 8152 8152 First Reading For Entire File .......... 4974.5 Last Reading For Entire File ........... 8189.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RLTNNUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4974.5 RPD 4981.5 RPM 4981.5 RPS 4981.5 RPX 4981.5 FET .4981.5 ROP 5029.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : · BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): STOP DEPTH 7333.5 7327.5 7327.5 7327.5 7327.5 7327.5 7368.0 18-MAY-00 Insite 65.41 Memory 7368.0 73.1 81.2 TOOL NUMBER 1523HWRGV6 1523PIWRGV6 8.500 7368.0 LSND 9.80 49.0 8.5 900 5.5 .700 .468 1.960 2.000 74.0 114.0 74.0 74.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HR Min Max 4974.5 7368 4.7 3196.61 38.99 145.18 1.05 1945.7 0.79 1713.32 2.67 2000 0.09 2000 0.13 40.8 First Reading For Entire File .......... 4974.5 Last Reading For Entire File 7368 Mean 6171.25 161.716 99.5693 8.8129 8.28166 13.1724 13.077 1.68717 Ns am 4788 4678 4719 4693 4693 4693 4693 4693 First Readin9 4974.5 5029.5 4974.5 4981.5 4981.5 4981.5 4981.5 4981.5 Last Reading 7368 7368 7333.5 7327.5 7327.5 7327.5 7327.5 7327.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7328.0 7623.5 RPD 7328.0 7623.5 RPM 7328.0 7623.5 RPS 7328.0 7623.5 RPX 7328.0 7623.5 GR 7334.0 7616.5 ROP 7368.5 7660.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 21-MAY-00 Insite 0.41 Memory 7660.0 69.6 71.9 TOOL NUMBER PB01456GR4 PB01456GR4 6.125 BARADRILL 9.20 50.0 9.5 27500 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPER3kTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 4.2 .100 .087 .120 · 140 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 '68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 75.0 86.9 75.0 75.0 Name Service Unit Min Max DEPT FT 7328 7660.5 ROP MWD030 FT/H 1.12 538.09 GR MWD030 API 38.98 149.47 RPX MWD030 OHMM 0.33 1994.69 RPS MWD030 OHMM 0.33 2000 RPM MWD030 OHMM 0.57 2000 RPD MWD030 OHMM 2.66 2000 FET MWD030 HR 0.51 62.08 Mean 7494.25 68.5861 78.9492 75.8603 392.801 659.847 717.503 9.70128 Nsam 666 585 566 592 592 592 592 592 First Reading 7328 7368.5 7334 7328 7328 7328 7328 7328 Last Reading 7660.5 7660.5 7616.5 7623.5 7623.5 7623.5 7623.5 7623.5 First Reading For Entire File .......... 7328 Last Reading For Entire File ........... 7660.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7617.0 8145~5 RPD 7624.0 8152.5 RPM 7624.0 8152.5 RPS 7624.0 8152.5 RPX 7624.0 8152.5 FET 7624.0 8152.5 ROP 7661.0 8190.0 $ LOG HEADER DATA DATE LOGGED: 23-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 8190.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.2 MAXIMUM ANGLE: 67.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MI/D AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): TOOL NUMBER PB01456GR4 PB01456GR4 6. 125 BARADRIL 9.20 46.0 9.2 26000 4.6 .100 .085 .110 .160 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 75.0 89.0 75.0 75.0 Name Service Unit Min Max DEPT FT 7617 ~190 ROP MWD040 FT/H 3.42 114.31 GR MWD040 API 37.84 139.43 RPX MWD040 OHMM 3.13 1787.01 RPS MWD040 OHMM 3.28 2000 RPM MWD040 OHMM 3.33 2000 RPD MWD040 OHMM 3.46 2000 FET MWD040 HR 0.49 20.14 Mean 7903.5 62.2913 82.0233 43.8825 278.319 400.728 427.156 2.08326 Nsam 1147 1059 1058 1058 1058 1058 1058 1058 First Reading 7617 7661 7617 7624 7624 7624 7624 7624 Last Reading 8190 8190 8145.5 8152.5 8152.5 8152.5 8152.5 8152.5 First Reading For Entire File .......... 7617 Last Reading For Entire File ........... 8190 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/10/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments · STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File
