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Home My WebLink About200-136 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. ~ /31, Well History 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 # Yes No Yes No Yes No Mud Logs # - Other # 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 • $LA-SSA OIL .~11TD Cz~S COI~TSERQATI011T COMIrIISSIOI~T /3~ SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brett Packer Wells Group Engineer ,, ~~~~ ~ ~ t,`: ~ ~ ~~ ConocoPhillips Alaska, Inc. `~"~" PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1 D-140 Sundry Number: 308-374 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, Daniel T. Seamount, Jr. Chair S DATED this day of October, 2008 Encl. ,~,1~~ ~ • ~0 ~I/' STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~111 ~, APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^/ Perforate ^ Waiver ^ 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 Q Exploratory ^ 200-136 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22974-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ ~ 1D-140 p.ef7 9. Property Designation: ~, 10. KB Elevation (ft): 11. Field/Pool(s): ~ y ADL 25650, 2 /p~ RKB 30' Kuparuk River Field /West Sak Oii Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8117' . 3772' 8117' 3772' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 110' 110' KF SURFACE 480' 10-3/4" 510' 510' - ~~ PRODUCTION 4128' 7-5/8" x 7" 4158' 3740' PRODUCTION 8087' 4.5" x 4" 8117' 3772' ~ ' 8S ~~OS° OfSitiliSSlA31 A L, Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4109'-8117' perfs thru screens 3733'-3772' 4-1/2" L-80 2356' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal O 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 15, 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 Signature ~ ~~~+ ~~ Phone 265-6845 Date /~~~ ~~~ Commission Use Onl Sundry Number i Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: 4~~ ~ ~Sv~~ d ~~.,~~~~ ~~ Subsequent Form Required: l.~ ~ ~ w ~ p ~~ ~~ APPROVED BY lG1I 2 Approved by: COMMISSIONER,t THE COMMISSION Date:+ Form 10-403 Revised 06/2006 ~.~ ~ ,_,y j i ~ ~ ~ ~ ~ ~ ~~`~ ~ ~ ~~0~ Submit in Dupli ate M..ZA . ~ ~ ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 16, 2008 Commissioner State of Alaska ~?'~~ f v ~ ~ ,. `~ i ~~- Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to temporarily suspend the West Sak Well 1 D-140 (PTD# 200-136). Producing well 1 D-140 was originally completed in Oct. 2000 as a dual lateral (B&D sand) 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 suspend the well for further evaluation as a possible sidetrack candidate. ~ ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 We ran a 4'/z" 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 I hereby r 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 Daily Operations Summary Report 1 D-140 Job: RECOMPLETION Start Date End Date Z Last 24hr Sum 10/7/2008 10/8/2008 Installed BPV in 1 D-121, RDMO well, reconfigured 11" BOP stack, CO ESP spools, moved rig and spotted over 1 D-140. 10/8/2008 ' 10/9/2008 RU Swaco filtration unit, filter kill wt fluid, pumped 180 bbls KWF and bullheaded 50 bbls, shut in and monitored well 10/9/2008 10/10/2008 Kill well, empty pits, ND tree, NU 11" BOP, test BOPE, RU and pull hanger, clean ESP completion equipment with , hot KWF, decomplete well. 10/10/2008 10(11/2008 Decompleted well, RIH and obtained a good casing test at 2,500 psi, POOH, PU milling BHA, RIH and start burning over junction at "D" sand window. 10/11/2008 10/12/2008 Cont burning overjunction at "D" sand window to 3,565', POOH for smaller OD mill, left 8' mill and washpipe assembly down hole, RIH with milling BHA and dress fish, POOH and change to 4 5/16" spear assembly, RIH and attempted to engage fish. 10!12!2008 10/13/2008 POOH and MU 4.32" spear assembly, RIH attempted to engage fish, POOH and change over to 4 1/4" milling assembly, RIH and milled with no gain in depth, POOH CO BHA to 5.101" grapple on spear, RIH and attempted to engage fish with no success, POOH for BHA change. 10/13/2008 10/14/2008 Mill on fish with 4 3/4" bladed junk mill, POOH and CO BHA to 6" burn shoe with reverse basket, RIH and milled to 3,654', POOH cleaned reverse basket, added 2 boot baskets and RIH with 6" burn shoe, washed down and milled from 3,651' to 3,654'. 10/14/2008 10/15/2008 POOH clean reverse basket, RIH with 6" burnshoe and milled with no success, POOH - LD BHA, RIH open 'ended, CBU and ran Haliburton camera on e-line to 3,654'. 10/15/2008 10/16/2008 POOH LD 3 1/2" DP, RIH with 4 1/2" kill string, POOH LD 4 1/2" tbg, MU and land hanger, set TWC, ND 11" BOP. 10/16/2008 10/17/2008 NU tree and test, pull TWC, RU and freeze protect well, RDMO well, remove 11 BOP for rig move, start rig move ,from 1 D pad to 2A pad. Page 1/1 Report Printed: 10/16/20081 -- f ~~ • Daily Project Report 1 D-140 Security Level: ~ ~ . ~ "' Report Number: 1 Report Date: 10/7/2008 API I UWI Well Type ,Field Name 5002922974 Development I WEST SAK Primary Job Type Actual Start Date End Date RECOMPLETION 10/7/2008 10/16/2008 10230597 _ i 1,400,000.00 Dail O erations Last 24hr Summary Daily Cost Total Installed BPV in 1D-121, RDMO well, reconfigured 11" BOP stack, CO ESP spools, moved rig and spotted over 1D-140. 69,419.69 24hr Forecast Cumulative Cost RU Swaco filtration unit, load pits sea-water to clean completion stri and kill well, ND tree, NU 11"BOP and test same, unseat hanger and pump hot ~ ng, swap to kill wt fluid, decomplete well. 69,419.69 Time Log ,~~, r~,~ ~: ~ ~ ~_ ~„ of ~~-,~i~ , 15:;10 1 [i:3U 1.00 Jack up and move rig off well 1 D-1 ~ 1. 16:30 22:00 5.50 Standby on pad and reconfigure 11" BOP stack, remove lower single gate and install lower double gate, CO upper pipe rams on lower double gate to 2 3/8" and lower pipe rams to 2 7/8" x 5" VBR's. 22:00 23:30 1.50 i Move rig over well 1 D-140, spot and level same. 23:30 00:00 0.501 Install Handy-Berm around cellar, RU containment for cuttings box. f Accept Nordic Rig 3 at 23:30 on 10/07/2008 Responsible Daily Contacts Nezaticky, Peter - CPAI, Wells Su .r~~~~.,~~~ pervisor WO Rance Pederson, Rig Supervisor !Randy Dexter, Rig Supervisor ;Head Count /Man Hours i Nordic Calista Services ~~ 22 I,Chulista Camp Services 3 ~ConocoPhillips Company 2 jMl Swaco 2 ! ii Nordic Calista Services 1 I 1 ~Safety Check Summary ---- - --------------------- L.~_i D:-~~< Type 'i Camp Fire and Evac Drill Camp Fire Drill I, Kick While Drilling Kick While Tripping 10/7/2008 Well Kill Drill Security Level: ~ ~ Daily Project Report 1 D-140 Report Number: 2 __ Report Date: 10/8/2008 API / UWi Well Type Field Name I 5002922974 Primary Job Type Development 1 WEST SAK ~ Actual Start Date End Date RECOMPLETION 10/7/2008 i 10/16/2008 10230597 ~ __ 1,400,000.00 Daily Operations __ Last 24hr Summary _______ _ Daily Cost Total RU Swaco filtration unit, filter kill wt fluid, pumped 180 bbls KWF and bullheaded 50 bbls, shut in and monitored well. 92,201.88 24hr Forecast _ Cumulative Cost Kill well, empty pits, ND tree, NU 11" BOP, test BOPE, RU and pull hanger, clean ESP completion equipment with hot 161,621.57 KWF, decomplete well. Time Log _--_ --- -- ~r~r. i ~~,~~ E~ ; o~~,~ n ~ ~ ~~~ _ of UU:OU ~ U1:3U 1.50 PU Vetco lubricator and pull BPV, SITE= 500 psi, IA= 500 psi, OA= u psi. 01:30 ~ 07:30 6.00 RU cuttings box in containment, Swaco filter van in containment, RU kill tank in containment and MU hardlines, ~ shuffle 3 1/2" DP in derrick. 07:30 ' 13:30 6.00 RU Mf fitter unit, 2 upright tanks, and jumper hoses, test filter equipment and hard lines. 13:30 18:30 ~ 5.00 Filtering 9.6 NaCI brine with 6% KCI. 18:30 20:00 i 1.50 Pump 9.6 ppg KWF at 5 bpm, 450 psi, total of 180 bbls, TP and IA at 0 psi. Attempted to bullhead 50 bbls and obtained 970 psi on well, shut down pump and pressure dropped to 0 psi, bullheaded 50 bbls at 2 bpm, ICP at 220 psi I - FCP at 830 psi and shut in well. 20:00 22:00 j 2.00 Cont filter 9.6 brine while monitoring well. SITP and SICP at 580 psi, 22:00 23:00 1.00 Pump 150 bbls 9.6 ppg KWF at 3 bpm, 200 psi taking clean returns to pits with good amount of oil at bottoms up (1605 stks) and diverted returns to kill tank, shut down pump, shut in well at 2500 stks (surf to surf). 23:00 00:00 1_00 Monitor well while filtering 9.6 KWF, SITP at 340 psi, SICP at 340 psi. Both bled down to 300 psi while monitoring. Responsible Daily Contacts _ __ __ _ -_ ~ Nezaticky, Peter - CPAI, Wells Supe rvisor WO , Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor Head Count /Man Hours ~.~~,~„r~~r: ~ ~,~~it_. idordic i:;alista Services Chulista Camp Services 22 3 ConocoPhillips Company 2 MI Swaco 2 Nordic Calista Services 1 1 Safety Check Summary _ a,~ ~,~~~ i,~.,:~ Camp Fire and Evac Drill ~ Camp Fire Drill 10/8/2008 Kick While Drilling Kick While Tripping 10/7/2008 'Well Kill Drill Page 1/1 Report Printed: 10/20/2008!. ~_ Daily Project Report Security Level: 1 D-140 Report Number: 3 Report Date: 10/9/2008 API f UWI Well Type Field Name 5002922974 Development WEST SAK Primary Job Type Actual Start Date End Date RECOMPLETION 10/7/2008 , 10/16/2008 ve~,:~~,w~i~i ~ r=:,~r~ ~.F~ s.:~ 10230597 1,400,000.00 Dail Operations _ Last 24hr Summary __ __ _ Daily Cost Total Kill well, empty pits, ND tree, NU 11" BOP, test BOPE, RU and pull hanger, clean ESP completion equipment with hot 87,766.08 KWF, decomplete well. 24hr Forecast Cumulative Cost RIH and test casing at 2,500 psi, POOH, PU milling BHA, RIH and burn over junction at "D" sand window, POOH. - 249,387.65 Time Log --- _ _ ~r r , , --a n~,". ~~ ~ uF ~~ l)U:UU UU:3U U.5U i Cont monitor well, SITP at 300 psi, SICP at 300 psi. 00:30 02:00 1.50 Pumped 150 bbls 9.6 KWF at 3 bpm, 350 psi taking clean returns to pits, bullheaded 50 bbls KWF at 2 bpm, 980 psi and shut down pump. 02:00 04:00 2.00 Cont monitor well with initial SITP and SICP at 890 psi and bled itself off to 0 psi in 30 min. Monitored well another 30 ~ min and pressure increased to 110 psi on both tbg and IA, bled 5 gallons fluid off at choke and dropped pressure to 0 j psi, cunt monitor well for 15 min. Well is dead. j 04:00 05:00 ~ 1.00 Blow down circ lines and install BPV. ~ 05:00 10:30 i 5.50 ND tree & NU BOPE 10:30 , 15:00 ~ 4.50 Test BOPE 250/3000 psi, annulus 250/2500 psi. Test annular with 2-3/8", 3-1/2" and 4-1/2". Tested bottom rams '; with variables with 3-1/2"and 4-1/2". 15:00 i 16:30 1.50 Pull test dart and BPV. Install Isolation sleeve and screw in landing joint. BOLDS. Un-land hanger with 140K#, PUH 5', close annular and prepare to rev circ. 16:30 ~ 18:30 2.00 Rev circ 210 bbl of hot 9.6 brine to clean tubulars prior to pulling completion, check for flow, well flowing, hot brine had, '. I a reduced wt of 9.4 ppg, cbu cold 9.6 at 5 bpm - 180 psi, shut down and check for flow, no flow. 18:30 ~ 19:00 0.50 Pull hanger to floor at 90K up wt, remove esp cable from penetrator, RU Centrilift tools and equipment. 19:00 ~ 23:00 4.00 Had flow up the tubing string, RU and pumped surface to surface 150 bbls 9.6 brine at 5 bpm - 180 psi, shut down and checked for flow,well still flowing, weighted up 300 bbls to 9.7+ and circ surface to surface 150 bbls at 5 bpm - ~ 100 psi - 2,500 stks, shut down and checked for flow, well still flowing, weighted up 300 bbls to 9.9 ppg with salt, j pumped 150 bbls at 5 bpm - 100 psi - 2,500 stks, shut down and check for flow, 23:00 ~ 00:00 1.001 No flow from well, blow down top drive, POOH slow standing back 4 1/2" tbg and spooling esp cable from 3,527' to 3,447. Responsible Daily Contacts ~ r Nezaticky, Peter - CPAI, Wells Supervisor WO Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor Head Count /Man Hours _ __ __ __ _ Company ~.,~-~a Nordic Calista Services 22 Chulista Camp Services 3 ConocoPhillips Company 2 MI Swaco 2 Nordic Calista Services 1 1 Safety Check Summary o:~. 1 ufyfzuui3 10/8/2008 10/9/2008 CCamp Fire and Evac Drill Kamp Fire Drill '!Kick While Drilling Kick While Tripping Well Kill Drill r; , , Page 1/1 Report Printed: 10/20/2008 I--___ I ~~^1,~ r~ Daily Project Report Security Level: 1 D-140 Report Number: 4 i Report Date: 1 0/1 0/2008 1 API I UWI Well Type Field Name 15002922974 r- - Development WEST SAK ~ - i Primary Job Type -- Actual Start Date End Date RECOMPLETION 10!7/2008 ~ 10/16/2008 ~~r~,::or~:,iu~ 1 ~:r:.=F_~s~,:~ 10230597 ~ 1,400,000.00 Dail O erations _ Last 24hr Summary __ Daily Cost Total Decompleted well, RIH and obtained a good casing test at 2,500 psi, POOH, PU milling BHA, RIH and start burning over 105,795.58 junction at "D" sand window. 24hr Forecast i Cumulative Cost Cont burning overjunction at "D" sand window, wash down to the Baker SC-1 R packer at 4,020', POOH PU BHA # and 355,183.23 RIH cleaning out B lateral from 4,020' to 8,117'. Time Log _ _ _ , ~ ~ .. ~e,~~:.. - I ~. ~~r, _~ur . firs Operation -- 00:00 04:30 I - _ _ -- ~t.5u Gont POOH stand back 4 1/2" tbg and spooling esp cable, dis-assemble pump assembly and LD same. 04:30 06:30 i 2.00 LD ESP completion. 06:30 08:00 1.50 C/O floor, clean and crown, set wear ring. 08:00 ;10:30 2.50 PJSM. P/U M/U RBP and test packer. RIH to 3475', up wt = 79K, down wt = 74K. 10:30 ~ 12:30 2.00 RIH to 3485' sat 10K#, PUH and repeat. PUH to 30'. Close annular, bullhead 30 bbl of 9. 9 brine down the IA to clean casing. Pressure increased to -1100 psi before breaking back to 400 psi pump pressure. Pressure gradually increased to 790 psi while bulheading. Started to bleed pressure off slowly after pumping. 12:30 14:00 1.50 Circulate hole volume, 150 bbl. Pressure = 0 psi. Monitor well with no pressure increase. 114:00 17:00 ~ 3.00 Open annular and RIH to 3570' with the RBP and packer. Set RBP at 3570' and release. PUH 30' and pressure casing down to the top of the RBP to 2500 psi, did not set packer. Retreive RBP. 17:00 20:30 3.50 POOH with RBP and packer, standing back DP, LD RBP and test packer. 20:30 23:30 3.00 PU and MU BHA #1 (rotary shoe), RIH with 4 3/4" DC's and 3 1/2" DP to 3,594' and tagged fill, washed down to 3,652' and tag hard (30' high), up wt 85K, dwn wt 70K, rot wt 80K. 23:30 00:00 0.50 Start milling on metal at 3,652', on bottom rot torque at 2,000 ft/Ibs, 68 rpms, 86 spm at 1,1 20 psi with 9.9 ppg brine. Responsible Daily Contacts . iJezaticky, Peter - GPHi, bUells Sup Rance Pederson, Rig Supervisor ,:, :~;, ervisor QUO Randy Dexter, Rig Supervisor --- ------ -- - ----------------------- . Head Count /Man Hours , . ~ Nordic Gahsta Services F , ,~~i ;; 22 Chulista Camp Services 3~ ConocoPhillips Company 2 i MI Swaco 2 ~ Nordic Calista Services 1 ~-- ----- - _ _ - _ -- - -- 1 ramp Fire and Evac Drill (Camp Fire Drill ~I Kick While Drilling ~! Kick While Tripping I Well Kill Drill Page 1!1 Report Printed: 10/20/2008 (Safety Check Summary Last Date r '-- -- I Daily Project Report Security Level: 1 D-140 'i Report Number: 5 ~ ~ Report Date: 10/11/2008] API / UWI - Well Type Field Name 5002922974 ~ Development ~ WEST SAK Primary Job Type - Actual Start Date End Date RECOMPLETION ~ 10/7/2008 10/16/2008 ,, r~r ..-tide . ~ ~:~i~,~ ~ ~ F~s~ ~:, 10230597 -- ___ - ___ 1,400,000.00 - ~- Dail / O erations ___ ___ _ Last 24hr Summary Daily Cost Total Cont burning over junction at "D" sand window to 3,565', POOH for smaller OD mill, left 8' mill and washpipe assembly 93,654.89 down hole, RIH with milling BHA a nd dress fish, POOH and change to 4 5/16" spear assembly, RIH and attempted to engage fish. _~ 24hr Forecast Cumulative Cost POOH and MU 4.32" spear assembly, RIH engage fish, POOH and change over to milling assembly, RIH cont milling "D" 448,838.12 window junction. ,Time log er.7 ~.e E-d Tcr~ ~~ ~7F ~r~,ir•~~ OO:Uu ub:,iu 5.5u 3,053' Iv 3,bb2', on bottom rot torque at 2 to 4,000 fUlbs, tits rpms, un spm at 1, Izu psi wdh 9.b ppg bane. 05:30 06:00 0.50 Pick up off bottom and CBU at 5 bpm. 06:00 08:30 2.50 POOH with 6" milling assembly for mill change. 08:30 09:00 0.50 BHA at surface, it was observed that the bottom 8.57', which was the mill, junk catcher subs and 2.49' of 5-3/4" wash ~ pipe had parted at the connection and remained downhole @ - 3662 feet. 09:00 14:30 ~ 5.50 Remaining wash pipe and VACS tool full of fill and holding trapped pressure. Circulating sub on VACS tool was removed from the top of the wash pipe. Once the circulating sub was removed, the wash pipe was run back in hole and the BHA was rattled and jarred several times until circulation down the drill pipe and through the wash pipe was established. LD BHA # 1. ~ 14:30 18:30 4.00 PU and MU BHA #2, CO ESP spoof on rig Floor, RIH to 3,499', up wt 85K, down wt 80K, rot wt 80K, wash down from 3,499' to 3,652' at 30 rpm, 5 bpm at 500 psi and tagged fill at 3,600', cleaned out hole and inside fish to 3,665'. 18:30 19:30 1.00 ~ CBU at 6 bpm - 700 psi, check for flow, blow down top drive. 19:30 21:00 1.50! POOH from 3,652' and LD BHA #2. 21:00 ; 23:00 2.00 MU BHA #3 (5.313" spear assembly) and RIH to 3,499', wash down to 3,654 and attempt to engage fish with no ~ success. Spear showed signs of entering fish but grapple not engaging -indicating washpipe section is split and flared out. 23:00 00:00 1.00 CBU at 5 bpm - 580 psi, make arrangements for a smaller od spear to be delivered to engage the 5 3/4" bushing junk - ~ catcher sub. Responsible Daily Contacts ~ Nezaticky, Peter - CPAI, Wells Supervisor WO Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor -- --- --- -- ---- I Head Count I Man Hours Nordic Calista Services _., ~ , . , ~l Chulista Camp Services 3 ConocoPhillips Company 2 MISwaco 3 ~~ Nordic Calista Services 1 1' j Baker Oil Tools ~ 2 Safety Check Summary ', 10/yiZOUtt !Camp Fire and Evac Drill LCamp Fire Drill 110/10/2008 !Kick While Drilling '~ 10/11/2008 ,Kick While Tripping 110/9/2008 ~ Well Kill Drill Page 1/1 Report Printed: 10/20/2008 Security Leyel: ~,'~ ` Daily Project Report 1 D-140 Report Number: 6 Report Date: 10/12/2008. API i UWI 5002922974 Well Type Field Name Development WEST SAK Primary Job Type iActual Start Date End Date RECOMPLETION I 10/7/2008 10/16/2008 r~~:r::~-,ter,, ~ i ~~,,~ a~E ~s~~F~ 10230597 ---- - - 1,400,000.00 -- jDailyO~erations __ _ _ _ __ Last 24hr Summary _ ____ _ Daily Cost Total POOH and MU 4.32" spear assembly, RIH attempted to engage fish, POOH and change over to 4 1/4" milling assembly, RIH and milled with no gain in depth, POOH CO BHA to 5.101" grapple on spear, RIH and attempted to engage fish with no 72,339.05 success, POOH for BHA change. 24hr Forecast Cumulative Cost Mill on fish with 4 3/4" bladed junk mill, POOH and CO BHA to spear and grapple, RIH and attempt to engage fish, possibly 521,177.17 ,POOH and run down hole camera. !Time Log 00:00 i ~ OOaU uau Gont G6U at 5 bpm - 58v psi. 00:30 ' 02:30 2.00 POOH from 3,650' and LD BHA #3. 02:30 03:00 0.50 Clean and clear rig floor, service top drive and blocks. 03:00 04:30 1.50. MU BHA #4 with 4.32" grapple and washing down from 3499', RIH to 3,654'. ~ 04:30 05:00 0.50 Attempt to latch into fish with grapple. Seeing some overpull, but no indication the fish was latched. ,05:00 06:30 ~ 1.50 Circulate well @ 5 bpm at 580 psi. 106:30 i 08:00 ~ 1.50 POOH with fishing BHA. Up wt = 85K#, down wt = 80K#. 108:00 i 09:00 1.00 LD fishing BHA w/ 4.32" grapple. PU and MU 4-3/16" bladed junk mill. 09:00 ~ 12:00 3.00 RIH with milling BHA to 3604'. Wash down from 3604' to 3652', 5 bpm @ 580 psi, up wt = 85K down wt = 80K. 12:00 18:00 6.00 Start milling, WOB 4-12K, rpm's 20-70, torque 1850-2700 fUlbs, 1-5 bpm @ 60-610 psi. 18:00 19:30 1.50 POOH and LD BHA # 5. 19:30 21:30 2.00 Load BHA # 6 (spear with 5.101" grapple), PU and MU same, RIH to 3,499'. 21:30 ~I 22:30 1.00 Wash down to 3,654' and attempt to engage fish with no success. 22:30 j 00:00 1.50 j POOH for BHA change. Resaonsible Dailv Contacts -~ Nezaticky, Feter - CPHI, Wells Supervsor VVu Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor Head Count /Man Hours j Nordic CaUsta Services Chulista Camp Services jConocoPhillips Company MI Swaco Nordic Calista Services Baker Oil Tools - --- - 'Safety Check Summary 110/9/2008 ~ ~ ~~~ 1,10/10/2008 'I 10/11/2008 10/9/2008 ,Camp Flre and Evac Dnil (Camp Fire Drill Kick While Drilling Kick While Tripping Well Kill Drill Page 1/1 LL 3 2, 3 1 11 Report Printed: 10/20/2008 • ~~ i Security Level: Daily Project Report 1 D-140 ~ Report Number: 7 - Report Date: 10/13/2008 j - - API / UWI -_ Well Type Field Name 5002922974 __ _ _ Development ,WEST SAK Primary Job Type Actual Start Date End Date RECOMPLETION 10!7/2008 10/16/2008 rrl,.-~-~.~io ~ i,:c~i:v :_.~_,~~,~ 10230597 1,400,000.00 , Daily Operations _ _ Last 24hr Summary Mill on fish with 4 3/4" bladed junk ___ _ _ _ mill, POOH and CO BHA to 6" burn shoe with reverse basket, RIH and milled to 3,654', ___ Daily Cost Total 114,648.05 POOH cleaned reverse basket, added 2 boot baskets and RIH with 6" burn shoe, washed down and milled from 3,651' to 3,654'. - - - 24hrForecast -- ------------------------ ---- Cumulative Cost POOH clean reverse basket, RIH with 6"junk mill to dress top of fish, POOH CO mill to 4 3/16" junk mill, RIH and mill 635,825.22 down through catcher subs. Time Log ~; r ~~ ,~ n,~ ~, - .. IUU:UU 01:30 1.50 Slip and cut drill line. i 01:30 02:00 0.50 MU BHA # 7 (4 3/4" bladed mill). 02:00 03:00 1.00 RIH to 3,654'. 03:00 07:00 4.00 Milling on fish. Could not work past 3,654', sitting down 10K with little/no increase in torque. 07:00 09:00 2.00 POOH standing back DP ~ DCs. LD BHA # 7. 09:00 12:00 ~ 3.00 LD milling tools, mill showed only minor wear. Clean floor, bring in tools, MU milling BHA # 8 (6" burn shoe with reverse junk basket). 12:00 j 13:30 1.50 RIH to 3,600', up wt = 85K down wt = 80K, circulating 5 bpm @ 710 psi, 50 rpm @ 1,600, cont wash down to 3,634', , increase pump rate to 10.5 bpm @ 3,000 psi. RIH with 5' increments, tag @ 3,652'. 13:30 16:30 3.00 Mill from 3,652' to 3,654'. 16:30 20:00 3.50 Pull up mill and junk basket, 25K overpull coming off bottom. Pulling 5K to 8K heavy while pulling up through 7" 20:00 20:30 0.50 section. POOH to check mill and reverse basket. Had only a handful! of small metal pieces in basket. MU BHA # 9 (6" burn shoe, reverse basket and 2 boot baskets). 20:30 00:00 ~ 3.50 RIH to 3,515', wash down to 3,551' at 10 bpm - 2,850 psi at 50 rpm's and start milling from 3,651' to 3,654', up wt 85K, down wt 80K, rot wt 84K. Responsible Daily Contacts --- __._ _ Superv~:.,:,~ ~.... Nezaticky, Feter - CPHi, vVells ~upernsor VVU Rance Pederson, Rig Supervisor i Randy Dexter, Rig Supervisor ~ Head Count /Man Hours --- - _ ,. , r . ~ ~, Nordic Callsta services , ; ~ ,;~,~ ~.,~ ~~ ~ ~L Chulista Camp Services 3 ConocoPhillips Company 2 MI Swaco 3' Nordic Calista Services 1 1 Baker Oil Tools 2 Safety Check Summary i 10/9/2008 Camp Fire and Evac Drill Camp Fire Drill 10/10/2008 Kick While Drilling .10/11/2008 Kick While Tripping 10/9/2008 I Well Kill Drill _ __ Page 1/1 Report Printed: 10/20/20081 ~_ _ ~ -~" '~-- Security Level: ~ ~ Daily Project Report ~ 1 D-140 ~ < , ,...~ _ Report Number: 8 Report Date: 10/14/2008 API / UWI j Well Type ,Field Name i 5002922974 Development WEST SAK Primary Job Type Actual Start Date End Date RECOMPLETION 10/7/2008 i 10/16/2008 ~,~r,:,,~i.~i^ ;~ Tata~~ ;~ia~s.u 10230597 _ 1,40U,OOQ00 Dail O erations Last 24hr Summary Daily Cost Total POOH clean reverse basket, RIH with 6" burnshoe and milled with no success, POOH - LD BHA, RIH open ended, CBU 75,497.90 and ran Haliburton camera on a-li ne to 3,654'. 24hr Forecast Cumulative Cost POOH LD 3 112" DP, RIH with 4 1 Rig 3. /2" kill string, freeze protect well, ND 11" BOP, NU tree and secure well. RDMO Nordic 711,323.12 Time Log c~~;r-~-~ ~ - r~~,.. ~ ~ or,r.. ~~ uu:uu u3:3u 3.50 Cont burning over fish from s,ti54' with no progress. 03:30 04:00 0.50 Increase pump rate to 10 bpm and reciprocate string, shut down pumps, blow down top drive, check for flow. , 04:00 07:00 3.00 POOH to check burn shoe and reverse basket. LD burnshoe, clean out boot baskets and finger baskets, recovered a good amount of metal. 07:00 07:30 I 0.50 MU BHA # 10 (new 6" burn shoe, reverse basket and 2 boot baskets) 07:30 08:30 j 1.00 RIH to 3,513', wash down @ 10 BPM, 3,200 psi, Up wt =85K, Dn wt = 80K ,tagged at 3,651'. 08:30 14:00 5.50 Mill from 3,651' to 3,654'. Unable to make hole due to fish spinning. 14:00 i 14:30 0.50 PU 2' to 3652', pump 20 bbls sweep, 11 BPM - 3100 psi. 14:30 ~ 16:30 2.00 POOH from 3,652' and cleaned out finger baskets and boot baskets, recovering one small piece of metal, LD BHA # 10. 16:30 17:30 1.00 Service rig. 17:30 20:00 2.50 RIH open ended with 3 1/2" DP, tag bottom at 3,654.85' MD, PU approx 8 inches to circ. 20:00 21:00 ~ 1.00; Circ DP volume at 5 bpm to clear DP of any pipe dope, cut back to 3 bpm and filter brine for camera run. j21:00 22:30 j 1.50j POOH one stand and RU Haliburton E-Line for camera run. (22:30 00:00 ~ ---- 1.50 RIH with camera on a-line to 3,580' through the 3 1!2" DP, and to a total depth of 3,654' tagging top of fish. 6" burnshoe appears to have sidetracked through 7" csg. Decision was made to suspend well. Responsible Daily Contacts _..... _. Supervisor Overstreet, Rick - CPAI, Wells Su Rance Pederson, Rig Supervisor pervisor WO Randy Dexter, Rig Supervisor Head Count /Man Hours _.T,~ ___- ---_ ~ _ -' ~ ~r Nordic Calisla Services ~~, ~ ~~~. ~ tG~ Chulista Camp Services 3 ',ConocoPhillips Company 2 MI Swaco 3 'Nordic Calista Services 1 Baker Oil Tools 2 ~ Safety Check Summary r;,,, 10/9/2008 ;Camp Fire and Evac Drill 'Camp Fire Drill 10/14/2008 Kick While Drilling 10/11/2008 Kick While Tripping ,10/9/2008 I Well Kill Drill j Page 1/1 i I Report Printed: 10/20/2008111 ~ ~ --""""~- __ - Security Level: r/ ~ ~, Daily Project Report 1 D-140 Report Number: 9 Report Date: 10/15/2008 API I UWI Well Type Field Name 5002922974 Development WEST SAK __ Primary Job Type Actual Start Date End Date RECOMPLETION 10/7/2008 ~ 10/16/2008 h e~RV~,rk'If! ~ i'.~la. ,VIE rSiip X10230597 _ ~ 1,400,000.00 Daily Operations Last 24hr Summary ___ __ ___ _ _ Daily Cost Total POOH LD 3 1/2" DP, RIH with 4 1/2 " kill string, POOH LD 4 1/2" tbg, MU and land hanger, set TWC, ND 11" BOP. 105,193.82 24hr Forecast Cumulative Cost NU tree and test, pull TWC, RU and freeze protect well, RDMO well, remove 11 BOP for rig move, start rig move from 1 D 816,516.94 pad to 2A pad. !Time Log - ----- ..---- ,n UU:UU U2:UU j L.UU wont camera work with Haliburton on E-line, POOH and RD lubricator and sheave, RD pump in sub and circ lines. 02:00 03:30 1.50 Unload completion jewelry and 2 3!8" DP from pipeshed for 3 1/2" DP LD, clear rig floor of Baker fishing tools. Suspending operations on the well. 03:30 i 09:00 5.50 POOH LD 3 112" DP and 4 3/4" DC's. 09:00 j 12:00 3.00 Break down and send out fishing tools. Pull wear ring, prep to run tubing back in hole. RD ESP sheaves. 12:00 14:00 2.00 RIH with 4 1/2" tbg to 3,358'. j 14:00 15:00 1.00 Remove ESP spool and spooer from rig with crane. 15:00 16:00 1.00 POOH UD tbg to 2,356', up wt 55K down 55K. 16:00 17:00 1.00 MU landing jnt and hanger, installed dummy penetrators & landed string at 2,356'. 17:00 !,18:00 1.00 RILD's, test upper and lower seals, lower hanger seal test failed. 18:00 ;18:30 0.50 LD landing jnt, removed isolation sleeve, installed TWC. 19:30 00:00 4.50 PU stack washer, cleaned BOP stack, blew down top drive, cleaning pits in prep for welding work. Removed rams from lower double gate, ND 11" BOP stack. Responsible Daily Contacts ! Overstreet, Rick - CPAI, Wells Supe rvisor vvV Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor ---------- -- Head Count !Man Hours -------- iJordic Calista Services _ -~ j zG Chulista Camp Services ~ 3 ConocoPhillips Company ~ 2 MI Swaco I 2 Nordic Calista Services 1 i~~---- ISafety Check Summary 1 1 U/y/2UUU Camp Fire and Evac Drill Camp Fire Drill 10/14/2008 Kick While Drilling 10/11/2008 Kick While Tripping 10/9/2008 !Well Kill Drill Page 1/1 Report Printed: 10/20!2008 r t I f~~ Daily Project Report Security Level: y 1 D-140 Report Number: 10 ' Report Date: 10/16/2008 API I UWI Well Type Field Name 5002922974 Development WEST SAK Primary Job Type Actual Start Date End Date RECOMPLETION 10/7/2008 ~ 10/16/2008 ~~~,,:-~:, ~.. i ~., u ~ ~,,:,, :,>F. ~.~~ ' 10230597 _ 1,400,Ouu.vO _ __ Daily Operations ~ _ __ Last 24hr Summary ____ Daily Cost Total Attempted to NU tree, reset BOP stack and shell tested, pilled hanger, turned and re-landed for alignment, ND BOP stack, 275,983.00 ~ NU tree, tested tree and hanger void, pulled TWC, RU and freeze protected well, RDMO well, cleaned and secured well, removed 11 BOP for rig move. ~ 24hr Forecast Cumulative Cost Move rig from 1 D pad to 2A pad. 1,092,499.94 ITime Log ~~i-,rr,., F.,~r„~,., ,~~,~i~ I ~ h~~,,~,~~ 00:00 02:30 2.50 Cont ND 11" BOP. 02:30 05:00 i 2.50 Attempted to NU adaptor and tree, bolt holes would not line up due to alignment of hanger, tree and guide slot on hanger. 05:00 09:00 I 4.00 Remove tree. NU BOP stack and shell test. Notified AOGCC of shell test at 5:30 hrs(Lou Gramaldi). 09:00 ~ 10:00 1.00 MU landing jnt, back out lock down screws, reset hanger. RILD's & test hanger seals. 10:00 ~ 13 00 ~ 13:00 17 00 3.00 4 00 ND BOPE. NU tree and test to 5000 psi. Test hanger void/packoff to 5000 psi. Pull two-way check. RU LRS f f PJ M k h IA : : . or reeze protect. , pumped 85 bbls diesel for freeze protect and hoo up oses to equalize tbg x , S j blew down hard line to kill tank, RD lines. 17:00 18:00 1.00 PU lubricator and set BPV, SITP = 300 psi, IA = 250 psi, OA = 0 psi. 18:00 21:00 3.00 Blew down water lines, removed mud shack and tanks, pulled off well, removed rig mats and cleaned out cellar box, broke down 11" BOP stack for storage, released Nordic rig 3 at 21:00 hrs 10/16/2008. i Responsible Daily Contacts 'Overstreet, Rick - CPAI, Wells Supervisor WO Rance Pederson, Rig Supervisor Randy Dexter, Rig Supervisor Head Count /Man Hours Nordic Calista Services Chulista Camp Services ConocoPhillips Company MI Swaco Nordic Calista Services Safety Check Summary r~ _,~.H 1 U/9/LUUti 10/16/2008 10/14/2008 10/11/2008 10/9/2008 Gamp Fuc ai+J Evac Drill Camp Fire Drill Kick While Drilling Kick While Tripping Well Kill Drill r..,~ ~, ~ zt 3 2 2 2 1 ~ Page 1/1 Report Printed: 1 • M ~OI'1OCOPf"'tl~ ~ I ~S Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 17, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: .~ ~~~ :"~~; ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Tarn Well 2L-321 (PTD 198-262). 2L-321 was completed in January of 1999. The well produced with gas lift for artificial lift until November of 2001. During this time the well had chronic problems with paraffin deposition. The well was converted to utilize a surface powered jet pump for downhole artificial lift in 2001. Not only did this provide lift, but it also provided heat to prevent paraffin deposition in the tubing. In July of 2006, the well began to show some irregular performance. Leak detect logs eventually ~ revealed a leak in the 5-1/2" production casing at +/- 8400' RKB. The well has been shut in since July 17, 2006. In May of 2007, Nordic 3 moved onto the well to repair the casing leak. Instead of one casing leak at 8400' RKB, pressure testing determined that casing leaks existed between 7694' and ~ 8415' RKB. The workover was suspended so that the next steps could be planned out and so that materials could be procured. The first objective of this workover will be to ensure the leaks in the 5-1/2" casing have been adequately cemented off. Then a 4-1/2" inner casing string will be run along with a 2-3/8" tubing string. Once the workover has been completed, the well will be capable of artificial lift via either jet pump or gas lift. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gober Wells Engineer CPAI Drilling and Wells • ~~ STATE OF ALASKA ~=~ ;, . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~~~k ocr ~ o zoa~ 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ aiv ~ Oft s. ~j Alter casing Q Repair well Q Plug Perforations ^ Stimulate ^ Time Extens~n ~~~~ Change approved program ^ Pull Tubing Q ~ Perforate New Pool ^ Re-enter Suspended Well ^/ ' 2. Operator Name: 4. Current Weli Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 198-262 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20286-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ^~ ~ 2L-321 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380053 RKB 28', Pad 115' Kuparuk River Field / Tarn Oil Pool ' 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12403' - 5890' ~ 11716' 5512' 7286', 11540' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 108' 108' SURFACE 3274' 7-5/8" 3302' 2288' PRODUCTION 11426' 5-1/2" 11454' 5359' LINER 926' 3-1 /2" 12380' 5878' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11680'-11720' 5489'-5512' 3.5" L-80 1627' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 27, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Group Engineer Signature Phone 263-4220 Date ~ ~- Commission Use Onl Sundry Number: ~ f., 7A Conditions of approval: Notify Commission so that a representative may witness 30~-~-7 lP Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: 350CJ ~ S ~ ~~ ~ T ~.S Subsequent Form Required: ~'ii`~(j 1 APPROVED BY S1 ~ ~ Y / ~ Approved by: CQMMISSID R THE COMMISSION 0 Date: Form 10-403 Revised ~ ~~"` U L I ~ , . ~ ~ ~~ I ~ Submit in Duplicates to ~,~ • • .. Kuparuk 2L-321 General Workover Procedure Pre-riq Work 1. Apply for Sundry General Workover Procedure Major steps: 1. MIRU Nordic #3 rig. 3~ L~C~ ~ ~ -~ ~~~ 2. Pull BPV. Ensure well is dead. Reset BPV. Q ~ 3. ND tree, NU and test 13-5/8" 5M BOP to 250/3Q~0 psi. Test annular to 250/2500 psi. MASP=2602 psi. ~~ 4. Pull 3-1 /2" kill string 5. Drill out cement retainer and cement in 5-1/2" casing to expose casing holes 7694'-8415' RKB. Pressure test casing to 1000 psi. Resqueeze if necessary. Continue to clean out down to 11425' RKB (just above casing seal receptacle). POOH. 6. Run scraper and string mill on 3-1/2" PH-6 workstring. Run stinger on bottom of scraper and cleanout CSR while on bottom. POOH. 7. Run 4-1/2" inner casing string. Load annulus with corrosion inhibited brine. Land in CSR. ND BOP. Install slips for 4-1/2" casing. Cut off 4-1/2" casing and NU new tubing head. Pressure test packoffs, NU and test BOP. Freeze protect 4-1/2" x 5-112" annulus. 8. RU slickline. RIH and set isolation sleeve in 4-1/2" AVA nipple. PT sleeve to 3500 psi. RD slickline. ~------~ 9. Run 2-3/8" completion with sliding sleeve in open position. Load tubing and IA with corrosion inhibited brine. Space out and land 2-3/8" tubing. CMIT tubing and IA to 3500 psi. 10. ND BOP, NU and test new 2-9/16" tree. Freeze protect tubing and IA. 11. RU slickline. Close sliding sleeve. Pressure test IA to 3500 psi. Pressure test tubing to 3000 psi. RD slickline. Set BPV. ~--•°--~ 12. RDMO Nordic 3. Post-Rig Work: 1. Pull BPV. 2. RU CTU with 1.5" tubing. RIH and mill up FasDrill bridge plug and clean out to PBTD. 3. RU slickline. Pressure test IA to 3500 psi. Open sliding sleeve. Run Weatherford jet pump assembly or concentric gas lift mandrel- 4. Modify S-riser for higher tree. 5. Return to production. Well: 2L-321 API: 501032028600 r~t~~tul~tj~~i~-5 Field: Tarn PTD: 198-262 2008 RWO PROPOSED COMPLETION EXISTING COMPLETION WELLHEAD Lift threads: 3%2" 8rd EUE BPV: 3" CIW H BPV Model: FMC Tarn Gen V Slimhole NEW COMPLETION WELLHEAD Lift threads: 2-7/8" 8rd EUE BPV: 2.5" CIW H BPV Model: FMC Tam Gen V Slimhole CONDUCTOR 16", 62.58 ppf, H-40 ,welded SURFACE CASING 7%8', 45.5 ppf, L-80, BTC-MOD PRODUCTION CASING 5%2', 15.5 ppf, J-55, BTC-MOD c D LINER 3%2", 9.3 ppf, L-80, EUE-8rd Mod PLUG 3-1/2" HES Fas Drill Bridge Plug Set at 11,540' RKB PERFS 11,680'-11,720' MD 5,489'-5,512' TVD 6 spf, 1/26!99 INNER CASING 4-1 /2", 11.6 ppf, T-95 & L-80, Hyd 513 TUBING 2-3/8", 4.6 ppf, L-80, IBT-Mod A: Sliding Sleeve: 2-3/8" with 1.875" X profile 6: AVA Nipple: 4-1/2" C: Seal Assembly: 2-3/8" D: Seal Assembly: 3-1/2" on bottom of 4-1/2" inner casing Last Tag: 7126/06 Tag Depth: 11,716' RKB Fill: 4' fill above btm pert TD: 12,403' RKB Last Updated: 17-Oct-08 Updated by: HBG Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 11:52 AM To: 'Packer, Brett B' ~.r~ ~~;: ~t'~.. ~!~ ; ~~#~'' Subject: RE: 1 D-140 (200-136) -Again 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 10/20/200$ 1 D-140 (PTD #200-136) Page 1 of 3 .' • • Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 1:54 PM To: 'Packer, Brett B' Subject: RE: 1 D-140 (PTD #200-136) Brett, You are correct. For some reason, I was unable to find our exchange of messages. Thanks for the work summary. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, October 20, 2008 1:52 PM To: Maunder, Thomas E (DOA) Subject: FW: iD-140 (PTD #200-136) Tom, I was under the impression that the email below served as a verbal approval. Attached is the hourly time log summary for this workover. We'll get the 1 D-140L1 Sundry to you as soon as possible. ,7. Brett hacker Drilling s~ `Welts ZUotkover~ngineer 'Wo~,# 265-6845 Cell~# 230-8377 From: Maunder, Thomas E (DOA} [mailtoaom.maunder@alaska.gov] Sent: Wednesday, October 15, 2008 4:18 PM To: Packer, Brett B Subject: RE: 1D-140 (PTD #200-136) Brett, Thanks for the update. Good news here is that it appears there were only 3 wells equipped with the RMLS junction and you have accounted for all of them. It is acceptable to halt operations as you plan. I will look forward to the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:J.Brett.Packer@conocophillips.com] Sent: Wednesday, October 15, 2008 4:11 PM To: Maunder, Thomas E (DOA) Subject: 1D-140 (PTD #200-136) i oi2oi2oos 1 D-140 (PTD #200-136) Page 2 of 3 ~~ Tom, As a follow-up to our conversation this morning, I wanted to outline the details of the workover operations on West Sak well 1 D-140 (PTD#200-136). A formal 10-403 Sundry Application to temporarily suspend the well will follow. Brief History: 1 D-140 is a dual lateral (B&D sand) ESP producer. It is one of the three West Sak wells that have the Sperry RMLS junction in the D-sand. You may recall the other two welts were 1 D-141 and 1 D-102, both of which the RMLS junction has been problematic. In the case of 1D-141, during the workover in 2001, an attempt was made to get past this junction and we inadvertently milled through the production casing. This resulted in plugging back the well and sidetracking the welt in early 2008. Also earlier this year, we attempted a workover on 1 D-102 and tried to get past this junction to do a cleanout, but were unable to get past and ended up just re- installing the ESP without a cleanout. We were hoping that the 3rd time would be a charm, but unfortunately such is not the case. This junction has a transition joint that connects to the D-lateral liner and extends back into the mainbore. The transition joint is cemented in place and then the piece sticking in the mainbore is shaved flush with the casing to allow full-bore access below. Over time, this junction has been known to fail, and that pipe that is shaved flush with the casing stuffs off into the mainbore. In order to get past it, we have to mill through that piece sticking in the mainbore and once again, shave it flush with the casing. Easier said than done, The original plans for this workover were to pull the ESP, test the casing, dress off the D-sand junction, cleanout the lower lateral, and re-install the ESP. Warkover details; 10/8/08: Killed well w/ 9.6 ppg brine. 10/9/08: ND tree, NU BOPE & test. Pulled hanger to floor, well began slight flow, weighted up to 9.9 ppg, well is dead. 10110/08: POOH w/ ESP completion. Set RBP at 3570' RKB, tested casing to 2500 psi, test good. RIH wJ BHA #1: 6" rotary shoe, junk baskets, washpipe, and VACS tool. Tagged at 3594' RKB (where the bottom of the ESP was). Cleaned out down to 3652' RKB and tagged hard (30' above D-lateral window}. Started milling on what seemed to be metal at 3652' RKB. Milled down to 3662' RKB and quit making hole. 10/11/08: POOH w/ BHA #1. Washpipe had parted at the connection. Left the mill, (2) junk catcher subs and a 2.5' piece of washpipe in the hole. Total: 8.57' fish. Cleaned out sand, fill, formation chunks from VACS tool. PU BHA #2: 4-3/4" bladed junk mill, cleaned out fill from 3600' - 3652'. Attempting to cleanout inside washpipe for fishing run. POOH. PU BHA #3: 4-5/16" Spear wf 4.32" grapple. Wash down to 3654', attempted to engage fish w/ no success. POOH. Spear showed signs of entering fish, but grapple not engaging, indicating washpipe is either split or flared out. 10/1.2/08: MU BHA #4: 4.32" spear w/ 4.961" grapple. RIH to 3654', attempt to latch fish with no success. POOH. MU BHA #5: 4-3/16" bladed junk mill. Washed down to 3652'. POOH. 10/20/2008 iD-140 (PTD #200-136) Page 3 of 3 MU BHA #6: 4-5/16" spear w/ 5.101" grapple Washed down to 3654', attempt to latch fish with no success. POOH. 10/13/08: MU BHA #7: 4-3/4" bladed junk mill. RIH to 3654', could not work past, no increase in torque. POOH. MU BHA #8: 6" rotary burn shoe w/ reverse junk basket. RIH tag at 3652'. Mill from 3652' - 3654'. POOH w/ handful of smatl metal pieces. MU BHA #9: 6" rotary burn shoe w/ reverse junk basket & 2 boot baskets. Wash down to 3651' and mill to 3654', could not make any more progress. 10/14J08: POOH w/ BHA #9, recovered a goad amount of metal and piece of washpipe. MU BHA #10: 6" rotary burn shoe w/ reverse junk basket & 2 boot baskets. RIH to 3651', mill to 3654', unable to make any hole, fish appears to be spinning. POOH. Decided to run a camera, RIH w/ DP open ended to 3655', circulate hole clean. PUH to 3580'. RU E-line w/ camera, tagged top of fish at 3654°. Indications that the 6" burn shoe had begun milling through casing. Determined workover operations to be unsuccessful and decided to suspend the well for future sidetrack. 10/7 5/08: Notify AOGCC on slope and in town of plans to suspend. RD E-line, POOH laying down DP. Currently running 2300' 4-1/2" tubing kill string, freeze protect well. RDMO I'fl have the 10-403 ready for you in the morning. This is a good well, so plans are already in motion to determine the best options with regards to a sidetrack. We would hope to be able to re-visit this well early next year. If you have any further questions, please don't hesitate to call. Thanks, .7. Brett Backer ~ri~ng az ~GVeCCs `Wor(gver~Engineer 'Work# 265-6845 Cell# 230-8377 10/20/2008 1 D-140 (PTD #200-136) Page 1 of ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 4:18 PM To: 'Packer, Brett B' Subject: RE: 1D-140 (PTD #200-136) Brett, Thanks for the update. Good news here is that it appears there were only 3 wells equipped with the RMLS junction and you have accounted for all of them. It is acceptable to halt operations as you plan. I will look forward to the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Packer, Brett B [mailto:).Brett.Packer@conocophillips.com] Sent: Wednesday, October 15, 2008 4:11 PM To: Maunder, Thomas E (DOA) Subject: 1D-140 (PTD #200-136) . - =~ '~a~~<.G `~,' ,'` ~l~)t? Tom, As a follow-up to our conversation this morning, I wanted to outline the details of the workover operations on West Sak well 1 D-140 (PTD#200-136). A formal 10-403 Sundry Application to temporarily suspend the well will follow. Brief History: 1 D-140 is a dual lateral (B8~D sand) ESP producer. It is one of the three West Sak wells that have the Sperry RMLS junction in the D-sand. You may recall the other two wells were 1 D-141 and 1 D-102, both of which the RMLS junction has been problematic. In the case of 1D-141, during the workover in 2001, an attempt was made to get past this junction and we inadvertently milled through the production casing. This resulted in plugging back the well and sidetracking the welt in early 2008. Also earlier #his year, we attempted a workover on 1 D-102 and tried to get past this junction to do a cleanout, but were unable to get past and ended up just re- installing the ESP without a cleanout. We were hoping that the 3rd time would be a charm, but unfortunately such is not the case. This junction has a transition joint that connects to the D-lateral finer and extends back into the mainbore. The transition joint is cemented in place and then the piece sticking in the mainbore is shaved flush with the casing to allow full-bore access below. Over time, this junction has been known to fail, and that pipe that is shaved flush with the casing stuffs off into the mainbore. In order to get past it, we have to mill through that piece sticking in the mainbore and once again, shave it flush with the casing. Easier said than done. The original plans for this workover were to pull the ESP, test the casing, dress off the D-sand junction, cleanout the lower lateral, and re-install the ESP. Workover details: 1018/08: Killed well w/ 9.6 ppg brine. 10/8/08: ND tree, NU BOPE & test. Pulled hanger to floor, well began slight flow, weighted up to 9.9 ppg, well is dead. 10/15/2008 1D-140 (PTD #200-136) Page 2 of +~ +~ t~- 10/10/08: POOH w/ ESP completion. Set RBP at 3570' RKB, tested casing to 2500 psi, test good. RIH w/ BHA #1: 6" rotary shoe, junk baskets, washpipe, and VACS tool. Tagged at 3594' RKB (where the bottom of the ESP was). Cleaned out down to 3652' RKB and tagged hard (30' above D-lateral window}. Started milling on what seemed to be metal at 3652' RKB. Milled down to 3662' RKB and quit making hole. 10/11/0$: POOH w/ BHA #1. Washpipe had parted at the connection. Left the mill, (2) junk catcher subs and a 2.5' piece of washpipe in the hole. Total: 8.57' fish. Cleaned out sand, fill, formation chunks from VACS tool. PU BHA #2: 4-314" bladed junk mill, cleaned out fill from 3600' - 3652'. Attempting to cleanout inside washpipe for fishing run. POOH. PU BHA #3: 4-5/16" Spear w/ 4.32" grapple. Wash down to 3654', attempted to engage fish w/ no success. POOH. Spear showed signs of entering fish, but grapple not engaging, indicating washpipe is either split or flared out. 10/12/08: MU BHA #4: 4.32" spear w/ 4.961" grapple. RIH to 3654', attempt to latch fish with no success. POOH. MU BHA #5: 4-3/16" bladed junk mill. Washed down to 3652'. POOH. MU BHA #6: 4-5/16" spearw/ 5.101" grapple Washed down to 3654', attempt to latch fish with no success. POOH. 10/13/08: MU BHA #7: 4-3/4" bladed junk mill. RIH to 3654', could not work past, no increase in torque. POOH. MU BHA #8: 6" rotary burn shoe w/ reverse junk basket. RIH tag at 3652'. Mill from 3652' - 3654'. POOH w/ handful of small metal pieces. MU BHA #9: 6" rotary burn shoe w/ reverse junk basket & 2 boot baskets. Wash down to 3651' and mill to 3654', could not make any more progress. 10/14108: POOH w/ BHA #9, recovered a good amount of metal and piece of washpipe. MU BHA #10: 6" rotary burn shoe w/ reverse junk basket 8~ 2 boot baskets. RIH to 3651', mill to 3654', unable to make any hole, fish appears to be spinning. POOH. Decided to run a camera, RIH w/ DP open ended to 3655', circulate hole clean. PUH to 3580'. RU E-line w/ camera, tagged top of fish at 3654'. Indications that the 6" burn shoe had begun milling through casing. Determined workover operations to be unsuccessful and decided to suspend the well for future sidetrack. 10/15/08: Notify AOGCC on slope and in town of plans to suspend. RD E-line, POOH laying down DP. Currently running 2300' 4-1/2" tubing kill string, freeze protect well. RDMO I'll have the 10-403 ready for you in the morning. This is a good well, so plans are already in motion to determine the best options with regards to a sidetrack. We would hope to be able to re-visit this well early next year. If you have any further questions, please don't hesitate to call. Thanks, Brett B~k~ 10/15/2008 1 D-140 PTD (2001360) Report of failed ESP ~ Page 1 of 1 Maunder, Thomas E {DOA) From: NSK Problem Well Supv [n1617 cQconocophillips.com] Sent: Tuesday, April 22, 2008 10:29 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 D-140 PTO (2001360) Report of failed ESP Tom, Not at this time. Brent ~~~~~E~ APR ~ 2 200 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, April 22, 2008 10:27 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA) Subject: RE: 1D-140 PTD (2001360) Report of failed ESP Is there any plan to gas lift? Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, April 21, 2008 4:54 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Weil Supv Subject: 1D-140 PTD (2001360) Report of failed ESP Tom, Kuparuk ESP producer 1D-140 (PTD 2001360) ESP pump failed on 04/18!08 due to a dawnhole electrical failure. The failure will require a RWO to repair. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, {nc. Desk Phone (907) 659-7224 Pager (907} 659-7000 pgr. 909 4/22/2008 . . ConocJPhillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNE;D SEP 0 6 2007 ~ÐD-. 13" Dear Mr. Maunder: ' Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of thes'ë wells was fôund to have a void in the conductor. These voids were filled with a corròsion inhibitor, engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. .~~~~. M.J.¿el~d ConocoPhillips Well futegrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10;.14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200'-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 "1C-11 199-172 - SF NA NA NA :0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 . 'y/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 yVest 7ili Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 " 2007 ... rÕ Co ~OO Dear lVIr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28, 2006 for 1D-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/C 0-:B Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-O 1 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14'6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 10-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 10-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 10-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 10-138 200-048 11'7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 10-140 200-136 29'9" 3.4 12" 12/16/2006 na na F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .II:,~.o.tr'. ~.' ,r-~". ,I., ,_.: ) ) ~ ~ ~ Mike Mooney Wells Group Team leader Drilling & Wells ~ ConocciPh ill ips 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 ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 10-140 and 1 0-140L 1 (APD ~a--136 and 200-146) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the multilateral Kuparuk well 10-140 and 10- 140L 1 . If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 11/[ 4 M.MO~ Wells Group Team Leader CPAI Drilling and Wells RECEIVED MAY 252004 Alaska Oil & G C as ons C . Anch . ommlssion Drage MM/skad O~\G\NAL ~ I ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 31' 1. Operations Performed: 8. Property Designation: ADL 25650 & 25649, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PRODUCTION LINER Perforation depth: measured true vertical measured true vertical Length 110' 407' 3517' 556' RepairWell 0 Pull Tubing 0 Operat. ShutdownD 8117' 3772' Size 16" 10-3/4" 7-5/8" 7" 4" Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - [2] Stratigraphic D Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 200-136/304-067 6. API Number: 50-029-22974-00 Exploratory D Service D 9. Well Name and Number: 10-140 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool feet feet Plugs (measured) Junk (measured) feet feet MD TVD Burst Collapse 110' 509' 3619' 4175' 8117' 110' 509' 3509' 3740' 3772' RECEIVED MAY 25 2004 Measured depth: perfs thru screens 4109'-8117' true vertical depth: 3733'-3772' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3595' MD. Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) pkr= BAKER 'SCR-1' PACKER W/5.5' SL-HT BOX pkr= 4020' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: N/A Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 497 663 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: Oil 0 GasD WAGD CasinQ Pressure TubinQ Pressure 380 263 Service D WINJD WDSPLD GINJD 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 Mike Mooney @ 265-4374 ;;1M;;; Signature Form 10-404 Revised 04/2004 Wells Group Team leader Date .5,f A~ r- Prepared bv ShtronC:: A/~ja~ 261~ nO I 51 NAL .....8fL M* \J , ,/ :\ ~ Submit Original Only Title Phone TUBING (0-3595, OD:4.500, ID:3.958) 'RODUCTION (0-3619. OD:7.625, Wt:26.00) SUB (3469-3470, OD:5.500) SCREEN (3547-3548. OD:5.000) SEAL (3557-3572. OD'5.000) MOTOR (3571-3588, OD:5.000) GAUGE (3588-3594, OD:5.000) 'ROOUCTION (3619-4175, OD:7.000, Wt:26.00) PKR (4020-4021, OD:6.059) LINER (4020-4109. OD:4.000. Wt950) Perf (4109-8117) ~ ~ KRU 1D-140 ConocoPhillips Alaska, Inc. 1D';140 ir8 Well Type: PROD Orig 10/12/2000 Completion: Annular Fluid: Last W/O: 5/8/2004 Reference Log: 31' RKB Ref Log Date: LastTag: TD: 8117 ftKB Last Tal/Date: m " " '" MaxHole Angle: 93 deg @ 4455 GaSing¡Stî:inIÍ .; éJ$Mtd~N: C.ASING,'S;¡¡RING ' , " Description Size Top Bottom CONDUCTOR 16.000 0 110 SURFACE 10.750 0 509 PRODUCTION 7.625 0 3619 PRODUCTION 7.000 3619 4175 CSG WINDOW 6.151 3684 3685 Ø_Jiíö,smfiii';LOWE R LAmE8AIi~ILINE RlAlf; ]ts4'Slank" & J?re.~paêked2 D. Däúiiescièen) Description I Size I Top l Bottom I TVD I Wt I Grade I Thread LINER 4.000 4020 4109 3733 9.50 L-80 HSLHT DUAL SCRE¡:N LNR 4.000 4298 8117 8117 9.50, L-80 HSLHT J'ubil1iiSlring.;tli.fBÎNG) ,,?m,,) :.".;. :.., ' ",'N"'",,:"':">:' Size I Top Bottom TVD I Wt I Grade I Thread 4.500 0 3595 3492 12.60 L-80 NSCT PerforationsSM'mmåìY, , Interval TVD 4109-8117 3733-8117 API: 500292297400 SSSV Type: NONE Angle @ TS: deg @ Angle@TD: 90deg@8117 Rev Reason: WORKOVER Last Update: 5/9/2004 TVD Wt Grade Thread 110 151.50 X-65 WELD 509 40.50 J-55 BTC 3509 26.00 L-80 BTC-MOD 3742 26.00 L-80 BTC-MOD 3552 26.00 L-80 to 10-141 L 1 Zone Status Ft SPF Date Type Comment WS B,WS 4008 50 10/12/2000 Screens Perfs thru screens C,WS B,WSB ,Gas,iliiftiMãïidrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2513 2507 Camco KBG-2 DMY 1.0 BK-5 0.000 0 5/7/2004 2 3440 3383 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 5/7/2004 Otl1:íárJ(pfugš; equip" etc.) - eOMMONJEWELRY ..n Depth TVD Type Description 3469 3405 SUB BAKER PHOENIX PRESSURE SUB set 5/8/2004 3547 3460 SCREEN TCC SCREENED INTAKE FOR PUMP set 5/8/2004 3557 3467 SEAL WSP TANDEM MOTOR SEAL GSB3DBILH6PFS set 5/8/2004 3571 3476 MOTOR BAKER ESP MOTOR KHM/190 set 5/8/2004 3588 3488 GAUGE BAKER PHOENIX GAUGE set 5/8/2004 3594 3492 Centralizer BAKER MOTOR CENTRALIZER set 5/8/2004 Øtlièr~(pfugS;ï'¡qùlp;, etc.) - LOWER LATERAL ¡jEWELRY :g~~hl~~~ I S~!~E I ~:~:~ ;~~¿:oa~~fn~/~'I;:~;~~~~:tion Generâl'NøtØ$ , ",; ,','0;';' Date Note 12/6/2000 NOTE: This is a multilateral well. This schematic represents the 'B' sand lower lateral. See schematic for 1 D-140L 1 for the 'D' sand upper lateral. ID 3.930 0.000 0.000 0.000 4.500 0.000 liD 4.000 3.437 ~ ~ 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: 5/412004 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 CMPL TN 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 CMPLTN 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 10-140 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 hardlines 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 tIcirculate. 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 wellbore fluid. Slowed rate down with no help. Shut down pumping. Montiored well, no flow observed. Decided to Bullhead down the IA to insure wellbore 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,Hydrili bag NU (BOPE). 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 master 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 10:53.06 AM ~ ~ , . . 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: 5/612004 11:45-12:15 0.50 CMPLTN CIRC DECOMP of level. 12:15 - 14:00 1.75 CMPL TN OBSV DECOMP Monitored well and waited for another fluid level to be shot. Fluid level @ 500'. 14:00 - 15:30 1.50 CMPL TN TRIP 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 CMPL TN TRIP 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 CMPl TN 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. 5/7/2004 00:00 - 03:00 3.00 CMPL TN TRIP DECOMP Continued to POOH. Pulled 114 its 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 CMPL TN 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 CMPL TN 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 it, 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 CMPLTN 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 CMPLTN SOHO CMPLTN Up Wt = 54k & Dwn Wt = 52k, Block Wt 10k. Landed Hanger, RILDS, and tested to 5000 psi. Good test. PrInted. 5/21/2004 10:5306 AM '. r'\ ~ ~ , 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: 5/812004 11:30 - 15:30 15:30 -18:00 18:00 - 00:00 4.00 CMPL TN NUND CMPL TN 2.50 CMPL TN SECT 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. RIU lubricator,set BPV. NU blind flanges on valves. Clean cellar area. RELEASED RIG at 00:00 HRS. Printed 5/21/2004 10:53'06AM 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 ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak weIl1D-140. 1 D-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 TTC 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. Sincerely, ~r Well Supervisor CPAI Drilling and Wells r<ECEIV'El1 MAR 0 2 2004 Alat~a Oil ¡~ Gas Cons, Comrm~sion A o'chor1tge ORtG\NAL SCANNE[) Ml..\H 1 5 2D Gfi ,.~~ !i..,"" C" L ~ ~\I L-. i ",\ 1/. .. j '.1,... I:,; I . L~.. A STATE OF ALASKA MAR 0 2 2004 56 APP~~~~ ~;~~ ~~~o~~~~~~c~;~~~v J..r.~a °,1 P< ::rsh~~~;r' ~';r¡;i~1 ~ 20 AAC 25.280 D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D D Repair well 0 Plug Perforations D Stimulate D Time Extension D D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D . Permit to Drill Number: 200-136 /200-146 6. API Numb~ 50-029-2297)(00 /50-029-22974-60 . Well Name and Number: 1 D-140 /1 D-140L 1 10. Field/Pool(s): West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7619 3718 Size MD 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 102' 4. Current Well Class: Development - 0 Stratigraphic D Exploratory D Service D 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): 8117' 3772' Casing Length CONDUCTOR 110' SURFACE 407' PRODUCTION 3517' PRODUCTION 556' Liner 3935' TVD 16" 110' 110 10-3/4" 509' 509 7-5/8" 3619' 3509 7" 4175' 3740 4.5"x4" 7619 3718 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 D BOP Sketch D 14. Estimated Date for Commencing Operations: June, 1,2004 16. Verbal Approval: Date: Perforation Depth TVD (ft): Tubing Size: 4-1/2" Packers and SSSV MD (ft) 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD 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 -n:::> Contact: Title: Signature Commission Use Only Phone 265-6820 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: '55òD S(cj'\ ßÙ\, ~s\- ~\~'''~I.),,-\ 'i;::>-.~t;.. .~I ,_. BY ORDER OF THE COMMISSION Form 10-403 Revised 2/2003 . Other D Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 35951 Service D Plugged D WINJ D Abandoned D WDSPL D Howard Gober @ 265-6820 Well Supervisor Date: Sundry Number: ~30J l \'" , ' \ .J... \ '''.' \,1 '~l ;.,.\,- . . {~~\ \~l" Date: 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 DV's in both pockets. 2. Obtain SBHPS (7 day SI) (downhole gauges are functional). 3. Kill well wlin 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. ND 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. NU Tree. Test tree. Pull 2-way check. 11. Freeze protect with diesel to +1- 2000' TVD. 12. Set BPV. RDMO workover rig. Post-Ria Work: 1. Pull BPV. 2. RU Slickline. Run TTC CESP pump, pack-off, & slip-stop. 3. Return to production. 01/27/04 Schlumberger NO. 3100 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ( Well Job# Log Description Date BL Color CD 3LJ '(JS3 2A-04 10709682 INJECTION PROFILE 12/27/03 1 "¡:::: '" 1..7~ô-- 2T-28 10709867 STATIC SURVEY 01/15/04 1 ~Lf -- Ei3 2A-04 10709691 RST 01/19/04 1 ~~ );)d.- 2K-01 10696828 LDL 01/14/04 1 a> (3ú 1 D-140 10696827 LDL 01/13/04 1 '3'1--1\ \ 3H-03 10709688 PRODUCTION PROFILE 01/16/04 1 "-3 -. \.:3 L{ 2P-447 10696819 SCMT 01/04/04 1 œ.- JS..3 2P-434 10709667 USIT/CBL 12/02/03 1 2P-432 .. , O~--C~\ \ 10696818 PERF RECORD & SBHP 01/03/04 1 ~ .- -.'j~ ...~ .~ ,,: I ~I:.Vr.:, VI-V "1"~>.,_'::) " """"'"'' J ÞJ-! 2,0 2004 S I G NED: ly"V",\ \ ..~ J. /'-1"'\ . " \--"j I.. Cì ~ ~ ~ /\/"- ' DATE: F~Ja5k.a OU & Gas COos. Commisinr~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8,317. Thank you. ¡\Of,borage ~f(;A"~NE¡C, JFEB 0 3 200ð~ _._''''''\~-'~''''';''''",,, ,I"", (::~ W 6 A-- I" '¡..(?' /'2-0 C)( ( (00" 1/2 -/° STATE OF ALASKA' " 1-- ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Operation Shutdown D Perlorate D Variance 0 Annular Disp. D Alter casing D Repair well D Plug Perlorations D Stimulate D Time Extension D Other D Change approved program D Pull Tubing D Perlorate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Perm~to Drill NU~ber: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 200-136 /200-146 3. Address: Stratigraphic D 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' 1D-140/1D-140L1 8. 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 (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8117' 3772' 7619 3718 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110 SURFACE 407' 10-3/4" 509' 509 PRODUCTION 3517' 7-5/8" 3619' 3509 PRODUCTION 556' 7" 4175' 3740 Liner 39351 4.5"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-80 35951 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 D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January, 30, 2004 /' Oil 0 /' Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs/Marie McConnell @ 659-7224 Printed Nam. e . MJ LovelanJII ¡/ /' Title: Problem Well supe~isor Signature ,.../1¡4//';/l~ ~ Phone 659-7224 Date: èiJ O\.JOt4-'\ ~ Y I .. / {~ Commission Use Only / Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3D t./- {)¿ÞtJ Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RECEIVED JAN 2 6 2004 Alaska Oil 8t Gas Cons. Commission ~ Anchorage ~ A,'" BY ORDER OF Approvea or: "" '.../' 'A...,....-. COMMISSIONER THE COMMISSION Date: e/ /.J ð1-- ~ ~ - / I Fonn 10-403 Revised ~NED FEEl (1 3 2004 0 RIG I N / '.' SUBMIT INc~~;LI~ATE ,.....j ,..3 . . I, ..,.. IL"L"..,,,,,; 1~1\\/)'lj I;J~l I'<~rl:':<\'i.i\:::ì If ICD) \W ) li.,(, lU r ( ( ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk WelllD-140 (PTD 200-136/200-146) January 20, 2004 This application for Sundry approval for well1D-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 well1D-140 include producing with conventional gas lift, 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 10 140 6:00 100 347 76 1027 951 38 1654 93 91 56 50 904 1 D 140 12:00 100 318 73 909 1065 48 1745 144 159 83 45 1057 10 140 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-140 ~. .ConocoPhillips Alaska, Inc. 1D-140 API: 500292297400 SSSV Type: NONE Rev Reason: Pull ESP assembl Last U date: 1/20/2004 To Bottom TVD Wt Grade Thread 0 110 110 151.50 X-65 WELD Gas Lift 0 509 509 40.50 J-55 BTC MandrelNalve 0 3619 3509 26.00 L-80 BTC-MOD 2 (3440-3441. 3619 4175 3742 26.00 L-80 BTC-MOD 3684 3685 3552 26.00 L-80 to 1D-141L 1 SUB (3463-3464, Thread 00:5.500) HSLHT HSLHT SUB Thread (3470-3471, NSCT 00:5.500) Status Ft SPF Date T e Comment 4008 50 10/12/2000 Screens Perfs thru screens SCREEN (3548-3549, Vlv 00:5.000) Cmnt .. _.n.. ._,.... ... ID 3.930 SEAL 3.930 (3558-3572, 0.000 00:5.000) 0.000 0.000 4.500 0.000 MOTOR - (3572-3589, 00:5.000) Centralizer - .--- . (3595-3596, 00:6.250) ::>ROOUCTION -- (3619-4175, 00:7.000, Wt:26.00) PKR - --..---- (4020-4021, 00:6.059) LINER - (4020-4109, 00:4.000, Wt:9.50) .... Perf (4109-8117) - - ---.-- / ) iÍ) Mike Mooney i~ ~. Wells Group Team Leader Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 ConocoPhillips 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 1 D-140 1 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, i1J ¡Jj~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED DEC 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage ~CANNED JJUI 2 4} 2004 0 R \ G \ N A L ~ '~ .. STATE OF ALASKA V 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. 0 Alter Casing D Repair Well 0 Plug Perforations 0 Stimulate D Time Extension 0 Other 0 Change Approved Program D Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 200-136/200-146 3. Address: Stratigraphic 0 Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22974-00/50-029-22974-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' 1 0-140 / 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 IVE D Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3595' MD. DEC 1 6 2003 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 I Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina 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 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number 0... r N!P. it c.O'f:q:!-J.. . . . ~ l~'.'" ':.}'...~._. ~ -J ~"j' ~l" , ,~ Contact Guy Schwartz @ 265-6958 Printed Name Mike Mooney Title Wells Group Team Leader Signature ,) I I J Phone Date t 2/1&/6 Y /1 .* }Ij~ Preoared bv Sharon AlIsÍJo-Drake 263-4672 ¡'Fi'~", 0.. ~ 111 ~ ~ Dle'h '¡ {}, 'í'~ð' r'\ ~'f\ . .:.~ ,~~ ~;'1' ,I:',~"'~' ,f ,~, I: ,',: ;: Form 10-404 Revised 2/2003. EC 2..~ !1t, 0 R t I..."': ! 1\.' , SUBMIT IN DUPLICATE (J (J ConocoPhilUps Alaska, Inc. KRU 1 D-140 1D.140 PROD 10/12/2000 10/28/2003 Ref L To Bottom TVD Wt Grade Thread 0 110 110 151.50 X-€5 WELD 0 509 509 40.50 J-55 BTC 0 3619 3509 26.00 L-80 BTC-MOD 3619 4175 3742 26.00 L-80 BTC-MOD 3684 3685 3552 26.00 L-80 to 1D-141L1 Thread HSLHT HSLHT Thread NSCT Status Ft SPF Date T e Comment 4008 50 10/12/2000 Screens Perfs thru screens ODUCTION (0-3619, OD:7.625, Wt:26.00) 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# SEAL I (3558-3572 I Descri tion I D OD:5.000) BAKER PHOENIX TEMPERATURE SUB set 10/23/2003 3.930 . BAKER PHOENIX TEMPERATURE SUB set 10/23/2003 3.930 TCC SCREENED INTAKE FOR PUMP set 10/27/2003 0.000 4.5" ESP PUMP SET 11/11/2003 - PACKOFF & SLlPSTOP W/CHECK SET 0.000 MOTOR 3483' WLM 11/22/2003 (3572-3589, 3558 3468 SEAL WSP TANDEM MOTOR SEAL GSB3DBILH6PFS set 10/27/2003 0.000 00:5.000) 3572 3477 MOTOR BAKER ESP MOTOR KHM/190 set 10/27/2003 0.000 3589 3488 GAUGE BAKER PHOENIX GAUGE set 10/27/2003 4.500 3595 3492 Centralizer BAKER MOTOR CENTRALIZER set 10/27/2003 0.000 ! Other lu 5, e ui . etc. . LOWER LATERAL JEWELRY De th TVD T e Descri tion ID 4020 3714 PKR Baker 'SCR-1' Packer w/5.5" SL-HT Box 4.000 4066 3725 SLEEVE Baker 4.5" CMD Slidin Sleeve 3.437 General Notes Date Note 12/6/2000 NOTE: This is a multilateral well. This schematic represents the 'B' sand lower lateral. See schematic for 1 D-140L 1 for the 'D' sand u er lateral. PKR (402~21 , 00:6.059) Perf (4109-8117) - - ( ConocoPhillips Alaska Page 1 of 5 Operations Summary Report Legal Well Name: 10-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 10/16/2003 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 6'~Je Phase Oescription.of Operations 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. 10/18/2003 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, toolpushers, 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 WELCT DECOMP Nipped down the tree. Tree and tubing head adapter were in good shape. 16:00 - 20:00 4.00 WELCT 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 WELCT SFTY DECOMP Hold pre-spud meeting with night crew, MI, Centrilift, Toolpusher, engineer, & Company Man. 21 :00 - 00:00 3.00 WELCT DECOMP Continue NU BOP stack. Install riser on top of annular preventer. MU choke and kill lines. 10/19/2003 00:00 - 00:45 0.75 WELCT DECOMP MU choke and kill lines. 00:45 - 01:15 0.50 WELLS 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 WELCT 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 WELCT 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 WELLS PULD DECOMP Setting up equipment for Centrilift spooler & Raychem spooler. 12:30 - 16:45 4.25 WELLS 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 WELCT EaRP DECOMP Blocked in the annulus. bleed and rigged up hardline 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 WELLS 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: 1 D-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 10/16/2003 End: 10/26/2003 Contractor Name: Nabors3sCompanyM@conocop Rig Release: 10/26/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Phase Description.of.Operations 10/19/2003 18:00 - 18:45 RURD DECOMP Finished cleaning the pits. 18:45 - 20:00 RURD DECOMP Load pits with filtered 9.8# brine from the tank farm. Suction pit 1 NTU. 20:00 - 22:00 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 IAtaking 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 WELLS 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 oft 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 downthe 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 oft. 13:15 - 15:20 2.08 FISH PULL DECOMP 10 stands in the rack. Fill hole, 10 bbls to top oft. 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 oft. 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 oft. 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: 10-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 10/16/2003 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 cfoUJe Phase Description of Operations 10/20/2003 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 WELLS WRKOVR M/U Running tool with wear ring. Set same, lay down running tool. 13:30 - 15:00 1.50 WELLS WRKOVR Strap & Drift BHA, M/U Baker dual casing scrapers. 15:00 - 18:00 3.00 WELLS 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 WELLS 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 WELCT WRKOVR Monitor well, flow check, OK 20:40 - 23:30 2.83 WELLS WRKOVR POH, Stand back 4-1/2" Tbg in derrick. Break down BHA. Lay down dual scrapers. 23:30 - 00:00 0.50 WELLS WRKOVR M/U Baker Retrievmatic test packer. 10/22/2003 00:00 - 03:30 3.50 WELLS WRKOVR RIH with Baker Retrievamatictest pkr on 4-1/2" tbg. 03:30 - 04:00 0.50 WELLS WRKOVR Set Baker Packer @ 3582' MD 04:00 - 04:30 0.50 WELLS WRKOVR Pressure test 7-5/8" casing to 2500 psi. Chart test. 04:30 - 05:00 0.50 WELLS WRKOVR Bleed off test pressure. Release packer. Blow down choke. RIU to circ. 05:00 - 08:00 3.00 WELLS 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 WELCT 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 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 WELCT 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, bullheading, and circulating. Elect to pull a few stands, monitoring well closely. 14:00 - 18:30 4.50 WELLS TRIP WRKOVR LD 3 joints, POOH 5 stands. Hole took properfill 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 (J t) ConocoPhillips Alaska Page 4 of 5 Operations Summary Report Legal Well Name: 1 D-140 Common Well Name: 1D-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 10/16/2003 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 Phase Descriptionof Operations 10/22/2003 18:30 - 19:00 0.50 WELLS Held PJSM with Schlumberger E-line crew. Discussed rig up procedures and hazards associated with e-line operations. 19:00 - 22:30 3.50 WELLS WRKOVR Install bope lubricator in stack. R/U Schlumberger.M/U tool string to run USIT log. 22:30 - 00:00 1.50 WELLS WRKOVR RIH with USIT log to 3,560' ELM. Log showed ~Jood casing. Make second pass with USIT log. 10/23/2003 00:00 - 01 :30 1.50 LOG 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 WRKOVR RD Schlumberger lubricator and logging tools. LD shooting nipple. 03:00 - 04:00 1.00 WELCT WRKOVR Monitor well. Well flowing slowly. Shut well in, well built up to 10 psi. Observe well, flows slowly. 04:00 - 05:00 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 WELCT WRKOVR Shut in well and monitor for pressure build up while preparing brine in pits to bullhead well. 10 psi. 07:00 - 11 :00 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 WELCT 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 WELCT 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 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 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 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 M/U 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 DEQT WRKOVR Install cable clamp protectors and flat armor guard on ESP assembly. 06:30 - 06:45 0.25 CMPL TN DEOT 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, M/U 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 CMPLTN 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. 10/25/2003 00:00 - 01 :30 1.50 CMPL TN SOHO WRKOVR Complete running ESP completion. M/U Vetco/Gray tubing hanger. M/U 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 'I {' ( ~ ConocoPhimps Alaska Page 5 of 5 Operations Summary Report Legal Well Name: 10-140 Common Well Name: 10-140 Spud Date: 9/22/2000 Event Name: WORKOVER/RECOMP Start: 10/16/2003 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 ¿óJe Phase Description of Operations 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 SEQT 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. M/U 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 WELLS 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 WELLS 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 i~e: vves! ,.'3aK vvorKovers Subject: Re: West Sak Workovers Date: Tue, 04 Nov 2003 07:11:50 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Schwartz, Guy L" <Guy. L.Schwartz@conocophillips.com> CC: "Mooney, M" <M.Mooney@conocophillips.com>, "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> Guy, et al: ~ "; ~(~)l~.-\'~ ~ Thanks for bringing over the USIT log on 1D-140. I concur with your assessment of the log. It did not appear that there was any wall loss and a pattern suggestive of the original mill marks was evident. You also provided the report sheets for the boroscope inspections and the Schlumberger engineer's assessment of the log. You emailed me the log for 1D-110A. I agree with ConocoPhillips' proposal to eliminate the casing inspection logs in 1 D-102 and 1 D-129, subject to the assessment of the condition of the tubing and any other factors that would lead one to believe that conditions in one of these wellbores is different than the initial wells surveyed. Based on choosing what you believed were the worst case wells based on annular production time and the flow rates should have given ConocoPhillips the most conservative inspection. I will place a copy of this message in the respective well files. Please call me with any questions. Tom Maunder, PE AOGCC ~, ~'~ - \q~) % ~ "Schwa~z, Guy L" wrote: ~ ~ - ~ ~ ~ ~ > Tom, > As per our conversation today regarding the ongoing West Sak ESP workovers I wanted formally state the results and discuss further diagnostic procedures. > The wells we have completed are first 1D-140 and 1D-110A. These two wells were chosen to be the first in our set of four workovers due to the longer duration of annular flow with these > wells. It was felt that if the casing and wellhead diagnostics looked favorable that further work on the fo/lowing two wells (1D-102 and 1D-129) could be re-addressed and possibly reduced in scope. > > Results to date: > 1D-140: Borescope of the wellhead showed no wear or erosion. Inside of the wellhead and VR threads looked to be in "like new" condition. > The 7 5/8" casing was pressure tested to 2500 psi and held solid. > A USIT corrosion log was run over the entire 7 5/8" casing and showed that it was in very good condition. Milling marks were still very visible on the inside of the tubing and virtually no wall loss was seen. > > 1D-110A The borescope of the wellhead also showed the wellhead and 2" valve and VR to be in like new condition. > The 7 5/8" casing tested to 2500 psi. > USIT corrosion log showed the 7 5/8" casing to be in great shape. > As a prudent operator we are proposing we continue to pressure test the 7 5/8" casing on the remaining workover wells but discontinue the borescope and USIT log. If conditions warrant change such as corroded tubing being pulled out the remaining two wells we would of course re-look at running the USIT log. > Thanks foryour consideration, > Guy Schwartz > > Drilling and Wells Engineer > office: 907-265-6958 > AT0-1548 I of 2 11/4/2003 7:12 AI~ Mr. Guy L. Schwartz Phillips Alaska 700 G Street Anchorage, Alaska Dear Mr. Schwartz: Upon review of the Ultra Sonic Imager corrosion log on Kuparuk well 1D-140L1 dated 22- October-2003. I have come to the conclusion that the log does not show any significant signs of metal loss from corrosion or pipe wear. One interval of note is approximately 600' MD. Several of the caliper presentations show some sort of anomaly. After reviewing the casing reports this anomaly is a port collar. These port collars are used in the event that a single stage cement job does not bring cement back to surface. Other than the port collar the log shows the casing to be in very good condition in my opinion. Senior Sales Engineer Schlumberger Oilfield Services 3940 Artic Blvd, Suite 300 Anchorage, Alaska Schwartz, Guy L From: Sent: To: Cc: Subject: NSK Problem Well Supv Friday, October 17, 2003 10:09 AM AK Wells Department@PHILLIPS; NSK DHD Tech; NSK Corr DS Coord; CPF1 DS Lead Techs NSK Problem Well Supv; NSK Full Field Prod Engr; CPF1 Prod Supv 1 D-140 Boroscope Yesterday, we performed the Boroscope inspection on West Sak well 1 D-140. The 2 1/16" 5M Annular outlet bore was examined by NSK Corrosion, DHD and Vetco Gray Representatives. The internals of the casing flange, VR Profile, Tubing OD all appear to be in like new condition with no signs of erosion, pitting, or metal loss. The job was not only successful from a technical standpoint, but also from an HSE perspective with all safety/environmental issues properly addressed. Thanks to all who contributed to the preparation and performance of this inspection. Following is a detailed account of the inspection: The gate valve bore showed no evidence of erosion or corrosion. The upstream & downstream R-24 connections had sharp corners at the flange face & bore inspections. The valve seat and gate bore areas were aligned, and the carbide material of both showed no damage. The valve removal plug threads were sharp, clean, debris free and showed no wear or damage. The OD of the 4 1/2" Tubing was inspected where it was exposed to the annulus outlet bore. The tubing showed no signs of erosion, pitting, or metal loss. The intersection of the vertical and annulus outlet bore were sharp and showed no evidence of rounding. The entire annular bore, 5.6" in length, along with the 14" valve bore showed original 250 (micro mm) machine surface finish. The observation of these finishes is a positive indication of no metal loss or corrosion. Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 L4uarterly llowline inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "rtl 617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1 D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1 D-121: PTD 1971810, Sundry #302-304 1 D-127: PTD 1981090, Sundry #353-057 1 D-129: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) /i'r"~, iI Name: 3H-05 Quarterly Inspection Log.xls ,/:~~ 3H-05 Quarterly Inspection Lo.q...xls : Type'. EXCEL File (application/msexcel) I tEnc°ding: base64 ¢1~1D-102 Insp Lo.q.xls; Type: EXCEL File (application/msexcel)l Encoding: base64 ..... ,/ 1D-105 Inspection Log,x!s Type: EXCEL File (application/msexcel)i1 Encoding: base64 J J'~ 1D-110 Insp Log,xls Name: 1D-110 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding' base64 Type: EXCEL File (application/msexcel):I Encoding: base64 ] 1D-127 Inspection Log,x!s Name: 1D-127 Inspection Log.xls Type: EXCEL File (application/msexcel),,l Encoding: base64 1 of 2 3.,~O/'~1[¢~E~:i? ~ ~ ~'~ 20~3 10/6/2003 3:17 PM L4uarterly llowline inspection reports ¢/Ir~---~ 1D-129 Inspection Log.xls Name: 1D-129 Inspection Log.xls t Type: EXCEL File (application/msexcel)I Encoding: base64 ¢~t['~--~ 1D-140 Inspection Lo.q.xls Name: 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 2 of 2 10/6/2003 3:17 PM 1D-140 Special Inspection Request Log DS1D 1D-140 - 2 in. Annulus flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage Comments Inspection Locations Loss % Grade 01/06/03 6 B 0% A ., Base Line Inspection 01/09/03 6 N 0% A 1 - Day Follow-up Inspection 01/16/03 6 N 0% A 1-Week recur i.nspection , 1-Week recur inspection No RT inspection performed locations are 01/23/03 2 N 0% A buried under snow bank 01129103 6 N 0% A 1 -W'eek recur inspection 03/02/03 6 N 0% A Monthly Inspection Interval 04/01/02 6 N 0% A Monthly Inspection Interval 05/02/03 6 N___...__D2/~ ~ -",~Q~T"~ Monthly Inspection Interval 07/27/03 6---.._._~ .......... ..... 0~?~_' .-..--A"~J ~. ~.0"[~ . Quarterly Inspection Interval 3H-05 Special Inspection Request Log DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Comments Inspection Locations Loss % Grade 01/18/01 9 B 0% A Base Line Inspection 03/24/02 9 N 0% A Start quarterly inspection 07/18/02 9 N 0% A Quarterly Inspection 11/23/02 9 N 0 % A Quarterly Inspection ----~ Quarterly Inspection slight increase erosion on well house riser 0~3 ~9~ I 12% B ~ '--'--% bottom elbow 05/~3/03 9 N 12% B /) Quarterly Inspection 08/23"/[73--~....._ 9 N 12% B ,~ Quarterly Inspection - 1D-102 Special Inspection Request Log DS1 D 1D-102 - Annulus flowback inspection - flow is still through the flowline - Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Inspection Grade Comments Locations Loss % O4/O4/O2 8 B O% 04/05/02 2 N 0% 04/18/02 6 N 0% O5/O4/O2 6 N O% 05/19/02 0 0 0% 06/19/02 2 N 0% 06/24/02 6 N 0% O7/2O/02 6 N O% 08/19/02 6 N 0% O9/2O/02 6 N O% 10/19/02 6 N 0% 11/20/02 6 N 0% 12/05/02 6 N 0% 01/29/03 6 N 0% 05/02/03 6 07/27/03 6 A Base line Inspection RT/UT A No Changes A No Changes A No Changes n/a No RT or UT inspection due to Drilling Rig A No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. A No changes noted A No Changes A No Changes A No Changes A No Changes A No Changes A No Changes A No Changes Quarterly Inspection Interval Quarterly Inspection Interval 1D.'I10A Special Inspection Request Log DS1D 1D-110A -' 2 in. Annulus flowback inspection ' M o n t h I y~ _i__n S_ .p_e_c_ti_o.._n..f'_r _eq_ u e__n__c y__a p_~_r_oo v__e _d.~..p_e r__e_ ~.a~[_fr~_~a~r~_n_D o_~_S~_ ~.2.~0~ B, I, N- (B - baseline inspecti_o__n:_!.-_l_n__c_re__a_se in % wall loss, N - No cha~n_ge_fro___m_._p_r_e.v.i_o_us_i_n_s_p_e_c_tiP_n)_ .............. Date of # of Inspection B, I, N Worst Case Damage Grade Comments Inspection Locations Wall Loss % 01/18/02 4 B 0% A Baseline inspection UT Insp only NO change to UT inspection locations extablish 02/02/02 10 N 0% A baseline by RT additional inspection locations 02/10/02 5 I 12% B Possible Erosion damag_e 5 0% Damage noted on 2/10/02 inspection turned out to be variation in thickness of the fitting (geometry). 02/!3/02 N A Radiograp__h shows no damage to fitting. 03/01/02 5 N 0% A No Change 03/04/02 10 N 0% 30 day RT follow-up of inspection locations no A damage due to erosion noted on radiograph 03/08/02 5 N 0% A No Change 03/18/02 5 N 0% A No Change - 03/25/02 5 N 0% A No Change -- 10 0% 30 day RT follow-up of inspection locations no 04/01/02 N A damage due to erosion noted on radiogra_ph 04/08/02 "' 5 N 0~/o A No Change 04/15/02 5 N 0% A No Change 04~22~02 .... 5 N 0% A ............................ . _N_o_ _C_h_a__n .~_e ........................... 04/29/02 5 N 0% A No Change / Inspection to be performed monthly -- 05/28/02 5 N 0% No Change by UT - No RT performed due to A personnel safety due to drilling rig in the area 06/24/02 14 .... N-- '-~-% --A No Change by_UT or RT on inspection locations. 07/23/02 14 N 0% .__ A ... No Change by UT or RT on inspection locations. 08/24/02 0% Line shut in 8/24/02 No Inspection scheduled until further notice New well house piping configuration - New baseline 10/08/02 9 B 0% A established in well house piping. No changes in existing piping. 11/04/02 6 N 0% A No Change bY_ UT or RT on insp_e__c_tion locations. 12/05/02 6 ._. _1~ 0% A No Change by_ UT or RT on inspection locations. 01/29/03 6 N __ 0% A No Change b~,..U_?_o_r_.R...T_,_.o_n_,_iq~_.p._.e_,c_tio___n__l~..c_ation_s.__ 04/30/03 6 N _ ~ Quarterly Inspection / No Changes 07/27/03 6 N ,,.,-~ 0% ---~-~'r~-r:i~,-~'l~ection / No Chan~es 1D-121 Special Inspection Request Log DS1D 1 D-121 - 2 in, Annulus fiowback inspection - Twice Monthly inspection frequency for 2 months then review by operations to inspection frequency B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Inspection Inspection Locations 10/19/02 6 10/21/02 6 11/04/02 6 11/20/02 6 12/05/02 6 01/06/03 6 01/29/03 6 04/30/03 6 07/27/03 6 B, I, N IWorst Case J Damage Wall Loss %1 Grade B 0% A N 0% A N 0% A N 0% A N 0% A N 0% A Comments Base Line Inspection 1 - Day Follow-up Inspection 2-Week recur inspection 2-Week recur inspection 2-Week recur inspection Monthly Inspection Interval N 0% A ~. _,.,, Quarterly Inspection Interval N _ _ 0% -- -"A ~..~uarterly Inspection / No Changes ~/~---~-~--N ....... 0% ~ Quarterly Inspection / No Changes 1D-127 Special Inspection Request Log DS1D 1D-127 - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - {B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage Comments Inspection Locations Loss % Grade 03/06/03 6 B 0% A Base Line Inspection 03/11/03 6 N 0% A 1 - Day Follow-up Inspection 03/18/03 6 N 0% A 1-Week recur inspection 03/25/03 6 N 0% A 1-Week recur inspection 04/01/03 6 N 0% A 1-Week recur inspection 04/08/03 6 N 0% A 1-Week recur inspection 04/30/03 6 N 0% A.-., Monthly Inspection Interval 05/31/03 6 N 0% A_..----'""-'.-'~ Monthly Inspection Interval 08/30/03 6 N ,...~~.JA .,-;'.~,u .... Quarterly Inspection Interval 1D-129 Special Inspection Request Log DS1D 1D-129 - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage Comments Inspection Locations Loss % Grade 04/13/03 6 B 0% A Base Line Frac Inspection 04/22/03 6 N 0% A 1-Week follow-up Inspection 05/13/03 6 N _,_~ ~)A 3-Week follow-up Inspection 06/17/03 6 ~ 0% ~ A .Operations Request 09/17/03 6 f N 0°/..~-''' A Quarterly Inspection Interval 12/17/03~ ~ ... _, ~ ,¢,,/' Quarterly Inspection Interval .... Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 18-10 l~) I~,. ~ SBHP 07/21/03 1C-27 ) ~-~% TEMP/PRESS SURVEY 07/22/03 1 D-140 ~,,- ~ '~-~ (~j? SBHP 07122/03 1J-10 ~'~.,~'~T'~ [ SBHP 07/21/03 28-01 .~<~ ~1 "~-\'-.C~ PRODUCTION PROFILE .07119/03 28-02 t~- 1,~,~. PRODUCTION PROFILE 07/20/03 28-14 1 ~ ~'-~/~ PRODUCTION PROFILE 07/23/03 28-11 ~ ~.!-]_.~,~.-,~/.~ PRODUCTION PROFILE 07/18/03 3K-08 i\~,'~ -~ '(.j~ ' ~ .~'~ LDL 07125103 3M-03 j<~~ I{?, LDL 07/24/03 3S-19 .~_~.~.~,. ~ PERF/JEWELRY/& INITIAL SBHPS 07111/03 DATE: '' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConoCOPhillips Guy Schwartz Senior Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 July 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval, West Sak 1D-140 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak well 1 D-140. 1 D-140 was drilled in October 2000 as a multilateral West Sak producer. A Through Tubing Conveyed Progressive Cavity Pump (TTC PCP ) assembly was run in order to enable pump change-outs with Slickline in the event of pump failure. The motor coupling failed in December 2002 and attempts to restart the motor section failed until the well was put on gas lift in early January 2003. The ESP pump section has been pulled and a packoff (w/KOBE KO) and slipstop set in the tubing to allow gaslift through the GLM at 3467'. Gaslift has been ongoing by injection down the tubing with production up the 4 Y2" tubing by 7 5/8" casing annulus. The workover objective is to change out the existing TTC PCP pump/motor assembly and install a Through Tubing Conveyed Centrifical ESP pump assembly (TTC CESP). The actual pump section will be run on slickline after the rig has moved off location. Other goals included in the workover include assessment of the 7 5/8" casing for corrosion/erosion and integrity in regards to long term annular flow. If the casing does not pressure test or the casing inspection log (USIT) shows significant wall loss the operation will be discontinued and the well secured. If you have any questions or require any further information, please contact me at 265-6958. Sincerely, Senior Wells Engineer CPAI Drilling and Wells GLS/skad C.,ANNE ,' JUL 2 03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon E~ Alter casing E~ Change approved program E~ Suspend [] Operation Shutdown [~ Repair well r~ Plug Perforations E~ Pull Tubing E~ Perforate New Pool [-'-] Perforate ~] Variance E~ Stimulate ~ Time Extension [~] Re-enter Suspended Well ['~ Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 4. Current Well Class: Development E~ Exploratory E~ Stratigraphic E~ Service E~ 5. Permit to Drill Number: 200-136 6. APl Number: 50-029-22974-00 7. KB Elevation (ft): RKB 30' 9. Well Name and Number: 1 D-140 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 MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8117' 3772' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' S U R FAC E 407' 10-3/4" 509' 509' PRODUCTION 3517' 7-5/8" 3619' 3509' PRODUCTION 539' 7" 4158' 3740' SCREEN ASS'Y 4089' 4.5" X 4" 8117' .¢" 3772' v/' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4109'- 8117' 3733'- 3772' 4-1/2" L-80 3595' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'SCR-I' PACKER W/5.5" SL-HT BOX pkr= 4020' no SSSV no SSSV 12. Attachments: Description Summary of Proposal [] 13. Well Class after proposed work: Detailed Operations Program [~ BOP Sketch E] Exploratory [~ Development [~ Service E~ 14. Estimated Date for Commencing Operations: August 11, 2003 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil F~ Gas E] Plugged r-'] Abandoned E~ WAG r--] GINJ [] WINJ r'-] WDSPL r-"] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Guy Schwartz ,¢ Signature ~"7 -~~ Commission Use Only Contact: Title: Phone Guy Schwartz @ 265-6958 Senior Wells Engineer Date Conditions of approval: Notify Commission so that a representative may witness Plug Integrity BOP Test ~ Mechanical Integrity Test ~ Location Other: Subsequent Form Required: BY ORDER OF THE COMMISSION ul lbll lAL Form 10-403 Revised 2/2003 · JUl_ t,. ,~ 2003 f'~, ;1t ,!,i~: '" ....... Date: SUBMIT PRE-RIG WORK: West Sak 1D-140 GENERAL WORKOVER PROCEDURE 1. 5-7 days before RWO, RU Slick Line Unit. RIH and pull HFCV from GLM @ 3984' leaving an open pocket. 2. Kill well by pumping down tubing, taking returns up the annulus. 10.5 ppg KWF is expected. 3. Set BPV in tubing and VR plug in annulus valve. 4. Prepare Location for Nabors 3S: Remove well house(s), check tubing hanger LDS's, Test tubing and casing packoffs. GENERAL WORKOVER PROCEDURE: 1. MIRU Nabors 3S. Lay hard-line to tree. 2. Verify if well is dead. If not circulate well with appropriate KWF based on surface pressure. Install BPV. 3. ND tree/NU BOPE. Function test BOPE. Pull BPV. Install test plug. 4. Test BOPE to 4000 psi. Pull test plug. 5. Screw in landing joint ( 4.909 MCA thread connection ). POOH standing back 4-1/2" tubing and spooling up ESP Cable and Heat Trace (BOT gauge wire is embedded in the power cable).?,,o~Q3~ ~3crc qt.t,xc~,,,q,,q,,~ 6. Load, strap and drift 3-1/2" drill pipe. RIH with retrievable bridge plug, set at 4~l,00~t and release from plug. Cover with 10' of sand. Test casing to 2500 psi for 30 min. POOH standing b3ck 3 ½ drill pipe. 7. RIH w/RBP latch, cleanout/casing scraper assembly. 8. Cleanout (reserving out) to 4100', relatch packer and release. POOH laying down 3-1/2" drill pipe. 9. PU and RIH w/Eline USIT casing inspection log. 10. RIH w/4-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable. 11. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 12. ND BOPE/NU Tree/Test. 13. Freeze protect with diesel to +/- 2000' TVD. Set BPV. RDMO workover rig. Lower Limit: 4.0 days Expected Case: 5.0 days Upper Limit: 7.0 days No problems encountered. Problems pulling ESP completion, Space out problems and control line issues. GLS 6/1/03 (0-110, OD:16.000, Wt151.50) TUBING (0-3595, 0D:4.500, ID:3.958) GE.:,.'~? 3X ~ 0r,. 5 il.Z)' (4C£2-.'.:.'21 OD 6:5?) ConocoPhiltips Alaska, Inc, KRU 1D-140 1D-140 PROD APl: SSSV Type: NONE Annular Fluid: Reference Lo, Last Ta PRODUCTION SURFACE CONDUCTOR PRODUCTION CSG WINDOW Well Type:' Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: COMMON CASING STRING Size Top 7.625 0 10.750 0 16.000 0 7.000 3619 6.151 3668 LOWER LATERAL LINER Size Top LINER 4.000 4020 DUAL SCREEN LNR 4.000 4109 10/12/2000 8117 ftKB 93 deg ~ 4455 Angle @ TS: Angle @ TD: Rev Reason: Last Update: deg ~ 90 deg @ 8117 Pull packoff, slipstop & pump, set OV & plug 1/7/2003 IBottom I TVDI Wt I Grade I Thread 3619 I 3509 126.001 L-80 I BTC-MOD 509 I 509 140.501 J-SS IBTC 11o I 11o 1151.5Ol x-65 I WELD 4158 I 3740 j 26.00 L-80 I BTC-MOD 1D-141L1 Bottom I TVO J Wt I Graae J Thread 4109 I 3733 19.50 I L-80 I HSLHT 8117 I 8117 19.50 i L-80 I HSLHT ;:TUBING;: : Size B°tt°m I TvD I wt IGrade I Thread 4.500 0 3595 3492 I 12.60 I L-80 I NSCT Pe~orati~nssumma~: : :: : : ::;: : :: ; ;: !:::;:: :;: : Interval TVD I Zone I Status/Ft SPF Date 1Type I Comment 4109-8117 I 3733-8117 I WSB,WSI ~40081 50 110/12/2000~ScreenslPerfs thru screens C WS I /11 / I G~S:Eift Ma:nd:r~l~lVal~s:: : : : :: :::: : :: ::::;:: ::: ::; viv Cmnt Description ID 0.000 CABLE 'Chem Heat Trace Cable PACKOFF BULL PLUGGED PACKOFF set 12/26/2002 NIP Centrilift 4.5" Slotted Nipple SEAL Centrilift Seal Section GST3 DB iL H6 PFS GEARBOX Centrilift 9:1 525 Series Gearbox MOTOR Centrilift PCESP Motor 57 HP 1315/26 KMH Centeralizer Centralizer w/Baker Sentry Gauge {¥ Description PKR Baker 'SCR-I' Packer w/5.5" SL-HT Box 0.000 0,000 0.000 0.000 0.000 0.000 ID 4.000 Note Baker 4.5" CMD Sliding Sleeve 3.437 NOTE: This is a multilateral well. This schematic represents the 'B' sand lower lateral. See schematic for 1D-140L1 for the 'D' sand upper lateral. (~uarterly Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "rtl 617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1D-121: PTD 1971810, Sundry #302-304 1D-127: PTD 1981090, Sundry #353-057 1D-129: PTD 1972130, Sundry #303-092 ID-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) Name: 3H-05 Quarterly Inspection Log:xls ~.~3H-05 Quarterly Inspection Lo,q.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~r~ 1D-102 Insp Lo.q.xls Name: 1D-102 Insp Log.xls '1 Type: EXCEL File (application/msexcel)~ Encoding: base64 I~" Name: 1D-105 Inspection Log.xls ~L~ 1D-105 Inspection Log.xls Type: EXCEL File (application/msexcel) · , ; Name: 1D-110 Insp Log.xls I ~ 1D-110 Insp L°'q:xlst~ Encoding:Type: base64EXCEL File (application/msexcel) ~1D-121 Inspection Loq.xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 "JUL .t. 6 200,3 1 of 2 7/14/2003 10:39 AM 1D-140 Special Inspection Request Log DS1D 1D-140 L~)t~ ._ ~-~ ~ - 2 in. Annulus flowback inspection · - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage Comments Inspection Locations Loss % Grade 01/06/03 6 B 0% A Base Line Inspection , 01/09/03 6 N 0% A, , 1 -Day Follow-up Inspection 01/16/03 6 N 0% A 1-Week recur inspection 1-Week recur inspection No RT inspection performed locations are 01/23/03 2 N 0% A buried under snow bank 01/29/03 6 N 0% A 1 -Week recur inspection 03/02/03 6 N 0% A Monthly Inspection Interval 04/01/02 6 N 0% A Monthly Inspection Interval 05/02/03 6 N 0% A , Monthly Inspection Interval Quarterly Inspection Interval , , , , , , ,, Quarterly Flowline line inspections I Name: 1D-127 Inspection Log.xls ~1D-127 Inspection Loq.xlsi Type: EXCEL File (application/msexcel) ................................................................................................................ ....................................................................................................... ~1D-129 Inspection Loq.xls Name: 1D-129 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 'I ~ 1D-140 Inspection Loq.xls I Name: 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) l Encoding: base64 J 2 of 2 7/14/2003 10:39 AM Permit to Drill 2001360 MD 8117" TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. KUPARUK RIV U WSAK 1D-140 Operator CONOCOPHILLIPS ALASKA INC 3772 ----- Completion Dat 10/31/2000 ~-- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22974~0-00 UlC N REQUIRED INFORMATION Mud Log No Sample No Directi°nal Survey__ __~'~_ _ _7_~.___' .... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret L L D D C C C C L L Name Interval Start Stop (data taken from Logs Portion of Master Well Data Maint OH I Dataset CH Received Number Comments ED ED ED ED R R L R D C D R R RS Reservoir Saturation RS Reservoir Saturation RS Reservoir Saturation RS R R L R D C D R R Reservoir Saturation ,.,~~og Log Run cale Media No RST Sigma 5 FINAL 10337 --- FI NAL 10368 ~ G ~,~ ~{~, FINAL 10369 ~"- t,0~'~ FINAL . ~ 5 FINAL Survey Report ~ Survey Report ~ FBHP/TEMP Profile 10239 10259~''/ 1033.y/ ...l,IS-'~rification -aS~rTfica~on 2/5 FI NAL FINAL FINAL FINAL FI NAL FINAL FINAL 500 502 502 502 20 502 20 496 1600 502 502 502 1565 80 5O2 502 5O2 502 3510 8O72 8072 6113 3510 7597 3510 3502 3510 7604 6106 8072 3514 35OO 7604 6106 6106 8072 ch OH OH OH ch Open Case Case Case Open Open Open Case CH oh oh CH oh oh OH 10126/2001 9/2712001 10/4/2001 10/4/2001 10/26/2001 8/9/2001 11/13/2001 8/16/2001 9/27/2001 9/27/2001 2/19/2002 1/9/2001 1/9/2001 6/15/2001 8/13/2001 8/13~2001 8/20/2001 9/2712001 9/27/2001 9/27/2001 500-3510 BL, Sepia 10337,~02-8072 Digital data 10368-/5502-8072 Digital Data 10369 '~2-6113 Digital Data 20-3510 BL, Sepia 10239~502-7597 10429 ~,,,"r.~., 10400 ~ 10399 .~ ~L 10259 ~..~2-7604 10334 ~02-6106 10337'~02-8072 Survey Report Paper Copy Survey Report Paper Copy 80-3500 BL, Sepia Lis Verification Paper Copy 10239/.~is Verification Digital Data 10259~'{~'2-7604 DIGITAL DATA 10334 ~"5"'02-6106 Digital Data i~ I~ ( 502-6106 LIS Verification 502-8072 LIS Verification Permit to Drill MD 8117 2001360 DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. KUPARUK RIV U WSAK ID-140 TVD 3772 Completion Dat 10/31/2000 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-22974-00-00 ED C RS Reservoir Saturation Lo RS Reservoir Saturation ED C RS Reservoir Saturation Lo RS Reservoir Saturation Lo Pre Pressure Lo Te Temperature Completion Statu 1-OIL Current Status 1-OIL UIC N 1 r'"'- 1500 3494 Case 8/9/2002 10995 u," 5. Blu 1~''''''~' 1500 3494 Case 8/9/2002 1~ 1738 3541 Case 10/1/2002 5 Blu 'f"' 1738 3541 Case 10/1/2002 5 Blu I 1738 3541 Case 10/1/2002 5 Blu 1 1738 3541 Case 1011/2002 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y [~ Chips Received? ~ Analysis ~ R ~.c~.ive. cl? Daily History Received? ~/N Formation Tops (~ / N Comments: Compliance Reviewed By: ConoCOPhillips Alaska PO Box 100360 Anchorage, Alaska 995 l0 December 8, 2002 Mr. Tom Maunder' Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notice variance reqUests for ConocoPhillips Alaska, Inc., West Sak wells 1D-110A and ID-140. The variance request for 1D-140 is to initiate gaslift on a failed ESP well. The variance request for 1D-110A is for an extension. Also attached are discussions and well Schematics. Please 'call Pete Nezatieky or me at 907-659-7224 if you have any questions. Sincerely, ConocoPhillips Problem Well Supervisor Attachments OR ® N'AL RECeiVED 2002 ~aska Oil & Gas ~n~. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 5128' FNL, 595' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 392' FNL, 542' FEL, Sec. 14, T11N, R10E, UM 5. Type of Well: Development mX Exploratory __ Stratigraphic m Sewice__ (asp's 560491, 5959814) (asp's 560502, 5964550) 6. Datum elevation (DF or KB feet) RKB 102 feet 7. Unit or Property name West Sak Oil Pool 8. Well number 1D-140 9. Permitnumber/approvalnumber 200-136 10. APInumber 50-029-22974 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 110' 16" SURFACE 407' 10-3/4" PRODUCTION 3517' 7-5/8" PRODUCTION 539' 7" Liner 4097' 4 Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 8117 3772 feet Plugs (measured) feet feet Junk (measured) feet Cemented 135 sx AS I 110 sx ArtiCrete 410 sx AS III Lite, 380 sx Class G see above 40 bbls Class G No Perfs - Pre pack screens in horizontal laterals 4-1/2", 12.6#, L-80 Tbg @ 3595' MD. BAKER 'SCR-I' PACKER W/5.5" SL-HT BOX @ 4020' MD. @ 'MD. Measured Depth 110' 509' 3619' 4158' 4109' True vertical Depth 110' 509' 3509' 3740' 3733' RECEIVED DE 2002 Nasla 0il & Gas Gons. Commission Anchorage 13. Attachments Description summary of proposal 14. Estimated date for~encin~q operation Decembe~ 1_~,~,2.002 ', 16. If proposal w~'~rbally approved _X Detailed operations program BOP sketch Name of approver Date approved 15. Status of well classification as: Oil __X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ C ~)~ Title: Problem Well Supervisor Jera~/'C. Dethlefs _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test m ,~chanical Integrity Test --~ Approved by order of the Commission Questions? Call Jerry Dethlefs 659-7224 Date J~/~~ Location clearance_ 10- qO q ~.~D~ --~'~ ~7~- Subsequent form requimd Commissioner Date ~~~~ Form 10-403 Rev 06/15/88 · ORIGINAL SIGNED ElY M L. Bil~ 2O02 SUBMIT IN TRIPLICATE ConocoPhiilips Alaska, Inc. West Sak Well 1D-140 SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/08/02 The purpose of this Sundry Notice is for approval to temporarily gaslift West Sak producer ID- 140 that is completed as an ESP (electric submersible pump) well. The ESP has failed apda workover is required to pull and replace the ESP, and is expected to occur during 2003( The well makes approximately 950 bopd via ESP, a majority of which may be possible to produce on r. gaslift. Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate will be 600-800 mcfd. ~'~' Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 700-800 BOPD. The basic gaslift and production facilities layout for ID-140 (under construction) will be identical to the current 1D-110A and 1D-102 layout. Phillips has presently started fabrication and will install a new 3" annulus flowline on 1D-140 to replace the existing 2" flowline prior to/ production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design is being implemented for 1D-110A and 1D-102 as a pro-active measure, even though there was no indication of active '/. erosion in the 2" line that was on well 1D-110A.) Velocity calculations have been done with maximum anticipated flow rates of 1000 BLPD and total GLR of 600 scf/stb up,~the~nulus~,,,~ and through the 3" annular flow line. Production is approximatelvt~30~PSIG. The maximum velocity through the NPS 3" sch 160 A333 pressure Gr6 line will be 18 ft/s.~t/'"'"'~(r~~ There have been five (15) solids s_~keouts on well 1D-140 since September 2001 and they range from 0.01% to 0.15% by volume. ConoeoPhillips intends to take production shakeouts both initially and periodically to monitor future performance. Below is a table of recent well test information. / Future Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows: Perform inspections weekly for the first month. Perform inspections monthly for the next two months. Perforr)a inspections quarterly thereafter. Submit inspections on a quarterly basis to the AOGCC. / As an extra safety feature, a valve handle to the IA API valve has been extended outside the ] wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. ConocoPhillips proposes that the AOGCC approve this request for a time period not to exceed 12 months from the approval date. If a workover is not completed within that time period, the AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. Well Test FTP WHT Oil Water WC Total Total Total ESPSpeed Name Date PSIG De~l F BOPD BWPD % Gas mcfd GOR GLR Hertz 1 D-140 10/30/2002 15:10 332 68 949 200 17 101 106 88 38.7 1 D-140 10/12/2002 6:44 285 73 944 187 17 114 120 101 38.7 1 D-140 10/1/2002 6:00 310 74 947 168 15 108 114 97 38.7 1D-140 9/18/2002 15:00 281 73 917 165 15 135 147 125 38.7 1 D-140 9/6/2002 5:24 288 73 911 156 15 173 190 162 38.7 1 D-140 8/26/2002 15:45 282 72 907 139 13 192 212 184 38.7 1D-140 8/13/2002 18:10 287 70 890 102 10 203 229 205 38.7 1D-140 8/5/2002 15:00 290 68 871 83 9 206 236 216 38.7 1D-140 7/25/2002 15:30 280 67 848 77 8 194 229 210 38.7 ID-140 WEST SAK WELLHEAD AND PIPING DESIGN LIFT GAS CHECK VALVE SET @ 500 PSI EXTRA THICK I SET @ 70 PSI WALLED 3" TEE BLIN~FLANGE / i~PiLOT SWiTCHI .,/ ssv '11 2" TO 3" X-OVER I ONDUCTOR (0-110, 01~.16.000, W~151.50) TUBING OD:4.500, ID:3.958) NIP 0D:4.500) SEAL (3566,3567, 0D:5.130) GEARBOX (3580,3,581, 0D:5.620) MOTOR 0D:6.250) Centeralizer (3588.35~, 0D:6.250) ~ ConocoPhi!lips Alaska, Inc. KRU 1D-140 1D-140 APl: 500292297400 SSSV Type: NONE Annular Fluid: Well Type:I PROD Orig J 10112/2000 Completion:I Last W/O: I Ref Log Date:J TD:18117 ftKB Max Hole Angle:J93 deg (~ 4455 COMMON CASING STRING SizeI Top I Bottom I TVD I wt I G~del CONDUCTOR 16.000 I 0 I 110 I 110 1151.501 X~S I SURFACE ; 10.750I 0 I s09 I 509 140.501 J-55 I PRODUCTION 7.625 I 0 13619 ) 3509 I 26.00 I L-B0 I PRODUCTION 7.00O I 3619 I 415S I 374O 126.001 L-SO I LOWER LATERAL LINER LINER DUAL SCREEN LNR '- TUBING . Size 4.500 0 Interval TVD 4109-8117 3733-8117 Bottom I TVD 3595 3492 Angle (~ TS:I deg @ /~gle @ TD:J90 deg @ 8117 I Rev Reason:JSet ESP, OV by Last Update:l 11121/2002 I i wt iGrada i 12.60I g-80 I Thread WELD UTC UTC-MOD UTC-MOD to 1D-141L1 Thread HSLHT HSLHT Thread NSCT ..... Comment Perfs thru screens CABLE PUMP Description Trace Cable (3000' long) CENTRILIFT ESP PUMP SET 11111102 WI4.5"SLIPSTOP & PACKOFF SET 11/1312002 NIP Centrilift 4.5" Slotted Nipple . SEAL Centrilift Seal Section GST3 DB IL H6 PFS ID 0.000 0.000 0.000 0.000 GEARBOX Centrilift 9:1 525 Series Gearbox 0.000 MOTOR Centrilift PCESP Motor 57 HP 1315/26 KMH 0.000 Centeralizer Centrilift Centralizer w/Baker Sentr~ Gauge ~i;. '.::!~:.;: i?;~ ~F!F~ :';.i;.. ::.':: '~: :~-.:,'.!:: 0.000 Description ID PKR Baker 'SCR-I' Packer w/5.5" SL-HT Box 4.000 SLEEVE CMD Sleeve 3.437 Note NOTE: This is a multilateral well. This schematic represents the 'B' sand lower lateral. See schematic for 1D-140L1 for the 'D' sand upper lateral. LINER (4020-4109, OD:4.000, Wt:9.50) 09~30~02 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2452 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 Sepia CD Color 1 D-140 22412 RST-SIGMA 081t3/02 1 1 RECEIVED DATE: OCT 0 1 ZOOZ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. NalkeO~ &GmCons.~ Scbbanberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2290 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 Sepia CD Color 2A-01A J ~¥.-'~)~'7 INJECTION PROFILE 07/t3102 1R-15 /~',.~.--/~,~ INJECTION PROFILE 011'!0102 ID-12$A ~:~O O-O ~ INJECTION PROFILE 07118102 2X-01 1 ~'5'"O~ INJECTION PROFILE 07111102 1D-114 j c~,_/,~ INJECTION PROFILE 07114102 ID-130 ICt7..i~'~5 INJECTION PROFILE 07/18/02 1D-101 :~O/::)""/~',:.,~ INJECTION PROFILE 07/14/02 1D-122 / (~.~.../t../? INJECTION PROFILE 07/t7/02 2D-0S l ~-/o~/~ INJECTION PROFILE 07/t2/02 1D-140 ~-/.~(= 22291 RST-SIGMA 05/07102 08/06/02 DATE: RECEIVED AUG 0 9 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. AlaakeOil&GasCons.~n Anchorage 02/19/02 Scklumkerger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1820 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 Sepia CD Color 3H-15 INJECTION PROFILE 02/01/02 I 1 1D-140 22066 RST-SIGMA 01/06102 I I 1 1L-20A 22054 SCMT 01/28/02 1 1C-24 22055 USIT 01/20/02 1 1C-24 22055 SSLT 01/20/02 1 2P-415 21488 BEST DT-SONIC PROCESSING 11/24/01 1 2P-415 21488 ELAN GLOBAL SOLVER ('FVD) 11/24/01 1 2P-415 21488 FRACADE ADVISOR MECH PROPERTIES ('I'VD) 11/24/01 1 2P-417 21243 ELAN ELEMENTAL ANALYSIS 05/12/01 1 2P-417 21243 FRACADE ADVISOR MECH PROPERTIES 05/12/01 1 DATE: RECEIVED FEB 2002 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. -Sc#_.ium. ber Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1608 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 Sepia CD Color lC-131 21466 SCMT 10119/01 1 1D-.140 (REDO) 21414 RST 09109101 I 11/8/2001 RECEIVED DATE; ~ ~r~ ~ . _ r~Aa4 I~UV I ,~ ~uut Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8311&~llk~i~iJ~l~S COILS. C0mm~i0n knct~age Scbimberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1639 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite t00 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1L-26A ~DI...~I" ; LEAK DETECTION LOG ~/' 09124101 1 1 1R-13 J~5-'1.5~ INJECTION PROFILE t/ 09124101 1 1 3K-19 o~O/--/O~/ 21361 SCMT ~ 07117101 1 1D-121 Jc)").-i~} 21403 RST 1 D-140 ~,~0-/.'~ 21404 RST V/ 09109101 I I 1 1 D-140 21379 RST ,/ 08115101 I I 1 .. I~1::~1:::, V r-L) _,,, OCT 2 6 2001 -Alaska Oil & Gas Cons. Commi~i0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank 10/16/2001 (, WELL LOG TRANSMITTAL To: October 01, 2001 The technical data listed below is being submitted herewith. concems to the attention off State of Alaska 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. Commi~ion WELL LOG TRANSMITTAL To; State of Alaska Alaska Oil and Gas Conservation Co. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 21, 2001 RE: MWD Formation Evaluation Logs; Redo ID-140, AK-MM-00202 1 LDWG formatted Disc with verification listing. API#: 50-029-22974-00 PLEASE ACKlgOWLEDGE RECEIPT BY SIGNII'4G AND RETURNING A COPY OF TIlE TRANSMITTAL LETTER TO ~ ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED S£P 2 7 200! Alaska Oil & Gas Cons. Commission Anchorage WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Co. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 21, 2001 RE: MWD Formation Evaluation Logs Redo ID-140 PB 1 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 ~ ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: WELL LOG TRANSMITTAL To: State of Alaska August 16, 2001 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 L1PB1, AK-MM-00202 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 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 AUG 70 001 Alaska Oil & Gas Cons. CommJssio~ Anchorage WELL LOG TRANSMrrTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 09, 2001 MWD Formation Evaluation Logs 1 D- 140, AK-MM-00202 1 LDWG formatted Disc with verification listing. APl#: 50-029-22974-00 PLEASE ACKNOWI~DGE RECEIPT BY SIGNISIG AND RET[rR_NING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: sign~~ RECEIVED 1 2.001 ~a Oi/~, Oas Cons. C~n' t ',, PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 December 14, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1D-140 and 1D-140ML (200-136 & 200-146) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Reports for the drilling operations on multilateral wells 1D-140 and 1D-140ML. If you have any questions regarding this matter, please contact me at 265-6434 or Steve McKeever at 265-6826. Sincerely, J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad RECEIVED DEC 1 5 7tiff0 Oil & Gas C(ms. Comm'msio~ STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas D Suspended r-~ Abandoned D Service D 2. Name of Operator ,~,,tllt-jl~ 7. Permit Number Phillips Alaska, Inc. ¥1~ 200-136 , 3. Address .~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ l; 50-029-22974-00 · 4. Location of well at surface 9. Unit or Lease Name 149' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM (ASP: 560491, 5959814) ':~.~ ?')"'" .... :' '''''=' = Kuparuk River Unit At Top Producing Interval ~ ":" .... 10. Well Number , .. !.o_. -: .~/: 863' FSL, 400' FEL, Sec. 14, T11N, R10E, UM (ASP: 560680, 5960331) .. ..'. ., 1D-140 At Total Depth .. . ~,~ ...... ' 11. Field and Pool 396' FNL~ 541' FEL, Sec. 14, T11 N, R10E, UM (ASP: 560502, 5964550) .............. 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 & 25649 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions September 22, 2000 October 4, 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 8117' MD/3772,TVD 8117' MD/3772'TVD YES [~] No DI N/A feet MD 1642' 22. Type Electric or Other Logs Run GR/PWD, GPJRes 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD I CASING SIZE WTm PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD i ,ou,~ 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 ArfiCrete 7-5/8' X 7' 29.7# / 26# L-80 Surface 4158' 9.875' 410 sx AS III Lite, 380 sx Class G 4.5"x4" 12.6#/9.5# L-80 4028' 8117' 6' screanassembly ~ I'~ I ~ , u ! b iL. , 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING' RECORD intewal, 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 ;i- IV 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ~ 0il & Gas c,..,orl~. November 16, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 11/27/2000 6 hrs Test Period > 617 103 12 110I 167 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) piss. 331 ps not available 24-Hour Rate > 174 22 3 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include intewal tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 3870' 3658' West Sak A3 8117' 3772' Base West Sak Sand 8117' 3772' Annulus left open - freeze protected with diesel. RECEIVED DEC 1 5 31. LIST OF ATTACHMENTS P, la~a ~Jn ~x wa= ,., ................ Summary of Daily Operations, Directional Survey Allchorage 32. I he .ruby certify that the following is tree and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826 James Trantham Prepared by Sharon AIIsup-Dral~e 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. Item 28: If no cores taken, indicate "none'. Form 10-407 Date: 11/29/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-140 ML STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SA/( 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) MW: 8.9 VISC: 120 PV/YP: 34/41 APIWL:' 6.2 TD/TVD: 637/637 (117) DRILLING.9 7/8" HOLE SUPV: . . 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 c. asing..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" h01e'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:Directiona'lly. drill 19-7/8" 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: 34/31APIWL: 3.5 TD/TVD: 4165/3735 (526) RUNNING HOLE OPF~ER & REAMER @ 1800'. SUPV:M.C. HEIM RIH to 3639'. Drilling and surveys from 3639' to 4165', checking for flow. CBU. POH. 09/27/00 (DT) 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/BHA%3. 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 (D8) 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 250/3000#. 09/29/00 (D9) MW: 0.0 VISC: '65 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 4368/3738' (203) DRLG. & SURVEYS ~ 4611 MD-3739 TVD. ' SUPV: M ~ C. HEIM ' RIH. Tag ~ 4067', drill wiper plug, .lc, cement, shoe and clean out to 4165'. Drilling from 4165' to 4185". Pump sweep and displace LSND mud with Baradrill. Perform FIT, 11.5#. POH for. repairs to ABI or MWD.' RIH, CBU for FIT. perform FIT, EMW 11.5%. 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 ' attempting to - . Drilling and surveys from 5618' to '5877', find top of. sand after drilling into fault. 1'0/02'/.00 (D12) MW: ' 9.8 VISC: 55 PV/YP: 10/21 APIWLt 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 ~1. Trenching from '5443' to 5493'. Drilling' and 'surveys from 5493' to. ' 5930 ' . .RECEIVED DEC 1.'5, zOoo AJaska Oil &. Gas ConS. (' 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:DONALD WESTER 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 t° 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: 8117/377.2 (1250) TD'D ~ 8117' POOH FOR REAMER HOLE OPENER RUN SUPV:DONALDWESTER RIH with 3.5" HWDP to.6867'. 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 52'47', 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) MW: 9.8 VISC: TD/TVD: 8117/3772 (' 0) PUMPING CAUSTIC WASH SUPV:DONALDWESTER '1010.710'0 (D17) TD/TVD:. 811'7/3772 ( SUPV:DONALD WESTER 0 PV/¥P:. 0/ 0 APIWL: 0.0 Continue to ream lower lateral.6" hole from 7096' t° 8117' with BHA ~7, harc calcite stringers. Circulate load'MI clear brine. PJSM. Start sweeps and Circ. RI'H to 8117~i. CBU oil. cut. mud on bottoms up. POOH to shoe ~ 4158".RIH with .scraper.assembly to.3580'. MW: 9.8 VISC': 0 Pv/YP:. 0/. 0. APIWL:. 0.0. 0). RUN LINER STOPED ~ 6147' ' 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: 4 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 %25 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. .lO/O9/OO (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 5'640'. RIH to 8117'. Circulate and work, string reamer from 5460' to 5550'. POOH. pump'out due to 'swabbing. i0/10/00 (D20) MW~' 9'.9 VISC:' 0 PV/YP:. '0/.0 TD/TVD:' 8117/3772 (' .0) ATTEMPTING TO RELEASE.FROM PACKER.' SUPV:M.C. HEIM 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)" MWi 9.9 VISC:. 0'PV/YP: 0/. 0 APIWL: 0.0 TD/TVD: 8117/3.772 ( 0) POH WASHING SCREENS W/ ACID. SUPV:M.C..HEIM 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/¥P: 0/ 0 API'wL: 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 1500~, 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, 12~. 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'. 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 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 62.86" 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 ppgl .Pumplout .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 bybrine 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 (D3i) 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'%19 WASH OVER ASS¥. TO RETRIEVE SPERRY-SUNWHI 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. ' ' RIH tag'up @ 3679'. clean out cement from transition jt3679' to 3695'. POOH. 1'0/24'/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 ~ 3.678', 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 250/3000%.. RIh 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) TD/TVD: 7663/3718 SUPV:M.C. HEIM 10/29/0.0 (D39) TD/TVD: 7663/3718 ( suPV:M.C. HEIM MW: 9.9 VISC: '0 PV/YP: 0/ 0 0) sERVIcING RIG-CREW CHANGE APIWL: 0.0 PJSM~ Displace well w/clean brine. Spot acid. PJSM. POH .pumping 'acid thru each screen. Shift sliding.sleeve shut & circ hole'clean. POH. MW: .9.9 rISC': 0 Pv/YP: 0/ 0 APIWL: .0.0 0) RUNNING COMPLETION ,, . . 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:DONWESTER 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-140PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 6,156.00' 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-140PB1 Job No. AKMMO0202, Surveyed: 2 October, 2000 SURVEY REPORT 13 November, 2000 -. " Your Ref: API.500292297470 Surface CoOrdinates: 5959813.97. N, 560490.55 E ('/0" 18' 02.7841" N, 210' 29' 23.7396" E) Kelly Bushing: 101.50ft above Mean Sea Level OlliI_I~IN Il B ! RV I f" ill ~li A Halliburton Cmpeny . Survey Ref: ;vy9$EE Sperry'Sun .Drilling Services Survey Report for 1D-140 Your Ref: API,500292297470 Job No. AKMMO0202, Surveyed: 2 October, 2000 North Slope. Alaska. Measured Depth- Incl. (fi) ,. AZim, Sub-Sea' Depth. (ft) Vertical - Depth (ft). Local 'Coordinates Northings Eaetinge (ft) (ft)' Global Coordinates Northinge Eeetinge (ft) (ft). Dogleg Rate (°/lOOft) Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1D. 140PGSS '- 0.00 120.00 172.00 266.00 358.00 ..451.00 477.00 1D-140PB1 548.34 640.91 · - 734.26 825.66 917.26 1008.96 1102.0o 1193.43 '1288.13 1384.36 0.000' 0.340 0.500 0.750 '0.300 0.600- 0.750 o.i3o 2.63O 3.010 4.330 - 6.490 ~9.010 8.000 7.930- 6.170 5.670 0.000 240~000 240.000 276.000 176.000 179.000 - 233.000 37~6g0 64.700 100.290 113.280 1'i0.860 111.420 114.390 105.250 105.400 -101.50.- 18.50 70.50 164.49 256.49 349.49 '375.49 446.82 539.36 .632.60 723.82 815.01 905.86 997.88 1088.43 1182.41 1278,13 0.00 120.00 172.00' -265.99 357.99 --450.99 476.99 ~48.32 640.86 734.10 825.32 916.51 1007.36 1099.38 ' 1189.93 . 1283.91 1379J63 0.00 N 0.18 $ 0.37 S 0.51 S -0.69 S 1.42 S 1.65 S 1.87 $ 0.39 S 2.06 N 2.47 N- 0.20 S 4.80 S' 9.76 S 14.69 S 18.73 S 21.35 S 0.00 E 5959813.97 N 560490.55 E 0.31 W 5959813.79 N 560490.24 E 0.64 W 5959813.60 N 560489.91 E 1.61 W .5959813.45 N 560488.95 E 2.19 W 5959813.27 N 560488.37 E 2.16 W 5959812.54 N 560488.40 E 2.30 W 5959812.30 N 560488.27 E 0.28 0.31 0.48 0.93 0.32 2.41 2.62 W 5959812.08 N 560487.95 E 1.23 0.95 W 5959813.57 N 560489.60 E 2.70 2.88 E '5959816.05 N 560493.41 E 0.92 8.45 E 5959816.51 N 560498.98 E 2.81 16.60 E 5959813.91 N 560507.16 E 2.70 28.08 E 40.91 E 52.58 E 63.44 E 73.01 E 5959809.39N 560518.66 E 5959804.54 N 560531.54 E 5959790.70N 560543.25E 5959795.76N 563554.14 E 5959793.21N 560563.73E 2.77 1.09 0.46 2.20 0.52 0.00 -0.18 -0.37 -0.51 -0.69 -1.42 -1.66 -1.87 -0.40 2.06 2.47 -0.19 -4.78 -9.73 -14.65 -18.68 -21.30 AK-2 BP_CG AK-6 BP_IFR-AK Continued... 13 November, 2000- 14:20 . . -2- DrlllQueet 2.00.05 North Slope Alaska Measured Depth (~t) 148i.54 1577.04 1673.34- 1768.92 i865.47 1961.03 '2057.93 2153.25 2250.39 2346.54 .Incl. Azim~- 5.340 112.150 4.270 111.330 3.040 !14.680 0.170 343.340 0.900 318.950 0.870 320.300 0.890 ' 3!8.040 '1.320". 316.350 1.53O 326.72O 0.330 123.950 2442.28 1.260 2539.31' 0.670 2636.35 0.990 2732.57 0.140 2798.55 1.880' 113.890 '93.040 89.210 192.020 8.320 2827.96 3.990 2860.30 6.170 2894.62 7.820 . 2923.73 8.880 295~10 10.810 2988.94. 12.690 3020.19 13.940 3053.22 15.850 . 3084.91 17.930 · 3116.69 20.140 12.520 9.300 10.730 9.880 9.540 9.350 9.520 .9.890 8.590- 7.350 Sub-Sea Depth (fi) 1374.86 1470.02 1566.13 1661.66 1758.21 1853.76 1950.65 2045.95 . 2143.06 2239.20 2334.93 2431.94 .2528.97 2625.19 2691.16 2720.53 2752.74 -2786.80 2815.60 2848~48 2879.65 2910.06 2941.98 2972.3O -3002.34 Sperry-Sun D illin g .Services Survey. Report for 1D-140 Your Ref: API-500292297470 Job No. AKMMO0202, 'Surveyed: 2 October, 2000 -Vertical .DePth' (ft) 1476.36 1571.52 1667.63 1763.16 1859.71 1955.26 2052.15 2147~45 2244.56 2340.70 2436.43 2533.44 2630.47- 2726.69 2792.66 2822.03 2854.24 2888.30 .2917.10 2949~98 2981.15 3011.56 3043.48 3O73.80 3103.84 Local Coordinates Northinga (ft) 24.33 27.30 29.67 30.59 29.88 .. 28.76 27.63 26.29 24.39 23.47 Global Coordinates Eastinga Northinge Eastings (~). (~) (~) 81.83E 5959790.30 N 560572.57 E 89.26E 5959787.39 N .560580.02E 94.92E 5959785.07N 560585.70E 97.18 E 5959784.16 N 560587.97E 96.64E 5959784.87N 560587.43E 24.05 $ 24.52 8 24,54 S- 24.64S - 23.65 S 95.68 E 5959785.98 N 94.71E 5959787.10 N 93.46 E 5959788.44 N 91.97E 5959790.32N 91.50 E 5959791.23N 22.17 S' 19.36 S 15.24 $ 11.08 S 5.46 S 0.94 N. 8.04 N. 16.40 N 25.49 N 35.76 N' 92.69E 5959790.66 N 94.23E- 5959790:21N 95.64E 5959790.21N 96.44E 5959790.11N 96.58 E 5959791.10 N 96.88 E 97.40E 98.13 E 98.89 E 99.85.E 102.09 E 103.52 E 105.00 E 103.43 E 560586.46 E 560585.48 E 560584.22 E 560582.72 E 560582.24 E 5959792.58 N 5959795.40N 5959799.52 N 5959803.68 N 5959809.32N 5959815.72N 5959822.83 N 5959831.21N 5959840.31N 5959850.58 N 560583.43E 56O584.98 E 560586.38 E 560587.19 E 560587.32E 560587.60 E 560588.10 E 560588.80 E 56O589.52 E 560590.44 E - 560591.45 E 560592.57 E 56O593.94 E 560595.34 E 560596.69 E Dogleg Rate (°llOOft) 0.75 1.12 1.30 3.30 0.78 0.04 0.04 0.45 0.34 1.91 0.98 0.70 0.33 1.07 3.06 7.21 6.80 4.83 3.67 5.79 5.91 4.00 5.79 6.67 7.07 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment -24.27 -27.23 -29.60 -30.52 -29.81 -28.69 -27.56 -26.22 -24.33 -23.41 -23.99 -24.45 -24.47 -24.57 -23.58 -22.10 -19.29 -15.17 -11.01 -5.39 1.01 8.11 16.48 25.57 '35.83 Continued... 13 November, 2000- 14:20 DrlllOueet 2.00.05 -North SI°pe Alaska Measured Depth . (ft) 3147.70 3181.73 3211.66 3244.26 3276.69 . Incl.. 22.310 24.580 25.410 26.800 29.170 3307.01 31.200 3339.84 33.410 3371.77 35.730 3402.93 37.540 3435.87 39.520 3466.90 3499.05 3534.41 3566.77 3594~63 3629.22 3659.82 3691.16 .3724.13 3757.67 .42.080 44.590 47.100 47.600 47.500 48.260 48.550 48.750 51.460 54.750 -3787.66 56.810 3821.20 57.760 .3853.15 60.010 3883.35 61.930 3916.73 64.920 Azim. 6.290. 5.850 5.020 4.690 5.550 .6.630 8.290 10.060 11.960 14.380 '.14.920 14.050 13.520 12.980 12.910 13.040 11.860 11.570 11.080 9.920 8.890 8.380 .6.730 5.750 5.420 Sub-Sea Depth .(~) 3031125 3062.46 3089.59 3118.87 3147.50 3173.71 3201.46 3227.75 '3252.75 3278.52 . ~3O2.ol 3325.39 3350.02 3371.94 3390.75 3413.95 3434.26' 3454.97 3476.11. 3496.25 3513.11 . . 3531.24' 3547.75 3562.40 3577~33 Sperry. Sun Drilling Services .Survey Report for 1D-140 Your Ref: API.500292297470 Job No, AKMMO0202, Surveyed: 2 October, 2000 Vertical Depth (ft)- 3132.75 3163.96 3191.09 3220.37 3249.00 - 3275.21. 3302.96 '3329.25 3354.25 3380.02 '3403.51 3426.89 3451.52 3473.44 3492.25' 3515.45 3535.76 3556.47 3577.61 3597.75 '3614.61 -3632.74 3649.25 3603~90 3678.83 Local Coordinates' Northinge Eastings (ft) -(fi) · 46:90 N 107.76 E 60.37 N 109.18 E 72.96 N 110.38 E 87.25 N 1 i 1.59 E 102.40 N 112.96 E 117.56 N 114.58 E 134.95 N 116.86 E 152.83 N 119.76 E 171.08 N 123.32 E 191.06 N 128.00 E 210.67 N ' 133.13 E 232.03 N. 138.64 E 256.67 N 144.69 E 279.83 N 150.14 E 299.87 N 154.75 E' 324.87 N 347.22 N 370.25 N 395.05 N' - 421.42 N 445:89 N. 473.79 N 500.90 N 527.15 N 556.86 N GlObal Coordinates Northlngs Eastings (ft) (ft) 5959861.74N 560597.92 E 5959875.21N 560599.25E 5959887.81N 560600.34E 5959902.11N 560601.44 E 5959917.28 N 560602.68 E 5959932.45 N 560604.18 E 5959949.86 N 560606.32E 5959967.76 N 560609.08 E 5959986.04N 560612.49E 5960006.03 N 560617.01E 5960025.70 N 560621.98 E ' 5960047.11 N 560627.32 E 5960071.79 N 560633.17 E 5960095.03 N 560638.43 E 5960115.08 N 560642.88 E 160.51-E 5960140.12 N 560648.44 E 163.44 E 5960162.51 N 560653.19 E 170.22 E ' 5960185.58 N 560657.78 E 175.18 E -5960210.42 N 560662.55 E 180.06 E 5960236.83 N 560667.21 E 184.11E 5960261'.33N 560671.07E 188.35 E 5960289.26 N . 560675.08 E 191;94'E 5960316.40 N 560678.45 E 194.81E 5960342.67 N 560681.11E 197.71E -5960372.40 N 560683.77E Dogleg Rate (°/lOOft) 7.11 6.69 3.01 4.29 7.41 6.93 7.25 7.92 6.85 7.55 8.33 8.02 7.18 1.97 0.40 2.21 3.04 0.94 8.30 10.19 7.43 3.11 8.31 6.96 9.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 46.98 60.44 73.03 87.33 102.48 117.64 135.04 152.92 171.17 191.15 210.76 232.13 256.77 279.94 299.98 324.98 347.33 37O.37 395.18 421.55 446.02 473.92 501.04 527.29 557.00 13 November, 2000 - 14:20 .. -4- Continued... DrlllQueet 2.00.05 NOrth Slope Alaska MeasUred Depth Incl. 3948.08 3979.80 4013.53 ' 4044.15 ' 4076.18 67.780 71.340 74~630 '76.310 78.110 4108.73 4119.68 .4168.00 4196.80 4231.26' 4264.66 4293.39 4325.91 4360.34 4389.48 ~;~1487.05 ~1519.13 ~t552.65 -~=~ 582.63 615.77 66748'39 8.43 4710.98 79.810 80.690 84.630 88.400 89.820 91.420 92.340 91.350 90.980 92.400 92.400 92.520 89.690 89.260- 89.510 89.880 90.800 91.410 89.320 -88.830 Azim. 4.390 2.160 359.970 358.950 356.940 356.710 -356.260 . 356.670 357.330 . 356.620 356.520 356.690· '357.21o · 357.510 357.220 357~340 356.840 356.580 357.020 355.740 355.530 355.110 -356.000 356.18o 357.380 Sub-Sea Depth (it) 3589.91 3600.99. 3610.86 3618.54 3625.63 3631.86 3633.72 3639.89 3641.64 3642.17 3641.81 .3640.87 3639.82 3639.12. 3638.26 .- ... 3636.77 3635.49- 3634.87 3635.16 3635.52 3635.68 . 3635.49 . 3634.86 3634.67 3635.19 Sperry. Sun: D illing Services Survey Report for 1D,140 Your Ref: API.500292297470 Job No: AKMMO0202, Surveyed: 2 October, 2000 Vertical' .Depth' (it) 3691.41 3702.49 3712.36 3720.04 3727.13 3733.36 3735.22 '3741.39 3743.14 3743.67 .3743.31 -3742.37 3741.32 3740.62 3739.76 '3738.27. 3736.99- 3736.37. 3736.66 3737.02 3737.18 --3736.99 3736.36 3736.17 3736.69. Local Coordinates Global Coordinates Eastinga Northings Eastinga (ft) (it) (It) Northings (It) 585.47 N 615.13 N 647.37 N 677.01 N- 7O8.22 N 740.12 N 750.89 N 798.72 N 827.42 N 861.82 N 895.16 N 923.83 N 956.28N 990.67N - 1019.76N 1055.39 N 1085.15 N 1117.13 N 1149.16 N 1182.61 N 1212.51 N 1245.53 N. 1278.05 N 1308.02 N 1340.51 N 200.16 E -5960401.03 N 560685.99 E 201.85 E 5960430.71 N 560687.45 E 202.45 E 5960462.95 N 560687.78 E 202.17 E 5960492.59 N 560687.26 E 201.05 E 5960523.79 N 560685.89 E 199.28E 5980555.67N 560683.86 E 198.61E 5980555.44N 560683.11E 195.66E 5960614.24 N 560679.78 E 194.16 E 5960642.92 N 560678.04 E 192.34E 5980677.32N 560675.94 E 190.34 E 5960710.64 N 560673.68 E 188.64 E- 5960739.28 N 560671.75 E 186.91 E 5963771.73 N 560669.76 E 185.33 E 5960806.10 N 560667.89 E 183.99 E 5960835.18 N 560666.32 E 182.29 E 5960870.80 N 560664.34 E 180.78 E 5960900.54 N 560662.59 E 178.94 E 5960932.51 N 560660.49 E 177.15 E 5960964.52 N 560658.45 E 175.04 E 5960997.95 N. 560656.06 E 172.75 E 5961027.83 N 560653.54 E 170.05 E 5961060.83 N 560650.57 E 167.52 E 5961093.33 N 560647.78 E 165.47'E 5961123;28 N 560645.49 E 163.65 E 5961155.76 N 560643.40 E Dogleg Rate (°/lOOit) 9.61 13.01 11.56 6.36 8.31 5.27 9.00 8.~ 13.29 4.61 4.80 3.26 3.44 1.38 4.97 0.34 1.72 8.87 1.92 3.89 1.42 3.05 3.31 6.98 3.98 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment ' 585.61 615.28 647.52 677.15 708.37 740.26 751.03 798.85 827.56 861.96 895.30 923.96 956.41 990.80 1019.89 1055.52 1085.27 1117.26 1149.29 1182.74 1212.63 1245.65 1278.17 1308.13 1340.63 MWD Magnetic -. 13 November, 2000 - 14:20 -5- Continued... DrlllQueet 2.00.05 Sperry. Sun. Drilling Services Survey Report for 1D-140 Your Ref: API.500292297470 Job No. AKMMO0202, Surveyed: 2 October, 2000 North, Slope Alaska Measured Depth' · ,(fi) 4744,27 4774.02 4807.14 4839.06 4869.57 '4904.54 4935.65 4967,12 5000,73 · 5032,80 Incl. 88.460 85.870 86.550· 88.830 89.570· 88.520 90.060 90,740 91.600 91.660 5063,61 5097,90 5128.39 5160,16 5192.78 90,430 90,180 91.660 91,910 90,000 Azim. 357.10o 356.420 354.670. 354.950 354,950 3541100 355.360 354,640 354.910 355.040 354.750 354.9OO 355,080 354.88O 354.210. 5225.30 89.940 353,550 5257.27 '90,680 353.430 5291,64 90,800 352,970 5321.4o 90.680 352.990 '5353.52 89.750 352.210 Sub,Sea Depth (ft) 3635.98 3'637.45 3639.64 3640.93. 3641.35 3641.94 3642.32 3642.10 ' 3641.41 3640.50 3639.94 3639.76 3639.27 3638.28 3637.74 3637,75 3637,58 3637.14 3636.75 3636.63 5385.53 88.950 352,160 3636.99 5417.55 89.260 351.980 '3637.49 5449.22 87.600' 352.030 3638.36 5481.90 87.480' 352.350 3639.76 5513.92 87.780 352.170 3641.09 Vertical Depth 3737.48 3738.95 3741.14 3742.43 3742,85 3743.44 3743.82 3743.60 3742.91 3742.03 3741.44 3741,26 3740,77 3739,78 3739,24 _ 3739,25 3739,08 3738,64 3738.25 3738,13 3738,49 3738,99 3739.86 3741,26 3742.59 LoCal Coordinates Northings "Eaetinge_ Northinge (ft) -(ft) (ft) Global Coordinates 1373~75N 162,04E 5961188,98 N 1403,42'N 160,36 E '5961218,63N 1436,36 N 157,80 E 5961251,56 N 1468,12 N 164,91E 5961283,29 N 1498,51N 152,23E 5961313,66 N 1533,32 N 148,89 E 1564,29 N- 146,03 E 1595.64 N . 143,29 E 1629,10 N 140,23 E 1661,04 N 137,42 E 1691,72 N . i34,68 E 1725,87 N. 13i,59 E 1756,24 N 128,93 E 1787.87 N "126,15 E 1820,34 N 123,03 E 1852,67N 119,58 E 1884,44N 115,96 E 1918,56 N 111,89 E 1948,09 N'.- 108,25 E 1979,95 N 104,11E 2011,66 N 99,76E 2043,37N 95,34E 2074,72N 90,94E 2107,06N 86.51E 2138,76N 82,20 E Eaetings 560641,53 E 560639,61E 560636,78 E 560633,64E 560630,71E 5961348,44N 5961379,39 N 5961410,71N 5961444,15 N 5961476,06N 560627,09 E 560623,99 E 560620,99 E 560617,66 E 560614,60 E 5961506,72 N 5961540,84 N 5961571,19 N 5961602,80 N 5961635,24 N 560611,61 E 560608,24 E 560605,34 E 560602,30 E 560598,94 E 5961667,54 N -5961699,28 N 5961733,37 N 5961762,87 N 5961794,69 N 560595,21 E 560591,33 E 560586,99 E 560583,11 E 560578,72 E 5961826,36 N 5961858,04N 5961889,35 N 5961921,66 N 5961953,33N 560574,11E 560569,44E 560564,79 E 560560,09E 560555,53 E Dogleg Rate (°/lOOft) 1,39 9,00 5,66 7,20 2,43 3,86 6,40 3,15 2,68 0.45 4,10 0,85 4,89 1.01 6,20 2,04 2,34 1,38 0,41 3,78 2,50 1,12 5,24 1,04 1,09 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1373,87 1403.53 1436.47 1468,23 1498,62 1533.42 1564,40 1595,74 1629.20 1661,13 1691.82 1725,96 1756,33 1787.96 1820,42 1852,76 1884,52 1918,64 1948.17 1980.02 2011.73 2043.43 2O74,78 2107.12 2t38.82 Continued,,, DrillQuest 2.00,05 13 November, 2000 - 14:20 . . -6- North Slope Alaska Sperry'Sun Drilling Services Survey Report for 1D. 140 Your Ref: AP1,500292297470 Job No. AKMMO0202, Surveyed: 2 October, 2000 Alaska State Plane 4 Kupsruk 1D MeasUred Depth Incl. 5545.46 87.110 5579.50 88.030 5609.7i ' 90.000 .5640.87 90.060 5676.63 90.220 5707.15 90.430 5736.50' 69.380 -5769.81 85.560 5799.88 82.790 5831.05' 82.410 5866.74 82.900 5896.68 80.660 5928.87 80.420 5961.47 80.550 5994.02 . 79.290 6024.99 78.610 6057.84 75.440 6079.91. 72.180 8156.00 72.180 Azim. Sub-sea Depth (fi) 351.660 3642.49 351.210 3643.94- '352.850 3644.46 352.080 3644.44 353.300 3644.35 '352.520 ' 3644.18 . 352.960 3644.23 352.850 3645.70 353.790. 3648.75 - 353.920 3652.76 353.600 3657.33 353.560- 3661.61 -353.610 3666.90 '-353.340 3672.29' 352.730 3677.98 Vertical Depth (~t) - 3743.99 3745.44 .3745.96 '3745.94 3745.85 3745.68 3745.73 '3747.20 3750.25 3754.26 -3758.83 3763.11 3768.40 3773.79 3779.48 '352.420 3683.92 3785.42 ''352~870 3691.30 3792.80 .351.720 3697.45 3798.95 351.720 ' 3720.73 3822.23 ' Local Coordinates Global Coordinates -Northinga . Eastinga Northings Eaetinge (ti) (ft) (ft) (ft) 2169.96 N 77.77 E 2203.59 N 72.70 E 2233.50 N 68.51 E 2264.39 N - 64.43 E 2299.86 N 59.88 E 2330.15 N 56.11E 2359.26 N 52.40 E 2392.28 N 48.29 E 2421.98 N 44.81E 2452.72 N_ 41.50 E 2487.90 N 37.65E 2517.35 N 34.34E' 2548.90 N ' 30.79 E 2580.85 N 27.14 E 2612.68N 23.25 E 2642.8O N 19.33E 2674.54N- 15.23E 2695.54N 12.39E 2767.23N 1.96 E 5961984.49 N 560550.84 E 5962018.07N -560545.51E 5962047.95 N 560541.08 E 5962078.81N 560536.75 E 5962114.24N 560531.91E 5962144.49 N 560527.90 E 5962173.58 N 560523.96 E 5962206.56 N 560519.58 E 5962236.24 N 560515.86 E 5962266.94 N 560512.31 E 5962302.10 N 560508.17 E 5962331.51N 560504.62E 5962363.04N 560500.82 E 5962394.95 N 560496.91E 5962426.73N 560492.77E 5962456.84 N 560488.60 E 5962488.55 N 560484.25E 5962509.52 N 560481.24E 5962581.12 N 560470.23E Dogleg Rate (°ll00ft) 2.67 3.01 8.48 2.48 3.44 2.65 3.88 11.47 9.72 1.29 1.64 7.48 0.76 0.91 4.29 2.41 9.74 15.60 0.00 Vertical Section Comment 2170.01 2203.64 2233.55 2264.44 2299.90 2330.18 2359.30 2392.31 2422.O2 2452.75 2487.93 2517.37 2548.92 2580.86 2612.67 2642.81 2674.55 2695.55 2767.23 Ali data is in feet unless otherwise stated. Directions and Coordinates are relative to 'True North. Vertical depths are relative to Well.' Northings and Eastings are relative to Well. .- _, Magnetic Declination at Surface is 26.771 ° (03-Nov-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth Of 0.041 ° (True). .. Based upon Minimum Curvature type calculatiOns, at a Measured DePth of 6156.00ft., The.Bottom 'Hole DiSplacement is 2767.23ft. in the Direction of 0.041° (True). 13 November, 2000- 14:20 - 7. - .. Continued... DrillQueet 2.00.05 SperrY'Sun Drilling Services . Survey Report for 1D-140 Your Raf: API-500292297470 Job No. AKMMO0202, Surveyed: 2 October, 2000 * North Slope Alaska Alaska State Plane 4 Kuparuk 1D .Survey tool program for 1 D- 140PB1. From - Measured. -Vertical Depth Depth (fi) (ft) 548.34 4168.00 To Measured Vertical · Depth Depth -.(ft)~ _(ft). 0.00 548.34 548.32. 548.32. 4168.00 3741.39 3741.39 6156.00 3822.23 Survey Tool Description AK-2 BP_CG. AK-6 BP_IFR-AK MWD Magnetic 13 November, 2000- 14:20 DrlllOueet 2.00.05 13-Nov-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Wel 1D-140 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 5,481.90' MD 5,493.00' MD 8,117.00' 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-140 Job No: AKMMO0202, surVeyed: 4 October, 2000 SURVEY REPORT 13 November, 2000 Surface C°ordinates: 5959813.97 N, 560490~55 E (70* 18' 02.7841" N, 210' 29' 23.7396" E) .- your Reft APl,500292297400 Kelly Bushing: 101.50ft above Mean Sea Level A HIIIIburton Company Survey Ref: svy9330 North Slope Alaska Measured Depth .. (ft) Incl. - Azim. 5481.90 87.480 352.350 5493.00 86.154 -352.557 5513.96' 83.650 352.950 5545.67 86980 353.510 5579.01 81.530 354.310 5611.70 79.800 '5640,87 81.350 5675.9O 84.27O 5706.23 85.560 5737.15 89.450 5768.64. 91.170 5800.86. '8~510 5831.54 89.140 5865.40 .88.030 5899.67 87.100 -356.590- 356.600 - 356.510 355.350 356.190 356.670 356.440 355.360 356.930 355.690 Sub-Sea Depth (ft) 3639.76 3640.38 3642.24 3646.48 3651.55 3656.85 3661.63 - 3666.02 3668.70 3670.05 3669.88 3669.69 ' 3670.05 - 3670.89 3672.34 5928.42 86.490 355.560 3673.95 5962.39 88.710 355.180 3675.37 5995.65 88.830 354.740 3676.09 . 6025.89 89.080 355.330 3676.64 6058.25 88.460 357.180 3677~33 6090.74' 88.520 358.070 6120.33 89.750 359.010 6152.98 90.310 357.760 6185.81 89.080 358.170 6215.85 90.550 .0.730 3678.19 3678.63 3678~62' 3678.79 3678.89 Sperry'Sun Drilling Services Survey Report for 1D,140 Your Ref: API-500292297400 Job No. AKMMO0202, Surveyed: 40otober, 2000 Vertical .Depth (ft) 3741.26 3741.88 3743.74 3747.98 3753.05 3758.35 3763.13 3767.52 3770.20 3771.55 3771.38 3771.19 3771.55 3772.39 3773.84 3775.45 3776.87- 3777.59 .3778.14 3778.83 3779.69 3780.13 3780.12 3780.29 3780.39 Local Coordinates -Global Coordinates Northlngs Eastings Northings Eestings (ft) (ft) (ft) 2107.06N 86.51E 5961921.66 N 560560.09 E 2118.05 N 85.05E 5961932.64N 560558.55 E 2138.76N ' 82.42E 5961953.32N 560555.75 E 2169.96 N 78.71E . 5961984.49 N 560551.79E 2202.73 N 75.22 E 5962017.23N 560548.03E '2234.88 N 2263.60 N 2298.29 N 2328.43N 2359.23 N 72.66 E 70.95 E 68.86 E 66.71 E 64.44 E. 2390.65 N. 2422.81 N 2453.41 N- 2487.18 N - 2521.35 N 62.48 E 60.54 E 58.35 E. 56.07 E 53.87 E 2549.97N 2583.8O N 2616.92 N 2647.04 N 2679.33N 51.68 E 48.94 E 46.02 E 43.40 E 41.29-E 2711.78 N- 2741.35 .N 2773.99 N 2806.80 N 2836.83 N 39.94 E 39.19 E 38.27 E 37.10 E 36.81 E - 5962049.36 N 560545.21E 5962078.07N 560543.27E 5962112.74N 560540.90 E 5962142.86 N 560538.52 E 5962173.64N 560535.99 E 5962205.05 N 560533.78 E 5962237.19 N 560531.58 E 5962267.77 N 560529.14 E 5962301.52 N 560526.60 E 5962335.67 N 560524.12 E 5962364.27 N 560521.70 E 5962398.08 N 560518.69 E 5962431.18 N 560515.80 E 5962461.28 N 560512.64 E 5962493.54 N 560510.27 E · 5962525.98 N 560508.66 E 5962555.55 N 560507.67 E 5962588.18 N 560506.48 E 5962620.97 N 560505.05 E 5962651.01 N 560504.52 E Dogleg Rate (°/lOOft) Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2107.85 Tie on 12.09 2118.82 Window Point 12.09 2139.50 8.60 2170.66 2.89 2203.39 8.68 5.31 8.34 5.71 12.87 5.67 5.20 3.72 5.68 4.52 2.17 6.63 1.37 2.12 6.03 2.74 5.23 4.20 3.95 9.83 2235.51 2264.22 2298.88 2328.99 2359,77 2391.17 2423.31 2453.88 2487.63 2521.77 2550.37 2584.17 2617.26 2647.35 2679.61 2712.04 2741.61 2774.24 2807.03 2837.06 Continued.,. 13 November, 2000- 14:27 -2- DrlllQueet~00.05 Sperry-Sun Drilling Services Survey :Report for 1D-140 Your Ref: API-500292297400 Job No. AKMMO0202, . Surveyed: 4 October, 2000 North Slope Alaska Measured Depth (fi) 6248.85 6282.29 6312.75. 6345.78 6378.24 . . '6408.75 6440.45 6474.34 6504.52 6536.85 6569.96 6600.24 6633.33 6665.76 6695.33 Incl. 89.510 89.510 -87.110 86.800 85.500 87.660 91.050 91.110 91.350 90.860 91~410 92.220 92.160 91.230 90.740' 6731.01 6762.05 .6791.62 6804.36 6840.38 90.120 91.230 91.600 91.790 91.600 Azim, .0.330 1.560 0.300 .. 0.570 358.250 359.060 358.5OO 357.960 358.570 358.870 358.790 358.670 358.680 357.410 356.260 355.650 359.320 356.660 357.55O 357.520 .Sub-Sea Depth (ft) 3678.87 3679.16 3680.06 3681.81 3683.99 3685.81 3686.17 3685.53 -3684.88 3684.26 083.6o 3682.64 3681.38 3680.42 3679.91 3679.-64 ~679.28' 3678.55 36~8.17. 3677.10 Vertical Depth (ft) - 3780.37. 3780.66 3781.56 3783.31 3785.49 3787.31 3787.67 3787.03 3786.38 3785.76 3785.10 3784.14 3782.88 378.1.92 3781.41 .- 3781.14 3780.78 3780.05 3779.67 3778.60 6872.72 90,310 357.860 3676.57 '3778.07 6903.20 91.290 357.560 -3676.14 .3777.64 6936.64 90.250' 358.450 3675.69 3777.19 6968.40 90.370 358.910 3675.52 3777.02 6998.60' 90.550 358.460 3675;28 3776.78 LOcal'Coordinates· . Northings (ft) · 2869.83 N 2903.26 N 2933.70 N 2966.69 N 2999.07 N 3029.51' N 3061.20 N 3095.O7 N 3125.23 N 3157.54 N 3190.54 N 3220.90 N. 3253.95 N 3286.35 N 3315.87 N 3351.46 N 3382.46 N 3412.00 N 3424.72 N. · 3460.69 N. 3493.00 N 3523.45 N 3556.87 N 3588.62 N 3618.81 N Eastings (fi) Global Coordinates Northinge Eastings .(ft) (fi) 37.12 E 5962684.01N 560504.56 E 37.67 E 5962717.44N 560504.85 E 38.16 E 5962747.89 N 560505.10 E 38.41E 5962780.87 N ' 560505.08 E 38.08 E 5962813.25 N 560504.49E 37.37 E 5962843.69 N 560503.53 E 36.69 E 5962875.37 N 560502.60 E 35.65 E 5962909.22 N 560501.28 E 34.73 E 5962939.37 N 560500.12 E 34.01 E 5962971.68 N 560499.14 E 33.33 E 5963004.77 N 560498.20 E 32.66 E 5963035.02 N 560497.28 E 31.90 E 5963068.07 N 560496.25 E 30.79 E 5963100.46 N 560494.89 E 29.16 E 5963129.97 N 560493.02 E 26.64 E 5963165.53 N 560490.21 E 25.28 E -5963196.52 N 560488.60 E 24.24 E 5963226.05 N 560487.33 E 23.60 E 5963238.77 N 560486.58 E 22.05 E 5963274.72 N 560484.74 E 20.75 E 5963307.02 N 560483.18 E 19.53 E 5963337.46 N 560481.72 E 18.37'E 5963370.87 N 560480.28 E 17.64 E 5963402.61' N 560479.30 E 16;94 E 5963432.80 N 560478.36 E Dogleg Rate (°/lOOff) 3.38 3.68 8.90 1.24 8.18 7.56 10.84 1.60 2.17 1.78 1.68 2.70 0.18 4.65 4.23 2.44 12.35 9.08 7.14 0.53 4.13 3.36 4.09 1.50 1.60 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2870.06 2903.50 2933.94 2966.92 2999.30 3029.74 3061.41 3095.27 3125.42 3157.72 3190.81 3221.06 3254.11 3286.49 3315.99 3351.55 3382.54 3412.07 3424.78 3460.73 3493.02 3523.46 3556.87 3588.61 3~18.79 Continued... 13 November, 2000 - 14:27 -3- DrlllQuest 2,00.05 North Slope Alaska Measured Depth (fi) Incl. - Azim.- Sub-Sea Depth (ft) 7030.33 -90.370 358.930 3675.02 7063.22 90.120 -357.210 3674.88 7093.41 91.050 357.760 3674.57 7126.58 '91-.350 -358.440 3673.88 7158.72 91.110 358.620 3673.19 7189,67 90.920 -7222,76 90,860 7255.43 90.920 7285.58 90.550 7317,86 90.680 7351.00 91.050 7381.29' 91.110 7414.05 91.540 7445.47 91,110 7476,30 90.990 7510,10 91.290 .7542,20 88,770 7572.05 88.280 7604.89' 88.770 7637.27 89.260 357.770- '358,240 358.170 0.510 359.6O0. 359,790 0.350 359,440 2.430- 2,540 3.810 3.820 3.470 3,05O - 3.410 3.620 3,010 4.090 4,020. 3.460 7668,31 '87.480 7701.49 87.170 7734,61 89.32O 7764.20 89.940 7798.13 ' 90.060 3672,64 3672,13 3671,62 3671.23 3670,88 3670,38 3669,81 3669,06 3668,33 3667,76 3667.09 3667.07 -3667.84 3668,69 3669,25 3670,13 3671,68 3672~69 3672.88 3672.88 Sperry-Sun Drilling Services Survey Report for 1D-140 Your Ref: API-500292297400 Job No. AKMM00202, Surveyed: 4 October, 2000 Vertical -Depth' 3776.07 3775.38' 3774.69 3774,14 3773,63 ' 3773~12 3772,73 3772.38 3771,88 .3771,31 3770,56- 3769,83 3769,26 Local Coordinates Global Coordinates Northings Eastings Northinga Eastings (fi) (ft) (ft) (fi) 3650,53 N 16,22 E ' 5963464,51 N 560477,38 E 3683.40 N 15,11 E 5963497,37 N 560476,01 E 3713,56 N 13,79 E 5963527,52 N 560474,44 E 3746,70 N 12,69 E 5963560,65 N 560473,08 E 3778,82 N- 11,86 E 5963592,77 N 560471,99 E 3809,75 N 10,89 E 3842,82 N 9,74 E 3875,47 N 8,71 E 3905.61 N 8,37 E 3937,89 N 8,40 E 3971,03N 8,22 E 4001,31N 8,26E. 4034,06 N 8,20 E 4065,46 N . 8,71E 4096,26.N 10,05 E 3768,59 4130,00 N 11,92 E 3768.57. 4162,03N 14,06E 3769,34 4191,81N 15,95 E 3770.1g 4224.58 N 17.82E '3770,75 4256.91N 19.64E 3771,63 -3773.18 3774,19 3774,~ 3774.38 4287,87 N 4320,96 N 4354.00 N 4363,52 N 4417,37 N 5963623,69 N 560470,77 E 5963656,74 N 560469,35 E 5963689,38 N 560468,07 E 5963719,52 N 560467,48 E 5963751,80 N 560467.25 E 5963784.93 N 560466.80 E 5963815.22 N 560466.60 E 5963847.97 N 560466.27 E 5963879.37 N 560466.53 E 5963910.18 N 560467.62 E 5963943,93 N 560469,22 E 5963975,98 N 560471,10 E 5964005,77 N 560472,76 E 5964038,56 N 560474,36 E 5964070,90 N 560475,92 E 21:55 E 5964101,88 N 560477,58 E 23,46 E 5964134,98 N 560479,23 E 25,51 E 5964168,04 N 560481,01 E 27,60 E 5964197,57 N 560482,86 E 29,82 E 5964231,44 N 560484,81 E Dogleg Rate (°/~OOft) 1,59 5,28 3,58 2,24 0,93 2,81 1,43 0,28 7,86 2,85 1.26 1,86 3,07 9,61 0,53 3.86 7,85 2,02 1,96 1,88 5,77 2,06 7.26 2,11 1,69 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3650,50 3683,36 3713,50 3746.63 3778.74 3809,66 3842,71 3875,35 3905,49 3937,77 3970,90 4001.18 4033,93 4065,34 4096,14 4129.90 4161,95 4191,75 4224,54 4256,88 4287,87 4320,97 4354,03 4383,57 4417,45 Continued,,, 13 November; 2000 - 14:27 - 4 - DrlllOuest 2.00.05 Sperry-Sun Drilling Services . Survey Report for 1D-140 Your Ref: API-500292297400 Job No. AKMMO0202, Surveyed: 4 October, 2000 North Slope Alaska Measured . Depth .(ft) 7830.18 7860.42 -7894.24 7926.41 7956.52 Incl, 90.800 90.860 g0.430 90.310 90.250 7990.57 90.250 8023.14 -90.250 8042.46 90.250 8117.00 90.250 Azim~ 4.O20 3.550 3.360' 3.58O 3.'910 .. 3.330 2.680 3.330 3.330 Sub-Sea Vertical DePth Depth (ft) (ft) 3672.20 3773.70 - 3671.82 3773.32' 3671.61. 3773.11 3671.47 3772.97 Local Coordinates Northings Eastings (~) -(~) 4449135 N -31.91 E 4479.52N 33.90 E 4513.28 N '' 35.94 E 4545.39 N 37.89 E 4575.44N 39.86 E · 3671.32 3772.82. . 4609.42 N 42.01 E 3671.18 3772.68 4641.94 N 43.71 E 3671.09 '3772.59 ' '4661.24 N 44.73 E 3670.77 3772.27 4735.65 N 49.06 E Global Coordinates Northings Eastings (ft) (ft) 5964263.44 N 5964293.62 N 5964327.39 N 5964359.52 N 5964389.58 N 56O486.64 E 560488.39 E 560490.16 E 560491.85 E 560493.57 E 5964423.58 N 5964456.11N '5964475.42N 5964549.86 N 560495.45 E 560496.89 E 560497.75 E 560501.48 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. · - Magnetic DeclinatiOn at Surface is 26.771 ° (03-Nov-00) . The 'Dogleg Severity is in Degrees per !'00-feet. Vertical Section is from Well and calculatedalong an Azimuth of 0.593° (True). Based upon Minimum Curvature type calculations,, at a Measured Depth 'of 8117.00ft., The Bottom Hole Displacement is 4735.90ft., in the Direction of 0.593° (True). 13 November, 2000- 14:27 . . Dogleg Rate (°ll00ft) 2.90 1.57 1.39 0.78 1.11 1.70 2.00 3.36 0.00 Alaska State Plans 4 Kuparuk 1D Vertical Section Comment 4449.45 4479.64 4513.41 4545.54 4575.60 4609.61 4642.15 4661.45 4735.90 Projected Survey Continued... DrillQuest 2.00.05 North Slope-Alaska Sperry-Sun Drilling Services Survey Report for 1D-140 . Your Ref: API.500292297400 Job No~ AKMMO0202, Surveyed: 4 October, 2000 Alaska State Plane 4 Kuparuk 1D Comments Measured Depth. (ft) Station Coordi.nat'es TVD Northings Eastings (ft) (ft) "(ft) ' 5481.90 '3741.26 -2107.06 N- 5493.00 · 3741.88 2118.05 N 8117.00 3772.27 4735.65 N Comment 86.51 E Tie on 85.05 E Window Point 49.06 E projected Survey Survey tool'program for 1 Dr 140 ' ' From Measured Vertical . Depth Depth. (fi) (ft) To Measured- Depth (fi) 0.00 548.34 4168.00 0.00 548.32 3741.39 548.34 ' 4168.00- - 8117.00 Vertical Depth 548~32 3741.39 3772.27 Survey Tool Description AK-2 BP_CG -AK-6 BP_IFR-AK . MWD_Magnetic 13 NoVember' 2000 - 14:27 -6- DrlllQuee! 2.00.05 ALASIIA OIL AND GAS CONSERVATION CO~L~liSSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kuparuk River Unit ID- 140 Phillips Alaska, Inc. Permit No: 200-136 Sur Loc: 149'FSL, 595'FEL, Sec. 14, T1 IN, R10E, UM Btmhole Loc. 406'FNL, 549'FEL, Sec. 14, TI IN, RIOE, 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 any 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 ID 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 annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~k~/' r- Daniel T: Seamount, Jr. Commissioner BY ORDER OF TH~ ~9MMISSION ,DATED this // ~- 7"~ ' day of September, 2000 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill r-~ I lb. Type of well. Exploratory r'~ StratigraphicTestD Development oil l'~l Re-entry D Deepen DI Service D Development Gas D Single Zone I~! Multiple Zone D 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 25.0251) 149' FSL, 595' FEL, Sec. 14, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 616' FSL, 423' FEL, Sec. 14, T11N, R10E, UM 1 D-140 #U-630610 At total depth 9. Approximate spud date Amount 406' FNL, 549' FEL, Sec. 14, T11N, R10E, UM September 15, 2000 $200,000 12. Distance to nearest property line ~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ~.-,%"'~,~J'~ 406' @ TD feet 1D-105 16' @ 489' feet 2560 8115' MD/3788' TVD I · 16. To b~ completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 500' MD Maximum hole angle 90.7° Maximum surface 1670 psig At total depth (TVD) 2088 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantify/of Cement Hole Casin~l Wei~lht Grade couplin~l LenCh MD TVD MD TVD (include sta~le data) 20" 16" 68# 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 ASLite & 380 sx Class G 6" 4" 9.5# L-80 HSLHT 4144' 3971 3710' 8115' 3788' Screen - No cement 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEIVED SEP 0 7 2000 Perforation depth: measured Alaska 0il & Gas Cram. Commmsbn true verticalAnchorage 20. Attachments Filing fee [~] Property Plat ~ BOP Sketch r~ .Oiverter Sketch [~] Drilling program r~ Drilling fluid program" [~] Time vs depth plot DRefraction analysis [~] Seabed report' D 20 AAC 25.050 requirements D 21. i hereby certi~ ~ that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever265-682~ Signed .I Title: Date 1~ $ Pret~ar~d bv Sharon Commission Use Onl} PermitNumber,~) ,../,.~:~)1 APInumber _ _, -- ISeecoverletter 50- (~) Z(~"'~-.~.-("J~ 7 ~"~) I Approval dat~ ..../~/~_.~) ~) If°r°ther requirements I Conditions of approval Samples required D Yes I~ No Mud log required I-1 Yes ~l No Hydrogen sulfidemeasures I~ Yes [~ No Directional surveyrequired [] Yes r'~ No Required wolldng pressure for BOPE D2M; [~~l'-] 5M; I~ lOU;D D Other: ORIGINAL SIGNED BY byorderof ~ Approved by _r') T~t!!~_.,, ~2.~. nl lnf 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 (Main Well Bore) Well Plan Summary RECEIVED SEP 07 2000 Alaska ~ & Gas Cons. Commission Anchorage Surface Location: 149' FSL 595' FEL Sec 14 T11N R10E UN B-Sand Lateral - Ta~et I 616' FSL 423' FEL Sec 14 T11N R10E UM B-Sand Lateral - TD 406' FNL 549' FEL Sec 14 T11N R10E UM I AFE Number: I AK0045 I I Rig: I Nordic3 Estimated Start Date: I 9/15/00 I I Operating days: I 37 I I I I I I I KBE: I S0' Type of Well I Producer I Well Design Horizontal Multilateral- Pm-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 Primary Wellbore and B-Sand Lateral Base Permafrost 1541 1642 1647 2 Ugnu C-Sand 2941 3042 3050 16 Ucjnu B-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 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 Quantity 12-1/4" 10-3/4" 40.5 ]-55 BTC 500' Surface 500'/500' 110 sacks (77 bbl) ArUCRETE 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 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 Logging/Formation Evaluation Program: IOpen Hole MWD/GR/RES/PWD (Pressure while Drilling) I Cased Hole Loqs: None Drillinq Fluid Tv_De 12-114" x 9-7/8" Surface Hole will be drilled with a standard Bentonite Slurry. 6" Production Hole will be drilled with a 6% KCL DrilrN Fluid. Drillinq Fluid Properties: Spud to 10-3/4" Casinq Point (+/- 500): Initial Final Density Viscosity Y__~P P._~V 8.5 - 8.8 250 - 300 40 - 70 20 - 35 8.5 - 8.8 250 - 300 40 - 70 20 - 35 10-3/4" Casing Point - Base of Permafrost (+/- 1647): Initial Final 10 s Gel 17 - 28 17 - 28 API Filtrate < 15 < 15 Density Viscosity YP PV 10 s Gel API Filtrate 9.6 - 9.8* 70 - 150 30 - 45 25 - 45 10 - 15 4- 10 9.6 - 9.8* 70 - 150 30 - 45 25 - 45 10 - 15 4- 10 ' Base of Permafrost - 7" x 7-5/8" Surface Casing Point (+/- 4121): Density Viscosity YP PV Initial 9.6 - 9.8* 70 - 150 30 - 45 25 - 45 Final 10.3 - 10.5 70 - 150 30 - 45 25 - 45 * 9.8 ppg if hydrates are found tauO 4-7 Production Interval (B-Sand Horizontal Lateral): Density Viscosity YP PV 10.3 - 10.5 45 - 53 18 - 24 11 - 17 HTHP Chlorides LGS < 10 150 - 170K 12 ppb (drilled LGS) Drillinq Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators 10 s Gel 10- 15 10- 15 API Filtrate 4- 10 4- 10 8.5 - 9.0 API Filtrate <4 RECEIVED SEP 0 7 2000 Alaska Oil & Gas Cons. Commission Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. I~IASP (Naximum Anticipated Surface Pressure): The well path of 1D-140 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/it, or 8.5 to 9.6 ppg EMW (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. Only one string of surface casing is planned for the West Sak 1D-140 well. Therefore, the surface hole to be drilled from surface through the West Sak Reservoir will be drilled using only a diverter system for well control purposes. Experience in the area has proven that these zones can be safely drilled using only a diverter system. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Calculating HASP based on the highest recorded reservoir pressure from the nearby wells, and assuming a gas gradient of 0.11 psi/it from maximum TVD in the B-Sand to surface, the following HASP can be computed: MASP = (3796 it)(0.55 - 0.11 psi/it) = 1,670 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" x 7" surface casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of 1,500 psi. The 7" 26# Sperry Preformed Window has a maximum burst rating of 2,500 psi; 70 % of this burst rating is 1,750 psi. Drillinq Area Risks: Drilling risks in the West Sak 1D-140 area are primarily limited to hydrates, lost circulation, and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of the pipe, controlling drilling rates and optimum rheological properties to safely appropriate gas breakout. 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: Listed below are nearby well bores that may be within 50 feet of the proposed well bore: Center-Center Depth of Closest Distance at Allowable Well # Approach (MD) Closest Approach Deviation 1D-105 489 16 9 1D-02 799 20 10 1D-102 599 22 14 1D-106 1187 29 14 Annular Pumping 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 leit with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-140 surface casing / production tubing annulus will be filled with diesel and ! or non-freezing brine alter running the ESP completion and prior to the drilling rig moving off of the well. RECEIVED SEP 07 2000 Alaska C~ & Gas Cons. Commission Anchorage Multilateral Producer (09/06/00) ~eneral Procedure (Primary Well Bore): 1. . 3. 4. 5. 6. m . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. Drill, Cas(_ and Completion Plan for West ~_.z 1D-140 RECEIVED SEP 07 2000 Alaska 0~ & Gas Cons. Commission Excavate cellar, install cellar box, set and cement 16" conductor to +/- 11~~. Weld landing ring on conductor. Move in / rig up Nordic 3. Install diverter & function test same. Spud and directionally drill 12-1/4" hole to 500'. (;ondiUon hole for casing. Run and cement 10-3/4" (;asing String to surface. Displace cement with mud. Drill out and directionally drill 9-7/8" hole to the casing point at +/- 4 12.~D / 3,734' TVD as per directional plan. Run MWD, LWD and PWD tools as required for directional monitoring and formation data gathering. (;ondition hole for casing. Run, orient and cement 7-5/8", 29.7#, L-80, BT(; Mod x 7", 26#, L-80, BT(; Mod (;asing String to surface. Displace cement with mud and perform stage job or tp job if required. · 7-5/8" Port (;ollar to be installed @ +/-600 MD / 600' TVD. · Employ lighbNeight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. · Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOG(;(; 24 hours before test PU 6" PD(; Bit and Directional BHA. RIH to tp of float equipment. Pressure lest casing to 1500 psi for 30 minutes. Record test results. Drill out cement and approximately 20' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results. This establishes a maximum allowable drilling mud weight below the casing shoe per 20 AA(; 25.030 (0.5 ppg less than the FIT or LOT EMW). Directionally drill 6" hole to TD at +/- 8,114.' MD / 3,788' TVD as per directional plan. POOH and lay down MWD, LWD and PWD tools. RIH with 6" hole opener and ream entire open hole. Orculat and condition hole to run liner. Displace mud with clean filtered brine and spot viscosified brine in open hole. Perform casing and drill pipe clean-up including (;ausUc SL Wash and acid pickle. Run 4-1/2" x 4" Liner with pm-packed screen (run liner with 2-7/8" inner wash string). Land liner, set liner top packer and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screens while POOH. Displace the well, above the liner tp packer, with clean filtered brine. ~ north Slope Alaska Kuparuk 1D DrillQuest' ,,..~.~., Alaska Stat,, Plane 4Phillips Alaska1D-140 WP9 Proposal Data for ! D-140 WPg Currant Well Properties Ver6~ Od~in: 1D-140WPil Hodzon~ 06gin: 1D*t,IO WP& 1D-140 WPa Nb~ummenl Un/~: ft W~I: V. r6cal S~i~n Daacdg~x~: 1D-D P. KB Ebva~on: 101.001t above Msan Sea I.~dVerlk:M Sl~ion Odgin: O.00 N,O.OO E 101.0Off above Well MeMuled Ind. ~zlm. V~'III:'''l Nm~llngl El~lln,~ Nodh P~ferer=e: Tree Nodh 893.3~ 5.000 IOO~O~ ~'~91 2..~2 S 1431 E -~4(! I~O -- 1168~7 12~6~ 46~?E -I I.Kq I171.11 9.00o Ii(U)00 37GO, 14 45.0(X) I0.000 3.q~oI .t~,2..10 N I.q9.70 E 412137 ~.874 3~3.127 37~4.00 7)&76N I~OAO E 740.14 II.00 412~.M $&462 35~.273 3734X~J 742."/I N 159!~.~ F. 744.0~ I 1.00 4569.05 88.462 )$).273 3746,00 11&~.20 N IU7.9; F- IIM.IO n0o 10:3/4" Casing - 500.00 MD, 500.00 TVD ~6~.o~ =~ ~n.~o n~.o, :z;z92n :e2~o:.: 521~.. I .n i6.1X]O 35&ooO 3762.00 1111.'1.44 N ~l.O'/E 1#16~flS I I ,,Begin Dir il 1.51Y'/100ft : 560.00It MD, 560.001t TVD sz4~.?; ll.~ 3s~.w6 37~t;s ~&q.,n.~ ~ ~; 5472.i0 is.."*4~ 35'/.176 3T/o5~ 2lja5.74 N 70.65 I-'- ..~4s'/.o$ l&eoo 3Y/.ggo 3'r/i.oo 211~.o0 N 7o.I)o I: 21eo$~ 6.[io 549)31 S7.60o 3.r/.6.1o yr/i.4~ 211:~.41 N 60.42 E 2112.94 6.oo 57Z0.~3 ~7.~0 3.V/.630 37~74 2.1J3.15 N ~21 E 700- $[~ 0 7 ~000 '~"~ "~' "~'~' '"'~' ~'"'~'~ ~'"' 61S6.06 B&79J 3~'/.7U3 3790.75 ~/g& lO N 41.61 E 61~.7~ ~.~t~ 357.1]oo }'/91.00 2~1~.79 N 41.1171.' 2~1o.o4 ~00.00 ' ' 621~.~0 g9.3~7 }.~.721 3'/91.17 2x2o. f~ N 4o.411 I': 21~1.115 6.00 ~4S.71t ~9.397 3.q6.721 379.~.~[ 32t~tL! N 15.)0 F. 3260.04 0.00 Alaska ~l & Gas Cons Commi~ion ...... '""' '"~" '"'"'~ '""': 677~.11 90.201 1.120 37")$.~1 3.~J6~2 N I ~1.'/9 I". 33.~32 6.00 · 7SO).!4 ~201 1.12~ 3792.O3 44~.114 N M.WI; 44~O.9~ O.00 Ancn---or,age '""" ~ "" "" ...... ~'"" '"'" rop to Vertical at 1171.1 lft ?~xm m.?~6 Lz~ .~1.~ 44~ux~x .~.~.lu ~ s i 14.g4 90.7~6 1.227 .l?M.ijo 47L,~.s5 ,-4 4 i.,~0 E 4'726.0.1 0.00 1200.00 ~ 1400 - ~ -~E-nd ~ft ~811 ~ O.OUO": 1111.1 IlTA/IL},ll§U.1 1ltl Vt.} -- B,r.~e P, t,adlr:,:t / ~ ~000.00' ~ ~ 2100 --- __ ~<,~o ~ ~o,~~' > .~.~.~. ~°°'°° ' ~,~.~*~ .~.~,. 2800- ~.oo.oo,, ,~-~* 3,?.0 ..... · ...... ..... -,'._ ,,-.- ~-- ---~,?~- . . . .~_,.~.-,, _....,, ~ · ...... ~.,.,.,-,,,,,,~ · -~. [~ ;~ [,6 ..... ~ .~..~,~ ~6O ' ~_~,~ _,,A~OA~'~,~,~\q, _,.~,~.~,~,, '-- _,,,.,~x ~xq, / EndDir, StadSail ~ 9(~_.766° :7820.06flMD,3791.94ffrVD v , ~ v ........ ]f,','~; .~d." I) .~,:n,." ' --'~- - /- /-~---- ----'-' ~ ~ ~ -- ~ -- --~ ......... /-: ___'..~:-., s.~ r'.~,,,l~ 7 5~8" X 7" C; sin- 7 .~.~v.,~, ?'~'o, ~;'-~...:.c,~; (T?~. .~:~.r..,.;,~- ;"~?). q/;-Y~r~'~"~- ?.,.,,"--_':.-G'_-7';:~ ""~'},"';'--.:'4,, T.~. ;.-'.,.z~-'/T: ~ ....... U 4 1/2" Pre-Packed screens li}.;.4,) !~ 7 ~"~'~'! '%" J~a'~2 F /I:~.~.32 7F. ~'~:7.~'.') ~. ~,~t~.~'~ :~'. n!. L~.'~ K .';.~;_~,~ :Y, 5~3; F '2,~.,":.~.a;: ?,;. ./!.On ,';' :;2:)2.,~. ~.' ~. ~.-'.,'~ £ ./~.%...' i 3-:.. T..:;:, .,'..' 47,~r...~.: .~,. 0 700 1400 21 O0 2800 3500 4200 4900 Scale: linch = 700ft (Target depths not hit on this plan) Vertical Section Section Azimuth: 0.503° (True North) . . DHllQuest North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-140 WPs Eastings Scale: linch = 700ff 0 4900--, -- 4900 4~oo- ~ - 4~oo 3500 - -- ~Be~n DJr ~ 6.~ */~00Jt : 6648.78~ M~. 3~95.8a~ TVD 3795.~ 2800 ~791.o4 ( /~ End Dlr, Start Sail e ~ z9.387 ': e~.eoftMD,379] - -- 2800 ~ Y'outt 2',*~', 'r ~nd D~, S~t Sail ~ }8.793 *: 5740,76~MD,3781,37~T~ O / ~nd D~, S{an Sail ~ S/,6~ ': 5499,5]~MD,377L48ffT~ Z 2100 - -- V.,~,,~ ~(, ~,( ~End Dlr, St~t Sail ~ 88.363 ': 5241.71~MD,3763.95~T~ ~B~n Dlr ~ 6,~ ~] ~ : 5157,78fl MD, 3759.93~ TVD 3756.23 ~ 1400 - ~ 1400 RECEIVE~ ,,~,~,~,~ ~7~.61 ~End Dlr, Start Sail ~, 88.657 ': 4645.~fiMD.3747.91~T~ N~a ~ & O~ Cons. Commiss~n 700 -a ~ ~.. D=, s,.. s,I700Jl~88'462 *: M~mge ' End Dlr, St~t SaJJ ~ 45.0~ *: 3535.~MD.3455.24~T~ Zo 0 ~ [[I g~gn DIr ~ 8.00 ~ 100~ : ~78~.0ffi MD. ~80.~ // 'End Dir, Sta~ Sail 0 0.~ ~: 1771.11ffMD,17~.1 ~B~inDir ~ 1.50=/1~ : 5~, ~ MD, ~0.~ ~D I 0 Scale: linch = 700ff Reference is True No~h RECEIVED SEP 07 2000 Alaska 0i.j & Gas Co,3s. Commission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -101.00 100.00 0.000 0.000 -1.00 200.00 0.000 0.000 99.00 300.00 0.000 0.000 199.00 400.00 0.000 0.000 299.00 500.00 0.000 0.000 399.00 560.00 0.000 0.000 459.00 600.00 0.600 100.000 700.00 2.100 100.000 800.00 3.600 100.000 499.00 598.97 698.84 893.33 5.000 100.000 791.91 900.00 5.093 100.421 798.55 1000.00 6.511 105.282 898.04 1100.00 7.960 108.395 997.24 1171.11 9.000 110.000 1067.57 1200.00 8.567 110.000 1096.12 1300.00 7.067 110.000 1195.19 1400.00 5.567 110.000 1294.58 1500.00 4.067 110.000 1394.22 1600.00 2.567 110.000 1494.05 1646.98 1.862 110.000 1541.00 1700.00 1.067 110.000 1594.00 1771.11 0.000 0.000 1665.11 1800.00 0.000 0.000 1694.00 1900.00 0.000 0.000 1794.00 Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs- 1D-140 WP9 Revised: 31 August, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 100.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 200.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 300.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 400.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 500.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 560.00 0.00 N 0.00 E 5959813.97 N 560490.55 E 600.00 0.04S 0.21 E 5959813.94 N 560490.76 E 699.97 -0.45 S 2.53 E 5959813.54 N 560493.08 E 799.84 1.31 S 7.42 E 5959812.72 N 560497.98 E 892.91 2.52 S 14.31 E 5959811.56 N 560504.88 E 899.55 2.63 S 14.89 E 5959811.46 N 560505.46 E 999.04 4.93 S 24.73E 5959809.24 N 560515.32 E 1098.24 8.61S 36.77 E 5959805.66 N 560527.39 E 1168.57 12.06 S 46.67 E 5959802.28 N 560537.31 E 1197.12 13.57 S 50.81 E 5959800.81 N 560541.47 E 1296.19 18.22 S 63.59 E 5959796.26 N 560554.29 E 1395.58 21.98 S 73.93 E 5959792.58 N 560564.65 E 1495.22 24.86 S 81.82 E 5959789.77 N 560572.57 E 1595.05 26.83 S 87.26 E 5959787.84 N 560578.02 E 1642.00 27.46 S 88.96 E 5959787.23 N 560579.73E 1695.00 27.92 S 90.24 E 5959786.78 N 560581.01E 1766.11 28.15 S 90.86 E 5959786.56 N 560581.63 E 1795.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 1895.00 28.15 S 90.86 E 5959786.56 N 560581.63 E Dogleg Rate (°/lOOft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 0.00 0.00 0.00 0.0o 0.o0 o.o0 0.00 -0.03 -0.42 -1.24 10 3/4" Casing Begin Dir @ 1.50°/100ft : 560.00ft MD, 560.00ft TVD -2.40 -2.50 -4.71 -8.28 -11.65 -13.12 -17.66 -21.33 -24.14 -26.07 Drop to Vertical at 1171.1 lft -26.67 -27.13 -27.35 -27.35 -27.35 Base Permafrost End Dir, Start Sail @ 0.000°: 1771.11ftMD,1766.1 lftTVD Continued... 5 September, 2000- 10:45 - 1 - DrillQuest 2.00.04 RECEIVED SEP 0 7 ; 000 Alaska 0~ & Gas CoNs. Commission Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 2000.00 0.000 0.000 1894.00 2100.00 0.000 0.000 1994.00 2133.00 0.000 0.000 2027.00 2200.00 0.000 0.000 2094.00 2300.00 0.000 0.000 2194.00 2400.00 0.000 0.000 2294.00 2500.00 0.000 0.000 2394.00 2600.00 0.000 0.000 2494.00 2700.00 0.000 0.000 2594.00 2785.00 0.000 0.000 2679.00 2800.00 0.900 10.000 2694.00 2900.00 6.900 10.000 2793.72 3000.00 12.900 10.000 2892.18 3050.41 15.924 10.000 2941.00 3100.00 18.900 10.000 2988.31 3200.00 24.900 10.000 3081.06 3300.00 30.900 10.000 3169.39 3319.47 32.068 10.000 3186.00 3399.55 36.873 10.000 3252.00 3400.00 36.900 10.000 3252.36 3500.00 42.900 10.000 3329.04 3535.00 45.000 10.000 3354.24 3600.00 45.000 10.000 3400.20 3603.96 45.000 10.000 3403.00 3653.97 45.000 10.000 3438.36 Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (fi) (ft) 1995.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2095.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2128.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2195.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2295.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2395.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2495.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2595.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2695.00 28.15 $ 90.86 E 5959786.56 N 560581.63 E 2780.00 28.15 S 90.86 E 5959786.56 N 560581.63 E 2795.00 28.03 S 90.88 E 5959786.67 N 560581.65 E 2894.72 21.33 S 92.06 E 5959793.38 N 560582.78 E 2993.18 4.41S 95.04 E 5959810.32 N 560585.62 E 3042.00 7.94 N 97.22 E 5959822.70 N 560587.70 E 3089.31 22.56 N 99.80 E 5959837.33 N 560590.16 E 3182.06 59.27 N 106.27 E 5959874.09 N 560596.34 E 3270.39 105.33 N 114.39 E 5959920.22 N 560604.09 E 3287.00 115.35 N 116.16 E 5959930.25 N 560605.78 E 3353.00 159.97 N 124.03 E 5959974.93 N 560613.28 E 3353.36 160.23 N 124.07 E 5959975.20 N 560613.33 E 3430.04 223.37 N 135.21E 5960038.43 N 560623.95 E 3455.24 247.30 N 139.43 E 5960062.38 N 560627.98 E 3501.20 292.56 N 147.41 E 5960107.71 N 560635.60 E 3504.00 295.32 N 147.89 E 5960110.47 N 560636.06 E 3539.36 330.14 N 154.03 E 5960145.34 N 560641.92 E Dogleg Rate (°/100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment -27.35 -27.35 -27.35 -27.35 -27.35 K-15 Sands -27.35 -27.35 -27.35 -27.35 -27.35 -27.23 -20.53 -3.58 8.80 23.43 60.20 106.33 116.36 161.05 161.32 Begin Dir @ 6.00~100ff : 2785.00ffMD, 2780.00ff TVD Ugnu C Sands Ugnu B Sands Ugnu A Sands 224.55 248.51 293.84 296.61 331.48 EndDir, S~ S~I @ 45.000° :3535.00ffMD,3455.24ffTVD K-13 Shale Top ML Window Joint Continued... 5 September, 2000 - 10:45 - 2 - DrillQuest 2.00.04 RECEIVED SEP 0 ? 2000 Alaska 0~i & Gas Coils. Commiss'Km Anchorage North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 3671.97 45.000 10.000 3451.09 3690.96 45.000 10.000 3464.51 3700.00 45.000 10.000 3470.91 3700.14 45.000 10.000 3471.01 3780.97 53.237 5.561 3523.88 3800.00 55.198 4.659 3535.00 3836.82 59.010 3.028 3555.00 3900.00 65.593 0.508 3584.35 3938.44 69.618 359.104 3599.00 4000.00 76.084 356.997 3617.14 4027.08 78.934 356.110 3623.00 4100.00 86.620 353.795 3632.16 4121.37 88.874 353.127 3633.00 4125.34 88.462 353.273 3633.09 4200.00 88.462 353.273 3635.10 4300.00 88.462 353.273 3637.78 4400.00 88.462 353.273 3640.46 4500.00 88.462 353.273 3643.15 4569.05 88.462 353.273 3645.00 4600.00 88.540 355.130 3645.81 4645.04 88.657 357.830 3646.91 4700.00 88.657 357.830 3648.20 4800.00 88.657 357.830 3650.54 4900.00 88.657 357.830 3652.89 5000.00 88.657 357.830 3655.23 Sperry-Sun Drilling Services Proposal Report for 1 D- 140 WPs - 1 D- 140 WP9 Revised: 31 August, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 3552.09 342.68 N 156.24 E 5960157.89 N 560644.03 E 3565.51 355.90 N 158.58 E 5960171.13 N 560646.25 E 3571.91 362.19 N 159.69 E 5960177.44 N 560647.31E 3572.01 362.30 N 159.70 E 5960177.54 N 560647.33 E 3624.88 422.78 N 167.82 E 5960238.09 N 560654.96 E 3636.00 438.16 N 169.19 E 5960253.48 N 560656.21 E 3656.00 469.00 N 171.25 E 5960284.33 N 560658.02 E 3685.35 524.88 N 172.94 E 5960340.22 N 560659.26 E 3700.00 560.41 N 172.82 E 5960375.75 N 560658.85 E 3718.14 619.16 N 170.80 E 5960434.49 N 560656.36 E 3724.00 645.55 N 169.21 E 5960460.86 N 560654.55 E 3733.16 717.55 N 162.83 E 5960532.81 N 560647.60 E 3734.00 738.76 N 160.40 E 5960554.00 N 560645.00 E 3734.09 742.71 N 159.93 E 5960557.94 N 560644.50 E 3736.10 816.82 N 151.19 E 5960631.98 N 560635.16 E 3738.78 916.10 N 139.48 E 5960731.16 N 560622.65 E 3741.46 1015.37 N 127.77 E 5960830.34 N 560610.14 E 3744.15 1114.65 N 116.06 E 5960929.52 N 560597.64 E 3746.00 1183.20 N 107.98 E 5960998.00 N 560589.00 E 3746.81 1213.98 N 104.85 E 5961028.76 N 560585.63 E 3747.91 1258.92 N 102.09 E 5961073.67 N 560582.50 E 3749.20 1313.82 N 100.01E 5961128.56 N 560579.98 E 3751.54 1413.72N 96.22 E 5961228.42 N 560575.39 E 3753.89 1513.62 N 92.44E 5961328.29 N 560570.80 E 3756.23 1613.53 N 88.65 E 5961428.16 N 560566,21E Dogleg Rate (o/looft) 0.00 0.00 0.00 0.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 11.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 344.03 357.28 363.58 363.68 424.24 439.63 470.48 526.37 561.90 620.64 Planned L1 Exit point Bottom ML Window Joint Begin Dir @ 11.00°/100ft : 3700.14ft MD, 3572.01ft TVD Planned Bridge Plug West Sak D Sand West Sak C Shale 647.01 718.95 740.14 744.08 818.12 917.29 1016.46 1115.63 1184.10 1214.85 West Sak B Sand 7 5/8" X 7" Casing End Dir, Start Sail @ 88.463° : 4125.34ftMD,3734.09ftTVD Begin Dir @ 6.00°/100ft : 4569.05ft MD, 3746.00ft TVD 1259.76 1314.65 1414.51 1514.38 1614,24 End Dir, Start Sail @ 88.657° :4645.04flMD,3747.91ffTVD Continued... 5 September, 2000 - 10:45 - 3 - DrillQuest 2.00.04 RECEIVED SEP 0 7 2_000 Alaska 0~ & Gas Co,~s. Commission North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 5100.00 88.657 357.830 3657.58 5157.78 88.657 357.830 3658.93 5200.00 86.129 357.992 3660.85 5202.15 86.000 358.000 3661.00 5241.71 88.363 357.776 3662.95 5300.00 88.363 357.776 3664.61 5400.00 88.363 357.776 3667.47 5472.80 88.363 357.776 3669.55 5487.08 88.000 357.000 3670.00 5499.51 87.600 357.630 3670.48 5500.00 87.600 357.630 3670.50 5600.00 87.600 357.630 3674.68 5700.00 87.600 357.630 3678.87 5720.83 87.600 357.630 3679.74 5727.50 88.000 357.632 3680.00 5740.76 88.793 357.703 3680.37 Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs- 1D-140 WP9 Revised: 31 August, 2000 5800.00 88.793 357.703 3681.62 5900.00 88.793 357.703 3683.73 6000.00 88.793 357.703 3685.83 6100.00 88.793 357.703 3687.94 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 3758.58 1713.43 N 84.87 E 5961528.02 N 560561.62 E 3759.93 1771.15 N 82.68 E 5961585.73 N 560558.97 E 3761.85 1813.29 N 81.14 E 5961627.86 N 560557.09 E 3762.00 1815.44 N 81.07 E 5961630.00 N 560557.00 E 3763.95 1854.92 N 79.61E 5961669.47 N 560555.23 E 3765.61 1913.14 N 77.35 E 5961727.67 N 560552.50 E 3768.47 2013.03 N 73.47 E 5961827.52 N 560547.82 E 3770.55 2085.74 N 70.65 E 5961900.22 N 560544.41 E 3771.00 2100.00 N 70.00 E 5961914.47 N 560543.64 E 3771.48 2112.41 N 69.42 E 5961926.87 N 560542.96 E 3771.50 2112.90 N 69.40 E 5961927.36 N 560542.94 E 3775.68 2212.72N 65.27 E 5962027.15 N 560538.00 E 3779.87 2312.55 N 61.14 E 5962126.94 N 560533.07 E 3780.74 2333.35 N 60.28 E 5962147.73 N 560532.04 E 3781.00 2340.00 N 60.00 E 5962154.38 N 560531.71 E 3781.37 2353.25 N 59.46 E 5962167.62 N 560531.06 E 3782.62 2412.43 N 57.09 E 5962226.78 N 560528.21 E 3784.73 2512.32 N 53.08 E 5962326.64 N 560523.40 E 3786.83 2612.22 N 49.07 E 5962426.50 N 560518.59 E 3788.94 2712.12 N 45.06 E 5962526.36 N 560513.78 E Dogleg Rate (°/lOOft) 0.00 0.00 6.00 6.00 6.00 0.00 0.00 0.00 6.00 6.00 0.00 0.00 0.00 0.00 6.00 6.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section 1714.11 1771.81 1813.94 1816.08 1855.54 1913.75 2o13.59 2086.28 210o.53 2112.94 2113.42 2213.21 2313.0o 2333.79 2340.44 2353.68 2412.83 2512.69 2612.55 2712.41 Comment Begin Dir @ 6.00°/100ft · 5157.78ft MD, 3759.93ft TVD End Dir, Start Sail @ 88.363° · 5241.71ftMD,3763.95ftTVD Begin Dir @ 6.00°/100ft · 5472.80ft MD, 3770.55ft TVD End Dir, Start Sail @ 87.600° · 5499.51ftMD,3771.48ftTVD Begin Dir @ 6.00°/100ft 5720.83ft MD, 3780.74ft TVD End Dir, Start Sail @ 88.793° · 5740.76ftMD,3781.37ftTVD Continued... 5 September, 2000 - 10:45 - 4 - DrillQuest 2.00.04 RECEIVED 8EP 0 7 2000 Oi' & Gas Cons. Comm North Slope AIssk8 Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 Alaska State Plane 4 Kuparuk 1 D Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 6186.06 88.793 357.703 3689.75 6197.78 88.800 357.000 3690.00 6200.00 88.920 356.943 3690.04 6208.60 89.387 356.721 3690.17 6300.00 89.387 356.721 3691.15 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (fi) (ft) (fi) 3790.75 2798.10 N 41.61 E 5962612.31 N 560509.64 E 3791.00 2809.79 N 41.07 E 5962624.00 N 560509.00 E 3791.04 2812.01 N 40.96 E 5962626.22 N 560508.87 E 3791.17 2820.60 N 40.48 E 5962634.80 N 560508.32 E 3792.15 2911.84 N 35.25 E 5962726.00 N 560502.36 E Dogleg Rate (°/lOOff) 0.00 6.00 6.00 6.00 0.00 Vertical Section 2798.35 2810.04 2812.26 2820.85 2912.04 Comment Begin Dir @ 6.00°/100ff : 6186.06ft MD, 3790.75ft TVD End Dir, Start Sail @ 89.387° : 6208.60ftMD,3791.17ftTVD 6400.00 89.387 356.721 3692.22 6500.00 89.387 356.721 3693.29 6600.00 89.387 356.721 3694.36 6648.78 89.387 356.721 3694.88 6680.80 90.200 358.461 3695.00 3793.22 3011.67 N 29.53 E 5962825.78 N 560495.84 E 3794.29 3111.50 N 23.81 E 5962925.56 N 560489.31 E 3795.36 3211.33 N 18.09 E 5963025.35 N 560482.79 E 3795.88 3260.03 N 15.30 E 5963074.02 N 560479.61 E 3796.00 3292.02 N 13.96 E 5963106.00 N 560478.00 E 0.00 0.00 0.00 0.00 6.00 3011.82 3111.59 3211.37 3260.04 3292.02 Begin Dir @ 6.00°/100ft : 6648.78ft MD, 3795.88ft TVD 6700.00 90.201 359.613 3694.93 6725.11 90.201 1.120 3694.84 6800.00 90.201 1.120 3694.58 6900.00 90.201 1.120 3694.23 7000.00 90.201 1.120 3693.88 3795.93 3311.22 N 13.63 E 5963125.19 N 560477.53 E 3795.84 3336.32 N 13.79 E 5963150.30 N 560477.48 E 3795.58 3411.20 N 15.26 E 5963225.18 N 560478.34 E 3795.23 3511.18 N 17.21 E 5963325.18 N 560479.49 E 3794.88 3611.16 N 19.16 E 5963425.17 N 560480.64 E 6.00 6.00 0.00 0.00 0.00 3311.21 3336.32 3411.20 3511.20 3611.19 End Dir, Start Sail @ 90.201 o : 6725.11ftMD,3795.84ftTVD .~,~. 7100.00 90.201 1.120 3693.53 7200.00 90.201 1.120 3693.18 7300.00 90.201 1.120 3692.82 7400.00 90.201 1.120 3692.47 7500.00 90.201 1.120 3692.12 7600.00 90.201 1.120 3691.77 7700.00 90.201 1.120 3691.42 7800.00 90.201 1.120 3691.07 7809.84 90.201 1.120 3691.03 7814.89 90.500 1.068 3691.00 3794.53 3711.14 N 21.12 E 5963525.16 N 560481.79 E 3794.18 3811.12 N 23.07 E 5963625.16 N 560482.94 E 3793.82 3911.10 N 25.03 E 5963725.15 N 560484.09 E 3793.47 4011.08 N 26.98 E 5963825.14 N 560485.24 E 3793.12 4111.06 N 28.93 E 5963925.13 N 560486.39 E 3792.77 4211.04 N 30.89 E 5964025.13 N 560487.54 E 3792.42 4311.02 N 32.84 E 5964125.12 N 560488.69 E 3792.07 4411.00 N 34.80 E 5964225.11N 560489.83 E 3792.03 4420.84 N 34.99 E 5964234.95 N 560489.95 E 3792.00 4425.89 N 35.09 E 5964240.00 N 560490.00 E 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 3711.19 3811.18 3911.17 4011.17 4111.16 4211.15 4311.15 4411.14 4420.98 4426.03 Begin Dir @ 6.00°/100ft : 7809.84ft MD, 3792.03ft TVD Continued... 5 September, 2000 - 10:45 - 5 - DrillQuest 2.00.04 RECEIVED SEP 0 7 2000 Al ka & Gas Cons. Commia North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (fi) (fi) Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (fi) (ft) (fi) 7820.06 90.766 1.227 3690.94 3791.94 4431.06 N 35.19 E 5964245.17 N 560490.07 E 7900.00 90.766 1.227 3689.87 3790.87 4510.98 N 36.90 E 5964325.10 N 560491.13 E 8000.00 90.766 1.227 3688.54 3789.54 4610.94 N 39.04 E 5964425.08 N 560492.47 E 8100.00 90.766 1.227 3687.20 3788.20 4710.91 N 41.18 E 5964525.06 N 560493.80 E 8114.94 90.766 1.227 3687.00 3788.00 4725.85 N 41.50 E 5964540.00 N 560494.00 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 1D-140 WPs. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from 1 D-D WPs and calculated along an Azimuth of 0.503° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8114.94ft., The Bottom Hole Displacement is 4726.03ft., in the Direction of 0.503° (True). Dogleg Rate (°/10Oft) 6.00 0.00 0.00 0.00 0.00 Alaska State Plane 4 Kuparuk 1 D Vertical Section Comment .A 4431.19 4511.13 4611.11 4711.09 4726.03 End Dir, Start Sail @ 90.766° · 7820.06ftMD,3791.94ftTVD Total Depth · 8114.94ftMD,3788.00ftTVD 4 1/2" Pre-pack screens Continued... 5 September, 2000 - 10:45 - 6 - DrillQuest 2.00.04 RECEIVED SEP 07 2000 Alaska 0~ & Gas Cons. Commission Anchorage North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 560.00 560.00 0.00 N 0.00 1171.11 1168.57 12.06 S 46.67 1771.11 1766.11 28.15 S 90.86 2785.00 2780.00 28.15 S 90.86 3535.00 3455.23 247.29 N 139.43 3671.97 3700.14 3780.97 4125.34 4569.05 4645.04 5157.78 5241.71 5472.80 5499.51 5720.83 5740.76 6186.06 6208.60 6648.78 3552.09 342.68 N 156.24 3572.01 362.29 N 159.70 3624.88 422.78 N 167.82 3734.09 742.70 N 159.93 3746.00 1183.20 N 107.98 3747.91 1258.92 N 102.09 3759.93 1771.15 N 82.68 3763.95 1854.92 N 79.61 3770.55 2085.74N 70.65 3771.48 2112.41 N 69.42 3780.74 2333.35 N 60.28 3781.37 2353.25 N 59.46 3790.75 2798.10 N 41.61 3791.17 2820.60 N 40.48 3795.88 3260.03 N 15.30 Comment Begin Dir @ 1.50°/100ft : 560.00ft MD, 560.00ft TVD Drop to Vertical at 1171.1 lft End Dir, Start Sail @ 0.000°: 1771.11ftMD,1766.1 lftTVD Begin Dir @ 6.00°/100ft : 2785.00ft MD, 2780.00ft TVD End Dir, Start Sail @ 45.000°: 3535.00ftMD,3455.24ftTVD Planned L1 Exit point Begin Dir @ 11.00°/100ft : 3700.14ft MD, 3572.01ft TVD Planned Bridge Plug End Dir, Start Sail @ 88.463°: 4125.34ftMD,3734.09ftTVD Begin Dir @ 6.00°/100ft : 4569.05ft MD, 3746.00ft TVD End Dir, Start Sail @ 88.657°: 4645.04ftMD,3747.91ffTVD Begin Dir @ 6.00°/100ft : 5157.78ft MD, 3759.93ft TVD End Dir, Start Sail @ 88.363°: 5241.71ftMD,3763.95ftTVD Begin Dir @ 6.00°/100ft : 5472.80ft MD, 3770.55ft TVD End Dir, Start Sail @ 87.600°: 5499.51ftMD,3771.48ftTVD Begin Dir @ 6.00°/100ft : 5720.83ft MD, 3780.74ft TVD End Dir, Start Sail @ 88.793°: 5740.76ftMD,3781.37ffTVD Begin Dir @ 6.00°/100ft : 6186.06ft MD, 3790.75ft TVD End Dir, Start Sail @ 89.387°: 6208.60ftMD,3791.17ftTVD Begin Dir @ 6.00°/100ft : 6648.78ft MD, 3795.88ft TVD Continued... 5 September, 2000 - 10:45 - 7 - DrillQuest 2.00.04 REOEIVED 8EP 0 7 2000 Alaska O~ & Gas Co~. ~mmission A.r~chorage Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 North Slope Alaska Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment Alaska State Plane 4 Kuparuk 1D Comments (Continued 6725.11 3795.84 7809.84 3792.03 7820.06 3791.94 3336.32 N 4420.84 N 4431.06 N 13.79 E 34.99 E 35.19 E End Dir, Start Sail @ 90.201° - 6725.11ftMD,3795.84ftTVD Begin Dir @ 6.00°/100ft · 7809.84ft MD, 3792.03ft TVD End Dir, Start Sail @ 90.766° · 7820.06ffMD,3791.94ftTVD Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 1541.00 0.000 0.461 2027.00 0.000 0.461 2941.00 0.000 0.461 3186.00 0.000 0.461 3252.00 0.000 0.461 3403.00 0.000 0.461 3555.00 0.000 0.461 3599.00 0.000 0.461 3623.00 0.000 0.461 Profile Measured Vertical Depth Depth (fi) (ft) 1646.98 1642.00 2133.00 2128.00 3050.41 3042.00 3319.47 3287.00 3399.55 3353.00 3603.96 3504.00 3836.82 3656.00 3938.44 3700.00 4027.08 3724.00 Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (st) 1541.00 27.46 S 88.96 E 2027.00 28.15 S 90.86 E 2941.00 7.94 N 97.22 E 3186.00 115.35 N 116.16 E 3252.00 159.97 N 124.03 E 3403.00 295.32 N 147.89 E 3555.00 469.00 N 171.25 E 3599.00 560.41N 172.82 E 3623.00 645.55 N 169.21E Formation Name Base Permafrost K-15 Sands Ugnu C Sands Ugnu B Sands Ugnu A Sands K-13 Shale West Sak D Sand West Sak C Shale West Sak B Sand Continued... 5 September, 2000 - 10:45 - 8 - DrillQuest 2.00.04 RECEIVED SEP 0 7 ~',~'~ Ala~a ~ & G~ Cons. Comm~s~n A~chorage North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1 D- 140 WPs - 1 D- 140 WP9 Revised: 31 August, 2000 Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Sudace> <Sudace> 3653.97 3539.36 3690.96 3565.51 <Sudace> <Sudace> <Sudace> <Su~ace> 500.00 500.00 3653.97 3539.36 3690.96 3565.51 4121.37 3734.00 8114.94 3788.00 Casing Detail 10 3/4" Casing Top ML Window Joint Bottom ML Window Joint 7 5/8" X 7" Casing 4 1/2" Pre-pack screens Targets associated with this wellpat Target Name 1 D-140 Fault I 1 D-140 Fault 2 1D-140_T1 1D-140_T2 1D-140_T3 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Target TVD (ft) 101.00 0.00 101.00 0.00 3734.00 3633.00 3746.00 3645.00 3762.00 3661.00 Entry Coordinate Northings Eastings (ft) (ft) Target Target Shape Type 2325.80 N 64.23 E Point 5962140.21 N 560536.05 E 70° 18' 25.6604" N 149° 30' 34.3871' 2364.81 N 63.54 E Point 5962179.22 N 560535.05 E 70° 18' 26.0441" N 149° 30' 34.4071" 5442466.40 S 5356423.27 E Point 560645.00 N 5960554.00 E 52° 51' 52.4216" N 125° 02' 59.9692" 5442525.98 S 5356866.81 E Point 560589.00 N 5960998.00 E 52° 51' 50.4447" N 125° 02' 53.7244" 5442563.06 S 5357498.53 E Point 560557.00 N 5961630.00 E Current Target Current Target 5 September, 2000 - 10:45 - 9 - DrillQuest 2.00.04 SEP 0 7 000 Alaska ~ & Gas Cons. ~mmission Anchorage North Slope Alaska Target Name 1D-140_T4 1D-140_T5 1D-140_T6 1D-140_T7 1D-140_T8 Sperry-Sun Drilling Services Proposal Report for 1D-140 WPs - 1D-140 WP9 Revised: 31 August, 2000 Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinate TVD Northings Eastings (ft) (fi) (ft) 52° 51'48.0569" N 125° 02' 44,5746" 3800.00 5442593.30 S 5358024.30 3699.00 560531.00 N 5962156.00 52° 51' 46.0751" N 125° 02' 36.9563" 3814.00 5442619.06 S 5358492.11 3713.00 560509.00 N 5962624.00 52° 51' 44.3219" N 125° 02' 30.1719" 3819.00 5442653.94 $ 5358973.84 3718.00 560478.00 N 5963106.00 52° 51' 42.4415" N 125° 02' 23.2305" 3815.00 5442651.07 S 5360107.90 3714.00 560490.00 N 5964240.00 52° 51'38.7762" N 125° 02' 06.4353" 3811.00 5442649.49 S 5360407.93 3710.00 560494.00 N 5964540.00 52° 51' 37.8138" N 125° 02' 01.9877" Alaska State Plane 4 Kuparuk 1D Target Target Shape Type E Point E E Point E E Point E E Point E E Point E 5 September, 2000 - 10:45 - 10 - DrillQuest 2.00.04 1 D-140 We'(S~ 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 KOP @ 3682' MD / 3559' 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 I Pup Joint 7-5/8" 29.7# L-80 BTC Mod Casing (Length 5'). 1 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/Intemal 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 07 2000 Alaska 0~; & Gas Cons~ Commission AnChorage MAC 08/30/OO 1 D-140 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 @ 5O0' (Gravel Isolation String) Production Casing 7-5/8' 29.7# L-80 BTC Mod RMLS to surface KOP @ 3682' MD / 3559' TVD Production Casing 7' 26# L-80 BTC Mod TD to RMLS 7' Casing Point @ 4121' MD / 3734' TVD RECEIVED :SEP 0 7 2000 Gas Cons, Commission An omge 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 (6.0" 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. I 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" Bakerweld 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 altemate 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. Liner Top Packer Set @ +/- 3971' MD TD B-Sand Lateral @ +/- 8116' MD/3811' TVD MAC 08/30/OO 1 D-140 West"=ak( Producer Multi Lateral w/Pre-Packed Screen Planned Completion- Phase 3 Nordic Rig #3 RKB @ O' 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 KOP @ 3682' MD / 3559' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS Sand Bridge Plug Upper Sperry Sperry 4-1/2' Baker Baker Baker Baker Baker Lateral 'Bonzai' Compl~':'~n (Run w/2-7/8" Hyd 511 Inner Wash Strina} 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 10'). 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 10'). 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 10'). 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 107. 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. 1 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 alternate Prepack Screen and Blank Pipe throuRh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4" HSLHT Box x 5" HSLHT Pin 1 Pup Joint 5" 15# L-80 HSLHT Tubing (Length 18'). Baker Model 'GPV' Set Shoe (5.560" Max OD). Bridge Plug Set @ +/- 5737' MD 'rD D-Sand Lateral @ +/- 9,502' MD / 3,707' I'VD RECEIVED 7" Casing Point @ 4121' MD / 3734' TVD Liner Top Packer Set @ +/- 3971' MD il SEP 0 7 2OO0 Alaska & Gas Coas, Commission An omge II .......... mq ) TD B-Sand Lateral @ +/- 8116' MD / 3811' TVD MAC 08/30/00 1 D-140 We~ Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 4 Nordic Rig #3 RKB @ O' 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 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 Cimulating 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" 'FTC Crossover Centrilift Tandem Seal Section: CST3 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 KOP @ 3682' MD / 3559' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 4121' MD / 3734' TVD 'TD D-Sand Lateral @ +/- 9,502' MD / 3,707' 'I'VD Liner Top Packer Set @ +/- 3971' MD RECEIVED SEP 07 2000 Alaska 0~ & Gas Cons, Commission Anchorage TD B-Sand Lateral @ +/- 8116' MD / 3,811' TVD MAC O8/3O100 (," 11" 5000 psi BOP St; 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. Obsen/e 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 arctic 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. 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 S c, 0 7 ,,,,. ! Gas Coas. An~0rage MAC 7/18/00 ( Port Collar Cementinq Practices · We will run a TAM Port Collar (see below for running details). · Circulate with casing on bottom at 10 bpm or greater if possible without losing returns. Equipment for the stage job consists of: · TAM Port collar · TAM Combo tool · TAM Choke Ensure that all connections are compatible or that there are appropriate crossovers available. If needed, TAM personnel can be available on site to check the equipment and confirm shear pin settings with prior notice. Run and cement with the Port Collar as follows: I. Check that all materials are at the rig site · 7 5/8" TAM Combo Tool, with 3-1/2" EUE Box by Pin and 7 5/8" 29.7 ppf Packer Cups · 7 5/8" TAM Port Collar with 7 5/8" BTCM Box x Pin Connections · Choke Sub with 3-1/2" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers II. Ensure that all connections are compatible or there are appropriate crossovers available III. Pick up and run 7 5/8" 29.7 ppf casing with Port Collar placed at 1000' TVD. Note: If packing off problems were seen around this depth when drilling or tripping, consult with the Drilling Engineer. · Install centralizers in the center of the joints above and below the port collar. IV. Pump first stage of cement job (spacer, lead and tail) as specified in Drilling Plan. Pump until the plug bumps and pressure up to 500 psi above circulating pressure to insure the plug has landed. If floats do not hold, maintain 1500 psi on casing for a minimum of 4 hours before rechecking. V. If cement is not returned to surface, a top job or use of the port collar will be required. The Arco company representative should review the attached decision tree is order to determine which method should be used. · Do top job using 1" tubing if good lead slurry cement did not circulate to surface. Run 1" tubing and tag top of previous cement job. If tubing does not tag, run it as deep as possible and contact the Arco drilling engineer or engineer on call to discuss options. Circulate while RIH to keep tubing from packing off. Flush annulus with water, then circulate annulus to cement. · AOGCC and Arco drilling engineer (or engineer on call) must be contacted prior to beginning top job. Do not proceed with top job without AOGCC approval. VI. If the Arco company representative determines that it is necessary to use the Port Collar, run in the hole with the 4" drillpipe until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. RECEIVED Port Collar Practices SEP 07 2000 I MAC, 09/06/00 Alaska 0~ & Gas Co~s. Commission Anchorage · In order to trip in with the 4" drillpipe and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. VII. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure VIII.Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. IX. Establish circulation rate and pressure X. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing Xl. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar XII. Pressure up on workstring to confirm collar is closed XllI.With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar XlV. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub XV. Reverse out excess cement as required XVI. Pull out of hole with tools Port Collar Practices 2 MAC, 09/06/00 ( KUparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement above Port / Collar (1000' 'i'VD)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Begin Primary One1 Stage Cement JobI Continue with Completion I / No Cement / / Cementto / to Surface Surface If Top Job is ineffective or unacceptable to AOGCC Cement below Port Collar (1000' TVD)/ Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion RECEIVED SEP 07 20OO A~aska Oil & Gas Cons. Co.~nmiss~ Anchorage Leak Off Test Procedure ( West Sak 1D-140 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. 2. Drill 20' to 50' of new hole below the casing shoe. . 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. R CEIVED SFD ~n~'~.0 0 7 Nas~.s 0~ & Gas Cons. Commission Anchorage MAC Page 1 09~06~00 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY September 07, 2000 Alaska Oil and Gas Conservation Commission 3001 Pomupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: West Sak 1 D-140 Surface Location: Target Location: Bottom Hole Location: 149' FSL, 595' FEL, Sec 14, T11N, R10E, UM 616' FSL, 423' FEL, Sec. 14, T11N, R10E, UM 406' FNL, 549' FEL, Sec. 14, T11N, R10E, UM Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore multilateral development well to the West Sak interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of 1D Pad, with two horizontal penetrations. This application is for the Permit to Drill the main well bore from surface to total depth of the horizontal penetration of the lower West Sak "B" Sand. Another application will be forthcoming for the Permit to Drill the upper lateral, designated 1 D-140 L1, a horizontal penetration of the West Sak "D" Sand. The well is designated as a horizontal producer using a 7-5/8" x 7" tapered casing string. A 4-1/2" x 4" Production Liner will be run 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 $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) 4) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing program is attached as 'per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. RECEIVED 'SEP 07 _000 Alaska & Gas Col s..C0mmis$ior 'Anch0m.qe 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). Also note that Phillips does not anticipate the presence of H=S 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 1D-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 log 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 (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is September 15, 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 1D-140 Well File Randy Thomas James Trantham RECEIVED SEP 07 2000 Alaska & Gas Cons. Commission An omge FIELD & POOL ~ ~ INIT CLASS~~-- E" i~ ~//._ GEOL AREA ADMINISTRATION ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... DATE 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... (~ .N. 16. CMT vol adequate to circulate on conductor & surf csg ..... N 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... ' --Y---N-- 22. Adequate 'wellbore separation proposed .............. ~ N 23. If diverter required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to .~(:~, psig. Y N 27. Choke manifold complies w/APl RP-53 (May 8-4) ........ ~ N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y dev v/reddl serv wellbore seg ann. disposal para req EE_Q SHORE Y N Y N Y N GEOLOGY,: ENGINEERING: UICIAnnul~. COMMISSION: 30. Permit can be issued wlo hydrogen sulfide measures ..... GEOLOGY 31. Data presented on potential overpressure zones ...... _. 32. · · · .- ........ '.' N 34. ss report N ANNULAR DISPOSAL35. With proper cementing records, this plan ~ ~n,~~'~e~.~'' ' (A) will contain waste in a suitable receiving zone; . . . .. APPR DATE , (B) willnot.contaminatefreshwater;orcausedrillingwas~e.'.- Y N . to surface; ~ (C) will not impair mechanical integrity of the well ~d for disposal; (D) will not damage producing formation or imp_,~recevery from a pool;, and ' / __ . (E) will not circumvent 20 AAC 25.252 or 2~. AAC 25.412. Commentsllnstructions: c:~rt~,office\wordian\diana\checklist (rev. 02117100) Z -i Well History File APPENDIX Information of detailed nature that is not 'particularly germane to the Well Permitting .Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file. under APPE .N. DIX~ o. No'special'eff0r[' has been' made to chronologically." .. ., organize this category of information. 1D140.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Jul 23 14:21:55 2001 Reel Header Service name ............. LISTPE Date ..................... 01/07/23 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 ..................... 01/07/23 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: 1D-140 API NUMBER: 500292297400 OPERATOR: PHILLIPS Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 23-JUL-01 # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-00202 A. WEAVER D. MICKEY MWD RUN 5 AK-MM-00202 R. MCNEILL DINK 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: 1D140.tapx 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 510.0 9.875 7.875 3682.0 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-140 IS TIED INTO 1D-140L1 AT THE KICKOFF POINT (TOP OF WHIPSTOCK).. THIS WELL KICKS OFF FROM 1D140L1 AT 3682' MD, 3550" 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. 4. 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/23 Maximum Physical Record..65535 File Type ................ LO Page 2 1D140.tapx 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 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 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 502.0 3682.0 5 3682.5 7659.5 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 1D140.tapx 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 Mean Nsam Reading 4080.75 14316 502 123.514 14300 510 71.5859 14191 502 33.284 14205 502 64.1926 14205 502 68.1456 14205 502 67.4814 14205 502 1.10549 14205 502 Last Reading 7659.5 7659.5 7597 7604 7604 7604 7604 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 ....... 01/07/23 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 ....... 01/07/23 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 FET 502.0 RPD 502.0 RPS 502.0 GR 502.0 RPM 502.0 ROP 510.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 3682.0 3682.0 3682.0 3682.0 3682.0 3682.0 3682.0 Page 4 26-SEP-00 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: 1D140.tapx 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 Insite 4.05.5 65.41 Memory 3681.9 .1 8O.7 TOOL NUMBER PB01660HWGRM6 PB01660HWGRM6 9.875 LSND 9.40 120.0 8.8 500 4.0 2.100 1.341 1.980 3.500 Name Service Order Units Size Nsam Rep Code Offset Channel Page 5 72.0 116.6 72.0 72.0 DEPT FT 4 ROP MWD010 FT/H 4 GR MWD010 API 4 RPX MWD010 OHMM 4 RPS MWD010 OHMM 4 RPM MWD010 OHMM 4 RPD MWD010 OHMM 4 FET MWD010 HR 4 1D140.tapx 1 68 0 1 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 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 R?D MWD010 OHMM 1.28 2000 FET MWD010 HR 0.4 4.57 Mean Nsam 2092 6361 112.652 6345 67.1311 6361 25.4858 6361 40.2421 6361 64.6087 6361 68.9012 6361 0.93056 6361 First Reading 502 510 502 502 502 502 502 502 Last Reading 3682 3682 3682 3682 3682 3682 3682 3682 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 ....... 01/07/23 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 ....... 01/07/23 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 6 RPD 3682.5 RPM 3682.5 RPS 3682.5 RPX 3682.5 GR 3682.5 ROP 3682.5 FET 3682.5 $ 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): 1D140.tapx 7604.0 7604.0 7604.0 7604.0 7597.0 7659.5 7604.0 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 7 Data Format Specification Record Data Record Type .................. 0 17-OCT-00 Insite 4.05.5 65.44 Memory 7663.0 48.7 92.1 TOOL NUMBER PB01672H4 PB01672H4 6.000 Water Based 9.80 58.0 9.0 110000 3.2 .O60 .044 .100 .080 65.0 91.4 65.0 65.0 1D140.tapx 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 MWD050 FT/H 4 1 68 GR MWD050 API 4 1 68 RPX MWD050 OHMM 4 1 68 RPS MWD050 OHMM 4 1 68 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 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 3682.5 7659.5 ROP MWD050 FT/H 3.34 892.46 GR MWD050 A?I 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 First Last Mean Nsam Reading Reading 5671 7955 3682.5 7659.5 132.178 7955 3682.5 7659.5 75.2049 7830 3682.5 7597 39.6079 7844 3682.5 7604 83.615 7844 3682.5 7604 71.0138 7844 3682.5 7604 66.3301 7844 3682.5 7604 1.24734 7844 3682.5 7604 First Reading For Entire File .......... 3682.5 Last Reading For Entire File ........... 7659.5 Fiie Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/07/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/07/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Page 8 Scientific Technical Services 1D140.tapx Reel Trailer Service name ............. LISTPE Date ..................... 01/07/23 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 9 Sperry-Sun Drilling Services LIS Scan Utility 1D140.tapx SRevision: 3 $ LisLib SRevision: 4 $ Thu Aug 23 15:27:44 2001 Reel Header Service name ............. LISTPE Date ..................... 01/08/23 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 ..................... 01/08/23 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: MWD RUN 1 AK-MM-00202 A. WEAVER D. MICKEY 1D-140 500292297400 PHILLIPS Alaska, Inc. Sperry Sun 17-JUL-01 MWD RUN 2 MWD RUN 3 AK-MM-00202 AK-MM-00202 A. WEAVER A. WEAVER D. HEIM D. HEIM 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 MWD RUN 4 AK-MM-00202 A. WEAVER D. HEIM 14 liN 10E 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 149 595 .00 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 510.0 9.875 7.875 4185.0 Page 1 REMARKS: 1D140. t apx ***THIS DATA SUPERCEDES ALL PREVIOUS LDWG DATA FOR WELL 1D-140 *** ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. MWD RUNS 1 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. GAMMA RAY LOGGED BEHIND CASING FROM 4099' MD, 3732' TVD TO 4158' MD, 3740' TVD. 1D-140 IS TIED INTO 1D-140 PB1 AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM 1D140 PB1 AT 5493' MD, 3742' TVD. MWD DATA 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. 5o MWD RUNS 1 - 4 REPRESENT WELL 1D-140 WITH API # 50-029-22974-00. 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 **** THIS DATA SUPERCEDES ALL PREVIOUS LDWG DATA FOR WELL 1D-140 ***** $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 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 FET 502.0 RPD 502.0 RPM 502.0 RPS 502.0 RPX 502.0 GR 502.0 ROP 510.0 STOP DEPTH 8072.5 8072.5 8072.5 8072.5 8072.5 8065.5 8116.0 Page 2 1D140.tapx BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 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. $ 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 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 502 8116 4309 15229 502 ROP MWD FT/H 2.66 466.17 114.352 15213 510 GR MWD API 15.85 117.33 68.0085 15128 502 RPX MWD OHMM 0.09 1870.36 32.114 15142 502 RPS MWD OHMM 0.1 2000 45.9905 15142 502 RPM. MWD OHMM 0.09 2000 58.8644 15142 502 RPD MWD OHMM 0.51 2000 65.6724 15142 502 FET MWD HR 0.27 76.61 1.52622 15142 502 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 ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Last Reading 8116 8116 8065.5 8072.5 8072.5 8072.5 8072.5 8072.5 Physical EOF File Header Service name ............. STSLIB.002 Page 3 1D140.tapx Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 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 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 (DES MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. REGIS. 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: STOP DEPTH 4109.0 4098.5 4109.0 4109.0 4109.0 4109.0 4164.5 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 50O 4.0 2.100 1.341 1.980 3.500 72.0 116.6 72.0 72.0 Page 4 1D140.tapx 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 DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 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 Units Size Nsam Rep 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 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 2333.25 109.126 69.3272 24.0505 37.3172 58.987 62.7708 1.03163 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 ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 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 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 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 STOP DEPTH Page 5 GR 4099.0 RPS 4109.5 FET 4109.5 RPD 4109.5 RPX 4109.5 RPM 4109.5 ROP 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: 4121.5 4128.5 4128.5 4128.5 4128.5 4128.5 4184.5 1D140.tapx 29-SEP-00 Insite 4.05.5 65.44 Memory 4185.0 80.7 80.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01667FGR4 EWR4 ELECTROMAG. RESIS. 4 PB01667FGR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.000 BOREHOLE CONDITIONS MUD TYPE: BARADRIL-N MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 65.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 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 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 Page 6 .0 .0 .0 .0 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 1D140,tapx 12 16 20 24 28 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 494,82.5 1335,77 66,2262 First Reading For Entire File .......... 4099 Last Reading For Entire File ........... 4184.5 File Trailer Service name ............. STSLIB,O03 Service Sub Level Name,,, Version Number ........... 1,0.0 Date of Generation ....... 01/08/23 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,004 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 Physical EOF File Header Service name ............. STSLIB,004 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 01/08/23 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: 02-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): 5493,0 TOP LOG INTERVAL (FT): Page 7 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: 1D140.tapx 84.6 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 TOOL NUMBER PB01646HAGRV4 PB01646HAGRV4 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: BARADRI L-N 10.10 53.0 8.5 120000 3.8 .060 .047 .040 .190 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 Name Service Order DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 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 First Last Mean Nsam Reading Reading 4807.5 2743 4122 5493 119.572 2617 4185 5493 66.2323 2743 4122 5493 46.0679 2729 4129 5493 62.78 2729 4129 5493 66.7941 2729 4129 5493 81.3677 2729 4129 5493 Page 8 FET MWD030 HR 0.27 76.61 First Reading For Entire File .......... 4122 Last Reading For Entire File ........... 5493 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 1D140.tapx 3.01897 2729 4129 5493 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Previous File 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: 04-OCT-00 SOFTWARE SURFACE SOFTWARE VERSION: In$ite 4.05.5 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8117.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.8 MAXIMUM ANGLE: 92.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01646HAGRV4 EWR4 ELECTROMAG. RESIS. 4 PB01646HAGRV4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS Page 9 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 HR 4 1 68 1D140.tapx BARADRIL-N 9.90 52.0 8.5 70000 3.4 .060 .047 .040 .190 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 72.0 93.2 72.0 72.0 Name Service Unit Min Max DEPT FT 5493.5 8116 ROP MWD040 FT/H 4.07 245.24 GR MWD040 API 41.48 106.74 RPX MWD040 OHMM 4.25 1777.33 RPS MWD040 OHMM 7.7 2000 RPM MWD040 OHMM 10.49 2000 RPD MWD040 OHMM 12.02 2000 FET MWD040 HR 0.33 10.04 Mean 6804.75 119.042 67.3987 36.2253 49.5385 51.2026 51.8266 0.939201 First Reading For Entire File .......... 5493.5 Last Reading Fo~ Entire File ........... 8116 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/08/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Nsam 5246 5246 5145 5159 5159 5159 5159 5159 First Reading 5493.5 5493.5 5493.5 5493.5 5493.5 5493.5 5493.5 5493.5 Last Reading 8116 8116 8065.5 8072.5 8072.5 8072.5 8072.5 8072.5 Page 10 1D140.tapx Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/08/23 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 ..................... 01/08/23 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 1D140PBl.txt Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Sep 21 08:59:19 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 MWD RUN 1 AK-MM-00202 A. WEAVER D. MICKEY 1D-140 PB1 500292297470 PHILLIPS Alaska, Inc. Sperry Sun 21-SEP-01 MWD RUN 2 MWD RUN 3 AK-MM-00202 AK-MM-00202 A. WEAVER A. WEAVER D. HEIM D. HEIM 14 11N 10E 149 595 .00 101.50 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 510.0 9.875 7.875 4158.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING Page 1 REMARKS: 1D140PBI.txt ***THIS DATA SUPERCEDES ALL PREVIOUS LDWG DATA*** PREVIOUSLY LABELED 1D-140 L1 PB1 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 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. GAMMA RAY LOGGED THROUGH CASING FROM 4099'MD,3732' TVD TO 4158'MD, 3740'TVD. 4. 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. 5. MWD RUNS 1-3 REPRESENT WELL 1D-140 PB1 WITH API 9 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 ***THIS DATA SUPERCEDES ALL PREVIOUS LDWG DATA*** PREVIOUSLY LABELED 1D-140 L1 PB1 $ 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 Co~ent 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: Page 2 1D140PBl.txt CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: 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 i 68 8 3 RPX MWD OH/~M 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OPE~M 4 1 68 24 7 FET MWD HR 4 i 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 502 6156.5 3329.25 11310 502 ROP MWD FT/H 2.66 466.17 106.922 11294 510 GR MWD API 15.85 124.03 70.5517 11209 502 RPX MWD OHMM 0.09 1870.36 29.389 11223 502 RPS MWD OPH~M 0.1 2000 42.915 11223 502 RPM MWD OHMM 0.09 2000 59.6373 11223 502 RPD MWD OHMM 0.51 2000 68.5241 11223 502 FET MWD HR 0.27 76.61 1.89081 11223 502 Last Reading 6156.5 6156.5 6106 6113 6113 6113 6113 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 ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Page 3 1D140PBl.txt 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: 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: 26 - SEP- 00 SOFTWARE 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 TOOL NUMBER DGR DUAL GAMMA RAY PB01660HWGRM6 EWR4 ELECTROMAG. RESIS. 4 PB01660HWGRM6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT) : 4158.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 120.0 MUD PH: 8.8 ~ CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2. 100 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.341 116.6 MUD FILTRATE AT MT: 1.980 72.0 MUD CAKE AT MT: 3.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN):.- TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 4 1D140PBl.txt 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 ROP MWD010 FT/H 4 i 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 i 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OH~5~ 4 1 68 FET MWD010 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 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 O~ 1 2000 RPM MWD010 OH/~M 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 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 ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ..... : ..... STSLIB.003 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 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 ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 5 1D140PBl.txt 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 FET 4109.5 4128.5 RPD 4109.5 4128.5 RPM 4109.5 4128.5 RPS 4109.5 4128.5 RPX 4109.5 4128.5 ROP 4165.0 4184.5 $ LOG HEADER DATA DATE LOGGED: 29-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4185.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.7 MAXIMUM ANGLE: 80.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01667FGR4 EWR4 ELECTROMAG. RESIS. 4 PB01667FGR4 $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 65.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 Page 6 1D140PBl.txt Max frames per record ............. Undefined Absent value ...................... -999 DeDth 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 OH~SH 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 Min Max Mean Nsam DEPT FT 4099 4184.5 4141.75 172 ROP MWD020 FT/H 29.12 154.43 113.015 40 GR MWD020 API 27.66 49.21 35.9176 46 RPX MWD020 OHMM 2.7 5.63 3.60744 39 RPS MWD020 OHI~M 4.17 9.38 6.39282 39 RPM MWD020 OHMM 0.09 2000 494.825 39 RPD MWD020 OHMM 5.65 2000 1335.77 39 FET MWD020 HR 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 ........... 4184.5 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 ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 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.003 Comment Record FILE HEADER FILE NI/MBER: 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 Page 7 FET 4129.0 ROP 4185.0 $ 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 $ BOREHOLEAND 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 1D140PBl.txt 6113.0 6156.5 02-0CT-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 .O6O .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 Page 8 72.0 93.2 72.0 72.0 1D140PBl.txt RPM MWD030 OHMM 4 1 68 20 RPD MWD030 OHMM 4 1 68 24 FET MWD030 HR 4 1 68 28 Name Service Unit Min Max Mean DEPT FT 4122 6156.5 5139.25 ROP MWD030 FT/H 4.45 316.15 102.777 GR MWD030 API 38.26 124.03 73.1726 RPX MWD030 OHMM 0.09 1819.8 39.3469 RPS MWD030 OHMM 0.1 1706.58 53.4496 RPM MWD030 OHMM 0.11 2000 56.5431 RPD MWD030 OHMM 0.51 2000 66.5307 FET MWD030 HR 0.27 76.61 2.8205 First Last Nsam Reading Reading 4070 4122 6156.5 3944 4185 6156.5 3969 4122 6106 3969 4129 6113 3969 4129 6113 3969 4129 6113 3969 4129 6113 3969 4129 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 ....... 01/09/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 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 Page 9