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Home My WebLink About200-146 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. dt't? ¡q 1:7 Well Hisrory File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # - Oversized Material Added to LaserFiche File Maps # Other # Yes No Yes No Yes No Mud Logs # - General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us ~ • ALASSA OIL A1~TD GAS COI~TSERQATI011T CODi1~IISSIOI~T Brett Packer Wells Group Engineer ConocoPhillipsAlaska, Inc. ~~'~ ~,;~ ~ ~. ~~~ P.O. Box 100360 Anchorage, Alaska 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1 D-140L 1 Sundry Number: 308-377 Dear Mr. Packer: 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. Sincerely, Cathy P. Foerster Commissioner rd DATED this ~ day of October, 2008 Encl. ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 20, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ~~ ~u ~ ~~~~ Alaska L3it ~~, ;~n~. ~.~~°ll~r,~s~o An~~ cra~?~ ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to temporarily suspend the West Sak Well 1 D-140L1 (PTD# 200-146). Producing well 1 D-140 was originally completed in Oct. 2000 as a dual lateral (B&D sand, 1 D-140L1 as the D-lateral) ESP producer. It is one of three West Sak wells, along with 1 D-141 and 1 D-102, to have the Sperry RMLS junction installed in the D-lateral window. Previous attempts to bypass this junction on 1 D- 141 and 1 D-102 were unsuccessful, one of which required the well to be plugged back and sidetracked. 1 D-140 has had two previous workovers in 2003 and 2004, neither of which attempted to bypass the junction; but due to the recent MBE (matrix bypass event) in the B-sand, the well was sanded up to the ESP and required a cleanout of the mainbore and lower lateral. Original plans for the workover were to pull the ESP, test the casing, dress off the RMLS junction, cleanout the lower lateral, and re-install the ESP. We knew our chance of cleaning out past the RMLS junction was limited based upon the failed attempts on 1 D-141 and 1 D-102. We also knew about the risk of possibly sidetracking through the production casing as was the case in 1 D-141. These were risks we were willing to accept, because as it was, the well could not be produced. The workover began on 10/8/08 and everything went as planned the first few days. We pulled the ESP, tested our casing, and cleaned out approximately 60' of fill that was below the ESP. We tagged upon something hard approximately 30' above the D-lateral window and milled through an additional 10' before it quit making any hole. At that time we pulled out only to find that our washpipe had parted at the connection leaving an 8.5' fish consisting of the mill, two junk baskets, and 2.5' of washpipe. The VACS tool we had on our string was packed solid with fill, and we even found chunks of formation up to 3" in diameter inside; thus indicating that our RMLS junction had indeed failed as suspected. Based on this finding, we knew our washpipe downhole was packed solid with fill and there was no chance of getting a spear inside without first milling through the center of the washpipe. We also could not get an overshot over the 6" washpipe because of the tight tolerances inside 7" casing. We ran in with a junk mill to bore through the center of the washpipe and gained about two feet before it quit making hole. We attempted a spear and could not get a bite on it. We fought this fish for four days with burn shoes, junk mills, and spears & grapples, making absolutely no progress; at which point we decided to run a downhole video to try and see what is going on. Based upon the video and the fact that there was ahalf-moon piece of the washpipe remaining that we had milled alongside, and the fact that our 6" burn shoes were only showing wear on the leading edge, it is presumed that we had begun milling through the side of the casing. We were at a point where the only thing we could do was get a little more aggressive with the milling, but we knew that if we continued on this path, we would ultimately end up milling through the casing, thus there was no point in continuing the workover operation. The decision was made to sus end t e el fc~r f~rther evaluation as a possible sidetrack candidate. `-'? ~ ~ ~- ~~`_ ~ s .,_ ,__ *' ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 We ran a 4'/2" kill string back in the hole to 2352' below the permafrost to allow for coil tubing access and further diagnostics, and we left the tubing far enough up hole so that we can lay a cement plug down there when the time comes to sidetrack this well. We landed the hanger, and re-installed the wellhead and left the well with 9.9 ppg brine and a diesel cap for freeze protection. Verbal requests for permission to temporarily suspend this well were obtained on 10/15/08 and thereby - submit a formal Application for Sundry Approval to temporarily suspend this well for further evaluation and a new plan of action can be implemented. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells ,s ; t • STATE OF ALASKA ~ \~J~~ ALASKA OIL AND GAS CONSERVATION COMMISSION (~ ~ f ~ (~ L008 APPLICATION FOR SUNDRY APPR0~~4~~.a (~~~ ~ ~~~ ~~~~ COrr)r~l,~s10~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown Q Perforate ^ Wa i O~e Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ 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 ^/ - Exploratory ^ 200-146 ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22974-60 ` 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? Y2S ^ NO ^~ 1 D-140L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650 RKB 30' Kuparuk River Field /West Sak 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): 7663' - 3719' 7619' 3718' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 110' 110' SURFACE 480' 10-3/4" 510' 510' PRODUCTION 3589' 7-5/8" 3619' 3509' L1 PRODUCTION 556' 7" 4158' 3680' PRODUCTION 4.5" x 4" 7619' 3719' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4231'-7619' perfs throu h screens 3680'-3719' 4-1/2" L-80 3595' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= D-SAND BAKER CTC 7' ISOZONE ECP ; B-SAND BAKER ' pkr-- 3951' ; 4020' ; 4075' no SSSV 13. Attachments: Description Summary of Proposal ~ Detailed Operations Program ^ BOP Sketch ^ 14. Well Class after proposed work: Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 20, 2008 Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer Title: Wells Group Engineer ~7 Signature r~ / ~ Phone 265-6845 Date ~0~2v/p~- Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 3Dis 37 Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~Q~ ~C~S~+>"~~ ©~\"~.~~b~, Subsequent Form Required: W ~ ~'t ~"' °~ ~ ~ ~ ~' ~~~ ~~~~~~ tom. a t ~ ~~ APPROVED BY Approved by: COMMISSIONER SSION Date: ~ ' Z3'~ V Form 10-403 Revi ed 06/2006 ~1Ubmit i Duplicate .. f ;,. <~ r,G~~. Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 2:18 PM To: 'Allsup-Drake, Sharon K' Cc: Packer, Brett 6 Subject: RE: 1 D-140 (200-136) -Again Sharon, It is appropriate to include a cover letter. Maybe just a copy of what was submitted for 1 D-140. Tom From: Allsup-Drake, Sharon K [mailto:Sharon.K.Allsup-Drake@conocophiflips.com] Sent: Monday, October 20, 2008 2:16 PM To: Maunder, Thomas E (DOA) Cc: Packer, Brett B Subject: FW: 1D-140 (200-136) -Again Tom - Thank you, Sharon 263-4612 Should we send over the cover letter with the 403 for 1 D-140L1? From: Packer, Brett B Sent: Monday, October 20, 2008 1:02 PM To: Allsup-Drake, Sharon K Subject: FW: iD-140 (200-136) -Again Sharon, It looks like we need a sundry for the suspension of 1 D-140L1 also. (PTD #200-146) ,7 Batt hacker <vriQing a~ 4Nelrs 'Wor~ver engineer 2t~ork# 265-6845 Cell# 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 20, 2008 11:52 AM To: Packer, Brett B Subject: RE: iD-140 (200-136) -Again 10/22/2008 Page 2 of 2 Brett, in addition to the earlier message ... 1. Since this well is multi-lateral, a sundry for 1 D-140L1 needs to be submitted as well. 2. Regarding the operations report, please send the report with "hourly detail. Email is fine for this. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 11:27 AM To: 'Packer, Brett B' Subject: 1D-140 (200-136) Brett, I am reviewing the sundry submitted for an operational SD on this well. In the letter, your seeking verbal approval is mentioned. I do remember speaking with you regarding the issues encountered attempting to clean out the well, however I don't find that any email from you regarding a "verbal" request. Do you have any email we might have exchanged? Call or message with any questions. Tom Maunder, PE AOGCC 10/22/2008 ) \ ¡~~,. MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _I nserts\M icrofi I m _Marker.doc '" J', ~ ~ Mike Mooney Wells Group Team Leader Drilling & Wells Conoc6Ph ¡iii ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 24, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-140 and 1 0-140L 1 (APD # 200-136 an&eOO-146) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the multilateral Kuparuk well 1 0-140 and 10- 140L 1. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ð'M1:;¡ç Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED MAY 252004 Alaska Oil & G C as Dns C . An h . Dmrmssion C Drage O~~!G\NAL 1. Operations Performed: ~ ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Alter Casing D D RepairWell 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 31' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION CSG WINDOW Perforation depth: ", measured 7663' 3719' true vertical measured true vertical Length Size 110' 407' 3517' 556' 16" 1 0-3/4" 7-5/8" 7" 4.5" x 4" Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: ~~ 260-146 1 304-068 6. API Number: 50-029-22974-60 Exploratory D Service D 9. Well Name and Number: 1D-140L1 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool feet feet Plugs (measured) Junk (measured) feet feet MD TVD Collapse Burst 110' 509' 3619' 4158' 7619' 110' 509' 3509' 3680' 3719' true vertical depth: 3680'-3719' Measured depth: perfs thru screens 4231'-7619' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3595' MD. RECEIVED MAY 252004 Packers & sssv (type & measured depth) pkr= BAKER pkr= 3951', 4075' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Alaska Oil & Gas Cons. Commission Anchorage Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Oil-Bbl 497 663 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Representative Daily Average Production or Injection Data Gas-Me! Water-Bbl 1091 293 64 693 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oil0 GasD WAGD CasinQ Pressure TubinQ Pressure 380 263 Service D GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 265-4374 Mike Mooney Jfiú(~ Form 10-404 Revised 04/2004 Title Phone Wells Group Team leader I J Date S /2f¡df' preoaredbv:£'r;nAlfsuo-Drake2fj-4612 ~~ f "* ;G ~ flIt "'- () n , (:', , J\' ð , -- Qf~it Original Only ! . .. TUBING (0-3595, 00:4.500, 10:3.958) SCREEN (3547-3548, 00 5.000) 'ROOUCTION (0-3619, 00:7.625, Wt:29.70) SEAL (3557-3571, 00:5.000) MOTOR (3571-3588, 00:5.500) GAUGE (3588-3594, 00:5.000) Centralizer (3594-3596, 00:6.250) LINER (3698-4231, 00:4.500, Wt:12.30) Perf (4231-7619) ,-......, ~ KRU ConoeóPhillips Alaska, loe" 1."'.'.-m:'~.1 '-.' .fu~ r:1 . '. Well Type: PROD Orig 10/31/2000 Completion: Annular Fluid: Last W/O: 5/8/2004 Reference Log: 31' RKB Ref Log Date: Last Tag: TD: 7663 ftKB Last Tag Date: Max Hole Angle: 92 deg @ 6088 Oas¡ng.ßtrirïg;,,;QSMM~N;;G'ÁßIIiIG;:';' i;;>i Description Size PRODUCTION 7.625 SURFACE 10.750 CONDUCTOR 16.000 PRODUCTION 7.000 CSG WINDOW JNT 6.750 . Oaslñi:ßlîiôíî;.. .. U I!>;l?c&R'J:A tSHÞ\!.: .£JNE * Description I Size I LINER 4.500 DUAL SCREENLNR . 4.000 .. Tûbing'Sli'iÖg." TOBING . Size I Top Bottom 4.500 0 3595 l?effórallöös'SaiririiârY . Interval I TVD 4231 - 7619 3680 - 3719 'Gas.Lift Manill"eliJValves St MD TVD Man Man Type V Mfr V Type V OD Latch Port Mfr 1 2513 2507 CAMCO KBG-2 DMY 2 3440 3383 CAMCO KBG-2 DMY c)lfîèíi};(piuQs,:e.öûJPiiiêlô¡) "';OPfteRLATERAL JEWELf;{¥ Depth TVD Type Description 3932 3648 VALVE BAKER 'HMCV' CEMENTING VALVE 3951 3652 PKR Baker CTC 7' Isozone ECP 4075 3674 PKR Baker CTC 20' Payzone ECP 4162 3681 KOIV KOIV 4197 3681 SLEEVE Baker 4.5" CMD Sliding Sleeve Other (j)IUgS¡ieq(lp.,'etc;) - COMMONJEWELBY Depth TVD Type 3469 3405 SUB 3547 3460 SCREEN 3557 3467 SEAL 3571 3476 MOTOR 3588 3488 GAUGE 3594 3492 Centralizer 'GenËlrelitilö1e$,¡;:;; . . Date Note 12/6/2000 NOTE: This is a multilateral well. This schematic represents the 'D' sand upper lateral. See schematic for 1D-140 for the 'B' sand lower lateral. 1 D-140L 1 API: 500292297460 SSSV Type: None .. Angle @ TS: deg @ Angle @ TD: 90 deg @ 7663 Rev Reason: WORKOVER Last Update: 5/9/2004 Top 0 0 0 3619 3684 Bottom 3619 509 110 4158 3685 TVD Wt Grade Thread 3509 29.70 L-80 BTC-MOD 509 40.50 J-55 BTC 110 151.50 X-65 WELD 3680 26.00 L-80 BTC-MOD 3552 0.00 L-80 joins 10-140 Top 3698 4231 . . TVD 3492 Thread NSCT ... . I Zone I Status 1Ft I SPF I Date I Type I Comment ~~:¡S~S3388 50 10/31/2000 Screen Perfs thru screens 1.0 1.0 BK-5 BK-5 0.000 0.000 Description BAKER PHOENIX PRESSURE SUB set 5/8/2004 BAKER TCC SCREENED INTAKE set 5/8/2004 ESP TANDEM SEAL set 5/8/2004 BAKER ESP MOTOR, KMH /190 set 5/8/2004 BAKER PHOENIX GAUGE set 5/8/2004 BAKER CENTRALIZER set 5/8/2004 TRO Date Vlv Run Cmnt 0 5/7/2004 0 5n/2004 ID 3.844 3.958 3.958 3.500 3.437 ID 3.930 3.930 0.000 0.000 4.500 0.000 . .. ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-140 10-140 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 5/4/2004 Rig Release: Rig Number: Spud Date: 9/22/2000 End: Group: 5/4/2004 00:00 - 04:00 4.00 MOVE DMOB DEMOB 04:00 - 08:30 4.50 MOVE MOVE DEMOB 08:30 - 12:30 4.00 MOVE MOB RIGUP 12:30 - 20:00 7.50 MOVE RURD RIGUP 20:00 - 23:00 3.00 WELCTL NUND WRKOVR 23:00 - 00:00 1.00 WELCTL COND WRKOVR 5/5/2004 00:00 - 05:00 5.00 WELCTL COND WRKOVR 05:00 - 06:00 1.00 WELCTL KILL WRKOVR 06:00 - 07:00 1.00 WELCTL KILL WRKOVR 07:00 - 08:30 1.50 WELCTL OBSV WRKOVR 08:30 - 09:30 1.00 WELCTL KILL WRKOVR 09:30 - 10:20 0.83 WELCTL OBSV WRKOVR 10:20 - 10:50 0.50 WELCTL KILL WRKOVR 10:50 - 13:00 2.17 WELCTL OBSV WRKOVR 13:00 - 14:00 1.00 WELCTL NUND WRKOVR 14:00 - 23:00 9.00 WELCTL NUND WRKOVR 23:00 - 00:00 1.00 WELCTL NUND WRKOVR 5/6/2004 00:00 - 06:30 6.50 WELCTL BOPE DECOMP 06:30 - 07:30 1.00 WELCTL OBSV DECOMP 07:30 - 09:45 2.25 WELCTL BOPE DECOMP 09:45 - 10:30 0.75 CMPLTN SFTY DECOMP 10:30 - 10:45 0.25 WELCTL BOPE DECOMP 10:45 -11:00 0.25 WELCTL CIRC DECOMP 11:00 -11:15 0.25 WELCTL OTHR DECOMP 11:15 -11:45 0.50 CMPL TN TRIP DECOMP 11:45-12:15 0.50 CMPL TN CIRC DECOMP Continue to prep rig for move to 1 D-pad. Lower derrick at 00:30. Move Rig from 2G-15 to 1D-140 Haul BOPE in and set behind the wellhead. Back Rig over the well and begin setting up. Spot pit section, pipe shed, connect utilities, mud lines, flow line, choke line, raise derrick and secure. Set up kill tank and RU hard lines for returns. Berm up sub, pits and maniflold. Accepted rig @ 20:00 hrs. RU lubricator to pull BPV. Swab valve would not hold. RU bleed tank, service valve and bled down, rmoved BPV. RU lines to tubing t/circulate. RU Little Red Hot Oiler and start heated 10 ppg Brine to 160 deg. for well kill. Heated Brine and loaded Brine in the Pits. Rig up to circulate Brine and Kill well. Pumped app: 115 bbls of 160 degree 10# brine down the tbg taking returns to the open top tank @ 2 BPM. Lost returns after getting back 100 bbls of well bore fluid. Slowed rate down with no help. Shut down pumping. Montiored well, no flow observed. Decided to Bullhead down the IA to insure well bore fluids are swept away from the tubing. Bullhead Heated 10# Brine down the IA @ 2 BPM. IA went on a Vac and Tbg pressure climbed to 100 psi, while pumping.Pumped 90 bbls and shut down pump. IA on a Vac and Tubing pressure 100 psi and falling. Monitored well for flow. No flow. Rig back up on the tubing side. Pump 60 bbls of Heated 10# brine down the tubing, tubing pressure dropped to basically nothing and IA climbed to 60 psi while pumping. Shut down pump, tubing pressure 5 psi and IA 60 psi and dropping. Monitor well for flow and bleed gas off. Gas believed to be flashing of from High temperature of the brine. Both tubing and IA bled down to a whisper. Well bled down. Prepare and install BPV. Prepare to nipple down the tree. ND the Tree and Picked up mud cross, double gate rams,Hydrill bag NU (BOP E). Talked with Jeff Jones of AOGCC on 5/4/04 and he waived witness of BOPE test. TO up BOP flanges and change out top rams to 4.5". Function test BOPE, test rams & choke manifold to 4000 psi and annular to 3000 psi. Flow nipple to short, welded on additional 24". Shoot fluid level on the IA. Fluid level @ 650' Line to Gas Buster frozen, thawing in process. Hang Elephant Trunk, Cable Sheave, & Cable Pull Rope. Fine tune the floor camera. Stage ESP equipment in pipe shed. Train APC hand to run spooler. Held Pre-Workover Mtg wI Rig Crew, Toolpusher, Centrilift Rep, Vetco Rep, M-I Rep, APC, & Co-Man. Screwed into BPV and bled gas off.Pull BPV. Begin filling tubing wI 150 degree 9.5#. Pumped 40 bbls. no indication of level. Installed Vetco Hanger Sleeve to allow circulating thru the horizontal mastèr hanger. Backed off the LDS and Pulled hanger from the Bowl. Pulled free @ 50k and hanging weight app: 40K. Begin filling IA wI 150 degree 9.5# brine. Pumped 40 bbls, no indication Printed. 5/21/2004 10:5306 AM ~ $ ~ ,,-..., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-140 10-140 WORKOVERIRECOMP Nabors Alaska Drilling Nabors 3S Start: 5/4/2004 Rig Release: Rig Number: Spud Date: 9/22/2000 End: Group: 5/612004 11:45-12:15 0.50 CMPLTN CIRC DECOMP of level. 12:15 - 14:00 1.75 CMPLTN OBSV DECOMP Monitored well and waited for another fluid level to be shot. Fluid level @ 500'. 14:00 -15:30 1.50 CMPLTNTRIP DECOMP Pulled Hanger to the floor. Checked connection and cable for electrical integrity. All checked out good. Disconnected cable from hanger. Pulled up to the splice and cut ESP cable. 15:30 - 17:00 1.50 CMPLTNTRIP DECOMP Layed down the Hanger and pulled 10 stands. Spooling ESP cable and removing clamps. 17:00 - 17:30 0.50 WELCTL OBSV DECOMP Shoot fluid level again and dropped to 590' . Added brine to well 4 bbls pipe displacement x 2. 17:30 - 00:00 6.50 CMPLTN TRIP DECOMP Continued POOH standing back 4.5" tubing in derrick, removing all clamps and spooling ESP cable. LD two GLM, NORM tested. Sent both GLMs to Camco for redress. No external scale or corrosion on 4.5" pipe. All clamps and bands accounted for. 5nt2004 00:00 - 03:00 3.00 CMPLTN TRIP DECOMP Continued to POOH. Pulled 114 jts 4.5" NSTC tubing, 2 GLMs, and LD Centrilift ESP equipment. Inspect Centrilift slotted nipple, intake coupling was broken into pieces. Motor tested good. Trash in top of motor and oil was very dark in color and at bottom oil was very dirty. Pipe and cable came out fairly clean after pumping the 160 deg Brine. 03:00 - 05:00 2.00 RIGMNT OTHR DECOMP Clean and straighten up rig floor. Environmental clean up on rig floor and pipe shed. Inspecting, clean and assemble Phoenix tool. 05:00 - 05:30 0.50 CMPL TN SFTY CMPL TN PJSM with centrilift and rig crew. Review ESP completion running procedures. Review Nabors well control shut-in procedure for running ESP completions. 05:30 - 06:00 0.50 WELCTL OBSV CMPL TN Shoot fluid level again, top of fluid @ 485'. 06:00 - 10:00 4.00 CMPL TN OTHR CMPL TN Change out cable spool. Pick up and Make up centrilift ESP Motor. Discovered a potential problem with the Intake coupling. 10:00 - 11 :00 1.00 WAlTON EQIP CMPL TN Centrilift carried coupling over to Machine Shop to have a hole drilled in it. 11:00 -12:00 1.00 CMPL TN OTHR CMPL TN Completed swapping spools out on the spooler. Begin splicing operation while coupling is being drilled. 12:00 - 12:15 0.25 WELCTL OBSV CMPL TN Shoot Fluid level and found level to be @ 465'. 12:15 - 13:15 1.00 CMPL TN OTHR CMPL TN Continued Splicing operations on the ESP cable. Coupling hole drilled and back on the Rig Floor. 13:15 - 17:00 3.75 CMPLTN OTHR CMPL TN Finished up Splice and Begin to re-assemble Intake coupling sub. Make up Phoenix gauge capillary tube. Connect ESP cable to the Motor. 17:00 - 17:15 0.25 WELCTL OBSV CMPL TN Shoot fluid level again, top of fluid @ 440' 17:15 - 00:00 6.75 CMPL TN TRIP CMPL TN Finish making up Phoenix gauge capillary tube and ESP cable. Begin tripping in hole with the completion. Drifting all tubing and jewelry with 3.833" drift. 5/8/2004 00:00 - 03:30 3.50 CMPLTN TRIP CMPL TN Continue to RIH Wlcompletion, drifting all tubing and jewelry W/3.833" drift. Check continuity on ESP cable every 900'. 03:30 - 04:30 1.00 CMPL TN SOHO CMPL TN M/U Tubing Hanger on completion string WI landing jt, and oriented in proper direction. 04:30 - 08:30 4.00 CMPL TN SOHO CMPL TN Make final splice of ESP cable to penetrator. Test conductivity of ESP cable. 08:30 - 09:15 0.75 CMPL TN SOHO CMPL TN Connect up and discover the ESP cable is a little to long. Pull back off to shorten. 09:15 - 10:45 1.50 CMPL TN SOHO CMPL TN Completed shortening the ESP cable, connected and tested. Checked out OK. Connected up to Hanger and re-checked. Test is good again. Installed all penetrators in hanger. 10:45 - 11 :30 0.75 CMPL TN SOHO CMPL TN Up Wt = 54k & Dwn Wt = 52k, Block Wt 10k. Landed Hanger, RILDS, and tested to 5000 psi. Good test. Pnnted: 5/21/2004 10.53:06 AM /""""\ ............, , , '" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-140 1 0-140 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S Start: 5/4/2004 Rig Release: Rig Number: Spud Date: 9/22/2000 End: Group: 5/8/2004 11:30 - 15:30 15:30 - 18:00 18:00 - 00:00 4.00 CMPL TN NUND CMPL TN 2.50 CMPL TN SEaT CMPL TN 6.00 CMPL TN FRZP CMPL TN Installed 2-way check and begin ND BOPE. Emptied and washed Pits. NU Tree and test void to 5000 psi. Body tested to 5000 psi. Pull TWC. RU LRS and bullhead 38 bbls diesel down tubing, and 46 bbls down IA for freeze protect. R/U lubricator,set BPV. NU blind flanges on valves. Clean cellar area. RELEASED RIG at 00:00 HRS. Printed, 5/21/2004 10'53:06 AM ConocJP'hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 26, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak well 1 0-140. 10-140 was worked over in October of 2003 to replace failed electric submersible pump (ESP) equipment. A new Through Tubing Conveyed Centrifugal ESP pump assembly (TTC CESP) was successfully run in the well. In November of 2003 the well was returned to production utilizing the. new equipment. Unfortunately, this new equipment failed after about 1 month of production. The AOGCC was notified of the ESP failure on 01/17/04. The failure appears to be in the coupling between the pump and motor. The well was put on gas lift and returned to production in January of 2004 (Sundry #304-020). The TTC CESP pump has been pulled and gas lift valves have been set in the mandrels at 2513' and 3440'. Gas lift gas is being injected down the 4-1/2" tubing by 7-5/8" casing annulus with production up the 4-1/2" tubing. The workover objective is to pull the existing TTC CESP motor assembly and replace it with a similar TIC CESP assembly. The pump section will be run on slickline after the rig has moved off location. If you have any questions or require any further information, please contact me at 265-6820. Howard B. Go er Well Supervisor CPAI Drilling and Wells RECEIVE[) MAR 0 2 2004 At8~k8 Oil & Gas Cons. Comrm~sjon .AflChoPJ,ge 8CÁ~NH~EI} MAR 1 5 2004 ORIGINAL f'\ C \.,.., C ~ \l l:.,~ t ....' STATE OF ALASKA MAR 0 2 ZOO~/:> APP~t~~ ~;~;: ~~~o~s~~;~~c~;~~~V j.'[~~ 0,1 ~ :::n~~:;(' c"'m"~ 20 AAC 25.280 "- Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Variance D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 200-136 /200-146 \. .?' 6. API Number: 1. Type of Request: D D D Suspend D Repair well 0 Pull Tubing 0 Perforate D Stimulate D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 102' Development - 0 Stratigraphic D Exploratory D Service D Annular Disp. 0 Other 0 50-029-22974-00/50-029-229 4-60 9. Well Name and Number: 1 D-140 /1 D-140L 1 Ý 10. Field/Pool(s): West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8117' 3772' 7619 3718 Casing Length Size MD CONDUCTOR 110' 110 509' 509 3619' 3509 4175' 3740 7619 3718 Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 35951 8. Property Designation: Kuparuk River Unit TVD SURFACE PRODUCTION 110' 16" 407' 10-3/4" 3517' 7-5/8" 556' 7" 3935' 4.5"x4" PRODUCTION Liner Perforation Depth MD (ft): No perfs pre packed screens in Hz laterals Packers and SSSV Type: Packerless completion no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: June, 1, 2004 16. Verbal Approval: Date: Perforation Depth TVD (ft): Packers and SSSV MD (ft) 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG D GINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Howard Gober '77:> Contact: Title: Phone 265-6820 Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance 0 Other:~5()O ~\ ~\~\ ,,,",,'V \1""- ~ö~ \Q:.~\- -,ei~~. BY ORDER OF THE COMMISSION Burst Collapse Service 0 Plugged 0 WINJ D Abandoned 0 WDSPL D Howard Gober @ 265-6820 Well Supervisor Date: Sundry Number: ~"3l)"i--l){ð g-- wa.... û ~j -- SUBMIT IN DUPLICATE West Sak 1D-140 General Workover Procedure Pre-ria Work 1. 10 days before Rig Workover, RU Slickline Unit. Pull GLV at 2513' and OV at 3440'. Install OV's in both pockets. 2. Obtain SBHPS (7 day SI) (downhole gauges are functional). 3. Kill well w/in 24 hrs of rig arrival by bullheading 1.5 WBVs of heated (160 degF) KW brine down the backside & tbg. 10.1 ppg KWF is expected. 4. Set BPV. 5. Prepare location for Workover Rig. General Workover Procedure 1. MIRU Workover Rig. 2. Verify that well is dead. 3. NO Tree, MU Test plug, NU BOPE. 4. Test the BOPE to 4000 psi. 5. Pull Test plug. 6. Pull tbg hanger. 7. RU spools for ESP cable. Pull tbg & ESP Motor. Stand-back tbg for re-run. 8. MU New ESP equipment. RIH on existing 4-1/2" tubing. 9. Land tubing hanger. RILDS. Install 2-way check. 10. ND BOPE. NUTree. Test tree. Pull 2-way check. 11. Freeze protect with diesel to +/- 2000' TVO. 12. Set BPV. ROMO workover rig. Post-Ria Work: 1. Pull BPV. 2. RU Slickline. Run TTC CESP pump, pack-off, & slip-stop. 3. Return to production. W0'~ I( '2.-~ / /-L/I . STATE OF ALASKA. DçTS / / ¿ G/ 9- , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Periorate D Variance 0 Annular Disp. 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate D Time Extension D Other 0 Change approved program 0 Pull Tubing 0 Periorate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Perm~to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 200-136/200-146 ./ 3. Address: Stratigraphic 0 Service D 6. API Num~: P. O. Box 100360 50-029-22974-00/50-029-22974-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 102' 1 D-140 /1 D-140L 1 à. Property Designation: 10. Field/Pool(s): Kuparuk River Unit West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 811T 3772' 7619 3718 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 1101 110 SURFACE 40T 10-3/4" 509' 509 PRODUCTION 351T 7-5/8" 36191 3509 PRODUCTION 556' 7" 4175' 3740 Liner 39351 4S'x4" 7619 3718 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): No perfs pre packed screens in Hz laterals 4-1/2" L-BO 3595' Packers and SSSV Type: Packers and SSSV MD (ft) Packerless completion no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January, 30, 2004 /' Oil 0 /' Gas 0 Plugged 0 Abandoned C 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs/Marie McConnell @ 659-722£ Printed Name ,MJ Loveland I / Title: Problem Well. supe.. ~s. or Signature ./};¡J//;./z/'\-.-l' ~ Phone 659-7224 Date: èiJ~J {";L4-1 ~ 4 I r¡ I ~ Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3D t./- tJ¿rO Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RECEIVED . /.. JAN 2 6 2004 SUbSSrzlqU F~rm )"ir ~... '. 40t..( AI k 0' & G C C .. , as 'a:¡I., "as on,.s. ommlSSlon ,I ,,;/ Anchorage I ! .. .' BY ORDER OF .' l' Approve ~ l' A........-- COMMISSIONER THE COMMISSION Date: ej /d / tJ1- -- ,// . =0='. ..." I I Form 10-403 Revised ~~~n~~~4EC: F~E:B Ü 2; 2.004. 0 S~ ~ CJ \ SUBMIT IN,~~PLlCATE . . > ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l1D-140 (PTD 200-136/200-146) January 20,2004 This application for Sundry approval for well 1 D-140 (PTD 200136/200146) is to document that the AOGCC and ConocoPhillips concur the well may be produced on gaslift due to a failed Electric Submersible Pump (ESP). The ESP failure was reported to the AOGCC on 01/17/04."-- The well was recently re completed with a new ESP during a workover in October 2003 and had been on production for about one month. Due to the configuration of the completion, the well does not have an isolation packer between the tubing and annulu( Prior to the workover the well was successfully produced with reverse gaslift (gas injected down the tubing and producing fluid up the lA, Sundry #302-376). / The current plans for well 1 D-140 include producing with conventional gaslift, injecting gas into the inner annulus and producing up the tubing using the 2 lift gas mandrels that were installed during the workover. All produced fluids will enter the tubing through the inactive pump. The applied gaslift will prevent annular flow of produced liquids. The well is equipped with a wellhead Safety Valve System as per regulations. ConocoPhillips intends to workover this well in the future to replace the ESP motor. /' Recent well test data shows the following results: WELL TEST SUMMARY REPORT FORM TOTL LIFT LIFT DS WL LENGTH CHK FTP FTT OIL WAT %WC FLUID GAS GOR GLR HZ PRES 1D 140 6:00 100 347 76 1027 951 38 1654 93 91 56 50 904 1D 140 12:00 100 318 73 909 1065 48 1745 144 159 83 45 1057 1D 140 6:00 100 311 68 736 1074 42 1269 111 151 88 40 0 As per this request, ConocoPhillips intends to produce 1D-140 on lift gas until the ESP is repaired. . . , KRU 1 D-140L 1 ConocoPhillips Alaska, Inc. 1D-140L 1 API: 500292297460 SSSV Type: None Rev Reason: Pull ESP assembl Last U date: 1/20/2004 To Bottom TVD Wt Grade Thread 0 3619 3509 29.70 L-80 BTC-MOD 0 509 509 40.50 J-55 BTC 0 110 110 151.50 X-65 WELD 3619 4158 3680 26.00 L-80 BTC-MOD 3684 3685 3552 0.00 L-80 joins 1 D- 140 Thread BTC MOD HSLHT Thread NSCT Comment Perfs thru screens :>RODUCTION (0-3619. 00:7,625. Wt:29.70) Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK-5 0.000 0 10/27/200 SOV 1.0 BK-5 0.000 0 11/22/200 2000# SEAL (3558-3559. ID 00:5.000) 3.930 MOTOR 3.930 (3572-3589, 00:5.500) 3.930 0.000 0.000 4.500 0.000 ID Centralizer 3.844 (3595-3596, 3.958 00:6.250) 3.958 3.500 3.437 LlNER-"-'" (3698-4231, 00:4.500, Wt:12.30) Perf (4231-7619) ..- It Mike Mooney ~ , Wells Group Team Leader Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 ConocoPhiiii pS Phone: 907-263-4574 December 5, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-1401 1 D-140L 1 (APD # 200- 136/200-146) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 D-140/140L 1. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, i4J ¡;¡~ M. Mooneý Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED DEC 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage SCA~~EiJ¡JA¡' 2 @ 2004 0 R \ G \ N A L ( ,( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter Casing D Repair Well Ii] Plug Perforations D Stimulate D Time Extension D Other D Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Ii] Exploratory D 200-136/200-146 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22974-00/50-029-22974-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' 1 D-140 / 1 D-140L 1 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field, West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 8117' / 7663' feet true vertical 3772' / 3719' feet Plugs (measured) Effective Depth measured 7619' feet Junk (measured) true vertical 3718' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 407' 10-3/4" 509' 509' PRODUCTION 3517' 7-5/8" 3619' 3509' PRODUCTION 539' 7" 4158' 3740' LINER 3935' 4.5" X 4" 7619' 3718' Perforation depth: Measured depth: no perfs, pre-pack screens in horizontal laterals true vertical depth: R E C E I VE D Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3595' MD. DEC 1 6 Z003 Packers & SSSV (type & measured depth) no production packer (packer-less completion) Alaska Oil & Gas Cons. Commission no sssv Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 734 666 287 - 314 Subsequent to operation 736 110 533 - 311 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development Ii] Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil Ii] GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Guy Schwartz @ 265-6958 Printed Name Mike Mooney Title Signature Phone 0 R , G " ~i ~ ~;, , SUBMIT IN DUPLICATE ( ( ConocoPhillips Alaska, Inc. KRU 1 D-140L 1 1D-140L 1 500292297460 PROD None 10/31/2000 10/28/2003 31' RKB To Bottom TVD Wt Grade Thread 0 3619 3509 29.70 L-80 BTC-MOD 0 509 509 40.50 J-55 BTC 0 110 110 151.50 X-65 WELD 3619 4158 3680 26.00 L-80 BTC-MOD 3684 3685 3552 0.00 L-80 joins 1 D-140 TUBING (0-3595, 00:4.500, 10:3.958) Zone WS D,WS DWS D Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK-5 0.000 0 10/27/2003 SOV 1.0 BK-5 0.000 0 11/22/2003 2000# MOTOR (3572-3589, Descri tion I D 00:5,500) BAKER PHOENIX TEMPERATURE SUB set 10/27/2003 3.930 BAKER PHOENIX TEMPERATURE SUB set 10/27/2003 3.930 BAKER TCC SCREENED INTAKE set 10/27/2003 3.930 4.5" ESP PUMP SET 11/11/2003; SLIPS TOP & PACK OFF SET @ 3483' 0.000 WLM 11/22/2003 3558 3468 SEAL ESP TANDEM SEAL set 10/27/2003 0.000 3572 3477 MOTOR BAKER ESP MOTOR KMH /190 set 10/27/2003 0.000 3589 3488 GAUGE BAKER PHOENIX GAUGE set 10/27/2003 4.500 3595 3492 Centralizer BAKER CENTRALIZER set 10/27/2003 0.000 Öthêìi li,......s...e.....Û¡...¡......etê; ......~.UPI?SRLÄmERÄIlJEWELR¥ De th TVD T e Descri tion 3932 3648 VALVE BAKER 'HMCV' CEMENTING VALVE 3951 3652 PKR Baker CTC 7' Isozone ECP 4075 3674 PKR Baker CTC 20' Pa zone ECP 4162 3681 KOIV KOIV 4197 3681 SLEEVE Baker 4.5" CMD Slidin Sleeve General Notes Date Note 12/6/2000 NOTE: This is a multilateral well. This schematic represents the 'D' sand upper lateral. See schematic for 1 D-140 for the 'B' sand lower lateral. LINER (369B4231, 00:4.500, WI: 12.30) Perf (4231-7619) ( ( ConocoPhillips Alaska Page 1 of 5 Operations Summary Report Legal Well Name: 1 0-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 1 0/16/2003 End: 1 0/26/2003 Contractor Name: Nabors3sCompanyM @conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From.. To Hours. Code Sub Phase Description of Operations .. Code .. ... 10/16/2003 20:00 - 23:00 3.00 MOVE RURD MOVE Rig released from 2T-12A. Prep rig for rig move. Scope derrick down. Jack up pit module and pipe shed. 23:00 - 00:00 1.00 MOVE RURD MOVE Wait on weather. Cross wind blowing 25+mph. Cannot lay derrick down until wind speed drops to 15 mph. 10/17/2003 00:00 - 10:00 10.00 MOVE RURD MOVE Wait on weather. Cross wind blowing 25+mph. Cannot lay derrick down until wind speed drops to 15 mph. 10:00 - 15:30 5.50 MOVE RURD MOVE Wind layed down and derrick layed over. Continue with the rig move. 15:30 - 16:30 1.00 MOVE MOVE MOVE Move rig from 2T to CPF-2. 16:30 - 19:00 2.50 MOVE MOVE MOVE Wait at CPF-2. Confined space work going on at CPF-2. Could not block emergency response access. 19:00 - 21 :00 2.00 MOVE MOVE MOVE Move rig from CPF-2 to 1 D. 21 :00 - 00:00 3.00 MOVE MOVE MOVE Arrive 1 D pad. Move camp from 2T to 1 D. Position mats around 1 D-140. Move rig over well. Very tight getting between adjacent wells. Move rig forward. Drop blooey line to get more cushion between rig and 1 D-1 05. Layout herculite around well. 1 0/18/2003 00:00 - 01 :45 1.75 MOVE MOVE MOVE Layout herculite line. Back rig over well. 01 :45 - 10:00 8.25 MOVE RURD MOVE Level up carrier sub. Spot pipe shed and pit module. Hook up lines between modules. Beat ice off the derrick in preparation to raise. 10:00 - 12:30 2.50 MOVE RURD MOVE Leveled sub and raised derrick and accepted Rig @ 12:00 pm. Setting up tank farm for filtering of the brine. 12:30 - 14:00 1.50 MOVE SFTY MOVE Held pre-spud meeting with Day rig crew, tool pushers, service rep's, and engineer. 14:00 - 15:00 1.00 MOVE RURD MOVE Re-Ieveled sub and centered derrick over the well. Prepared to ND the tree. Well is dead with a slight vac on the IA. 15:00 - 16:00 1.00 WELCTL NUND DECOMP Nipped down the tree. Tree and tubing head adapter were in good shape. 16:00 - 20:00 4.00 WELCTL NUND DECOMP NU BOP stack. NU is taking extra time because stack had to be broken into 3 pieces when ND at 2T-12A. BOP cradle will not fit behind West Sak wells. 20:00 - 21 :00 1.00 WELCTL SFTY DECOMP Hold pre-spud meeting with night crew, MI, Centrilift, Toolpusher, engineer, & Company Man. 21 :00 - 00:00 3.00 WELCTL NUND DECOMP Continue NU BOP stack. Install riser on top of annular preventer. MU choke and kill lines. 1 0/19/2003 00:00 - 00:45 0.75 WELCTL NUND DECOMP MU choke and kill lines. 00:45 - 01 :15 0.50 WELLSR PLGM DECOMP Equalize pressure underneath BPV. Small amount of gas. Bled right down. Pull BPV. Set 2-way check in hanger. 01 :15 - 04:00 2.75 WELCTL OBSV DECOMP Small amount of gas pressure on annulus. RU bleed trailer and bleed down annulus. Suck out gravel for mousehole. Set mousehole. Fill pits with 50 bbls fresh water for caustic wash. Water has diesel in it. Call for vac truck and new water. 04:00 - 09:00 5.00 WELCTL BOPE DECOMP Test BOP equipment to 250 low and 5000 psi high. Test annular preventer to 250 low and 3500 psi high. Remove water from pits and rinse the pits down. Put 50 bbls fresh water in pits for caustic wash. 09:00 - 11 :00 2.00 RIGMNT RSRV DECOMP Slip and cut drilling line. 11 :00 - 12:30 1.50 WELLSF PULD DECOMP Setting up equipment for Centrilift spooler & Raychem spooler. 12:30 - 16:45 4.25 WELLSF CIRC DECOMP Performed caustic wash of all surface lines and pumps. Also washed lines out to the tank farm. Rinsed the same with fresh water. Re-clean the pits post caustic wash. 16:45 - 18:00 1.25 WELCTL EQRP DECOMP Blocked in the annulus bleed and rigged up hard line to the IA. Pulled the 2-way check and monitored the hole. Had a little bubbling gas, but fluid level seems to be dropping. Closed blinds in preparation for upcoming circulation. Continued to clean the pits. 18:00 - 18:45 0.75 WELLSF RURD DECOMP Loaded clean filtered 9.8# brine into clean tank at the tank farm. Printed: 12/2/2003 4:41 :34 PM ( ( ConocoPhilHps Alaska Page 2 of 5 Operations Summary Report Legal Well Name: 1 0-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 1 0/16/2003 End: 1 0/26/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From -To Hours Code Sub Phase Description of. Operations ... Code ... .. .. 10/19/2003 18:00 - 18:45 0.75 WELLSF RURD DECOMP Finished cleaning the pits. 18:45 - 20:00 1.25 WELLSF RURD DECOMP Load pits with filtered 9.8# brine from the tank farm. Suction pit 1 NTU. 20:00 - 22:00 2.00 FISH CIRC DECOMP Circ down IA taking returns through choke manifold to shaker. First 10 bbls returns were oil then cleaned up. Continue circulating. Returns fairly clean (56 NTU) until bottoms up. Started getting more oil in returns. Circulate total of 200 bbls. Returns still oily. SD pump. Close choke. Pump 40 bbls into formation. 2.5 bpm 150 psi start. 2.5 bpm 240 psi end. SD pump. Recovered approx 50 bbls crude oil. 22:00 - 00:00 2.00 FISH RURD DECOMP Call out more brine. Filter remaining returned brine in pits. Load 10 jts 4-1/2" tubing in pipe shed. Bring tubing tools to floor. Prep to hang sheaves and containment hose for power cable. 10/20/2003 00:00 - 04:45 4.75 FISH RURD DECOMP Hang sheave for Centrilift power cable and sheave for Raychem heat trace. Hang containment hose for power cable. Thread rope through hose and sheaves. Install drain hose on power cable sheave. Put 9.8# brine in tank farm. Filter brine and ship to pits. 1 NTU in pits. 04:45 - 05:15 0.50 FISH CIRC DECOMP 20 psi on IA. Open up IA through choke to shaker. Pump filtered brine down IA taking returns up tubing. Recovered 5 bbls oil. Returns cleaned up nicely after bottoms up. Brine coming back approx 20 NTU. 05:15 - 05:30 0.25 WELLSF PLGM DECOMP Set side port isolation sleeve in hanger. 05:30 - 08:15 2.75 FISH RURD DECOMP Pump fluid out of pits to tank farm. Blow down lines to MI and through choke system. Empty oily fluid out of pits. Prep pipe shed for handling clamps. Put XO and TIW valve on landing joint. 08:15 - 08:45 0.50 FISH SFTY DECOMP Held pre-job meeting with all involved on the rig floor. 08:45 - 09:25 0.67 FISH PULL DECOMP Stabbed into hanger with landing joint. Pulled up to 55K and noticed that 7-5/8" moved slightly. Slacked back off and checked it out. Appears to be that compression is being relieved, looks OK. Pulled up to 63K and hanger started coming up. Pulled very smoothly. Hanger at the rig floor and all cables intact. Filled hole, took 9 bbls to top off. 09:25 - 11 :45 2.33 FISH PULL DECOMP Disconnected the cables from the hanger and tested the cables all tested good. The heat trace is good. Inspected the hanger and it looks to be in good shape. Layed down the hanger, left the 30' joint connected to the hanger. Layed down the landing joint. 1 st stand in the rack. 11 :45 - 13: 15 1.50 FISH PULL DECOMP 5 stands in the rack tubing looks to be in good shape, but is coming back coated with oil. All flat guards and 26 bands collected, this is 2 more than was indicated on the original tally. Filled hole, took 16 bbls to top off. 13:15 - 15:20 2.08 FISH PULL DECOMP 10 stands in the rack. Fill hole, 10 bbls to top off. Tubing still looks to be in good shape, the same with the cannon super clamps. 15:20 - 16:45 1.42 FISH PULL DECOMP 15 stands in the rack. Fill hole, 9 bbls to top off. Strapped stands and cleaned up the rig floor a little. Tubing and clamps coming back in good shape, just oily. 16:45 - 18:15 1.50 FISH PULL DECOMP 20 stands in the rack. Fill hole, 8 bbls to top off. Crownomatic started giving them problems and found it to be bent. 18:15 - 18:45 0.50 RIGMNT RGRP DECOMP Repair the crownomatic. 18:45-21:15 2.50 FISH PULL DECOMP 30 stands in the rack. Tubing in good shape. Everything coated with oil. Bands are in good shape. Call out vac truck for returns. Will try circulating hole to see if it will clean up the tubing. Continue to pull while waiting on vac truck. 21 :15 - 22:45 1.50 FISH PULL DECOMP 40 stands back. Hole taking 10 bbls per 5 stands pulled (8.6 bbls more than calculated). Oil coating on pipe cable and clamps is getting worse. 22:45 - 23: 15 0.50 FISH CIRC DECOMP Clean up rig floor. Prep to circulate. Take on filtered brine from MI tank farm. Printed: 12/2/2003 4:41 :34 PM ( ( ConocoPhillips Alaska Page 3 of 5 Operations Summary Report Legal Well Name: 1 0-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 1 0/16/2003 End: 1 0/26/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From -To Hours Code Sub Phase Description of Operations ... Code . ... .. .. 1 0/20/2003 23:15 - 00:00 0.75 FISH CIRC DECOMP Brine in pits 4 NTU. Pump filtered 9.8# brine down tubing taking returns up the annulus. Oily returns to start then cleaned up to a small amount of oil with brine. 10/21/2003 00:00 - 01 :00 1.00 FISH CIRC DECOMP Finish pumping brine. 4 NTU in. 6 NTU out of well. Small amount of oil in returns. SD pump. Blowdown lines to MI. Remove oily return fluid from pill pit. 01:00 - 03:15 2.25 FISH PULL DECOMP POOH to end of heat trace cable on stand 49. Spool up all heat trace cable and release Raychem hand. Pull stand 50. Fill hole took 9 bbls. Pipe is pulling less oily. Slowed down pulling speed and wiped both cables and pipe to keep oil and water from blowing off pipe and cables in derrick. 03:15 - 03:45 0.50 FISH PULL DECOMP Clean up rig floor. Prep to pull remainder of pipe and ESP equipment. 03:45 - 05:30 1.75 FISH PULL DECOMP POOH wI std 56. Move cannon clamps from top of skate in pipe shed. LD GLM with pup joints on top and bottom. Pull std 57. Pull and laydown 2-9' pup joints. Cut I-wire above splice. 05:30 - 08:30 3.00 FISH PULD DECOMP Lay down Centrilift ESP equipment. Inspect Centrilift Pump, Drive Shaft Failed. 08:30 - 12:30 4.00 RIGMNT OTHR DECOMP Clear handling tools off rig floor. Environmental clean up on rig floor and pipe shed. 12:30 - 13:30 1.00 WELLSF OTHR WRKOVR MIU Running tool with wear ring. Set same, lay down running tool. 13:30 - 15:00 1.50 WELLSF TRIP WRKOVR Strap & Drift BHA, MIU Baker dual casing scrapers. 15:00 - 18:00 3.00 WELLSF TRIP WRKOVR Trip in hole with scrapers on 4-1/2" tbg from derrick. No returns.Well taking fluid @ 3-8 bph. 18:00 - 20:30 2.50 WELLSF CIRC WRKOVR Circulating down tbg taking returns to MI Filtration Unit. Clean fluid to surface. Reverse circulate one hole vol. clean fluid to surface. Brine in pits 3 ntu, returns 11 ntu. 20:30 - 20:40 0.17 WELCTL OBSV WRKOVR Monitor well, flow check, OK 20:40 - 23:30 2.83 WELLSR TRIP WRKOVR POH, Stand back 4-1/2" Tbg in derrick. Break down BHA. Lay down dual scrapers. 23:30 - 00:00 0.50 WELLSR TRIP WRKOVR MIU Baker Retrievmatic test packer. 1 0/22/2003 00:00 - 03:30 3.50 WELLSR TRIP WRKOVR RIH with Baker Retrievamatic test pkr on 4-1/2" tbg. 03:30 - 04:00 0.50 WELLSR DEOT WRKOVR Set Baker Packer @ 3582' MD 04:00 - 04:30 0.50 WELLSR DEOT WRKOVR Pressure test 7-5/8" casing to 2500 psi. Chart test. 04:30 - 05:00 0.50 WELLSR CIRC WRKOVR Bleed off test pressure. Release packer. Blow down choke. R/U to circ. 05:00 - 08:00 3.00 WELLSR CIRC WRKOVR Reverse circulate one hole volume. Monitor well, flowing slowly. Circulate another bottoms up. Monitor well, slow flow. Close pipe rams, no pressure build up. 08:00 - 09:00 1.00 WELCTL OTHR WRKOVR Inject 30 BBLS into formation to flush out casing and laterals, 2.5 BPM, 290 psi. Leave shut in 1 hour. 09:00 - 11 :30 2.50 WELCTL CIRC WRKOVR Circulate bottoms up through choke holding 0-30 psi back pressure, 2.5 BPM, 130 psi. Returns are clean brine, no oil on bottoms up. 9.8 ppg in & out. Lost an additional 18 Bbls while circulating through choke. Shut in and monitor well while transferring return brine off rig to tank and bringing in filtered brine. 0 psi on Tbg, 10-20 psi on annulus after 1 hour. 11 :30 - 14:00 2.50 WELCTL OBSV WRKOVR Open well and monitor. Flow from well continued to slow, initial rate at 12 Bbl/hr, slowed to 3 BPH after 1 hr, 1.5 BPH after 2 hrs. Tubing dead, very slow flow from annulus, 9.8 ppg in and out. Well charged from losses while reversing, bull heading, and circulating. Elect to pull a few stands, monitoring well closely. 14:00 - 18:30 4.50 WELLSF TRIP WRKOVR LD 3 joints, POOH 5 stands. Hole took proper fill up. Continue POOH. Stopped twice to monitor hole with fill-up pump off, no flow. Hole took 4 Bbl over calculated fill. LD last single and Baker Retrievamatic Packer. Printed: 12/2/2003 4:41 :34 PM (' ( ConocoPhillips Alaska Page4 of 5 Operations Summary Report Legal Well Name: 1 0-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 1 0/16/2003 End: 1 0/26/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From -To Hours Code Sub Phase Description of. Operations .. Code 1 0/22/2003 18:30 - 19:00 0.50 WELLSR SFTY WRKOVR Held PJSM with Schlumberger E-line crew. Discussed rig up procedures and hazards associated with e-line operations. 19:00 - 22:30 3.50 WELLSR OTHR WRKOVR Install bope lubricator in stack. RIU Schlumberger.M/U tool string to run USIT log. 22:30 - 00:00 1.50 WELLSR OTHR WRKOVR RIH with US IT log to 3,560' ELM. Log showed good casing. Make second pass with USIT log. 10/23/2003 00:00 - 01 :30 1.50 LOG OTHR WRKOVR Continue logging with USIT second pass, casing good. Hole taking a small amount of brine while logging. 01 :30 - 03:00 1.50 LOG PULD WRKOVR RD Schlumberger lubricator and logging tools. LD shooting nipple. 03:00 - 04:00 1.00 WELCTL OBSV WRKOVR Monitor well. Well flowing slowly. Shut well in, well built up to 10 psi. Observe well, flows slowly. 04:00 - 05:00 1.00 WELCTL KILL WRKOVR Bullhead 40 Bbls of 9.8 ppg brine into well, 2.5 BPM, 250 psi. Bleed off pressure, got back 20 bbls. Open blinds and monitor well. Well flowing back and had some gas breaking out and some crude. 05:00 - 07:00 2.00 WELCTL OBSV WRKOVR Shut in well and monitor for pressure build up while preparing brine in pits to bullhead well. 10 psi. 07:00 - 11 :00 4.00 WELCTL KILL WRKOVR Bullhead 166 Bbls of 9.8 ppg brine, 3 BPM, 220 psi to 420 psi. Leave shut in and monitor pressure fall off. 250 psi ISIP, 60 psi at 1 hr, 40 psi at 2 hrs, 20 psi at 3 hrs. Sting Centrilift line through derrick sheave while monitoring well and tie off at rig floor. 11 :00 - 12:30 1.50 WELCTL OBSV WRKOVR Open choke line and bleed off through poor boy degasser and monitor returns. Rate slowing. Call for 290 bbls of 10.0 ppg brine. 12:30 - 16:30 4.00 WELCTL COND WRKOVR Weight up brine in pits to 10.0 ppg. Transfer to tank. Bring in balance of brine from tank and weight up to 10.0 ppg. Fill suction pit with 10 ppg and line up to bring in 10 ppg from tank. Monitor returns from well while weighting up, got 55 Bbls back, rate slowing but continuing. 16:30 - 19:00 2.50 WELCTL KILL WRKOVR Bullhead 180 Bbls of 10.0 ppg brine into well, 3 BPM, 230 psi to 390 psi. Leave shut in and monitor pressure fall off. 230 psi ISIP, 30 psi after 1 hr. Prepare to bleed off pressure and observe well. 19:00 - 23:00 4.00 WELCTL KILL WRKOVR Open choke line and and monitor returns to pits thru poorboy degasser. Observed 18 bbls bleed back from well. Open blind rams. Well stable. 23:00 - 00:00 1.00 WELLSF DEOT WRKOVR PIU one joint drill pipe. MIU wear ring running tool. BOLDS. Pull wear ring. UD running tool and drill pipe. 10/24/2003 00:00 - 00:30 0.50 CMPL TN SFTY WRKOVR PJSM with centrilift and rig crew. Review ESP completion running procedure. Review Nabors well control shut-in procedure for running ESP completions. 00:30 - 06:00 5.50 CMPL TN RUNT WRKOVR MIU motor centralizer, phoenix gauge assembly, ESP motor, ESP tandem seal section, and TCC intake screen with tubing pup jt. Install MLE cable and instrument lines to ESP assembly. 06:00 - 06:30 0.50 CMPL TN DEOT WRKOVR Install cable clamp protectors and flat armor guard on ESP assembly. 06:30 - 06:45 0.25 CMPL TN DEQT WRKOVR Surface test MLE cable and instrument lines. Well taking fluid @ 3 to 5 BPH. 06:45 - 09:30 2.75 CMPL TN RUNT WRKOVR Run 2 jts 4-1/2" tubing, MIU Phoenix pressure and temperature sub assembly. Install pup jt to line up instrument slots with ESP cable. 09:30 - 11 :30 2.00 CMPL TN RUNT WRKOVR Hook up instrument lines to Phoenix subs. 11 :30 - 14:30 3.00 CMPL TN DEOT WRKOVR Surface test and calibrate Phoenix pressure and temperature subs. 14:30 - 18:00 3.50 CMPL TN RUNT WRKOVR RIH with ESP completion on 4-1/2" tubing. Inspect threads and drift tubing with 3.833" rabbit. CIO 2 jts of tubing with damaged threads. 18:00 - 00:00 6.00 CMPL TN RUNT WRKOVR RIH with ESP completion on 4-1/2" tubing. Inspect threads and drift tubing with 3.833" rabbit. 1 0/25/2003 00:00 - 01 :30 1.50 CMPL TN SOHO WRKOVR Complete running ESP completion. MIU Vetco/Gray tubing hanger. MIU landing joint. Orient tubing hanger to alignment pin. 01 :30 - 03:30 2.00 CMPL TN SOHO WRKOVR Make final splice of ESP cable to penetrator .Megger cable. M/U ESP Printed: 12/2/2003 4:41 :34 PM ( ( ConocoPhillips Alaska Page 5 of 5 Operations Summary Report Legal Well Name: 1 0-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 1 0/16/2003 End: 10/26/2003 Contractor Name: Nabors3sCompanyM @conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From -To Hours Code Sub Phase Description of Operations .. Code . .. 10/25/2003 01 :30 - 03:30 2.00 CMPL TN SOHO WRKOVR penetrator to tubing hanger. Drain BOP stack. Rig down cable spooler.Clear floor of all handling equipment. 03:30 - 04:00 0.50 CMPL TN SOHO WRKOVR Land tubing. Check alignment on tubing hanger. RILDS.Pressure test upper and lower hanger seals to 5000 psi.Back out and lay down landing joint.Set BPV. 04:00 - 05:00 1.00 CMPL TN NUND WRKOVR Pull and lay down mouse hole, clear all lines of fluid. Dump and clean pits. Blow down choke manifold. 05:00 - 09:00 4.00 CMPL TN NUND WRKOVR NID BOPE 09:00 - 10:30 1.50 CMPL TN NUND WRKOVR NIU Tree 10:30 - 14:00 3.50 CMPL TN SEaT WRKOVR PJSM, NIU Hi-pressure lubricator. Pull BPV. Set TWC. Pressure test to 5000 psi. Pull TWC. 14:00 - 20:00 6.00 CMPL TN FRZP WRKOVR RIU lines, choke skid and pump unit to tree. MIU return lines to MI tank farm. PT lines 1500 psi. Displace well with 155 bbls SW. Recover 10 ppg brine to MI tank farm.R/U lines to pump down tbg x csg annulus. PT lines to 1500 psi. Pump 65 bbls diesel down annulus taking SW returns up tbg to MI tank farm. Shut in tubing. Bullhead 15 bbls down annulus, 3.2 bpm @ 800 psi.Blowdown lines, RID pump truck. Install jumper to u-tube diesel.FSIP 525 psi. 20:00 - 21 :30 1.50 CMPL TN FRZP WRKOVR U-tube diesel between tubing and tubing by casing annulus. 21 :30 - 22:30 1.00 WELLSF SEaT WRKOVR Attempt rig down u-tube jumper line. Shut master valve on tree. Master valve leaking. Call out valve crew. Grease valve. OK. Rig down u-tube line. 22:30 - 00:00 1.50 WELLSR SEaT WRKOVR Rig up hi- pressure lubricator on tree, set BPV. BPV and master valve on tree both leaking. Grease master valve. OK. Pull BPV. Body seal damaged. Redress BPV. Reset BPV.Lay down lubricator. Shut-in and secure tree and wellhead for rig move. Released rig from operations on well 1 D-140 @ 0000 hrs on 10-26-03. Notified Wells group of leaking master valve on tree. Printed: 12/2/2003 4:41 :34 PM ~'- Q3~ &>0- J 4 ~ogl-Cft 12/08/03 Schlnmbel'ger NO. 3057 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ( Well Job# Log Description Date BL Color CD .,' 3B-01 5<. ::CS-("Y:::j( INJECTION PROFILE 11/24/03 1 1 L-09 ,C IO--E "d~ :L LEAK DETECTION LOG 11/26/03 1 1 C-119 ...,~ ( ~{- I:2.Y INJECTION PROFILE 11/27/03 1 1 C-121 ~ ~ I-~¡-y,/) INJECTION PROFILE ~ 11/30/03 1 1D-110A 10709648 USIT - Ù"-t ~~~ (,-~ \õ ,,"'"LS1~....,.J:":'\ n--();£-C~ 10/31/03 1 I..t. 1 D-140L 1 10709639 USIT \ 10/22/03 1 2P-432 ~<. )--.j..{)1 SLIM SONIC LOGGING TOOL 11/21/03 1 \ 2P-432 10687658 US IT 11/16/03 1 --r .f:': E\ II:: I "'" it J P a \. L- \..,. i,..... I V ........ L..! ( SIGNE~"'~ê\_' ( ,:;""..\"'" \. ( 0;"" ~/V" . \ DEC 1 2 2003 DATE: Alaska Oil & bas Cons. Gommi~on Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Anchorage c.\,~r'I' ~ HI¡.~E'~"" DE' '11 t1) n ion") ~~~ \\\. ~\':"'\\1'"~¡\~R'~'"J-.< ~, ~~ fij) ~,iJ _.U~~ Permit to Drill 2001460 MD 7663 TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~20O3 Well Name/No. KUPARUK RIV U WSAK 1D-140L1 Operator CONOCOPHILLIPS ALASKA INC 3719 Completion Dat 10/31/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22974-60-00 UIC N REQUIRED INFORMATION Mud Log No Sample N.__~o Directional Survey __.-I~o---_~.).~,. ..... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No (-~0~0260 FINAL C C C C R R D D C C T T T T T R R D D D D R R (data taken from Logs Portion of Master Well Data Maint 10261~''''''~ FINAL. LIS Verification ~ FINAL 10338 ~ FINAL 10370 ~ FI NAL "~ey Report 10240 10241 Lis Verification FINAL FINAL ~"'"'~- FINAL Interval Start Stop OH I CH ' 502 8072 ch Received 8/2012001 8/20/2001 5O2 5O2 5O2 502 502 5O2 502 5O2 5O2 6113 7604 7604 7604 8072 7604 6113 6106 8065 ch OH OH OH Open Open Open Open Open oh oh oh 9/27/2001 9/27/2001 10/4~2001 8/16/2001 9/27/2001 8/16/2001 8/9/2001 8/9/2001 1/9/2001 8/13/2001 8/13~2001 8/13/2001 Dataset Number Comments 10260'~-~072 Digital data"-~-~ lO261 r~}2~113 digital data (,, ~ 502-7604 LIS Verification 10338~,~0~-7604 Digital Data 10370 t.F~-7604 Digital Data ~ ~ 1026(~-8072 (~~' '1 10338~./b~2-7604 ] 10241 ~'0'~-6106 10240 %02-8065 Survey Report Paper Copy 10240 ~s Verification Digital Data 10241~,~s Verification Digital Data ~, .[ Lis Verification Paper Copy Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 1116~2O03 Permit to Drill 2001460 Well Name/No. KUPARUK RIV U WSAK 1D-140LI Operator CONOCOPHILLIPS ALASKA INC MD 7663 TVD 3719 Completion Dat 10/31/2000 Completion Statu 1-OIL Current Status Well Cored? Y/~ Daily History Received? Chips Received .-~,-~'-~;~~-'~' Formation Tops (~ N Analysis R~.n~.iv~.d ? APl No. 50-029-22974-60-00 1-OIL UIC N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: The technical data listed below is being submitted herewith. concerns to the attention of: State of Alaska October 01,2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 1 MWD Formation Evaluation Logs: 1D-140, 1D-140 L1, 1D-140 PB1, AK-MM-00202 Please address any problems or Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-140: Digital Log Images: 50-029-22974-00 1 CD Rom 1D-140 LI: Digital Log Images: 50-029-22974-60 1 CD Rom 1D-140 PBI: Digital Log Images: 50-029-22974-70 1 CD Rom Note: This data replaces all previous data for well: 1D-140. RECEIVED OCT 0,1 2001 Alaska Oil & Gas Cons. C, omml~ion WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 21, 2001 RE: MWD Formation Evaluation Logs Redo 1D-140 L1, AK-MM-00202 1 LDWG formatted Disc with verification listing. APl#: 50-029-22974-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: SEP 2. 7 .001 ~c~or~e WELL LOG TRANSMITTAL To'- August 16, 2001 State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1D-140, 1D-140 L1, 1D-140 L1 PB1, AK-MM-00202 c~ or)- / $~ ~oo- ~g/o The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1D-140: Digital Log Images: 50-029-22974-00 1 CD Rom 1D-140 LI: Digital Log Images: 50-029-22974-60 1 CD Rom 1D-140 L1 PBI: ! Digital Log Images: 50-029-22974-70 1 CD Rom RECEIVED AU$ 20 2001 Alaska Oil & Gas Cons~ Commissi~ Anchorage WELL LOG TRANSM1TFAL To: State of Alaska August 09, 2001 Alaska Oil and Gas Conservation Co. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-140 L1, AK-MM-00202 1 LDWG formatted Disc with verification listing. APl#: 50-029-22974-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sm Drilling Service Atto: lim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed~~~~;)~.~ RECEIVED (' WELL LOG TRANSMITTAL To: State of Alaska August 09, 2001 Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-140 L1 PB1, AK-MM-00202 1 LDWG formatted Disc with verification listing. API#: 50-029-22974-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED ArIS 1 Z 2001 Anchorage ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas r"] suspended D Abandoned D Service 2. Name of Operator -~--: ~ ~ ' ? 7. Permit Number Phillips Alaska, Inc. ~,~ 200-146 3. Address,.-~ ....... 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 i~ 50-029-22974-60 4. Location of well at surface L~- r~. 9. Unit or Lease Name 149' FSL, 595' FEL, Sec. 14, T11N, R10E, UM (ASP: 560491, 5959814) '; '.'/! ".'" '~:'.' ' i Kuparuk River Unit At Top Producing Interval ..i'.' .'i'! 10. Well Number ' ""/~ ~'-'~'-/'~"~-- ~ 1 D-140L1 744' FSL, 360' FEL, Sec. 14, T11 N, R10E, UM (ASP: 560719, 5960412) At Total Depth 11. Field and Pool 844' FNL, 534' FEL, Sec. 14, T11 N, R10E, UM (ASP: 560513, 5964103) :~ ......................... ,, Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool 30' RKB feetI ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Suep. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 22, 2000 October 19, 2000 October 31,2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7663' MD/3719'TVD 7619' MD/3718'TVD YES r~ No D'1 N/A feetMD 1642' 22. Type Electric or Other Logs Run GR/PWD, GR/Res 23. CASING, LINER AND CEMENTING RE(~ORD ! SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 151.5# X-65 Surface 110' 24" 135 sx AS I 10.75" 40.5# J-55 Surface 510' 12.25" 110 sx ArtiCrete 7-5/8" x 7" 29.7# / 26# L-80 Surface 4158' 9.875" 410 sx AS III Ute, 380 sx Class G 4.5" x 4" 12.6# / 9.5# L-80 3684' 7619' 6" 40 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD). 4.5" 3596' 4020' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. No perfs, pre-pack screens in horizontal laterals DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4298'-7535' 6% formic acid 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.)LJ November 16, 2000 Flowing Date of Test -louts Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 11/27/2000 6 hfs Test Period > 617 103 12 110 I 167 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') press. 331 ps not available 24-Hour Rate · 174 22 3 not available . 28. CORE DATA Brfef description of Ilthology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.RECEIVED ./A DEC 1 5 000 Naska 0il & Gas Cons. Com~ssion Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. [ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include Interval tested, pressure data, all fluids recovered and gravily. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4019' 3666' West Sak A3 7663' 3719' Base West Sak Sand 7663' 3719' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is tree and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 ' Signed_ ~ ~11 t~.~,~, ~"~'~- ~, Title Drillin.q E n,cllneerin(:~ Supervisor Date v James Trantham Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 Gas Cons. Con'~nission Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-140 ML STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:09/22/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22974-00 09/21/00 (D1) TD/TVD: 0/0 SUPV: MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 (0) M/U BHA Secure well. PJSM, rig move. Move rig from 1D-141 to 1D-140. Accept rig ~ 2200 hrs. 9/21/00. NU diverter system. 09/22/00 (D2) TD/TVD: 520/519 SUPV: MW: 0.0 VISC: 0 PV/YP: 0/ 0 (520) CIRCULATE FOR 10 3/4" CMT JOB APIWL: 0.0 N/U diverter and function test. Held pre-spud meeting. Spud in, drill 12.25" hole from 120' to 309'. Problem w/top drive, pull back to cond., repair TD. Ream from 120' to 309', circ, run gyro. Drill 12.25" hole from 309' to 520' Circ and pump sweep. 09/23/00 (D3) TD/TVD: 637/637 SUPV: MW: 8.9 VISC: 120 PV/YP: 34/41 ( 117) DRILLING 9 7/8" HOLE APIWL: 6.2 Wiper trip to 120' & RIH to bottom, no fill. Circ bttms up. Pull out to run 10.75" casing, hole slick. Rig up to run casing. PJSM. Run 10.75" casing. Circ an~ cond mud for cement job. PJSM. Pump cement. RIH tag .up @ 422', c/o to 501', C/O cement from 501' to 510, drill out shoe @ 510', c/o rat to 510', drill 9-7/8" hole from 520' to 535'. Pump sweep, displace w/new mud. Drill 9-7/8'". hole from 535' to 637'. 09/24/00 (D4) MW: 9.2 VISC: 90 PV/YP: 35/33 APIWL: 4.0 TD/TVD: 2102/2096 (1465) DRILLING @ 2584' SUPV: Directionally drill 9-7/8" hole from 637' to 1717'. Pump sweep and circ hole clean. Wiper trip from 1717' to 504', hole slick, service TD, RIH to 1717', hole slick. Directionally drill 9-7/8" hole from 1717' to 2102'. 09/25/00 (D5) MW: 10.2 VISC: 90 PV/YP: 40/42 APIWL: 2.5 TD/TVD: 3639/3522 (1537) DRILLING @ 3771' SUPV:DON MICKEY Directionally drill 9-7/8" hole from 2102' to 3639'. Pump sweep ~ 3543'. Pump dry job, wiper trip from 3639' to 1717', no problems. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/26/00 (D6) MW: 10.3 VISC: 77 PV/YP: 34/31 APIWL: 3.5 TD/TVD: 4165/3735 (526) RUNNING HOLE OPENER & REAMER @ 1800' SUPV:M.C. HEIM RIH to 3639'. Drilling and surveys from 3639' to 4165', checking for flow. CBU. POH. 09/27/00 (D7) MW: 10.1 VISC: 72 PV/YP: 32/23 APiWL: 3.0 TD/TVD: 4165/3735 ( 0) CEMENTING 7" X 7 5/8" CSG. SUPV:M.C. HEIM RIH w/BHA93. Wash and ream 9-7/8" hole from 550' to 4165' w/no problems. POH. PJSM. Run 7" x 7-5/8" casing. Circ and condition hole. 09/28/00 (DS) MW: 10.1 VISC: 65 PV/YP: 34/17 APIWL: 4.0 TD/TVD: 4165/3735 ( 0) RIH W/ HWDP SUPV:M.C. HEIM Circ and reciprocate for orienting window and cementing 7" x 7-5/8" surface casing. PJSM. Pump cement. ND diverter system. NU BOPE and function test to 250/30009. 09/29/00 (D9) MW: 0.0 VISC: 65 PV/YP: 0/ 0 TD/TVD: 4368/3738 (203) DRLG. & SURVEYS ~ 4611 MD-3739 TVD. SUPV:M.C. HEIM APIWL: 0.0 RIH. Tag @ 4067', drill wiper plug, fc, cement, shoe and clean out to 4165'. Drilling from 4165' to 4185'. Pump sweep and displace LSND mud with Baradrill. Perform FIT, 11.59. POH for repairs to ABI or MWD. RIH, CBU for FIT. Perform. FIT, EMW 11.59. Drilling and surveys from 4185' to 4368' 09/30/00 (D10) MW: 10.1 VISC: 50 PV/YP: 15/28 APIWL: 3.8 TD/TVD: 5618/3749 (1250) DRLG. SLOW THRU FAULT @ 5748' (DRILLED INTO FAULT ~ 5 SUPV:M.C. HEIM Drilling and surveys from 4368' to 5618'. 10/01/00 (Dll) MW: 10.1 VISC: 53 PV/YP: 14/30 APIWL: 3.2 TD/TVD: 6038/3788 (420) DRLG. IN SAND-ATTEMPTING TO IDENTIFY WHICH ONE. SUPV:M.C. HEIM Drilling and surveys from 5618' to 5877', attempting to find top of sand after drilling into fault. 10/02/00 (D12) MW: 9.8 VISC: 55 PV/YP: 10/21 APIWL: 3.6 TD/TVD: 5930/3775 ( 0) DRLG. ~ 6290' SUPV:M.C. HEIM Continue drilling from 5877' to 6147'. Pump sweep, circ & reciprocate. POH to 5493' and start sidetrack 91. Trenching from 5443' to 5493'. Drilling and surveys from 5493' to 5930' Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 10/03/00 (D13) MW: 9.9 VISC: 52 PV/YP: 13/28 APIWL: 3.4 TD/TVD: 6867/3778 (937) DRILLING AHEAD W/ 6" LOWER LATERAL 'B' SAND ~ 6976' SUPV:DONALDWESTER Continue to directional drill 6" lower lateral "B" sands from 5830' to 6001'. Changed out mud system to 9.8 ppg mud. Drill ahead while running 25 bbls water cutting mud weight to 9.5 ppg. Well started to flow ~ 6920'. Bring weight back to 9.9 ppg while drilling ahead to 6480'. Continue drilling ahead from 6480' to 6867'. Pumping two sweeps for hole cleaning. POOH to 5700'. Hole not taking fluid light swabbing. Back ream side track from 5700' to 5300'. CBU no gas or oil cut mud. Continue POOH. 10/04/00 (D14) MW: 9.8 VISC: 50 PV/YP: 13/27 APIWL: 3.4 TD/TVD: 8117/3772 (1250) TD'D ~ 8117' POOH FOR REAMER HOLE OPENER RUN SUPV:DONALD WESTER RIH with 3.5" HWDP to 6.867'. Continue drilling 6" lower lateral from 6867' to 8117' TD. Changed out mud to 9.7 ppg. POOH pump out due to swabbing. 10/05/00 (D15) MW: 9.8 VISC: 48 PV/YP: 15/24 APIWL: 3.0 TD/TVD: 8117/3772 ( 0) DISPLACE BARADRIL-N W/ SEA WATER AND FOLLOWED BY 9.8 P SUPV:DONALD WESTER Continue to pump out due to swabbing from 7839' to 5247', hole fill good. RIH with 6" hole opener reamer assembly to 4158' 7" casing shoe. Ream 6" hole from 4158' to 7096' 10/06/00 (D16) TD/TVD: 8117/3772 ( SUPV:DONALD WESTER MW: 9.8 VISC: 0 PV/YP: 0/ 0 0) PUMPING CAUSTIC WASH APiWL: 0.0 Continue to ream lower lateral 6" hole from 7096' to 8117' with BHA ~7, harc calcite stringers. Circulate load MI clear brine. PJSM. Start sweeps and circ. RIH to 8117'. CBU oil cut mud on bottoms up. POOH to shoe @ 4158'.RIH with scraper assembly to 3580'. 10/07/00 (D17) TD/TVD: 8117/3772 ( SUPV:DONALD WESTER MW: 9.8 VISC: 0 PV/YP: 0/ 0 0) RUN LINER STOPED ~ 6147' APIWL: . 0.0 RIH w/7-5/8" & 7" scrapers assembly to 4080'. PJSM. Displace viscosified brine with clear brine. R/U to pump caustic wash. PJSM. Pump caustic wash. PJSM. Pump acid pickle job. POOH. R/U to run 4" x 4.5" Baker pre-pack screen liner. PJSM. RIH w/Baker screen assembly. Run 2-7/8" Baker cup assembly. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 10/08/00 (D18) TD/TVD: 8117/3772 ( SUPV:DONALD WESTER MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0)POOH W/ SCREENS 925 DAMAGED. CLEAR FLOOR. Run 2-7/8" cut assembly inside 4" screen assembly. PJSM. RIH on running string. Tight hole @ 5800' to 6147' string stopped. This is end of original hole before sidetracking. From 5446' to 5693' new hole. M/U top drive rotate string slowly w/4000 to 5000 ft/lb trying to make screen assembly go into new hole from 5423' to 5611' continue RIH stopped @ 6147' in old hole. Circulate brine. Heavy oil and gas cut oil coming from old hole. Stuck screen assembly for a short time. Worked string free. Pull to casing shoe @ 4158'. Circulate brine. Monitor well OK. Pull 4" screen assembly. 10/09/00 (D19) TD/TVD: 8117/3772 ( SUPV:DONALD WESTER MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 0) POOH PUNP OUT TO 5420' RIH WITH OUT PUMP TO 6200' PUMP Continue to pull and lay down 4" x 4.5" screen assembly. Weekly BOP test to 250/3500 psi. RIH with 6" hole opener to 6147' TD old hole. CBU. Pull 9 stands 5420'. Circulate and ream and try to re-enter sidetrack. Ream and wash at slow rate from 5420' to 5640'. RIH to 8117'. Circulate and work string reamer from 5460' to 5550'. POOH pump out due to swabbing. 10/10/00 (D20) TD/TVD: 8117/3772 ( SUPV:M.C. HEIM MW: 9.9 VISC: 0 PV/YP: 0/ 0 0) ATTEMPTING TO RELEASE FROM PACKER. APIWL: 0.0 Continue POH to 5409', pumping out. Monitor well and RIH to 6210'. POH to shoe, pump out to 5036'. Continue POH. PJSM. RIH w/4" blanks and screens, run 2-7/8" inner string. Circ capacity of 2-7/8" inner string. RIH w/screens on HWDP and DC. 10/11/00 (D21) TD/TVD: 8117/3772 ( SUPV:M.C. HEIM MW: 9.9 VISC: 0 PV/YP: 0/ 0 0) POH WASHING SCREENS W/ ACID. APIWL: 0.0 Continue RIH w/ 4" liner and screens to 8117'. Set packer and attempt to release from same. Work pipe, rotate, pressure up and pull, packer released. PJSM. Pump acid. Allow acid to soak. PJSM. Circ acid out of pipe & annulus. Pump acid. 10/12/00 (D22) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 8117/3772 ( 0) RIH W/ WHIPSTOCK SUPV:M.C. HEIM Pumping acid thru each screen while POH. POH. Make up HES 7" bridgee plug, RIH and set ~ 3788' and test to 15009, OK. Drop 20/40 sand down DP and circ into place. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 10/13/00 (D23) TD/TVD: 8117/3772 ( SUPV:M.C. HEIM MW: 9.8 VISC: 41 PV/YP: 14/19 0) SLIDING IN SHALE @ 3790'. APIWL: 3.6 RIH to tag sand @ 3762'. Reverse circ ~ 3701 capacity of dp. POH. RIH w/whipstock. Test whipstock. Circ dp volume.~ POH. RIH w/window mill. Displace to drilling mud and mill ~ window from 3682' to 3702'. Pump sweeps and clean hole. ~' Circ hole clean and run FIT, 129. PJSM. POH, lay down milling assembly. PJSM. RIH w/dp. 10/14/00 (D24) MW: 9.7 VISC: 47 PV/YP: 13/22 APIWL: 3.2 TD/TVD: 4209/3677 ( 0) DRLG. & SURVEYS @ 4656' SUPV:M.C. HEIM Continue run in hole to 3702'. Drilling and surveys from 3702' to 4209'. 10/15/00 (D25) MW: 9.8 VISC: 47 PV/YP: 10/21 TD/TVD: 5731/3715 (1522) DRLG.& SURVEYS @ 6000'. SUPV:M.C. HEIM Drilling and surveys from 4209' to 5135'. APIWL: 3.2 10/16/00 (D26) MW: 10.0 VISC: 57 PV/YP: 14/31 TD/TVD: 6692/3710 (961) DRLG. & SURVEYS ~ 6981' SUPV:M.C. HEIM APIWL: 3.2 Drilling and surveys from 5731' to 6190'. POH to pick up more 3.5" dp, hole not taking proper amount of fluid (slight flow). RIH to bottom. Drilling from 6190' to 6286' while increase mud wt. POH to 3.5" dp. Drilling and surveys from 6286' to 6692'. 10/17/00 (D27) MW: 10.0 VISC: 54 PV/YP: 12/26 APIWL: 3.3 TD/TVD: 7663/3718 (971) POOH DN LOAD MWD & LAY DOWN, R/U TO TEST BOP'S SUPV:DONALD L. WESTER Continue drilling 6" upper lateral from 6692' to 7663' TD. Pump sweeps and increase mud weight to 10.0 ppg. Pump out of hole 7663' to 4331'. 10/18/00 (D28) MW: 10.0 VISC: 56 PV/YP: 15/27 APIWL: 304.0 TD/TVD: 7663/3718 ( 0) REAMING 6" HOLE ~ 7663' TD SUPV:DONALD L. WESTER Continue to pump out from 4300' to 3684'. POOH from 3684' without pumping to MWD equipment. Flush out MWD equipment. Test BOPs Run and set wear ring. RIH w/6" hole opening assembly to 3754'. Ream 6" hole from 3754' to 6430' Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 10/19/00 (D29) MW: 10.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) WAIT ON NEW VISCOSIFIED BRINE SUPV:DONALD L. WESTER Continue to ream 6" hole from 6430' to 7663' TD of upper lateral. Pump sweeps followed by filtered brine followed by viscosified brine. Pump out due to swabbing from 7663' to window ~ 3682'. RIH with tandum 7-5/8" scrapers w/brush. PJSM on caustic wash. Pump clear brine followed by caustic followed by brine displace w/viscosified brine. 10/20/00 (D30) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) R/U TO SET ECP PACKERS & RELEAASE FORM HANGER. SUPV:DONALD L. WESTER Continue to caustic wash DP & casing from 3617'. Displaced caustic w/viscosified brine. Load new brine and displace hole volume. POOH slowly. R/U to run upper 4" x 4.5" lateral screen assembly. PJSM. Run 4" x 4.5" pre-pack screens. 10/21/00 (D31) MW: 9.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) POOH AFTER CEMENT JOB. L/D PIPE NOT NEEDED. SUPV:DONALD L. WESTER Continue to run 2-7/8" enter string. RIH w/4" x 4.5" Baker screen assembly. Inflate lower ECP packer @ 4075'. Locate upper ECP packer @ 3951'. Pump cement. 10/22/00 (D32) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) CONTINUE TO CLEAN OUT HARD CEMENT ~ 3590' ~ 0600 HRS SUPV:DONALD L. WESTER POOH w/cementing assembly. WOC. Tag cement stringers @ 3130'. Clean out cement stringers from 3130' to 3250' firm cement and hard from 3310' to 3340' 10/23/00 (D33) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) M/U BHA 919 WASH OVER ASSY. TO RETRIEVE SPERRY-SUN W HI SUPV:DONALD L. WESTER Continue to clean out cement from 7-5/8" & 7" casing 3341' to 3679'. Rotate and reciprocate Pump sweep hi-vis. POOH. RIM tag up @ 3679'. Clean out cement from transition jt3679' to 3695'. POOH. 10/24/00 (D34) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) POH W/ BHA ~21 AFTER SETTING PRODUCTION WHIPSTOCK & PU SUPV:M.C. HEIM RIH tag ~ 3678', start washover procedure @ 3673', complete washover, circ sweep, jar whipstock loos. Pump pill. POH. RIH with mill. POH. RIH with retriev-o-matic packer and set packer. RIH with whipstock to 3698'. Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 10/25/00 (D35) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) CLEANING OUT @ 4150'. SUPV:M.C. HEIM Rotate whipstock into place. PJSM. Pump acid pickle job. POH. RIH with reverse basket, circ, slide to bottom, attempt to pickup junk w/reverse basket. POH. RIH, drill cement from 3688' to 3860'. 10/26/00 (D36) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) SERVICE RIG. SUPV:M.C. HEIM Continue drilling cement to 3988'. RIH and tag KOIV @ 4158', mill on KOIV. POH. Test BOPE, perform drawdown test, annular failed. Change out annular element, test annular to 250/30009. Rib w/2-7/8" tubing. 10/27/00 (D37) TD/TVD: 7663/3718 ( SUPV:M.C. HEIM MW: 9.9 VISC: 0 PV/YP: 0/ 0 0) ACID SOAK FORMATION. APIWL: 0.0 RIH to koiv @ 4161'. Mill out debris & koiv, clean out thru sliding sleeve @ 4195'. RIH, tag @ 7602'. mill out, drop ball, open lower pump out sub, circ 2 liner volumes, crude oil returns, drop bar & open upper circ sub, cbu. POH. RIH w/2-7/8" tubing. RIH & tag @ 7600'. attempt to work down to 7607', no go. 10/28/00 (D38) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) SERVICING RIG-CREW CHANGE SUPV:M.C. HEIM PJSM. Displace well w/clean brine. Spot acid. PJSM. POH pumping acid thru each screen. Shift sliding sleeve shut & circ hole clean. POH. 10/29/00 (D39) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) RUNNING COMPLETION SUPV:M.C. HEIM RIH w/HRT to 3675'. Circ, wash & release production whipstock. POH. RIH to 3723' w/retrieving tool. Circ, latch & release bridge plug. POH slow. RIH w/tam collar closing tool. Safety meeting. 10/30/00 (D40) MW: 9.9 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) FREEZE PROTECTING W/ DIESEL. SUPV:M.C. HEIM P/U ESP motor and assembly, run in hole w/4.5" tubing. Test pump assembly. Run 4.5" ESP completion. Secure heat trace and test thru hanger. 10/31/00 (D41) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7663/3718 ( 0) RELEASE RIG @ 1200 HRS 10/31/00 SUPV:DON WESTER Set BPV, nipple down BOPE. Nipple up tree and test to 250/5000 psi. OK. Freeze protect well. Move rig off hole. Release rig @ 1200 hrs. 10/31/00 13-Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Wel 1D-140L1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 3,659.82' MD 3,682.00' MD 7,663.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope. Alaska Alaska State.Plane 4 Kuparuk 1D 1D-140L1 Job No. AKMMO0202, Surveyed: 17 October, 2000 .. S UR VE Y REP 0 R T 13 November, 2000 Your Ref: AP1~500292297460 Surface Coordinates: 5959813.97 N, 560490.55 E (70* 18' 02.7841" N, 210' 29' 23.7396" E) Kelly Bushing: 101.50ft above Mean Sea Level A Halliburton Company Survey Ref: svy9331 North Slope Alaska Measured ·Depth -(~) 3659.82 3682.00' _3714.57 3747.24 3779.72 3811.51 -3845.17 3877.75 3908.27 3943.18 3975.65 4008.32 '4036.4O 4069.14 4099.13 4133.30 4165.77 4198.49 4230~0 4262.28 Incl. Azim. 48.550 11.860 -. 48.690' 11.650 53.690 13.010 58.940 14.210 64.130 '15.290 68.700 16.260 73.320 17.220 77.530 '16.980 78.850 .16.390 76.900 15.330 76.840 i2.980 79.790' 11.350 . 81.230 10.930 81.160 "11.120 84.270 10.550 87.780 9.950 88.770 6.500 91.170 3.800 90.180 0.590 89.320 358.350 4291.50 89.020 356.010- 4326.28 89.260 354.980 4358.49 88.890 355.180' -4388.15 89.080 355.860 4422.45' 88.890 - 355.880- Sub-Sea Depth (ft) 3434.26 3448.92 3469.33 3487.45 3502.92 3515.64 3526.59 3534.78 3541.03 3548.36 3555.74 3562.36 3566.99 3572.00 3575.80 3578.17 3579.15 3579.1.6 3578.79 3578.93 3579.35. 3579.87 3580.39 3580.92 3581.53 Sperry-Sun . Dr#h'n g Services Survey Report for 1D.140L1 Your Ref: API-500292297460 Job No. AKMMO0202, Surveyed: 17 October, 2000 Vertical Depth (ft) 3535.76 Local Coordlnatea. Nothings Eaatinga (~) (~) . · 347.22 N 165.44E 3550.42 363.51N ' 168.83 E 3570.83 388.29 N- 174.26 E 3588.95 414.70 N 180.66 E 3604.42 442.30 N 187.93 E' .3617.14 470.33 N 195.86 E '3628.09 500.80 N 205.03 E 3636.28 530.93 N 214.29 E 3642.53 559.55 N_ 222.87 E 3649.86 592.38 N 232.20 E 3657.24 3663.86 3668.49 3673.50 3677.30 3679.67 3680.65 3680.66 3680.29 3680.43. '3680.85 3681.37 3681.89 3682.42' 3683.03 623.03 N 654.31 N 681.48 N . 713.24 N 742.45 N 239.93 E 246.67 E 252.02 E 258.21 E 263.80 E 775.99 N 808.10 N 840.69 N 872.47 N 904.44 N 269.86 E 274.50 E 277.44 E 278.66 E 278.36 E 933.62 N 968.29 N 1000.38 N 1029.94 N 1064.15 N 276.93 E 274.19 E 271.43 E 269.12 E 266.65 E Global Coordinates Northinga Fastings (ft) (ft) 5960162.51N 560653.19 E 5960178.83 N 5960203.65 N 5960230.11 N 5960257.77 N 560656.45 E 560661.68 E 560667.87 E 560674.92 E 5960285.86 5960316.40 5960346.61 5960375.29 5960408.20 560682.61 E 560691.54 E 56O700.56 E 560708.91 E 560717.97 E 5960438.92 5960470.24 5960497.46 5960529.26 5960558.52 56O725.46 E 560731.94 E 560737.08 E 560743.01 E 560748.36 E 5960592.11 5960624.26 5960656.86 5960688.65 5960720.62 5960749.79 5960784.44 5960816.50 5960646.04 5960880.23 560754.16 E 560758.54E 560761.21E 560762.18 E 560761.62E 560759.95 E 560756.94 E 560753.92 E 560751.37 E 56O748.62 E Dogleg Rate (°llOOft) 0.95 15.69 16.36 16.24 14.64 13.99 12.94 4.72 6.33 7.05 10.27 5.34 0.61 10.54 10.42 11.05 11.04 10.56 7.50 8.07 3.04 1.31 2.38 0.56 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 349.37 365.71 390.56 417.05 444.75 Tie on MWD Magnetic Window 472.88 503.47 533.72 562.44 595.39 626.15 657.51 684.75 716.59 745.87 779.49 811.66 844.28 876.07 908.04 937.20 971.83 1003.88 1033.41 1067.58 Continued... 13. November, 2000- 14:27 DrlllQueet 2.00.05 Sperry, Sun Drilling Services Survey Report for 1D-140L 1 Your Ref: API,500292297460 Job No. AKMMO0202, Surveyed: 17 October, 2000 North SloPe AlaSka Measured . Depth . .(ft) 4455.24 4484.34 -4518.55 4551.18 4580.49 4613.83 4645.43 4676.94 4709.89 4742.86 Incl. 88.580 89:020 '90.430 89.260 89.750 -90.250 90.550 90,430 89,820 89.940 Azim. ' 355.250 355.780 353.950-- 35!.640 351.320 351.290 351.300 350.980 . 350.690 4773,83 4806,79 4841.32 4870.39 4901.86 89.380 351,170 89.010 350.280 89.690 350.400 89.750 350.430 88.950 - 350.610 4934.22 88.690 350.060 4964,71 89,140 350.110 '4997.76 89.200 350.260 5029.49 89,140 350.090 5060.11 89,750 349.830 SUb. Sea Depth .(ft) 3582.22 3582.86 3583.02 3583.11. 3583,37 3583.37 3583,14 3582,88 3582,80 3582,87 . 3583.06 3583.52 3583,91 3584,05 3584,41 3585.02 3585,54' 3586.02 3586,48 3586,78 5093.79 89.570 350,080 3586,98 5125,77 89.260 350.310 3587,31' 5156,92 89.140' 352.080 -3587.74 5190.47. 89.200 353.060 3588.23 5222.25 89,020 353.900 3588.72. Vertical Depth (ft) 3683,75 3684.36 3684,52 3684.61 3684,87 3684,87 3684,64 3684,38 3684,30 3684,37 3684,56 3685,02 3685,41 3685,55 3685,91 -.. 3686,52 3687,04 3687,52 3.687,98 . 3688,28 3688,48 3688,81. 3689~24 3689,73 3690,22 Local'Coordinatea Global Coordinatea Northinga Eaatinga Northinga Eaatinge (ft) (fi) (ft) (ft) 1096,83 N 1125,84' N 1159,91 N 1192,27 N 1221,26 N 1254.21" 1285,45 N 1316,59 N - 1349.15 N 1381,70 N 254,11 E 5960912.89 N 560745,82 E 261,84 E 5960941,88 N 560743,31 E 258,77 E 5960975,92 N 560739,98 E 254,68 E 5961008,26 N 560735,63 E 250,34 E 5961037,21 N 560731,05 E 245,28 E 5961070,12 N 560726,73 E 240,48 E 5961101,31N 560720,67 E 235,71E 5961132,42 N 560715,65 E 230,63E 5961154,93 N 560710,31E 225,38 E 5961197,44N 560704,80 E 1412,28 N. 220,50 E 5961227,98 N '1444,80 N. 215,19 E 5961260,46 N 1478,84 N -209,39 E 5961294,45 N 1507,51 N 204,55 E 5961323,07 N 1538,54 N 199,37 E 5961354,07 N 1570,44N . 193,94 E 5961385,92N 1600,47N 188,69E 5961415,91N 1633,00N 183,06 E ' 5961448,42N 1664,29 N. 177,54E 5961479,64N 1694,44N. 172,30 E 5961509,75N 1727,61N. '166,43 E 5961542,86 N 1759,12 N 160,98.E 5861574,33N 1789,90 N 156,22 E 5961605,07 N 1823,16 N - 151,88 E 5961638,29 N 1854.73 N 148,27 E -5961669,83 N 560699,67 E 560694,10 E 560688,03 E 560682,96 E 560677,53 E 560671.84 E 560666.35 E 560660.45 E 560654.79 E 560649.21 E 560643,07 E 560637,37 E 560632,35 E 560627,75 E 560623,88 E Dogleg Rate (°/lOOft) 2,14 2,37 6.75 7,94 2,00 1,53 0,97 0,38 2,09 0,95 2,36 2,92 2,00 0,23 2,61 1,71 0,84 0,49 0,57 2,17 0,91 1,21 5,69 2,93 2,70 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1100,23 1129,20 1163,22 1195,54 1224,46 1257.35 1288,51 1319.59 1352,08 1384,55 1415,07 1447,52 1481.48 1510,08 1541,04 1572,87 1602,82 1635,31 1666,50 1696,57 1729.65 1761,09 1791.80 1825.01 1856.53 13 NOvember, 2000- 14:27 · . . -3- Continued... DrillQuest 2.00.05 North Slope Alaska Measured Depth (fi) Incl.. 5251.06 89.630 5285.54 89.940 5319.86 ' 89,690 5349.22 89;820 5380.88 90,250 5414.58 90,680 -5443.66 90.490 5478:29 90.000 5510.81 90.370 5540.60 86.980 5574.44 83.770 5607.35 '82.290 5636.44 82.590 5675.11 79.980 5702.77 80.600 5732.45 83.340 .5766.81 85,250 5798.66 87.110 5828.42 88.890 5862.29 90.310 5894.87. 90.680 5924.68 91,420 5959.26 -91,540 5990.13 91.420 6021.34'91,420 Azim. - 357.090 358.130 358.380 358.060 357.500 357,220. ' 358.030 357,530 358.140 ' 358.33O 357.890 357,910 357.610 356.080 - 355,640 355.020 354,670 353,910 353.830 353.030 352.270 352.600 352,730 355,430 355,830 Sub-Sea Depth (ft) 3589,06 3589.19 3589.30 3589,43 .3589.41 3589,13 3588.84 3588.69 3588,58 3589.27 3592,00 3595,99' 3599.82 3605.68 3610,34 ' 3614.49 3617,91 ' 3620,03 3621.07 3621,30 3621,02 3620.48 3619,58' 3618,78 3618,01 Sperry. Sun Drilling Services Survey Report for 1D-140L1 Your Ref: API,500292297460 Job No. AKMMO0202, Surveyed: 17 October, 2000 Vertical Depth' (fi) 3690,56 3690,69 3690,80 3690,93 3690.91 3690.63 3690,34 3690,19 3690;08 -3690,77 3693,50 3697,49 3701,32- 3707.18 3711,84 37-15,99 3719,41. 3721.53 3722.57 3722~80 3722.52 '-3721,98 3721,08 3720,28 3719.51- Local Coordinates Northlngs (ft) 18,3.45 N 1917.90 N 1952.20 N 1981.54 N 2013.18 N- 2046.84 N 2075.90 N 2110.50 N 2143.00 N 2172.76 N 2206.47 N 2239.11 N 2267.93 N 2306.09 N . 2333,28 N 2362,57 N 2396,62 N 2428,24 N 2457,81 N 2491,45 N 2523,77 N 2553,31 N 2587,60 N 2618.29 N ' 2649.40 N Eaetlngs 145.Ol E 144.57 E '143.52 E 142.61 E 141.39 E 139.83 E 138,63 E 137,29 E .138,06 E 135,14 E 134,03 E 132,83 E. 131,71 E 129,60 E 127,64 E 125,24 E 122,17 E 119,01 E 115,83 E 111.96 .E 107179 E 103.87 E 99,45 E 96,27 E 93,89 E .Global Coordinates Northings Eastlnga (ft) (ft) 5961698,53N 560621,39 E 5961732,97N 560619,68 E 5961767,26N 560618,35 E 5961796,60N 560617,21E 5961828,22 N 560615,72 E 5961861,87N 560613,90 E 5961890,92N 560612,46 E 5961925,51N 560610,84 E 5961957,99 N 560609,35E 5961987,75N 560608.20E 5962021,44 N 560606,81 E 5962054,08 N 560605,35 E 5962082,88 N 560603,99 E 5962121,03 N 560601,59 E 5962148,20 N 560599,40 E 5962177,47 N 560596,77 E 5962211,49 N 560593,42 E 5962243,09 N 560590,01 E 5962272,63 N 560586,59 E 5962306,24 N 560582,45 E 5962338,52 N 560578,02 E 5962368,03 N 560573,86 E 5962402.28 N 560569,17 E 5962432,95 N 560565,74 E 5962454.04 N 560563,11 E Dogleg Rate (o/looft) 11,27 3,15 1.03 1,18 2,23 1,52 2,86 2,02 2,19 11,40 9,57 4,50 1,45 7,80 2,74 9,46 5,65 6,31 5.99 4,81 2.59 2,72 0.51 8,75 1.28 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1885.21 1919,64 1953.93 1983,26 2014.87 2048,51 2077,55 2112,13 2144,61 2174.36 2208.05 2240,67 2269,47 2307,60 2334,76 2364,02 2398,O2 2429.60 2459.12 2492,72 2524,97 2554,46 2588.68 2619,33 2650.41 13 November, 2000 - 14:27 '4' ' Continued,,, DrlllQueet 2.00.05 Sperry. Sun Drilling Services Survey Report for 1D.140L1 Your Ref: API.500292297460 Job No. AKMMO0202, SurveYed: 17 October, 2000 North SlOpe AlaSka Measured Depth'. . (ft) Incl. Azim. 6054.30 91.540 355.490 6088.18 92:090 355.600 -6116.05- 90.490 356.910 6150.10 89.880 357.040 6181.47 89.570 356.980 6212.07 89,510 6229.87 89.450 6262.74 89.320 6294.24 89.450 6325.44 90,180 90.120 90.000 90.550 90.120 90.250' 6358.47 6390.60 6421.51 6454.83 6487.34 356.720 355,880 355,750 356,080 356.160 356.48O 356.440 355.59O -354,540 6518.60 90.430 354.760 6551.17 90,180 ' 353.980 6583.11 90.060 358.530 6615.'04 90.120 359.480 6647.02 90.060 358,720 _Sub-Sea Depth (fi) 3617.16 3616.09 - 3615.46 3615.35. 3615.50 3615.75 3615.91 3616.26 . 3616.60 3616.70 3616.61 3616.58 3616.43 3616.24 3616.13 3615.94 3615.77- 3615.70 3615.65 .3615.60 6681.14 90.920 357.600 3615.31 6710.61 90.920 357,920-. 3614.84' 6743.21 91.050 358.120 3614.28 6775.41 91.110 357.450 3613.67 6806.91 90.620 357.510 3613.20 VertiCal Depth (ft) 3718.66 37'17.59 3716.96. 3716.85 37i7.00 3717.25 3717.41 3717.76 3718.10 3718.20 . 3718.11 3718.08 3717.93 3717.74 3717.63 .. 3717.44 3717.27 3717.20 3717.15 3717.10 37i6.81 3716.34 3715.78 ' 3715.17 3714.70 '- Local Coordinates Northings (ft) 2682.25 N 2716.01 N 2743.81 N 2777.82 N 2809.14 N 2839.70 N 2857.47 N 2890.27 N 2921.68 N 2952.80 N 2985.76 N 3017.82 N 3O48.67 N 3081.91 N 3114.30 N 3145.42 N 3177.83 N 3209.70 N 3241.62 N 3273.60 N.- 3307.70 N 3337.14 N 3369.72 N 3401.89 N- 3433.35 N Global Coordinates Eaetings Northinga Eaatings -(ft) (ft) (ft) . 91.40E 5962496.87N 560560.35 E 88.77E 5962530.61N 560557.45 E 86.95 E 5962558.40 N 560555.41E 85.15 E 5962592.38N 560553.34 E 83.52E 5962623.70 N 560551.45 E 81.86 E 5962654.23N 560549.54 E 80.85 E 5962672.00N 560548.39E 78.73 E 5962704.78N 560546.01E 76.43E 5962736.17 N 560543.46 E 74.21E 5962767.27N 560540.98 E 71.97E 5962800.21N 560538.48 E 69.91E 5962832.26 N 560536.16 E 68.00E 5962863.09 N 560534.01E 65.69E 5962896.31N 560531.42 E 62.89 E 5962928.67N 560528.37E 59.98 E 5962959.77N 560525.20 E 56.78 E 5962992.16 N 560521.75 E 54.69E - 5963024.00N 560519.40 E 54.14 E 5963055.92N 560518.59 E 53.64E 5963087.89 N 560517.83 E 52;54 E 5963121.98 N 560516.46 E 51.39 E 5963151.42 N 560515.07E '50.26 E 5963183.98 N 560513.69 E 49.02E 5963216,14 N 560512.18 E 47.64E 5963247.60 N 560510.54 E Dogleg Rate (°/lOOff) 1.09 1.66 7.42 1.83 1.01 0.62 0.56 2.59 0.58 2.57 0.30 1.06 1.78 2.86 3.25 0.91 2.51 14.25 2,98 2.38 4.14 1.09 0.73 2.09 1.57 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2683.23 2716.95 2744.72 2778.70 2810.00 2840.53 2858.29 2891.06 2922.44 2953.53 2986.45 3018.48 3049.30 3082,51 3114.86 3145.94 3178.31 3210.14 3242.05 3274.02 3308.10 3337.53 3370.09 34O2.24 3433.68 Continued... 13 November, 2000- 14:27 -5.- DrlllQueet 2.00.05 North Slope Alaska MeaSured Depth (ft) Incl. 6839.12 91.420 6873.20 91.850 6903.51- 91.910 6936.58 91.850 6969.23 91.540 6999.69 89.380 7031.28 87.540' 7064.17 86.120 7094.21 86.300 7127.67 ' 86.610 7159.36 87.230' 7190.83' 87.660 7223.84 90.860' 7256.30 91.110 7286.40 90.620 7320.44 90.120 7351.24 90.43O 7382.40 90.490 7415.81' 90.120 7448.71 90.000 7478.38. 90.000 7510.73 90.000 7546.07 89.750 7578.40 89.630 7663.00 89.630 .' A~m. 356.630 357.290 357.390 358.690 359.800 1.14o 1.47o 2.320 1.7oo :2.060 1.96o 1.57o 1.94o 2.18o 2.090 Sub-Sea Depth (ft) 3612.62 3611.65 3610.66 .3609.57 3608.61 13 November, 2000 - 14:27 Sperry. Sun Drilling Services Survey Report for 1D-140L 1 Your Ref: API-500292297460 Job No. AKMMO0202, Surveyed: 17 October, 2000 'Vertical . Depth (ft) 3714.12 3713.15 3712.16 3711.07 3710.11 36O8.36 3609.21 3611.03 3613.01 3615.08 3709.86 3710.71 3712.53 3714.51 -3716.58 3616.79 3618.19 3618.62 3618.06 3617.60 .3718.29 . - 3719.69 3720.12- 3719.56 3719.10 .. 1.650 3617.38 3718.88 1.270 -3617.24 3718.74. 1.220 3616.98 3718.48 1.000 3616.81 3718.31' '0.640 3616.77 3718.27 359.960 3616.77 3718.27 0.360 3616.77 ' 3718.27 - 10.820 3616.85 3718.35 0.770. 3617.02 3718.52 0.770 -3617.57 3719.07 Local Coordinates Northinga Eaatinga (ft) (ft) 3465.52 N 3499.53 N 3529.79 N 3562.83 N 3595.46 N · 3625.91 N 3657.48 N 3690.30 N 3720.26 N 3753.64 N 3785.26 N 3816.69 N 3849.67 N- 3882.11 N 3912.18 N 3946.20 N 3976.99 N 4008.15 N. 4041.55 N 4074.44 N' 4104.11N 4136.46 N - -4171.80 N 4204.13 N 4288.72N 45.99 E 44.18 E 42.78 E 41.65 E 41.22 E 41.47 42.19 43.27 44.32 45.42 46.53 47.50 48.51 49.67 50.79 51.91 52.69 53.37 54.01 54.49 54164 54.73 55.10 55.54 56.68 Global Coordinates Northings Eaatinga (~) (~) 5963279.74N 560508.64E 5963313.75N 560506.56 E 5963343.99 N 560504.91E 5963377.02N 560503.51 E 5963409.64N - 560502.82 E 5963440.10 N 560502.83 E 5963471.67N 560503.29 E 5963504.50 N 560504.11E 5963534.47 N 560504.92 E 5963567.85 N 560505.75E 5963599.48 N 560506.60E 5963630.91N 560507.32E 5963663.91N 560508.06E 5963696.35 N 560508.97E 5963726.44N 560509.85 E 5963760.46 N 560510.69 E 5963791.26 N 560511.22 E 5963822.41N 560511.65 E 5963855.82 N 560512.03E 5963888.72 N 560512.23 E 5963918.39 N 560512.15 E 5963950.74N 560511.98 E 5963986.08 N 560512.06E 5964018.41N 560512.25 E 5964103.01N 560512.70E -6- Dogleg Rate (°ll00ft) 3.69 2.31 0.38 3.93 3.53 8.34 5.92 5.03 2.14 1.42 1.98 1.84 9.76 1.07 1.66 1.96 1.59 0.25 1.29 1.15 2.29 1.24 1.48 0.4O 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3465.82 3499.81 3530.05 3563.07 3595.69 3626.15 3657.72 3690.55 3720.52 3753.91 3785.55 3816.98 3849.98 3882.42 3912.51 3946.55 3977.34 4008.50 4041.91 4074.81 4104.48 4136.83 4172.17 4204.50 4289.09 Projected Survey Continued... DrillQuest 2.00.05 Sperry. Sun Dr#ling Services Survey Report for 1D.140L1 Your Ref: API-500292297460 Job No. AKMMO0202, Surveyed: 17 October, 2000 ._ North' Slope Alaska Alaska State Plane 4 Kuparuk 1D All data is in feet unless otherwise stated. Directions-and cOordinates are relative to True North. Vertica! depths are relative to Well. Northings and Eastings are relative to Well.- Magnetic Declination at Surface is 26.771 ° (03-Now00) . . The Dogleg Severity is in Degrees iper 100 feet. Vertical Section is from Well'and calculated along an Azimuth'of 0.757° (True). . Based upon Minimum Curvature.type calculations, at a Measured Depth of 7663.00ft., The Bottom Hole Displacement is 4289.09ft., in the Direction of'0.757° (True). Comments Measured Depth (ft) .. 3659.82 3682.00 7663.00 Station Coordinates TVD ' · Northings. Eastings Comment (ft) - - (ft) (fi) 3535.76 3550.42 3719.07 .. 347.22 N 165.44 E Tie on 363.51 N 168.83 E Window . 4288.72 N 56.68 E Projected Survey Continued... 13 November, 2000- 14:27 -. .7. DrlllQuest~O0.05 Sperry. Sun Drilling Services Survey Report for 1D'140L 1 Your Reft. API-500292297460 JOb No. AKMMO0202, SUrveyed: 1'7 October, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Survey tool program for 1D- 140L 1 · Fro'm - To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 '-548.34 3659.82 0.00 548.32' 3535.76 '548.34 3659.82 7663.00 Vertical Depth * Survey Tool Description (fi) -548.32 3535.76 3719.07 AK-2 BP_CG . AK-6 BP_IFR-AK. MWD Magnetic 13 November 2000.14:27 °O' . DrlllQuest 2.00.05 ALASILA OIL AND GAS CONSERVATION COPlPIISSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 ' / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Prudhoe Bay Unit 1D-140L1 Phillips Alaska, Inc. Permit No: 200-146 Sur Loc: 149'FSL, 595'FEL, Sec. 14, T1 IN, R10E, UM Btmhole Loc. 406'FNL, 499'FEL, Sec. 14, T1 IN, R10E, UM Dear Mr. Trantham: 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. Please note that may disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a.well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the amaular space of a single well. or to use that well for disposal purposes for a period longer than one year. The permit is for a new wellbore segment of existing well 1D-140, Permit No. 200-136, API 50-029- 22974. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficiem 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 659-3607. Sincerely, Commissioner BY ORDER OF THE (~.OMMISSION DATED this ~;~~ day of September, 2000 dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Depamnent of Environmental Conservation w/o encl. STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of worlc Drill [~1 Redrill O I lb. Type of well. Exploratory O Stratigraphic Test O Development Oil ['~ Re-entry r~ Deepen OI Service [~ Development Gas O single Zone ['~ Multiple Zone O 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 30 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 2,5.02,51) 149' FSL, 595' FEL, Sec. 14, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 668' FSL, 406' FEL, Sec. 14, T11N, R10E, UM 1D-140 L1 #U-630610 At total depth 9. Approximate spud date Amount 406' FNL, 499' FEL, Sec. 14, T11N, R10E, UM October 1,2000 $200,000 12. Distance to nearest properly line ~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 406' @ TD feetI 1D-140 feet 2560 ,~g~.~l'5 ' MD/,~,6:8' 'I'V,D.,~ 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AA¢ 2,5.03,5 (e)(2)) Kickoff depth: 3672' MD Maximum hole angle 90° Maximum surface 1462 psig At total dep~ (TYD) 1875 psig 18. Casing program ! Settin~l Depth size : Specitlcations Top Bottom Quantib/of Cement Hole Casin~l Wei~lht Grade CoupIin~l Len~h MD TVD MD TVD (include sta~le data) 20' 16' 66# L-80 BTC 80' 110' 110' 110' 110' Pre-installed 12.25" 10.75" 40.5# J-55 BTC 470' 110' 110' 500' 500' 110 sx ArtiCRETE 9.875" 7-5/8' x 7" 29.7 / 26 L-80 BTC-Mod 4091' 110' 110' 4121' 3734' 410 sx ASL. ite& 380 sx Class G 6' 4" 9.5# L-80 HSLHT 4144' 3971 3710' 8100' 3746' Screen - No cement 19. To be completed for Redrlll, Re-entry. and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet EI/ective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Meeeured depth True Vertical depth Conductor Surface Production RECEIVED Pe.ora. ondapth: measured $[¢ 1,5 000 20. Attachments Filing fee [~ Property Plat D BOP Sketch r'~ Dive,er Sketch D,,ing,aid program [] m~mevsdepth p~ot DRefractk~n analysis I--I Seabed report I--I 20AAC 2S.0S0 requirements D 21. I hereby c ;rlify that the foreg,o,i,,n,g Is true and correct to the best of my knowledge Questions? Call Steve McKeever265-682{ , Oommission Use Onl~ Permit Number2..(:~:~>.- / %/~ I APl number q-- _~'(/JO Iforother requirements 50- ~.~:~ - ~;~-...(:::~ 7~ '- ~) ~3 I Appr. q.val date .~ ... I See cover letter Conditions of approval Samples required D Yes [] No Mud log required [~ Yes ~] No Hydrogen su.,de mea.ures I--I Yes E] .o D rect,onalsurveyrequ,red Yes I--I .o D2 ; D O loM;D O Required working pressure for BOPE Other: ORIGINAL SIGNED BY byorderof 9' Approved by ~ T~vlnr Se;,~mo0nt Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1D-140 Multilateral Producer (L1 Upper Well Bore) Well Plan Summary Surface Location: 149' FSL 595' FEL Sec 14 TllN R10E UM Main Wellbore B-Sand Lateral - Target I 616' FSL 423' FEL Sec 14 TllN R10E UM B-Sand Lateral -TD 406' FNL 549' FEL Sec 14 TllN R10E UM Sidetrack Wellbore D-Sand Lateral -Top D-Sand 668' FSL 406' FEL Sec 14 TllN R10E UM D-Sand Lateral - TD 406' FNL 499" FEL Sec 14 T11N R10E UM I AFE Number: I AK0045 I I Rig: I Nordic 3 Estimated Start Date: I 10/01/00 I I Operating days: I 37 I IType of Well Well Design I I I I KBE: I 30' Producer Horizontal Multilateral- Pre-Packed Screen Formation Markers: (all depths adjusted for Nordic RKB) Formation Tops True Vertical True Vertical Measured Hole Angle Depth (SS) Depth (RKB) Depth (RKB) Degrees Main Wellbore and B-Sand Lateral Base Permafrost 1541 1642 1647 2 Ugnu C-Sand 2941 3042 3050 16 Ugnu 8-Sand 3186 3287 3319 32 Ugnu A-Sand 3252 3353 3400 37 K-13 Shale 3403 3504 3604 45 West Sak D-Sand 3555 3656 3837 59 West Sak C-Shale 3599 3700 3938 70 West Sak B-Sand 3623 3724 4027 79 West Sak B-Sand Heel 3633 3734 4121 89 West Sak B-Sand Toe TD 3687 3788 8115 91 Sidetrack Wellbore D-Sand lateral West Sak D-Sand 3556 3657 3884 76 West Sak D-Sand Heel 3568 3669 3993 90 West Sak D-Sand Toe TD 3645 3746 8100 91 RECEIVED SEP 5 o00 Na~ka 0~1 & Gas Cons. commiss'~ A~c~orage Well 1D- 140 L 1 Permit Package Drilling Fluid Program, Pressure Calculations & Drilling Area Risks Page 1 of 3 Casing/Tubing Program: (all depths adjusted for Nordic RKB) Hole Csg/Tbg Top Btm Cement Size OD Wt/Ft Grade Conn. Length MD/TVD MD/TVD (~uantity 12-1/4" 10-3/4" 40.5 .1-55 BTC 500' Surface 500'/500' 110 sacks (77 bbl) ArtiCRETE 9-7/8" 7-5/8" x 7' 29.7 / L-80 BTC - Mod 4,121' Surface 4,121' / 3,734' 410 sx (324 26 & 29 bbl) ASLite, 380 sx (79 bbl) Class G 6" Lower 4" Screen 9.5 L-80 HSLHT 4,144' 3,971'/3,710' 8,115'/3,788' Screens- No Lat. Cement 6" Upper 4" Blank/ 9.5 L-80 HSLHT 4,428' 3,672'/3,552' 8,100'/3,746' 195 sx (35 Lat. Screen bbl) Logging/Formation Evaluation Program: Open Hole MWD/GR/RES/PWD (Pressure while Drillinq) I Cased Hole Logs: None I Drilling Fluid Tvoe 6" Production Hole will be drilled with a 6% KCI / NaCI DrilrN Fluid. Drillinq Fluid Properties: Production Interval (D-Sand Horizontal Lateral): Density Viscosity YP PV tauO P_.U AP_..[1 Filtrate 10.3 - 10.5 45 - 53 18 - 24 11 - 17 4 - 7 8.5 - 9.0 < 4 HTHP Chlorides LGS < 10 150 - 170K 12 ppb (drilled LGS) Drilling Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: RECEIVED SEP 15 2000 Alaska Oi{ & Gas Cons. Commission Anchorage Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Well 1D- 140 L 1 Permit Package Drilling Fluid Program, Pressure Calculations & Drilling Area Risks Page 2 of 3 MASP (Maximum Anticipated Surface Pressure): The well path of 1D-140 L1 traverses the West Sak reservoir between water injection wells. Injection into these nearby wells has been suspended, and off take from nearby producers continues in an effort to lower the reservoir pressure in the vicinity of this well. Declining pressures at these nearby wells have been monitored, and will continue to be monitored until this well is spudded. Based on the observed declining pressure trends, the expected reservoir pressures for this well will range from 0.442 to 0.499 psi/~c, or 8.5 to 9.6 ppg EHW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.3 ppg can be predicted as a maximum mud weight required to safely drill this formation. Calculating HASP based on the highest recorded reservoir pressure from the nearby wells, and assuming a gas gradient of 0.11 psi/ft from maximum TVD in the D-Sand to surface, the following HASP can be computed: MASP : (3750 I'c)(0.50 - 0.11 psi/ft) = 1,462 psi Blowout prevention equipment as illustrated in the attached diagram will be in use during all drilling and completion operations of this well, having been nippled up on the 7-5/8" surface casing during the previous drilling of the main well bore and lower lateral. (See permit application for Well 1D-140). Based on this calculation for HASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Drillinq Area Risks: Drilling risks in the area of the West Sak 1D-140 L1 lateral are primarily limited to lost circulation, and potential borehole instability in the K-13 shale above the "D" Sand. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, and the pressure monitoring of nearby wells, 10.3 ppg mud should be adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Phillips has drilled through the West Sak formation many times in nearby wells. For this reason, Phillips Alaska, Inc. requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted over pressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D- 140. Well Proximity Risks: The closest well bore to the 1D-141 L1 lateral is the other leg of this multilateral well. The 1D-141 L1 wellbore will follow a course parallel to the lower lateral, approximately 40 feet above and 50 feet to the east of that lateral. The risk of collision will be minimized by the use of real time "logging while drilling" and "at bit inclination" tools to stay with in the "D" sand and on the planned course of the well path. Annular Pumpinq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be le~c with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-141 surface casing / production tubing annulus will be filled with diesel and / or non-freezing brine al'cer running the ESP completion and prior to the drilling rig moving off of the well. RECEIVED SEP 1 5 2000 A as a & Gas Cons. Com.mi n / chora Je Well 1D-140 L1 Permit Package Drilling Fluid Program, Pressure Calculations & Drilling Area Risks Page $ of 3 Drill, Cas~ =nd Completion Plan for West S(". 1D-140 L1 General Procedure (Upper Lateral Well Boro): 1. Multilateral Producer (o9/~3/oo) Set bridge plug approximately 4 joints below preformed window. Spot +/- 30' of sand on top of bridge plug. 2. Orient and set whipstock assembly. 3. Tag whipstock and displace well with DrilrN Fluid. 4. Hill preformed window and circulate hole clean. 5. PU 6" PDC Bit and Directional BHA. RZH to top of whipstock. 6. Slide out window and drill approximately 20' of new hole. Perform FIT not to exceed 12 ppg EHW and record results. This establishes a maximum allowable drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EHW). 7. Directionally drill 6" hole to +/- 4100' HD / 3,668' '[VD. Displace well to clean DrilrN Fluid. Continue to directionally 6" hole to TD at +/- 8,100' HD / 3,746' TVD as per directional plan. 8. Circulate and condition hole to run liner. 9. Lay down HWD, LWD and PWD tools. 10. RTH with a stiff 6" hole opener - Ream entire open hole section. Hake wiper trip to window, and return to bottom, reaming any indications of tight hole. CBU. 11. Displace mud with viscosified brine. 12. Perform casing clean-up including Caustic SL Wash and pickle. 13. Run 4-1/2" x 4" Bonzai Liner with pro-packed screen (run liner with 2-7/8" inner wash string). 14. Land liner, inflate lower ECP and release liner running tool. 15. PU and inflate upper ECP. 16. PU cementing BHA, RZH and locate across cementing valve. Open cementing valve, condition the hole and pump cement job as designed. 17. PU 6" Hilled Tooth Bit and cleanout excess cement to liner top. 18. PU 3-3/4" Hill and cleanout excess cement from top 30' of liner. 19. Wash over liner top and retrieve whipstock assembly. 20. Dress off window junction with watermelon mill and reverse circulate sand / debris from top of bridge plug. RECEIVED SEP 15 2000 Alaska Oi{ & Gas Cons. Commission Anchorage Well 1D-140 L 1 Permit Package General Procedure Page 1 of 2 21. Orient and set workover whtk~,ockt~-assembly. ~ /' 22. Cleanout liner to TD. 23. Displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screen while POOH. 24. Displace the well, above the window, with clean filtered brine. 25. Retrieve workover whipstock assembly. 26. Retrieve bridge plug. 27. RZH w/ 4-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable and ;[-wire to penetrators. 28. Land tubing hanger. R[LDS, install two-way check and test tubing hanger. 29. ND/NU/'I'est. 30. Freeze proted[ with diesel to +/- 2000' TVD. RECEIVED SEP 15 2000 Alaska Oit & Gas Cons. Commiss'~ Anchorage Well 1D- 140 L 1 Permit Package General Procedure Page 2 of 2 1 D-140 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 1 Nordic Rig #3 RKB @ O' 16" Conductor @ 110' 10-3/4' 40.5# J-55 BTC @ 500' (Gravel Isolation String) Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface Window @ 3672' MD / 3552' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 4121' MD / 3734' TVD 7-5/8" 29.7# L-80 LTC Mod or BTC Mod Casing as required from TAM Port Collar to Surface. TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 600' TVD 7-5/8" 29.7# L-80 BTC Mod Casing as required from Orienting Crossover to TAM Port Collar. Sperry RMLS System 1 Pup Joint 7-5/8" 29.7# L-80 BTC Mod Casing (Length 57. I Pup Joint 7-5/8" 29.7# L-80 BTC Mod Casing (Length 5'). Sperry Orienting Crossover 7-5/8" 29.7# BTC Box x 7" 29# BTC Pin w/Internal Orienting Muleshoe. 1 Pup Joint 7" 29# L-80 BTC Mod Casing (Length 5'). I Joint 7" 29# L-80 BTC Mod Casing. Sperry RMLS Window Joint 7" 29# L-80 BTC w/Aluminum Extemal Sleeve and Latch Coupling. 7" 26# L-80 BTC Mod Casing as required from Landing Collar to Latch Coupling. Sperry Float / Landing Collar 7" 29# L-80 BTC Box x Pin. 2 Joints 7# 26# L-80 BTC Mod Casing. Sperry Float Shoe 7" 29# L-80 BTC Box Up. RECEIVED SEP 1,5 2000 Alaska ~I & Gas Cons. Commission Anchorage MAC 08/~/00 1 D-140 WeSt Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 2 Nordic Rig #3 RKB @ O' 16" Conductor @ 110' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface KOP @ 3672' MD / 3552' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 4121' MD / 3734' TVD TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 600' TVD Lower Lateral Completion (Run w/2-7/8" Hyd 511 Inner Wash Strinq) Baker SC-1R '70B-40' Single Bore - Rotationally Locked, Liner Top Packer (6.O" Max OD, 4" Min ID) w/5-1/2" HSLHT Box Down. Baker 6' Extension w/5-1/2" HSLHT Pin x Pin Crossover Sub w/5-1/2" HSLHT Box x 4-1/2" HSLHT Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" HSLHT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4-1/2" HSLHT Box x 4" HSLHT Pin. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. 4" x 4-1/2' BakenNeld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. Plan to alternate Prepack Screen and Blank Pipe throu.qh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Baker Model 'GPV' Set Shoe Assembly (5.560" Max OD). Assembly Includes Shoe, 5" Blank Pipe Above Shoe (18' Pup Joint) and Crossover Back to 4" Blank Pipe. RECEIVED Liner Top Packer Set @ +/- 3971' MD II,'- ..... '=1 TD B-Sand Lateral @ +/- 8116' MD / 3811' ']'VD SEP 15 2000 Alaska 0~I & Gas Cons. Commission Anchorage MAC 08/30/00 1D-140 L1 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion- Phase 3 Nordic Rig #3 RKB @ 0' 16" Conductor @ 110' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 600' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface Window @ 3672' MD / 3552' TVD Sand Bridge Plug Set @ +/- 3772' MD Production Casing 7" 26# L-80 BTC Mod TD to RMLS Bridge Plug 7" Casing Point @ 4121' MD / 3734' TVD RECEIV SEP 15 2000 Aias & Gas Cons. Commissior Upper Sperry Sperry 4-1/2" Baker Baker Baker Baker Baker Lateral 'Bonzai' Comp~,*"~n (Run w/2-7/8" Hyd 511 Inner Wash Strine) RMLS Transition Joint.~. (TAM) Hydraulic Release Sub. 12.6# L-80 BTC Mod Tbg as required from Indicator Sub to Hyd Release Sub. Handling Pup 4-1/2" 12.6# L-80 IBT Box x Casing BTC Pin (Length 103. Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 103. HMCV Cementing Valve 4-1/2" 12.6~ L-80 Casing BTC Box x Pin. 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (as required), 4-1/2" 12.6# L-80 IBT Box x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2' 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6~ L-80 Casing Box x Pin (Length 103. Baker CTC 7' Isozone ECP 4-1/2" 12.6# L-80 Casing BTC Box x Box (3.833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. Spacer Joints / Pup Joints (as required), 4-1/2" 12.6# L-80 IBT Box x Pin. Baker Indicator Sub (10K-15K Snap Force) 4-1/2" 12.6# L-80 Casing BTC Box x Pin. Baker Handling Pup 4-1/2" 12.6# L-80 Casing Box x Pin (Length 103. Baker CTC 20' Payzone ECP 4-1/2" 12.6# L-80 Casing BTC Box x Box (3.833 Min ID). Baker 3' Bottom Sub 4-1/2" 12.6# L-80 Casing BTC Pin x IBT Pin. 1 Joint 4-1/2" 12.6# L-80 BTC Mod Tubing. Baker Model C 'KOIV' Knock Out Isolation Valve w/3.50" ID and 4-1/2" IBT Box x Pin. I Joint 4-1/2" 12.6# L-80 BTC Mod Tubing. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" IBT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 BTC MOd Tubing. Crossover Pup, 4-1/2" IBT Box x 4" HSLHT Pin. 4" x 4-1/2" Bakerweld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from Drillable Packoff Bushing to Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/HSLHT Connections as required from Drillable Packoff Bushing to Sliding Sleeve. Plan to altemate Prepack Screen and Blank Pipe throu.qh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4" HSLHT Box x 5" HSLHT Pin I Pup Joint 5" 15# L-80 HSLHT Tubing (Length 18'). Baker Model 'GPV' Set Shoe (5.560" Max OD). TD D-Sand Lateral @ +/- 8100' MD / 3,746' TVD Liner Top Packer Set @ +/- 3971' MD -I I- ) TD B-Sand Lateral @ +/- 8116' MD / 3811' TVD MAC 08/30/00 1D-140~-'"',[' West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 4 Nordic Rig #3 RKB @ 0' 16" Conductor @ 80' 10-3/4" 40.5# J-55 BTC @ 500' (Gravel Isolation String) TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 600' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface Window @ 3672' MD / 3552' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 4-1/2" Vetco Gray Tubing Hanger w/4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down, ESP Power Cable Penetrator, Heat Trace Penetrator and TEC Wire Penetrator. 4-1/2" 12.6# L-80 NSCT Spaceout Pups as required for Heat Trace (Heat Trace Cannot Be Spliced). Raychem Heat Trace @ +/- 3,000' MD. 4-1/2" 12.6# L-80 NSCT Tubing to Surface.. 4-1/2" x 1" Camco 'KBG-2' GLM run open. After rig moves off location, the Wells Group will install a Shear Circulating Valve pinned for 3000 psi Tubing to Casing Differential. 6' handling pups installed on top and bottom of GLM. 2 Joints 4-1/2" 12.6# L-80 NSCT Tubing. 10' Spaceout Pup 4-1/2" 12.6# L-80 NSCT Tubing 10' Handling Pup 4-1/2" 12.6# L-80 NSCT Tubing Centrilift ESPCP (components as listed below): Centrilift 4-1/2" Slotted Nipple Centrilift 4-1/2" TIC Crossover Centrilift Tandem Seal Section: GST3 DB IL H6 PFS Centrilift PC Pump Assembly: R&M 375 Series 40-S-340 Single Lobe PC Pump Centrilift Gear Reduction Unit: 525 Series, 9:1 Centrilift Motor: 57 HP 1315/26 KMH Centrilift Motor Centralizer 2-7/8" Baker Sentry Gauge mounting pup joint. Pup Joint has 6-3/4" OD Centralizer Fins on bottom end TD D-Sand Lateral @ +/- 8,100' MD / 3,746' TVD 7" Casing Point @ 4121' MD / 3734' TVD Liner Top Packer Set @ +/- 3971' MD RECEIVED SEP 15 2000 Alaska Oit & Gas Cons. ~;ommission Anchorage -_B I :--:-:: TD B-Sand Lateral @ +/- 8116' MD/3,811' TVD MAC 08/30/00 IBq:3ti~li'~l~..~a-J!~ North Slope AI~'""~ Phillips Alaska Kuparuk ~O Dril[Quest* Eastings Cufl'MltWeilProl~llMO! Scale: 1 inch = 800ft ~.v~: ~o..s.s.mE 4 1/2" Liner - 8099.55 MD, 3746.00 TVD ,va E~mm: :o~.om ~ ~,~,~ L.,M Total Depth: 8099.55ffMD,3746.00ffB/D- u,~: rw End Dir, Start Sail O 90.765°: 7802.57ftMD,3749.O6ftTV - ' ~ - 4400 4400 Propom D~ to~ t ~-~40 ~.~ Wino Begin Dir @ 8.00°1100ft : 7795.18ft MD, 3750.03ff TV[ ~. a?so.a? Ne~h R~m: Tree ~ Ve~cll SOCll(Xt De~dl~km: I D- 14o wPl VlgtM 6eC~Ofl ~: O. eO N.O. eO E Rite- ..................... :: ' : ........ 3600 3600 5]ae.91 aa.~ ~57.~.~.~ .~,,~?? i?,n.2,;n ....]~,,5: [~ Begin Dir @ 8.00°ll00ff : 6639 52ff MD, 3753 81ff TVD- w,~.. ~.?~ .&?~o .~?~ .~.-n , n,xz~? .o Be n Dir @ 8.00°/100ft : 6171 96ft MD, 3748.76ft TVD End Dir, Start Sail ~ 88.348°: 5759.60ftMD,3736.81 ItTVD--'-- ' ~ a?a4.~s O Begin Dir @ 8.00°/100ft : 5668.79ft MD, 3732.11f TVD ~' Z 2000 - - 2000 ~ 3700. O0 End Dir, Start Sail @ 85.583°: 5240.54ftMD,3699.1 lftTVD"--'--~' Begin Dir ~ 8.00°1100ff : 5166.91ff MD, ~96.77' :TVD ~' ' find Dir, Start Sail ~ 88.534°: 4585.10~MD,3881.8~ ~200- B - 1200 Begin Dir @ 8.00°/100~ : 4527.6~t MD, ~80.32fl find Dir, Stall Sail ~ 88.400° .' 4150.40~MD,~69.78t F{ECEIVEDBegin Dir@ 12.50°1100ff :3993.06ftMD, 3669.2, ftTVD .-------. Dir Rate Deomase @ 13.00°/100ff : 3946.17ffMD,~667.4~ RTVD --------- 400 -~72.~tTv~ .,,oo. o0- 400 Dir Rate Inorea~e ~ 15.00°/100ft 3701 97ffMDj Alaa~ 0il & Gas Cons. Corr:mission o Anchorage Reference is True North Eastings · 00.00 OOlO0 " 0 ' ~ /Oral ueptn: I:IUt~.55TtMD,3746.00ftTVD ~ 4 1/2' Liner. 80~9.55 MD, 3746.00 TVD 400 1200 2000 2800 3600 4400 Scale: I inch = 800ff Section Azimuth: 1.109° O'rue North) ¥~rtical $~¢tion RECEIVED SEP '15 .~000 Gas Cons. C0mmi~ An~orage Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 L1 Wp l O Revised: 6 September, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3671.97 45.001 10.000 3451.09 3552.09 3700.00 48.256 11.166 3470.33 3571.33 3701.97 48.484 11.244 3471.64 3572.64 3800.00 63.135 9.703 3526.58 3627.58 3900.00 78.092 8.501 3559.68 3660.68 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) ' (ft) 342.68 N 156.24 E 5960157.89 N 560644.03 E 362.70 N 159.99 E 5960177.95 N 560647.62 E 364.14 N 160.28 E 5960179.39 N 560647.89 E 443.68 N 174.88 E 5960259.04 N 560661.85 E 536.56N 189.72 E 5960352.04 N 560675.94 E Dogleg Rate (°/100fl) 12.00 12.00 15.00 15.00 Vertical Section 345.64 365.73 367.17 446.98 540.13 Comment Begin Dir @ 12.00°/100ft : 3671.97ft MD, 3552.08ft TVD 7 5/8" X 7" Casing Dir Ratelncmase @ 15.00°/100ff : 3701.97ffMD,3572.64ffTVD 3946.17 85.000 8.000 3566.47 3667.47 3993.06 90.611 10.386 3568.26 3669.26 4000.00 90.552 9.520 3568.19 3669.19 4100.00 89.693 357.050 3567.97 3668.97 4104.41 89.655 356.500 3568.00 3669.00 4150.40 88.400 353.041 3568.78 3669.78 4200.00 88.400 353.041 3570.17 3671.17 4300.00 88.400 353.041 3572.96 3673.96 4400.00 88.400 353.041 3575.75 3676.75 4500.00 88.400 353.041 3578.54 3679.54 581.73N 196.27 E 5960397.26 N 560682.13 E 627.96 N 203.75 E 5960443.55 N 560689.24 E 634.80 N 204.95 E 5960450.40 N 560690.38 E 734.43 N 210.67 E 5960550.08 N 560695.30 E 738.84 N 210.42E 5960554.48 N 560695.01 E 784.62 N 206.23 E 5960600.22 N 560690.46 E 833.84 N 200.22 E 5960649.39 N 560684.05 E 933.06 N 188.11 E 5960748.52 N 560671.14 E 1032.29 N 176.00 E 5960847.64 N 560658.24 E 1131.51N 163.89 E 5960946.76N 560645.33 E 15.00 13.00 12.50 12.50 12.50 8.00 0.00 0.00 0.00 0.00 585.42 631.79 638.64 738.37 742.77 788.46 837.56 936.53 1035.50 1134.47 Dir Rate Decrease @ 13.00°/100ft : 3946.17ftM D,3667.47ftTVD Begin Dir @ 12.50°/100ft : 3993.06ft MD, 3669.26ft TVD End Dir, Start Sail @ 88. : 4150.40ftMD,3669.78ftTVD 4527.69 88.400 353.041 3579.32 3680.32 4552.17 88.400 355.000 3580.00 3681.00 4585.10 88.534 357.633 3580.88 3681.88 4600.00 88.534 357.633 3581.26 3682.26 4700.00 88.534 357.633 3583.82 3684.82 1158.99 N 160.54 E 5960974.21N 560641.75 E 1183.32 N 157.99 E 5960998.52 N 560639.01E 1216.17 N 155.87 E 5961031.36 N 560636.63 E 1231.05 N 155.26 E 5961046.23 N 560635.89 E 1330.93 N 151.13 E 5961146.08 N 560630.96 E 0.00 8.00 8.00 0.00 0.00 1161.88 1186.15 1218.96 1233.83 1333.61 Begin Dir @ 8.00°/100ft : 4527.69ft MD, 3680.32ft TVD End Dir, Start Sail @ 88.534° : 4585.10ftMD,3681.88ftTVD Continued... 8 September, 2000 - 9:44 - 1 - DrillQuest 2.00.04 RECEIVED SEP 15 2000 Alaska O~ & Gas Cons. Commission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Sperry-Sun Drifting Services Vertical Depth (ft) 4800.00 88.534 357.633 3586.38 3687.38 4900.00 88.534 357.633 3588.94 3689.94 5000.00 88.534 357.633 3591.50 3692.50 5100.00 88.534 357.633 3594.05 3695.05 5166.91 88.534 357.633 3595.77 3696.77 5185.25 90.000 357.563 3596.00 3697.00 5200.00 88.822 357.621 3596.15 3697.15 5240.54 85.583 357.781 3598.13 3699.13 5300.00 85.583 357.781 3602.71 3703.71 5400.00 85.583 357.781 3610.41 3711.41 5500.00 85.583 357.781 3618.11 3719.11 5600.00 85.583 357.781 3625.82 3726.82 5668.79 85.583 357.781 3631.11 3732.11 5700.00 86.573 355.484 3633.25 3734.25 5713.39 87.000 354.500 3634.00 3735.00 5759.60 88.348 357.945 3635.88 3736.88 5800.00 88.348 357.945 3637.04 3738.04 5900.00 88.348 357.945 3639.92 3740.92 6000.00 88.348 357.945 3642.81 3743.81 6100.00 88.348 357.945 3645.69 3746.69 6171.96 88.348 357.945 3647.76 3748.76 6182.19 89.000 357.450 3648.00 6192.62 89.402 356.720 3648.15 Proposal Report for 1D-140 WPs - 1D-140 L1 WplO Revised: 6 September, 2000 3749.00 3749.15 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1430.82 N 147.00 E 5961245.92 N 560626.03 E 1530.70 N 142.87 E 5961345.77 N 560621.09 E 1630.58 N 138.74 E 5961445.61N 560616.16 E 1730.46 N 134.61E 5961545.46 N 560611.23 E 1797.29 N 131.85 E 5961612.26 N 560607.93 E 6200.00 89.402 356.720 3648.22 3749.22 1815.62 N 131.08 E 5961630.58 N 560607.01 E 1830.35 N 130.46 E 5961645.31N 560606.27 E 1870.80 N 128.84 E 5961685.75 N 560604.32 E 1930.04 N 126.54 E 5961744.97 N 560601.55 E 2029.67 N 122.68 E 5961844.56 N 560596.89 E 2129.30 N 118.82 E 5961944.16 N 560592.23 E 2228.93 N 114.96 E 5962043.75 N 560587.56 E 2297.47 N 112.31E 5962112.26 N 560584.36 E 2328.54 N 110.48 E 5962143.33 N 560582.28 E 2341.86 N 109.31E 5962156.64 N 560581.00 E 2387.93 N 106.27 E 5962202.68 N 560577.59 E 2428.28 N 104.82 E 5962243.02 N 560575.82 E 2528.18 N 101.24 E 5962342.88 N 560571.43 E 2628.07 N 97.65 E 5962442.74 N 560567.04 E 2727.96 N 94.07 E 5962542.60 N 560562.66 E 2799.85 N 91.49 E 5962614.47 N 560559.50 E 2810.07 N 91.08 E 5962624.68 N 560559.00 E 2820.48 N 90.55 E 5962635.09 N 560558.39 E 2827.85 N 90.13 E 5962642.45 N 560557.91 E Dogleg Rate (°/lOOft) 0.00 0.00 0.00 0.00 0.00 8.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 8.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 8.00 8.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 1433.39 1533.18 1632.96 1732.74 1799.51 1817.81 1832.53 1872.94 1932.13 2031.67 2131.20 2230.74 2299.21 2330.24 2343.54 2389.54 2429.86 2529.66 2629.47 2729.27 2801.10 2811.31 2821.7O 2829.06 'Comment Begin Dir @ 8.00°/100ft : 5166.91ft MD, 3696.77ft TVD End Dir, Start Sail @ 85.583° : 5240.54ftMD,3699.13ftTVD Begin Dir @ 8.00°/100ft : 5668.79ft MD, 3732.1 lft TVD End Dir, Start Sail @ 88.348° : 5759.60ftMD,3736.88ftTVD Begin Dir @ 8.00°/100ft : 6171.96ft MD, 3748.76ft TVD End Dir, Start Sail @ 89.402° : 6192.62ftMD,3749.15ftTVD 8 September, 2000 - 9:44 - 2 - DrillQuest 2.00.04 RECEIVED SEP 15 2000 Alaska G~ & Gas Cons. C0mmi~n Anchorage North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (fi) (ft) 6300.00 89.402 356.720 3649.27 3750.27 6400.00 89.402 356.720 3650.31 3751.31 6500.00 89.402 356.720 3651.35 3752.35 6600.00 89.402 356.720 3652.40 3753.40 6639.52 89.402 356.720 3652.81 3753.81 6665.27 89.750 358.750 3653.00 3754.00 6695.18 90.207 6700.00 90.207 6800.00 90.207 6900.00 90.207 7000.00 90.207 7100.00 90.207 7200.00 90.207 7300.00 90.207 7400.00 90.207 7500.00 90.207 7600.00 90.207 7700.00 90.207 7795.18 90.207 7799.46 90.550 7800.00 90.587 7802.57 90.765 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.098 1.100 1.122 1.225 1.225 1.225 7900.00 90.765 8000.00 90.765 Proposal Report for 1D-140 WPs - 1D-140 L1 Wp l O Revised: 6 September, 2000 3653.01 3652.99 3652.63 3652.27 3651.91 3651.55 3651.18 3650.82 3650.46 3650.10 3649.73 3649.37 3649.03 3649.00 3648.99 3648.96 3647.66 3646.33 3754.01 3753.99 3753.63 3753.27 3752.91 3752.55 3752.18 3751.82 3751.46 3751.10 3750.73 3750.37 3750.03 3750.00 3749.99 3749.96 3748.66 3747.33 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2927.68 N 84.41 E 5962742.23 N 560551.38 E 3027.51 N 78.68 E 5962842.02 N 560544.86 E 3127.34 N 72.96 E 5962941.80 N 560538.33 E 3227.17 N 67.24 E 5963041.58 N 560531.81 E 3266.63 N 64.98 E 5963081.01 N 560529.23 E 3292.35 N 63.96 E 5963106.73 N 560528.00 E 3322.26 N 63.92 E 5963136.64 N 560527.72 E 3327.08 N 64.01 E 5963141.46 N 560527.78 E 3427.06 N 65.93 E 5963241.45 N 560528.89 E 3527.04 N 67.85 E 5963341.44 N 560530.00 E 3627.02 N 69.76 E 5963441.44 N 560531.11E 3727.00 N 71.68 E 5963541.43 N 560532.22 E 3826.98 N 73.60 E 5963641.42N 560533.34 E 3926.97 N 75.52 E 5963741.42 N 560534.45 E 4026.95 N 77.43 E 5963841.41 N 560535.56 E 4126.93 N 79.35 E 5963941.40 N 560536.67 E 4226.91 N 81.27 E 5964041.40 N 560537.79 E 4326.89 N 83.18 E 5964141.39 N 560538.90 E 4422.05 N 85.01E 5964236.56 N 560539.96 E 4426.33 N 85.09 E 5964240.85 N 560540.00 E 4426.87 N 85.10 E 5964241.38 N 560540.01 E 4429.44 N 85.15 E 5964243.95 N 560540.04 E 4526.84 N 87.24 E 5964341.36 N 560541.34 E 4626.81 N 89.37 E 5964441.35 N 560542.67 E Dogleg Rate (°/lOOft) 0.00 0.00 0.00 0.00 0.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8.00 8.00 8.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 2928.77 3028.47 3128.17 3227.87 3267.27 3292.97 3322.87 3327.70 3427.69 3527.69 3627.69 3727.69 3827.69 3927.69 4027.69 4127.69 4227.69 4327.69 4422.87 4427.15 4427.69 4430.26 4527.68 4627.67 Comment Begin Dir @ 8.00°/100ft : 6639.52ft MD, 3753.81ft TVD End Dir, Start Sail @ 90.207° : 6695.18ftMD,3754.01ftTVD Begin Dir @ 8.00°/100fi : 7795.18ft MD, 3750.03ft TVD End Dir, Start Sail @ 90.765° : 7802.57ftMD,3749.96ftTVD 8 September, 2000 - 9:44 - 3 - DrillQuest 2.00.04 RECEIVED SEP 15 2000 Alaska 0~ & Gas Cons. Commission Anchorage Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs- 1D-140 L1 WplO Revised: 6 September, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8099.55 90.765 1.225 3645.00 3746.00 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4726.32 N 91.50 E 5964540.88 N 560544.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-140 WPs. Northings and Eastings are relative to 1 D-140 WPs. Magnetic Declination at Surface is 26.534° (31-Aug-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from 1 D-140 WPs and calculated along an Azimuth of 1.109° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8099.55ft., The Bottom Hole Displacement is 4727.21ft., in the Direction of 1.109° (True). Dogleg Rate (°/lOOft) o.oo Alaska State Plane 4 Kuparuk 1D Vertical Section 4727.21 Comment .,.~.,~ Total Depth: 8099.55ftMD,3746.00ftTVD 4 1/2" Liner Continued... 8 September, 2000 - 9:44 - 4 - DrillQuest 2.00.04 RECEIVED SEP 15 2000 Alaska ~ & Gas Cons. North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 L1 WplO Revised: 6 September, 2000 Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3701.97 3946.17 3993.06 3993.06 4150.40 4527.69 4585.10 5166.91 5240.54 5668.79 5759.60 6171.96 6192.62 6639.52 6695.18 7795.18 7802.57 8099.55 3572.64 364.14 N 160.28 3667.47 581.73 N 196.27 3669.26 627.96 N 203.75 3669.26 627.96 N 203.75 3669.78 784.62 N 206.23 3680.32 1158.99 N 160.54 3681.88 1216.17 N 155.87 3696.77 1797.29 N 131.85 3699.13 1870.80 N 128.84 3732.11 2297.46 N 112.31 3736.88 2387.92N 106.27 3748.76 2799.85 N 91.49 3749.15 2820.48 N 90.55 3753.81 3266.63 N 64.98 3754.01 3322.26 N 63.92 3750.03 4422.05 N 85.01 3749.96 4429.44N 85.15 3746.00 4726.32 N 91.50 Dir Rate Increase @ 15.00°/100ft : 3701.97ftMD,3572.64ftTVD Dir Rate Decrease @ 13.00°/100ft : 3946.17ftMD,3667.47ftTVD End Dir, Start Sail @ 90.611 °: 3993.06ftMD,3669.26ftTVD Begin Dir @ 12.50°/100ft : 3993.06ft MD, 3669.26ft TVD End Dir, Start Sail @ 88.400°: 4150.40ftMD,3669.78ftTVD Begin Dir @ 8.00°/100ft : 4527.69ft MD, 3680.32ft TVD End Dir, Start Sail @ 88.534°: 4585.10ftMD,3681.88ftTVD Begin Dir @ 8.00°/100ft : 5166.91ft MD, 3696.77ftTVD End Dir, Start Sail @ 85.583°: 5240.54ftMD,3699.13ftTVD Begin Dir @ 8.00°/100ft : 5668.79ft MD, 3732.1 lft TVD End Dir, Start Sail @ 88.348°: 5759.60ffMD,3736.88ftTVD Begin Dir @ 8.00°/100ft : 6171.96ft MD, 3748.76ft TVD End Dir, Start Sail @ 89.402° :6192.62ftMD,3749.15ftTVD Begin Dir @ 8.00°/100ft : 6639.52ft MD, 3753.81ft TVD End Dir, Start Sail @ 90.207°: 6695.18ftMD,3754.01ftTVD Begin Dir @ 8.00°/100ft : 7795.18ft MD, 3750.03ft TVD End Dir, Start Sail @ 90.765°: 7802.57ftMD,3749.96ftTVD Total Depth: 8099.55ftMD,3746.00ftTVD Continued... 8 September, 2000- 9:44 - 5- DrillQuest 2.00.04 RECEIVED SEP 15 2000 Naska ~ & Gas Cons. N~chorage North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 L1 WplO Revised: 6 September, 2000 Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) <Surface> <Surface> 500.00 500.00 3653.97 3539.36 3653.97 3539.36 <Surface> <Surface> 3671.97 3552.08 <Surface> <Surface> 8099.55 3746.00 Casing Detail 10 3/4" Casing Top ML Window Joint 7 5/8" X 7" Casing 4 1/2" Liner 8 September, 2000 - 9:44 - 6 - DrillQuest 2.00.04 ( 11" 5000 psi BOP St_e : Kuparuk River Unit' West Sak Operations - Producer Wells Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi 'and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of amtic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. RECEIVED 1. 13-3/8" Landing Ring 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Pipe Rams 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines 5. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 6. 11" 5000 psi Annular Preventer SEP 15 2000 Alaska ~ & Gas Cons. C0mmi~ MAC 7/18/00 Leak Off Test Procedure West Sak 1 D-140 L1 . After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 1500 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the Leak Off Test (LOT) form (you can locate form on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. (NOTE: This step previously done during early 1 D- 140 operations) 2. After milling the window in the 7" casing, drill 20' to 50' of new hole below the casing window. . Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 11.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a Formation Integrity Test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered, Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. RECEIVED SEP 1 5 2000 Alaska ~ & Gas Cons. Commission Aflchomge MAC Page 1 09/13/00 . PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 September 14, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application. for Permit to Drill: West Sak 1 D-140 L1 Surface Location: Target Location: Bottom Hole Location: 149' FSL, 595' FEL, Sec 14, T11 N, R10E, UM 668' FSL, 406' FEL, Sec. 14, T11N, R10E, UM 406' FNL, 499' FEL, Sec. 14, T11N, R10E, UM Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well herewith applied for is a continuation of a multilateral well project (1 D-140), and is the second lateral well bore associated with that project, and is designed to penetrate and develop the production potential of the West Sak D-Sand in the vicinity of 1D Pad. The well is designated as a horizontal sidetrack producer exiting from the 7" surface casing of the 1D-140 well. A 4-1/2" x 4" Production Liner will be run and cemented and the well will be completed with 4-1/2" tubing and ESP. The well will be drilled and completed using Nordic Rig 3. 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 $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole 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) Diagrams and descriptions of the blowout prevention (BOP) equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing program is attached as per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. RECEIVED SEP 15 2000 Alaska & Gas Cons. Cornmissio Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Aisc note that Phillips Alaska does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H~S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Additionally, Phillips Alaska requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted over pressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1 D-140. This request is due to the many nearby penetrations of the West Sak formation with nearby wells. Please note that because of the large volume of regional information available in this area, Phillips considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. The following are Phillips 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 Mike Werner, Geologist (20 AAC 25.071) 265-6191 Please note that the anticipated sidetrack date for this well is October 01, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Randy Thomas at 265-6830 or James Trantham at 265-6434. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: cc: KRU 1 D-140 Well File Randy Thomas James Trantham RECEIVED SEP 15 ?.000 Naska 0~ & Gas Cons. Commission Anchorage 134 r, DOLLARS OTVALID FOR AHOUNT OVER $ 1000 WELL PERMIT CHECKLIST FIELD & POOL /./4:~'(._~ ! ~-~._~ COMPANY /Z'~c'//'t,~,5 WELL NAME iZ:>-/~/c3 L ' PROGRAM: exp INIT CLASS ---~-~ ??~/* f-.-' GEOL AREA ADMINISTRATION DATE 1. Pern~it 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 party ................... 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 ........... ENGINEERING ATE. 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 ~ 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 ................. ! devv/ redrll serv wellbore seg. ann. disposal para req UNIT# 0 / //~;~ 0 ON/OFF SHORE N N x r Y GEOLOGY 30. permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .......... )k)'.~l. Y II AP, I~R J;)AT~ . 33. Seabed condition survey (if off-shore) ....... ~ .... Y ~. ~ ff,/¢/-,.~ 34. Contact name/phone for weekly progress rep~ploratory only] Y (A) will contain waste in a suitable receiving zone; .~.../Y APPR DATE (B) will not contaminate freshwater; or cause drill, i.'fG/wast.~.,.. Y to surface; ' . / / / will not impair mechanical integrity of th~,,~ell ~is,,e{I for disposal; Y (D)(C) will not damage producing formation o~impair W~covery from a Y pool; and ./ (E) will not circumvent 20 AAC 25.252 or 20 AA~ 25.412. Y N ENGINEERING: UlClAnnular/' COMMISSION: N N N N c:~msoffice\wordianMiana\checklist (rev. 02117100) Comments/Instructions: m Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part 'of the history file, To improve the readability of the' Well History file and to simplify' finding information, information', of this nature is accumulated .at the end of the file under APPE .N. DIX~ ., 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 $ Fri Sep 21 16:00:48 2001 Reel Header Service name ............. LISTPE Date ..................... 01/09/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/09/21 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 HEADER 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 MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1D-140 L1 500292297460 PHILLIPS Alaska, Inc. Sperry Sun 21-SEP-01 MWD RUN 1 MWD RUN 5 AK-MM-00202 AK-MM-00202 A. WEAVER R. MCNEILL D. MICKEY DINK HEIM 14 llN 10E 149 595 .00 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 10.750 510.0 2ND STRING 9.875 7.875 3682.0 3RD STRING PRODUCTION STRING REMARKS: **** THIS DATA SUPERSEDES ALL PREVIOUS LDWG DATA FOR WELL 1D-140 Li**** 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGE MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. 1D-140L1 IS TIED INTO 1D-140 AT THE KICKOFF POINT (TOP OF WHIPSTOCK).. THIS WELL KICKS OFF FROM 1D140 AT 3682' MD, 3550' TVD. MWD DATA IS CONSIDERED PDC PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 11/13/00. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. MWD RUNS 1 AND 5 REPRESENT WELL 1D-140 WITH API # 50-029-22974-00. THIS WELL REACHED A TOTAL DEPTH OF 7663' MD, 3719' 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 **** THIS DATA SUPERSEDES ALL PREVIOUS LDWG DATA FOR WELL 1D-140 Li**** $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 C6mment 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 FET 502.0 7604.0 RPD 502.0 7604.0 RPM 502.0 7604.0 RPS 502.0 7604.0 RPX 502.0 7604.0 GR 502.0 7597.0 ROP 510.0 7659.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 502.0 3682.0 5 3682.5 7659.5 REMARKS: MERGED MAIN PASS. $ 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 MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 502 7659.5 ROP MWD FT/H 2.66 892.46 GR MWD API 15.85 122.05 RPX MWD OHMM 0.67 2000 RPS MWD OHMM 1 2000 RPM MWD OHMM 1.12 2000 RPD MWD OHMM 1.28 2000 FET MWD HR 0.34 8.26 First Last Mean Nsam Reading Reading 4080.75 14316 502 7659.5 123.514 14300 510 7659.5 71.5859 14191 502 7597 33.284 14205 502 7604 64.1926 14205 502 7604 68.1456 14205 502 7604 67.4814 14205 502 7604 1.10549 14205 502 7604 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 7659.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/21 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 ....... 01/09/21 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 RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 502.0 3682.0 FET 502.0 3682.0 RPD 502.0 3682.0 RPS 502.0 3682.0 GR 502.0 3682.0 RPM 502.0 3682.0 ROP 510.0 3682.0 $ 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: 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): 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): 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 26-SEP-00 Insite 4.05.5 65.41 Memory 3681.9 .1 80.7 TOOL NUMBER PB01660HWGRM6 PB01660HWGRM6 9.875 LSND 9.40 120.0 8.8 50O 4.0 2.100 1.341 1.980 3.500 72.0 116.6 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 " ' OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HR 4 1 68 2O 24 28 Name Service Unit Min Max DEPT FT 502 3682 ROP MWD010 FT/H 2.66 261.98 GR MWD010 API 15.85 115.29 RPX MWD010 OHMM 0.89 1870.36 RPS MWD010 OHMM 1 2000 RPM MWD010 OHMM 1.12 2000 RPD MWD010 OHMM 1.28 2000 FET MWD010 HR 0.4 4.57 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 3682 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/21 Maximum Physical Record..65535 File Type ................. LO Next File Name ........... STSLIB.003 Mean 2092 112.652 67.1311 25.4858 40.2421 64.6087 68.9012 0.93056 Nsam 6361 6345 6361 6361 6361 6361 6361 6361 First Reading 502 510 502 502 502 502 502 502 Last Reading 3682 3682 3682 3682 3682 3682 3682 3682 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLDB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3682.5 7604.0 RPM 3682.5 7604.0 RPS 3682.5 7604.0 RPX 3682.5 7604.0 GR 3682.5 7597.0 ROP 3682.5 7659.5 FET 3682.5 7604.0 LOG HEADER DATA DATE LOGGED: 17-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4,05.5 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7663.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM AN~LE: MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMFbA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PBO1672H4 PB01672H4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 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): 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 Water Based 9.80 58.0 9.0 110000 3.2 .060 65.0 .044 91.4 .100 65.0 .080 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 R?S MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 3682.5 7659.5 ROP MWD050 FT/H 3.34 892.46 GR MWD050 API 44.69 122.05 RPX MWD050 OHMM 0.67 2000 RPS MWD050 OHMM 1.54 2000 RPM MWD050 OHMM 4.73 2000 RPD MWD050 OHMM 4.32 2000 FET MWD050 HR 0.34 8.26 Mean 5671 132.178 75.2049 39.6079 83.615 71.0138 66.3301 1.24734 First Reading For Entire File .......... 3682.5 Last Reading For Entire File ........... 7659.5 Nsam 7955 7955 7830 7844 7844 7844 7844 7844 First Reading 3682.5 3682.5 3682.5 3682.5 3682.5 3682.5 3682.5 3682.5 Last Reading 7659.5 7659.5 7597 7604 7604 7604 7604 7604 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIBo004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/09/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/09/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File 1D140L1PBl.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jul 17 13:14:47 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER 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 MSL 0) KELLY BUSHING: 1D-140 L1 PB1 500292297470 PHILLIPS Alaska, Inc. Sperry Sun 15-JUL-01 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00202 AK-MM-00202 AK-MM-00202 A. WEAVER A. WEAVER A. WEAVER D. MICKEY D. HEIM D. HEIM 14 liN 10E 149 595 .00 Page 1 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1D140L1PBl.tapx 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 510.0 9.875 7.875 4158.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. SGRC LOGGED BEHIND CASING FROM 4099' MD, 3732' TVD TO 4158' MD, 3740' TVD. 4. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 11/13/00. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 3 REPRESENT WELL 1D-140L1PB1 WITH API % 50-029-22974-70. THIS WELL REACHED A TOTAL DEPTH OF 6156' MD, 3822' 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 ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Page 2 1D140L1PBl.tapx 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 FET 502.0 6113.0 RPD 502.0 6113.0 RPM 502.0 6113.0 RPS 502.0 6113.0 RPX 502.0 6113.0 GR 502.0 6106.0 ROP 510.0 6156.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH - BIT RUN NO MERGE TOP MERGE BASE 1 502.0 4164.5 2 4099.0 4184.5 3 4122.0 6156.5 MERGED MAIN PASS. $ 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 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 MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Page 3 First Last 1D140L1PBl.tapx Name Service Unit Min Max DEPT FT 502 6156.5 ROP MWD FT/H 2.66 466.17 GR MWD API 15.85 124.03 RPX MWD OHMM 0.09 1870.36 RPS MWD OHMM 0.1 2000 RPM MWD OHMM 0.09 2000 RPD MWD OHMM 0.51 2000 FET MWD HR 0.27 76.61 Mean Nsam Reading Reading 3329.25 11310 502 6156.5 106.922 11294 510 6156.5 70.5517 11209 502 6106 29.389 11223 502 6113 42.915 11223 502 6113 59.6373 11223 502 6113 68.5241 11223 502 6113 1.89081 11223 502 6113 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 6156.5 File Trailer Service name .......... '...STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 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 ....... 01/07/17 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 RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 502.0 4109.0 RPM 502.0 4109.0 RPS 502.0 4109.0 RPX 502.0 4109.0 GR 502.0 4098.5 FET 502.0 4109.0 ROP 510.0 4164.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 26-SEP-00 Page 4 1D140L1PBl.tapx SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 65.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4165.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 80.7 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 NUMBER PB01660HWGRM6 PB01660HWGRM6 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 9.875 4158.0 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 LSND 9.40 120.0 8.8 50O 4.0 2.100 1.341 1.980 3.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Page 5 72.0 116.6 72.0 72.0 1D140L1PBl.tapx ROP MWD010 FT/H 4 1 68 GR MWD010 AP1 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HR 4 1 68 4 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 502 4164.5 ROP MWD010 FT/H 2.66 466.17 GR MWD010 API 15.85 117.33 RPX MWD010 OHMM 0.89 1870.36 RPS MWD010 OHMM 1 2000 RPM MWD010 OHMM 1.12 2000 RPD MWD010 OHMM 1.28 2000 FET MWD010 HR 0.4 5.96 Mean Nsam 2333.25 7326 109.126 7310 69.3272 7194 24.0505 7215 37.3172 7215 58.987 7215 62.7708 7215 1.03163 7215 First Reading 502 510 502 502 502 502 502 502 Last Reading 4164.5 4164.5 4098.5 4109 4109 4109 4109 4109 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 4164.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 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 ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4099.0 STOP DEPTH 4121.5 Page 6 FET 4109.5 RPD 4109.5 RPM 4109.5 RPS 4109.5 RPX 4109.5 RO? 4165.0 $ 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: 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): 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): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 1D140L1PBl.tapx 4128.5 4128.5 4128.5 4128.5 4128.5 4184.5 Page 7 29-SEP-00 Insite 4.05.5 65.44 Memory 4185.0 80.7 80.7 TOOL NUMBER PB01667FGR4 PB01667FGR4 6.000 LSND 10.20 65.0 8.5 500 4.0 .000 .000 .000 .000 .0 .0 .0 .0 1D140L1PBl.tapx 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 DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 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 Min Max DEPT FT 4099 4184.5 ROP MWD020 FT/H 29.12 154.43 GR MWD020 API 27.66 49.21 RPX MWD020 OHMM 2.7 5.63 RPS MWD020 OHMM 4.17 9.38 RPM MWD020 OHMM 0.09 2000 RPD MWD020 OHMM 5.65 2000 FET MWD020 HR 63.19 66.62 Mean 4141.75 113.015 35.9176 3.60744 6.39282 494.825 1335.77 66.2262 Nsam 172 40 46 39 39 39 39 39 First Reading 4099 4165 4099 4109.5 4109.5 4109.5 4109.5 4109.5 Last Reading 4184.5 4184.5 4121.5 4128.5 4128.5 4128.5 4128.5 4128.5 First Reading For Entire File .......... 4099 Last Reading For Entire File' 4184.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 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 ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Page 8 1D140L1PBl.tapx Comment Record FILE HEADER FILE NUMBER: 4 RAW 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 GR 4122.0 6106.0 RPD 4129.0 6113.0 RPM 4129.0 6113.0 RPS 4129.0 6113.0 RPX 4129.0 6113.0 FET 4129.0 6113.0 ROP 4185.0 6156.5 $ 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: 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): 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: Page 9 02-OCT-00 Insite 4.05.5 65.44 Memory 6156.0 72.2 92.5 TOOL NUMBER PB01646HAGRV4 PB01646HAGRV4 6.000 LSND 10.10 53.0 8.5 120000 3.8 .060 .047 .040 .190 72.0 93.2 72.0 72.0 1D140L1PBl.tapx HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 R?D MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 4122 6156.5 ROP MWD030 FT/H 4.45 316.15 GR MWD030 API 38.26 124.03 RPX MWD030 OHMM 0.09 1819.8 RPS MWD030 OHMM 0.1 1706.58 RPM MWD030 OHMM 0.11 2000 RPD MWD030 OHMM 0.51 2000 FET MWD030 HR 0.27 76.61 Mean Nsam 5139.25 4070 102.777 3944 73.1726 3969 39.3469 3969 53.4496 3969 56.5431 3969 66.5307 3969 2.8205 3969 First Reading 4122 4185 4122 4129 4129 4129 4129 4129 Last Reading 6156.5 6156.5 6106 6113 6113 6113 6113 6113 First Reading For Entire File .......... 4122 Last Reading For Entire File ........... 6156.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Page 10 1D140L1PBl.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 11 1D140Ll.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jul 17 13:16:12 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 1D-140 L1 500292297460 PHILLIPS Alaska, Inc. Sperry Sun 17-JUL-01 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00202 AK-MM-00202 AK-MM-00202 A. WEAVER A. WEAVER A. WEAVER D. MICKEY D. HEIM D. HEIM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-00202 A. WEAVER D. HEIM 14 liN 10E Page 1 FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1D140Ll.tapx 149 595 .O0 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 510.0 9.875 7.875 4185.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. SGRC LOGGED BEHIND CASING FROM 4099' MD, 3732' TVD TO 4158' MD, 3740' TVD. 4. 1D-140L1 IS TIED INTO 1D-140L1PB1 AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM 1D140L1PB1 AT 5493' MD, 3742' TVD. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. OF 11/13/00. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 1 - 4 REPRESENT WELL 1D-140L1 WITH API ~ 50-029-22974-60. THIS WELL REACHED A TOTAL DEPTH OF 8117' MD, 3772' 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 Page 2 1D140Ll.tapx $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 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 FET 502.0 8072.5 RPD 502.0 8072.5 RPM 502.0 8072.5 R?S 502.0 8072.5 RPX 502.0 8072.5 GR 502.0 8065.5 RO? 510.0 8116.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 502.0 4164.5 2 4165.0 4184.5 3 4185.0 5493.0 4 5493.5 8116.0 MERGED MAIN PASS. $ Page 3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 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 ROP MWD FT/H 4 GR MWD API 4 RPX MWD OHMM 4 RPS MWD OHMM 4 RPM MWD OHMM 4 RPD MWD OHMM 4 FET MWD HR 4 1D140Ll.tapx 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 Name Service Unit Min Max DEPT FT 502 8116 ROP MWD FT/H 2.66 466.17 GR MWD API 15.85 117.33 RPX MWD OHMM 0.09 1870.36 RPS MWD OHMM 0.1 2000 RPM MWD OHMM 0.09 2000 RPD MWD OHMM 0.51 2000 FET MWD HR 0.27 76.61 First Mean Nsam Reading 4309 15229 502 114.352 15213 510 68.0085 15128 502 32.114 15142 502 45.9905 15142 502 58.8644 15142 502 65.6724 15142 502 1.52622 15142 502 Last Reading 8116 8116 8065.5 8072.5 8072.5 8072.5 8072.5 8072.5 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 8116 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 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 ....... 01/07/17 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 RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 502.0 STOP DEPTH 4109.0 Page 4 GR 502.0 RPS 502.0 RPM 502.0 RPD 502.0 FET 502.0 ROP 510.0 $ 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: 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): 1D140Ll.tapx 4098.5 4109.0 4109.0 4109.0 4109.0 4164.5 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): REMARKS: $ Page 5 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 26-SEP-00 Insite 4.05.5 65.41 Memory 4165.0 .1 80.7 TOOL NUMBER PB01660HWGRM6 PB01660HWGRM6 9.875 4158.0 LSND 9.40 120.0 8.8 5OO 4.0 2.100 1.341 1.980 3.500 72.0 116.6 72.0 72.0 1D140Ll.tapx 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 DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD010 FT/H 4 1 68 MWD010 API 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 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 Min Max DEPT FT 502 4164.5 RO? MWD010 FT/H 2.66 466.17 GR MWD010 API 15.85 117.33 RPX MWD010 OHMM 0.89 1870.36 RPS MWD010 OHMM 1 2000 RPM MWD010 OHMM 1.12 2000 RPD MWD010 OHMM 1.28 2000 FET MWD010 HR 0.4 5.96 Mean 2333.25 109.126 69.3272 24.0505 37.3172 58.987 62.7708 1.03163 Nsam 7326 7310 7194 7215 7215 7215 7215 7215 First Reading 502 510 502 502 502 502 502 502 Last Reading 4164.5 4164.5 4098.5 4109 4109 4109 4109 4109 First Reading For Entire File .......... 502 Last Reading For Entire File ........... 4164.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date Of Generation ....... 01/07/17 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 ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Page 6 1D140Ll.tapx Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4099.0 4121.5 RPS 4109.5 4128.5 FET 4109.5 4128.5 RPD 4109.5 4128.5 RPX 4109.5 4128.5 R?M 4109.5 4128.5 ROP 4165.0 4184.5 $ 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: 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): 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: Page 7 29-SEP-00 Insite 4.05.5 65.44 Memory 4185.0 80.7 80.7 TOOL NUMBER PB01667 FGR4 PB01667 FGR4 6.000 BARADRI L-N 10.20 65.0 8.5 500 4.0 .000 .000 .000 .000 .0 .0 .0 .0 1D140Ll.tapx HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 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 Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 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 Mean Nsam 4099 4184.5 4141.75 172 29.12 154.43 113.015 40 27.66 49.21 35.9176 46 2.7 5.63 3.60744 39 4.17 9.38 6.39282 39 0.09 2000 494.825 39 5.65 2000 1335.77 39 63.19 66.62 66.2262 39 First Reading 4099 4165 4099 4109.5 4109.5 4109.5 4109.5 4109.5 Last Reading 4184 5 4184 5 4121 5 4128 5 4128 5 4128 5 4128 5 4128 5 First Reading For Entire File .......... 4099 Last Reading For Entire File ........... 418.4.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Page 8 1D140Ll.tapx Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW 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 GR 4122.0 5493.0 FET 4129.0 5493,0 RPX 4129.0 5493.0 RPS 4129.0 5493.0 RPD 4129.0 5493.0 RPM 4129.0 5493.0 ROP 4185.0 5493.0 $ 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: 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: Page 9 02-OCT-00 Insite 4.05.5 65.44 Memory 5493.0 84.6 92.4 TOOL NUMBER PB01646HAGRV4 .PB01646HAGRV4 6.000 BARADRIL-N 10.10 53.0 8.5 1D140Ll.tapx 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): 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 120000 3.8 .060 .047 .040 .190 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 72.0 93.2 72.0 72.0 Name Service Unit Min Max DEPT FT 4122 5493 ROP MWD030 FT/H 6.08 316.15 GR MWD030 API 38.26 90.84 RPX MWD030 OHMM 0.09 1819.8 RPS MWD030 OHMM 0.1 1706.58 RPM MWD030 OHMM 0.11 2000 RPD MWD030 OHMM 0.51 2000 FET MWD030 HR 0.27 76.61 . Mean Nsam 4807.5 2743 119.572 2617 66.2323 2743 46.0679 2729 62.78 2729 66.7941 2729 81.3677 2729 3.01897 2729 First Reading 4122 4185 4122 4129 4129 4129 4129 4129 Last Reading 5493 5493 5493 5493 5493 5493 5493 5493 First Reading For Entire File .......... 4122 Last Reading For Entire File ........... 5493 Page 10 1D140Ll.tapx File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum ?hysical Record..65535 File Type ................ LO Previous ~ile Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW 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 RPD 5493.5 8072.5 RPM 5493.5 8072.5 RPS 5493.5 8072.5 RPX 5493.5 8072.5 GR 5493.5 8065.5 ROP 5493.5 8116.0 FET 5493.5 8072.5 $ 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 Page 11 '04-OCT-00 Insite 4.05.5 65.44 Memory 8117.0 79.8 92.2 TOOL NUMBER PB01646HAGRV4 PB01646HAGRV4 1D140Ll.tapx 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): 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 6.000 BARADRI L-N 9.90 52.0 8.5 70000 3.4 .O6O .047 .040 .190 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 72.0 93.2 72.0 72.0 Name Service Unit Min Max Mean Nsam DEPT FT 5493.5 8116 6804.75 5246 ROP MWD040 FT/H 4.07 245.24 119.042 5246 GR MWD040 A?I 41.48 106.74 67.3987 5145 Page 12 First Reading 5493.5 5493.5 5493.5 Last Reading 8116 8116 8065.5 1D140Ll.tapx RPX MWD040 OHMM 4.25 1777.33 36.2253 RPS MWD040 OHMM 7.7 2000 49.5385 RPM MWD040 OHMM 10.49 2000 51.2026 RPD MWD040 OHMM 12.02 2000 51.8266 FET MWD040 HR 0.33 10.04 0.939201 5159 5493.5 8072.5 5159 5493.5 8072.5 5159 5493.5 8072.5 5159 5493.5 8072.5 5159 5493.5 8072.5 First Reading For Entire File .......... 5493.5 Last Reading For Entire File ........... 8116 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LIST?E Date ..................... 01/07/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/07/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 13