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Home My WebLink About185-242185-242 T38919 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:12:36 -08'00' • • C) 2...0Q., _ ' H ,+ x 6J ci) o :;c::., 3 Y . T 21 w �c o v E v 0 uo *c 0 v o c a c c co — c +� (\ V d (0 a% (0 '?' 'O O L u Q �//'�� Y E 0- m U' F p N w Q a1 O i J (` Q❑ J <Q'm w co {o m m m CO co CD m CO O O t N u N too ¢� l7 Y L -D 0 i < r < a 6) 6) 8) 6) m a) 6) a s E Y 0 J Q Q Q Q Q Q Q Q Q Q u, Y L c Nf N t0 N a0 N O r r N ou •D cc 0 *' Q N N N N N N N N M co • U to z Q O C v z Q ,C-, a + o O C C N v Ln Q U ❑ ❑ ❑ ❑ o ❑ ❑ ❑ ❑ ❑ ❑ ❑ LU J J J J J J J J J J J Jvl C `'- L.) O CL LULLJUJLULLILLIW UJUJUJUJUI v a v a O Q J J J J J J J J J J J J u N O O I!) H' Q Q Q Q Q Q Q Q a Q Q Q O• O) o Z Z Z Z Z Z ZZZZZZ -C _ > LL LL LL LL LL U. 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V CO cv (0 Z ECj C Wr C cia w r al= w eC v 9Z6ilio, p( QfCo O O a a OfO 0 .0 O O r O O O r O N FOE Y C 0) aQN W N M M V) VI@ 3 CO CD 03 tb 0 a • Pro /85- z4pZ Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Thursday, May 23, 2013 10:57 AM To: 'Bearden, J Daniel' Subject: RE: 3F -05 (PTD# 185 -242) RWO Sundry #313 -211 Daniel, BOP test to 3000 psi approved as outlined below. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer SCANNED JUN 1 4 L01J State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(7a alaska.gov From: Bearden, 3 Daniel [mailto :J. Daniel .Bearden @conocophillips.com] Sent: Thursday, May 23, 2013 10:41 AM To: Ferguson, Victoria L (DOA) Subject: 3F -05 (PTD# 185-242) RWO Sundry #313 -211 Victoria, After further investigation into the subsidence RWO of Kuparuk producer 3F -05, we will need to perform a BOP test after the damaged upper 7" production casing has been removed from the well. As such, we request that the particular BOP test be limited to 250/3,000 psi due to the max working pressure of the casing head. Wellhead: Tree: FMC Gen III, 3 -1/8" 5M Tbg Adapter: 3 -1/8" 5M top x 7 -1/16" 5M bottom Tbg Head: 7- 1/16" 5M top x 11" 3M bottom Tbg Hanger: 3 -1/2 x 7 -1/16" BTC, 1 port Casing Head: 11" 3M top flange Casing Hanger: 7" 3" ISA BPV Approved Alaska State Sundry Letter #313 -211 states a required BOP test pressure of 3,500 psi. This is fine for our initial BOP testing during MIRU, but we request the BOP test after the 7" is removed to be limited to 3,000 psi. Regards, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 1 �PV OF /T�4', THE STATE Alaska Oil and Gas F l�� fALAS� Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue omr "' Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dan Bearden SCAtaiED A } 1 0 Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 5 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3F -05 Sundry Number: 313 -211 Dear Mr. Bearden: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P.204.f4kL- Cathy P. oerster �,�/� Chair /t " DATED this day of May, 2013. Encl. II ; ° STATE OF ALASKA . •KA OIL AND GAS CONSERVATION COMMISSIO o „be /3 . c 11 3 APPLICATION FOR SUNDRY APPROVALS $1.04 c- /O 20 AAC 25.280 ., C 1. Type of Request: Abandon E Plug for Redrill 1 Perforate New Pool ( Repair w ell I✓ - Change Approved Program E Suspend E Plug Perforations r Perforate r Pull Tubing Time Extension 1 Operational Shutdown E Re -enter Susp. Well E Stimulate f Alter casing I✓ - Other: I_._.. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Iv • Exploratory l 185 -242 • 3. Address: Stratigraphic (— Service { — 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 21460 - 00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No :`% 3F -05 , 9. Property Designation (Lease Number): I l I S 10. Field /Pool(s): ADL 25643 t ,'(,S (e..52._ Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 8875 • 6390 8683' 6253' • 8167' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3937 9.625 3974' 3094' PRODUCTION 8738 7 8773' 6317' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8204' 8280', 8406 8447', 8462' - 8504' 5916 5969', 6059' 6086', 6096 3.5 x 2.875 J - 55 8346 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER • MD= 8135 TVD= 5869 PACKER - BAKER FB -1 PACKER ' MD= 8324 TVD= 5999 SSSV - CAMCO TRDP -1A • MD =1797 TVD =1668 12. Attachments: Description Summary of Proposal • (y 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch ( Exploratory l Stratigraphic r Development 141. Service (mm 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/7/2013 Oil i✓ ■ Gas (.-- WDSPL r Suspended (-" 16. Verbal Approval: Date: VVINJ f" GINJ (— WAG I- Abandoned E Commission Representative: GSTOR (-- SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Bearden @ 263 -4864 Email: beardid(a).conocoohillios.com Printed Name Dan Beard Title: Drilling Engineer Q/ Signature , O frrzrk9A...—/• Phone: 263 -4612 Date q /3 3 Commission Use Only Sundry Number: ,, 3 _ 2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 1 BOP Test - Mechanical Integrity Test E Location Clearance r- RBDMS MAY 1 0 1013 Other: n OP f 7 f 1-a X J - 0 p s 1 Spacing Exception Required? Yes ❑ No E7i Subsequent Form Required: / d 4- b APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: S — (� pproved application is valid for 12 months date of approval. '�1 Form 10 -403 (Revised 10/2012) tJ R I G I N A , V G r i ,' Submit Form and Attachments in Duplicate 1\�.� \�o,� / / /1j • . • Illv RECEIVED ConocoPhillips MAY D 20'3 Alaska P.O. BOX 100360 AOGGO ANCHORAGE, ALASKA 99510 -0360 April 30, 2013 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 Kuparuk Producer Well 3F -05 (PTD# 185 -242). Producing well 3F -05 was drilled and completed in 1985 as an NC sand producer. A surface casing leak around 114' MD was discovered and addressed with Brinker Platelets in January 2009. The well was returned to service until the Brinker Platelets failed in December 2010, when the well was granted a waiver for production without lift gas. The well produced under the waiver until it failed an MIT -IA in February 2012. Leak detect logging diagnostics indicated a leak in the 7" production casing around 3,272' MD. This invalidated the waiver to produce and the well was shut -in and secured with a wireline retrievable plug set below the top packer. A rig workover is required to perform a subsidence -style remediation to address the surface casing leak, and patch over the deeper production casing leak. This subsidence -style fix consists of pulling the 3.5" tubing, cutting and pulling, and backing off the 7" production casing above the top of the Arctic pack cement, running new premium TCII 7" production casing with a cementing stage tool to cement the OA (7" x 9 -5/8" annulus) to surface, installing an expandable 7" casing patch over the deeper leak, and running new 3.5" tubing. This Sundry is intended to document the proposed change to the production casing as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 263 -4864. Sin rely, 15.MjEe0 Daniel Bearden Drilling Engineer CPAI Drilling and Wells • 3F -05 Kuparuk Producer Rig Workover (PTD #: 185 -242) Current Status A surface casing leak around 114' MD was discovered and addressed with Brinker Platelets in January 2009. The well was returned to service until the Brinker Platelets failed in December 2010, when the well was granted a waiver for production without lift gas. The well produced under the waiver until it failed an MIT -IA in February 2012. Leak detect logging diagnostics indicated a leak in the 7" production casing around 3,272' MD. This invalidated the waiver to produce and the well was shut -in and secured with a wireline retrievable plug set below the top packer. Scope of Work A rig workover is required to perform a subsidence -style remediation to address the surface casing leak, and patch over the deeper production casing leak. This subsidence -style fix consists of pulling the 3.5" tubing, cutting and pulling, and backing off the 7" production casing above the top of the Arctic pack cement, running new premium TC -Il 7" production casing with a cementing stage tool to cement the OA (7" x 9 -5/8" annulus) to surface, installing an expandable 7" casing patch over the deeper leak, and running new 3.5" tubing. This Sundry is intended to document the proposed change to the production casing as well as request approval to workover the well. General Well info MASP: 2,161 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure/TVD: 2,770 psi at 6,090' TVD SBHP taken on 1/8/09 Wellhead type /pressure rating: WKM (Cameron), Gen V, 11" 5K BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT Results: MIT -IA failed 2/9/2012 Well Type: Kuparuk Producer Estimated Start Date: June 7, 2013 Production Engineer: Suzanne Short Drlg / RWO Engineer: Daniel Bearden (263 -4864 / beardjd @ConocoPhillips.com) Pre -Riq Work Request 1. Obtain new SBHP. 2. PT tubing and casing packoffs, function test lockdown screws. 3. Set BPV. Proposed Procedure 1. MIRU Nordic 3. 2. Pull BPV. Load well with 9.6 ppg NaCI brine. Ensure well is dead. Set BPV. ND tree. 3. NU 11" 5M BOP. Install blanking plug. Pressure test BOP including annular to 250/3500 psi. Pull blanking plug and BPV. 4. MU landing joint, BOLDS, POOH laying down tubing and spooling up control line 5. RIH w/ 7" casing scraper on 3 -1/2" drillpipe to top of PBR and circulate well clean. POOH and lay down casing scraper. 6. RU E -line, RIH w/ caliper, gyro, CAST -M w/ CBL and log from PBR to surface to determine condition and TOC (arctic pack job). Fire string shot across 2 collar above TOC. • 7. RIH w/ 7" test packer, set test packer at 3,300' MD. Test below test packer to 2,500 psi. Test back side to 2,500 psi. (Back side should leak off due to 7" casing leak at 3,272' MD). a. If PT below test packer at 3,300' MD passes, work test packer uphole to isolate leak in 7" casing. POOH standing back drillpipe. b. If PT below test packer at 3,300' MD fails, release test packer, RIH to 8,100' MD, set test packer, PT below test packer to 2,500 psi (testing upper selective packer and WRP in tubing). i. If PT below test packer at 8,100' MD fails, POOH standing back DP, RIH w/ RBP & test packer, set RBP at 8,100' MD. Release from RBP, pickup one stand, set test packer, test RBP to 2,500 psi. Work test packer uphole to locate leaks in 7" casing. POOH standing back drillpipe. ii. If PT below test packer passes, release test packer and work test packer uphole to locate leaks in 7" casing. POOH standing back drillpipe. 8. RIH & set an RBP above the top casing leak and below TOC which is estimated at 1,850' MD. PT to 3,000 psi and drawdown test to 0 psi. Dump 50' of sand on top of plug. POOH standing back ✓ drillpipe. 9. ND BOP stack, ND tubing head using Hydratight Tensioners, spear the 7" casing and re -land in slips. Cut off excess casing growth with Wachs cutter. Tack weld slips to casing. 10. NU BOP stack to casing head. 11. RIH w/ 5 -1/2" multi- string cutter, cut the 7" casing stub, circulate well clean. POOH standing back drillpipe. 12. Circulate out the arctic pack from the OA w/ heated diesel & seawater. 13. Spear the 7" casing and POOH laying down. 14. RIH w/ a 9 -5/8" casing scraper to the top of the 7" stub, circulate well clean. POOH standing back drillpipe. 15. RIH w/ the backoff tool to top of the 7" stub, engage 7" casing stub and backoff. POOH standing back drillpipe. 16. RIH w/ 7" casing spear, retrieve 7" casing stub. POOH standing back drillpipe. 17. RU GBR casing crew & RIH w/ new 7" TC -II casing and ES cementer, screw into top of 7" casing, PT casing to 3,000 psi. 18. RU SLB cementers, cement the 7" x 9 -5/8" annulus to surface. 19. ND BOPE, pull 7" casing in tension and land in slips. Cut excess 7" casing w/ Wachs cutter. NU new tubing head & BOP stack, PT BOP's. 20. RIH w/ 6 -1/8" mill tooth bit to TOC, drill up cement, closing plug, and ES cementer. RIH w/ 6 -1/8" concave mill and dry drill any remaining debris on top of sand. RIH w/ wash string assembly and circulate out sand on top of the RBP /IBP. POOH standing back drillpipe. 21. RIH w/ RBP retrieving head to top of plug, swap well back to 9.6 ppg NaCI brine, engage RBP and pull to release. POOH standing back drillpipe. a. If upper selective packer did not test from Step #7b -i, RIH w/ RBP retrieving head to top of RBP at 8,100' MD, engage RBP and pull to release. POOH standing back drillpipe. b. MU FHL stack packer & seal assembly, RIH to just above the PBR. Spot corrosion inhibited brine in the IA below the FHL packer. Sting into PBR until fully located. PU to neutral weight + 1'. Drop a ball & rod, set the FHL packer. Shear the PBR. POOH standing back drillpipe. III • 22. PU lower Weatherford Metal -skin 1 -trip patch, RIH to depth below bottom 7" casing damage as determined from 7" casing caliper and casing pressure tests. Set 7" Metal -skin expandable straddle patch across damaged area. Release from patch, POOH standing back drillpipe. 23. RIH w/ new 3 -1/2" IBTM -SCC w/ KGB2 -9 gaslift mandrels to just above the PBR, engage the PBR until fully located, space out 7' off bottom, mark the pipe and pull out of the PBR. 24. Space out w/ pups, MU hanger. Spot corrosion inhibited brine in the IA below the bottom GLM. Land hanger, RILDS. 25. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 26. Pull the landing joint, install the two -way check. 27. Swap well over to corrosion inhibited seawater. 28. Freeze protect through the open SOV, set BPV. 29. RDMO Nordic 3. Post -Rig Work request: 1. Reset well house and flowline. 2. Pull BPV. 3. Pull SOV and install DV. 4. RU slickline: Pull SOV, replace w/ DV. Pull ball & rod if necessary. Pull catcher sub, pull plug. 5. Turn well over to Operations. Il • KUP 3F -05 ConocoPhillips , ; ;1,310E4 Well Attributes Max Angle & MD TD Alasi 8 Inc Wa Wellbore APBUWI Field Name Well Status Inc! ( °) MD (RKB) Act Btm (ftK8) Lai d1,p 500292146000 KUPARUK RIVER UNIT PROD 51.65 2,500.00 8,875.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: LOCKED OUT 250 11/21/2011 Last WO: 41.00 10/21/1985 Well Contio - 3F -05, 10119/2012 - Soh tic- Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,567.0 2/15/2012 Rev Reason: WELL REVIEW osborl 10/19/2012 Casing Strings HANGER. 33 _'' Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd ` CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,973.8 3,094.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD) .. String Wt... String .. String Top Thrd 1 _ i Fl PRODUCTION 7 6.276 35.0 8,772.8 6,317.2 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 33.0 8,346.8 6,015.4 9.30 J -55 EUE8rdMOD CONDUCTOR. 3.5 "x2.875" @8324' 38 -115 Completion Details - - Top Depth (TVD) Top Inc' Nomi... SAFETY VLV, E - - Top (RKB) (RKB) (°) it Description Comment ID (in) 1 ! . .1 33.0 33.0 0.32 HANGER FMC HANGER 3.500 1,797.2 1,667.7 41.68 SAFETY VLV CAMCO TRDP -1A- SAFETY VALVE (LOCKED OUT 3/21/96) 2.813 GAS LIFT. 2,718 8,121.7 5,859.8 46.83 PBR BAKER PBR 3.000 r 8,135.4 5,869.1 46.75 PACKER BAKER FHL PACKER 3.000 8,209.9 5,920.1 45.88 BLAST JT RICKERT BLAST JOINTS (3) 3.000 c 8,313.0 5,991.8 45.77 NIPPLE AVA BPL PORTED NIPPLE 2.750 8,315.9 5,993.8 45.76 XO Reduang CROSSOVER 31/2 x 2 7/8 2.441 SURFACE, 8,322.1 5,998.2 45.76 LOCATOR BAKER LOCATOR 3.000 • 37 -3,974 8,323.9 5,999.4 45.75 PACKER BAKER FB-1 PACKER 3.000 GA54124T9 8,338.6 6,009.7 45.74 NIPPLE CAMCO D LANDING NIPPLE 2.250 l 8,346.0 6,014.9 45.73 SOS CAMCO SHEAR OUT SUB 2.441 GAS 51205 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl GAS LIFT. Top (RKB) (RKB) (°) Description Comment Run Date ID (In) 5,678 8,167.0 5,890.7 46.56 PLUG 2.69" WRP 3/13/2012 0.000 8,313.0 5,991.8 45.77 SLEEVE -O AVA BPC SLEEVE 9/12/2000 OPEN 8/16/1998 2.310 GAS LIFT, AM 6,173 P &Slot Shot GAS LIFT, Top (ND) Btm(TVD) Dens 8,839 Top (RKB) Bfm (RKB) (R KB ) (RKB) Zone Dale (eh° Type Comment 8,2 5,9 5,968.8 C -3, C -2, C-1, 12/4/1985 12.0 IPERF 120 deg. ph, 5" HJ II Csg Gun 3F -05 GAS LIFT, 7,104 8,408.0 8,447.0 6 , 05 9 .2 6 A -3, 3F -05 12/4/1985 4. 0 IPERF 90 deg. p h, 4" HJ II Csg Gun 8,462.0 8,504.0 6,096.1 6,125.5 A -2, 3F -05 12/4/1985 4.0 IPERF 90 deg. ph, 4" HJ II Csg Gun GAS LIFT, In 7,589 Notes: General & Safety End Date Annotation GAS LIFT, 6/24/2000 NOTE: Hole in TBG @ 8303' bottom of blast joints detected. 8,071 2 � 7/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Ir 3/7/2011 NOTE: WAVIERED WELL, IA x OA x FORMATION COMMUNICATION 4/26/2012 NOTE: 7' CASING LEAK LOCATED @ 3272' RKB. IDENTIFIED USING TECWEL LDL 1.6 GPM LR. PBR.8.122 0 PACKER, 8,135 PLUG. 6,167 -- PRODUCTION. 8,172 ,. PERF, 8,2044L280 NIPPLE, 8,313 SLEEVE -0,N 8.313 PACKER.8.324 III NIPPLE, 8,339 IV III SOS,8,346 ea. Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) (1 Make Model (in) Seri Type Type On) (psi) Run Date Com... _ 1 2,717.7 2,266.7 50.82 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/31/2011 IPERF, 2 4,428.9 3,408.3 46.95 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/31/2011 6408 -8,447 3 5,205.1 3,926.2 46.29 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/31/2011 4 5,677.8 4,240.5 49.23 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/19/1991 IPERF. ■ 5 6,173.3 4,568.4 47.55 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/14/1990 8,462-8,504 6 6,638.5 4,886.1 47.79 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/14/1990 7 7,104.4 5,191,8 50.43 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/1/1997 8 7,588.5 5,502.6 49.20 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/5/1985 9 8,071.2 5,824.8 46.70 MERLA TPDX 1 1/2 GAS LIFT DMY 'T -2 0.000 0.0 2/1/2011 PRODUCTION, 35 -8.7 3 & 10 8,1722 5,894.3 46.53 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 1/21/1999 TD, 8,875 • , . 0 ConocoPhillips Well: 3F -05 Producer 2013 PROPOSED RWO RECOMPLETION `new items in RED) API: 500292146000 PTD: 185 -242 / (1.)L- v/ 2.87 Wellhead: WKM Gen V D8 X -mas Tree: 3 -1/2 ", 5K psi New Tubing Lift Threads: 3 -1/2" 8rd EUE I 3 -1/2" 9.3# L -80 IBTM -SC BPV: 3" 'ISA' • _._. lo . , O New Production Casing 7" 26# L -80 TCII 0 7" HES cementer Arctic Pack 10/28/1985 Est Top at 1,850' MD j (30 bhl cmt a 05 551 d 'iesel do esqueezedoh squeeze ) lV Surface Casing a Metal -Skin 7" x 5 -1/2" casing patch 9 -5/8" 36# J -55 BTC . j ■ Shoe at 3,974' MD J1 1 J il i a Baker PBR @ 8,122' MD X X Baker FHL Packer @ 8,135' MD , <.69" WRP @ 8,167' set March 2012 AVA PL A VA B open 8,313' MD BPC P @ xnp /� Baker FB -1 Packer @ 8,324' MD D- Nipple 2.25" @ 8,339' MD D Production Casing Last Updated: 30- Apr -13 7" 26# J -55 BTC 4 Updated by Bearden Shoe at 8,773' MD WELL LIG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Shartzer 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 SCM4t4 0 VIA`' 13x.013 1) Leak Detection - WLD 26- Apr -12 3F -05 1 CD 50- 029 - 21460 -00 2) Leak Detection - WLD 29- May -12 1D-110 1 CD 50- 029 - 22920 -01 Signed : �" '5 Date : (WI 6 /'d-- Print Name:11�45� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245-8952 E-MAIL : PDSANCHORAGERMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COIVI DAArchives\Distribut ion\ TransmittalSheets \ConocoPhillips_Transmit.docx • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3F -05 Run Date: 3/13/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -05 ... ».,....• Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 21460 -00 SCANNED MAY 1 3 9 13 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: `4,0 Signed: 3/ll /l • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 1, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 504190 R 3 2n RE: Plug Setting Record: 3F -05 Run Date: 1/28/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21460 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 00 rafael.barreto @halliburton.com Date: Signed: i FEB R_ t 2011 Alaska Gil & Gas C. Commission Anth :a e • ~L.~ L ~~~1~~~~ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C - _ -~ ~' ~.~~ Anchorage, AK 99518 ~~'~~ ~ ~~~' ' ~ ~~ Fax: (907j 245-8952 1) Caliper Report 28,Jun-10 3F-05 2} i~sS-~~~. l~~s~ Signed Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : Cdsanchorag~merreonffog.com WEBSITE : ww+nt.rreemorvlog.com 1 Report / EDE 50-029-21460-00 C:\Docmnents and Settings\Diane Williams\Desktop\Transudt_Conoco.docx • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3F-05 Log Date: June 28, 2010 Field: Kuparuk Log No.: 7421 State: Alaska Run No.: 2 API No.: 50-029-21460-00 Pipet Desc.: 3.5" 9.3 Ib. J-55 EUE 8RD Top Log Intvl1: Surface Pipet Use: Tubing Bot. Log Intvl1: 8,334 Ft. (MD) Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD Top Log Intvl2: 8,334 Ft. (MD) Pipet Use: Tubing Tail Bot. Log Intvl2: 8,347 Ft. (MD) Inspection Type Buckling & Restriction Inspection COMMENTS This caliper data is tied into the 2.875" tubing tail @ 8,347' (Driller's Depth). This log was run to assess the condition of the tubing with respect to buckling and I.D. restrictions for optimal design and implementation of a slim patch. The caliper recordings indicate multiple holes in the 3.5" tubing in joint 267 (8,302' to 8,304'}, where the caliper also recorded 25% cross-sectional wall loss in the vicinity of the erosion opposite the holes. A 3-D log plot of the caliper recordings across this interval is included in this report. The remainder of the 3.5" tubing appears to be in good to fair condition with respect to corrosive and mechanical damage. WaII penetrations ranging from 20% to 30% wall thickness are recorded in 8 of the 274 joints logged. Recorded damage appears in the forms of general corrosion and scattered pitting. Excluding the erosion opposite the holes in joint 267, no other significant areas of cross-sectional wall loss are recorded. Deposits are recorded throughout the 3.5" tubing, restricting the I.D. to 2.56" in joint 249 (7,715'). A graph illustrating minimum recorded diameters on a joint-by-joint basis is included in this report. The caliper recordings indicate moderate buckling from surface to 8,100'. ^ The caliper recordings indicate the 2.875" tubing tail appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The body region analysis and joint tabulation data for the 3.5" tubing and 2.875" tubing tail are combined. This is the second time a PDS caliper has been run in this well and the second time the 3.5" tubing has been logged from 2,020' to 8,320'. A comparison of the current and previous log (July 11, 2000) indicates a slight increase in corrosive damage during the time between fogs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes (100%) Jt. 267 @ 8,302 Ft. (MD) ' Corrosion (33%) Jt. 255 @ 7,868 Ft. (MD) Corrosion (28%) Jt. 250 @ 7,717 Ft. (MD) Isolated pitting (25°~) Jt. 246 @ 7,626 Ft. (MD) ' Isolated pitting (24%) Jt. 257 @ 7,925 Ft. (MD) PraActive viagi~astic Services, Inc. i` P.~. Sax 1369, Staffard, TX 7;x+9? Phone: (281) or (888) 565-9085 Fax: {281) Ii65-1369 E-mai+: PDS ~memorylag.com Pr~dhae Bay Field c)ffice Phone: {9U.~) 654-2,30 Fax; X90?) 659-2314 ins-aN2 ~qqS~ • MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Erosion opposite a hole (25%) Jt. 267 @ 8,303 Ft. (MD) No other significant areas of cross-sectional wall loss (> 10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum I.D. = 2.56" Jt. 249 @ 7,715 Ft. (MD} Deposits Minimum I.D. = 2.68" Jt. 167 @ 5,179 Ft. (MD) Deposits Minimum I.D. = 2.73" Jt. 158 @ 4,892 Ft. (MD) Deposits Minimum I.D. = 2.75" Jt. 176 @ 5,441 Ft. (MD} Deposits Minimum I.D. = 2.77" Jt. 94 @ 2,941 Ft. (MD) Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: C. Fitzpatrick FroActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone; {281} or (888? 565-9Q85 Fa<: {281j 565-1369 E-mail: PDS~amemorylog.com Prudhoe Bay Field Offce Phone: {907) 659-237 Fax: {907) 659-2314 • PDS Multifinger Caliper 3D Log Plot ~- -- . Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3F-05 Date : June 28, 20'10 Description : Detail of Caliper Recordings Across Multiple Holes Recorded in 3.5" Tubing. • ~-"l Well: 3F-05 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Dale: June 28, 2010 Prey. Date: July 11, 2000 Tool tJW MFC 24 No. 211387 Tubing: 3.5" 9.3 Ib 1-55 EUE 8RD Overlay Mar. R ec. Pen . (mils ) 0 5 0 1 00 1 50 2 00 Z5 0 66 76 86 95 105 115 125 135 144 154 ~ 164 0 173 c 'b 183 192 201 211 220 229 239 248 `°' ~ I 258 --- 263 ^ June 28, 20 10 ^ J uly 11, 2000 Difference Diff. in Maz. Pen. (mils) -100 -50 0 50 100 76 i 86 i 95 105 115 12S 135 ' 144 154 a a E 164 0 Z 173 e "o 183 192 ' 201 211 220 229 239 248 258 263 -10 - S 0 5 10 App rox. Corcos ion Rate ( mpy) • Correlation of Recorded Daman ® Pipe 1 3.5 in (59.6' - 8333.7) Well: Pipe 2 2.875 in (8333.7 - 8347.0') Field: Company: Country: Survey Date, s ;e to Borehole Profile 3 F-05 Kuparuk ConocoPhillips Alaska, Inc. USA June 28, 2010 ® A pprox. Tool De viation ^ A pprox. Borehol e Profil e i 1 -, 68 25 800 50 1564 75 2338 GLM 1 100 3107 ~ 125 iv 3860 ~ i E ~ ~ GLM 2 ' c 150 4633 ~ C ~ GLM 3 175 5409 GLM 4 GL.M 5 6187 GLM 6 225 6960 GLM 7 GLM 8 250 7715 GLM 9 I PM 10 267.7 8347 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 267.7 • ~~ Minimum Diameter Profile Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1.69 0.1 6 13 20 ?7 34 41 48 55 6U 6i 74 81 87.1 94 101 1U8 115 122 ~ 129 ~ 136 Z 143 ~O 149 156 163 169 176 183 189 196 202 209 215 222 229 235 242 248 255 261 264 Minimum Measured Diameters (In.) 1.94 2.19 2.44 2.69 294 i I I i= I ~~ ~-' I i I J--' I~ ~_ I ' Ti PDS Report Overview L-~~_ Body Region Analysis Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 CUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body - metal loss body 300 250 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10°% 20% 40% 85% 85% Number of'oints anal sed total = 274 pene. 0 109 156 8 0 1 loss 0 273 0 1 0 0 Damage Configuration (body ) 80, bU, 40 2(i i n rsofatecJ general linr ring hole/poss pitting corrosion corrosion corrosion iblehole Number of ~oints dama ed total = 97 71 25 0 0 1 Damage Profile (% wall) ~ penetration body ~_ metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 GLM 7 GLM 8 PM 10 Bottom of Survey = 267.7 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 3F-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: June 28, 2010 Joins No. Jt. Depth (Ft.) !'~^n. I lpsc~t (Ins.) Pen. Body (Ins.) Nr.~n. °i~, M~~t.il I c~ °4, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 60 ! t 0.02 0 ' 2.92 PUP Bucklin . .2 64 i) 0.01 -; ) 2.94 PUP 1 68 tt 0.02 ~) (~ 2.90 2 99 tt 0.02 ~' t, 2.89 Ovali due to Bucklin . 3 129 i1 0.03 1~' 2.88 Shallow ittin Lt. De osits. 4 159 +t 0.02 ') ~ 2.89 Lt. De osits. 5 190 ~ ~ 0.03 1O 2.90 Lt. De osits. 6 218 i i Q02 9 2.89 Bucklin . 7 250 i t 0.03 I O -t 2.89 8 280 ~ t 0.02 ') ~i 2.90 9 310 !t 0.03 1 ; 2.89 Shallow ittin L.t. De osits. 10 341 i i 0.03 1 S 2.91 Shallow ittin Lt De osits. 11 371 i1 0.02 ~t 2.90 Bucklin . 12 402 U 0.02 ti 2.90 13 433 +t 0.03 11 2.91 14 463 t? 0.02 ~) 2.92 Ovali due to Bucklin . 15 493 it 0.02 2.90 Ovalit due to Bucklin . 16 524 tt 0.02 tj -1 2.91 17 555 i t 0.02 f3 -1 2.90 Lt. De osits. 18 586 t t 0.02 ~i -1 2.89 Bucklin . 19 616 tt 0.03 11 5 2.90 20 646 tt 0.02 £3 1 2.91 Ovali due to Bucklin 21 677 t> 0.01 6 ~i 2.90 22 707 a 0.02 7 2.91 23 738 it 0.02 t~ 2.91 Bucklin . 24 769 ct 0.04 1(> 2.90 Shallow ittin . 25 800 U 0.02 t; 2.91 ~ 26 831 t t 0,03 1 i 2.88 27 861 tt 0.03 1 i (~ 2.89 Shallow ittin Ovali due to Bucklin . 28 890 U 0.03 12 - 2.90 29 920 ~,t 0.03 11 ', 2.90 Lt. De osits. 30 951 ! t 0.03 1(t 2.91 Bucklin . 31 983 t t 0.02 ~ 1 2.92 32 1013 i t 0.02 ' % ? 2.90 33 1044 tt 0.03 Ilt -+ 2.88 Ovali due to Bucklin . 34 1075 i t 0.03 1 'I - 2.90 Ll. De osits. 35 1105 tt 0.03 1;~ ~ 2.90 Shallow ~ittin . 36 1134 it 0.03 1~ =1 2.90 Ovali due to Bucklin . 37 1164 +t 0.03 1~ ) 2.39 Shallow ittin Lt. De osits. Ovali 38 1 194 ~ t 0.02 `i ~ 2.90 Ovali due to Bucklin . 39 1225 +~ 0.02 ~> _' 2.92 40 1255 (t 0.02 ``t i, 2.90 41 1286 tt 0.03 I f i, 2.91 Lt. De osits. 42 1315 n Q_02 ~~ "~ 2.91 Bucklin . 43 1347 i t 0.03 1 1 .) 2.90 44 1378 tt 0.02 t5 2.92 45 1409 a 0.04 14 i, 2.90 Shallow ~ittin . 46 1440 i ~ 0.02 t3 2.91 Bucklin . 47 1470 ;! 0.03 11 -1 2.88 48 1502 ii 0.05 19 a 2.91 Shallow ~ittin . _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf J-55 LUE 8RD Well: 3F-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: tune 28, 2010 Joint No. Jt. Depth (Ft) t'~ r+. UI~SC~i !Irn.) Pen. Body (Ins.) Prin. % Metal I mss "~~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 49 1533 a 0.02 9 5 2.88 Bucklin 50 1564 U 0.03 13 (> 2.89 Shallow corrosion. Lt. De osits. 51 1596 it 0.03 1:i -1 2.91 Shallow ittin . Ovali due to Bucklin . 52 1627 `) 0.03 13 > 2.85 Shallow ittin Lt Dc osits. 53 1656 +! 0.03 1~' 1 2.89 Shallow ittin Lt. De osits. 54 1686 t! 0.03 1 ~' r, 2.89 Ovali due to Bucklin . 55 1715 i! 0.04 1 ~ ~, 2.89 Shallow ittin . 56 1746 ~! 0.02 ~? - 2.88 Lt. Deposits. Bucklin . 57 1777 ! ~ 0.03 I ~ 2.89 Shallow ittin Lt. De osits. - 57.1 1808 n 0.03 I ~' (~ 2.96 PUP Shallow ittin . 57.2 1818 i+ 0 U (! 2.81 Camco'TRDP-1A-SSA' SSSV 58 1829 +! 0.03 13 7 2.90 Shallow ittin Lt De osits. 59 1859 t! 0.03 10 2 2.90 Bucklin . 60 1890 +! 0.04 14 5 2.91 Shallow ittin Lt. De osits. 61 1918 ti 0.03 1 ' S 2.91 Shallow ittin . 62 1948 +> 0.03 1 Z (~ 2.89 Lt De osits. Ovali due to Bucklin . 63 1978 !) 0.03 1 1 ~,' 2.91 64 2009 U 0.02 ~) 2.91 65 2038 U 0.02 ~) 2.90 Bucklin . 66 2069 U 0.03 12 ~ 2.86 Shallow ittin . 67 2101 t) 0.02 ~) a 2.89 68 2130 l! 0.03 12 -1 2.92 69 2161 l) 0.03 12 ~ 2.88 Bucklin . 70 2191 (? 0.03 11 2.90 71 2219 t! 0.02 ~) ~ 2.89 Lt De osits. 72 2250 t! 0.03 1 I !, 2.90 Ovali due to Bucklin . 73 2280 t1 0.03 13 ~ 2.88 Shallow ittin Lt. De osits. 74 2309 (! 0.03 1 a ~4 2,89 Shallow ittin , Ovali due to Bucklin , 75 2338 +' 0.03 I I (~ 2.88 Lt. De osits. Ovali due to Bucklin . 76 2370 ~! 0.03 10 2.90 77 2398 O 0.03 I r, 2.89 Shallow ittin Lt. De osits. 78 2428 t! 0.04 1-l 2.90 Shallow ittin Lt. De osits. 79 2457 ti 0.04 1 5 - 2.89 Shallow ittin . Ovali due to Bucklin . 80 2488 !~ 0.04 lf, -l 2.92 Shallow ittin . Ovali due to Bucklin . 81 2516 !! 0.04 15 (> 2.90 Shallow ittin . Ovali due to Bucklin . 82 2547 +! 0.02 ~> ? 2.87 Lt De osits. 83 2579 11 0.03 12 i 2.87 Lt De osits. 84 2611 l) 0.03 13 5 2.92 Shallow ittin Bucklin . 85 2641 (! 0.04 16 l 2.90 Shallow "ittin Lt. De osits. 86 2672 t! 0.03 10 - 2.91 Ovali due to Bucklin . 87 2704 i! 0.02 ~! -r 2.90 87.1 2734 i i 0 U ;~ N A GLM 1 Latch @ 6:00 88 2741 (~ 0.03 11 ~~ 2.90 Bucklin . 89 2772 t! 0.03 11 -1 2.88 90 2803 i ~ 0.03 1 Z 2.86 Lt. De osits. 91 2834 1) 0.04 17 -1 2.89 Shallow ittin Lt. De osits. Ovali 92 2865 U 0.03 1O ~ 2.90 Lt. Deposits. Ovali due to Bucklin ~ , 93 2896 (i 0.03 12 2.80 De osits. 94 2928 t! 0.03 11 2.77 De osits. 95 2958 +! 0.03 1(t -! 2.91 ~ ' _ Penetration Body Metal Loss Body Page 2 • i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 93 ppf J-55 EUE 8RD Well: 3F-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: June 28, 2010 Joint No. Jt. Depth (Ft.) I'~~~n. l lF>set (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °i<, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 96 2988 a 0.02 ~) 2.89 Bucklin . 97 3018 U 0.03 1 t) (> 2.91 98 .9046 n 0.02 ~_) 4 2.89 99 3076 tt 0.03 1U 3 2.85 Lt. De osits. 100 3107 t! 0.02 ~) 4 2.89 Lt. De osits. Ovali due to Bucklin . 101 3137 t? 0.03 10 7 2.90 Ovali due to Bucklin . 102 3167 t; 0.04 14 -1 2.86 Shallow corrosion. 103 3197 t~ 0.04 14 (, 2.86 Shallow corrosion. 104 3228 ~ ~ 0.02 ') (.~ 2.88 Ovali due to Bucklin . 105 3258 t) 0.03 13 6 2.89 Shallow ittin . Ovali due to Bucklin . 106 3289 tt 0.03 10 ~ 2.87 Lt De osits. 107 3320 U 0.03 12 5 2.86 108 3351 t ~ 0.02 ~) ? 2.87 Bucklin . 109 3380 c) 0.03 1 U 2.87 Lt. De osits. 110 3409 t) 0.03 l l 2.92 11 1 3440 ~ ~ 0.03 1 L 5 2.89 112 3468 tt 0.04 15 2.85 Shallow corrosion. Ovali due to Bucklin . 113 3499 r ~ 0.04 1(~ 3 2.88 Shallow corrosion. Lt. De osits. Ovali 114 352 8 U 0.03 12 ~ 2.92 115 3557 t~ 0.03 11 _' 2.89 Bucklin . 116 3587 a 0.03 1 I ~ 2.89 Lt. De osits. 117 3616 ;! 0.03 li) ? 2.88 118 3645 t~~ 0.03 1 1 5 2.87 Lt. De osits. Ovali due to Bucklin . 119 3676 U 0.03 13 4 2.88 Shallow ittin Lt. De osits. Ovali 120 3707 ti 0.03 4 2.92 Shallow ittin Lt. De osits. Ovali 121 3738 t1 0.03 1I 2.90 122 3769 a 0.03 13 ') 2.89 Shallow ittin . 123 3800 i 1 0,03 10 _' 2.88 Lt De osits. Bucklin . 124 3829 i'~ 0.03 12 -1 2.88 125 3860 '? 0.03 1 ; 2.88 Shallow ittin Lt. De osits. Ovalit . 126 3891 a 0.03 10 (, 2.90 Lt. De osits. Ovali due to Bucklin . 127 3921 tt 0.03 1 4 2.85 Shallow ittin Lt De osits. 128 3952 t~ 0.03 12 2.87 Lt. De osits. 129 3981 U 0.01 (~ 2.87 Lt De osits. Bucklin . 130 4013 t ~ 0.03 1 1 2.90 131 4045 U 0.03 I 1 ~ 2.89 Lt Deposits. Ovali due to Bucklin . 132 4076 t~ 0.03 1 2.88 Shallow ~ittin Lt. De posits. 133 4106 t) 0.03 1t1 2.88 Lt De osits. 134 4137 (~ 0.02 ~? - 2.89 Lt. De osits. 135 4168 it 0.03 1O 1 2.89 Ovali due to Bucklin . 136 4199 0.03 1O 2.88 Lt De osits. 137 4231 t? 0.03 1 1 2.89 Lt De osits. 138 4260 t! 0.03 1 U 2.90 139 4291 tt 0.02 9 ~ 2.89 Bucklin . 140 4321 a 0.03 1 1 4 2.88 Lt. De osits. 141 4352 c t 0.03 1 u ~ 2.89 142 4384 ti 0.03 I i 5 2.92 Shallow >ittin Lt. Deposits. Ovali 143 4414 U 0.04 1 i 2.90 Shallow ittin Lt. De osits. 143.1 4442 t) 0 u i ~ N A GLM 2 Latch @ 4:30 144 4449 i~ 0.03 1 Z 2.81 Shallow ittin De osits. _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 3F-05 Body Wall: 0.254 in field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: June 28, 2010 Joint No. Jt. Depth (Ft) I'r~n. Lipset (In;.) Pen. Body (Ins.) Pen. °/> Metal Loss "r6 Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4480 i) 0.04 16 ~) 2.87 Shallow corrosion. Lt. Deposits. Ovali -- 146 4512 i) 0.03 13 ') 2.89 Shallow corrosion. 147 4542 +) 0.04 111 1U 2.88 Shallow corrosion. Ovali due to Bucklin . 148 4573 i) 0.03 1 ; 6 2.88 Shallow ittin . 149 4604 a 0.02 ') 0 2.89 Lt. Dc osits. 150 4633 U 0.03 I 1 7 2.87 Bucklin . 151 4663 U 0.03 11 2.86 152 4691 t? 0.03 1 3 t, 2.86 Shallow corrosion. 153 4722 U 0.03 1 3 a 2.88 Shallow ittin .Bucklin . 154 4753 O 0.03 1t) ~ 2.89 155 4785 O 0.03 13 `~ 2.86 Shallow ~ittin Lt. De posits. 156 4815 (? 0.04 1 ~ `i 2.86 Shallow corrosion. Lt De osits. Ovali 157 4846 U 0.05 1 ti t, 2.85 Shallow corrosion. Lt De osits. Ovali _ 158 4877 ~? 0.03 11 2.73 De osits. 159 4908 t) 0.03 1 i ? 2.85 Shallow ~ittin Lt. De ~ osits. ~~ 160 4937 t ~ 0.04 1 1 2.90 Shallow corrosion. Lt. De osits. Bucklin . 161 4968 i' 0.03 1O (, 2.89 162 4999 t? 0.02 4 ~ 2.87 163 5030 0.02 8 2.85 Bucklin ~ 164 5061 i? 0.04 15 4 2.85 Shallow ittin Lt. De osits. 165 5092 ~' 0.03 10 ~~ 2.87 ' ~ 166 5123 c) 0.03 1 S > 2.90 Shallow ittin . 167 5154 i ? 0.03 1 1 4 2.68 De osi ts. 168 5184 U 0.03 lU ~ 2.88 Lt. De osits. Bucklin 168.1 5214 ~) 0 i) ,! N A GLM 3 Latch L 4:30 169 5223 i? 0.03 I1 2.89 170 5253 !? 0.03 lU 2.85 Lt. De osits. 171 5284 ~? 0.04 10 ~ 2.86 Shallow ittin Bucklin . 172 5316 i ~ 0.02 ') -: 2.88 Lt. De osits. 173 5347 +! 0.03 I > 2.87 Shallow ittin . 174 5379 t) 0.03 12 2.90 Shallow ittin . 175 5409 ~) 0.03 1 U 2.90 Lt De osi ts. Bucklin . 176 5439 !:~ 0.04 14 2.75 Shallow ittin De osits. 177 5470 t? 0.02 ~) ~ 2.81 De osits. 178 5501 it 0.03 11 =1 2.88 Lt De osits. 179 5532 ! i 0.02 ~? 2.88 Bucklin . 180 5563 ?? 0.03 11 ~) 2.88 181 5594 (? 0.03 11 (, 2.90 Shallow ittin Lt. De osits. Ovali ~, 182 5625 tt 0.03 i I -l 2.83 Lt. De osits. Ovali due to Bucklin . 183 5656 t? 0.04 1-1 1 2.92 Shallow ittin Lt. De osits. Ovali 183.1 5686 ~? 0 t) U N A GLM 4 Latch C 10:30 184 5693 i) 0.04 i; 2.89 Shallow corrosion. Lt. De osits. 185 5724 (? 0.03 1 1 /1 2.90 Ovali due to Bucklin . 186 5755 i) 0.04 I ~ 2.89 Shallow ittin . Ovali due to Bucklin . 187 5785 c? 0.04 I -1 - 2.90 Shallow ittin . Ovali due to Bucklin . 188 5815 t? 0.03 12 2.90 189 5846 0.03 11 -1 2.91 190 5877 ~ i 0.03 1 l) ~' 2.91 Bucklin . 191 5907 U 0.02 7 ? 2.89 ~ 192 5938 U 0.03 1 U s 2.90 _ Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 EUE 8RD Well: 3F-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 28, 2010 Joint No. Jt. Depth (Ft.) I'~~n. (ll~sel (Ins.) Pen. Body (Ins.) Pc°n. `% ~~4c~l,rl Loss °~b Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 193 5968 (~ 0.03 1 I _' 2.91 Bucklin . 194 5998 U 0.02 `> 4 2.88 195 6030 O 0.03 I 1 2.90 196 6060 t~ 0.02 ') 2.90 Bucklin . 197 6091 !? 0.03 L', 2.88 Shallow ittin . 198 6121 ~_) 0.03 I i 2.90 Bucklin . 199 b152 a 0.04 14 2.90 Shallow ittin . 199.1 6181 O 0 0 +) N A GLM 5 Latch ~~ 12:00 200 6187 i) 0.03 11 ~1 2.91 Ovali due to Bucklin . 201 6215 t) 0.03 12 5 2.90 Ovali due to Bucklin . 202 6245 a 0.03 1 U ~ 2.92 203 6276 t) 0.03 lU ? 2.91 Bucklin . 204 6306 U 0.04 I Ei 4 2.90 Shallow ittin . 205 6337 O 0.03 I I -i 2.93 Ovali due to Bucklin . 206 6368 i) 0.03 11 ~1 2.92 Ovalit due to Bucklin . 207 6398 i) 0.03 10 ~, 2.93 208 6429 U 0.03 10 1 2.90 209 6460 i1 0.02 ') 2.91 Bucklin . 210 6492 O 0.03 1 U 2.90 Lt De osi ts. 211 6522 U 0.05 I ti -1 2.90 Shallow corrosion. Lt. De osits. Ovali 212 6554 U 0.03 1 U s 2.90 213 6585 U 0.02 ~> 2.89 Bucklin . 214 6616 i) 0.03 l s ~ 2.89 Shallow ittin Lt. De osits. 214.1 6645 t) 0 t) t) N A GLM 6 Latch @ 2:30 215 6651 ~) 0.03 13 -l 2.90 Shallow ittin . 216 6682 ~) 0.03 1 1 2.91 Bucklin . 217 6714 O 0.03 12 -) 2.91 218 6743 + ~ 0.03 1 I 1 2.90 219 6775 (' 0.03 I I 2.91 Lt. De osits. Bucklin . 220 6804 ~~ 0.03 13 -~ 2.87 Shallow ittin . 221 6835 t) 0.03 1(1 ? 2.91 222 6866 (~ 0.03 1 I 2.89 Bucklin . 223 6898 t? 0.03 1 3 -1 2.91 Shallow -ittin . 224 6929 t) 0.04 15 5 2.90 Shallow ittin . 225 6960 n 0.03 l U ~ 2.88 Bucklin . 226 6990 ~! 0.03 1 1 i 2.89 Lt. De osits. 227 7019 r) 0.02 ~) ' 2.89 228 7049 (~ 0.02 ~? (~ 2.90 Bucklin . 229 7080 (i 0.02 2.93 229.1 71 10 i ~ 0 U N A GLM 7 Latch @ 7:30 230 71 16 t? 0.03 1O ) 2.93 231 7145 (~ 0.03 i U 2.88 Bucklin . 232 7177 0.03 I U ~ 2.88 233 7206 t) 0.03 I1 -l 2.88 Lt. De osits. 234 7236 (~ 0.03 11 2.86 235 7264 l) 0.02 ~) _' 291 Bucklin . 236 7295 O 0.03 IU 2.91 237 7324 O 0.03 10 i 2.91 Bucklin . 238 7354 ii 0.03 1"', ~ 2.88 Shallow ittin . 239 7383 it 0.03 1~' =l 2.90 Lt. De osits. Ovali due to Bucklin . Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf )-55 EUE 8RD Well: 3F-05 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in C~nrpany: CunucoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: June 28, 2010 Joint No. Jt. Depth (Ft.) f't•n. ill~srt (Ins.) Pen. Body (Ins.) Pen. °i~~ M<~tal Ir~SS "'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 240 7415 ii 0.04 16 -3 2.90 Shallow ittin . 241 7444 t! 0.03 IO 2.91 Lt. De osits. 242 7472 !! 0.03 lU i 2.90 Lt. De osits. Bucklin . 243 7503 ~ ~ 0.03 I ? -J 2.92 244 7533 t! 0.04 l~ ~ 2.87 Shallow ittin Lt. De osits. Ovali 245 7563 l! 0.03 i I i 2.88 Bucklin . 245.1 7593 c! 0 i.- t! N A GLM 8 Latch ~ 12:00 246 7599 t! 0.06 _"~ 2.85 Isolated ittin Lt. De osits. Ovali 247 7628 ! - 0.04 l ti 3 2.87 Shallow corrosion. Lt. De osits. 248 7656 t) 0.05 I ~9 4 2.87 Shallow corrosion. Lt. De osits. 249 7686 i? Q04 I b 2..56 Shallow corrosion. De osits. Ovali 250 7715 U 0.07 Z8 6 2.86 Corrosion. Lt. De osits. Ovali 251 7747 i) 0.05 21 5 2.87 Corrosion. I_t. De osits. 252 7 777 i! 0.06 24 -1 2.85 Corrosion. Lt. De osits. Bucklin . 253 7806 U 0.03 13 2.86 Shallow ittin Lt. De osits. 254 7835 O 0.03 13 -+ 2.88 Shallow ittin Lt. De osits. 255 7866 l! 0.08 ~~ 2.87 Corrosion. Lt De osits. Bucklin . 256 7895 (~ 0.05 IV -t 2.85 Shallow ittin Lt. De osits. 257 7925 (? 0.06 Z-1 2.87 Isolated ~ittin Lt De osits. 258 7953 U 0.05 Z i ,, 2.88 Corrosion. Lt De osits. Bucklin . 259 7982 O 0.04 I (, 2.89 Shallow ittin LL De osits. 260 8012 U 0.02 ~~ (~ 2.88 261 8043 U 0.03 12 4 2.89 Lt De osits. 261.1 8073 (! 0 U (1 N A GLM 9 Latch @ 4:00 262 8084 U O.UZ ~~ - 2.91 Bucklin _ 262.1 8113 t! 0.04 1 <t + 2.91 PUP Shallow corrosion. 262.2 8124 (! 0 O t! 3.00 Baker PBR 262.3 8138 i i 0 U t l 3.00 Baker'FHL' Packer 263 8145 i! 0.02 i -4 2.93 Bucklin . 263.1 8174 !! 0 O ! i N A Production Mandrel 10 Latch L 3:30 264 8181 U 0.03 1 "3 - 2.87 Shallow ittin _ 265 8212 ! ~ 0.05 Z 1 2.89 Corrosion. Lt. De osits. 266 8242 t! 0.03 10 2.90 Lt. De osits. Bucklin . 267 8273 t! 0.75 100 '~~ 2.92 Multi le Holes! 267.1 8304 (1 0.04 17 2.79 PUP Shallow corrosion. De osits. 267.2 8314 (! 0 0 ti 2.31 AVA Sleeve w BPI. Ported Ni le 267.3 8324 i~ 0 0 u 3.00 Baker'FB-1' Packer 267.4 8334 i! 0.01 4 _' 2.39 2.875" PUP 267.5 8339 r) 0 O t! 2.25 Camco'D' Landin r'~i le 267.6 8341 t) 0.01 4 ~ 2.36 2.875" PUP 267.7 8347 U 0 O t! 2.44 2.875" Tubin Tail Penetration Body Metal Loss Body Page 6 • • ~ ~ PDS Report Cross Sections Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubir~: 3.5 ins 9.3 ppf J-55 EUE 8KU Analyst: C. Waldrop Cross Section for Joint 267 at depth 8302.79 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining w,-all area = 84 °% Tool deviation = 52 " Finger 2 Penetration = 0.754 ins Hole 0.75 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 • • ~ PDS Report Cross Sections Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 2~ tubing: 3.5 ins 9.3 ppf J-55 EUE 8RD Analyst: C. Waldrop Cross Section for Joint 255 at depth 7868.24 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 °% Tool deviation = 51 ° Finger 14 Penetration = 0.084 ins Corrosion 0.08 ins = 33% Wall Penetration HIGH SIDE = UP Cross Sections page 2 • • ~ PDS Report Cross Sections ~., Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f J-55 EUE 8RD Anal st: C. Waldro Cross Section for Joint 267 at depth 8302.77 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 75 °% Tool deviation = 52 " Finger 3 Radius = 2.192 ins Hole 25%Cross-Sectional Wall Loss HIGH SIDE = UP Cross Sections page 1 • • PDS Report Cross Sections Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW i~iFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J-55 EUE 8RD Analyst: C. Waldrop Cross Section for Joint 249 at depth 7714.6 ft Tool speed = 43 Nominal ID = 2.992 Norninal OD = 3.500 Remaining wall area = 100 °,~o Tool deviation = 54 " Finger 9 Projection =-0.37 ins Deposits Minimum I.D. = 2.56 ins HIGH SIDE = UP Cross Sections page 3 PDS Report Cross Sections ~~,. ~ ., Well: 3F-05 Survey Date: June 28, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 __ Tubing: 3.5 ins 9.3 ppf J-55 EUE 8RD Analyst: C. Waldrop Cross Section for Joint 167 at depth 5178.9 ft Tool speed = 43 Norninal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 °% Tool deviation = 55 " Finger 5 Projection = -0.282 ins Deposits Minimum I.D. = 2.68 ins HIGH SIDE = UP Cross Sections page 4 ~,, ~~~ KUP ~ 3F-05 ConoeoPllilli ps ! } II Attributes An le & MD TD "" '- f ~ Wellbare A 50029 PI/UWI 2146000 Fleltl Name WMI Status Inc! (°) KUPARUK RIVER UNIT PROD 51.65 ND ¢tf(B) 2,500.00 AQ Blm IRKB) 8.875.0 ~ I Commem SSSV: LO CKED OU N251ppm) T 170 Date 1/6/2008 Anrwta[ian L t WO Entl Dffie KB•Grtl Ift) 41 00 Rig Release Cate '' 10/21/19E5 ~~ Well Confi : -3F-0v 9/ Smematic 6/ 00 -Actua 9801 l :40 Fivi Arra[atlan Last Tag: SLM Depth lftKB) 8.545.0 as : . End Date Arrwtatlan Last MOtl By 8/22/2009 Rev Reasem TAG FILL Imesbor End Date 9/6/2009 I Casin Strin s rnNDUCTOR, ~ Casing D escriptlon String O fin) D Stnng ID (in) Top IftKel Set Depth IftK61 Se[ Depth (ND) (ftKB) String Wt pbsrRl Strin Grad g e stung Ta p Th~ 11s CONDUCTOR 1 6 15.062 0.0 115.0 115.0 62.50 H-40 sAFETrvLV _ SURFACE 95 /3 8.765 0.0 3,974.0 3,0945 36.00 J-55 i , 1.7a6 o PRODUCTION 7 6.151 0.0 8.773.0 6,317.3 26.00 J-55 -i Tubin Strin s cAS LIFT 7Ubi Descri on String O Pnl D Stdrg ID Iln) To a Set Depth (ftK8) Set lhPth (ND) IM(B) Strtng Wt (lbsllq 5[drg Gratle Strt T Thrd , . z,rla TUBING 31 /2 2.992 0.0 8,316.0 5,993.9 9.30 J-55 EUE 8RD TUBING 2 7 /8 2.441 8,316.0 $347.0 6,015.6 6.50 J-55 EUE 8RD I sURFACe, 3 974 Other I n Hole A ll Jewel :Tubin Run 8 Retrievable Fish etc. , cA:, L:FT Top )ft1t8) Top Depm IND) I~BI lop Ind 1.1 Descrlpdon Comment Rtn Dffie ID (In) 4629 1.785 1.658.6 41.28 S AFETY VLV Camco TRDP-tA-SSA' (Locked Out 3/21/96) 10/9/1997 2.813 2,718 2,266.9 50.82 G AS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 1 8/12/2003 2.875 GAS LIFT 4,429 3,408.4 46.95 G AS LIFT CAMCO/KBUG/1/DMVlBK!// CommenT STA 2 R/19/1991 2.A75 , 6,zos 5,205 3,926.1 46.29 G AS LIFT CAMCO/KBUG/1/DMY/BK/// Comment: STA 3 5/1/1997 2.875 5,677 4,240.0 49.23 G AS LIFT CAMCOlKBUG/1/DMY/BK!//Comment STA4 8!19/1991 2.875 6,173 4,568.3 47.55 G AS LIFT CAMCO/KBUG/1/DMY/BW//Comment: STA5 12/14/1990 2.875 ., suFT, ~ 5 677 6,638 4.885.8 47.79 G AS LIFT CAMCO/KBUG/1/DMYiBW7/Comment STA6 12/14/1990 2.875 7,104 5.191.6 5043 G AS LIFT CAMCOIKBUG/1/DMYlBK///Comment: STA7 5/1/1997 2.875 7,589 5502.9 49.20 G AS LIFT CAMCO/KBUG/1/DMY/BK!!! Comment: STA 8 12/5/1985 2.875 cAS uFT, 8,071 5,824.7 46.71 G AS LIFT MERLNTPDX/1.5/DMY(f-2/// Comment: STA 9 5/1/1997 2.875 6~'T' 8,122 5,860.0 46.83 P BR Baker 12/5/1985 3.000 8,135 5,868.9 46.75 P KR Baker'FHL' 12/5!1985 3.000 GAS LIFT. 6 638 8,172 5.894.1 46.54 P RODUCTION CAMCO/KBUG/1/DMV/BW//Comment: CLOSED STA 10 1/21/1999 2.875 . 8,313 5,991.8 45.77 N IP AVA BPL Ported Nipple 12/5/1985 2.750 8,313 5,991.8 45.77 S LEEVE-O AVA Sleeve; set BPC 9/12/00. OPEN 8/16/1998 2.310 cnS uFr. 8.324 5.999.5 45.75 P KR Baker'FB-1' 12/5!1985 3.000 7,104 8,339 6,010.0 45.74 N IP Camco'D' Landing. 1/21/99 -A-2 plug pulled. 8!1611998 2.250 8.346 6.014.9 45.73 S OS Camco 12/5!1985 2.441 8.347 6,015.6 45.73 T TL 12/5/1985 2.441 cAS urr, zfis9 Perfora tions & Slots lo tlCB Btm ttlB Top (ND) (RKB) Btm (7VD) CBI Z O t sha Dens Ish.- ".a' uFT, s.m1 p n ) 8,204 l 8,280 5,975.9 5,968.8 one C-3, C-2, C-1, a e 12/4/1985 12.0 Type IPERF Comment 120 de h 5" HJ II Cs Gun 9~ P 9 3F-05 8.408 8.447 6,059.2 6,085.8 A-3, 3F-05 12/4/1985 4.0 IPERF 90 deg. ph, 4" HJ II Csg Gun PeR, eAZZ 8,462 8,504 6,096.1 6,125.5 A-2, 3F-05 12/4/1985 4D IPERF 90 deg. ph, 4" HJ II Csg Gun Notes: General 8 Safe Ena Da ce Amotffiton 6/24/2000 NOTE: Hale in TBG @ 8303' bottom of blast joints detected. PKP. a.13@ 7;8;2002 NOTE: WAIVERED :h/ELL IAX GA COMMUNICATION PRODUCTION 8,172 IVERF, a,zoa-a zao- NIP, 6,313 SLEEVE-0, "0 313 ~ PKR,8324 NIP, 8,339 505.8 346 TTL, 8,347 IPERF. 8,408-8.44] ~PERF ~ 9 452A 5~4 PROOUCnora 8 773 TD, 8 875 ' ~ 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3F-OS Run Date: 4/18/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-OS Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21460-00 Production Profile Log 50-029-21460-00 r}°~~.r. ~~ ~ ~ ~ a~~7r; 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barret Date: I~AY 1 % 2010 t .~ 5--, air 2 t9~53 Signed: .a,F..: ~:~. ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 26, 2008 • iW~ i~ ~ LUtlJ :i~s~a Oil Oss l~a~y~~.. ~a~rva~ssi~~ r~~~b ~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 tz ,~4! I~' ~-~~ ~ ~ ,r ~~~~ Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113F-OS (PTD 185-242). The report records the successful surface casing repair with Brinker Platelets. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, .. MJ Loveland Well Integrity Project Supervisor • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION j8S~8 ~~ ~iBS ~`Of1Sr ~Ott1ff11SSIA( REPORT OF SUNDRY WELL OPERATIONS ~ncnl~t•ae~ 1.Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other Q Platelete sC repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 185-242 3. Address: Strati ra hic Service g p ^ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21460-00 ' 7. KB Elevation (tt): 9. Well Name and Number: RKB 93' 3F-05 8. Property Designation: • 10. Field/Pool(s): ADL 25632 ALK 2565 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8875' feet true vertical 6390' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 3881' 9-5/8" 3974' 3094' PRODUCTION 8680' 7" 8773' 6317' Perforation depth: Measured depth: 8204-8280, 8408-8447, 8462-8504' true vertical depth: 5916-5969, 6059-6085, 6096-6125 Tubing (size, grade, and measured depth) 2_7/g~~, J-55, 8347' MD. 3-1/2", J-55, 8316' Packers &SSSV (type & measured depth) pkr= BAKER 'FHL' ; BAKER 'FB-1' pkr= 8135' ; 8324' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1000 3650 2980 1400 300 Subsequent to operation 1000 ~ 3650 2980 1400 300 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: NA contact MJ Loveland/ Perry Klein Printed Name MJ Loveland Title WI Project Supervisor Signature ~ ~, ~__~~-~ Phone 659-7043 Date ~ - r , ~ ?`~, ~~ ~'~ ~r=1 t ~t:~ a ~ Anna J _ . .f~ z • /0'-~9 Form 10-404 Revised 04/2004 Submit Or' ' _Or~~j~ 3F-05 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/25/0 Brinker Platelet SC Repair -successful. MITOA,- passed. Initial T/I/O = 300/430/0. Rigged up LRS to the platelet injection skid and established a LLR down the OA of .55 bpm @ 450 psi. with diesel. Loaded batch # 1 with 50 - 8 mm lite platelets and started pumping at a rate of 1 bpm @ 1040 psi. seeing a slight increase of psi. to 1300 psi. and falling back to 150 as. @ .5 bpm. Loaded batch # 2 with 50 - 10 mm heavy platelets and started pumping at a rate of 1 bpm @ 440 psi. dropping the rate to .5 bpm Cad 1040 psi. climbing up to 1810 psi. shutting down the pump to start a MITOA. Initial T/I/O = 300/430/1810, 15 min. T/I/O = 300/430/1810, 30 min. T/I/O = 300/430/1810. 45min. T/I/O = 300/430/1810. 60min. T/I/O = 300/430/1810. ~ Bleed down the OA to 520 psi. Tagged OA with instructions to do not bleed below 500 psi. Summary Repaired OA leak with Brinker Platelets. MITOA Passed to 1800 psi PLATELETS® Overview & Case Studies PrOdu~t Ov~rvi~w Platelets® are an innovative means of sealing leaks in fluid flow applications such as pipelines, umbilicals and other items of system infrastructure. Platelets° are free floating, discrete particles which are injected into a system which has a known or suspected defect. The Platelets® are transported downstream with the flow in the system and when they reach a leak fluid forces entrain them into it thus providing a seal. This unique and innovative concept is based on the method the human body uses to heal wounds and can be optimised for a wide variety of fluid flow applications. Since Platelets° are deployed remotely they are a cost effective alternative to other remedial techniques such as clamps and wraps since direct access to the leak site, and therefore vessel intervention, is not required. Platelets° can be deployed in response to an emergency loss of containment incident but are most effectively incorporated as part of an ongoing integrity management programme to remove unnecessary system downtime. Platelet° material is selected depending upon the conditions within the system, such as pressure, temperature, fluid type, predicted leak geometry etc. but generally polymeric and elastomeric materials have the required characteristics for Oil & Gas applications. In all instances Platelets® are entirely inert and are therefore a low risk solution as they will have no negative effect on system infrastructure or indeed the carrier fluid. Platelets° can be introduced into a pipeline in a number of ways such as via pig launchers or by pumping through teeing points on the line; in all deployments to-date it has been possible to utilise existing infrastructure for injection and no modifications to the system have been required. Platelets®-The Facts Remote deployment- no requirement • for vessel intervention or access to leak site. No requirement to shut-down, • deployed whilst system operational. Adaptability for variety of leak scenarios: corrosion pitting, fitting failures, hairline cracks, 6 o'clock grooves. Emergency response or effective component of ongoing integrity management programme. Temperature <_ 90°C, Pressure <_ 3,000 psi 01eak/ fdPipeline = 1 /20. ... ,~ ~'~ ~ l ~ ~/~ ; NO. 5035 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 _ ATTN: Beth ry~ ~; ~ `~i ' ~~,~~' , ,. .., LL VI kE~aW s.1~2 .. ~ ~J. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Weil Job # Log Description Date BL 3F-05 12115003 PRODUCTION PR ^ ' • ' 1 E-22 12115008 OFILE ~ y;~ - ~ .) '" G, ~ ~::;~ INJECTION PRO ' 12/20/08 1 3F-12 12115008 FILE ~ ~~ _ .') ~. ~ .- ~. ; -~ INJECTION PR ' 12/24/08 1 1 D-136 3F-O6 3J-02 2N-332 2N-323 12115008 AZED-00003 12115008 12096514 AZED-00008 OFILE ~-(. ~_ . ~,~ °~, ) -' /'z x INJECTION PROFILE ~, '~ =r T~. - ) ~ .~ C : .. 41!~~ PRODUCTION PROFILE ~, j - ,;).~'.~t_.I ~'_~ ~_~ INJECTION PROFILE ~ ~ ;^~ . ~ = • ~ - / , -?~ -. _ ~ !"l . SBHP SURVEY ~,v _ :1~::"' '=~ ~,/ ^~y SBHP SURVE "= = ~' 12/25/08 12/26/08 12/27/08 12/29/08 12/30/08 1 1 1 1 1 2N-342 12096514 -}- j ;' Y - )-/ j/~~. - ~~; SBHP SURV ' ~ 12/30/08 1 2N-302 2P-417 2V-03 1R-13 1 B-02 AZED-00007 AZED-00012 12115000 AYS4-00019 AYS4-00020 EY ~) ~. } -•.. ~ ' --~_ < < SBHP SURVEY ~ ,: ~ ~ : ~ _. I ~- 1 ! ~- SBHP SURVEY ~ ~ r , (- (;!; ~'; ~ - _j ~_ i_ ~- ~ INJECTION PROFILE f_i' " ; ~ - j(;;`" r-~ , INJECTION PROFILE ~,, f i L 1 `- ! ~•; `~ I' ~ ~ L ~ ~ ^ INJECTION PROFILE ~ i^% ( ~~ ~ j ~'.'1 r •' j. ~ ~ --~ ~ ~,~ 12/30/08 12/30/08 01/02/09 12/17/08 01 /03/09 01 /04/09 1 1 1 1 1 1 Color CD 1 1 1 1 1 1 1 1 1 1 1 1 01 /08/09 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . "Y ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 E'" (\..~ f( 200D ~t:;ANNED 5 'r Ie! '-' - ~~6~?J-id- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I 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 corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. ,,' Please call Jerry Dethlefs or myself at 907-659-7043"i{you have any questions. /' / Sincerely, /1 iF ,// .·..Pi / ;/~fl'"/~ ,/ f M.J .loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet ~ Gallons Date " .. 3F-O,1, '. ". ; 1tl5?~ï:~ ' I.;, <....".,. .', ·NA···· '. . . , .. I', . ;"', 8¡~:fItUO§; , .. . Lv' " 3F-02 1 85-226 24' 7.0 8/1 4/2006 7.5 8/21/2006 ·~;?~n3. , ". '. '.' . ..., .;. 2..3,. . ' " ..... . " 8t1r4'r1g0,~ : , ß/~1i/iÎ~~~?;' '" ", " 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 ., E .r::: .. ";'·a)¡f~J2.fXø:6/ ' , " ~é')íê1llt1«6:: . . ,,' "'," .,.<-:.; '.' ", .... . f·;a."'" '. 3F-06 1 85-244 Did not modify 3~G1é ., >~,/j '1~~~~ ,:1'. ,,' .' . '.. 6,6 .. ,~/1'4120QB: :" 7.5 .. Ji~/21t2t1Ø~" 3F-08 185-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 3F,;Q$ '. " '1e~~O' Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 .. ' :3fiH .~ .. '-18'$?~12; '" ,. NA. ' I'I.IA··· . ' . .. 1.:7. '.. ~/~~lZé1~Q 3F-12 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 ~ ' ·;':1~_tl(;;;,:.: .;, " ;; .' " NA' ", "' ~ ".,' ':I'I'" . """., .': :,t'j2~Þ2~Q&'" 3F-14 1 85-292 Did not ..v"'...y ~ .2A·, '.': .,' . " r i$f~3Z4Ð:Qß ' :' , ß'f14'k2ØJ16;: ... " 3F-1 6 196-151 6" NA NA 2.7 8/23/2006 ,I ~ 11"·::" I' 3.1 ' , '8r1;;412:øO.~ . '; B, . ,.. 812ß12QÐ~~; 3F-1 8 196-112 4' NA NA 28 8/23/2006 .'~r;:~t9,· ,-.' <., .2:r:1~'{a:!6: .~. ~~;a-': ',' .; NA~, . : ·8" NA . ",' c·...·... 2 ' " ,,;~¡;2l12Ø:Q'6 ; . . , 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-2,1 . < ·.20b;2Ò~ '45,í. .- . " NA " NA 31 I, 81Ž1;t2QÙ'& , Schlumbergef1 -:.. ~F,vc;r~ RE'-'-I . L?~ NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth n£("> 2 1.. 'Îon¡::, U L- Lv,", Company: ...!~... 0;& '.? ~~~ ('r'I"~ Ccrnrr::S-;:£r1 ~ \.fit ~ ~ 1",oVI1.... - Anchorag€ Field: ~ Well Job # Log Description Date BL 1Y-19 11144040 PIEZO SONA TOOL 11/19/05 1 1Y-27 11072935 PRODUCTION PROFILE WIDEFT 11/22/05 1 20-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 It'-"ì--;rl r > N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE WIDEFT 09/10/05 1 10-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 10-09 11141233 INJECTION PROFILE 12/02/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 10-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 '~.- 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 10-101 11144044 MDT 11/24/05 12/20/05 \ @"5- d- 4- 9--- Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 SIGNED: ANv,,!iF'. r\ ~.'. 1"\ i\\ :-1..> f) 2.0Gb c<.<{î'. ~'1!bl",)' J M 1'& "" ~ ~~ ~'.u.... DATE:&~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10/09/03 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2991 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-05 ~'~:~-~ J-! ~3~ PRODUCTION PROFILE/DEFT 09~25~03 1 3F-07 ~.~'~,~ INJECTION PROFILe 09/04/03 1 3J-12 i ~-3~'~:;~ INJECTION PROFILE 09127/03 1 3B-12 '5~_~II-(D ~NJECTION PROFILE 09124/03 1 IA-23 C~ i 'O~ STATIC SURVEY 09130/03 1 3G-05 ~ ~'('~'~2 PRODUCTION PROFILE 09/28/03 1 3G-18 iC{;~-/C~.~' PRODUCTION PROFILE/DEFT .... 09/26/03 1 ; ,Aias~a Oi,~ & ~, Ccx~s. C. ornmi~or~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. /.~Ch0TSi§~ Memory, Multi-Finger Caliper Log Results Summary / Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: PHILLIPS Alaska, Inc. July 11, 2000 4124 1 3.5" 9.3 lb. J-55 EUE Tubing Well: 3F-05 Field: KUPARAK State: Alaska APl No.: 50-029-21460-00 Top Log Intvl: 2,020 Ft. (MD) Bot. Log Intvl: 8,320 Ft. (MD) Inspection Type: Restriction Evaluation COMMENTS: This Icg was run to assess the condition of the tubing with respect to restriction evaluation. The caliper recordings indicate tubing buckling from approximately 2,600' to the bottom of the 3.5" tubing @ 8,316'. Most of the buckling appears to be relatively minor over the interval 2,600' - 5,400', and increases in severity below this point. Apparent severe buckling occurs at two places above 5,400' (3,505' & 5,335'), and at several points below 5,400'. Pipe buckling is rated as 'severe' when the caliper recordings indicate pipe ovality (the beginning of plastic deformation) at the elbow of the recorded bend. A hole is recorded in Joint No. 267 @ 8,304', approximately 13 ft. above the AVA isolation sleeve. A ring of erosion, with a maximum wall penetration of 39%, and cross-sectional metal loss of 27% is recorded @ 8,305' - just below the recorded hole. This type of damage is usually associated with a hole at the same location. Though no hole is recorded here, there is a significant probability that one exists that fell between the caliper fingers during the Icg. Scattered light deposits are recorded throughout the Icg interval, but none greater than 0.10" in thickness. MAXIMUM RECORDED WALL PENETRATIONS: HOLE (97%) Jt. 267 @ 8,304' MD Ring of Erosion (39%) Jt. 267.1 @ 8,305' MD No other wall penetrations in excess of 15% wall thickness were recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Ring of Erosion (27%) Jt. 267.1 @ 8,305' MD No other areas of cross-sectional metal loss in excess of 9% were recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No area of significant ID restriction (in excess of 0.10 in.) was recorded throughout the interval logged as a result of scale deposits. The following restrictions appear to be the result of pipe ovality. Ovality Min. ,D-2.70 in.J,. R E C E IV E D Ovality Min. ID - 2.82 in. Jt. 262 @ 8,090' Ovality Min. ID - 2.83 in. Jt. 113 @ 3,505' Ovality Min. ID -2.83 in. Jt. 239, @ 7,405' Ovality Min. ID- 2.84 in. Jt. 172 @ 5,334' JUL 2 4 2000 Alaska 0il & Gas Cons. Commission Anchorage l Field Engineer' J. Morgan Analyst: J. Burton Witness: B. O'Dell ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: s 10 metal loss 50 00 Overview page Pipe: 3.5 ins 9.3 Wall thickness. N0!1lInai penetration metal loss ;~ Metal ~ /¡ií';mum Joint No. I Upset !Body ynn"'h~ 0 "'0 00 inches inches '70 ')b inches inches inches TOP OF LOG ",T"I;>\iAI IW' 66 0 .02 j 2 0 .03 2.91 155; 67 0 .02 81 0 .04 2.91 ¡ji' 68 0 .01 f. 3 0 .04 2.92 69 0 .Ol!; 1 0 .041 2.93 70 0 .02 8 3 0 .04 2.92 ( .\ 1 3 0 .04 2.91 .( (.04 2.90 ( ..04 2.90 .03 2.91 0 2.92 7E .04 2.90 7 1 78 0 .0 79 0 .01 f. 2 80 0 .01. f. 2 81 0 .03 '11 2 0 )j ) 0 82 0 .03 12 2 0 .04 ) 11 Wii' 83 0 .02 t 5 0 .05 2 90 t. ¡W; 2 0 0 2.88 I <;11",h, 84 0 .02 ) 1m" 85 0 .02 / i 0 .04 2.91 r:;'; 86 0 .02 q 2 0 .03 2.89 SIÍ\zht r;; 87 0 m £; ¡ 0 .02 2.86 87.1 0 0 C 0 0 0 2.70 GLlvl! (Latch @ 'dO) I::;;; 88 0 .03 II 2 0 .10 2.70 Lt n",.v~c;+c VW 89 0 .02 (; 2 0 .04 2.91 S;¡ght'~" I;;;' 90 0 .02 8 2 0 0 2.90 I" 2.90 r ,> n j j' 91 0 m E 1 0 .04 Ii';;; )2 .02 8 2 0 .03 291 rlii .01 (; 1 0 () 2.89 Slight ;;i;;: :JL .02 C 2 0 .04 2.92 liil 2.90 Lt. n, ;h .01 E 2 () .05 Ifli: J 2.93 S¡¡ght ) 1 0 0 rli/? 2 0 .06 2.89 Ill. n, ih Fl;;Y.; 2 0 .04 2.90 iRii! 19 ) ) 4 0 .03 2.90 Sllg!1t IliG 100 ) "2 2 0 .04 2.89 17;: 101 0 .02 q 4 0 .04 2.90 ¡ S ig1t ;?;!l .102 0 .03 n 2 0 .08 2.87 Lt 103 0 .02 I 0 0 2.85 SIi2 ht FiJi; 104 0 .02 7 2 0 .03 288 105 0 .02 7 2 0 .04 2.89 ¡ ')1¡2ht 1106 0 .01 E 2. 0 .04 2.91 107 0 .02 2 0 0 2.86 Slid1t 108 0 .Ol !; 2 0 .04 2.89 2.91 I SIÍI?:ht ,. 109 0 .01 6 2. 0 .04 110 0 .02 7 3 0 .03 2.93 0 .04 2.89 Slight ,. 111 0 .02 q 2 Iii 2.85 " 112 0 .04 14 2 () .03 113 0 .02 q I 0 .03 2.83 I OVAL SEVERE I'll ¡(¡<lINt; 1114 0 .01 r: 1 0 ,04 2.90 Tabulations pagel U~.h¡ '" 'V'CtcH, "'" "'c"" Upset Bodv C~, "'" n.' % inches inches inches 2 0 () 2.89 Slight Î 0 0 2.90 9 0 0 2.91 rL. ¡¡ () .03 2.91 Shallow .02 2.88 .90 Slight .91 Slight .03 '88 0 .86 Slight 0 :J Slight Slight Pipe: 3.5 ins 9.3 Wall thickness. f'.JolllinaIID: Joint inches I 0 11:, 11 11 1 inches '10 )2 8 )2 8 ¡415 1415 13 1 , 12£ 127 128 129 130 131 132 133 134 135 136 13; 13: 13' 1 L 1 L 1 ) 1 ¿ 1 3.1 1.'4 ) 145 0 146 0 147 0 ,02 148 0 .02 9 149 0 .02 9 4 150 0 .01" 2 Ll'3J. 0 .01 61 ! 152 0 .03 10 6 153 0 .02 7 3 154 0 .02 9 4 155 0 .02 9 2 156 0 .02 8 3 J-'m=F~~jL Jl .02 91 l .02 7 2 .1 .02 9 3 160 6 3 ~JÜ .02 9 3 .02 8 2 .02 9 2 0 0 0 0 0 0 0 0 0 () 0 III .02 7 2 .02 8 2 .02 7 2 .02 q 4 01 6 2 .02 6 2 .02 q 1 .03 10 2 .02 q 2 ,0310 2 .,02 81 .02 6 2 .02 7 1 .02 8 2 .02 í 3 .02 2 .02 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 é 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .03 n Slíght .04 2.89 .04 2.90 Slight ~ " .04 2.89 04 2.92 Slight ~ " I 2.91 2.90 Slight 2.92 0 2.94 Slight n " 0 2.91 0 2.89 Slight 0 2.87 0 2,89 Slight 0 291 .03 2.82 Slight 0 2.75 GLtv~ 2 (Latch @ 5:00) )9 2.75 Lt. i }PDD,.t, 2.90 2.87 Slight 2.90 2.89 Slight 2.90 2.85 Lt. 2.86 Slight' 2.88 2.88 Slight' 2.9\ 2.88 Sight n , 2.88 2.85 ll. ~ 2.91 2.86 Slight n , 2.85 2.92 Slight ~ , 2.88 2.89 Slight n " J Date: .05 .04 0 ,04 .03 .03 .04 .06 0 .03 .03 0 .03 .04 Tabulations page 2 s 3F.05 Uamage 0 ~o , " , no :, , . , " '. ", , '. .. ", " , " ..' " , '., , , Ii Pipe: 3.5 ins 9.3 Wall thickness. . \!omllìaIID: 2.992 ins Joint , in~hes inch 1 i () I H;' 0 116£ 0 1167 0 1168 0 .168.1 I 169 170 i 71 172 173 174 17)0 171) 0 I 0 11 0 1 '9 0 110 0 181 0 182 0 183 0 1183.1 0 1184 0 185 0 186 0 187 0 188 0 189 0 ,190 0 .191 0 :192 0 193 194 195 196 I 197 198 0 199 0 1991 0 200 0 201 0 202 0 203 0 204 0 20.5 0 206 0 207 0 208 0 1209 0 1210 0 Well: "~,-, n '. ,.J("!".,,,,-, ¡Yleldl j ¡II, IUJ o/,) '%)! l¡;~:~:s ;~ì~~~( s inches ~,¡'" 'I 02.83 2 0 2.86 1 Slight II 3 i 2.88 q 3 I .07 2.87 Lt q 2 ( .07 2.88 Lt 0 0 0 0 2.84 G ;\ 3 ~a:tch @ 400) .0310 2 .04 2.84 Q".,I,I; .02 q 3 .03 2.89 Q IA:, 01 4 .05 7( Lt ' 03 ..~ .03 li::JV AL SEVERE RI .02 0;1 ~li2ht .02 .07 ì2 ..t .02 8 0 0 n <;llght .02 q 0 .04 )] .02 0 0 J4 ! Siighl .02 2. 0 JL ~5Jg .02 2 0 -:92 0 3 0 2139 () 1C 4 0 2.87 ,0 7 2 0 (4 2.88 .0 lC 4 0 19 2.89_t. 0 COO 0 2.87 GLM 4 lLatrh@ 11 :om 7 2 0 ,04 2.87 q 2 0 OS 2.87 7 4 0 05 2.90 q 3 0 05 2.86 l.t 9 2 0 04 2.86 1310 3 0 .04 2.91 .02 7 2 0 .05 2.88 Lt .02 ( 4 0 .04 2,92 .02 7 2 .04 2.87 .02 q 2 .04 2.86 .02 7 2 .04 2.90 .02 7 2 .05 2.89 ' ~, .02 9 2 0 .05 2.89 .02. 8 2 00/1 2. R 7 ' ~, , m h 2 0 .0'\ 2-?;f, 02 7 2. 0 .04 2-P,(; " n' , 0 0 0 0 0 2Rg GlM 5 Ilatch @ '120m n) ( 2 0 .04 2R9 m 2. 0 .04 28g m ~F 1 0 .04 2')2 m J 0 .03 2R5 OVAL <;FVFRF Rilniiilll\;r": mlr 2 0 .04 2.89 mq 2 0 .04 2.92 m Ùì 3 0 ,04 2.87 m f, 2. 0 ,05 291 m [] 2 0 .04 292 me) 3 0 .04 2'12 mg 2 0 .05 2.90 , D ",IA;"" n ". n "'"A'!,nn -;-: "". " ". n n ". n ". n ". page 3 Damage ) ';0 1C I' I', I. I '..' ì I" 1 , . { , ',' . ;' I ". 1./ ", ;'. ," " Pipe: 3.5 ins 9.3 Wall thickness. NominaID: 2.992 ins !\fletal "> "'"""u inc les inc;~:~Y (Yo 'Yo ~;~~~~s ~!~~;~es inches I q 2 0 .04 2.87 0 .04 2.88 0 2.87 .04 2.89 0 2.86 .04 '.86 .04 ~~. Joint No. :1 '1 I '1 ì .1 21 216 0 217 0 218 0 219 0 220 0 221 0 .222 0 223 0 224 0 225 0 1226 0 :2 0 0 0 .1 0 0 1 .02 .01 4 2 .02 6 2 .02 8 3 .02 7 .02 ß 2 .02. 8 .01 6 .02 q 0 C 0 .02 8 2 010 2 .0: 7 4 ;; 2 10 8 )2 1233 234 1235 1236 ( 23 7 0 12 1238 0 .02 1239 0 .02 .240 0 .02 1241 0 .02 ! 242 0 .02 '243 0 ,03 244 0 .02 245 0 .02 245,1 0 0 246 0 .03 247 0 .03 r~iJ!~~$.03 .03 .03 251 0 .03 2S2 0 .03 253 0 .03 )54 0 .03 2SS 0 .03 256 0 .03 257 0 ,02 2 8 2 8 'I 11 2 9 2 9 2 0 0 Ii 13 2 11 2. 11 2 13 2 1,1 2 12 Î 2 2 n 2 12 2 12 2 8 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .07 .04 .05 ,.D4 .05 .05 0 .03 0 0 .08 0 .D3 ,04 0 .04 .04 .04 .05 .04 0 .06 .04 .07 .07 .09 .07 .07 .08 .08 .08 .08 .07 Well: Date: mJ R "...Í/lín<, GLM 6 (Latch @ 200ì K",'l.lino n Lt l' )( 2.88 2.91 2.85 ' OVAL SEVERE RIICk, 1"-1("; 2.84 2.92 ,~ 2.76 ClM 7 (Latch @ 7:00\ 2.76 . L1 2.85 OVAL SEVERE Rllnn ¡"-Ie; 2.86 296 2.87 2.90 2.85 I OVAL SEVERE RllíKIIN("; 2.85 2.90 n 2.83 ! OV AL. SEVERE R! IrKI ¡N" 31 I,d I 1 Lt. : .dl 19 \6 Lt 291 2.88 Gl r\ 8 (Latch @II :30\ 2.88'( Ditting, Lt 2.89 Shal ow 2.86 2.80 '( " 2.81 2.87 <;h"llnw í. 2.84 D, .<: 2,85 Ll. ~ 2.86 .", Dltting, U, ,~ 2.88 n It. ~ 2.89 Shallow r- L1. ~ 2.88 Lt ~ D ,0: Lt. U. ( Ll. L1. L1. D, .1: Tabulations page 4 penetration Illeta loss ~ 10/ \ '" 50 100 ITIIII IIIIII IIIII IIIII i I I I I IIIII I III [I I II II I Iii I I I IIIII IIIIII IIIIII 1IIIIII II III I' II11 III I i III I I IIII I II [ I I, IIII IIIIII Lull.ULI , , . , :- " ': , , . " ," : RJ Pipe: 3.5 ins 9.3 VV al thickness. 10: 2,992 Well: Date: Joint !~ U uU~'U Metal udrT1age No. ! l¡:~~I~s 1 ~¡~;~es r in( hes ¡ndf~ lYe, Inches ) 50 1 " 1 0 .07 2.86' It 'YiY rT " 0 .09 2.83 rL L1. npnn"ik 'i'" I i ,( lmi UUUdJl 'h :;;/ 261 .03 10 2.74 1 OV At. SEVERE Rl irK! INC ,,1' I I ! 2611 0 0 ( 2.82 ell\¡1 9 (Latch @ 1000) i I 1262 0 .02 2.82 I OV At SEVERE Rt ¡rKIING. y,,:: II 262,1 0 0 0 PBR II 12622 0 .03 I .03 ,8 PUF '>i!dllOW pitting, :;/i 1262.3 0 0 ¡-'f\Ll\tK I i 263 () .02 1W;: I 1 12631 0 0 « ( 0 PROD. MAI\ir1RI=I I I 1264 0 .03 10 0 .05 31 I '¡ 1265 0 .02 =~t~ ~ 0 .07 2.84 III I, 1266 () .04 .12 .04 2.87 '>i!c ow pitting. I I I [ 1267 0 .25 0 .17 2.88 ¡HC _E I 1267.1 0 ,.10 39 27 .08 06 2.91 PUP Ring pm"inn Lt ¡I I I.L._... 1268.2 0 0 0 0 0 0 0 AVA Sleeve 00 1 ! [ I I ! I [ ! I , I ! .J Classifications Penetration / Hole penetration exceeds Line. Cenera . Isolated. T abuations page 5 rJ) t'-- co cr; 0 00 0 . 0 0 N Z- ~ "1" '-0 ~N'::::' U~ LL~ :;: u Z ::L ::)U) c¿CL In « ::::J OCL....! LL ::) T: cn::LO:: ~ :ê ::::J CO I , - u I 3 U rt ¡;¿ rJ) :.... ..... ro Or'¡ 0 00 80 N z" - "" '-0 := f15 íI. "" 2: N QJ -;¡; 0 (!) .~ >, V1 <1)-- f; 0 0 0 ~~~z u Z <- v Vi < -' :L.< ::JV1 ¡:¿CL Lr)<::J oeL=:!< u:.. ::J ::r: V1 U) M:L.CL::JM =<::5 QJ--: 3:£ >- t: c g:Q u¡:::: CL ::) w 0 U1 I U I -;::a 3: ;fi! û'; M c 0 1-.... r,j if¡ ~ .- 1'-.. co (V) 0 00 0 . 00 N Z." --q- ~ N~ ~::¿::::-q- ¿:~N u Z CL ::J II I LJ I rJ) !-. .- t'-.. ro '" 0 00 0 0 ~ z" - "t ;:: ~ N-...... ~U LL ~ :?:~ u z =-ö we:; SÜ:: 0.., :=> Ii I U I ~ 0 r; ~ ~ w ro ð c£ L1J PDS uALIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset-- 0.254ins NoFninal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches 66 2046.88 31.21 2.978 67 2078.09 29.49 2.990 68 2107.58 31.13 2.990 69 2138.71 30.04 3.007 70 2168.75 28.00 2.984 71 2196.75 31.62 2.988 72 2228.3 7 30.69 2.976 73 2259.06 2 7.24 2.985 74 2286.30 30.67 2.979 75 2316.97 30.81 2.989 76 2347.78 29.28 2.989 77 2377.06 30.31 2.995 78 2407.37 28.97 2.982 79 2436.34 30.08 2.988 80 2466.42 2 7.95 2.996 81 2494.37 32.56 2.976 82 2526.93 30.19 nominal 83 2557.12 32.92 2.974 84 2590.04 31.30 2.989 85 2621.34 31.20 2.988 86 2652.54 32.04 2.987 87 2684.58 31.36 2.983 87.1 2715.94 6.84 nominal GIm 1 88 2722.78 30.72 2.984 89 2753.50 30.85 nominal 90 2784.35 29.10 nominal 91 2813.45 32.20 nominal 92 2845.65 31.91 2.986 93 2877.56 31.41 2.977 94 2908.97 29.56 2.987 95 2938.53 31.32 2.997 96 2969.85 29.29 2.995 97 2999.14 28.31 2.990 98 3027.45 29.87 2.990 99 3057.32 30.62 2.973 100 3087.94 31.08 2.987 101 3119.02 30.06 2.978 102 3149.08 30.92 2.981 103 3180.00 31.05 2.965 104 3211.05 30.70 2.989 105 3241.75 30.90 2.994 106 3272.65 31.43 2.991 107 3304.08 30.25 2.969 108 3334.33 29.77 2.994 109 3364.10 30.08 2.985 110 3394.18 29.69 2.985 111 3423.87 28.09 2.983 112 3451.96 30.65 2.978 113 3482.61 30.17 2.973 114 3512.78 28.54 2.995 Well: 3 F-05 Field: KUPARUK Company: PHILLIPS ALASKA, INC. Country: USA Date: July 11, 2000 Joint Depth Length Measured Type No. ID feet feet inches 115 3541.32 29.81 2.990 116 3571.13 29.14 3.003 11 7 3600.27 29.41 2.972 118 3629.68 31.61 2.967 119 3661.29 30.40 2.977 120 3691.69 31.19 2.984 121 3722.88 31.43 2.976 122 3754.31 31.50 2.962 123 3785.81 29.47 2.978 124 3815.28 30.95 2.978 125 3846.23 30.49 2.981 126 3876.72 31.28 3.000 127 3908.00 30.88 2.984 128 3938.88 28.95 2.979 129 3967.83 31.74 2.979 130 3999.57 31.56 2.990 131 4031.13 30.84 2.990 132 4061.97 30.96 2.988 133 4092.93 31.37 3.007 134 4124.30 31.14 nominal 135 4155.44 30.96 2.997 136 4186.40 30.91 2.989 137 4217.31 29.57 3.006 138 4246.88 31.60 3.001 139 4278.48 30.73 2.995 140 4309.21 30.79 nominal 141 4340.00 31.33 2.973 142 4371.33 31.21 2.996 143 4402.54 2 7.53 2.973 143.1 4430.07 6.52 nominal GIm 2 144 4436.59 31.72 2.977 145 4468.31 31.19 2.980 146 4499.50 31.21 2.978 147 4530.71 30.99 2.976 148 4561.70 31.11 2.974 149 4592.81 28.81 2.971 150 4621.62 29.11 2.957 151 4650.73 28.79 2.977 152 4679.52 31.42 2.978 153 4710.94 32.16 2.987 154 4743.10 30.59 2.988 155 4773.69 30.29 2.967 156 4803.98 31.11 2.974 157 4835.09 31.34 2.979 158 4866.43 30.66 2.984 159 4897.09 29.04 2.970 160 4926.13 31.60 2.977 161 4957.73 31.95 2.987 162 4989.68 31.02 2.979 163 5020.70 29.81 2.963 Joint Tally page 1 RECEIVED JUL 24 2000 Alaska 0il & Gas Cons. Commission Anchorage PDS u LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches 164 5050.51 30.90 2.966 165 5081.41 31.61 2.966 166 5113.02 31.66 2.998 167 5144.68 30.66 2.991 168 51 75.34 27.04 2.994 168.1 5202.38 10.42 nominal GIm 3 169 5212.80 31.76 2.985 1 70 5244.56 30.60 2.990 1 71 5275.16 30.75 2.967 1 72 5305.91 31.89 2.975 1 73 5337.80 30.58 2.981 1 74 5368.38 32.66 3.000 1 75 5401.04 30.22 2.989 1 76 5431.26 31.42 2.991 1 77 5462.68 30.21 2.988 1 78 5492.89 31.73 2.975 1 79 5524.62 30.23 2.995 180 5554.85 30.90 2.979 181 5585.75 31.10 2.986 182 5616.85 31.05 2.995 183 5647.90 30.61 2.991 183.1 5678.51 6.29 nominal GIm 4 184 5684.80 32.00 2.980 185 5716.80 30.44 3.005 186 5747.24 30.82 2.978 187 5778.06 30.09 2.991 188 5808.15 31.09 3.011 189 5839.24 30.91 2.995 190 5870.15 30.62 2.994 191 5900.77 29.84 2.994 192 5930.61 30.84 2.990 193 5961.45 30.82 2.997 194 5992.2 7 30.84 2.988 195 6023.11 30.20 nominal 196 6053.31 30.76 2.998 197 6084.07 30.53 2.979 198 6114.60 30.53 2.983 199 6145.13 28.69 2.990 199.1 61 73.82 7.08 nominal GIm 5 200 6180.90 28.39 2.988 201 6209.29 30.27 2.986 202 6239.56 30.20 2.991 203 6269.76 30.63 nominal 204 6300.39 31.23 2.987 205 6331.62 30.67 nominal 206 6362.29 30.99 2.989 207 6393.28 30.63 3.008 208 6423.91 31.14 2.996 209 6455.05 30.94 2.999 210 6485.99 30.84 2.995 Well: 3 F-05 Field: KUPARUK Company: PHILLIPS ALASKA, INC. Country: USA Date: July 11, 2000 Joint Depth Length Measured Type No. ID feet feet inches 211 6516.83 31.12 2.980 212 6547.95 31.59 2.984 213 6579.54 30.80 2.996 214 6610.34 30.49 2.986 214.1 6640.83 6.16 nominal GIm 6 215 6646.99 31.21 nominal 216 6678.20 31.10 2.995 21 7 6709.30 29.95 2.997 218 6739.25 31.40 2.985 219 6770.65 29.48 2.997 220 6800.13 31.28 2.990 221 6831.41 31.53 3.002 222 6862.94 30.98 2.990 223 6893.92 31.35 nominal 224 6925.27 31.68 2.982 225 6956.95 30.54 2.982 226 6987.49 28.93 2.988 227 7016.42 28.99 2.987 228 7045.41 30.47 2.994 229 7075.88 29.94 3.005 229.1 7105.82 7.40 nominal GIm 7 230 7113.22 29.42 3.007 231 7142.64 31.04 nominal 232 71 73.68 29.14 2.974 233 7202.82 29.49 3.004 234 7232.31 29.71 2.988 235 7262.02 30.18 2.989 236 7292.20 28.42 2.985 237 7320.62 32.08 2.985 238 7352.70 28.71 nominal 239 7381.41 30.53 2.991 240 7411.94 29.43 2.995 241 7441.37 30.34 3.011 242 7471.71 29.47 2.982 243 7501.18 30.02 3.009 ~244 7531.20 29.91 2.989 245 7561.11 28.74 2.981 245.1 7589.85 8.31 nominal GIm 8 246 7598.16 28.22 2.988 247 7626.38 28.56 nominal 248 7654.94 29.66 2.988 249 7684.60 30.83 2.990 250 7715.43 30.10 2.985 251 7745.53 30.54 3.001 252 7776.07 29.54 2.988 253 7805.61 29.50 2.988 254 7835.11 30.87 2.984 255 7865.98 28.30 2.995 256 7894.28 29.91 2.982 257 7924.19 28.10 2.997 Joint Tally page 2 RECEIVED JUL 2 4 2000 Alasffa 011 & Gas Cons. Commission PDS C LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf J-55 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins I Joint Depth Length Measured Type No. ID feet feet inches 258 7952.29 29.87 2.979 259 7982.16 30.47 3.002 260 8012.63 28.83 2.990 261 8041.46 31.24 2.986 261.1 8072.70 8.66 nominal GIm 9 262 8081.36 32.58 nominal 262.1 8113.94 10.18 nominal PBR 262.2 8124.12 10.91 2.976 Pup 262.3 8135.03 9.83 nominal PKR 263 8144.86 28.53 3.005 263.1 81 73.39 7.80 nominal PRD MI 250 8181.19 30.72 2.985 265 8211.91 30.39 2.991 266 8242.30 31.23 3.001 267 8273.53 31.06 3.020 267.1 8304.59 26.60 nominal Pup 267.2 8331.19 unknown 2.985 AVA )RL Well: 3 F-05 Field: KUPARUK Company: PHILLIPS ALASKA, INC. Country: USA Date: July 11, 2000 Joint Depth Length Measured Type No. ID feet feet inch es Joint Tally page 3 RECEIVED JUL £ 4 000 Alaska Oit & G~s Cons. Oo,m,,T~iSSiOr~ Anchorage ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3F-13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Ku~aruk Well Pressure Report Ku ~aruk Ku ~aruk Ku ~aruk Ku }aruk Ku ~aruk Ku ~aruk Ku ~aruk Ku ~aruk Ku ~aruk Ku 3aruk Ku3aruk Ku~aruk Ku3aruk Kuapruk Ku ~aruk Ku ~aruk Ku~aruk Ku ~aruk Ku3aruk Ku3aruk Ku~aruk Ku3aruk Kuaaruk Ku3aruk Ku~aruk Ku )aruk Ku~aruk Ku )aruk Ku~aruk Kuaaruk 10-06-88 8-29-88 Well Pressure Report I 2- 2 0 - 88 Well Pressure Report 8 - 29 - 8 7 Well Pressure Report 8 - 29 - 87 Well Pressure Report 8 - 29 - 89 Well Pressure Report 8 - 1 7 - 8 7 Well Pressure Report 8 - 1 7- 87 Well Pressure Report 8 - 29 - 87 Well Pressure Report 6 - 26 o 8 7 Well Pressure Report 1 2 - 1 2 - 88 Well Pressure Report 1 2 - 31 - 88 Well Pressure Report 6 - 1 I - 87 Well Pressure Report 6 - 1 I - 8 7 Well Pressure Report 9 - 01 - 8 7 Fluid Level Report 5 - 04 - 8 7 Fluid Level Report 2 - 1 3 - 89 Fluid Level Report 2 - 1 0 - 89 Fluid Level Report 2 - 1 0 - 89 Fluid Level Report 6 - 05 - 8 7 Fluid Level Report 6 - 09 - 8 7 Fluid Level Report 6 - 1 8 - 87 Fluid Level Report 6 - 1 6 - 8 7 Fluid Level Report 6 - 21 - 8 7 Fluid Level Report 5 - 08 - 8 7 Fluid Level Report 8 - 1 8 - 8 7 Fluid Level Report 8 - 24 - 8 7 Fluid Level Report 6 - 05 - 8 7 Fluid Level Report 6 - 2 / 3 - 8 7 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 - 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing ~chorage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Re 3crt Re 3crt Re 3crt Re 3crt Re 3crt Re 3crt Re )crt Re 3crt Re 3ort Re 3crt Re 3crt Re 3ort Re 3crt Re 3ort Re 3crt Re )crt Re )crt Re )crt Re )crt Re )crt Re )crt Re )crt Re )crt Re )crt 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 I -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Alaska Oil & Gas Cons. Commission ....... ~rn~Orage DISTRIBUTION: D&M State of Alaska ; Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Post Olfice t_., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 28, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk . ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal'~ 6098 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~' 2X-16 ~3M-lO - 3M-11 ~ lQ-12 ---- 3C-1 ~ 3F-5 ~ 3F-5 ~ 3C-15 ~ 3C-16 - 3C-14 Kuparuk Well Pressure Report(Otis) 10-3-87 PBU 'A' Sand Kuparuk Well Pressure Report(Otis) 10-2-87 Static 'A' Sand Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand Kuparuk Operations Engineering Pressure Falloff Analysisl 3-15-87''A' Kuparuk Well Pressure Report(Otis) 8-15/18-87 PBU 'A' Sand Bottom-Hole Pressure Survey 'C' Dual-Zone PBU 10-13-87 50-029-21460 Bottom-Hole Pressure Survey 'A' Dual-Zone PBU 10-13-87 50-029-21460 Kuparuk Well Pressure Report(Otis) 8-28-87 Static 'C' Sand Kupaurk Well Pressure Report(Otis) 8-30-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-19-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-16/19-87 PBU 'A' Sand Receipt Acknowledged: · DISTRIBUTION: Date: D&M BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary o! AllantlcRichfieldCompany STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION CO~v~'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILX~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2.,N,,a,,m~e ,o,f ORerator' 7. Permit Number ~u /~lasKa~ inc. 85-242 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21460 4. Location of well at surface 9. Unit or Lease Name 49' FNL, 70' FWL, Sec.29, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1573' FNL, 1521' FEL, Sec.20, T12N, RgE, UM 3F-5 At Total Depth 11. Field and Pool 1184' FNF, 1244' FEL, Sec.20, T12N, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D, Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 10/14/85 10/19/85 10/21/85*I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey t 20. Depth where SSSV set I 21.Thickness of Permafrost 8875'MD, 6390'TVD 8683'MD, 6253'TVD YESY~] NO[-] 1797 feet MD 1550' (approx) 22. Type Elect.tic or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET, GCT 1- 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP ~ BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6" 62.~ H-40 5urt 115' 24" 328 sx AS II ~-5/~" 36.0# J-55 Surf 3974' 12-1/4" 1060 sx PF "E" & 425 sx pF "C" /" 26.0# J-55 Surf 8773' 8-1/2" 200 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8504' - 8462' w/4 spf 3-1/2" 8347' 8135' & 8324' 8447' - 8408' 26. ACID, FRACTURE, CEMENT soUEEZE, ETC. 8280' - 8204' w/1 2 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See addendum attacled to Well Completion Report ,, dated 3/31/86. 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (~o~r) Press. 24-HOUR RATE I~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, r None Form 10-407 * NOTE: Tubing was run & the well perforated 12/05/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WCl/047 Submit in duplicate 29. ' 30. :, GEOLOGIC MARKERS ' ' : .... " ':' ' ' : FORMATION TESTS . NAME , ? ' ._ ' Include interval tested, pressure data,'allfluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8200' 5913' N/A Base Kuparuk C 8282~- 5970' Top Kuparuk A 8387.' 604~,' .. Base Kuparuk A 8568' 6171' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the .best of my knowledge Signed (~~ ~j~J~ Title ASSoci ate Engineer Date // INSTRUCTIONS General' This form is designed for submitting a complete and correct well completio, n report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where 'not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show. the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump,. Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 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 [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-242 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21460 4. Location of well at surface 9. Unit or Lease Name 49' FNL, 70' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1573' FNL, 1521' FEL, Sec.20, T12N, R9E, UM 3F-5 At Total Depth 11. Field and Pool 1184' FNL, 1244' FEL, Sec.20, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 93' RKB ADL 25632 ALK 2565 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116'N°'°f Completions 1 0/14/85 1 0/19/85 10/21/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8875'MD, 6390'TVD 8683'MD, 6253'TVD YES [~(X NO []I 1797 feet MD 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor installation rept. not yet receiw 9-5/8" 36.0# J-55 Surf 3974' 12-1/4" 1060 sx PF "E" & 425 sx PF "C" 7" 26.0# J-55 Surf 8773' 8-1/2" 200 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8504' - 8462' 3-1/2" 8347' 8135' & 8324' w/4 spf 8447' - 8408' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8280' - 8204 ' w/1 2 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Add~:ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED APR O 3 Zg86 Alaska Oil ~ 6as Cons. Comtn~lon ~chora,ge Form 10-407 * NOTE: Tubing was run & the well perforated 12/05/85. GRU13/WC13 Submit in duplicate ~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top. Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 8200' 8282' 8387' 8568' TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity GOR, and time of each phase. 5913' 5970' 6043' 6171' N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so_ state in item 16, and in item 24 show the producing interva!s for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached s. uP.plemental records for this well should show the details of any multiple stage cement- 'lng and the Iocat..ic~ of the 'cerflenting tool. Item 27: Method't°f. Operatio~· Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- .jection, Gas Injection, Shut-in, Other?explain. . · , :~,~ ~, .... Item 28' If no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 10/29/85 11/14/85 12/28/85 3F-5 Arctic Pak w/175 sx PF "C". Rn CET log f/8647'-6970' & 3450'-1800'. Rn GCT gyro f/PBTD - surf. Frac Kuparuk "A" sand perfs 8408'-8442' & 8462'-8504' in 3 stages per 12/17/85 procedure using gelled diesel, Musol & 20/40 sand. Press'd ann to 2400 psi w/diesel. Tst ins to 7000 psi; OK. Pmp'd 20 bbls 5% Musol, followed by 73 bbls of cln diesel on 12/20/85. Stage 1: 35 bbls gelled diesel pad @ 5.2 BPM, 2570 psi. Stage 2: 31 bbls gelled diesel w/6 ppg, 20/40 mesh sand @ 5.2 BPM & 2550 psi. Stage 3: 73 bbls gelled diesel flush @ 20.5 BPM, 2420/4150 psi. Pmp'd 4500# 20/40 mesh sand in formation leaving 500# 20/40 sand. Load to recover 232 bbls of diesel. Job complete @ 2000 hrs, 12/28/85. Drilling ~uperintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3F-5 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 3F-5. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L26 Enclosures RECEIVED FEB 0 4 Alaska Oil & Gas ...... ,.,~,,~. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfietdCompany STATE OF ALASKA ALASKA O,,_ AND GAS CONSERVATION CO,.,,vllSSION WELL COMPLETION OR.RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS I-] SUSPENDED i--I ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-242 ,. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21460 . 4. Location of well at surface 9. Unit or Lease Name 49' FNL, 70' FWL, Sec.29, T12N, RgE, UM ~ Kuparuk River Unit i LL,x~/~ i ~,~ 1. At TOp Producing Interval~ ¥c--_--~- 1 ~'~,~'p,'[:'l~r~. Ii 10. Well Number 1573' FNL, 1521' FEL, Sec.20, T12N, RgE, LIH[ j~ ! 3F-5 At Total Depth~,,v..~- [!/Sur~L~_~.-' 11. Field and Pool 1184' FNL, 1244' FEL, Sec.20, T12N' RgE, UN IB[B~H'~ Kuparuk River Field 5. Elevation in fat (indicate KB, DF, etc.) ~ 6. L~se D~ignation and Serial No. Kuparuk River 0~ ~ Pool 93' EKBJ ADL 25632 ALK 2565 12. Date Spudd~ 13. Date T.D. Re~h~ 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/1 ~/85 10/19/85 10/21/85* N/A feet MSL 1 I ' 17. lotal ~th {~+TVD} 18.¢1u~ 8~k ~th{M~} 10. ~ir~tional Surv~ I 20. D,pth ~h~r~ SSSV ~t 21. T. hickn~ of P~rmafro~t 8875'MD, 6390'TVD 8683'~, 6253'T~ YES ~X NO ~I 1797 f~t MD 1550' (approx) i 22. Type El~tric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET, ~T 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE~.PER FT. GRADE TOP BOSOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5~ H-40 Surf 115' 24" Conductor installation rept. not yet;receive 9-5/8" 36.0~ . J-55. Surf 3974' 12-1/4" 1060 sx PF "E" & 425 s. PF "C" 7" 26.0~ J-55 Surf 8773' 8-1/2" 200 sx Class G & 175 s. PF "C" 24. Perforations open to Production (MD+TVD of T~ and Bottom and 25. TUBING RECORD intewal, size and numar) SIZE DEPTH SET (MD) pACKER SET (MD) 8504' - 8462' 3-1/2" 8347 ' 8135 ' & 8324 ' w/4 spf 8447' - 8408' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8280~ - 820~~ w/12 spf DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Pr~uction Method of Operation (Flowing, ~s li~, etc.) Date of Test Hours T~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing C~ing Pr~ure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) press. 24-HOUR RATE ~ 28. CORE DATA Brief de~ription of lithology, porOsity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None FEB 0 Form 10-407 TEMP3/WC47 *NOTE: Tubing was run & the well perforated 12/05/85 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .. . 30. . . - ~ "GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kup'aruk C 8200' 5913' N/A Base Kuparuk C .8282' 5970' Top Kuparuk A 8387' 6043' Base Kuparuk A 8568' ' 6171' -. ? · . . 31. LIST OF ATTACHMENTS Addendum (dated 12/11/85), Gyroscopic Survey (2 copies)/ ~/~/f~_-~! ~l'~'/~.f'y (dOmplz,-h'0n 32. i hereby certify that the foregoing is true and correct to the best of my knoWledge (~~ ~ Title Associate Engineer Date Signed 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 f¢om more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Daily Well History-Initial RePOrt Instmctionl: Prepare and submit the "lnitill Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized_ on the form giving inclusive dates only. Dislrict I County or Parish State IW Alaska North Slope Borough i Alaska Field Lease or Unit . all no. Kuparuk River ADL 25632 3¥-5 Auth. or W.O. no. ITM AFE AK0430 I Completion Nordic 1 API 50-029-21460 Operator I A.R.Co'a W.I. ARCO AlaSka, InC' I 56.24% 'Spuddad or W.O. begun. IOat,: IHou,. IP,or ,tllu,, e W.O. I 12/4/85. I 1130' hrs. I Comple~:e Oate and depth ~- aa of 8:00_a.m._ . ~, ~ .... ~ 12/05/85 ._ Complete record for each day reported · 7" @ 8772~; ~ 8683' PBTD,: RIH w/3~" tb~'~ ' Wt 9.9 PPg NaC1/NaB]: Accept rig @~ 1130 hfs,. 12/4/85. ND tree, NU &'tst BOPB¥~ RU' Schl, perf w/4" gum-, 4 SPF, 90° phasins-f/8462'-S504,' & 8408'-8447'. Perf'w/5" gun, 12 SPF, 120* phasinS~ f/8204'-8280'. RIH~ w/6-1/8" sase rins/JB, POOH. pkr, set @ 8312' WLM. RI): Schl. RIH w/3~" tbs. The above is correct Signature For form prepsration and {~tdbution. see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate . ITitle Drilling Superintendent ARCO Oil and Gas .Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also When operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska Field . ]Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE AK0430 I Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 12/06/85 North Slope Borough ADL 25632 CompieCi°n I Accounting State cost center code Alaska IWell no. 3F-5 API 50-029-21460- 56.24% Complete record for each day reported 1214185- Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our IPrlor status if a W.O, 1130 hrs. I 7" @ 8772' 8683' PBTD, RR Wt 9.9 ppg NaCl/NaBr RIH w/262 its, 3½", 9.3#, J-55 8RD EUE IPC tbg w/SSSV @ 1797' FEL Pkr @ 8135', FB-1 pkr 8324', "D" NiPple @ 8339', TT @ 8347'. Tst tbg & ann to 2500 psi. ND BOPE, NU & tst pack-off. Displ well w/diesel. RR @ 2000 hrs, 12/5/85. Old TD Released rig 2000 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data INew TD 8683' PBTD Date Rotary I PB Depth [Kind of rig 12/5/85 I IType completion (single, dual, etc.) Single * Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date , corrected The above is correct For form preparation and dO'tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 10/29/85 11/14/85 3F-5 Arctic Pak w/175 sx PF "C". Rn CET log f/8647'-6970' & 3450' f/PBTD - surf. -1800' Rn GCT gyro RECEIVED ~,:.,n.~. Co.rnlTlission i I'~b'u i ,,.4; 1V Drilling/Superintendent I~ate ARCO Alaska, Inc. ~-~.~ Post Office L 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85 TRANSMITTAL # 5481C Transmitted herewith are the following items. Please acknowledge receipt and retu~n one signed copy of th-'.s transmittal. Open Hole Finals/ Schl/ One * of Each 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu ~ Cyberlook 5" ~ . DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu ~ ~ Cyberlook 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu ~2" Den/Neu 5" Den/Neu 2" Dem/Neu ~, Cyberlook 11-03-85 Run#1 11~03~85 Run#1 (poro) 11-03-85 Run#1 (poro) 11-03-85 Run#1 (~aw) 11-03-85 Run#1 (raw) 11-03-85 Run#l_ 11-03-85 Rungl 1~-27-85 Run #1 10-27-85 Run 91 (poro) 10-27-85 Run #1 (poro) 10-27-85 Run #1 (raw) 10-27-85 Run #1 (raw) 10-27-85 Ran 91 10-27-85 Run #1 10-20-85 Run 91 10-20-85 Run #1 (poro) 10-20-85 Run #1 (poro) 10-20-85 Run #1 (raw) 10-20-85 Run #1 (raw) 10-20-85 Run 91 10-20-85 Run #1 3457-8033 3457-8033 4800-8007 4800-8007 4800-8007 4800-8007 7300-7984 3384-7715 3384-7715 3384-7689 3384-7689 3384-7689 3384-7689 3384-76~9 2000-8862 2008-8862 ~5600-8836 5600-8836 5600-8836 5600-8836 7500-8813 Receipt Acknowledged: STATE OF ALASKA * BL & SE RATHMELL *BL NSK CLEPc~ *BL DRILLING *BL. VAULT *FXLMS DEGLOYER & MACNAUGHTON *BL Date: ,~l~t"t~ al~.k~ In~ ,~ · .~ubsidiar¥ of AtlanticRiclllleldComl~anY ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3F-5 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3F-5. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L110 Enclosure RECEIVED Alaska Oil & Gas Cons. Oom~nts~ior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKA G~ AND GAS CONSERVATION cO._~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL r-] GAS [] SUSPENDED r~X ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-2/+2 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21460 4. Location of well at surface 9. Unit or Lease Name 48' FNL, 70' FWL, 5ec.29, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 3F-5 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Fi eld 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKB ADL 25632 ALK 2565 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/14/85 10/19/85 10/21/85 N/A feet MSLI N/A 17. Total Depth (MD+T~D) 8875 'MD 18.Plug Back Depth (MD+TVD)19. Directional SurveY8683,MD YES [~X NO [] I20' Depth Where SSSV setN/A feet MD [ 21. Thickness of Permafrost1550, (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" '62'.5# H-40 Surf 115' 24" Conductor installation rept. not ~,et receive 9-5/8" 36.0# J-55 Surf 3974' 12-1/4" 1060 sx PF "E" & 425 s:[ PF "C" 7" 26.0# J-55 Surf 8773' 8-1/2" 200 sx Class G & 175 s:( PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, cEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/^ ,_ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.} I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OiLRATIO TEST PERIOD II~ . Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED AJaska 0il & 13as Cons. C0rr-,,m!ssi0n Form 10-407 TEMP2/V/C63 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " GEOI'OGICMARKERS' ' ' ' ' :~ ~ 'FORMATION TESTS" _.; .3:: ~'.' ' ''~ · NAME Inclu~le interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . · To be submitted wk~n gyro is rece:¢ed. N/A · . . .. 31. LIST OF ATTACHMENTS Well History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~~-~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gas Company .~' ,~, Well History - Initial Report - Daily Inslructlone: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily worl( prior to spudding should be summarized on the form giving inclusive dates only, District ICounty, parish or-borough IState Alaska Alaska I North Slope Borough Field lLease or Unit IWell no. Kuparuk River I ADL 25632 I 3F-5 Auth. or W.O. no. ITitle AFE AK0430 I Drill I Doyou 9 A.PI 50-029-21460 Operator -. {ARCO w.I. ARCO Alaska, Inc. ' I 56.24% Spudded or W.O. begun {Date IHour {Prior status if a W,O. Spudded 10/14/85 1600 hrs. Date and depth as o! 8:00 a.m. 10/15/85 lO/16/85 lO/17/85 lO/18/85 Complete record for each day reported 16" @ ±115' 1545', (1430'), Navi-Drl Wt. 9.8, PV 14, YP 18, PH 9, WL 15.2, Sol 10 Accept rig @ 1100 hfs, 10/14/85. NU diverter sys. 1600 hfs, 10/14/85. Drl & surv 12¼" hole to 1545'. 300', Assumed vertical 469', 4.4°, Na0.25E, 469 TVD, 5 VS, 1N, 6E 935' 18.5°, N70.25E, 925 TVD, 88 VS, 35N, 90E 1087;, 22.9°, N64.25E, 1067 TVD, 137 VS, 56N, 139E 1393', 29.6°, N52.25E, 1340 TVD, 269 VS, 129N, 254E Spud well @ 16" @ 115' 3980', (2435'), Short trip Wt. 9.8, PV 22, YP 26, PH 9.5, WL 8.6, Sol 10 Drl & surv 12¼" hole to 3980', short trip to HWDP. 1708', 38.2°, N51.25E, 1602 TVD, 445 VS, 240N, 391E 2080', 49.8°, N48.25E, 1869 TVD, 701 VS, 407N, 587E 2405', 51.5°, N46.25E, 2075 TVD, 952 VS, 580N, 770E 9-5/8" @ 3974' 3990', (10'), TOH- Wt. 8.6+, PV 2, YP 2, PH 10, WL 16.8, Sol 2 Fin short trip & cond well, TOH. RU & rn 99 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3974', FC @ 3892'. Cmt w/1060 sx PF "E", followed by 425 sx PF "C". Displ using rig pmps, bump plug. CIP @ 1745 hfs, 10/16/85. Good rtns throughout job. 9-5/8" @ 3974' 6831', (2841'), Navi-Drl Wt. 9.4+, PV 8, YP 3, PH 9.5, WL 5.4, Sol 7 Fin trip f/Navi-Drl, drl & surv 8½" hole to 6831'. 4070', 44.8°, N50.25E, 3161TVD, 2203 VS, 1385N, 1737E 4509', 47.6°, N44.25E, 3462 TVD, 2522 VS, 1598N, 1974E 5045', 47.5°, N42.25E, 3819 TVD, 2922 VS, 1891N, 2246E 5546', 49.5°, N38.25E, 4155 TVD, 3293 VS, 2170N, 2492E 6110', 47.8°, N39.25E, 4526 TVD, 3716 VS, 2502N, 2757E 6426', 46.5°, N36.25E, 4741TVD, 3946 VS, 2685N, 2899E ,R FCEiVED Alaska Oil & Gas Cons, Anchorago The above is correct Slgn alu re ~.,~ ~1~1~.~ For form preparation and dlst{~bution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. I,~ate ~I-~Z] ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instruction,: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Reporl" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire oPeralion if space is available. District ICounty or Parish Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE AK0430 Doyon 9 North Slope Borough ADL 25632 Drill JAccounting cost center code State Alaska IWell no. 3F-5 API 50-029-21460 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 10 / 14/85 Dale and depth Complete record for each day reported as of 8:00 a.m, 10/19/85 thru 1o121185 10/22/85 10/28/85 I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1600 hrs. 9-5/8" @ 3974' 8875' TD, 8683' PBTD, Prep to set wellhead Wt. 9.9, PV 10, YP 7, PH 9.5, WL 5.6, Sol 11 Navi-Drl & surv f/6831'-8875', short trip to shoe, hole sticky on btm. C&C, TOH f/logs. RU & log w/DIL/GR/SP/SFL f/8880'-3974'. Rn FDC/CNL f/8880'-7500', & f/6600'-5800'; rn CAL f/8880'-6500', RD Schl. TIH w/DP, C&C well, POOH, LDDP. RU & rn 202 jts, 7", 26#, J-55 BTC csg w/FS @ 8773', FC @ 8682'. Cml w/200 sx CL "~' @ 15.6 ppg, displ well & bmp plug w/3500 psi_. CIP @ 0315 hrs 10-21-85. Flts held OK prepare to set wellhead. 6490', 46.1°, N36.25, 4785 TVD, 3992 VS, N2723, E2926 7023', 50.4°, N37.25, 5140 TVD, 4385 VS, N3042, E3162 7594', 49.1°, N38.25E, 5507 TVD, 4820 VS, N3389, E3428 7906', 47.8°, N37.25E, 5714 TVD, 5052 VS, N3574, E3571 8810', 43,25°, N39.25E, 6346 TVD, 5693 VS, N4091, E3959 7" @ 8773' 8683' PBD, RR NU & tst tree to 3000 psi. RR @ 0700 hfs, 10/21/85. Arctic packed well w/175 sx PF "C" Old TO Released rig 0700 hrs. Classifications (oil, gas, etc.) Oi'i Producing method Flowin~ New TD Date 8875' TD PB Depth 10/21/85 Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(§) Kuparuk Sands 8683' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity ~ ~, ;-~ A~wable~ ~., i~ ~ Effective date correct~d~:~; ~ ~ ~ A~a~ ka 0~I & P;as Oc, a~. Oomc~'~''- The above is correct II-l~-Z~ For form preparation and distrib~ion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent SUB. SURFACE DIRECTIONAL SURVEY ~UIDANCE ~]ONTINUOU$ [~OOL Company Well Name Fleld/Locatlon ARCO AI,ASKA INCORPORATED , 3F-5 (49' FNL, 70' FWL, S29, T12N, R9E, UM) KUPARUK, NORTH SLOPE, ALASKA Jol~ ~eflrlnCl No~ 71103 Loaae4 BY; LESN IE / SARBER 19-DECEMBER-85 Comguted CUDNEY '£USTOMER LISTINS FOR ~RC3 ALASKA, ZNC. 3F - NgqTH SLOPF.., ALASKA SURV,~Y D~TE: 14-NOV-85 ENGINEER: LESNIE/SARBER TOiL LOCATZDN: T~NS~NTZ6L- .6VER~GED DEVIATION ~NO &ZiMUTH INT:RPSL~TiJN: LiN~R VeRTiC~L $iCT:]N: d~RIZ. 'DIST. PROJ2CT~D ONTO ~ T&RSET AZIMUTH OF NORTH 9 MIN E~ST 3=-5 KJPARUK NO~TH SLOPE,ALaSKA COMPJTATIJ~.~ D~T£: i')-DEC-85 PAGE DATE OF SURVEY: 14-NOV-B5 KELLY BUSHING ELEVATION: ENGINEER: LESNIE/SAREER 93.00 FT '4EASUR~D DEPTH INT~=RPDL~TEZ VA~_OES F-IR "V:N lOO =EEl TRUE SUn-SEA V=RTICAL VERTICAL JEPTt DEPTH' 0.00 0.O0 -93,00 120.00 100.00 7,00 200.00 200.00 107,00 300.00 299.9) 205,99 400,00 399,99 305.9~ 500.00 499.78 405.78 6OO.OO 599.02 506.02 700.00 597.53 604.53 800.30 795,02 702.02 900,00 891,3~ 798,34 lO00,JO 985,:91 392.91 llO0,OO 1078,50 985,60 1200.00 1169.25 1076.25 1300.00 125~,35 1165.35 1400.00 1345,79 1252.79 1500,00 1431.~3 1~3~.03 1600.00 1513.55 1420.55 1700,00 1593,25 1500.25 1800,00 1669.'79 1576,79 1~00,00 17w2.55 20OO,O0 1912.20 1719.20 2100,00 1877,85 1784.55 2200,00 1941.42 1~4~.~2 2300.00 2004.~4 1911.54 2400.00 2067.74 1974.74 2~00.00 2129.d2 2035.82 2600.00 2192.10 2099.10 2700.00 2255.~4 2162.0~ 2800.00 2318.34 2225.34 2900.0J 2380.~6 2257.&6 3000.00 24~3.33 2350.33 3100.00 250~.68 2413.6~ 3200.00 2570.~ 2477.88 3300.00 2635.71 2542.71 3400.00 2701.!5 3500.00 2767.~1 1674.41 3600.00 2834,50 2741.50 3700.00 2902.51 2809.61 3800.00 2'971.54 287~.8~ 3~00.00 3041.5~ 29~8.~ CGUR'SE V=RTICAL DEVIATI,SN .DllMOrm SECTION DEG ~IN 2=.3 MiN FEET 0 0 N 0 0 { 0 21 S ~w 53 'N -3.3'9 0 25 S 10 51 N -1.01 0 30 S ,5 37 W -1.63 1 50 .S 52 2 ~ -1.43 5 10 N ,5~ 3 .~ 3.46 8 25 N 62 12 z 14.92 11 ') N 55 40 £ 30.56 14 ~1 N 59 ~9 ~ 51.17 17 '0 N 70 45 E 75.20 20 34 N 5,5 44 f 104.54 23 36 N 62 53 5 139.75 2~ 2 N 5'9 22 2 180.05 27 55 N 56 2 f 22~.25 30 12 N 53 33 ~ 271.92 32 51 N 51 13 = 3'~3 64 .35 ~9 ~ 49 35 '-- 379.7'9 38 29 Iq 51 57 ~ 439.82 ~1%6 N 52 ,50 ~ 503.35 44 37 IN 5~ 32 - 571.34 47 !8 N ~B 54 ~ 5~2.77 50 14 N 47 53 ~ '717.94 50 35 N 45 WB ~ 795.06 50 ~5 N 46 3 E ~72.34 51 23 N 45 4,5 ~ 950.02 ~1 33 N 47 $ E 1028.32 51 13 N 47 27 : 110~.4~ 50 ~7 N 45 15 2 1183.99 5~ 55 N 49 6 51 29 N 5~ 2 = 133~,85 51 ! N 50 25 f 1415.45 50 21 N 50 24 ~ 1493.39 49 50 N 50 34 :~ 1559.60 4'~ i'~ N 5S 45 ~ 1.545,24 4:3 !33 iq 5C, 51 ~ 1720.35 ~8 5 N 50 *9 ~ 179~.73 ~7 33 N 50 51 ~ !,35~.37 45 36 N 51 2, ~ 45 52 N 51 28 E 2012.57 43 21 ~ 31 41 ~ 2083.49 ME&SURED DEPTH DOSLEG RECTANSULAR COORO SEVERITY NORTH/SOUTH EAST/ OEG/IO0 FEET FEET 0.00 0.00 N 0.0 0,23 0,24 S 0,3 0,15 0.82 S 0.6 0.39 1.52 S 0.7 3.41 2,~0 S 0.3 4,00 1,21 5 6.2 2,00 4,16 N 17,1 ~,07 11,58 N 31,9 2.73 19.92 N 52.9 4.14 28.84 N 78.2 3,25 40,44 N 103,5 3,5~ 56,51 N 142,4 3,2~ 76.73 N 179.4 2.08 101.28 N 217.6 2.82 12,9.22 N 257.3 3,16 161.16 N 298,5 2.98 197.33 N 342.0 4.31 235.94 N 388.~ 3.86 274.48 N 439.9 2.73 317.04 N 493.70 3,2~ 363.75 N '~48.14 2,80 413,50 N 604,~1 0,41 456,$4 N 660,90 0.52 520,39 N 716,36 0.93 574.02 N 772.54 0.25 627.~9 N 829.98 0.68 580.58 N 887.45 0.52 732.70 N 945.08 1,14 783.88 N 1003,16 0.69 834.44 N 1062.61 0,50 884.30 N 1122.65 0.81 933.60 N 1182.35 0.39 982.40 N 1241.48 0.48 1030,59 .N 1300.34 0,67 1078.45 N 1358,97 0,67 1125,76 N 1417.03 0,70 1172.53 N 1474.57 0,96 1218,69 N 1531.~0 0,59 1253,84 N 1587,68 0,19 1308,18 N 1643.$8 INATES HORIZ. DEPARTURE ' AZIMUTH WEST DIS '. FEE..'. L~i-.,~ DEG MIN 0 E 0 1 W 0 0 W 5 W 5 E 2 2 E 6 4. E 17 6 E 33 4 E 56 6 ,= 83 8 E 3 E 7 E 4 E 0 E 6 f 1 E 2 E E E E' E E E E E E 115.87 N 69 34 E 153.23 N 68 21 .. 195.1'9 N 66 51 E 2~0.05 N 65 2 E 237.92 N 63 20 E 33'~.36 N 6i 33 E 39~. ~3 N 60 0 E 454.46 N 58 43 5 51S,5Z N 53 2 E 536,73 ~ 57 17 E 657 732 80~ 885 962 1040 1118 1195 1273 1351 1429 1506 158.3 1659 1734 1809 1383 1957 2029 2100 · 11 N 51 46 E · 50 N 51 42 E · 16 N 51 38 E .28 N 51 35 f .89 N 51 33 E .78 N 51 32 E · 93 N 31 30 E ,14 N 51 29 E .30 N 51 28 E ,72 N 31 29 E COMo~jTATIDN DAT.=_: ! PAGE 2 ARCO ALACK4, INC. 3~-5 KURARUK NSRTH SLCPE,AL~SKA D~TE OF SURVEY: 14-N]V-85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE/S&RSER 93.00 F INTERPOLAT:3 VALJES FSR =V~N 100 FE:T OF TRU£ SUE-SEA MEASURE3 VERTICAL V;RTI'AL 2EPTH OEPTH DEPTH CS]RS= VERTIC&L DSGLEG DEVI4TZ]N AZIMUT~ S=CTION SEVERITY ,DEG MIN D:$ MIN FEET OEO/lO0 FEE 4000.00 3112.38 3019.38 4100.00 3133.14 3090.14 4200.00 3252.68 3159.68 4330.00 3320.5'3 3227.69 4500.00 3358.~7 3295.67 ~SOO.O0 3456.35 33,53.35 4600.00 3523.16 3430.16 ~700.00 35~8.83 3495.83 4800.00 3654.85 35.51.8~ 4900.00 3721.~0 3628.40 44 53 ~'~ 51 ~3 E 45 13 N 51 31 5 46 3; N 3C 19 = 47 ~1 N 48 23 : 47 ~ N 45 43 : 47 41 N 43 58 E 48 ~2 N ~3 30 = 4~ 27 N 42 ~1 ~ ~ .~ N ~2 37 ~ 5000.00 3788.55 3595.~5 5100.00 3855.91 5200.00 3:923.56 3830.55 5300.00 39}1.26 3898.~8 5400.00 4055.34 3'965.34 5500.00 4124.29 4031.29 5600.00 5189.~1 409~.31 5700.00 ~254.56 ~151.50 5~00.00 4319.96 ~226.96 5900.00 4335.54 ~292.64 6000.00 4451.24 ~35~.94 6100.00 '518.53 ~23.63 6200.00 4535.95 ~49'2.95 6300.00 4653.~5 ~560.:35 6~00.00 ~722.J0 ~529.00 6500.00 4791.03 ~698.03 6500.00 4~59.67 ~766.67 6700.00 4927.g7 4834.27 6800.00 4993.83 ~900.83 6900.00 5059.~0 ~96~.~0 48 20 N 37 37 E 47 5B N 37 31 E ~7 23 N 37 1~ ~ 47 9 N 37 14 .~ 40 ~2 N 35 57 E 46 18 N 36 39 E 57 8 N 35 55 ~ 45 2 N 26 2 E 48 26 N 3~ 0 ~ 4~ 41 N 36 2 ~ 7000.00 5124.24 5031.94 7100.00 5188..58 5095..5~ 7200.00 5252.26 515~.26 7300.00 5315.99 3222.99 7400,.00 5380.10 5287.10 75~0.00 5444.~1 ~351.61 7600.00 5509.7~ 5416.74 7700.00 3575.52 5482.42 7~00.00 5641.57 354'~.57 7~00.00 3708.~0 5515.40 2133.75 0.21 1332. 2223.80 1.40 1395. 2295.14 1.72 1441. 2369.13 2.06 1488. 24~1.37 1.03 153~. 2514.9~ 0.95 1591. 25B9.3~ 0.85 1544. 266~.78 0.$~ 1699. 2739.85 0.44 1754. 2~1~.49 3.43 1809. 2~88.65 0.39 1364. 2962.44 0.31 1918, 3036.04 0.23 1973. 3109.58 0.34 202~. 3183.65 0.70 2083. 3236.66 2.01 2140, 333~.30 0.56 2200. 3409.6~ 0.32. 2259. 3484.8'9 0.35 2319. 3559.82 0.92 2378. 3634.21 0.50 2438, 3708.23 0.61 2497. 3781.67 0.5~ 2356. 3834.5~ 0.32 261~. 3927.19 0.94 2672. 399~.95 0,47 2730. ~070.99 0.83 2789. ~143.91 1.49 2849. &217.80 1.13 21909- g292.09 1.07 29?0. ~367.43 0.97 3030. ~44~.01 0.38 3091. ~520.6~ 0.43 3153. ~597.20 0.42 3214. ~673.38 0.30 3273. 5749.19 0.41 3336. ¢~24.50 0,42 3397. 43~'3.28 1.03 3~57. 4973.55 0.66 3517. 5047.20 0.71 3578. ME4SURED DEPTH RECTANGIJLAR COOR NORTH/SOUTH EAS~ T FEE 08 N 1.699. 89 N 1754. 13 N 1810. 713 N 1866. 89 N 1919. 05 N 1971. ~5 N 2023. 75 N 2074. 66 N 2126. 51 N 2176. 1~ N 2226'. 69 N 2276. 29 N 2325. 03 N 2375. 56 N 2424, 92 N 2473. 19 N 2520. 69 N 2567. 36 N 2613. 99 N 2660. 26 N 2705. 30 N 2751. 03 N 2796. 45 N 2840. 79 N 2884. 76 N 2928. 34 N 2971. 04 N 3014. 38 N 3058. 16 N 3102. 90 N 3148. 81 N 3195. 01 N 3242. 29 N 32B8. 46 N 3335. 48 N 3381. 03 N 3427. ~.5 N 3472. 95 N 3516. 15 N 3560. DINATES HORIZ. DEP4RTURE /WEST D~.~..;';,: AZIMUTH T F ',!i" DEG HIN 32 E 2171.'59 77 E 2242.26 59 E 2314'11 29 E 2387,37 84 E 2460.48 78 E 2533.64 17 ~ 2507.44 88 E 2682.21 08 E 2756.63 7~ E 2830.64 88 E 290~.17 57 E 2977.35 09 E 3050.34 28 E 3123.28 32 E 3196.71 02 E 3270.99 55 E 3345.75 48 E 3420.26 99 E 3494.62 13 E 3568.74 58 E 3542.37 33 E 3715.69 27 E 37~3.46 72 E 3860.71 39 E 3932.74 20 E 4003.92 27 E 4073.40 47 E 41~7.78 wOE 4221.17 45 E 4295.00 04 E 4369.95 22 E 4445.21 25 E 4522.58 98 f 4598.~1 34 E 46?4.73 31 E 4750.30 05 E 4825.40 17 5 4900.00 ~+8 E 4974.09 19 E 5047.59 N 51 29 E N 51 29 E N 51 28 E N 51 25 E N 31 17 E N 50 5 N 50 40 E' N 50 28 E N 50 I5 E N 50 3;2 N 49 52 N ~9 30 E N 49 19 E .~ 49 7 E N 48 52 E N 48 38 E N 48 25 E N 48 11 E N 47 5~ E N 47 46 E ~ 47 34 E N 47 22 E N ~7 1,1(<_~ N 46 59( N 46 48 .. N 46 36 E N 45 2,5 E N 46 14. E N 45 5 E N 45 56 E N 45 47 E N 45 39 E N 45 31 E N 45 22 E N 45 15 E N 45 7 E N 44 59 E N 44 51E 3:-$ KUP~RUK NORTH SLOPE,~LASK~ TRUW '4EASURED V=RTIC~L 3EPTH G6PTM $000.05 57?5.97 9130.00 3844.~0 8200.0~ 5913.34 8300.09 5~2.77 8~00.00 5052.51 8500.00 5122.5'6 8630.00 81)3.33 5700.03 8204.37 8~00.00 5336.38 8575.00 6390.01 INT=RPOL&T=B~ _ VA~ U:~_ r,JR :VEN 100 FEET SJE-SEA C]URS~ V:RTiCML DDG EG VERTICAL DEVIMTIPN 4ZI,,~JTH SECTIDN S~VERIT'! DEPTH DEG MiN O:G MIN =EET 3~G/lO0 55~2.97 47 i1 !q 3: 52 : 5120.14 '$.75 · ~" : 5192.32 0.25 5751 40 46 37 N :~ 55 = 5820.34 46 Z2 N 35 4~ - 5264.01 O.iB 58:~9.77 45 46 N 35 13 == _5B35'16 0.2~ 595~.51 45 40 "~ ,35 3 : z405.95 0.37 ~103.33 44 16 N 3~ 43 = ~546.15 4.06 bI'~I.B7 44 20 q 35 57 ~. 5515.32 O.Og o243.3.B 44 20 N B5 57 ~ 5~4.51 0.00 6297.01 44 20 N 35 57 ~ 5736.40 0.00 M':ASUR NO~TH FE 3537 3596 3755 3814 3872 3931 39&9 4045 4102 4144 PAGE DATE DF SURVEY: 14-NOV-S5 KELLY BUSHING ELEVATION: ENGINEER: LESNIE/SARSER 93.00 F 50 DEPTH /S :T UL~R CDORDINATES HDRIZ. SUT~ EAST/WEST FEET ,. 7 N ,3603.40 E 51Z06~! N 1 N.B845.Z1 E 5192;49 -'N ~ N 3588.69 E 5264.!! 8 N ]730.46 E 53~5.20 N 6 N 37Tl.T5 E 5405.96 N 7 N 3812.59 E 5476.38 N 9 N 3853.1'9 E 5546.17 N 7 N ~894.21 E 5615.37 N $ N 3'935.25 E 5584.60 N 0 N 3966.03 E 5736.54 · DEPARTURE AZIMUTH DES MIN ~4 43 E 44 36 E 44 29 E 44 21 E ~3 5~ E 43 48 E ~3 44 E ARCO ALASKA, INC. 3F-5 KUPARUK NDRTH CLCPE~ALASKA CO'qPUT'~TIDN DATE: 1 ~-D,=C-95 PAGE CATE OF SURVEY: 14-NJV-$5 KELLY 8USH!NG ELEVATION: ENGINEER: LESNIE/SARBER 93.00 F' iNT~POLAT~o VA~ .,-'- :Oq ..: _ -_ , - -~-- . 'V~N lOCO ~FET TRUE SJS-S:A MEASURED VERTICAL VERTICAL DfPTM D~PT~ DfPTH O.OO O.OO -93.00 1300.03 985.)I 892.91 200J.O0 1512.20 1719.20 3000.00 2~43.38 2350.35 4000,30 3112.33 3019.38 5000,03 37~$,~5 3695,45 5000,00 4451,94 g35~,94 7000,00 512&,)4 5031,9~ 5000.00 5'775.97 5682.97 8~75.00 3390,31 5297.01 C2URSf OEViATi~N~ A~iMUT~~ DEG MIN D=3 MIN 0 0 N 0 0 ZO 34' N 6~ &~ 47 13 N ~ 5~ 51 I N 50 25 44 53 N 51 43 47 ~2 N ~2 27 ~8 20 N 27 37 50 15 N 37 38 47 11 N 35 52 44 ZO N 35 57 V:RT!SAL DJGLEG SECTION SFVERITY ~E~T DEG/IO0 0 30 0 OD ID4.6~ 3.25 5~2.77 3.26 14i5,45 0.50 2!55,75 0.21 2~'38.65 0,39 3534.21 0,50 ~367.43 0.97 5120,14 .J,76 5736.40 0.00 ME&SU RECTA NORTm FE 0 4O 363 884 1352 1564 2438 303,3 3537 RED DEPT NCULAR CODROINATES H]RIZ. /SOUTH EAST/WEST DICT- ET FEET FEET!,'/. .. .oo N o.oo E .o.00 .44 N. 108.58 E 1'I5.87 .75 N 548.1~ E 657'85 · 3O N [[2Z.:5~ ~ [~29.[[ · [~ N Z226.88 E 2904.[7 .26 N 2705.~8 a 3542.37 · 90 N 3148.04 E 4369.95 · BT N 3503.~0 E 5120.41 .TD N 3966.03 E 573,5.5~ DEPARTURE AZIMUTH DE& MIN 0 0 E 69 34 E 56 25 E 51 46 E 51 29 E 50 3~ 47 N 45 5E 44 43 E N 43 44 E 2'~',I~DT&TI'DN 2~T'=: 1~-C=C-85 ARCO 4L4S.<A, Z~C. 3=-5 KJPARUK NSRTH SLGP._;, ~L ~S:tA DATE 3F SdRVEY: 14-NDV-85 KELLY BUSHING ELsV&TZON: ENGIN:ER: LESNZE/SAqBER 93.00 F INTERP3LATE3 VALJiS 23,? ;VEN 100 FEET 3F 'TRU' SuG-SEA MEASURED VERTIC&L V~TISAL DEPTH DEPTd DEPTH 0.00 0.00 -93.00 93.00 93.00 0.00 193.00 193.00 100.00 293.01 293.00 ~00.00 393.02 3:93.00 303.00 493.1~ 493.00 ~O0.O0 593.91 593.00 500.00 595.29 593.00 6.00.00 797.91 793.00 700.00 901.73 ~93.00 800.00 1007.57 993.00 900.00 1115.76 1093.00 lOO0.O0 1226.59 1193.00 llO0.O0 1339.37 1293.00 1200.00 1~55.05 1393.00 1303.00 1574.77 1493.00 1403.00 1599.57 1593.00 1500.00 1831.37 1593.00 1800.00 1971.93 1793.00 1703.00 2123.78 1893.00 1800.00 2281.30 1993.00 1'900.00 2440.61 20'93.00 2601.44 2193.00 2100.00 275'9.93 22'93.00 2200.00 2919.51 2393.00 2300.00 3078.49 2~93.00 2400.00 3234.25 2593.00 2500.00 3387.51 2693.00 2603.00 3538.2% £793..30 2700.00 3685.99 2893.00 3830.34 2993.00 3972.66 3093.00 3000.00 4114..02 3193.00 3100.00 4259.08 3293.00 3200.00 4406.37 3393.~0 3303.00 4554.56 34)3.00 3400,00 ~706.35 35'93.00 3500.03 4~57.41 3693.30 3500.00 5006.75 3793.00 3700.09 5154.32 3393.00 3800.00 C'2JqS~ VSqTICAL DOGLEG DEVI4T~.~'~ A:I~IUTd' S~CTIgN SEVERITY DEG MIN DES MIN FEET DES/lDO 0 O N :3 3 E 0.00 0.00 0 21 S ~.5 51 ~ -0.35 9.21 0 24 S 11 45 ~ -0.96 0.16 0 30 S ~ 12 W -1.53 0.32 1 39 S 7~ 3~ :_ -1.58 3.13 4 55 N 70 9 ~ ')i B 90 ~ 1~ N 62 12 : 1~.08 2.20 10 58 N ~5 22 E 29.73 4.08 : 30.70 2.72 14 28 N 59 46 : 17 5' N 70 44 ~ 75.66 ~.10 20 4.5 N .56 20 = 107.08 3.30 2~ 3 N 62 25 ~ 145.03 3.25 .~6 34 N 57 39 = 191 43 2 90 28 44 N 55 9 : 242.57 2.57 ~1 ~1 N 52 Ii3 2 299.,~9 2.95 ~5 5 N 49 44 ~ 365.22 36 28 N 51 57 5 43~.61 4.33 42 ~8 N 52 2 = 524.24 3.60 46 Za N 4,:~ 59 2 522 37 3 .... ~ · ,,, ' 50 2~ N 47 17 = 736.24 50 ~l N 45 35 : ,~57.~8 0.47 51 38 N 45 59 ~ 981.79 0.53 51 13 N 47 23 ~ 1!07.5b 0.70 50 ~3 N 45 40 E 1230.22 0.92 51 28 N 50 11 ~ 1:354.05 0.61 50 30 N 50 25 ~ 1476.89 ,3.71 49 .%0 N 50 35 ~ 1595.59 40 58 N 50 50 ~ 1711.08 47 56 N 50 54 ~ 1~22.95 0.35 ..6 43 N 5i O E 1930.9~ 0.77 45 ~1 N 51 35 E 2034.25 0.75 ~5 0 N !51 43 E 2134.63 0,.90 45 23 N 51 23 ~ 2233.68 1.70 4Z 15 N 49 18 E 2338.11 1.60 47 9 N 45 38 ~ 2445.04 1.0~ 4~ ,5 N 43 40 E 2555.39 1.55 ~ 53 N 43 8 '~ 2659.57 0.65 48 17 N 42 42 E 27:~2.77 0.62 47 ~1 N ~'2 27 :: 2393.63 0.38 47 ~4 N 42 7 ~ 3002.79 0.40 SUB-SEA RESTAN NORTH/ O. D. O. 1. 2. 1. 3. 11. 19. 29. 41. 59. 82° 111· 1~6. 187. 235. 287. 350. 595. 5~!. 763. 844. 923. 999. 1072. 1143. 1212. 1277. 1340. 1402. 1468. 1542, 1620. 1703. 1786. 1867. 1948. DEPTH GULAR COORDINATES H'ORIZ. SOUTH EAgT/WEST DIST. T FEET FEET O0 N 0.00 E 0.00 21 S. 0.25 W 0.35 77 S 0.59 N 0.97 56 S 0.74 W 1.72 36 S 0.15 E 2.37 43 S 5.55 E 5.82 74 q 16.34 E 16.76 20 N 31.14 E 33.10 74 N 52.45 E 56.05 O1 N 78.74 E 83.92 48 N 111.02 E 113.51 47 N 143.12 E 159.61 85 N 139.50 E 106.82 84 N 233.07 E 25~.51 31 N 279.85 ~ 315.79 84 N 330.96 ~ 380.46 82 N 38~.25 E ~54.25 35 N 456.65 E 539.54 29 N 532.'?1 E 637.56 84 N 618.36 E 750.81 34 N 705.:90 E 871.10 76 N 795.85 E 994.14 33 N 888.28 E 1119.49 46 N 979.77 E 1242.11 25 N 1074.33 E 1366.36 02 N 1169.55 E 1489.91 O1 N 1281.70 E 1509.31 55 N 1351.73 ~ 1725.56 69 N 1439.07 E 1838.19 25 N 1523.%8 E 1946.95 38 N 1604.72 E 2051.05 15 N 1684.18 E 2152.31 10 N 1762.55 E 2252.23 99 N 1843.59 E 2357.27 15 N 1923.18 E 2465.13 24 N 1999.72 E 2573.72 24 N 2078.15 E 2586.95 17 N 2155.24 E 2799.19 87 N 2230.26 E 2909.12 58 N 2303.80 E 3017.36 DEPARTURE AZIMUTH DES MIN 0 0 =_ S 53 4 ~ 37 26 W 25 28 N 3 59 E 754( '- 77 ~ 70 13 E 69 22 E 6'9 46 E 69 30 E N 68 7 E 66 23 E 64 21 E 62 23 E 60 24 : 57 49 E 56 40 E 55 25 E N 50 8 E N 53 10 E q 52 30 E N 52 4 E N 51 50. E N 51 4~ N 51 3 . ~ 51 34 5 ~ 51 31 E N 51 29 E N 51 28 E ~1 51 29 E ~ 51 29 E N 51 27 E N 51 16 E N 30 59 E N 30 39 E N 50 20 E N 50 3 E N 49 46 E ~C3 ALASiIA, I~C. KJPARJK N3RTH SLOPE,ALASKA CDMPUTATiCN D~T-: 19-D £C-8 5 DATE OF SURVEY: 14-N3V-85 KELLY BUSHING ELEVATIgN: EN$IN;ER: LESNIE/SA~BER 93.00 J !NTERPOLITEO VALJES mOR EVeN lO0 FrET OF TRUE SUB-SE4 SURE2 VERTICAL VERTICAL EPTH DEPTH 9~PTH 5302 5452 5605 5758 5911 ~051 6357 5502 6569 9~ 50 06 53 20 26 77 25 70 14 57 99 39 75 67 69 71 72 7~ 75 77 81 85 8~ C3URSE VERTZC.~L 30GLEG DEVi&TI]N AZiMUTh SECTION S~VERITY DEG qIN J~G MIN FEET DEG/iO0 .57 3993.00 3900.00 .35 &093.00 ~OOO.O0 .68 4193.0C .82 4293.~0 ~200.00 .11 ~393.00 4300.00 .64 44'93.00 4400.00 .41 ~593.00 4500.00 .55 ~693.00 4500.00 .8~ ~793.00 ~700.00 ,14 4893,00 ~00,00 47 21 N ~I 49 E 3111.47 0.43 48 ~2 N 40 24 E 3222.84 1.26 49 2; N 3S 22 = 3338.50 0.61 49 9 N '37 33 ~ 3453.96 0.43 45 35 N 37 ~1 : 3.563.09 0.55 48 8 N 37 34 : 3679.88 0.23 47 20 N 97 18 = 37~9.27 0.51 47 1 N 27 7 = 33)6.42 0.71 46 18 N 35 39 = &000.99 0.50 47 24 N 35 51 = 4106.72 0.67 · 75 ~993.00 ~900.00 .41 5093.00 5003.00 .77 5193.00 5100.00 ,97 5293.00 5200,00 · 0~ 5393.00 5300.00 · 33 5493.00 5~OO.O0 .62 5593.00 fSO0.O0 .05 5593.30 5500.00 .00 5793.00 5700.00 .52 5893.00 5~00.00 4'{ 26 N 35 J ~ ~216,87 1,08 ~9 23 N 3.5 53 5 ~329.76 2.65 50 25 N 37 3~ ': 4449.19 0.40 50 21 N 37 lB : ~569.66 0.23 49 55 N 37 1 = ~638.60 0.29 4) 14 N 37 3 E 4.~05.25 0.30 43 38 N 36 19 ~ 4919.08 0.53 ~7 J4 N ~5 55 : 5030.34 0.47 46 59 ~ ~5 55 ~ 5138.26 0.'7~ 45 iB N 35 5~ ~ 5242.89 0.62 · 65 5993.00 5900.00 .84 6093.00 5000.00 .54 6193.00 ~!00.00 .34 6293.00 5200,30 · OO $390.91 6297.01 ~+5 ~7 N 35 13 E 5345,53 0.31 45 29 N 3~ 31 E 5446,72 0,17 ~4 16 N 3.5 ~2 E 5545.83 ~.89 44 20 N 35 57 E 5642,54 0.00 ~4 20 N 35 57 E 5736.40 O.O0 SUB-SE4 DEPTH RECTANGULAR COORDINATES H N3RTH/SOUTH EAS.T/W=ST FE~T FEET FE 2029.44 N 2376.53 E 2113.43 N .2~49.91 E 2203.58 N 2523.24 E 229~.77 N 2594.91 E 2385.58 N 2665.22 E 2~74.68 N 2733.93 E 2562.11 N 2800.90 E 2648.05 N 2866.21 E 2732.~2 N 2929.43 E 2818,62 N 2992,41 E 2908.52 N 3057.85 E 3000.76 N 3125.00 E 3095.94 N 3198.41 E 3192,22 N 3272.18 E 3287,70 N 3344.58 E 3381,55 N 3415.37 E 3473.55 N 3484.01 E 3564.37 N 3550.20 E 3652.70 N 3614.13 E 373~.27 N 3676.21 E ORIZ. DEPARTURE ST- AZIMUTH E'T .' OEG MIN , 3125,15 N 49 30 3235,53 N 49 13 3349.99 N 48 52 3464.03 N 48 30 3795.98 N 47 3 2~ 3902.22 N 47 15 4005.95 N 45 59 4110.86 N 46 42 4220 4332 4451 4571 4589 4806 4919 5030 5135 5243 .25 .46 .37 .37 .90 .21 .75 .77 .50 .01 382,2.7,5 N 3'736.52 E 5345.57 N 44 20 E 3'90,5.62 N 3795.,0 !~ 5446.72 N ~ 10 E 3988.83 N 3553.00 E 5545.~5 N 4~, 0 E ~067.94 N 3910.36 E 5642.50 N 43 52 E 4144.70 N 3966.03 E 5735.54 N 43 44 .... E ARCO ~LASKA, !NC. 3F-5 K UPARU'(, N3RTH SLOPE,ALASKA TOP 3ASE TOP 6,~S E PBTD TD NUPARUK C KUPAqUK C EUPARUK ~ KUPARUK A C OM P UT &T l 3N INTERPOLATED VALUES FOR MEASJREC aELOW K5 8Z00.03 8232.00 3337.00 8558.00 8583.00 8875.00 D~T.--': 19-3"C-B5 CrtJSEN H3RiZ3NS 32IGiN: TVD FR3M K5 5913.34 5970.21 5043.~3 6170.55 5252.71 5390.01 SUB-SEA 5a20.34 5877.21 5950.43 5077.58 5159.71 6297.D1 P~GE DATE OF SURVEY: l~-NDV-85 KELLY BUSHING ELEVATION: ENGINEER: LESNIE/S~BER T 93.00 FNL,70' SURF FWL,SEC R~CTANG NORTH/ 3755. 3803. 3855. 3'970. 4036. 41~4. ACE LOCATION ATI 29,T12N,RgE,UM ULAR COORDINATES SOUT~ EAST/WEST 58 N 3688.59 6~ N 3723.02 15 N 3766.~0 74 N 3840.20 06 N 3887.23 70 N 3955.03 E E E C3MPUTATi3N gAT:: 19-DEC-85 ARS9 4LASAA, I'~C. 3F-3 KUP~RUK NgRTH SLDPE,ALASK& gATE gF SURVEY: 14-NDV-$5 KELLY 5USHING E'LEVATIDN: ENGINEER: L:SNIE/SARBER 93.00 FT M,~RK;R T'DP KUPADUK 3 B.a,S: KUDAqU,q C TCP KUP~,RUr< A 6AS=. F,U~ARUK ~' DSTD TD qE&SdRES DEPTH B200.O0 ~3Z 82. O0 -33B7. O0 · 86.33 · 00 8875.0O ORIGIN: ~9' FNL,70' TVD =ROM K5 SUB-SEA 5913.34 5520.34 5970.21 5877.21 50~3.~3 5950.~3 6170.53 5077.58 6252.71 615~.71 5390.01 6297.01 FWL, SURF SEC TANG RTH/ 755. 803. 8 ,$ 5. 970. 036. 1~4. ACE LOCATION 29,T'I~N.,RgE,UM UL&R COORDINATES SDUT5 EAST/WEST 58 N 368~.69 6% N 3723.02 15 N 3765.~0 7% N 3840.20 05 N 3887.Z3 ?0 N 3966.03 ~IN&L MEAS'JR~O DEPTH WELL LOCATi]N ~T TD: TRUE SJ~,,-$ =A V 7_-. R Ti CAL VER'TZCAL DEP'TH 3EOTH 8875.00 .53'~0.01 5297.01 HORIZONTAL DEPARTURE 'DIS T,4 NC E & ZI MUTH F:~T DEG MIN 5736.54 N 43 4~ 6 SCHLUMBERGER O I RF~CT I ONAL SURVEY COMPANY ARCO ALASKA I NC B-2 WELL 3F-S FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE O000?ll03 224. WELL NAME: 3F-5 SURFACE LOCATION: 49' FNL, 70' FWL, S29, T12N, R9E, UM 10120 L~)gO ~000 4000 ~000 PROJECTION ON VERTICAL PLANE 44. - 224. SCALEO IN VERTICAl- OEPTI-~ HORIZ SCALE = l/lO00 IN/FT VERTICAL PROJECTION 6000 ?000 44. WELL NAME: 3F-5 SURFACE LOCATION: 49' FNL, 70' FWL, S29, T12N, R9E, UM NI31~'I'H ~DOD I~EF 130130'71 ] Oq 5000 4OOO 9OOO 2OOO lO00 -lO00 5~IJ3'H -2000 -2000 HORIZONTAL PROJECTION SCRLE = ~/1000 IN/FT -1000 0 I000 2000 9000 4000 SO00 6000 Suggested form to be inserted in each "Active" well folder to cheek for timely compliance with our regulations. · . Reports and Materials to be received by: Date '-Required Date Received" Remarks Completion Report Well History . Samples Cbr~ 'Description . Registered Survey Plat _~ ~ Inclination Survey Directional Survei:~ Drill Stem Test Reports . . , . ARCO Alaska, Inc. Post Office [...... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-07-~5 TKANSt~ITTAL NO: 5431 ~TUt{N TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 -~J~NSMITTED HEREWITH APE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ~CEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ~EN HQLE LIS TAPES PLUS LISTING/ SCHL/ ONE COPY OF EACH ~3'-8 / 10-16-85 RUN ~J"- 7~/' 10-09-85 RUN 3F-5~'' 10-20-85 RUN 3~-4 ?'"' 10-13-85 RUN ~C- 16 ~'~ 09-29-85 RUN 3 _C.- 15-"" 10- 08- 85 RUN ~C- 14 ----'~ 10-15- 85 RUN 5~-~ 10-24-85 RUN SA- 6 ~,'"' !0-18-85 RUN }~-5~'''' 10-11-85 RUN 1748 O- 7 58 5. 0~.d ~ 7 ~-~-~_e~- / ?44~- ~d~-~ 1994 ] 0-8647.0~ ~z/~.--.5-~'/ue/?-/??~-~z7 3030.0- 6900. ~oaT~-s-oPe~-3~3o - ~?~o 3692.5-6851.5~d~7 ~-3-~e~ - 3~?~_~/ 3816 4050 1948 3410 3952 0-7617. 5- 8683.5~ CEIPT ACKNO%~LEDGED: CURRIER~ EVRON ~ M DISTKIBUTION: D}{ILLING W. PASHER L. JOHNSTON EXXON P~OBIL PHILLIPS OIL NSK CLERK J. .P~ATPIME LL ARCO Ataska. Inc. is a Subs~o~ary c)f AllanticRichf~eldCompany ARCO Alaska, Inc. Post Office B,,.~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the October monthly reports for the following wells: 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C--14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures RECEIVED t?ov FJ85 Alaska Oil & Gas Cons. Cornm!ssion Anchora9s ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA C~.~AN D GAS CONSERVATION COI~_.~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling we~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-242 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21460 4. Location of Well atsurface ~8~ FNL, 70' FWL, Sec.29, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25632 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of October ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1600 hfs, 10/14/85. Drilled 12-1/4" hole to 3980'. Ran, cmtd & tstd 9-5/8" csg. Drilled 8-1/2" hole to 8875'TD (10/19/85). Ran logs. Ran, cmtd & tstd 7" csg. PBTD = 8683'. Secured well & RR ~ 0700 hrs, 10/21/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 115'. Conductor installation report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3974'. Cmtd w/1060 sx PF "E" & 425 sx PF "~'. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8773'. Cmtd w/200 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/8880' - 3974' FDC/CNL f/8880' - 7500' Cal f/8880' - 6500' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (~ ~./ .'),~~2L~ TITLE Associate Engineer DATE NOTE--Report ~this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TEMP2/MR25 Submit in duplicate MEMORANDUM State-of Alaska TO: THRU: ALASKA OIL AND GAS CONSERVATION COt~ISSION C. tterton DATE: October 22, 1985 Chai~~ /~'~" ,~-~'--';~ ' '"' F,LE NO: D. BDF. 108 Lonnie C. Smith" Commissioner FROM: Bobby' D. Foster{ ~ ~ ' SUBJECT: Petroleum Inspector TELEPHONE NO: BOPE Test · ~ ARCO-K. R..t~t, - 3F- 5 Permit #85-242 Kuparuk River Pool Wednesday, October 16, 1985 w'a's concluded at 11 ~30 pm. there were no failures. The BOPE Test began at 10:30 pm and As the attached BOPE test report shows, In summary, I witnessed the BOPE test on ;~RCO's 3F-5. Attachment 02-O01AfRev. 10/79) O&G #4 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Inspector Operator Date Location: Sec~ T/~R ~ M U ~/~Casing Set @ Location, General_~~_~Well Sig~)~ ACO~ATOR SYST~ ' General Housekeeping ~ Rig ~ Full Charge PreSsure Reserve Pit M~d Systems Visual Audio Trip Tank Pit Gauge Flow Monitor ~-~ Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Pressure After Closure /~'2~O psig Pump incr. clos..pres. 200 psig Full Charge Pressure Attained: Controls: Master ~_,~ l min~ I sec, min ~7sec. Remote~,,~ Blinds switch cover~~ Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressur~ Ball Type / Test Pressure Inside BOP_ / Test Pressure Choke Manifold L~Test Pressure No. Valves No. flanges Adjustable Chokes / Hydrauically operated choke Test Results: Failures Test Time ) hrs. Repair or Replacement of failed equipment to be made within day~ and Inspector/ Commission office notified. Remarks: ~,~ ~~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspec ARCO Alaska. In~.. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-05 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 DATE 09-15-86 TRANSMITTAL ~ 5761 Please acknowledge receipt and One * of each Receipt Acknowledged: Vault*films . A]as~ Oil & Gas Cons. Commission Anchorage Date: ~ NSK Files*bl ARCO Alalka. Inc. ~s a Subs,diary of AllanticRichfteldComPan¥ - ARCO Alaska, Inc Post Office~.,..~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985' Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-~uilt Location Plat - 3F Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED OCT 2 5 Alaska 0JJ & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AS DUI CONDUCTORS i-t) IN SEGTION Z9 · X= 508,662.35 LONG=149°55' 46.5 89 FNL, 162 FWL, 52 O.G., 56.1 PAD. 2- ¥=5,985,745.10 LAT=70°22 , 20. 1856,, X= 508,638.99 LONG=149°55' 47.233,, 78 FNL, 139 FWL, 52 O.G., 56.3 PAD 3- Y=5,985,754.79 LAT=?OO22 ' 20. 2812" ×= 508,616.29 LONG=149°55 ' 47. 896,! 69'FNL, 116 FWL, 52 O.G. 56.3 PAD 4- Y=5,985,764.77 LAT=70°22' 20. 3796,, · ' X= 508,593.66 LONG=149°55'48.558" L 59 FNL, 93 FWL,_ 52 O.G. 56.2 PAD 5- Y=5,985,774.87 LAT=70°22' 20. 4792'' X= 508,570,43 LONG=149°55 ' 49. 237 ~r 49 FNL, 70 FWL, 52 O'.G. 56.2 PAD 6- Y=5,985,784.84 LAT=?O°22"20.5776'' L X= 508,547'58 LONG=i49°55'49-906" . NOTES 39 FNL, 48 FWL, 52 O.G. 56.1 PAD I. COORDINATES ARE A.S.R, ZONE4. 7- Y=5,985,794.93 LAT=70°22'20.6771,, 2. SECTION LINE DISTANCES ARE TRUE. X= 508,524.44 LONG.149°55'50.582,, 28 FNL, 24 FWL, 52 0.G.,55.9 PAD $. HORIZONTAL AND VERTICAL POSITIONS ARE BASED 8- Y=5,985,804.81 LAT=70°22' 20. 7744,, ON MONUMENTS SF-MIDDLE & SF-EAET PER L.i~D&ASSOC. X= 508,501.41 LONG=149°55'51.256'' 4.0. G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 O.G. ,55.9 PAD CED-RIXX-30;~O RE~.~V,~4~_~. AS ~UII~T CONDUCTORS 9-16 IN SECTIqN 19 4~,r~f,,OF a~ ~ 9- Y=5,985,834.85 LAT=70o22'21.0708'' m_ · ...... ..~. · ~z~.." A ' '. ~.-~ - X= 508,432.81 LONG=149°55' 53.26~" ~:~. --~-~ '.-~ - 12 FSL, 67 FEL, 51.20.G. 56 1 PAD ,~ .C"J .' ,,! r~ TH'~ '."J7 ~ ' ' ~w.'. '~'~"~ · ,~ 10- Y=5,985,84~.70 LAT=70°22'21.16 - 78" ~oo·&4e.....·,~,..~...: .. · ~ X= . 508,410.73 LONG=149°55 ' 53 · 908" '. ~~~ 21' FSL, 89 FEL, 51.20.G., 56.2 PAD ~ ~2 '- .ow*--~. ,~-"~'" : .~ .41' . ~,.~% : ~ . 11- Y=5,985,855.14 LAT=70°22'21.2708'' ?~ % ~eo.s ..' ~ ~ - X= 508,387.41 LONG=149°55'54.590'' V~f~L]''....·,~ ---'- ~''''''~4' 32 FSL, 112 FEL, 51.20.'G., 56.3 PAD ' ' '~2"~:~11~ ~.~ ' 12-Y=5,985,865.19 LAT=70°22 ' 21.3699'' X= 508,364.05 LONG=149°55' 55. 273'' I HEREBY'CERTIFY THAT I AM PROPERLY II~I~TERED 42 FSL, 136 FEL, 51 · 1 O.G. 56.2 PAD ANO LICENSED TO PRACTICE LAND ~M~IIVEYIN4~'IN 13- Y=5,985,874.97 LAT=70°22'21.4663'' THE.STATE OF ALASKA, THAT THI~ PLAT RIPtEIENT8 X= 508,341.36 LONG=149°55' 55.937'' A ~URVEY MADE UND. ER MY DIRECTI&IPIRVlIIOll AND. 52 FSL, 158 FEL,51.1 O.G., 56.3 PAD THAT CONDUCTOR~ I TI~IM E AIIE.CORRICT A8 OF 14- Y=5 985 885 08 LAT=70°22'21 5660" SEPTEMIER 19,19~ AMO.COIIN~TQ4tl · 11~1U 1· ' ' ' ' ARE CORRECT A8 OF~EPTE~ER ~·,1~1. X=. 508,318.27 LONG=149°55'56.612'' 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD ,gSTU,~% DS. SB~,~~_~~ ~~. ' 15-Y:5,985,894.96 LAT:70°22'21.6635'' ..... - 72 FSL, 204 FEL, 51 O.G. 56.1 PAD D'S3F"'/ ~ /. ,"~c'.~ne,~' 16- Y=5,985,904.95 LAT=70°22'21.7619'' ~O 29~ 27~ ~ ~ P ~0~ X= 508,272.74 LONG=149°55' 57. 943'' 6 ~/~)I1~)2~ } ~ !1 I. ii ~ ' CONDUCTOR AS-BUILT ,, 1,,/r :.:: LOCATIONI ' CONDUCTORS I THRU 8 LOCATED IN PROTRACTEDIII Ill: ~' :~i ' ' SEC. 29, T. I2 N.,R.9E., U. MER. ]lSll[ Dltl: October 11,198,5 $,.14:' N.T.S. CONDUCTORS 9 THRU 16 LOCATED IN PROTRACTED SEC. 19, T. 12N.,R.9E.,U. MER. ,,,,,,,~. -- , ,,, ,,.,,w= Drifted by: Sydney2 DII. N~. N~4(85-26 October 10, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-5 ARCO Alaska, Inc. Permit No. 85-242 Sur. Loc. 48'F~L, 70'FWL, Sec. 29, Tt2N, R9E, Btmhole Loc. 1096'FNL, ll02'FEL, Sec. 20, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The'~permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor-pipe. C. V. Chatterton Chaiman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o eric!. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 3, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-5 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3F-5, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on October 17, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/HRE/lt . PD/L05 RECEIVED Enclosures OCT 0 ? 985 · Alaska Oil & Gas Cor~s. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COi~-rr~IlSSION PERMIT TO DRILL DRILL J]~X REDRILL [] DEEPEN [] 20 AAC 25.005 EXPLORATORY [] SERVICE [] ~ STRATIGR DEVELOPMENT OIL [~X SINGLE ZONE ~ .... DEVELOPMENT GAS [] MULTIPLE ZONE% 9. Unit or lease name Kuparuk River Unit lb. Type of well 2. Name of operator ARCO Alaska, inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 48' FNL, 70' FWL, 5ec.29, T12N, Pge, UN At top of proposed producing interval 1445' FNL, 1442' FEL, $ec.20, T12N, Pge, UN At total depth 1096' FNL, 1102' FEL, Sec.20, T12N, Pge, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 93' PAD 56' , 6. Lease designation and serial no. ADL 25632 ALK 2565 10. Well number 3F-5 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 48' ~ surface feet J3F-4 Well 25' @ SURFACE feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease J 18. Approximate spud date 8949' MD, 6380' TVD fe~.t 2560 J 10/17/85 19. If deviated (see 20 AAC 25.050) J20. Anticipated pressures 21~44 psig@ ROoF Surface KICK OFF POINT 350 feet. MAXIMUM HOLE ANGLE 49 OI(see20AAC25.035 (c) (2) ~psig@ 5953 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE j Hole Casing 24" 16" 12-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36.0# J 26.0# J 22. Describe proposed program: CASING AND LINER Grade Couplingl Length ,-,-4o / MD TOP TVD 80' 35' I 35' 3924' 35' I 35' I I 34' I 34' MD BOTTOM TVD 115'I 115' 3959'I 3093' I 8949'1 6380' I I (include stage data) * 200 cf 1060 sx PF "E" & 425 sx PF "C" 325 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8949' MD (6380' TVD). Selected intervals will be logged. A 20", 2000 psi annular diver,er will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2644 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing.the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F~5 will be 25' away from 3F-4 at SURFACE. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby c¢.,~+(y that the foregoing is true and correct to the best of my knowledge T h e spa c~/~o~v ~'~/9~ m "~s i o n ~ s~- CONDITIONS OF APPROVAL Samples required [~YES ~[.NO Permit number APPROVED BY ~~ Form 10-401 (HRE) PD/PD05 Mud Jog required J Directional Survey required I API number [-]YES ~O ] ~YES I--INO J 50_O%.~'_"Z../,~ I Approval date , //~1J)t/10/~5, SEE COVER LETTER FOR OTHER REQUIREMENTS --,COMMISSIONER DATE October 10; 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3F-5 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED AlasKa Oil & Gas Cons. C0mmissio~ ~ch0ra.ce Z - - O. 1000 i ami O. - 1000 . . ~L,tRF/K~E LOCATIONs 4~' FNL. ?0' FWL N 44 5585' DE8 9 HI N E (TO TARGET) t : RECE'IVED_ AlaSka Oil-& Gas Cons. Commission ! \,m EOC TVD 1787-- Ti'iD-!97'7 DEP-6$2 - UGNU SNDS TVD'19.18 THD.21 .DEp,80! ?000. _ ' J '' i ' i ' i ' i ' i 1000 2000 :3000 4000 SO00 6000 VERTICAL SECTION 300 200 1 O0 0 1 O0 200 :~00 400 500 600 I I I ~ I I ~NC:-- -- -- -- ^E~s~. ---- / - ~LL NO, 5-6-?-e .PROUD I FIELD. NORTH SL~E. ~ · / ~[PSTOCK. INC. ~ , '~ , ,, · 1 955 .... : ............. ; ............. / / 4240 ' ~LL PATHS EXTEND BEYOND /' THIS VIE~ING,~INDO~ · · / , - ,: ' / / ' ' . ,/ / " : ~--~ 4 ', ~ /~ /~ :'' ' ~3~3~~z 1890 --: ~> ~ ,.,/:~ ~ . : > ................ ~"~~~ ,,,, ,,,,,,,,,,, ....... ,,,,,,, , ~ ~ o ,~ ~oo KUPARUK R I VER UNIT '20" DIVERTER SCHEMATIC DESCRIPTION I. 16' C~IXJCTOR. 2. TAI~O STARTER HEAD. $. TAI~(3 SAVER SU~. 4. TAI~O LO~ER QUICK-C~CT AS,.~Y. S. TAINI<O UI~R QUICK-C~CT A.~Y. 6. 20" 2000 I~! DRILLING Vl/I O" (31JTL£TS. 7. IQ" I-ICR BALL VALVES W/I DIVERTER LI~So VALVES AUTOMATICALLY ~ CLOSUR~ (DF' 8. 20" 2000 PS] ~AR PREVENTER. . MAI NTENANCE & OPERAT I ON I. UPON INITIAL INSTALLATI(DN, CLOS~ PREVENTER AlVIn VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE ~AR PREVENTER AI~ BLOW AIR THROUGH DIVERTER LIltS EVERY 12 HOURS. cLo~ ^-~,-~ P~vE~£. ~. T.E EV~.T THAT ^. ~LUX ~ ~LU~DS O. CAS ~S DETECTED. 0.0~ A~P.<~ATE VALVE TO ~ E C ~iV E D^c"~EvE ocw~~ DO NOT SHUT [N MiLL AlasKa Oil & Gas Cons. E;o~~R ANY ¢IRCU~TAN~E~o Anchorage 7 ~ 6 4 h > > I _ 4. ~ UP TO 2~3 I~Z~¥Q:) I-a.D FCR I0 MIN. ]:N-- ~ ~ T~_~ ~ I..N:I, J3 FC~R I0 MIN. LII~ VALVES. CLOS~ TC~ PIPE ~ A/~ NCR VALVES ~N KILL 6. TEST TO 250 ~I AN;~'~CX:)~St~ AS IN STEP 4. ? ECEiVED 13-5/'~' BCP STAO( TEST i. Fl%L BC:P STAO( Aid3 (:343(E MINZF(:X.D Ft,l.i.Y RE-.~. SEAT TEST PLUG IN WITH l~q.r~q;.Ng Jl' ~ U IN LCX:XIX:Mi LIllE VALVES ~ TO ~ ~'rA(3?,. ALL. MANZF01.D AN3 LI~ES ARE FULL CE ~ING FLUID. ~'T NJ. VALVES IN ERILLIN~ P(~ITIC~. PI~ ~ ~I. 13. ~ TEST I~~TI~ ~ ~~ ~ ~ST F~, SI~, ~ ~ TO ~I~I~ ~l~. 14. ~Y T~ ~I~Y ~~ ~ ~ILY. oc'ro ? I~B5 Alaska 0ii & Gas Cons. Commission si ooe4oo ~ ~Ev.~ I~AY 1 5. 19~S CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE YES NO REMARKS (1) Fee (2) Loc (3) Admin ~ / o-f-~O''~ 9. (9 thru 12) 10. (10 ~nd 12. Is the permit fee attached ..... · .......... . .......... . ..... 2. Is well to be located in a defined pool .................. 3. Is well located proper distance from property line ...... - 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party ....... ' . 8. Can permit be approved before ten-day wait '[[i[[[[[[[[[[[i[[. Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~'~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... (13 thru 21) (22 thru 26) (6) Add :.~. ~./~- ~' ,~ 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10'-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system req. uired ,,,. ......... Are necessary diagrams of diverter and BOP''''''''' '''''''' "'''''equipment'attached'"''''' ~ Does BOPE have sufficient pressure rating - Test to ~OCK) psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................... /;gM_ Additional requirements eeeeelelle.eeeeee.eeeeeleeeeeeeleee.eeeeeeeee Additional Remarks: Geology: Eng ~e'ging: HWK ~ K LCg ~/~. WVA~ MTM ~ HJH~- JAL ~.~:'U-...._. ' ~ ' ' rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE o ; '° o !! t , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file~ To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , RECEIVED , ********************** I'~OV 1 8 ~gg§ ,--------------------, Gas Cons. Oommlss ' ..... An ~ ~o~ a,.;.. VEP,]~IFTCATTON t,I~TTN~ L¥~' PlO,w02. VER!FIr'A~'.Ic)N ,I....,ISTI,~tG PAf, E I DATE ORIG~N : RE~L N~MF :14~62 CONTINUATION DATE :R5/10/25 ORIGIN :0000 TAPE NA~ , :OBi8 CO~TINUA~In~ ~ CO~M~NTS :LIBRARY TAPE VE~$10~ DATE ~RMV!O~iS ** I~JF~R~ATiON RFCPRDM ** [!NIT TYPE CAT~ SIZE CODE mmm. mmmm mmmm m~mm ~ CN ~ ~RCO Ar,ASKA IN~ 000 000 016 065 W~ t 3F-5 OOO 000 004 065 WN ~ ~[,{FA~UK 000 000 OOB 065 ~A~G: OB 000 000 002 065 TOWN! 12~ 000 000 004 065 SEC],': ~9 000 000 002 065 COUNt ~{,SL~PW 000 000 012 065 STAT: ~La&WA 000 000 006 065 C~y: uS~ 000 000 004 065 TYPE CATE SIZE CODE ORWS: M 000 000 001 065 ** CmM.E~TS ** ******************************************************************************** * ~bA$,w~ A *************************************************************************************** ¢O~PfNY = A~CO ~b~,SKA, FIELD = COUNTY : N~RTH SLOPE STATE = ALASKA JOB NUMB~iR AT ACC: 70898 RI}~t ill, DATE braGgED: 20 f]CT ~5 LOP: L,. m, CI.ID~EY CA~I~IG = 9 6~5" ~ 3974,' - ~IT SIZ< = 8,5" TO 8875' TYPE FLU~{) = L,~ND DEIST,fY = 10,1 T,.,B/G ~COS,'TY = 46.n S R~F = 4.,, = 9,5 ~bi,l{J~ LOSS = 9,4 C3 bVP OIO.WO~. VEPlFICA~J~ON LIS~I~!G UAGE ~{ ****************************** SC~L~:M~E~GER LOGS I~CbUDED WTTH T~{iS M~GNgTIC TAPE: , , * · r)U.Ab IMDUCTiON SPHERIC..abLY FOCUSM[) bOG (DIL) * O' * · D~ A. AVAIbABb~: 2000,0' · ~OPM~TION D~NSITY CO~PE~qSATED t..O~ · COMPM~SAT~D NE~TROM LOG (FDN~ * · O~Tt, AV~IbABLM: 5600.0' TO 86~6.0' * · Ga~'~A ~Al IN CASi~G (GR.CSGJ * , , , , , , , , , , , , , * , * * * * * * * * * * * * * * * * ** DAT~ 'FORMAT RECORD ** ~NTRY TY~E KIZ~ ~EPR COD~ 2 I 6~ 0 1 ~ 4 9 4 65 ,1TN ~.6 I 66 0 1 ~6 0 D~TUM SPKCTFTC~T:ON BbncK$ WNMM SKRVlCE SKRVICE {,INIT APl ~pT aPi ~P! FILE SIME $~h REPR PROCKM$ ID OPDR~{ # LOG TYPE C[,,~$S MOD N~, CODE [OC~) D~;PT r~~ O0 000 O0 0 0 4 1 68 00000000000000 SE'£,U ~it o~tu~,'~ nO ~20 Ol 0 0 4 1 68 00000000000000 tb~ ~I1.i oH~.~i oo 1,2o 4b 0 0 4 1 68 00000000000000 Ib~ ~i[, O~t~ oO 120 ~4 0 0 4 I 68 00000000000000 SP ~I1, ~V O0 010 O1 0 0 4. 1 68 00000000000000 GR n'IG ~,I O0 310 01, 0 eR rl..>tr ¢;API O0 ~,1.0 Ol 0 C A I., I ~ L) ~ T N 00 2 ~ 0 01 0 ~HO~ PDV C/C3 O0 350 02 0 DR~O PD~~ C/C3 O0 356 01 0 ~ R ,~ T rD ~ 00 420 01 0 RNRA F'D~; O0 000 O0 0 ~PHI PDt,~ PO O0 ~90 O0 0 ~C~[.~ rD~,~ C, PS O0 330 31 0 F'C~]b WDN CPS O0 330 30 0 qR CSt ~APi O0 3!,0 Ol 0 1 68 00000000000000 1 68 UO000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 0000000000'0000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000'000 OEPT 8600.0000 SFLU RHOB 2.4065 ORPO NPHI 46,1,4~b OEPT 8500.0000 SF[,O RHOB 2.~"11.~ DRWO VPHI 3~.4707 NC~b OEPT 8400.0000 gP -1,4.~4B0 ~R ~HOB 2.'~065 ~PH], 20,3457 MCa'L., SP 1~ 651 4 g~ ~PHI 2q.0805 ~Cb'L OEP1' 8~0o 0000 SFLU 8P -23!0264 ~R ~HOi:~ ~ 494% DRHU ~PHI 2~.!738 ~CML qPgI 4g.6Blb MC~b 4.1179 Tied 34.'440,~ ~R -0'326 NRmT 506.3906 PCNI., 4 44.,2 GR 30~1265 NR~,T 1894.6875 PCNb 6.8250 ILO 1.07 0898 GR -0:004~ ~R~T 2513.5000 PCNL 9,52~4 IhO 87.4023 gR -0.0010 NRAT 2607.5000 ~CM[, 5.3289 ThO ~17-40~3 GR 0.0664 ~RAT 2545.500U PCNb 1.6895 lbo !25,5273 GR 0 0132 t~RAT P.6057 ILO 9~.5273 CR -0,0005 ~RbT 1~0V.6875 FCML 4,3250 34.4,492 5569 13~'4375 34:4492 3,6057 ,477.3906 ! L~ 3,396 7 CAbl 8 , S020 OR -999, ' 0 I{h" 1~,4707 CALl GR -9 , 6.0828 Ih~ 6,328.9 1. 07 0898 CALl 8.6504 2; 7092 RNRA 2,742'4 qlS.tml~5 CE -999,3500 7 9226 5 B66. 1 11 6897 898.8125 GR -999, O0 Ib~ ~4,926~ CALl .,, 345 ~N~A 2,8303 C,R -999,2500 3 8225 ~NRA 4 3445 456~1406 GR -999 2500 ~.4924 98.~273 889 447.8906 IbM 2,5452 CALl 9,5879 RNRA 4.0359 GR -99q,2500 RHOB ~' 31 ~6 DRHO NPHI 45. ~OOB NCDlb 3 280 1996 5 F'C b 4 7664 lbD ~34,:56~5 ~R 0.0015 NR.RT DEbT 7700 o000 .SFi.,U 4. 121.8 AHaB ~.~5 DR~HUc. o.~0259 N~a,r NpH'~ 4~.~a ~ ~, 1~9.687s rCNb DEDT 7600 0000 SFLU ~P -15' ~793 ~R RHOB 9.~465I DRHO NPHI 44,53~,3 NCNb OEP? 7500,0000 SFI, U SP -16,2205 GR NPHI 43:7988 N:CNL OEPT 7~()0.0000 SFt, U SP -19 ~07b GR RHO5 -o9gi~500 DRHO NPHI -~99 ~500 NCnb DEPT 7900 0000 Sf'I,,,U $P - 0'~238 ~R NPHI -QgD,~50~ NC~b DEPT 7000.oono $FI,U RHOB -99~.~500 DRHb NpHI -Ogg.~50u NC~Tb gEDT b~oo.n0oo SFi..U gP 16.?'164 GR ~HnB -g9g,?500 DR~C) 4,.~4~9 lbD ~7t, 375 GR 0.0161 NR~T 2~71,5000 FCNh ~29 25 0'0444 21.19~5000 FCNL 5 9734 Ifad -,~99.2soo ,NR~T -~99.~500 ~CNt, 4.6257 tbD 105.9648 -~9~ ~500 -o9~: 2500 3 4104 !.05i214U -q9g 2500 -09q.~bnO FCNI: 2.56~7 TI.,D 113.8398 ~R -99o 9.500 ~RaT . 74!3 IbM 14 .~3 5 CAt,! ,.9 5 RNRA 49 ..J406 ~R 2 9768 4,58:8901 aR i.~186 IbM ,, 1!6 RNRA , 906 4,4265 IbM 171.9375 CALl 3,.6Bt9 RNRA 522-8125 GR ! M 129 31 I 3 6624 RN~A 565,8125 OR 4,4539 lb~ '~99.~500 CALl '999,~500 RN~A -999, 500 ~R . 4.?039 rb~ i CALI .~9~, ~00 .999, O0 RNRA 999..500 GR 4 4343 ~99i2500 CALl -q99 2500 RNRA -999.~500 GR 4.4070 Ib~ 999~500 CAL! 2999.2500 RNRA -999.~500 GR 3.3948 9~.2500 ~N~A -99q.2500 5959 Ybw -999:2b00 CALI ,924~ 4. 47'6, -999&2~00 3 0784 -,99~' ~50 $$66 999 O0 -999.' -6 -999, 4,8250 -999,25~0 =999,25 0 -999, ~$00 4.4187 -999,2S00 -999.2500 -.999,~500 3,4983 -999, O0 '999.{~00 -,999.2500 2,6370 '999,2500 -999,2500 bVP OIO,HO? vg~.:[FIC^~In~ L,T. STiS!(; .PAC, E 6 DEPT ~:PH I O~O0.O0, O0 SFI, U ].?522 lbo 1l.)652 r,R ~34.1.~?5 gR , ,;~. (.) D l-~('.:) -g9q. 2500 NR&T -qgO,~500 ~'~ C ~,~ [, -q99,7500 rCNb DEPT b?O0,O000 SFI,U 3,9768 SP -l~l,g'701 OR 135,0625 ~HOB -q99, ~500 DRHO -~99. 2500 NRAT NPHI -q99,~500 NC~G -~99,~500 DEPT SP ~.HOB NPHI 6600.0000 SFLU 4,6531 IbD ~. ~389 ~R 13R,56~5 OR '1~'4.006 DR~{O 0,0366 N'RAT 37o~:0~,4 NCNb 216,t.5000 FCNL DEPT {iSUO 0000 SF' 1.,, U ],6709 ,~hD SP -~: 2402 GR J 56.. 4375 GR ~HO'B ~ 3850 r>R,O 0 t255 ~R~T ~I 4~:7soo .c~b 2005:~s~s' vc.b DEPT 5P ~HOB NPHI RHOB ~pH I SP SP SP SP r~ e.;m .I., 6400.0000 SFI, U 2.0£165 IbD ~049 OReO 0.0132 ~T 43:g965 NC~b 2~25,5000 ~CNL ~:~1~6 DiS.~t:.i 0 0059 ~RAT 40 0879 ~,CNb 2391:5000 FCNL 6:00 0000 SFI.U ~,. 703,~ lbD ~.)147 Dado "0:0068 NR~'t 44.~'130 ~lC~tb 2123,5000 ~CN[., -11.:451.:2 OR 130:q375 2,3167 ~.~O 0,0073 NRAT 4n.7277 NCNb 21 17.5000 FCWL -0.1667 GR 1'13:5625 OR ~.3303 DR~O 0,0112 NRRT ,~1..064b ~C~L 1~5fi.6875 FCML 5qO0 0000 qFbL! 7.4456 ILD ?.~049 DRHLi 0.0713 ~RAT 41.6902 NC~!L 2i3],5000 FCN[., 5~00.0000 ~Fr,ti 2.4006 lhD ln.18q5 GR 97,4023 OR -999.~500 GR 2.8401 IbM -999.2500 -q9~,2500 RNRA, '990..~500 GR 3.9495 Ib~ -g9g.!~O0 CAI.I · .999. 00 RNRA ..999, .500 GR 4.41r09 IbM ).38,5625 C.AbI 3,3049 RNRA 549,81~5 ~R S2 .3'1~.§ ~R 2.1155 J32.1875 CALl 3,549I ~NRA 582.3125 3284 .T. LM 115:6523 CAt, I 3733 RNRA 613.~1~5 GR 2.6155 Ib~ ~40.31~5 CALl 3.6252 RN~A 575.8125 GR 2 7 09 3.4143 ~NRA 585.3125 3.0276 173 CALI 6 RNRA 504.1406 2.5920 IbM B~.9648 CALl 3.4534 RNRA 578.8125 mR ~.5276 IbM 97.4023 CAI.,I -099,~500 ~,OlZO '999'..60 -999, -999,~500 4.0476 "999~.~00 ~999~2500 ~999,~500 ,9,j38 -99~,25'00 1,2952 9,1113 3.,90{0 -099.~S00 ~,338! ,e,948 -o99,25oo 2,6135 8,8926 3,6858 -999,~500 =g99 0 3,1194 2 ,5452 8!9395 -999,~00 [,,VP 010.;407 VEPlF,iCATION LISTING PA~E 7 ~ P W I 4 !,. 455 '1 ~,t C N b O,CPT 5600. 0000 SP ,,,I 3.52,~ 5 OR RHOB ~.312i DRHO NpHI 4~,n410 NCN|~ 9CPT 55~0.0000 SFLU SP 6.13fi0 ~500 DR. HO RHf~B '099'~500 NCNb NpHI RHnB -099;9, 50,,) DRHU MPHI -g99,~500 NCNL SP -2:5935 C.,R RHOP. -~99,2500 DRHO NpHI -q9o, 9~500 NCNb DEDI, 51~0.0000 SFLU SP 7,0852 NPHi .Q90.7500 nEPT 4oO0.nO00 SFI~U SP -10.61~2 ~R RHO6 -Q9Q.2500 DRFiO NPgl -999,75o0 MC~'L DEPT 4~00.00n0 SFLU ~p -g.9355 C~ RHnB -099.9500 DRHO NPHI -~99.7500 ~:CFL n. EDT 4~ 700. hue0 SFI.U 0,01.32 NRAT 2211.5000 FCNb 0.0054 NRAT 2~,47.5000 FCNh 2.34?0 lbo ~,1,0'52~3 CR 0.0166 MR4. 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