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Home My WebLink About205-029 • • • P7-0 R05-02q Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,January 19, 2018 1:55 PM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE: KRU 1F-01A(PTD 205-029) report of SCP of OOA update 1-19-18 Attachments: 1F-01A 90 day 110 SCADA snapshot 1-19-18.JPG Follow Up Flag: Follow up Flag Status: Flagged Victoria, No,the OOA pressure was not displayed on the TIO plot that Jan submitted. I have attached a new plot with that info. While the OA and OOA have normally been maintained below 150psi,they do appear to be tracking based on the diagnostics run on the well so far. In late December 2017,the OA was pressurized with gas and the OOA was observed to slowly climb. Due to the historical IAxOA communication to gas before the 5.5" liner was installed during the 2015 RWO,this was not unexpected. But then in early January 2018,an attempt to perform an MITOA,using liquid,failed as well due to the slow continual build up in OOA pressure. At that point, both annuli were pressurized together and we were able to obtain a passing combo MITOAxOOA pressure test. Based on the pressure trends,there does not appear to be IAxOA communication and a recent passing TIFL confirmed the tubing and packer have integrity. Because the OA is permitted to go to 1000psi,we waivered the well to allow the OOA annulus to go to 1000psi as well. No further diagnostics are planned to pinpoint the location of the leak in the 7" (causing the OAxOOA communication) because we have sufficient barriers in place at this time. Please let me know if you have any more questions or would like to discuss further. Thanks Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 SCANNED _. 9 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,January 17, 2018 10:05 AM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: [EXTERNAL]RE: KRU 1F-01A(PTD 205-029) report of SCP of OOA Jan, On the T/I/O plot, I don't see the OOA operating above the 150 psi DNE. Is the OOA plotted? Are there diagnostic plans for this well? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�.alaska.gov 1 • CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent:Thursday,January 11, 2018 9:53 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: KRU 1F-01A(PTD 205-029) report of SCP of OOA Victoria, KRU gas lifted producer 1F-01A(PTD 205-029) is experiencing sustained casing pressure of the Outer Outer annulus (OOA)as the pressure has continued to increase above the 150 psi DNE. A RWO in 2015 installed a 5.5" liner creating an additional annulus. Diagnostics indicate OAxOOA(5.5"x7"x 7"x10-3/4")communication. A CMIT OAxOOA to 1800 psi and TIFL both passed on 1-7-18 to prove sufficient barriers exist. CPA intends to waiver the well for known OAxOOA communication allowing the OOA pressure to operate up to 1000 psi. The 10-3/4",45.5 lb, L80 surface casing has an internal yield pressure of 5210 psi(45%-2345 psi). Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 friE..L.S TEAM Coma2 a ' CP a H o < Ct1 I:4 t..... A I-I 4. .. W W 1 , • •-•..4 o L....., ,..., „I 0 ra, >., ,:::) OC. w a L a w No I Z 3 ,q. O ;.. N. N N. N N. N N. +-+ ,-4 r,,. N. r., s. N. N. N N. r .. .4 N. N N. N, N. N N, N. 0II I I r.) „ti• n,• 0,.. NC`.... � , r., (N.. C.• r....Z r-{ �I N. N. N N. N. N. N. 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C.% 4-4 C) V • PTD 3,05- -07- 9 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday,January 11, 2018 9:53 AM To: Loepp,Victoria T(DOA) Cr Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1F-01A(PTD 205-029) report of SCP of OOA Attachments: 1F-01A.pdf; 1F-01A 90 day TIO trend jpg Follow Up Flag: Follow up Flag Status: Flagged SC 0148) Victoria, KRU gas lifted producer 1F-01A(PTD 205-029) is experiencing sustained casing pressure of the Outer Outer annulus (OOA)as the pressure has continued to increase above the 150 psi DNE. A RWO in 2015 installed a 5.5" liner creating an additional annulus. Diagnostics indicate OAxOOA(5.5"x7"x 7"x10-3/4")communication. A CMIT OAx00A to 1800 psi and TIFL both passed on 1-7-18 to prove sufficient barriers exist. CPA intends to waiver the well for known OAx00A communication allowing the OOA pressure to operate up to 1000 psi. The 10-3/4",45.5 lb, L80 surface casing has an internal yield pressure of 5210 psi (45%-2345 psi). Attached is a wellbore schematic and 90 day TIC trend. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 41111WELLS TEAM c 1 0 PSI 0 ND -IN. CD CO m c. c‘ c.) c-) 4,,ir, 1. 1 .1 1 I, I .I s 1 . I i 1. 1 ii i LI 0 hi ,' i hi m , i . 1 • . . . . .-•, . . . •-' - . . • . -,.4 r: • . ' . • • • • - I) • : : : • • - • • • . • • 0 • - . : . • . -0 ---I . ' _...x _,..) : -c=z, • • . • . - --,4 s..„, • ----7: ' • . • • • • • ' _ • : • • ..--- -,-.._, • ' • • • • • 1 • .,. • • . • • .• i . Z • • . • - • • . . • . • . • - < : ___ ---:- ---- : • . • . • 1 - . _..), - • * * - - - . . . . -,....4 ` • • * • • - . . . - • • . - iss..) - - - • -41 • • • . i : • • . - t-,- - 0 0 - . ..., ....... - . • . - < • . - • , • - . . . _ ii . 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Wellbore APUUWI Field Name Wellbore Status nci(°) MD(ftKB) Act Stm(ftKB) , ptye, 500292088901 KUPARUK RIVER UNIT PROD 94.60 8,702_43 10,5330 --" ,..., Comment H2S(ppm) Data Annotation End Date KB-Grd(ft) Rig Release Date 1E-01A,11320176:10'51 PM SSSV:NONE 30 8/18/2008 Last WO: 11/26/2015 40.59 1/23/1983 Vertical schematic(actual) Annotation Depth(kK8) End Date Annotation - Last Mod By End Date Last Tag:SLM 8,478.0 11/3/2015 Rev Reason:TAG 8 PULL RHC PLUG pproven 1/3/2017 • Casing Strings ..........._ - Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER;34.5 11 1-1117 -I16 15.250 35.0 80.0 80.0 65.00 H-40 WELDED 14!,14. ) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 34.3 2,636.9 2,221.5 45.50 L-80 BUTT ` Casing Desviption OD(in) ID(in) Top(ftKB) Set Depth(5168) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION Post Sir 7 6.276 32.3 6,253.0 4,330.9 26.00 K-55 BTC MOD .,....._..................................................... ._.1.-- .. Casing Description OD(in) ID(in) Toe(MB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Tap Thread LINER TOP 41/2 3.958 6,086.3 8,335.0 6,063.1 12.60 L-80 IBTM XO Reducing(Tubing);379 i Liner Details Nominal KD I^'I Top(ftKB) TDP(TVD)(588) Top Ind(*) Item Des Com (in) 6,086.3 4,218.3 48.83 PACKER BAKER ZXP LINER PACKER w/HOLDDGWNS-HR 3.875 CONDUCTOR;35.0-804 • PROFILE 6,1)0.7 4,234.5' 48.50 HANGER BAKER FLEX-LOCK II HYDRAULIC LINER 3.958 HANGER 6,120.1 4,240.7 48.35 XO BUSHING BAKER CROSSOVER BUSHING 3.970 Casing Deswiption OD(in) ID(in) Top(11168) Del Depth(5168) .Set Depth(TVD)...Wt/Len(I...Gratia Top Thread WINDOW AL1 4 1/2 3.000 8,248.0 8,255.0 6,023.4 26.00 Cooing Dneedp1on "OD(in) ID(in) Top(f(KB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Slotted LINERA 2 7/8 2.441 8,242.3 10,474,0 6,172.4 6.16 L-80 STL SURFACE;34.3-2,836.9 Liner Details • Nominal ID Top(kK8) Top(ND)(ftKB) Top Ind(°) gem Des Com (in) ® 8,242.3 6,016.0 54.54 DEPLOY BAKER DEPLOYMENT SUB 3.000 GAS UFT;3,121.2 : ' 10,439.7- 6,171,7 88.86 0-RING 'BOT 0-RING SUB 1.000 llDeTubingStrings Tubing Descriptio String Ma...ID(in) Top(ft(B) Set Depth(ft..Set Depth(ND)(...WI(lb/ft) Gratis Top Connection 5-1/2"Inner Liner 51/2 4.950 34.5 6,100.0 4,227.4 15.50 L-80 5.5 RWO 2015 cnsLtFr:6,051 4 Completion Details e Nominal ID I®1• Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Dee Com (in) 34.5 34.5 0.03 Liner 5.5"BTCM Casing 15.5#L-80 Cut Off Jt#142 4.950 6,053.6 4,196.9 49.23 XO Reducing Crossover CPLG 5.5"BTC-M x 5"BTC-M 4.390 GAS LIFT;8939.1 t 6,054.6 4,197.6 49.32 SBE Baker 80-40 Seal Bole Extension 4.000 ®x. 6,073.4 4,209.9 48.99 Liner 4.5"IBTM Tubing L..80 12.6#Pup Jt. 3.950 ® 6,084.6 4,217.3 48.85 LOCATOR 5.75"Locator 3.910 6,085.6 4,217.9 48.84 SEAL ASSY 5.0"Baker Bullet Seal Assy. 3.910 ® Tubing Description String Ma...ID(in) Top(11168) Set Depth(ft..Set Depth(WD)(...Wt(ib/It) Grade Top Connection NIPPLE;5,987.1 Tubing RWO 2015 2 7/8 2.441 34.5 6,065.5 4,204.7 6.50 L-80 EUE 8rd Mod III Completion Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") item Des Com (in) 34.5 34.5 0.03 HANGER FMC Tubing Hanger,TC-IA-EMS,11"x 3-1/2",EUE 8rd 2.992 X0 Enlarging(Tubing);6,0452 Box x Box,3"H BPVG IR: 5,997.1 4,160.3 49.97 NIPPLE Nipple,2.312"DS,SN:1041415 2.315 LOCATOR;6,048.8 8,046.8 4,192.5 49.31 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 6.31') 2.990 O. xo Reducing;6,053.6 :! 6,048.0 4,193.2 49.30 SEAL ASSY 'Seal Assembly,80-40 2.990 SEAL ASSY;6,047.9 IlZ.It SBE;6.054.6 11'...i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(TVD) Top Ind Top(ftKB) (568) ("I Des Corn Ron Date 11)(In) 8,248.0 6,019.3 54.62 WHIPSTOCK AL1 WEATHERFORD LSX WHIPSTOCK 5/312005 3.958 XO'Meads 6,677.1 x o Perforations&Slots LOCATOR;6,0848 1Shot .-...._r; Dens Top(WO) Ban(WD) (shots/f SEAL ASSY;6,085.6 i! Top(5KB) Bhn(ftKB) (5168) (5168) Zone Date t) Type Com III 8,426.0 10,439.0 6,102.0 6,171.6 A-4,A-5,A-4, 5/31/2005 40.0 SLOTS Slotted Liner r • ' A-5,1F-01A _ Mandrel Inserts St - alt PRODUCTION Post 5/1-;32.3- on Top(T1/0) Valve Latch Port Sire TRO Run 6,253.0--° N Top(ftKB) (kK8) Make Model OD(In) Sara Type Type (in) (pal) Run Data Can 1 3,121.2 2,501.4 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,317.0 12/3/2015 • 2 5,051.7 3,595.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,317.0 12/3/2015 rL 3 5,939.1 4,123.4 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 12/3/2015 Notes:General&Safety WHIPSTOCK 8,248.0 End ata Annotation WINDOW AL1;6,248.0-8,2564 - 5/31/2005 NOTE:TREE:FMC 3-1/16"5M GEN V 5/31/2005 NOTE:MULTI-LATERAL WELL:SIDETRACK A-SAND(1F-0)A),C-SAND(1F-01AL1) 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 LINER A TOP;6,086.3-8,335.0 • SLOTS;8,426.0-10,439.0-.---� 6 Slotted LINER A;8242.3 ,k 10,474.0 • v 0le �— , ❑ n D o - N• z OA J-+ r > ro 1 I ��n to -0 ra 1.1 Q `I- Y0 -• u O > iC"' O .r.: n a C C 4 O N a v a a c > += m ro •c - a W ca O co m Q CZE a Y " s m --. w N N N N N N N N O If- c(rrQ w '7 i '7 y -2 -6) p L— n Q 0 3 3 7 7 7 g1 '- 'a ++ '- 0 C.� �1 w -� Q c c u v w N (N r o0 0) p c ++ p 2. 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W QNU EY ▪ O /9 0Cr 0 O 0 OU m o 0 0 0 0 o O - If) N N O O O1 O 4+ • O_ I.- N CO CO ac CO CO m it r N 0_ C) 01 00 0 04 0.1N - a N N N N N N N VI . _C— r, ner) c o a O a N N N N N N N e3 OU 0 Q1 O O O O O O O I- O O O O O O6 O O N 4+ O C So CE 00 c U) U) U) U) N U) U) a 0 0w 0 O cou • g.. z m e CU .I10 . a w w CD u .i Ia co h. Q ICI U) CD M Q v c Z a) M M O O N ',1-, A = �' o z Y m N N m E o `^ '^ C �� d a 00 N W M M N N N N VI Z H O O ,_ ca in •1 c n 3 co L 4! O O O � a 3 4 �i � a0.— F IISTE OF ALASKA KRU 1F-01A A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing F Operations Shutdown Performed: Suspend E Perforate E Other Stimulate n Alter Casing F Change Approved Program Plug for Redrill r Perforate New Pool E Repair Well F Re-enter Susp Well E F. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory fa 205-029 3.Address: 6.API Number: Stratigraphic n Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20889-01 7.Property Designation(Lease Number): 8.Well Name and Number: AD;25652 KRU 1F-01A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10533 feet Plugs(measured) None true vertical 6174 feet Junk(measured) None Effective Depth measured 6301 feet Packer(measured) 6086 true vertical 6047 feet (true vertical) 4218 Casing Length Size MD TVD Burst Collapse CONDUCTOR 45 16 80 80 0 0 SURFACE 2603 10.75 2637 2221 0 0 PRODUCTION 6221 7 6253 4331 0 0 WINDOW AL1 7 4.5 8255 6023 0 0 LINER A TOP 2249 4.5 8335 6063 0 0 SLOTTED LINER. 2232 2 7/8 10474 6172 0 0 INNER LINER 6065 5.5 6100 Perforation depth: Measured depth: 8426-10439 True Vertical Depth: 6102-6177 RECEIVED Tubing(size,grade,MD,and TVD) 2 7/8, L-80,6065,4205 DEC 2 2 2015 Packers&SSSV(type,MD,and TVD) 6086=MD 4218=TVD A\./GCC SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured) r` Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL fl Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ r WAG r GINJ r SUSP r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-670 Contact Diana Guzmaniu'�.265-6318 Email Diana.Guzman@conocophillips.com Printed Nam . a Guz an Title Sr. Wells Engineer Signature Phone:265-6318 Date i2-/ 2-/f,0`` OW '&.J94 iDr b. Gvr ,\ 1/Yi 3/i.9//G Form 10-404 Revised 5/2015 0#0. RBDMSIL DEC R 2015 Submit Original Only .: DA* REPORT OF WELL OPERATIOI 1F-01A ConocoPhillips DTTM JOBTYP SUMMARYOPS START 11/18/15 RECOMPLETION RD and Move off of 1D-36. MIRU on 1F-01A. Accept Nabors 9ES. 11/20/15 RECOMPLETION Load pits w/KWF and pull BPV with lubricator. Kill well, ND Tree and BOPE. Conduct Initial 11/21/15 RECOMPLETION Continue to test BOPE. RU slick line and RIH and Pull XX Plug in profile nipple @ 6042-ft. RIH 11/21/15 DRILLING ***9ES RIG JOB*** RAN FLAPPER CHECKER TO 2400' RKB. PULLED 3.81"XX PLUG SUPPORT FROM 6042' RKB; SET PARAGON II PACKER RETRIEVABLE BRIDGE PLUG @ 6167' RKB; CIRC OUT WELL AND PRESSURE TEST TO 2500 PSI PASSED. COMPLETE. 11/22/15 RECOMPLETION Continue to RIH w/Mechanical plug to and set @ 6156 SLM , 6167 RKB. PT @ 2,500 psi for 15 minutes. Good Test. RD Slick line, Unland hanger and Pull seals. Circulate 1.5 hole 11/23/15 RECOMPLETION Finish laying down De Completion from 800-ft. PU, MU and RIH w/5-1/2 Inner liner to 6,099-ft. Reverse circulate in CI 9.1 ppg NaCI Brine and flow with freeze protect to 2,000-ft TVD, Stab seals. PT 5-1/2"volume to RBP for 15 minutes, then the 5-1/2 x 7"annulus to 2,500 psi for 30 minutes. NFT both. Drain stack through the IA valve and suck down the 5-1/2 volume. ND 11/24/15 DRILLING ***9ES RIG JOB**** PULLED 3.75" RBP PLUG FROM 4.5" LINER @ 6167' SLM. SUPPORT COMPLETE. 11/24/15 RECOMPLETION NU New FMC Gen V Tbg Spool and 13-5/8 Class IV BOP Stack. Shell test tubing spool and BOP. PT IA to 2,500 psi for 30 minutes. RU Slick line to Dutch riser with lubricator, RIH with equalizing prong and attempt to equalize the RBP but were unsuccessful. RIH with GS spear, release the 4-1/2" Paragon RBP, and POOH with RBP. RD Slick line. PU, MU, and RIH with 11/25/15 RECOMPLETION RIH with 2-7/8"tubing per tally, engage the seals into the SBE, locate out on the SBE, mark the pipe and space out with pups. RU circulating equipment and reverse circulate 135 bbls of 9.1 ppg corrosion inhibited brine down the IA taking returns up the tubing at 3.5 BPM. Land the tubing hanger and RILDS. Drop the ball & rod and allow time for it to fall to seat. PT the tubing to 3000 psi for 15 minutes(good test). Bleed the tubing to 1500 psi and PT the IA to 2500 psi for 30 minutes (good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Quickly pressure up on the IA to shear the SOV(sheared at 2600 psi). Bleed the pressure to 0 psi. Monitored the well for flow for 30 minutes and the well is static. Install 3" 'H' BPV. Pressure up on the IA to 11/26/15 RECOMPLETION Finish the COP BWM program on the BOP stack. Attempt to change out packing on the HCR kill but unable to do it. Remove HCR kill from the BOP stack. ND the BOP, NU the tubing head adapter, PT the void to 250/5000 psi (good test), and NU up the tree. Pull the BPV and install the TWC with lubricator. PT the tree to 250/5000 psi (good test). Pull the TWC with lubricator. RU Little Red Services and freeze protect the well with 50 bbls of diesel. Place the tubing and IA in communication allowing the well to u-tube and equalize. Install the 3" 'H' BPV with the lubricator. RD Little Red Services. Clean the cellar and dress the tree. Final well pressures: KUP PAVE) 1F-01A Conon �1iliup5 '•}'n Well Attribut Max Angle TD Naska,Inc F` :_ Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) Corwcd'Hitfips 500292088901 KUPARUK RIVER UNIT PROD 94.60 8,702.43 10,533.0 -.. . Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date IF-01A,12/22/20153:20:56 PM SSSV:NONE 30 8/18/2008 Last WO: 11/26/2015 40.59 1/23/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,478.0 11/3/2015 Rev Reason:WORKOVER,GLV C/O lehallf 12/22/2015 Ilk ( asing rings HANGER;34.5 I I I Cas ng Description _OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �t 4I. CONDUCTOR 16 15.250 35.0 80.0 80.0 65.00 H-40 WELDED til Casing Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I.Grade Top Thread SURFACE 10 3/4 9.950 34.3 2,636.9 2,221.5 45.50 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION Post S/T 7 6.276 32.3 6,253.0 4,330.9 26.00 K-55 BTC MOD Casing Description SOD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread XO Reducing(Turing);379 I T LINER A TOP 4 1/2 3.958 6.086.3 8,335.0 6,063.1 12.60 L-80 IBTM 4. Liner Details 1Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;35.0-80.0 6,086.3 4,218.3 48.83 PACKER BAKER ZXP LINER PACKER w/HOLDDOWNS-HR 3.875 PROFILE 6,110.7 4,234.5 48.50 HANGER BAKER FLEX-LOCK II HYDRAULIC LINER 3.958 HANGER 6,120.1 4,240.7 48.35 XO BUSHING BAKER CROSSOVER BUSHING 3.970 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • WINDOW AL1 41/2 3.000 8,248.0 8,255.0 6,023.4 26.00 _ SURFACE;34.3-2,636 9----• Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread Slotted LINER A 2 7/8 2.441 8,242.3 10,474.0 6,172.4 6.16 L-80 STL I Liner Details GAS LIFT;3,121.2 I_.: Nominal ID 11 I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 8,242.3 6,016.0 54.54 DEPLOY BAKER DEPLOYMENT SUB 3000 10,439.7 6,171.7 88.86 0-RING BOT 0-RING SUB 1.000 Tubing Strings GAS LIFT;5,051.7 I.; Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...I Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 5-1/2"Inner Liner 5 1/2 4.950 34.5 6,100.0 4,227.4 15.50 L-80 5.5 RWO 2015 Completion Details Nominal ID Top(ftKB) Top(TVD)(MB) Top Incl r) Item Des Com (in) GAS LIFT,5,939.1 34.5 34.5 0.03 Liner 5.5"BTCM Casing 15.58 L-80 Cut Off Jt#142 4.950 6,053.6° 4,196.9 49.23 XO Reducing Crossover CPLG 5.5"BTC-M x 5"BTC-M 4.390 6,054.6 4,197.6 49.22 SBE Baker 80-40 Seal Bore Extenssion 4.000 It 6,073.4 4209.9 48.99 Liner 4.5"IBTM Tubing L-80 12.68 Pup JL 3.950 6,084.6' 4217.3 48.85 LOCATOR 5.75"Locator 3.910 NIPPLE,5,907.1 6,085.6 4,217.9 48.84 SEAL ASSY 5.0"Baker Bullet Seal Assy. 3.910 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection IITubing RWO 2015 2 7/8 2.441 34.5 6,065.5 4,204.7 6.50 L-80 EUE 8rd Mod Completion Details in (Tubi Nominal ID XO Enlarging 9 ng);6,045.2 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) LOCATOR;6,046.8 34.5 34.5 0.03 HANGER FMC Tubing Hanger,TC-1A-EMS,11"x 3-1/2",EUE 8rd 2.992 Box x Box,3"H BPVG ; 5 5,997.1 4,1603 49.97 NIPPLE Nipple,2312"DS,SN:T041415 2.315 i.X0 Reducing;6,053.6 6,046.8 4,192.5 49.31 LOCATOR Locator Sub,GBH-22(bottom of locator spaced out 6.31') 2.990 SEAL ASSY;6,047.9 I VIII SBE,6,054.8 f1131M,11 9 8 6,048.0 4,193.2 49.30 SEAL ASSY Seal Assembly,80-40 2.990 I I Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl XO Threads;6,077.1Top(ftKB) (ftKB) CI_ Des Com Run Date ID(in) LOCATOR 6084 s ® 8,248.0 6,019.3 54.62 WHIPSTOCK AL1 WEATHERFORD LSX WHIPSTOCK 5/31/2005 3.958 , 11111= Perforations&Slots SEAL ASSY,6,085.6 _ 1 Shot Dens Top(ND) Btm(ND) (shots/ (AM Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn Ill 8,426.0 10,439.0 6,102.0 6,171.6 A-4,A-5,A-4, 5/31/2005 40.0 SLOTS Slotted Liner A-5,1 F-01 A _ Mandrel Inserts PRODUCTION Post S/T;32.3- St 6,253.5 oh N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1, 1 3.121.2 2,501.4 Camco KBMG 1 GAS LIFT GLV BK 0156 1,317.0 12/3/2015 III 2 5.051.7 3,595.1 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,317.0 12/3/2015 3 5,939.1 4,123.4 Camco KBMG 1 GAS LIFT OV BK 0250 0.0 12/3/2015 WHIPSTOCK 8,248.0 I Notes:General&Safety WINDOW 411,8,248.0-8,255.0 `' End Date Annotation 5/31/2005 NOTE:MULTI-LATERAL WELL SIDETRACK A-SAND(1F-01A),C-SAND(1F-01AL1) 5/31/2005 NOTE:TREE:FMC 3-1/16"5M GEN V 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 LINER A TOP;6,086.3-8,335.0 SLOTS;8,426.0-10,439.0 L Slotted LINER A;8,242.3- 4 L 10,474.0 • • Drilling Operations Summary (with Timelog Depths) &Wells 1F-01 CortocoPhiillps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2015 11/19/2015 3.27 MIRU MOVE RURD P Bridal up, Lay over cattle chute,pay 0.0 0.0 23:59 03:15 out tugger,man rider and Bridal line tugger lines. Lay derrick over 11/19/2015 11/19/2015 2.75 MIRU MOVE RURD P Separate mud pits from sub base,PU 0.0 0.0 03:15 06:00 mats and load out truck. 11/19/2015 11/19/2015 2.50 MIRU MOVE MOB P Warm up moving system and pull sub 0.0 0.0 06:00 08:30 base off 1D-36 and clean up matting base sub sat on, Load out mats on truck. 11/19/2015 11/19/2015 6.75 MIRU MOVE MOB P Move sub base and pit module from 0.0 0.0 08:30 15:15 1D Pad to 1F Pad 11/19/2015 11/19/2015 1.75 MIRU MOVE RURD P PJSM with crew. Remove Jeep out 0.0 0.0 15:15 17:00 from under pit module and tie directly on to the pits. Set herculite,matting material around cellar and load tree in cellar. Stage equipment behind well. 11/19/2015 11/19/2015 1.50 MIRU MOVE RURD P Pull rig over well and center. Set up 0.0 0.0 17:00 18:30 matting under base and sit sub down. 11/19/2015 11/20/2015 5.50 MIRU MOVE RURD P Back in pit module and connect 0.0 0.0 18:30 00:00 interconnects from sub base to pit module. Lay power cable for tie in to camp and shop complexes. Raise derrick,finish berming of the cellar and pit areas,wire up top drive and Bridal down. Accept Nabors 9ES at 22:00 hrs on 11 -19-15 11/20/2015 11/20/2015 5.00 MIRU MOVE RURD P Hang Bridal lines,RU Rig floor and 0.0 0.0 00:00 05:00 Cellar for well kill. Take on fluid to pits, load Lubricator in pipe shed to warm up. 11/20/2015 11/20/2015 2.00 MIRU WELCTL MPSP P PU Lubricator and PT to 1,500 psi- 0.0 0.0 05:00 07:00 observe for visual leaks -good test. Recover BPV and lay down lubricator. 11/20/2015 11/20/2015 1.75 MIRU WELCTL SEQP P Finish tying in the cellar lines,blow air 0.0 0.0 07:00 08:45 through lines to kill tank. Hydro Test lines to 3,500 psi-leaking gasket, repair and retest-good.. Blow down lines. 11/20/2015 11/20/2015 3.50 MIRU WELCTL KLWL P Circulate 92 bbls of 9.1 ppg NaCI 0.0 0.0 08:45 12:15 Brine at 5 bpm at 300 ICP and 150 FCP with 90 bbls returns in kill tank. Reverse circulate 209 bbls of 9.1 ppg NaCI Brine at 5 bpm at 460 ICP and 300 FCP with 205 bbls returned. SITP =60 psi and SICP=28 psi. SIOAP= 800 psi 11/20/2015 11/20/2015 0.75 MIRU WELCTL OWFF P Bleed off SITP and SICP,Monitor well 0.0 0.0 12:15 13:00 for flow for 30 minutes-No flow. 11/20/2015 11/20/2015 0.50 MIRU WHDBOP MPSP P Dry rod in BPV and lay down dry rod. 0.0 0.0 13:00 13:30 11/20/2015 11/20/2015 0.50 MIRU WHDBOP OTHR P Blow down all circulating lines and RD 0.0 0.0 13:30 14:00 the same. 11/20/2015 11/20/2015 0.50 MIRU WHDBOP SFTY P Held AAR on well kill task- 0.0 0.0 14:00 14:30 Standardize the equipment removal and storage Page 1/10 Report Printed: 3/15/2016 0 . ,: Drilling Operations Summary (with Timelog Depths) &Welts 1F-01 iti- C onocoPhitl ps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/20/2015 11/20/2015 0.75 MIRU WHDBOP MPSP P Pressure up on the BPV in direction of 0.0 0.0 14:30 15:15 flow to 1,000 psifor 10 minutes.- Good test. 11/20/2015 11/20/2015 1.75 MIRU WHDBOP NUND P PJSM, Bleed pressure off SSSV 0.0 0.0 15:15 17:00 control line and adapter. Break bolts on the master valve and adapter. Break adapter. 11/20/2015 11/20/2015 1.00 MIRU WHDBOP OTHR P Remove tree from cellar and load 3- 0.0 0.0 17:00 18:00 1/2 x 6"VBR's in cellar to be installed in the UPR's. 11/20/2015 11/20/2015 3.00 MIRU WHDBOP NUND P NU BOPE and install 3-1/2 x 6 VBR's 0.0 0.0 18:00 21:00 in the UPR's cavities. Install mouse hole and riser. 11/20/2015 11/20/2015 2.50 MIRU WHDBOP RURD P PJSM,RU testing equipment,Grease 0.0 0.0 21:00 23:30 choke manifold, HCR's and Kill valves. 11/20/2015 11/21/2015 0.50 MIRU WHDBOP BOPE T Conduct Initial BOP test as per Sundry 0.0 0.0 23:30 00:00 #315-670 @ 250/2,500 psi 24 hr Notice was given to AOGCC @ 6:11 hrs on 11-18-15 and Right to witness was waived by Bob Noble @ 17:48 hrs on 11-18-15. Conduct test#1 Blind Rams,CM 1,2,3, 16 and HCR Kill,Upper!BOP and mud manifold. fail 11/21/2015 11/21/2015 2.50 MIRU WHDBOP BOPE T Continue to chase surface leaks and 0.0 0.0 00:00 02:30 found 2"Demco-failed. Regrease HCR Kill. Page 2/10 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) Drilling • 1F-01 Conor l+hilgps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 11/21/2015 11/21/2015 7.50 MIRU WHDBOP BOPE P Conduct Initial BOP test as per Sundry 0.0 0.0 02:30 10:00 #315-670 @ 250/2,500 psi 24 hr Notice was given to AOGCC @ 6:11 hrs on 11-18-15 and Right to witness was waived by Bob Noble @ 17:48 hrs on 11-18-15. Conduct test#1 Blind Rams,CM 1,2,3, 16 and HCR Kill, Upper IBOP and mud manifold. Test#2 CM 4,5,6, Manual Kill, Lower IBOP. Test#3 CM 7,8,9,and 4-1/2 EUE 8rd FOSV RD testing equipment and Blow down top drive. Test#4 Manual and Hydraulic Super Choke, Test#5 CM 10,11, Test#6 CM 12,13, 14 Test#7 MU 5-1/2 test joint w/HT 40 FOSV, Dart and head pin. MU to FMC blanking plug w/LH thread. test CM #15,Annular,Dart Valve,HCR Kill Test#8 3-1/2 x 6"UPR's,HCR Choke,and 2"Demco kill- Passed Change out to 2-7/8 Test joint Test#9 2-7/8 Test joint in Annular,Manual Choke valve,HT 40 FOSV. Test#10 2-7/8 Test joint in2-7/8 x 5"LPR's, HCR Kill and Choke valve, HT 40 FOSV. Change out to 4-1/2 test jt. Test#11 4-1/2 test in 2-7/8 x 5"LPR's, Manual Kill and Choke valve,HT 40 FOSV. Test#12 4-1/2 test in Annular, Outer test spool valve, HT 40 FOSV,CM 8,12,13 Test#13 4-1/2 test in 3-1/2 x 6 UPR's, HCR Kill, Inner test spool valve,HT 40 FOSV, Koomey Test Initial Pressure 2,950 psi After Closure 1,600 psi 200 psi Attained 35 seconds Full psi Attained 157 seconds 6-N2 bottles AVE 2,008 psi 11/21/2015 11/21/2015 0.50 MIRU WHDBOP RURD P Lay down test joint,cross over subs, 0.0 0.0 10:00 10:30 blow down test lines. 11/21/2015 11/21/2015 1.50 MIRU WHDBOP RURD P Pull blanking plug and BPV. 0.0 0.0 10:30 12:00 Page 3/10 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) 2 1F-01 ConocssPhffh�ss Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2015 11/22/2015 12.00 COMPZN RPCOMP SLKL X Held PJSM with Halliburton Slick line 0.0 0.0 12:00 00:00 crew. PU and MU 4-1/2 NS CT pin x 4-1/2 IBTM landing joint. MU 4-1/2 FOSV on top with 4"Otis head pin. RU HES Pump in sub,followed with Wire Line BOP's. PU Lubricator and MU tool string to rope socket. RU Flapper valve indicator to tool string, PT lubricator to 2,500 psi. RIH to SSSV @ 2,400-ft and verify open. POOH and change to X-Equalizer, PT lubricator-2,500 psi-good test. RIH to 6,042-ft with 1,500 pressure held, Pull X equalizer dart-equalize well- flowing back @ 1 BPM @ 290 psi. POOH and Change over to 4"GS Spear. PT lubricator @ 2,500 psi. RIH to 6,042-ft and engage X plug body and POOH. Well bore pressure at 18:22 hrs-350 psi and at 19:30 hrs 695 psi. MU DPU and 4-1/2 Paragon II Packer Retrievable Bridge Plug w/ 3.76"Maximum OD. PT lubricator© 2,500 psi -Good Test. Open up to well,RIH to 3,300-ft,POOH and reassess the following plan do to ID's and OD's. Lay down DPU tool and RBP. RD wire line tools and restring while discussing options with town engineers as this well is a category II well and we will be landing the 5-1/2 Inner casing string on E-Slips and ND BOPE for pack off setting and additional TBG spool addition.- Decision was made to up size the SBE from a 80-32 w/3.25"ID to a 80- 40 with a 4"ID. RU again w/ the DPU and 4-1/2 Paragon II Packer Retrievable Bridge Plug w/3.76" Maximum OD. PT lubricator @ 2,500 psi -Good Test. Open up to well, RIH to 4,000-ft as of Mid night. 11/22/2015 11/22/2015 3.00 COMPZN RPCOMP SLKL X Continue to RIH with DPU and RBP 0.0 0.0 00:00 03:00 from 4,000-ft to 6,167-ft and set 4-1/2 Paragon II Packer Retrievable Bridge Plug w/3.76"Maximum OD.Top at 6,156 to 6,183-ft. POOH and lay down setting tools. 11/22/2015 11/22/2015 5.00 COMPZN RPCOMP KLWL X PJSM on killing well with SICP of 790 0.0 0.0 03:00 08:00 psi. Bleed pressure off well and started flowing back diesel. Close in well, Pump 50 bbls to load hole and pressure up to 1,000 psi and chart for 15 minutes-good test. Bleed back 12 bbls of gas and diesel cut until 9.1 ppg brine recovered at sample catcher, then pumped 42 bbls until good 9.1 at surface. Lost 4.8 bbls to gas displacement. PT well bore to 2,500 psi and chart for 15 minutes.-Good test. Bleed off and blow down lines. 11/22/2015 11/22/2015 0.50 COMPZN RPCOMP OWFF X Monitor well for flow. No flow 0.0 0.0 08:00 08:30 Page 4/10 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) &Wells 1F-01 ConocoPhiliips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/22/2015 11/22/2015 0.50 COMPZN RPCOMP RURD X Blow down all circulation lines and RD 0.0 0.0 08:30 09:00 circ lines. 11/22/2015 11/22/2015 3.00 COMPZN RPCOMP SLKL X PJSM, RD slickline from the rig floor. 0.0 0.0 09:00 12:00 11/22/2015 11/22/2015 0.75 COMPZN RPCOMP PULL P PJSM, BOLDS, unseat hanger at 6,098.0 6,068.0 12:00 12:45 130K and pull seals from 15-ft Tie back sleeve. 100K UP wt,73K Dn wt. 11/22/2015 11/22/2015 1.25 COMPZN RPCOMP CIRC P Circulate at 5 bpm at 275 psi for 202 6,068.0 6,068.0 12:45 14:00 bbls,shut down- well still flowing, CBU,monitor well-no flow. Blow down Top drive. 11/22/2015 11/22/2015 1.00 COMPZN RPCOMP RURD P RU pipe handling equipment,control 6,068.0 6,068.0 14:00 15:00 line spooling unit and prep work area for laying down 4-1/2 12.6#Tubing. 11/22/2015 11/22/2015 6.00 COMPZN RPCOMP PULL P POOH laying down TBG hanger„ 6,068.0 3,689.0 15:00 21:00 space out pups,and 75 jts 4-1/2, 12.6#, L-80 IBTM Tubing,and Camco TRM-4PE-CF SSSV. Recovered 80 SS Bands-Norm all control line equipment pulled. 11/22/2015 11/22/2015 1.00 COMPZN RPCOMP RURD P Offload control line spooling unit and 3,689.0 3,689.0 21:00 22:00 equipment from the rig floor. 11/22/2015 11/23/2015 2.00 COMPZN RPCOMP PULL P Continue to POOH with 4-1/2, 12.6#,L 3,689.0 800.0 22:00 00:00 -80 IBTM Tubing and jewelry recovered from 3,689-ft to 800-ft. 11/23/2015 11/23/2015 1.25 COMPZN RPCOMP PULL P Continue to POOH with 4-1/2, 12.6#, L 800.0 0.0 00:00 01:15 -80 IBTM Tubing and jewelry recovered from 800-ft. 11/23/2015 11/23/2015 2.00 COMPZ1 RPCOMP RURD P Change over equipment to RIH w/5- 0.0 0.0 01:15 03:15 1/2 Inner liner as per run order. 11/23/2015 11/23/2015 1.25 COMPZ1 RPCOMP PUTB P PU,MU and RIH w/5-1/2 Inner Liner 0.0 89.0 03:15 04:30 completion as per run order. PU,MU and RIH w/seal assembly,SBE and 1 joint of 5-1/2", 15.5#,L-80, BTC-M to 89-ft. Tongs failed 11/23/2015 11/23/2015 1.50 COMPZ1 RPCOMP RURD T Weatherford tongs failed- swap out 89.0 89.0 04:30 06:00 11/23/2015 11/23/2015 7.75 COMPZ1 RPCOMP PUTB P PJSM, Run 5-1/2, 15.5#,L-80, BTC- 89.0 6,085.0 06:00 13:45 M,R-3 casing to Tie back sleeve,MU head pin,X-O sub in jt#142. Locate tie back @ 6,086-ft insert seals and No-Go at 6,101-ft. PU 16-ft to 6,085-ft 11/23/2015 11/23/2015 1.00 COMPZ1 RPCOMP CRIH P Reverse Circulate 35 bbls of CI 9.1 6,085.0 6,085.0 13:45 14:45 Brine at 2 bpm @ 377 psi,chase with 3 bbls of Neat 9.1 ppg Brine to clear lines. 11/23/2015 11/23/2015 1.00 COMPZ1 RPCOMP FRZP P PJSM, RU Little Red Services,PT 6,085.0 6,085.0 14:45 15:45 lines at 2,500 psi to IA and Reverse Circulate 22 bbls of diesel following CI 9.1 ppg NaCI. Slide through Annular and insert seals in tie back. Open IA valve and drain stack. 11/23/2015 11/23/2015 0.25 COMPZ1 RPCOMP PRTS P Open Annular and insert seals to No- 6,085.0 6,100.0 15:45 16:00 Go. Pressure test 5-1/2 casing to RBP at 2,500 psi for 15 minutes- good test. Bleed off. Page 5/10 Report Printed: 3/15/2016 • • ,. priming Operations Summary (with Timelog Depths) y{ &Wells 1F-01 CorPhillips Awkp Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/23/2015 11/23/2015 2.00 COMPZ1 WHDBOP OTHR P PJSM, RD Casing equipment and 6,100.0 6,100.0 16:00 18:00 clear floor. Blow down lines,change out elevators. Drain BOP stack through the IA and suck down fluid level in 5-1/2 Casing to remove fluid to below cut depth. 11/23/2015 11/23/2015 2.50 COMPZ1 WHDBOP NUND P Remove Turn buckles,pull riser, 6,100.0 6,100.0 18:00 20:30 Mouse hole and Lock out Accumulator. ND Stack at 3 flanges- DSA/well head,DSA/Test spool and Test spool/Single Gate. Lift BOPE. 11/23/2015 11/23/2015 2.00 COMPZ1 WHDBOP CUTP P Hang off 5-1/2"15.5#, L-80,BTC-M 6,100.0 0.0 20:30 22:30 R3 Casing in Emergency slips at 110K Wt indicator wt-35k block wt=75K string wt.as per FMC rep. Cut and remove 33.93-ft of Jt#142-5-1/2 csg stub from well,Rack BOPE. 11/23/2015 11/24/2015 1.50 COMPZ1 WHDBOP WWSP P Clean and dress casing stub to accept 0.0 0.0 22:30 00:00 pack-off. Install pack off. 11/24/2015 11/24/2015 1.00 COMPZ1 WHDBOP WWSP P NU new 11"5M x 11"5M FMC Gen V 0.0 0.0 00:00 01:00 tubing head per FMC rep. 11/24/2015 11/24/2015 0.50 COMPZ1 WHDBOP PRTS P PT 5-1/2"x 7"pack off test at 250/ 0.0 0.0 01:00 01:30 4,990 psi(70%of Collapse). 11/24/2015 11/24/2015 3.00 COMPZ1 WHDBOP NUND P NU BOPE and tighten flanges,tighten 0.0 0.0 01:30 04:30 turnbuckles install riser and mouse hole. 11/24/2015 11/24/2015 1.00 COMPZ1 WHDBOP RURD P RU BOPE testing equipment. Install 0.0 0.0 04:30 05:30 test plug 11/24/2015 11/24/2015 1.00 COMPZ1 WHDBOP BOPE T Shell test BOP stack to 250/2,500 0.0 0.0 05:30 06:30 psi. Test plug not holding. Pull test plug,replace the rubber,and re-install test plug. 11/24/2015 11/24/2015 0.50 COMPZ1 WHDBOP RURD P PJSM. RU to PT the 5-1/2"x 7" 0.0 0.0 06:30 07:00 annulus(new OA) 11/24/2015 11/24/2015 1.00 COMPZ1 WHDBOP PRTS P PT 5-1/2"x 7"annulus to 2,500 psi for 0.0 0.0 07:00 08:00 30 minutes on chart-Good test 11/24/2015 11/24/2015 1.25 COMPZ1 WHDBOP BOPE T PJSM, PT breaks on BOPE and well 0.0 0.0 08:00 09:15 head install along with 3 1/2 EUE 8rd FOSV @ 250/2,500 psi. Found leaking ports on tree and HCR kill. Tightened the leaking port on the tree. Greased HCR and Manual Kill. Change line up to choke side and pump up senator. 11/24/2015 11/24/2015 0.25 COMPZ1 WHDBOP BOPE P Re-test the breaks on BOPE and well 0.0 0.0 09:15 09:30 head install along with 3 1/2 EUE 8rd FOSV @ 250/2,500 psi. Good test. 11/24/2015 11/24/2015 0.50 COMPZ1 WHDBOP RURD P Pull test plug,RD BOPE testing 0.0 0.0 09:30 10:00 equipment,and blow down lines. 11/24/2015 11/24/2015 0.50 COMPZ1 RPCOMP SLKL P PJSM. PU and install Dutch riser. 0.0 0.0 10:00 10:30 11/24/2015 11/24/2015 2.75 COMPZ1 RPCOMP SLKL P PJSM with the HES slickline crew and 0.0 0.0 10:30 13:15 rig crew. RU slickline, PU slickline tools,and RU slickline lubricator with extensions. 11/24/2015 11/24/2015 0.25 COMPZ1 RPCOMP SLKL P PT lubricator,Dutch riser,and lines to 0.0 0.0 13:15 13:30 2500 psi(good test). Page 6/10 Report Printed: 3/15/2016 • • Cig Operations Summary (with Timelog Depths) Wells 1F-01 conocoPhittips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/24/2015 11/24/2015 2.00 COMPZ1 RPCOMP SLKL P RIH with slickline and attempted 0.0 0.0 13:30 15:30 several times to equalize across the RBP but were unsuccessful. POOH with equalizing prong. 11/24/2015 11/24/2015 0.50 COMPZ1 RPCOMP SLKL T Attempt to equalize the RBP with 0.0 0.0 15:30 16:00 tubing pressure but were unsuccessful. 11/24/2015 11/24/2015 1.75 COMPZ1 RPCOMP SLKL T Add 5'weight bar to the tool string, 0.0 0.0 16:00 17:45 RIH with equalizing prong,and attempted several times to equalize across the RBP but were unsuccessful. POOH with equalizing prong and lay down. 11/24/2015 11/24/2015 1.25 COMPZ1 RPCOMP SLKL T MU and RIH with GS spear to retrieve 0.0 0.0 17:45 19:00 the RBP. Engage the RBP,attempt to release,not releasing,and POOH with GS spear. GS spear packed off with mud. 11/24/2015 11/24/2015 2.50 COMPZ1 RPCOMP SLKL P Redress the GS spear, MU into tool 0.0 0.0 19:00 21:30 string, PT the lubricator to 2500 psi, blow down kill line,and RIH with GS spear. Engage RBP,jar free,and POOH. Recovered the RBP and all elements. RBP full of mud. 11/24/2015 11/24/2015 1.00 COMPZ1 RPCOMP SLKL P RD HES slickline sheave, RD 0.0 0.0 21:30 22:30 lubricator, lay down lubricator,clear floor of slickline tools, RD surface lines,pull Dutch riser, lay down Dutch riser. 11/24/2015 11/24/2015 0.50 COMPZN RPCOMP RURD P RU Weatherford tubing tongs,RD 4" 0.0 0.0' 22:30 23:00 DP elevators,and RU 2-7/8"tubing elevators. 11/24/2015 11/24/2015 0.50 COMPZN RPCOMP SFTY P PJSM with crew and thrid party hand 0.0 0.0 23:00 23:30 for running 2-7/8"tubing completion. 11/24/2015 11/25/2015 0.50 COMPZN RPCOMP PUTB P PU and MU seal assembly and 1 joint 0.0 57.0 23:30 00:00 of 2-7/8"tubing. 11/25/2015 11/25/2015 7.25 COMPZN RPCOMP PUTB P PU and MU nipple assembly, 1 joint of 57.0 6,043.0 00:00 07:15 2-7/8"tubing,GLM assembly with SOV and RIH with 2-7/8"tubing per tally 6043'RKB. 11/25/2015 11/25/2015 1.75 COMPZN RPCOMP RURD T Bring 3.5"elevator to the rig floor and 6,043.0 6,043.0 07:15 09:00 RU,MU crossover,and RU circulating equipment. The elevators are the wrong style,RD circulating equipment, and change back to 2-7/8"elevators. 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP HOSO P RIH,engage the seals into the SBE, 6,043.0 6,059.0 09:00 10:00 locate out on the SBE,and mark the pipe for space out(PU=63K,SO= 55K). 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP HOSO P Lay down 3 joints of 2-7/8"tubing, MU 6,059.0 6,033.0 10:00 11:00 two 10'pup joints,and 1 joint of 2-7/8" tubing. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP RURD P RU circulating equipment and change 6,033.0 6,033.0 11:00 11:30 elevators to 3-1/2". 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP THGR P MU landing joint,tubing hanger,and 6,033.0 6,033.0 11:30 12:00 crossover. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP SFTY P PJSM for circulating corrosion 6,033.0 6,033.0 12:00 12:30 inhibited brine with crew and third party hands. Page 7/10 Report Printed: 3/15/2016 • ! `~ � - Operations Summary (with Timelog Depths) &We 1F-01 [onocoPhitlips 5.tvska Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP CRIH P Reverse circulate 135 bbls of 9.1 ppg 6,033.0 6,033.0 12:30 13:30 corrosion inhibited brine down the IA taking returns up the tubing at 3.5 BPM=420 psi. 11/25/2015 11/25/2015 1.25 COMPZN RPCOMP THGR P Drain the BOP stack,land the tubing 6,033.0 6,052.0 13:30 14:45 hanger and RILDS. 11/25/2015 11/25/2015 0.25 COMPZN RPCOMP RURD P Blow down circulating lines. Break off 0.0 0.0 14:45 15:00 circulating equipment. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP WAIT P Drop the ball&rod and allow time for 0.0 0.0 15:00 15:30 it to fall to seat. MU circulating equipment. 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP PRTS T Attempt to pressure test the tubing to 0.0 0.0 15:30 16:30 3000 psi but there was a leak at the connection between the TIW and pup joint. Attempted to re-test and connection still leaked. Break out the pup joint and MU the TIW with head pin to the landing joint. 11/25/2015 11/25/2015 1.50 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 15 0.0 0.0 16:30 18:00 minutes(good test). Bleed the tubing to 1500 psi and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Quickly pressure up on the IA to shear the SOV(sheared at 2600 psi). Bleed the pressure to 0 psi. 11/25/2015 11/25/2015 1.00 COMPZN RPCOMP OWFF T Open up the tubing and IA to the pits 0.0 0.0 18:00 19:00 and observed slight flow. Line up the tubing to the trip tank,open up the tubing to the trip tank,and no flow. The IA still had slight flow to the pits. Open the IA to atmosphere,slight flow,and then no flow. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP OWFF P Monitored the well for flow for 30 0.0 0.0 19:00 19:30 minutes and the well is static. 11/25/2015 11/25/2015 0.50 COMPZN RPCOMP RURD P RD pressure testing equipment,TIW, 0.0 0.0 19:30 20:00 and head pin. Lay down landing joint and drain the BOP stack. 11/25/2015 11/25/2015 0.50 COMPZN WHDBOP MPSP P Install 3"'H'BPV. Pressure up on the 0.0 0.0 20:00 20:30 IA to 1000 psi to test the BPV from below in the direction of flow for 10 minutes(good test). Bleed pressure to 0 psi and blow down line. 11/25/2015 11/25/2015 1.00 COMPZN WHDBOP NUND P RD all circulating valves and lines in 0.0 0.0 20:30 21:30 the cellar. Pull the riser, pull the mouse hole,and lay down the mouse hole. 11/25/2015 11/25/2015 0.50 COMPZN WHDBOP SVRG P Perform CPAI BOPE inspection per 0.0 0.0 21:30 22:00 CPAI Between Well Maintenance (BWM)program. Install 4"joint of tubing and function annular checking for excessive wear and overall condition(photos taken of annular). 11/25/2015 11/25/2015 0.50 COMPZN WHDBOP SVRG P CPAI BOPE inspection per CPAI 0.0 0.0 22:00 22:30 BWM program: Break bolts on upper ram doors,open doors,and function ram piston to the closed position. Inspect ram cavities,sealing surfaces, and door seals. Inspect 3-1/2"x 6" VBR's upper seal and front packer assembly. Page 8/10 Repoli:Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) &Wells 1F-01 ConocoPhitlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/25/2015 11/25/2015 0.50 COMPZN WHDBOP SVRG P Change upper rams to 2-7/8"x 5"and 0.0 0.0 22:30 23:00 change the door seals on both doors. Close upper ram doors and tighten bolts(photos taken of all components and of stack cavities). 11/25/2015 11/26/2015 1.00 COMPZN WHDBOP SVRG P CPAI BOPE inspection per CPAI 0.0 0.0 23:00 00:00 BWM program: Break bolts on blind ram doors,open doors,and function ram piston to the closed position. Inspect ram cavities,sealing surfaces, and door seals. Change the door seals on both sides. Inspect blind upper seal and front packer assembly. Close blind ram doors and tighten bolts(photos taken of all components and of stack cavities). 11/26/2015 11/26/2015 1.00 COMPZN WHDBOP SVRG P CPAI BOPE inspection per CPAI 0.0 0.0 00:00 01:00 BWM program: Break bolts on lower ram doors,open doors,and function ram piston to the closed position. Inspect ram cavities,sealing surfaces, and door seals.Change the door seal on the driller side door. Inspect piston and rod wear plate. Inspect 2-7/8"x 5"VBR's upper seal and front packer assembly. Attempt adjust the driller side door but adjustment bolt is maxed out. Close lower ram doors and tighten bolts(photos taken of all components and of stack cavities). 11/26/2015 11/26/2015 3.00 COMPZN WHDBOP RGRP T Attempt to change out packing on the 0.0 0.0 01:00 04:00 HCR kill but unable to do it. Remove HCR kill from the BOP stack. 11/26/2015 11/26/2015 1.00 COMPZN WHDBOP NUND P ND the BOP stack,rack back on the 0.0 0.0 04:00 05:00 stump,and secure to the stump. 11/26/2015 11/26/2015 3.50 COMPZN WHDBOP NUND P NU the tubing head adapter and NU 0.0 0.0 05:00 08:30 the tree. Verified orientation with DSO. 11/26/2015 11/26/2015 0.25 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 08:30 08:45 psi. 11/26/2015 11/26/2015 1.00 COMPZN -WHDBOP RURD P PJSM,RU to test tree with Little Red 0.0 0.0 08:45 09:45 Services(LRS). 11/26/2015 11/26/2015 1.00 COMPZN WHDBOP SEQP P PT lines to 5,000 psi,working flange 0.0 0.0 09:45 10:45 leaked on production valve,Tighten valve and PT lines to 5,000 psi(good test). Bleed off pressure. 11/26/2015 11/26/2015 1.00 COMPZN WHDBOP MPSP P PJSM. RU lubricator and PT to 2500 0.0 0.0 10:45 11:45 psi(good test). Lubricate out BPV. Shut master valve. 11/26/2015 11/26/2015 0.50 COMPZN WHDBOP MPSP T Install TWC but the threads were bad 0.0 0.0 11:45 12:15 on the TWC. FMC traveled to the valve shop for a new one. 11/26/2015 11/26/2015 0.75 COMPZN WHDBOP MPSP P RU lubricator and PT to 2500 psi 0.0 0.0 12:15 13:00 (good test). Install TWC. 11/26/2015 11/26/2015 0.50+COMPZN WHDBOP PRTS P PT tree to 250/5000 psi against TWC 0.0 0.0 13:00 13:30 (good test). Page 9/10 Report Printed: 3/15/2016 • t�riil Operations Summary (with Timelog Depths) :__i &Wells 1F-01 ConocoPhitlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2015 11/26/2015 0.75 COMPZN WHDBOP MPSP P RD lubricator,change over to pulling 0.0 0.0 13:30 14:15 tool,RU lubricator,PT lubricator to 2500 psi(good test),lubricate out the TWC,and RD lubricator. 11/26/2015 11/26/2015 1.25 COMPZN WHDBOP FRZP P PJSM. RU LRS to freeze protect the 0.0 0.0 14:15 15:30 well with diesel. PT the hard line to the kill tank with air(good test). PT LRS line and cellar lines to 2500 psi (good test). 11/26/2015 11/26/2015 0.75 COMPZN WHDBOP FRZP P Freeze protect the well with diesel by 0.0 0.0 15:30 16:15 pumping 50 bbls of diesel down the IA taking returns out the tubing at 2 BPM = 1150 psi(FCP). Shut down and shut in the well. 11/26/2015 11/26/2015 0.50 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 16:15 16:45 communication allowing the well to u- tube and equalize.Tubing and IA pressure=200 psi. 11/26/2015 11/26/2015 1.00 COMPZN WHDBOP MPSP P RU lubricator, PT to 2500 psi(good 0.0 0.0 16:45 17:45 test),install 3"'H'BPV,and RD lubricator. 11/26/2015 11/26/2015 0.50 DEMOB MOVE FRZP P RD LRS. 0.0 0.0 17:45 18:15 11/26/2015 11/26/2015 1.75 DEMOB MOVE RURD P Blown down lines, RD cellar lines, RD 0.0 0.0 18:15 20:00 annulus valve, Install FMC manifold, secure well,and secure cellar. Final well pressures: Tbg=300 psi, IA= 200 psi,OA=50 psi,and OOA= 150 psi. Release the rig at 20:00 hours. • Page 10/10 Report Printed: 3/15/2016 0 III ' :ti oF/Ty� THE STATE Alaska Oil and Gas ��'�►-��—�� ¢' Conservation Commission It ? L A S KA. 333 West Seventh Avenue I: Anchorage, Alaska 99501-3572 iliitr , _I GOVERNOR BILL WALKER Main: 907.279.1433 wh.` 0,k, .0., Fax: 907.276.7542 www.aogcc.alaska.gov Diana Guzman •• � nib Sr. Wells Engineer ConocoPhillips Alaska, Inc. SatigiEVI0 5 OJ J P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1F-01A Sundry Number: 315-670 Dear Ms. Guzman: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, '� Cathy P. oerster ca&-. Chair DATED this U day of November, 2015 Encl. RBDMS Nov 0 9 2015 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI ION OCT 2 7 2015 APPLICATION FOR SUNDRY APPROVALS itxtyy, 20 AAC 25.280 1.Type of Request: Abandon Plug Perforations I Fracture Stimulate I.._ Pull Tubing ( Operations Shutdown f I Suspend P Perforate 1- Other Stimulate -- Alter Casing F • Change Approved Program I Plug for Redrill -- Perforate New Pool _ Repair Well IFv Re-enter Susp Well r Other: i 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory [.. Development �' 205-029 • 3.Address: 6.API Number: Stratigraphic P Service I P.O. Box 100360,Anchorage,Alaska 99510 50-029-20889-01 - 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No ±[ KRU 1F-01A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25652 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): 10533 - 6174 - 'j3C31 (p040 Casing Length Size MD TVD Burst Collapse CONDUCTOR 45 16 80' SURFACE 2603 10.75 2637' PRODUCTION 6221 7 6253' WINDOW AL1 7 4.5 8255' LINER A TOP 2249 4.5 8335' SLOTTED LINER A 2232 2 7/8 10474' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8426'-10439'Slotted Liner - 6102'-6172' 4.5 L-80 6100 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SAFETY VLV-CAMCO TRM-4PE-CF SAFETY VALVE MD=2400 TVD=2083 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program l BOP Sketch Exploratory Stratigraphic Developments Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/16/2015 - Suspended 3..... OIL �� • WINJ � WDSPL p 16.Verbal Approval: Date: GAS WAG I GSTOR 1- SPLUG Commission Representative: GINJ Op Shutdown P Abandoned I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Diana @ 265-6318 Email: Diana.Guzman@conocophillips.con Printed Name Diana Guzman Title: Sr. Wells Engineer Signature --� 11 Phone:265-6318 Date I 0 I 2.7 r S (l/ Commission Use Only SundryNum ( ber:/ Conditions of approval: Notify Commission so that a representative may witness 15 ^. "I 0 ' Plug Integrity P BOP Test l" Mechanical Integrity Test P Location Clearance " 5 c p fit5_)' fv Z5-e)o�//)5r �j (A/[05/-) /S 2041 p.51 Other O Z 5-0C-)/7,1„, /fyLnv/arPr-r. 17tt7-r- S-� fi Spacing Exception Required? Yes ❑ No P Subsequent Form Required: `0 — 4-0 4 alek,7/764- 14*L'' APPROVED BY // 2 _Approved by: _ COMMISSIONER THE COMMISSION Date: (/. " - /'SVTL !�� yl/S ApaR i is li or 12 mo ` from1o��Idast approval./ RB pdd 0 9 2015 Form 10-403 Revised 5/2015 'v H /`(04,57, Attachments • • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 OCT 2 5 ANCHORAGE,ALASKA 99510-0360 October 20,2015 AOGCC Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to workover the Kuparuk Well 1F- OlA(PTD#205-029). Well 1F-01A was sidetracked and coil tubing drilled in 2005 from the existing 1F-01 wellbore to re-access the A and C sands. The mother bore was shut-in in 1999 due to a toolstring stuck above the 'A' sand at 8280'. Several attempts to retrieve the fish by slickline and coil tubing were unsuccessful. A leak detect log ran in 2004 identified two tubing leaks at 7716' and 7742'. 1F-01A has IAxOAxOOA communication on gas since 2006.The internal and outer hanger leaks were diagnosed as the cause and a seal tite treatment was performed in 2008 unsuccessfully. Additionally, a noise log ran in 2009 indicated a possible leak at 2200' (IAxOA). The repeat passes and stop counts were unable to make a positive confirmation of the leak. Several tests were performed on liquid in 2012 and 2013 and it was concluded that 1F-01A has no IAxOAxOOA communication on liquid but on gas. Prior to being shut-in in 2009 due to the annular communication on gas,well 1F-01A production rate was 144 BOPD. The purpose of this workover is to repair the annular communication on gas on 1F-01A. This will be accomplished by pulling the existing 4 'h" tubing and replacing it with a 5 '/2" liner and 2 '/8" tubing. This sundry is intended to document the proposed work on the producer well,as well as request approval to workover 1F-01A. If you have any questions or require any further information,please contact me at 907-265-6318. Sincere y, ...4.4.1.txxx-y147-1_______-- iana Guzman Wells Engineer CPAI Drilling and Wells • • 1F-01A Rig Workover Pull 4 1/2" Tubing, Install 5 '/z" Liner w/2 '/g" Tubing (PTD #: 205-029) Current Status: This well is currently shut in and awaiting pre-RWO well work. Scope of Work: • Pull and replace 4 '/2"tubing. • Install 5 '/2"liner to surface and 2'/8"tubing. General Well info: Well Type: Producer MPSP: 2041 psi using 0.1 psi/ft gradient(Most recent SBHP=2633 psi on 01/11//14) ✓ Reservoir Pressure/TVD: 2633 psi/5920' TVD(8.5 ppg)on 01/11//14 Wellhead type/pressure rating: FMC Gen I/5M psi TH,3M Csg Hd. BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: MIT—T failed January 13,2014 MIT—IA passed December 20,2013 MIT—OA passed August 25,2015 Earliest Estimated Start Date: November 16,2015 Drillsite Petroleum Engineer: Amanda Patterson Workover Engineer: Diana Guzman Work:265-6318 E-mail:Diana.Guzman@conocophillips.com Pre-Rig Work 1. Pull plug at 6042', obtain a new SBHP. Dummy off all GLM's leaving bottom GLM open for circulation. Lock out SSSV. 2. PT tubing and casing packoffs,FT LDS's. 3. Set BPV. Proposed Procedure: 1. MIRU 2. Pull BPV. Circulate workover fluid. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug or two-way check,PT from below if possible.ND tree,NU BOPE&test to 2500 psig. 4. Pull blanking plug&BPV. Screw in landing joint,BOLDS's,and pull tbg hgr to the rig floor. 5. POOH laying down 4 Y2"tubing.If tubing will not pull free,RU E-line: Cut the tubing.RDMO E-line. 6. While pulling out of hole, MU storm packer. Set storm packer at—500'. NDBOP & Tbg head. NU new csg head and test packoffs.NU BOP&test.Pull storm packer. 7. LD rest of the 4 '/2"tubing. 8. RIH with new 5 '/2"liner to SBE. 9. Slowly cycle the charge pump and look for pressure increase as the seals engage the SBE. Shut down charge pump. Space out,mark the pipe,and pull out of SBE. 10. Space out w/pups,MU hanger. Spot a balanced pill of corrosion inhibited brine.Land the hanger.RILDS. 11. MU 5 '/2"RBP and hydraulic setting tool on 2 '/8"tubing. TIH to 50'and set RBP. Test casing and perform a drawdown. ND BOPE. Cut excess casing off, install packoffs, NU tbg head. Test csg packoffs. NU and test BOPE. • i 1F-01A Rig Workover Pull 4 1/2" Tubing, Install 5 1/2" Liner w/ 2 '/8" Tubing (PTD #: 205-029) 12. TIH on 2 7/8"tubing and latch on to RBP fishing neck.Release and retrieve RBP. TOOH laying down RBP 13. RIH w/ new 2 '/8" tubing and seal assembly to just above the SBE. Engage the seal locator until fully located,space out 7'mark the pipe and pull out of the SBE. 14. Spot a balanced pill of corrosion inhibited completion fluid. 15. Install space out pups below the hanger,MU hanger. Land the hanger,RILDS.✓ 16. PT the tubing and IA.Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing joint, install two-way check.PT two-way check through IA. 18. ND BOPE,NU tree. Pull BPV,install tree test plug. Test tree. Pull tree test plug. 19. Freeze protect well. 20. Set BPV. 21. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Run GLD replace w/DV. Set up for production. 4. Handover to Ops to put back on injection. • 1 F-01A ConocoPhiHups Proposed Completion 5 '/2" Liner to Surface with 2 78" 16"65.0#, H-40 to 80' MD Tbg 10 3/4" 45.5#, L-80 to 2637' MD -41-- 2 Ye", 6.5#, L-80 EUE-8RD Tbg -4-- 51/2' 15.5#, L-80, BTCM SCC -4-- 2'/8" x 1 MMG Production Mandrel 2'/e"x 1 MMG Production Mandrel 411-- 2'/8" x 1 MMG Production Mandrel - 2.313" DS Nipple Profile 1 ir.4- Baker 80-32 LTSA i•• i 4 Baker ZXP Liner Packer @ 6086' MD 7" 26.0#, L-80 IBTM to 6253' MD i � A- & C-Sand. — . . — .� I . . — . . _ Laterals: Not � I detailed here _ I Date: October 10,2015 Drawn By: Diana Guzman Y KUP1101D 1F-01A ConocoPhillips 3 Well Attribu Max Angle D TD Alaska,In . Wellbore APIIUWI Field Name Wellbore Status nclV) MD(ftKB) Act Btm(ftKB) o .n,:Aiihps 500292088901 KUPARUK RIVER UNIT PROD 94.60 8,702.43 10,533.0 ... ,µ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date IF-01A,10/22/20154:18:31 PM SSSV:TRDP Last WO: 5/31/2005 40.59 1/23/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:RKB 8.478.0 10/17/2011 Rev Reason:DRILL DEPTHS/DATES osborl 4/24/2013 Casing Strings HANGER;345 li5� f Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread -'- CONDUCTOR 16 15.250 35.0 80.0 800 6500 H-40 WELDED I. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen p.Grade Top Thread SURFACE 10 3/4 9.950 34.3 2,636.9 2,221.5 45:5,1..0.. 50 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen p.,.Grade Top Thread PRODUCTION Post SIT 7 6.276 32.3 6,253.0 4,330.9 26.00 K-55 BTC MOD ,,,,__„�,�,�,-�,,,,,�,-,r-�,-,�,,,, , mLL Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread LINER A TOP 4 1/2 3.958 6,086.3 8,335.0 6,063.1 12.60 L-80 IBTM Liner Details CONDUCTOR;350-80.0 • Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn lin) 6,086.3 4218.3 48.83 PACKER BAKER ZXP LINER PACKER w/HOLDDOWNS-HR 3.875 PROFILE 6,110.7 4,234.5 48.50 HANGER BAKER FLEX-LOCK II HYDRAULIC LINER 3.958 HANGER SAFETY VLV,2,399.8_1,--t 6,120.1 4,240.7 48.35 XO BUSHING BAKER CROSSOVER BUSHING 3.970 Casing Description OD(in) ID(n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread WINDOW ALA 41/2 3.000 8248.0 8,255.0 6,0234 2600 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Slotted LINER A 2 7/8 2.441 8242.3 10,474.0 6,172A 6.16 L-80 STL Liner Details Nominal ID Top(ftKB) Top(TVD)IRKS) Top Incl V) Item Des Corn (in) 8.242.3 6,016.0 54.54 DEPLOY BAKER DEPLOYMENT SUB 3.000 SURFACE;34.3-2,636.9-. 14439.7 6,171.7 88.86 0-RING BOT 0-RING SUB 1.000 Tubing Strings Tubing DescriptionMa...ID(in) Top(BOB) Set Depth(ft..Set Depth(TVD)(...WI(Ibttt) Grade Top Connection GAS LIFT,3291.3: TUBING I String 41/21 3.5001 34.51 6,099.91 4, 227.31 12.601 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(TVD)(11013) Top Incl I') Item Des Corn (in) 34.5 34.5 0.03 HANGER FMC GEN V TUBING HANGER 4.500 2,399.8 2,083.2 54.29 SAFETY VLV CAMCO TRM-4PE-CF SAFETY VALVE 3.812 GAS LIFT,5.299.6 6,042.3 4,189.5 49.37 NIPPLE HALLIBURTON X NIPPLE 3.813 6,084.6 4,217.2 48.85 LOCATOR BAKER LOCATOR 3.880 6,085.6 4,217.9 48.84 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.940 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Corn Run Date ID(in) GAS LIFT,5.59e.3 6,042.3 4,189.5 49.37 PLUG SET 3.813"XX PLUG IN NIPPLE 10/17/2011 0.000 in8,248.0 6,019.3 54.62 WHIPSTOCK AU WEATHERFORD LSX WHIPSTOCK 5/31/2005 3.958 Perforations&Slots NIPPLE,6,042 2 PLUG;6,042.3-3 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,426.0 10,439.0 6,102.0 6,171.6 A-4,A-5,A-4, 5/31/2005 40.0 SLOTS Slotted Liner A-5,1F-01A LOCATOR,6,084.5 Mandrel Inserts .,r St ati SEAL ASSY;6,085.6 /.. 2 1 on Top(TVD) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn am at 1 3,291.3 2,598.7 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 6/8/2009 F. 2 5,299.6 3,739.7 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 4/11/2007 ` 3 5,998.3 4,161.0 CAMCO KBG-2 1 GAS LIFT DMY BK 0_000 0.0 4/11/2007 Notes:General&Safety 7- End Date Annotation PRODUCTION Post Sir, 5/31/2005 NOTE:MULTI-LATERAL WELL:SIDETRACK A-SAND 1F-01A C-SAND 1F-01AL1 8,253.0 ( �, ( ) 5/31/2005 NOTE:TREE:FMC 3-1/16"5M GEN V 9/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 i WHIPSTOCK,8,248.0 ' WINDOW AL1;8.2480-8,255.0 LINER A TOP;6.086.3-8,335.0 SLOTS;8,426.0-10,439.0 4F 6 Slotted LINER A,8,242.3- 44 10,474.0 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may bescanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q':¡- - O;l ç¡ Well History File Identifier Organizing (done) o Two-sided 1111111111111 11111I o Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA ~olor Items: 0 Diskettes, No. ~eYSCale Items: 1 p~ 0 Other, Norrype: o Poor Quality Originals: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date 1/¡e-/07 o Other:: BY: ~ 151 ¡M~ Project Proofing 1111111111111' ,,1/1 Date 111~/ 07 Isl VVlf Y- X 30 = IJ.:O + E--- = TOTAL PAGES I d. S- Date 7/ i d-. / 0 7 (Count does not ;~~,ulldlellclol,v,elrllsl h, elle,t,) YV\ ~ Production Scanning Page Count from Scanned File: / J. (P (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES (Mãriã) Date: 1/1 d- / 07 If NO in stage 1, page(s) discrepancies were found: BY: ~ Scanning Preparation BY: ~ Stage 1 Stage 1 YES NO 151 VV\ P NO BY: BY: Maria Date: 151 111/1111111I11 1111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111I11 "III BY: Maria Date: 151 Comments about this file: Quality Checked /111111111111111111 1 0/6/2005 Well History File Cover Page.doc .~.v ~. : A ~ / L ~etoAcrive !)iAyniostic S~evic~s, in~c. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ M?T) 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 InternaCional Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Leak Detection - WLD 03,JuF09 1 F-01 A EDE 50-029-20889-01 2) ~a~ 0~9 1~33~ PROACTIVE DIAONOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCtfORAGE, AK 99518 PHONE: (907)245-8951 FAx: (90T-245-88952 - E-NIAIL : '__~_~_~_ ____-_~_____: WEBSITE _e_` _~.._,._ ` C:~Documents and Settings\Ownet\Desktop\Transmit_Conoco.docx • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ' March 18, 2008 ~~~y~ l~.~A~ ~ ~~ ~~ • ~'~~~ ~ _ ' t / Y c ~~2® Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~i~~~~ os 6a ~~s ~r~~ ~~ ~~ Dear Mr. Maunder: ~ ~.-- , Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 13th, 2009. The corrosion inhibitor/sealant was pumped March 4th, 1 lth & 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Pen, ~~.,,.~~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/16/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-01A 205-029 7" N/A 7" N/A 1.7 3/16/2009 1 F-02 182-211 SF N/A SF N/A 2.90 3/4/2009 1F-03A 196-096 SF N/A SF N/A 2.20 3/4/2009 1 F-04 182-172 20" N/A 20" N/A 5.20 3/4/2009 1F-05 182-132 SF N/A SF N/A 1.60 3/4/2009 1 F-06 182-145 SF N/A SF N/A 2.10. 3/4/2009 1 F-07 182-156 SF N/A SF N/A 2.40 3/4/2009 1 F-08 182-162 SF N/A SF N/A 2.20 3/4/2009 1F-10 183-105 20" NA 20" NA 1.70 3/11/2009 1F-12 183-136 54' 7.50 5'6" 2/13/2009 18.70 3/11/2009 1F-13 183-144 SF NA 6" NA 1.30 3/11/2009 1F-16A 201-209 SF NA 22" NA 1.70 3/11/2009 • • WELL LOG TRANSMITTAL To: State of Alaska September 10, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1F-OlA PB1 AK-MW-367484 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1F-OlA PB1: Digital Log Images 50-029-20889-70 ~~;~~~ ~~~ 1 ~ ~~~% 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING~'Al\175 RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ ~ ~~ ~~~ _, ~.,, , , , L .. 1,l / / V Signed: ~o S -~~`j ~ ~ 5S l ~ II J~b DATA SUBMITTAL COMPL ANCE REPORT 7/2/2007 ~ :l4'A1p~ Permit to Drill 2050290 Well Name/No. KUPARUK RIV UNIT 1F-01A Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-20889-01-00 MD 10533 /' TVD 6174 /' Completion Date 6/11/2005 /' Completion Status 1-01L Cu rrent Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes _.~ DATA INFORMATION Types Electric or Other Logs Run: GRlRes, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: - Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED n Aco Directional Survey 4 10533 Open 7/14/2005 ~D Lis 13283 Induction/Resistivity 6154 8290 Open 9/26/2005 GR EWR4 ROP PWD pt 13283 LIS Verification 6154 8290 Open 9/26/2005 GR EWR4 ROP PWD ~ Production 5 Blu 2500 8230 Case 9/28/2005 Production Profile W/DEFT ~C 31 Jul 2005 .Pdfl.. \ S 13529 Rate of Penetration 6283 8336 Open 2/22/2006 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic ~ Wave Resistivity C Pdf 13529 Rate of Penetration 6283 8336 Open 2/22/2006 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ~ 14299 Gamma Ray 5 Blu 8255 10533 Open 12/28/2006 TVD MPR, GR 31-May-05 .: ~ 14299 Gamma Ray 5 Blu 8255 10533 Open 12/28/2006 MD MPR, GR 31-May-05 ~ 14299 LIS Verification 8259 10533 Open 12/28/2006 LIS Veri, GR, ROP, i w/Graphics C Lis 14299 Induction/Resistivity 8259 1 0533 Open 12/28/2006 LIS Veri, GR, ROP 14358 LIS Verification 6206 8336 Open 1/29/2007 PB1 LIS Veri, GR, FET, ~ ROP C Lis 14358 I nd uction/Resistivity 6206 8336 Open 1/29/2007 PB1 LIS Veri, GR, FET, ROP r;/ C Lis 14428 Induction/Resistivity 6154 8338 Open 1/29/2007 LIS VERI, GR, ROP w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050290 Well Name/No. KUPARUK RIV UNIT 1F-01A Operator CONOCOPHILLlPS ALASKA INC MD 10533 Completion Status 1-01L Current Status 1-01L TVD 6174 Completion Date 6/11/2005 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? 'V"NoL.. Daily History Received? &N (JJN Formation Tops Analysis Received? ~ Comments: I ' Compliance Reviewed By: ~ Date: ;< API No. 50-029-20889-01-00 UIC N /Cì JJ; ¡~7 e . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21_Ll_L2_L3, 1D-28_L1, 1F-OlA, 3F-l9A,3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1B-15A: dot..I-;)-S-~ 'it ¡'-!¿.f3D Digital Log Images: 50-029-23465-01 ~ IOd. Ç)D~-03Lf ¡ dOS"-/oo¡ QOS -101 ¡ 6)0 - /l../L/3'-1 /443f) 14'-/310 1¿./¿/3+ 1 CD Rom 1C-21 L1 L2 L3: - - - Digital Log Images: 50-029-23253-00,60,61,62 1 CD Rom 1D-28 L1: Digital Log Images: 50-029-23237-00,60 ;)6~ -~3"? 14L1J'd f)o'l -~3"íí 14/¿/33 1 CD Rom 1F-01A: dO<E; -o;;f7 # /4Lld7s Digital Log Images: 50-029-20889-01 3F-19A: (){)I..{ -0/0 # /Lj£.¡ 3/ Digital Log Images: 50-029-22680-01 1 CD Rom 1 CD Rom 3H-14B: 066 -0<91 :It t4¿.ICA Digital Log Images: 50-103-20092-02 1 CD Rom I( . Transmittal Form . 1·/;'~ ~-i ~ .' .('¡)i.~~"íìll ..o····DAI\EI HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: IF-OIA, IF-OIALI Contains the following: 2 LDWG Compact Disc (Includes Graphic Image files) 2 LDWG lister summary 2 bluelines - MPR-DIR_md Log 2 bluelines - MPR-DIR_tvd Log LAC Job#: 906970 Sent By: cosettaE.od.i ica A J Received By: L. ~ Anchorage GEOScience Center íJ !j II Ii 'i ii II r i Date: Dec. 15, 2006 Date: ,/-) / 0 --::; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ;)Of) -Od9 ,¡;t 14 JC1C) 905 -Ood ~ I L!3DD Baker Hughes INTEQ 7260 Horner Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ! ¡!f!'T~~- 1;.(I·~m'f\I(.I!J ! I=_'_c.~¿~~c~:..:::.i !....J< ." :-:;;. .~ , ,,', /. "'-.:'.; . . WELL LOG TRANS MITT AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Avenue, Suite 100 Anchorage, Alaska December 18,2006 RE: MWD Formation Evaluation Logs IF-O/A ~PBl, AK-MW-3657484 1 LDWG formatted Disc with verification listing. API#: 50-029-20889-70 PLEASE ACK1~OWLEDGE RECEIPT BY SIGNmG A1~D RETUR..l~lNG A COPY OF THE TRA1~Sl\UTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. RÊ~èEÑË618 ~ J\ f~\! t~ 9 Date!j,~\<' ,~ Signed ~.J1---- ~ Note: This data replaces previous data for well: IF-OIA due to name change as per CPA!. {)o~ -0 d'i ~ ¡'L/3£"r . . ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 { oJ 5~9 RE: MWD Formation Evaluation Logs IF-OIA, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Dril1ing Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 IF-OIA: LAS Data & Digital Log Images: 50-029-20889-01 ~I)-t)~q 1 CD Rom c:::.I !)ift/«. ì c9 fA Ð- [Olo . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West ih Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1F-01A, 1 LDWG formatted Disc with verification listing. API#: 50-029-20889-01 July 26, 2005 AK-MW-3657484 ~\~t2J li PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: IJ 1¡rJA \ ) Signed ~JlJ ÂUL}- 6À~ . . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 12, 2005 RECEIVED JUL 1 3 2005 Alaska Oil & Gsa Con- C.omm" .. . . . Q, 1$$100 Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 F-01A and 1 F-01AL 1 (205-029 I 205-032) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk well 1 F-01A and 1 F-01AL 1. If you have any questions regarding this matter, please contact me at 265-6830 or Jake Flora at 265-6040 or Aras Worthington at 265-6802. Sincerely, ~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ,'-'"-"" · STATE OF ALASKA I REceiVED ALASKA OIL AND GAS CONSERVATION COMM ~ ION WELL COMPLETION OR RECOMPLETION REPORT ANøLLœú05 1 a. Well Status: Oil 0 Gas U GINJ D 2. Operator Name: WINJ D WDSPl D Plugged U Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. location of Well (Governmental Section): Surface: 1161' FNL, 388' FEL, Sec. 19, T11N, R10E, UM At Top Productive Horizon: 2459' FNL, 1237' FEL, Sec. 18, T11N, R10E, UM Total Depth: 21. logs Run: GRlRes, Dens/Neu 22. CASING SIZE wr. PER FT. 16" 62.5# 10.75" 45.5# 7" 26# 4.5" 12.6# 2-7/8" 6.2# GRADE H-40 K-55 K-55 L-80 L-80 5958365 5962342 5962835 Zone- 4 Zone- 4 Zone- 4 Suspended D 20AAC 25.110 Other WAG D D1 b. K'{äl$~~ïit il-& Gas Consl" CtornmiBid.. erelopmen L.Ð 'Exp ora ory LJ" Service DAnch'M~geraPhic TestD 12. Permit to Drill Number: 5. Date Comp., Susp., ,; or Aband.: June 11, 2005 205-029 6. Date Spudded: ¡lip"'''' 2. B I ZAOS- 13. API Number: _ M~ ''I.. ?nn" .,(.p 1·22. -oS- 50-029-20889-01 7. Date TD Reached: ,/ 14. Well Name and Number: May 31, 2005 8. KB Elevation (ft): 44' AMSL 9. Plug Back Depth (MD + ìVD): 8301' MD /6047' TVD 10. Total Depth (MD + ìVD): 10533' MD /6174' TVD 11. Depth where SSSV set: 2400' 19. Water Depth, if Offshore: N/A 1 F-01A 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25652 17. land Use Permit: ALK 2578 20. Thickness of feet MSL Permafrost: 1450' MD CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ìVD TOP BOTTOM TOP BOTTOM Surf. 80' Surf. 80' Surf. 2630' Surf. 2216' Surf. 6253' Surf. 4331' 6086' 8335' 4217' 6070' 8242' 10474' 6016' 6172' 23. Perforations open to Production (MD + ìVD of Top and Bottom Interval, Size and Number; if none, state "none"): 1956' FNL, 1712' FWL, Sec. 18, T11N, R10E, UM 4b. location of Well (State Base Plane Coordinates): Surface: x- 539592 y- TPI: x- 538708 y- Total Depth: x- 536716 y- 18. Directional Survey: Yes 0 NoU slotted liner from 8242'-10474' MD 26. Date First Production June 25, 2005 Date of Test Hours Tested 6/28/2005 Flow Tubing press. 178 psi 27. 6 hours Casing Pressure 749 Production for Test Period --> Calculated 24-Hour Rate -> 24. SIZE 4.5" HOLE SIZE CEMENTING RECORD AMOUNT PUllED 24" 250 sx AS II 1000 sx Fondu & 250 sx Permafrost C 850 sx Class G & 250 sx PF C 65.4 bbls liteCrete slotted liner 13.5" 8.5" 6-1/8" 4-1/8" TUBING RECORD DEPTH SET (MD) 6100' I PACKER SET none 25. ACID, FRACTURE. CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing. gas lift, etc.) Oil Producer - shares production with 1 F-01AL 1 Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE 152 621 306 176 bean Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (carr) 559 2518 1205 23· CORE DATA Form 10-407 Revised 12/2003 NONE IGAS-OIL RATIO 4506 rcaX;;L~~f^: >S;{J~'t I"t-'"l'''"' ' 4 7lorf ~_.[-~ I 'I.:u \ ¡ RBDMS BFL JUL 2 6 1005 CONTINUED ON REVERSE GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. NAME MD TVD / Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted. state "None". 1 F-01A Top Kuparuk A4 Top Kuparuk A4/Base A5 Top Kuparuk A4 Top A4/Base A5 Top Kuparuk A4 8456' 9038' 9158' 9827' 9905' 6114' 6125' 6126' 6136' 6137' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randv Thomas Signature ~ \. ~ Title: Greater Kuparuk Area Drillinq Team Leader Phone ·Z"Jt'-¥·r~O Contact: Jake Flora @ 265-6040 or Dan Venhaus @ 263-4372 7 1('Llo~ Date Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/19/2005 17:00 - 00:00 7.00 MOVE DMOB MOVE Prep rig for move, Remove beaver slide from outside sub base. Prep to slide floor. 4/20/2005 00:00 - 02:00 2.00 MOVE DMOB MOVE Disconnect service loops between drilling module and support module. 02:00 - 04:00 2.00 MOVE DMOB MOVE Skid rig floor and derrick to middle of drilling module. 04:00 - 06:00 2.00 MOVE MOB MOVE Move support module offweIl3H-14B. 06:00 - 08:00 2.00 MOVE MOB MOVE Contact CPAI CPF-3 DSO to observed moving rig off well. Move drilling module offweIl3H-14B. 08:00 - 09:00 1.00 MOVE OTHR MOVE P/U matting boards around wellhead. Clean location. Take on fuel in drilling module. 09:00 - 18:00 9.00 MOVE MOB MOVE Held PJSM w/ crew on rig move. Notified NSK Security of rig move. Move rig down access road from 3H-pad to CPF-3 pad. 18:00 - 20:00 2.00 MOVE RGRP MOVE Repair moving system. 20:00 - 00:00 4.00 MOVE MOB MOVE Move rig and support module from CPF-3 Pad onto spine road. Move down spine road. Located in from of KCS pad at midnite. 4/21/2005 00:00 - 05:00 5.00 MOVE MOVE MOVE Move Rig down Spine Road to 1 F-Pad access road. 05:00 - 10:30 5.50 MOVE MOVE MOVE Turn corner off spine road, Move rig down access road onto 1 F-Pad. 10:30 - 12:30 2.00 MOVE MOVE MOVE Move rig across pad and stage in front of well 1 F-O 1 A. 12:30 -16:30 4.00 MOVE POSN MOVE Lay down liner and matting boards around well 1 F-01A. 16:30 - 18:00 1.50 MOVE POSN MOVE Position drilling module to move over well. 18:00 - 19:00 1.00 MOVE OTHR MOVE Lower wellhead casing valve leaking. Will not hold pressure. Call out FMC and CPAI valve crew. Casing valve repaired and secured. OA= 50 psi, IA= 550 psi. 19:00 - 22:30 3.50 MOVE POSN MOVE Call out CPAI DSO from CPF-1 to witness rig moving over well. Move drilling module over well. Move support module next to drilling module. Skid rig floor and derrick over well center. RKB measurements = GL 40.59', Csg Spool 36.89', Tbg Spool 34.85' 22:30 - 00:00 1.50 MOVE RURD RIGUP RIU beaver slide, Berm up around rig and cellar area. Hook up all service lines between modules. ~ Q - R Ç,au.t.~~ S 5 ~ c- J,: 4/22/2005 00:00 - 06:00 6.00 MOVE RURD RIGUP Accept rig at 00:00 hrs, 4/22/2005. Hook up all service lines, berm !?v\ around rig, spot bleed tank and choke skid. Prep to RU on tree to circulate. 06:00 - 07:30 1.50 MOVE RURD DECOMP Continue RU of hard line from tree to choke skid. Take on 8.8 ppg brine in pits. Spot rock washer. RU bleeder tank, manifold and flowline. 07:30 - 09:00 1.50 WELCTL CIRC DECOMP Pull BPV (550 psi on tbg and 550 psi on 3-1/2" x 7" annulus). 09:00 - 10:30 1.50 WELCTL CIRC DECOMP PJSM. Blow air through line and bleeder tank. Test lines to 1,500 psi w/ brine. 10:30 - 12:00 1.50 WELCTL CIRC DECOMP Circulate 8.8 ppg brine thru outer choke and bleed tank. Displace freeze protect diesel from well. 12:00 - 14:00 2.00 WELCTL CIRC DECOMP Continue circulating at 4 BPM and 500 psi. Shut down and monitor well for 10 minutes, 70 psi of press. Circulate and monitor well for 10 minutes. Well was static. Blow down lines. 14:00 - 15:30 1.50 WELCTL OTHR DECOMP Drain diesel from tree. Set BPV. 15:30 - 18:00 2.50 WELCTL NUND DECOMP PJSM. NO tree. Inspect and confirm threads on hngr - 4-1/2" LH Acme. Remove tree from cellar. 18:00 - 00:00 6.00 WELCTL NUND DECOMP Continue NU DSA and riser. Studs too short for 11",3,000 lb. Replace studs. NU BOPs. Measure and cutoff pitcher nipple. Install turnbuckles and mousehole. 4/23/2005 00:00 - 03:00 3.00 WELCTL NUND DECOMP Continue NU. Install turnbuckles and mousehole. 03:00 - 05:30 2.50 WELCTL BOPE DECOMP RU test joint and crossovers. Fill BOPs with water. Body test stack to 250 psi /3,000 psi for 5 min each. RD. 05:30 - 06:00 0.50 WELLSR PLGM DECOMP Pull Blanking plug. RU and pull BPV. 06:00 - 07:00 1.00 WELLSR RURD DECOMP PU/RU Control line spooling unit and tubing handling equipment. 07:00 - 08:00 1.00 WELLSR PULD DECOMP MU landing joint and crossovers. Attempt to screw into 4-112" LH acme Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: Rig Release: Rig Number: 4/19/2005 5/11/2005 Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/23/2005 07:00 - 08:00 1.00 WELLSR PULD DECOMP running tool into tubing hanger. Made numerous attempts. No-Go. 08:00 - 10:30 2.50 WAlTON EQIP DECOMP Lay down landing joint. Call out Baker Fishing with spearing equipment. 10:30 - 11 :30 1.00 FISH PULD DECOMP MU Spear. Spear into tubing, back out lock down screws. 11 :30 - 12:00 0.50 FISH OTHR DECOMP Pull tubing, working up to 250K, (11 OK over). 12:00 - 14:00 2.00 FISH OTHR DECOMP Continue working tubing, pulling to 250K, plus. Note: when hanger was pulled near the rig floor, the control line was missing from the hanger port. 14:00 - 15:30 1.50 FISH CIRC DECOMP Reverse circulate tubing at 15 SPM and 520 psi. Discuss options with Drilling Management. 15:30 - 16:30 1.00 FISH OTHR DECOMP Continue pulling and work torque into string., working tubing, spear released. 16:30 - 18:30 2.00 FISH PULD DECOMP Lay down spear, break down landing joint, pup joint, TIW valve, crossovers, 15 pup joint to floor. 18:30 - 20:30 2.00 WAlTON EQIP DECOMP Wait on subs for surface jars from Baker. 20:30 - 21 :00 0.50 FISH PULD DECOMP PU/MU spear with bumper sub 21 :00 - 00:00 3.00 FISH JAR DECOMP Spear into tubing hanger and adjust trip on jar to 120K, jar down. Adjust trip on jars to 180K, continue jarring. Total movement string moved down +/- 4". 4/24/2005 00:00 - 00:30 0.50 FISH JAR DECOMP Continue jarring down on tbg string. No movement observed. 00:30 - 01 :30 1.00 FISH OTHR DECOMP M/U top drive to jarring assembly. Attempt to work torque down into tbg string. Work string up and down. String rotates freely. No movement observed. 01 :30 - 08:00 6.50 WAlTON EQIP DECOMP Discuss options with Drilling Management. Call out Schlumberger E-line unit to run freepoint and cut tbg. 08:00 - 10:30 2.50 FISH CPBO DECOMP Attempt to release 3-1/2" spear from tbg. Unable to release spear. Attempt to work RH torque down into string, no movement. Work LH torque into string. String free, pull tbg hgr to rig floor. String weight indicates that +/- 1,000' of 3-1/2" tbg back-off. 10:30 - 11 :00 0.50 CMPL TN PULD DECOMP Lay down jarring assembly. Lay down FMC/OCT tbg hgr and pup jts. 11 :00 - 14:30 3.50 CMPL TN PULD DECOMP POH, lay down 27 jts. of 3-1/2" tbg. Recovered C/L entangled around tbg collars starting at jt # 10 to jt # 27. Estimate TOF at 920'. Observed C/L in stack at top of wellhead. 14:30 - 15:00 0.50 CMPL TN PULD DECOMP Clear rig floor of C/L, spooling unit, and tbg tongs. 15:00 -16:00 1.00 FISH PULD DECOMP Service Fishing tools, M/U jars and driil pipe. 16:00 -17:00 1.00 FISH TRIP DECOMP PU Baker Rope spear BHA, Jars and 1 DC. Tag bird nested control line at the wellhead. Rotate and PU to rig floor (recovered 100-200') Continue RIH picking up DCs to 300'. 17:00 - 20:45 3.75 FISH TRIP DECOMP Continue PU/MU 4-3/4" DCs and 20 joints of 4" DP, rabbiting on pipe skate. RIH and tag TOF at 913' DP measure. 20:45 - 21 :45 1.00 FISH TRIP DECOMP POOH standing back DP and DCs. Recover +/- 30' of additional control line. LD Rope Spear and Jars. 21 :45 - 00:00 2.25 FISH TRIP DECOMP PU/MU overshot. RIH with DP from derrick, PU 8 additional joints. Tag up on TOF at 913'. Wash down with 4-5 BPM and swallow 2' offish, PU to 150K, set back down to 130K. PU to 250K slowly and monitor - no movement. Circulate and prep to chemical cut tbg. 4/25/2005 00:00 - 01:15 1.25 FISH OTHR DECOMP Attempt to work tbg string free, work drill pipe from 130K dn to 250K up. No movement, string not free. 01:15 - 02:00 0.75 FISH CIRC DECOMP Circulate btms up from TOF. Sand and scale observed in returns at surface. Slight volume of gas at BU (max = 4,980 units). Shut down pumps. Monitor well, static. Call out Schlumberger to cut tbg. 02:00 - 03:45 1.75 FISH ELlN DECOMP Release overshot. Change out bales on top drive for longer set. M/U Schlumberger pump-in sub. Printed: 5/18/2005 3:44:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: Rig Release: Rig Number: 4/19/2005 5/11/2005 Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/25/2005 03:45 - 05:00 1.25 FISH ELlN DECOMP M/U Schlumberger equipment on drill string. 05:00 - 05:15 0.25 FISH ELlN DECOMP M/U jt of drill pipe. Slack off down over fish. Engage fish with 20K overpull. 05:15 - 06:30 1.25 FISH ELlN DECOMP M/U E-line sheave, M/U 80 gr string shot and tool string, stab into drill pipe. 06:30 - 08:15 1.75 FISH ELlN DECOMP RIH with string shot on E-line. Log into position. Fire string shot at 6,320' ELM. 08:15 -10:00 1.75 FISH ELlN DECOMP POH with E-line to surface. 10:00-10:15 0.25 FISH ELlN DECOMP PJSM on handling chemical cutter. 10:15-11:30 1.25 FISH ELlN DECOMP M/U 2-1/4" chemical cutter on E-line tool string. 11 :30 - 13:00 1.50 FISH ELlN DECOMP RIH with 2-1/4" chemical cutter on E-line. Log into position. Fire chemical cutter at 6,320' ELM. 13:00 - 14:30 1.50 FISH ELlN DECOMP POH with E-line to surface. 14:30 - 15:00 0.50 FISH ELlN DECOMP RID Schlumberger. 15:00-15:15 0.25 FISH PULL DECOMP Latch elevators onto drill string. P/U string free at 130K. 15:15-16:30 1.25 FISH CIRC DECOMP Circulate btms up, slight gas show at surface (max = 2,020 units). Circulate until well bore static. Shut down pumps. Monitor well, Static. Pump slug. 16:30 - 18:00 1.50 FISH PULL DECOMP POH with tbg & drill pipe. Stand drill pipe in derrick. LD overshot. 18:00 - 19:45 1.75 WELLSR CIRC DECOMP RU to circulate. Increase brine weight to 9.0 ppg. 19:45 - 21 :00 1.25 WELLSR CIRC DECOMP Circulate 9.0 ppg brine at 3 BPM (Max gas 3,070 units). Monitor well, Static. (7" x 9-5/8" Annulus pressure before circ = 300 psi, after = 600 psi). 21 :00 - 21 :30 0.50 WELLSR CIRC DECOMP Pump slug and blow down all surface lines. 21 :30 - 23:30 2.00 WELLSR TRIP DECOMP POOH, LD tbg. (control line was on jt below drillpipe). Cut C/L in 30-60' lengths and put in waste bags. Recovered 21 additional clamps. LD41 joints and SSSV. NORM tested same + tree - okay. 23:30 - 00:00 0.50 WELLSR TISO DECOMP PU storm pkr and set 90' below RKB with 20K below pkr. 4/26/2005 00:00 - 00:30 0.50 WELLSR OBSV DECOMP Monitor well. No flow 00:30 - 04:30 4.00 WELLSR NUND DECOMP Drain BOPs. NO Bell Nipple and remove turnbuckles while bleeding off pressure from 9-5/8" x 7" annulus. 04:30 - 05:30 1.00 WELLSR NUND DECOMP NO BOPs and riser from DSA. 05:30 - 06:00 0.50 WELLSR SEQP DECOMP Remove DSA and FMC Gen I casinghead. Pull packoff. 06:00 - 09:00 3.00 WELLSR SEQP DECOMP Clean Packoff area. Install new packoff. NU Gen V casinghead and test packoff seals to 3,000 psi, for 10 min - okay. New RKB to LOS = 34.5'). 09:00 - 12:00 3.00 WELLSR NUND DECOMP PJSM. NU DSA and BOPs. 12:00 -12:30 0.50 WELLSR NUND DECOMP Continue NU BOPs. 12:30 - 14:00 1.50 WELLSR SEOT DECOMP RU and run test joint. Fill BOP stack and choke manifold. 14:00 - 18:00 4.00 WELLSR SEQT DECOMP Test BOPE - Annular to 250 / 3,500 psi, Pipe rams, Blind rams, Choke and Kill line valves, TIW, dart valve, manual and auto IBOP. Perform accumulator closure test. 18:00 - 19:30 1.50 WELLSR SEOT DECOMP Continue testing BOPE to 250 psi low and 3,500 psi high. AOGCC rep, John Spaulding waived witnessing of test. 19:30 - 20:30 1.00 WELLSR PLGM DECOMP Pull test plug and install Wear bushing. Run in 2 lock down screws on WB. 20:30 - 21 :00 0.50 WELLSR PLGM DECOMP PU Storm packer pulling equipment. 21 :00 - 22:00 1.00 WELLSR PLGM DECOMP RIH, screw into Storm packer, close annular preventer, open choke, release packer, monitor well, open annular and pull Storm packer + Printed: 5/1812005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/26/2005 21 :00 - 22:00 1.00 WELLSR PLGM DECOMP 22:00 - 22:30 0.50 WELLSR OTHR DECOMP 22:30 - 00:00 1.50 WELLSR PULD DECOMP 00:00 - 02:00 2.00 WELLSR PULD DECOMP 02:00 - 03:00 1.00 WELLSR PULD DECOMP 03:00 - 04:15 1.25 WINDOWPULD DECOMP 04: 15 - 06:00 1.75 WINDOWTRIP DECOMP 06:00 - 12:00 6.00 WINDOWTRIP DECOMP 12:00 - 12:30 0.50 WINDOWTRIP DECOMP 12:30 - 14:30 2.00 WINDOWCIRC DECOMP 14:30 -15:00 0.50 WINDOWOBSV DECOMP 15:00 -18:00 3.00 WINDOWTRIP DECOMP 18:00 - 18:30 0.50 WINDOWPULD DECOMP 18:30 -19:00 0.50 WINDOWOTHR DECOMP 19:00 - 20:15 1.25 WINDOWRURD DECOMP 20:15-21:00 0.75 WINDOWELlN DECOMP 21 :00 - 22:00 1.00 WINDOWELlN DECOMP 22:00 - 22:30 0.50 WINDOWELlN DECOMP 22:30 - 00:00 1.50 WINDOWELlN DECOMP 00:00 - 00:30 0.50 WINDOWELlN INTRM1 00:30 - 01 :00 0.50 WINDOWELlN INTRM1 01 :00 - 01 :30 0.50 WELLSR DEQT DECOMP 01 :30 - 03:45 2.25 WINDOWPULD DECOMP 03:45 - 04:30 0.75 WINDO\l\lOTHR DECOMP 04:30 - 05:30 1.00 WINDOWPULD DECOMP 05:30 - 06:00 0.50 WINDOWTRIP DECOMP 06:00 - 07:00 1.00 WINDO\l\lOTHR DECOMP 07:00 - 11 :30 4.50 WINDOWTRIP DECOMP 11 :30 - 12:00 0.50 WINDOINCIRC DECOMP 12:00 - 12:30 0.50 WINDO\l\lOTHR DECOMP 12:30 - 14:30 2.00 WINDOWCIRC DECOMP 14:30 - 17:30 3.00 WINDOWSTWP DECOMP 17:30 - 18:00 0.50 DRILL CIRC DECOMP 18:00 - 18:45 0.75 DRILL CIRC DECOMP 18:45-19:15 0.50 DRILL OTHR DECOMP 19:15 - 19:45 0.50 DRILL CIRC INTRM1 19:45 - 20:30 0.75 DRILL OTHR INTRM1 20:30 - 22:30 2.00 DRILL CIRC INTRM1 22:30 - 23:00 0.50 DRILL LOT INTRM1 4/27/2005 4/28/2005 tubing to rig floor. LD Storm packer. POOH and LD 3-1/2" tubing. (Note: tubing free of pitting, chemical scale, and threads are in good condition). Continue POOH and LD 3-1/2" tubing. Total of 129 jts +26.27' cutoff. RD tubing handling equipment. PU/MU Mill BHA. RIH picking up 4" DP from the pipe shed, drifting every joint. Continue RIH picking up DP. Continue RIH and tag up on Tbg stump at 6,329' DPM. Circulate one full hole volume at 5 BPM and 530-570 psi. Note: peak gas measurement = 4,980 units. Pump 30 bbl sweep. Monitor well - static. Pump slug, LD two singles and blow down TO. POOH with mills. LDmills. Clear rig floor of mill assembly. RU wireline equipment, and MU wireline head. RIH with 6.0" Guage Ring and Junk Basket to 6,315' (no tight spots). POOH with GRlJB (no tight spots - no overpull). No junk recovered in Junk Basket. PUlMU Baker WL Bridge Plug. RIH, log on depth, set Bridge Plug at 6,265' WLM (7' above csg collar and 30' below collar. POOH w/ WL tools. RD, LD WL tools. RU recording equipment. Pressure test casing to 3,000 psi for 15 minutes. PU whipstock assembly and MWD. PU Upload MWD data. Surface test. Continue PU BHA. RIH w/ 4" DP from derrick. Lubricate rig. RIH with Whipstock assembly to 6,271' DPM and tag up on retainer. Cir and condition mud. Orient whipstock 85L degrees. Set whipstock Displace 8.8 ppg brine from hole with 10.2 ppg LSND. Mill window. TOW = 6,253' md, BOW = 6,265' md. Drill new hole to 6,283'. Work mills through window. Pump "Super Sweep at 4 BPM. Had 50-75% increase in cuttings returns. Continue circulating out sweep. Hole losing mud. Lost a total of 45 bbl. Shut down pumps. Monitor well. Well flowing with 90 psi drillpipe pressure. Flow decreased to 2 bbllhr and 70 psi DPP. Mud out: 10.2+ ppg, FV=48 sec. Circulate bottoms up at 7 BPM with hole losing mud. Slowed pumps to 5 BPM and 1,100 psi circ pressure, and losses were minimal. Max gas was seen at btms up 576 units). Lost 12 bbl while circ. Monitor well with returns taken at an isolated pit. Flowback = 8 bbl. Circ @ 5 BPM and 1,100 psi with Max Gas = 449 units. Not losing returns. Stage up to 5.5 BPM, not losing. Stage up to 6 BPM and hole began losing returns at a small rate. Back off pump rate to 5.5 BPM. Attempt to perform FIT to 12.5 ppg with 10.2 ppg LSND mud in the hole. Leak-off occured at 440 psi surface presure for 12.2 PPG EMW. /- v' Printed: 5/18/2005 3:44:56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 4/28/2005 23:00 - 23:30 0.50 DRILL CIRC INTRM1 Break circulation at 5 BPM. 23:30 - 00:00 0.50 DRILL CIRC INTRM1 Pump 20 bbl pill of fine, 20 Ib/bbl LCM material. Note: Open hole volume = 1 bbl. 4/29/2005 00:00 - 00:30 0.50 DRILL CIRC INTRM1 Pump 20 bbl pill of fine, 20 Ib/bbl LCM material. Note: Open hole volume = 1 bbl. 00:30 - 03:00 2.50 DRILL CIRC INTRM1 PU 5 stands to pull out of LCM pill. RU to hesitation squeeze LCM pill. Close upper pipe rams. Pump until pressure just below leak-off pressure, allow to dissapate and pump again. Maintain pressure on LCM pill between 270 - 470 psi. Squeezed away 6 bbls. opened well and 1 bbl flowed back. 03:00 - 04:00 1.00 DRILL OBSV DECOMP Monitor well and RD squeeze equipment. 04:00 - 04:30 0.50 DRILL TRIP DECOMP Wash to bottom, 6,283' at 5 BPM. Lost 8.5 bbl, loss rate decreasing to zero. 04:30 - 05:00 0.50 DRILL CIRC DECOMP POOH to inside window. Circulate bottoms up at 2-5 BPM. Lost 3 bbl. 05:00 - 05:30 0.50 DRILL OBSV DECOMP Monitor well, flowed back with initial DP pressure at 150 psi. Pressure and flowback rate decreased to zero. Flow back of losses from washing and circulating. Net loss zero. 05:30 - 06:00 0.50 DRILL LOT DECOMP Repeat LOT with same results. 06:00 - 07:30 1.50 DRILL CIRC DECOMP Circ and Cond mud. Spot 17 bbl LCM pill. 07:30 - 09:00 1.50 DRILL TRIP DECOMP POOH 10 stds slowly, with 40K of drag from 6,251' - 6,064'. 09:00 - 09:30 0.50 DRILL OBSV DECOMP Monitor well for 15 minutes - static. Pump slug and blow down TO. 09:30 - 12:00 2.50 DRILL TRIP DECOMP POOH and stand back 58 stds of DP and 5 stds of HWDP. 12:00 - 14:00 2.00 DRILL PULD DECOMP LD MWD and mills, clear rig floor. Note: mills in guage. 14:00 -15:30 1.50 DRILL OTHR DECOMP RU and wash out stack. Function test all ram BOPs. Blow down TO. 15:30 - 17:00 1.50 DRILL PULD INTRM1 PU motor and set AKO to 1.5 deg/ MU bit. PU/MU MWD including PWD. 17:00 -18:00 1.00 DRILL PULD INTRM1 Upload MWD. 18:00 - 20:30 2.50 DRILL PULD INTRM1 Handle BHA. LD 9 joints of steel 4-3/4" DCs. 20:30 - 21 :15 0.75 DRILL PULD INTRM1 RIH w/ HWDP, PU jars, RIH w/ MWD and shallow test same. 21:15-22:45 1.50 DRILL TRIP INTRM1 PU 39 joints of 4" DP from pipe shed, TIH. 22:45 - 00:00 1.25 DRILL TRIP INTRM1 TIH w/4" DP from the derrick. 4/30/2005 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 Continue TIH with DP from derrick. 01 :00 - 02:30 1.50 DRILL OTHR INTRM1 Cut and slip 101' of drill line. Check crown-o-matic. 02:30 - 03:30 1.00 DRILL TRIP INTRM1 Orient toolface, pass through window - no problems. Wash to TO at 6,283'. 03:30 - 06:00 2.50 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,283' to 6,365' MD, 4,409' TVD. ADT - 2.4 hrs, ART - 0.0 hrs, AST - 2.4 hrs. WOB - 9K, RPM - 0, GPM-256, PRESS - 2,020 psi UWT = 155K, DWT = 120K 06:00 -12:00 6.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,365" to 6,445' MD, 4,470' TVD. ADT - 4.83 hrs, ART - 0.68 hrs, AST - 4.15 hrs. WOB - 5K, RPM - 80, GPM-264, PRESS - 2,300 psi TORQUE on/off =-7K15K UWT= 155K, DWT= 115K, ROT= 140K 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 6-118" hole from 6,445" to 6,725' MD, 4,710' TVD. ADT - 11.78 hrs, ART - 7.59 hrs, AST - 4.19 hrs. WOB - 2-5K, RPM - 80, GPM-264, PRESS - 2,330 psi TORQUE on/off =-7K15K UWT= 155K, DWT= 115K ECD = 11.96 ppg, ECD @ Window = 11.92 (calc) Losses for day = 180 bbl (5-30 bbllhr losses, 5/20 bbl flowback when pumps shut off). Printed: 5/18/2005 3:44:56 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/112005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,725' to 6,833' MD, 4,790' TVD. ADT - 4.18 hrs, ART - 1.52 hrs, AST - 2.66 hrs. WOB - 5K, RPM - 80, GPM-264, PRESS - 2,100 psi TORQUE on/off =-7K / 5K UWT = 155K, DWT = 115K ECD = 11.74 ppg, ECD Losses = 180 bbl Note: Increased Mud Wt to 10.6 ppg to test formation integrity with anticipated MW for well TO. 06:00 - 11 :00 5.00 DRILL DRLG INTRM1 Drill 6-1/8" hole from 6,833' to 7,064' MD, 5,000' TVD. ADT - 3.56 hrs, ART - 1.64 hrs, AST - 1.92 hrs. WOB - 2-5K, RPM - 80, GPM-254, PRESS - 2,400 psi TORQUE on/off =-7K /4K UWT = 160K, DWT = 128K, ROT =140K ECD = 12.04 ppg, ECD 11 :00 -12:00 1.00 DRILL CIRC INTRM1 Circ and condition mud. Loss rate increased from 30 bbllhr to 60 bbllhr. Mix and pump 39 bbl of DynaRed Fine + Safe Carb LCM pill at 20 Ib/bbl. 12:00 - 14:30 2.50 DRILL CIRC INTRM1 Continue to circulate decreasing flowrate to 3 BPM, 2 BPM, 1-1/2 BPM. Losses = 520 bbl (0700 hrs - 1400 hrs) 14:30 - 15:30 1.00 DRILL OBSV INTRM1 Monitor well. Flowback decreasing. 15:30 - 18:00 2.50 DRILL TRIP INTRM1 POOH slowly, 9 stands, and pass through window. 18:00 - 19:00 1.00 DRILL OBSV INTRM1 Try to break circulation - losing returns. Monitor well for flowback in trip tank. 19:00 - 23:00 4.00 DRILL CIRC INTRM1 Circulate at 1-2.5 BPM to circulate btms up (Max Gas = 65 units). Confer with Anchorage. Losses = 110 bbls (1800 hrs - 2300 hrs) 23:00 - 00:00 1.00 DRILL OBSV INTRM1 Monitor well. Flowback = 72 bbl total in one hour. Flowrate negligble at the end of the hour. 5/2/2005 00:00 - 00:30 0.50 DRILL TRIP INTRM1 POOH 5 stands, from 6,230' - 5,805'. Gain - 17.5 bbl 00:30 - 02:30 2.00 DRILL OBSV INTRM1 Monitor well, gained 10 bbl in first 50 min, gained 3 bbl in the next 30 min. 02:30 - 03:00 0.50 DRILL TRIP INTRM1 POOH 5 stands, from 5,805' - 5,341'. Gain - 11.5 bbl. 03:00 - 04:00 1.00 DRILL OBSV INTRM1 Monitor well. Well gained 17.8 bbl, with decreasing flowback rate. 04:00 - 04:30 0.50 DRILL TRIP INTRM1 POOH 5 stands, from 5,341' - 4,873'. Gain - 10 bbl. 04:30 - 05:30 1.00 DRILL OBSV INTRM1 Monitor well, gained 2.8 bbl. 05:30 - 06:00 0.50 DRILL TRIP INTRM1 POOH 5 stands, from 4,873' - 4,402'. Gain - 7 bbl. 06:00 - 06:15 0.25 DRILL OBSV INTRM1 Monitor well, gained 1.7 bbl. 06:15 - 06:30 0.25 DRILL CIRC INTRM1 Break circ., pump slug. 06:30 - 07:45 1.25 DRILL TRIP INTRM1 POOH 25 stands, from 4,402' - 2,083'. Gain - 23.5 bbl. 07:45 - 08:00 0.25 DRILL OBSV INTRM1 Monitor well, gained 2.2 bbl. 08:00 - 11 :00 3.00 DRILL TRIP INTRM1 POOH to MWD. 11 :00 - 12:00 1.00 DRILL PULD INTRM1 Download MWD. Printed: 5/18/2005 3:44;56 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/2/2005 12:00 - 13:00 1.00 DRILL PULD INTRM1 Clean rig floor and RU 2-7/8" tubing cement stinger. 13:00 - 14:15 1.25 CEMENT PULD INTRM1 PU 10 jts of 2-7/8" tubing from pipe shed. RD tubing handling equip. 14:15 - 16:00 1.75 CEMENT TRIP INTRM1 TIH w/ drillpipe from derrick to 3,000'. 16:00 - 16:45 0.75 CEMENTCIRC INTRM1 Circ btms up at 2.5 BPM and 340 psi. 16:45 -17:15 0.50 CEMENT TRIP INTRM1 Blow down top drive and TIH to 4,535'. 17:15 - 18:15 1.00 CEMENTCIRC INTRM1 Circ btms up at 2.5 BPM and 400 psi. 18:15-19:15 1.00 CEMENT TRIP INTRM1 TIH to 6,200'. 19:15 - 20:45 1.50 CEMENTCIRC INTRM1 Circ btms up at 1.5 to 2.5 BPM - Lost 22 bbl. 20:45 - 21 :45 1.00 CEMENTOTHR INTRM1 Monitor well, gained 17 bbl. ~ ~\~~ >~-..)t..t.. "LE:.. 21 :45 - 22:00 0.25 CEMENT SFTY INTRM1 PJSM for cement squeeze job. 22:00 - 22:30 0.50 CEMENT PUMP INTRM1 TIH to 6,300', RU cmt head, pump bbl of water, pressure test lines to 3,000 psi, jet mix and pump 8 bbl of 13.3 PPG, 8% bentonite cmt, Yld = 1.9 ft3/sk, followed by 5 bbl of water. Note: Thickening time = 5 hr 40 min at 90 deg BHT. 22:30 - 23:00 0.50 CEMENT DISP INTRM1 Displace cement with 5 bbl of 12.8 ppg mud and 60 bbl of 10.6 ppg LSND mud at 3.5 BPM and 500 psi. 23:00 - 00:00 1.00 CEMENT TRIP INTRM1 POOH 5 stands to 5,832'. Note: BOP test interval was verified to be 14 days by Tom Maunder- AOGCC. 5/3/2005 00:00 - 04:30 4.50 CEMENTCIRC INTRM1 Circulate and condition mud. Reduce mud weight to 10.4 ppg 04:30 - 06:45 2.25 WELCTL OBSV INTRM1 Observe well. Gained 33 bbl. 06:45 - 08:00 1.25 DRILL CIRC INTRM1 CBU @ 2.5 bpm,410 psi 08:00 - 08:15 0.25 DRILL REAM INTRM1 Wash and ream from 5832' to 6018' 08:15 - 09:15 1.00 DRILL CIRC INTRM1 CBU @ 2.5 bpm, 420 psi 09:15 - 10:00 0.75 DRILL REAM INTRM1 Wash and ream from 6018' to 6300' 10:00 - 11 :00 1.00 DRILL CIRC INTRM1 CBU @ 3.0 bpm, 470 psi 11 :00 -12:45 1.75 DRilL REAM INTRM1 Wash and ream from 6300' to 7064' 12:45 - 13:45 1.00 DRILL CIRC INTRM1 Circulate and condition mud. P/U= 152k, S/O=115k, 43 spm @ 660 psi 13:45 - 14:30 0.75 WELCTL OBSV INTRM1 Monitor well-slight flow back. Flow back decreasing 14:30-15:15 0.75 DRILL TRIP INTRM1 POOH to 6025' 15:15 - 15:45 0.50 DRILL TRIP INTRM1 Pump slug and blow down top drive 15:45 - 18:00 2.25 DRILL TRIP INTRM1 POOH to 320' and prepare to UD 2-7/8" tubing stinger 18:00 - 19:00 1.00 DRILL PULD INTRM1 UD 2-7/8" stinger 19:00 - 19:30 0.50 DRILL RIRD INTRM1 RID tubing tools 19:30 - 22:00 2.50 DRILL PULD INTRM1 M/U BHA and uplow MWD 22:00 - 22:45 0.75 DRILL TRIP INTRM1 Trip in hole to 3000' 22:45 - 23:00 0.25 DRILL CIRC INTRM1 CBU @ 185 gpm, 1000 psi 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Trip in hole to 6178' 5/4/2005 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 CBU @ 185 gpm and 1200 psi. Orient to go through window 01:00 - 02:15 1.25 RIGMNT RSRV INTRM1 Change TDS saver sub 02:15 - 04:00 1.75 DRILL REAM INTRM1 Trip through window and wash to 6636' 04:00 - 05:00 1.00 DRILL CIRC INTRM1 CBU 05:00 - 06:00 1.00 DRILL REAM INTRM1 Wash from 6636' to 7064' 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill from 7064' to 7149', 5078' TVD 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drill from 7149' to 7300', 5219' TVD. AST=5.9, ART=3.3, Pump pressure = 1700 psi on bottom/1500 psi off bottom, Torque= 6K on/5k off, P/U= 170k, S/O= 130K. WOB=8K, 43 spm/180 gpm, 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill from 7300' to 7363', TVD=5215' 5/5/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7363' to 7438' 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill and slide ffrom 7438' to 7522'. TVD=5432' 12:00 - 18:00 6.00 DRILL DRLG INTRM1 Drill and slide form 7522' to 7581'. TVD=5489'. 42 spm, 180 gpm @ 1900 psi on bottom/1700 psi off bottom. 80 rpm, Torque= 6 k off Printed: 5/18/2005 3:44:56 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/5/2005 12:00 -18:00 6.00 DRILL DRLG INTRM1 bottom, 6.5 k on bottom. WOB = 8k. P/U = 175k, S/O = 130k. Rot=150k 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7581' to 7666', TVD=5569' AST=4.89, ART=.49 5/6/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7666' to 7742'. TVD=5639'. AST=3.32 hrs. ART=.24 hrs 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7742' to 7832'. TVD=5720'. AST=4.73 hrs. ART=.44 hrs 12:00 -18:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7832' to 7923'. TVD=5797'. AST=2.80 hrs. ART=2.08 hrs Pump = 43 spm (180 gpm) @ 1900 psi on bottom /1610 psi off bottom. Torque= 7k on/6k off. P/U=180kl S/0=135k1Rot=150k 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill and slide from 7923' to 8035'. TVD=5898'. AST=3.71 hrs. ART=.68 hrs. max gas @ 7995' = 1464 units. Flow-chekc no flow 5/7/2005 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drill and slide from 8035' to 8118'. K-1 @ 8025' MD. Max gas =5014 units.. Flow check-well static. AST=3.28, ART=.29 P/U=195k, S/O=135k Rot=160k 06:00 - 12:00 6.00 DRILL DRLG INTRM1 Drill from 8118' to 8232'. TVD=6010'. AST=2.8 hrs, ART=1.11 hrs 12:00 - 14:15 2.25 DRILL DRLG INTRM1 Drill from 8232' to 8336'. TVD=6070'. ART=1.64hrs. Connection gas = "" 2500 units. 14:15 -15:15 1.00 DRILL CIRC INTRM1 Circulate and condition mud to 10.4 ppg 15:15 -16:45 1.50 DRILL CIRC INTRM1 Circulate high vis sweep. Lost 30 bbl mud. ECD=12.0 ppg EMW 16:45 - 17:00 0.25 DRILL OBSV INTRM1 Monitor well on trip tank. Flow back decreasing. 17:00 - 18:00 1.00 DRILL CIRC INTRM1 Circ and condition mud w/ full returns 18:00 - 21 :30 3.50 DRILL TRIP INTRM1 Pump out of the hole from 8336' to 6224' 21 :30 - 22:00 0.50 DRILL OBSV INTRM1 Monitor well. Well static 22:00 - 23:00 1.00 DRILL TRIP INTRM1 RIH from 6224' to 8234' 23:00 - 23:45 0.75 DRILL REAM INTRM1 Wash and ream from 8234' to 8336' 23:45 - 00:00 0.25 DRILL CIRC INTRM1 Circulate and condition mud while circulating 128 gpm, 80 rpm, 1100 psi. 5/8/2005 00:00 - 01 :45 1.75 DRILL CIRC INTRM1 Circulate and condition mud 01 :45 - 02:00 0.25 DRILL OBSV INTRM1 Monitor well- static 02:00 - 02:30 0.50 DRILL OTHR INTRM1 Spot 100 bblliner running pill 02:30 - 05:00 2.50 DRILL TRIP INTRM1 Pump out of hole from 8336' to 6070' 05:00 - 07:45 2.75 DRILL CIRC INTRM1 Pump super sweep pill around 07:45 - 08:00 0.25 DRILL OBSV INTRM1 Monitor well-static 08:00 - 11 :00 3.00 DRILL TRIP INTRM1 Pump slug. Drop rabitt and POOH from 6070' to 700' 11 :00 - 12:00 1.00 DRILL PULD INTRM1 UD HWDP, jars, flex collars 12:00 -14:00 2.00 DRILL PULD INTRM1 PJSM, drain motor, break bit and motor. Download MWD 14:00 -14:30 0.50 DRILL PULD INTRM1 UD BHA 14:30 -15:30 1.00 CASE RURD INTRM1 Clear floor and RIU to run 4-1/2" liner 15:30 -16:15 0.75 CASE SFTY INTRM1 PJSM prior to running liner 16:15-19:30 3.25 CASE PULR INTRM1 M/U shoe track and check floats. fill pipe and run liner per running order 19:30 - 20:30 1.00 CASE PULR INTRM1 P/U liner hanger and fill top w/ gel 20:30 - 21 :30 1.00 CASE CIRC INTRM1 Circulate liner volume and blow down 21 :30 - 00:00 2.50 CASE RUNL INTRM1 Run liner on d.p. from derrick to 6199' 5/9/2005 00:00 - 00:30 0.50 CEMENT PULD INTRM1 M/U cement head w/ single and UD 00:30 - 01 :15 0.75 CASE CIRC INTRM1 CBU 01:15 - 03:15 2.00 CASE RUNL INTRM1 Trip in hole w/ d.p. from derrick 03:15 - 03:45 0.50 CASE RUNL INTRM1 P/U cement head and tag bottom @ 8336' 03:45 - 06:00 2.25 CEMENTCIRC INTRM1 Circ and condition mud for cement job @ 3 bpm -750 psi 06:00 - 06:30 0.50 CEMENTCIRC INTRM1 Circ and condition mud while holding PJSM 06:30 - 07:30 1.00 CEMENTI PUMP INTRM1 Pump 5 bbl water and test lines to 3960 psi. Pump 20 bbl CW100, 30 Printed: 5/18/2005 3:44:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 ROT - SIDETRACK doyonc@ppco.com Doyon 15 Start: 4/19/2005 Rig Release: 5/11/2005 Rig Number: Spud Date: 4/22/2005 End: 5/11/2005 Group: 5/9/2005 06:30 - 07:30 1.00 CEMENT PUMP INTRM1 bbl Mudpush XL @ 12.5 ppg. Mixed and pumped 65.4 bbl Litecrete slurry @ 12.5 ppg. Dropped plug. 07:30 - 08:30 1.00 CEMENTDISP INTRM1 Displace cement w/ 40 bbl water w/ OS and 62 bbl mud w/ rig pump. Bumped plug. 08:30 - 08:45 0.25 CEMENTOTHR INTRM1 Set liner hanger w/ 2900 psi. Set liner top packer w/ 3900 psi. P/U and establish circulation. Set down on top of hanger to insure released. 08:45 - 09:45 1.00 CASE CIRC INTRM1 Circulate and condition mud. Had ~ bbl contaminated mud cement in returns. 09:45 - 10:30 0.75 CASE RURD INTRM1 Set down weigh to insure packer set. RID cement head and broke down manifold. Blew down 10:30 - 11 :00 0.50 CASE OTHR I NTRM 1 Pumped slug, cleared floor and blew down top drive 11 :00 - 14:00 3.00 CASE OTHR INTRM1 POOH UD 4" d.p. 14:00 - 15:00 1.00 DRILL TRIP INTRM1 RIH w/21 stands 4" d.p. from derrick 15:00 - 17:30 2.50 DRILL PULD INTRM1 UD 4" d.p. 17:30 - 18:00 0.50 CEMENT PULD INTRM1 UD liner setting tool and r/u to pull wear ring 18:00 - 19:00 1.00 CMPL TN NUND CMPL TN Pull wear ring. Drain stack and make dummy run w/ tubing hanger and landing jt. 19:00 - 20:00 1.00 CMPL TN RURD CMPL TN RIU to run 4-1/2" tubing. Hold PJSM 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN Run 4-1/2" tubing and completion jewelry. / 5/10/2005 00:00 - 02:00 2.00 CMPL TN RUNT CMPL TN RIH with 4-112" Completion string. 02:00 - 02:45 0.75 CMPLTN DEQT CMPL TN M/U TRSSSV with C/L, Test to 5,000 psi, OK. 02:45 - 05:30 2.75 CMPLTN RUNT CMPL TN RIH with 4-1/2" completion string and C/L. Total jts. ran 191. Total C/L bands 80. 05:30 - 07:15 1.75 CMPLTN SOHO CMPL TN Space out seal assembly, Pressure up to ensure seals engaged. OK. M/U space out pup jts with tbg hgr and C/L. Land tbg. 07:15 -11:00 3.75 CMPLTN CIRC CMPL TN P/U hgr off seat, Break circulation and displace well to seawater with corrosion inhibitor. 11 :00 - 12:00 1.00 CMPL TN SOHO CMPL TN Land tbg hgr. RILDS, Back out and lay down landing jt. 12:00 - 13:00 1.00 CMPL TN RURD CMPL TN Clear rig floor, lay down all handling tools. 13:00 - 13:30 0.50 CMPL TN RURD CMPL TN Set BPV in tbg hgr. 13:30 - 15:30 2.00 CMPL TN NUND CMPL TN C/O top pipe rams to 4-1/2" x 7" VBR, Btm pipe rams to 3-1/2" x 6" VBR. 15:30 - 19:30 4.00 CMPL TN NUND CMPL TN Pull and lay down mouse hole. NID BOPE. 19:30-21:00 1.50 CMPL TN NUND CMPL TN N/U adapter flange and production tree. Test adapter flange to 5,000 psi for 15 min. OK 21 :00 - 22:00 1.00 CMPL TN SEQT CMPL TN RIU Pump Truck to tree, Pressure test tree to 5,000 psi for 15 min. OK 22:00 - 23:00 1.00 CMPL TN RURD CMPL TN Pull 2-way check. RIU lines to test tbg and annulus. PT surface lines to 4,000 psi. OK 23:00 - 23:30 0.50 CMPL TN SEQT CMPL TN Pressure test tbg to 3,500 psi for 30 min. OK 23:30 - 00:00 0.50 CMPL TN SEQT CMPL TN Bled off tbg pressure to 1,500 psi. Pressure up on tbg x csg.annulus to 3,500 psi for 30 min test. OK 5/11/2005 00:00 - 00:30 0.50 CMPL TN FRZP CMPL TN Bled down tbg pressure, observed valve shear at 2,650 psi. 00:30 - 01 :00 0.50 CMPL TN FRZP CMPL TN LRS pump truck displaced 67 bbls diesel to well for freeze protection. 01 :00 - 01 :45 0.75 CMPL TN FRZP CMPL TN U-tube Diesel 01 :45 - 02:45 1.00 CMPL TN FRZP CMPL TN Clear all surface lines of diesel to LRS pump truck. RID test lines from tree. 02:45 - 03:00 0.25 WELLSR PLGM CMPL TN Set BPV. 03:00 - 04:00 1.00 MOVE DMOB CMPL TN Secure wellhead and tree. Finish cleaning Rock Washer and Pits. Prepare for Rig Move. Released rig from operations on Well 1 F-01 A at 04:00 hrs on 5/11/2005. Printed: 5/1812005 3:44:56 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/1 0/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/23/2005 00:00 - 12:30 12.50 MOB P PHE Rig released on 3M-13 at 22:00 hrs 5-22-2005. Moved off well and made ready to mobilize to 1 F Pad. Started rig move at midnight Stopped at 1 Q Pad for Kuparuk Crew change Stopped at 1 A Pad for low fling planes Travel up 1 F Pad excess road 12:30 - 14:00 1.50 MOB P PRE Rig on 1 F Pad Load 2-3/8" reel on rig. Conducted Pad \~"''C'~~~ Inspection with DSO Working with Kup Safety on placement of camps. 14:00 - 17:00 3.00 MOB PRE Moved rig to edge of well, PJSM and put flange and new kill hose in well cellar. 17:00 - 18:00 1.00 MOB P PRE Moved rig onto well. Remove tree cap. Prep to NU BOP's. 18:00 - 23:30 5.50 BOPSUP P PRE NU 7-1/16" 5K BOP's. Install 3" combi's. Take on 290 bbls 8.6ppg used Flo-Pro mud. 23:30 - 00:00 0.50 BOPSUF P PRE Pressure test BOP's 250 psi low 4500psi high. Witnessing waived by AOGCC 5/24/2005 00:00 - 04:30 4.50 BOPSUF P PRE Continue to test BOPE. 250 psi low and 4500 psi high. Tested accumulator. 04:30 - 06:00 1.50 WHIP P WEXIT PU injector. Make up pack-off assembly. String coil across and stab to injector. 06:00 - 10:00 4.00 WHIP P WEXIT Finished securing BOP stack. Install control panel on TRSSSV and pressured up to 5,000 psi. Meged Eline at 60mH, Pumping fluid (rev cir) for CT slack management. 10:00 - 13:00 3.00 WHIP P WEXIT RU to cut off CT to find wire. Cut off 17 ft CT. Dimpled CTC Pull test CTC to 50k Rehead CT Eline. Repacked wireline packoff and rehead BHI tested tool. Circ CT and open well. Pc = 50 psi. Open up and bled down to zero. 13:00 - 13:45 0.75 WHIP P WEXIT Circulated 1 coil volume and Cut off MH for BHA's, check reel bushing OK 13:45 - 14:45 1.00 WHIP P WEXIT PU 3.8" Parabolic Mill BHA and stab CT 14:45 - 16:45 2.00 WHIP P WEXIT RIH wo/ pumping w/ new 3.8" Parabolic mill BHA No problem running throught TRSSSV at 2,400 ft. Tagged 8217 ft, PU, open EDC and started cir down CT at 2.75 bpm to swap well bore to 8.6ppg flo-pro and tie-in 16:45 - 17:00 0.25 WHIP P WEXIT PUH to 8,000 ft to tie-in 17:00 - 17:30 0.50 WHIP P WEXIT Logging down to tie-in Corrected +5' Circulated 30 bbls 10.5ppg drilling mud with lots of sand of of well bore. Closed EDC and cir through bit. RIH and confirm PBTD before cleanout. 17:30 - 18:15 0.75 WHIP P WEXIT Cleanout wellbore at 2.8 bpm 3552 psi Nothing hard from 8,222 ft to 8265 ft Tagged landing colllar at 8265 ft. PUH and wash from 8222 ft to 8263 ft twice 18:15 - 20:30 2.25 WHIP P WEXIT PUH to 8050 ft and painted flag. EOP at 8000 ft, Opened EDC and circulated 3.00 bpm POOH. Stop at 2000'. Pressure well to 1000 psi. Close SSSV. Open well to help verify SSSV is holding. Appears to be holding based on small volume of fluid rtns. Hold PJSM to discuss BHA un-deploy and WS make up. 20:30 - 21 :45 1.25 WHIP P WEXIT At surface. Get off well. LD motor & mill. No wear on mill. Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 A. '-fl.~~ 1 F-01 ')" '1 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/24/2005 20:30 - 21 :45 1.25 WHIP P WEXIT Re-configure MWD tools to run orienter. Test same. MU Weatherford 4-1/2" LSX-N whipstock on Fury setting tool. Inspect all components. Scribe orienter to ws tray. TOW to tray btm: 8.25' TOW to PIP tag: 8.90' 21 :45 - 22:45 1.00 WHIP P WEXIT Stab coil. Get on well. RIH at 75 fpm. Tag sssv at 2400'. Check control panel pressure. Increase from 4000 to 4500 psi. Tag up again. Suspect sssv is closed. 22:45 - 23:45 1.00 WHIP P WEXIT POOH. 23:45 - 00:00 0.25 WHIP P WEXIT Get off well. Un stab coil. 5/25/2005 00:00 - 00:30 0.50 WHIP N DFAL WEXIT LD whipstock. MU nozzle on MWD tools. Stab coil. Get on well. 00:30 - 01:15 0.75 WHIP N DFAL WEXIT RIH. Tag SSSV at 2400'. Pressure up well to 1500 psi. RIH. SSSVopen. Bleed WHP and try again. Valve open. 01:15-01:30 0.25 WHIP N DFAL WEXIT POOH 01 :30 - 02:00 0.50 WHIP N DFAL WEXIT Get off well. Remove nozzle. MU and scribe whipstock to MWD tools. Test tools. Get on well. 02:00 - 04:00 2.00 WHIP P WEXIT RIH. 04:00 - 04:30 0.50 WHIP P WEXIT Log GR tie in from 8050'. Add 4' correction. 04:30 - 04:45 0.25 WHIP P WEXIT Continue in hole. Set top of whipstock at 8249' with a 30r orientation. Close EDC and presure coil to 2950 psi. Whipstock appears to have set. 04:45 - 06:55 2.17 WHIP P WEXIT POOH. Closed SSSV at 2200 ft 06:55 - 08:30 1.58 WHIP P WEXIT LD WFT running tool and PU WFT window exit BHA. Added 5 ft lubricator for pressure deployment and checked measurements. 1.5 ft down after tagging up on pack off for pressure undeployment and deployment 08:30 - 10:50 2.33 WHIP P WEXIT RIH to 470 ft, found lubricator leaking (oring). POOH and changed, RIH 10:50 - 11 :30 0.67 STWHIP P WEXIT Tied in at 8,020 ft logging down Corrected - 2ft Closed EDC RIH and tagged 8253 ft. Set WOB 11 :30 - 18:00 6.50 STWHIP P WEXIT Milled window at 0.1 ft / hrs WOB changing due to geometry of wellbore Be careful so not to jump out to soon. Started at 9249.1 ft and raising mud denity to 9.9 ppg 18:00 - 00:00 6.00 STWHIP P WEXIT Continue milling ahead. 3780 psi @ 2.72 in/out. DHWOB: 2-3k#. WHP/BHP/ECD: 73/3550/11.58 ppg IAlOAlPVT: 365/242/375 bbls. Increase whp to 650 psi, ECD to 13.45, BHP: 4100 psi. 4100 psi @ 2.55 in/out. Appear to milling formation. 5/26/2005 00:00 - 00:30 0.50 STWHIP WEXIT Exit casing. Mill formation to 8265'. Confirm formation in btms ./ up sample. Uncorrected to mother bore Top window: 8249.1' v Btm window: 8255.2' RA tag: 8258' 00:30 - 01:15 0.75 STWHIP WEXIT Ream and backream window three times. Dry drift. 01:15 - 02:45 1.50 STWHIP WEXIT Open EDC. Circulate out of hole following pressure schedule. Paint EOP flag at 8000'. Continue to POH. 02:45 - 03:45 1.00 STWHIP WEXIT Close sssv. Rearrange sssv panel control line to correct fitting on wellhead. Bleed WHP to zero. Tag up. Get off well. Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/26/2005 02:45 - 03:45 1.00 STWHIP WEXIT Unstab coil. LD BHA assembly. 03:45 - 04:30 0.75 DRILL PROD1 MU build assemby #1 (2.2 deg mtr w/ HTC bicenter). Stab coil. Test MWD. Get on well. 04:30 - 06:25 1.92 DRILL PROD1 Open EDC. RIH. Circulate and maintain WHP to follow pressure schedule once sssv is opened Tied-in at 8020 ft. Correction -2 ft, closed EDC and oriented TF to HS 06:25 - 06:35 0.17 DRILL PROD1 RIH string wt lower than normal, 6500 down wt above the window wo circulating, Tagged at 8265 ft Open choke and adusted Qp to achieve BHP of 4200 psi and 600 psi at surface. Vp = 367 bbl 06:35 - 11 :00 4.42 DRILL PROD1 DOCTDD TF @ 75R- 90R ROP 30-40 fph Qp = 2.61/2.65 bpm; Pp = 3,800 / 4222 psi BHP / WHP = 4,100/600 psi; Increased to 4200 /700 psi ECD = 13.4pppg Density = 9.9 /9.96 ppg Vp = 367 @ 0635hrs Drilled through A5 at 5,975 ft TVD (as per prognosis) 11:00 -11:10 0.17 DRILL PROD1 Computer locked up. SO pump, SWI at 1,100 psi. Reset at 8,354 ft 11:10 -14:30 3.33 DRILL PROD1 DOCTDD in A5 TF @ 90R- 120R ROP 15-25 fph Qp = 2.61/2.65 bpm; Pp = 3,800 / 4222 psi BHP / WHP = 4,248 / 700 psi; ECD = 13.8pppg Density = 9.91/ 9.97 ppg Vp = 364 @ 11 :00 hrs 14:30 - 14:50 0.33 DRILL PROD1 Wiper trip and change to MP2 Clean wiper trip 14:50 - 17:00 2.17 DRILL PROD1 DOCTDD A5/ A4 w/ TF @ 90R- 120R ROP 15-25 fph Qp = 2.60/ 2.61 bpm; Pp = 4,000 / 4,400 psi BHP /WHP = 4,318/690 psi; ECD = 13.9pppg Density = 9.91/10.00 ppg Vp = 363 @ 14:45 hrs Fault 1 at approximately 8,538 ft MD 6,015ft TVD Reduced WHP to 630 psi at 8,481 ft to keep BHP at closer t04200 psi 17:00 - 21 :00 4.00 DRILL PROD1 DOCTDD A5 / A4 w/ TF @ 75R ROP 15-70 fph Qp = 2.60 /2.61 bpm; Pp = 4,061/ 4,200 psi BHP / WHP = 4,218/630 psi; ECD = 13.6pppg Density = 9.91/10.00 ppg Vp = 360 @ 17:00 hrs Land build at 8600'. Projected Inc / Az: 92 deg /285 deg. 21 :00 - 22:30 1.50 DRILL PROD1 Wiper trip to window. Hole smooth. Orient TF for window. Shut dn pump and inc WHP to 1050 psi. Resume circulation. Continue to POOH following WHP/BHP pressure schedule. Transfer fluid in pits to prep for mud swap. Close TRSSSV with 1100 psi on well. Continue to POOH. 22:30 - 00:00 1.50 DRILL PROD1 At surface. Get off well. LD BHA assy. MU resistivity tool in MWD string. Test same. 5/27/2005 00:00 - 01 :15 1.25 DRILL P PROD1 Continue to mu and catwalk test mwd with resistivity tool added to string. MU BHA with Hycalog bi-center bit on 0.8 deg mtr. Change packoffs and inspect power pack. Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/27/2005 00:00 - 01:15 1.25 DRILL P PROD1 Stab coil. Test MWD. Get on well. 01:15 - 02:45 1.50 DRILL P PROD1 RIH. Inc WHP to 1100 psi. Open TRSSSV. RIH. Follow BHP schedule. 02:45 - 03:15 0.50 DRILL P PROD1 Log gr tie in from 8040'. Minus 2 ft correction. 03:15 - 04:00 0.75 DRILL P PROD1 RIH to window. MADD pass resistivity down through build section. Circ at min rate. Tag btm at 8601'. New mud to bit. Take last of used mud to pit #1. Mud swap complete. New mud system ordered to top off uprights on location. 04:00 - 06:00 2.00 DRILL P PROD1 Drill ahead from 8600'. 3900 psi fs @ 2.65 in/out. 200-300 dpsi. DHWOB: 1k-2k#. ROP: 40-60 fph. WHP/BHP/ECD: 600/4100/13.1 ppg. IAlOAlPVT: 5/10/353 bbls. I NC/AZlTF: 92.8/294/80r. 06:00 - 06:45 0.75 DRILL P PROD1 DOCTDD in A4 TF @ 60L ROP 15-30 fph Qp = 2.69/2.66 bpm; Pp = 4,000 / 4200 psi BHP / WHP = 4,200 /650 psi; ECD = 13.2pppg Density = 9.91 /9.97 ppg Vp = 351 @ 06:15 hrs 06:45 - 10:20 3.58 DRILL P PROD1 DOCTDD in A4 TF @ 90R-135R. ROP 5-30 fph Qp = 2.69/2.66 bpm; Pp = 4,000 / 4175 psi BHP /WHP = 4,145/650 psi; ECD = 13.2pppg Density = 9.92/ 9.96 ppg Vp = 352 @ 06:45 hrs Next Fault at 8,825 ft MD / 6002 ft TVD 10:20 - 11: 15 0.92 DRILL P PROD1 Wiper trip to tie-in 4-1/2" liner to RA in WS Reduced Qp to 0.25 bpm and trapped 900 psi on WH and pulled through wind. Open EDC and cir at 2.00 bpm pulling tight, some packing off above WS. Worked bit down and increased Qp to 2.6 bpm. RIH to TOW and cleaned up solids buildup above WS. PUH to 8,050ft and RIH at 80 fpm to assist in hole cleaning 11: 15 - 11 :35 0.33 DRILL P PROD1 Logging tie-in Corrected +1 ft RIH, closed EDC and RIH through window to 8,290 ft 11 :35 - 11 :50 0.25 DRILL P PROD1 Tie-in RA Marker Corrected RA Marker: TOW @ 8251.1 ft BOW @ 8258.0 ft RA Marker 8260.0 ft 11 :50 - 12: 10 0.33 DRILL P PROD1 RIH 12:10 -12:15 0.08 DRILL P PROD1 DOCTDD in A4 TF @ 90R. ROP 1-5 fph Qp = 2.53 / 2.52 bpm; Pp = 3,900 / 4175 psi BHP / WHP = 4,133/640 psi; ECD = 13.2pppg Density = 9.92/9.96 ppg Vp = 340 @ 12:00 hrs Maintain 92-93 deg hole angle until 8,900 ft Adding dry product Flo-Vis Plus to mud to increase LSRV to 55-60k 12:15 - 12:35 0.33 DRILL P PROD1 Lost all rig power while drilling. Re-started 2 generators and made 100 ft wiper trip. Down for 5 minutes. 12:35 - 15:20 2.75 DRILL P PROD1 DOCTDD in A4 TF @ 140 - 90R. ROP 5-20 fph Qp = 2.53/ 2.53 bpm; Pp = 3,900 / 4175 psi BHP / WHP = 4,150/645 psi; ECD = 13.2pppg Density = 9.92/9.96 ppg Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/27/2005 12:35 - 15:20 2.75 DRILL P PROD1 Vp = 336 @ 12:00 hrs 8,750 ft sample showed hard shale and claystone, ROP was 1-5 fph 15:20 - 17:00 1.67 DRILL P PROD1 DOCTDD in A4 TF @ 140 - 180R. ROP 5-30 fph Qp = 2.53/2.57 bpm; Pp = 3,900 / 4275 psi BHP / WHP = 4,197 / 652 psi; ECD = 13.4pppg Density = 9.92/9.96 ppg Vp = 340 @ 1530 hrs. LSRV at 58k 17:00 - 17:15 0.25 DRILL P PROD1 DOCTDD in A4 TF @ 90 R. ROP 30-50 fph Qp = 2.53 / 2.59 bpm; Pp = 3,900 / 4215 psi BHP / WHP = 4,199 /635 psi; ECD = 13.48pppg Density = 9.92/9.96 ppg Vp = 340bbl @ 1700 hrs. The 0.8 deg motor bend is giving us and 14.8 deg DLS averages DLS 17:15 - 18:15 1.00 DRILL P PROD1 Wiper trip to check soilds build up above WS Clean above WS 18:15 - 21:00 2.75 DRILL P PROD1 Drill ahead from 8850'. 4050 psi fs @ 2.7.in/2.7 out. 300-400 dpsi. DHWOB: 2k-3k#. ROP: 30-50 fph. WHP/BHP/ECD: 645/4200/13.4 ppg. IAlOAlPVT: 229/256/331 bbls. INC/AZ/TF: 92.1/287/110r. Drilling ROP continues to be variable. 20 to 60 fpm. Numerous stalls noted. 21 :00 - 22:30 1.50 DRILL P PROD1 Drill ahead from 8955'. 3950 psi fs @ 2.6 in/2.6 out. INC/AZ/TF: 89.7/300.1/85L 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to 7900'. Open and cased hole very smooth. Maintain TF as drilled in and out of hole. 5/28/2005 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 9002'. 4000 psi fs @ 2.4.in/2.4 out. 250-400 dpsi. DHWOB: 2.5k-3k#. ROP: 20-60 fph. WHP/BHP/ECD: 600/4220/13.46 ppg. IAlOAlPVT: 420/410/325 bbls. INC/AZ/TF: 90.9/299/40L. Continue to experience numerous stalls. Not much margin between pump pressure and max pump pressure available due to WHP needed to maintain required BHP. 03:00 - 04:00 1.00 DRILL P PROD1 Drill ahead from 9072'. Plow into shale. 04:00 - 05:15 1.25 DRILL P PROD1 Wiper trip to 7900'. Plot logs and discuss geology with town. Decide to drill ahead and try to drill down out of shaley interval. Log GR tie in to well bore. Minus 4.5' correction. Hole very smooth. 05:15 - 08:45 3.50 DRILL P PROD1 Drilling in A4 TF @ 180. Turned TF to 90L 9,130 ft ROP 5-20 fph Qp = 2.40 / 2.43 bpm; Pp = 4,100/ 4450 psi BHP / WHP = 4,210 / 571 psi; ECD = 13.5pppg Density = 9.95/9.99 ppg Vp = 326 @ 06:30 hrs; 334 bbl @ 0830 hrs Called for Mud Swap at 1200 hrs, Solids at 0.5% CTP at 4350 psi.at 2.37 bpm 08:45 -11:15 2.50 DRILL P PROD1 POOH, Need mud swap, CTP at 4400 psi at 2.3 bpm on bottom, AV dropping and ROP to slow for BC bit. Pulled through window while trapping 1000 psi WHP and tried to open EDC while move CT Unable to open, Cir through bit and POOH. Closed SSV with 1100 psi below. Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/28/2005 11 :15 - 13:30 2.25 DRILL P PROD1 OOH, checked flow, stood injector back. LD MWD and tested EDC. Changed out bit and checked HS on motor, (OK) Change out EDC (bad pump) and DBV inserts. PU BHA 13:30 - 15:15 1.75 DRILL P PROD1 RIH with EDC open at 3.00 bpm Stopped at 1,950 ft closed choke and pressured up on wellbore to 1,100 psi, Open SSSV and let equalize. Pressure under SSSV 1,190 psi, no loss or gain while changing out BHA (3 hrs). RIH following pressure schedule 15:15-16:00 0.75 DRILL P PROD1 SO pumps, closed EDC and orient TF to HS RIH past WS, RIH tagged bottom at 9,159 ft. 16:00 - 18:15 2.25 DRILL P PROD1 Drilling in A4 TF @ 90L ROP 2-45 fph in Ankerite stringers Qp = 2.40 /2.43 bpm; Pp = 4,000 / 4250 psi BHP / WHP = 4,250 /600 psi; ECD = 13.7pppg Density = 9.95/9.99 ppg Vp = 322 bbl @ 16:00 hrs. Begin mud swap. 18:15 - 20:30 2.25 DRILL P PROD1 Wiper trip to window. Hole smooth. Log gr tie from 8060. Add l' correction. Log RA tag. Found at 8260' (no change). Continue in hole. 20:30 - 0.00 DRILL P PROD1 Drill ahead form 9275'. 3800 psi fs @ 2.4 in/2.4 out. 200-350 dpsi. DHWOB: 1k-2k#. ROP: 40-80fph. WHP/BHP/ECD: 650/2400/13.45 ppg. IAJOAJPVT: 0/61/341 bbls. INC/AZ/TF: 88.1/270/80R. 5/29/2005 00:00 - 00:45 0.75 DRILL P PROD1 Complete wiper trip to/from window. Hole smooth. 00:45 - 06:00 5.25 DRILL P PROD1 Drill ahead rorm 9500'. 3800 psi fs @ 2.4 in/2.4 out. 200-350 dpsi. DHWOB: 1k-2k#. ROP: 60-110fph. WHP/BHP/ECD: 630/4198/13.45 ppg. IAJOAJPVT: 24/100/320 bbls. INC/AZlTF: 87.1/282192R. Hit a hard spot f/9555' to 9560'. 1-5 fph. ROP increased again at 9560'. 06:00 - 09:05 3.08 DRILL P PROD1 Drilling in A4 TF @ 75R. ROP 5 fph Ankerite Qp = 2.54/ 2.56 bpm; Pp = 3975 / 4000 psi BHP / WHP = 4,206/600 psi; ECD = 13.5 ppg Density = 9.95/10.0 ppg Vp = 327/314bbl @ 06:15 hrs Drilling in Ankerite Invert at 91 deg to 10,000 ft /6,010 ft TVD at 10,000 ft, drop angle and land at 6045 ft TVD at 10,400 ft Tested all emergency alarms on rig. 09:05 - 10:45 1.67 DRILL P PROD1 Wiper trip to below WS 10:45 - 17:05 6.33 DRILL P PROD1 Drilling in ankerited A4 TF @ 60L-90R-30L. ROP 0-5 fph. WOB 14k (-6.7k string wt) Qp = 2.54/2.56 bpm; Pp = 3975 / 4190 psi BHP / WHP == 4,224/600 psi; ECD = 13.5 ppg Density = 9.95/ 9.99 ppg Vp = 313/312bbl @ 12:00 hrs Drilling in Ankerite. Broke through at 9,682 ft 17:05 - 17:45 0.67 DRILL P PROD1 Drilling in A4 TF @ 30L. ROP 45-70 fph Qp = 2.54/2.56 bpm; Pp = 3975/ 4000 psi BHP / WHP == 4,251 / 600 psi; ECD = 13.6 ppg Density = 9.96/ 9.9 ppg Vp = 303/310bbl @ 06:15 hrs Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/29/2005 17:45 - 20:45 3.00 DRILL P PROD1 Drill ahead form 9718'. 3930 psi fs @ 2.4 in/2.4 out. 100-250 dpsi. DHWOB: 2k - 4k#. ROP: 30-50 fph. WHP/BHP/ECD: 620/4252/13.6 ppg. IA/OA/PVT: 590/566/301 bbls. INC/AZlTF: 92.7/292.2/80L. Altemating fast drilling with hard (ankerite) streaks. 20:45 - 22:30 1.75 DRILL P PROD1 Wiper trip to window. Hole very smooth in and out. 22:30 - 00:00 1.50 DRILL P PROD1 Drill ahead from 9803'. 3950 psi fs @ 2.5 in/2.5 out. 100-250 dpsi. DHWOB: 2k - 4k#. ROP: 30-60 fph. WHP/BHP/ECD: 580/4200/13.5 ppg. IA/OA/PVT: 610/597/297 bbls. INC/AZlTF: 94.1/286/95L. Note GR change at 9840'. Appear to nearing base of A5. Turn TF down to begin slow drop towards TO. 5/30/2005 00:00 - 02:45 2.75 DRILL P PROD1 Drill ahead from 9868'. 3950 psi fs @ 2.5 in/2.5 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 30-50 fph. WHP/BHP/ECD: 550/4260/13.6 ppg. IA/OA/PVT: 620/598/296 bbls. INC/AZlTF: 90.5/281.6/130L. Appear to be in lower A5. Continue to drill ahead at 85-86 deg incl. GR begining to drop. 02:45 - 05:30 2.75 DRILL P PROD1 Wiper trip to 7900'. Log gr tie in at 8060'. Add 6 ft correction. Continue to RIH. Hole very smooth in and out. 05:30 - 08:30 3.00 DRILL P PROD1 Drill ahead from 9990 ft to 10119 ft Drilling in A4 TF @ 165R. ROP 20-50 fph. Qp = 2.54/ 2.56 bpm; Pp = 3975 / 4000 psi IA / OA / SSSV= 620/615/4248 psi BHP / WHP = 4,226/502 psi; ECD = 13.5 ppg Density = 10.0/10.05 ppg. Vp = 290/295 bbl @ 06:15 hrs 08:30 - 11 :20 2.83 DRILL P PROD1 Drill ahead from 10,119 ft. WOB = 5.5K Drilling in A4 TF @ 165-180 R. ROP 5-10 fph Ankerite Qp = 2.54 /2.56 bpm; Pp = 3975/ 4,000 psi IA / OA / SSSV= 624/610/4,288 psi BHP / WHP = 4,226/502 psi; ECD = 13.5 ppg Density = 10.0 /10.05 ppg. Vp = 284/289 bbl @ 09:15 hrs Drilled into Ankerite at 6,023 TVD as yesterday 11 :20 - 13:40 2.33 DRILL P PROD1 Wiper trip to repair MP #1 and wipe hole after drilling 146 ft. Fixed MP1 and switched from MP#2 and test drive 13:40 - 18:00 4.33 DRILL P PROD1 Drill ahead from 10,136 ft. in Ankerite Drilled 10,141 ft to 10159 ft at 50 ftp then back to 2 fph. Drilling in A4 TF @ 150-165 R. ROP 5-10 fph Ankerite Qp = 2.44/2.48 bpm; Pp = 3990 / 4,250 psi BHP / WHP = 4,235/520 psi; ECD = 13.6 ppg Density = 9.93/9.94 ppg. Vp = 272/280 bbl @ 14:00 hrs Started mud swap at 15:00 hrs at 10,137 ft Finished at 17:30 hrs 10,160ft 18:00 - 22:30 4.50 DRILL P PROD1 Drill ahead from 10,167'. 3950 psi fs @ 2.4 in/2.4 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 2-10 fph. WHP/BHP/ECD: 650/4212/13.5 ppg. IA/OA/PVT: 0/56/349 bbls. INC/AZlTF: 85.5/279/120L. Continue to drill hard A4 (ankerite ') ROP approaching zero. Decide to POH to check BHA and bit. 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to window. Circ out of hole to check BHA and bit. Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 5/31/2005 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to POOH. Shut in well at 2000'. Hold 1100 psi on well. Close TRSSV. POOH to surface. WHP 7 psi and steady. RIH to 500' to circ cuttings out. Hold PJSM with crew to discuss BHA handling procedure. 01 :30 - 02:00 0.50 DRILL P PROD1 At surface. Get off well. Note minor flat spot on coil above connector. Check with ultrsonic tester. +/- 12% wall loss. Break off motor and bit. Bit 5-6-1. 02:00 - 02:30 0.50 BOPSUF P PROD1 Weekly function test of BOPs. Inspect injector sling and shackles. 02:30 - 03:00 0.50 DRILL P PROD1 MU replacement 08. mtr and HCC bi-center bit. Stab coil. Test MWD. 03:00 - 04:45 1.75 DRILL P PROD1 Run in hole with BHA # 9. Stop at 2000'. Pressure up well to 1100 psi. Open TRSSSV. Continue to run in hole following pressure schedule. 04:45 - 05:00 0.25 DRILL P PROD1 Log gr tie in at 8060'. No correction. 05:00 - 06:10 1.17 DRILL P PROD1 Circulate while runriing in hole. 06:10 - 09:30 3.33 DRILL P PROD1 Tagged bottom at 10,178 ft, Sticky on bottom cleaned up Drill ahead from 10,178 ft Broke through Ankerite at 10,184 ft TF @ 100L· 165R. ROP 50-70 fph. Qp = 2.45/2.46 bpm; Pp = 3,975/ 4,090 psi BHP / WHP = 4,217 / 615 psi; ECD = 13.5 ppg Density = 9.91/9.92 ppg. Vp = 342/347 bbl @ 07:30 hrs 09:30 - 11 :50 2.33 DRILL P PROD1 Wiper trip at 10,330 ft, Clean trip. 1 small bopple at 10151 ft. 11:50 -15:00 3.17 DRILL P PROD1 Tagged bottom at 10,330 ft Drill ahead from 10,330 ftt TF @ 100L - 165R. ROP 50-70 fph. Qp = 2.45/ 2.46 bpm; Pp = 3,975/ 4,090 psi BHP / WHP = 4,243/630 psi; ECD = 13.5 ppg Density = 9.91/9.92 ppg. Vp = 337 / 344 bbl @ 11 :30 hrs 15:00 - 16:30 1.50 DRILL P PROD1 Drill ahead from 10,460'. 3950 psi fs @ 2.4 in/2.4 out. 200-400 dpsi. DHWOB: 3k - 4.5k#. ROP: 40-60 fph. WHP/BHP/ECD: 630/4280/13.65 ppg. IAlOAlPVT: 408/403/344 bbls. INC/AZfTF: 89.5/279.8/120L. TO "A" lateral at 10530'. ,/ 16:30 - 18:30 2.00 DRILL P PROD1 Wiper trip to 7900'. 18:30 - 18:45 0.25 DRILL P PROD1 Log gr tie in at 8060'. Corr +5' 18:45 - 20:00 1.25 DRILL P PROD1 Wiper back to TO was clean. Tagged at 10533' (official TO) 20:00 - 21 :15 1.25 DRILL P PROD1 Wiper back to window 2.5/3760/550 maintaining 4200 psi bhp leaving fresh mud in hole 21:15-23:00 1.75 DRILL P PROD1 Pull thru window, clean. Circ thru bit while POOH following pressure schedule 2.6/4000. Close TRSSSV after trapping 11 00 psi below 23:00 - 00:00 1.00 DRILL P PROD1 Set injector on legs. LD drilling BHA 6/1/2005 00:00 - 01:1 0 1.17 CASE P LNR1 RU to run liner 01:1 0 - 01 :25 0.25 CASE P LNR1 Safety mtg re: liner 01 :25 - 04:25 3.00 CASE P LNR1 MU Unique indexing shoe, one jt 2-7/8" STL solid liner, O-ring sub, 66 jts 2-7/8" 6.16# L-80 STL slotted liner and 6 jts 2-7/8" STL solid liner. MU BTT 4" GS CTLRT 04:25 - 05:25 1.00 CASE P LNR1 MU BHI MWD assy 05:25 - 07:45 2.33 CASE P LNR1 RIH wI liner on CT. Correct to EOP flag at 5500'. Subtract 6' Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/1/2005 05:25 - 07:45 2.33 CASE P LNR1 correction. Up wt at window: 32k#. On wt: 9k#. Through window ok. RIH open hole. ' Set down a few times near TO. Able to PU and work ahead. Definitely running out of push. Stop at 10473'. Inc pump rate to 1.3 bpm. Release from liner. 07:45 - 08:15 0.50 CASE P LNR1 POOH. Log gr tie in from 8060'. Add l' correction. Liner TOP at 8242' $<'\ o~t\oc.~_ Liner btm at 10474'. 08:15 - 10:00 1.75 CASE P LNR1 Open EDC. Circulate out of hole maintaining whp pressure as per schedule. Close TRSSV w/11 00 psi on well. Pull to surface. 10:00 - 10:30 0.50 CASE P LNR1 LD MWD tools. 10:30 - 14:00 3.50 STWHIP P WEXIT RU to reveres circulate reel to manage e-line slack. Circat 3700 psi @ 3.18 bpm. Cut 72' coil and 10' e-line. MU Kendal connector and Inteq connector. Circulate forward 90bbls. 14:00 - 14:45 0.75 STWHIP P WEXIT PU packer and setting tool assembly. Place in mouse hole to inspect same. Weatherford hand attempted to adjust setting sleeve above packer. Packer fell off setting tool into mouse hole. 14:45 - 16:00 1.25 STWHIP N SFAL WEXIT Order replacement packer and fishing tools from Deadhorse. 16:00 - 17:15 1.25 STWHIP P WEXIT MU replacement KS-WS packer assembly. Scribe to Inteq orienter. Mule shoe lug set to orienter highside. Stab coil. Get on well. Test Inteq mwd tools. 17:15 - 19:20 2.08 STWHIP P WEXIT Run in hole to TRSSSV. Pressure well to 1100 psi. Open valve. RIH at 70'/min circ thru EDC 1.0/2300 following pressure schedule 19:20 - 19:40 0.33 STWHIP P WEXIT Log GR tie-in down from 8075' 1.0/2170/780 Add +1' 19:40 - 20:05 0.42 STWHIP P WEXIT Log CCL tie-in down from 8150 to 8235' 1.0/2180/750 w/o tag (TOL is @ 8242'). Check tie-in with collars on PDS GRlCCL of 5/15/05 and are within 2' when tied back to geo PDC 20:05 - 20:20 0.25 STWHIP P WEXIT PUH to 8200' (end of BHA) 25.4k. SO pump, close EDC holding 1100 psi WHP. Orientation is 8R. Pressure up dn CT at 18.5k to 3950 psi and lost 7.5k string wt. Pump thru at 0.5 bpm. Orientation is now 10R. SO pump w/1050 psi bp. Stack 7k to 8203.5'. PUH 26.3k and left packer with top at +/- 8159' ELMO and end of guide shoe at +/- 8202'. Open EDC PVT 113 (10.0 ppg mud) 20:20 - 21 :50 1.50 STWHIP P WEXIT POOH w/ packer setting assy 1.1/2200 following pressure schedule. Close TRSSSV 21 :50 - 23:00 1.17 STWHIP P WEXIT LD WIS setting tool, standback MWD assy. MU WIS WS/seal assy and jars. Add MWD assy 23:00 - 00:00 1.00 STWHIP P WEXIT RIH w/ BHA #12 @ 70'/min 6/212005 00:00-01:15 1.25 STWHIP P WEXIT Continue RIH w/ WS assy circ thru EDC 0.211700 following pressure schedule 01 :15 - 01 :35 0.33 STWHIP P WEXIT 8100' 28.4k 0.211680/800 RIH w19.7k to wt loss at 8162' CTD. Stack 9k in 3 stages to 8164.3'. PUH 40.5k and sheared off. PUH 10' and park. Bleed off WHP and no flow for 5 min. PVT 110 Preliminary WS depths are TOWS 8150'. RA 8152', BOWS 8159' Printed: 6/2212005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/2/2005 01 :35 - 02:50 1.25 STWHIP P 02:50 - 03:30 0.67 STWHIP N 03:30 - 05:20 1.83 STWHIP N 05:20 - 06:15 06:15 - 08:45 0.92 STWHIP N 2.50 STWHIP N 08:45 - 09:00 0.25 STWHIP N 09:00 - 10:00 10:00 - 12:00 1.00 STWHIP N 2.00 STWHIP N WEXIT POOH w/ WS setting tool circ'ing thru open choke 1.0/1400. Close TRSSSV (just because. . .) PVT 68 DFAL WEXIT Found WS was still attached to setting tool! Wear marks on top of latch collet indicated it had entered packer bore and had at least partially latched. Also, a few minor scars in seal area verified the same-seals were okay. The bottom of the lug was slightly bent outward. But, why the well didn't flow is a real mystery . . . DFAL WEXIT Wait on replacement of complete latch assy from WIS Deadhorse shop Remove orientor and GR from MWD assy DFAL WEXIT Remove existing latch assy and replace with new one DFAL WEXIT Stab coil. Test MWD. Get on well. Run in hole. Open TRSSSV Continue to RIH holding 200 psi whp. DFAL WEXIT 29.4k#up,11k#dnwtat8100'. Tag packer at 8162.2' RIH additional 2'-3' and set dn 5k#. On jars fired. PU to neutral. Set dn 5k#. No jar indication. PU to neutral again. Set dn 5k# over. Jars fired again. PU. SHeared in up direction at 45k# (+/- 15k# over free up wt.) RIH. Set down at 8159' or +/- 3' above initial tag depth of 8162'. This looks good. DFAL WEXIT POOH holding 200 psi whp. DFAL WEXIT At surface. Get off well. WS still attached to running tool. Alignment lug showed signs of deformation on btm of "V", as though it is too far down whipstock mandrel body. Send seal assembly to Deadhorse to shorten lug. Injection test into well at 0.22 bpm @ 1600 psi MU 2" x 4' stinger and 2.5" 00 nozzle as per town. Stab coil and get on well. RIH to clean out seal bore on packer while waiting on ws latch. Tag packer at 8166'. Make three passes. Coil pressured up each time nozzle sat down inside packer. Circulate out of hole. Hold 200 psi WHP. Close TRSSSV with 200 psi on well. Continue out of hole. At surface. Get off well. Unstab coil. LD nozzle assembly. Change packoffs on injector while waiit on whipstock from Deahorse. Also, add GR to MWD assy MU WIS WS assy with shorter lug and corresponding shorter mandrel 00. Add jars and MWD assy PVT 82 RIH w/ BHA #15 at 70'/min 0.4/1150 thru open EDC holding 200 psi bp. Open TRSSSV and saw no pressure change PVT 121 8050' close EDC, pump thru tool 0.5/1300/200. Wt chk 29.2k w/200 psi bp. Begin GR log down from 8030' to packer 11.1 k dn. Corr was less than -0.5' and did not correct Start losing wt at 8159.5' Stack 6k to 8161.2' and no jar action. PUH slowly w/ same 0.5/1300/200 to 31.3k. RIH and set 7k down to 8162.2' w/ no jar action. PUH slow to 33k at 8158.3'. 12:00 - 12:30 0.50 STWHIP N DFAL WEXIT 12:30 -14:30 2.00 STWHIP N DFAL WEXIT 14:30 - 14:45 0.25 STWHIP N DFAL WEXIT 14:45 - 16:30 1.75 STWHIP N DFAL WEXIT 16:30 - 16:45 0.25 STWHIP N DFAL WEXIT 16:45 - 18:00 1.25 STWHIP N DFAL WEXIT 18:00 - 19:00 1.00 STWHIP N DFAL WEXIT 19:00 - 21:15 2.25 STWHIP N DFAL WEXIT 21 :15 - 22:30 1.25 STWHIP N DFAL WEXIT 22:30 - 23:30 1.00 STWHIP N DFAL WEXIT Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 DFAL WEXIT RIH slow and stack 7k and got a jar lick. Repeat last sequence 4 more times, but only got to 30k. PUH to 8148' w/ no overpull. RIH and start losing wt at 8160.3' and stack 8k to 8162.6'. Repeat to 8148' and stack 12k to 8163.6'. PUH w/ no overpull. Doesn't act like it latched-may have left it in hole tho after the first jar lick. .. PVT 120 POOH 1.0/1750/200 to check assy Finish POOH w/ WS setting tools 1.0/1600/200. Close TRSSSV PVT 80 Standback BHA and WS was still attached to setting tool. Bottom of tool had flat spot/scar indicating tool probably never entered packer. LD BHA while discuss Wait for new packer/anchor assy from WIS Deadhorse. Will need to machine off bottom STL pin to give extra room when setting (so that next WS exit will be just below 4-1/2" collar at 8143' ELMO). Power outage in Deadhorse Reconfigure BHI toöl string for running packer Replace reel swivel and PT @ 5k Wait on packer MU replacement/modified 4-1/2 KS-WS packer assembly on Inteq mwd. Stab coil. Get on well. Test mwd. RIH. Hold 200 whp. Open TRSSSV. Continue to RIH. Log gr tie in from 8060' to top of packer at 8159'. No initial correction. Packer top tagged at 8159'. PU l' above packer at 8159'. Orient packer alignment slot to 1 OR. Attempt to close EDC. No repsonse from EDC. Trouble shoot, but no progress. Pull out of hole. At surface. Get off well. LDpacker assy. Change out EDC module. MU packer assy. Stab coil. Get on well. Test MWD. Run in hole at 70 fpm with packer. Tag lower packer at 8159'. PU to neutral weight plus 1 foot. Orient alignment slot to 190 deg. Close EDC. Pressure coil slowly to 4350 psi. Setting tool activated and sheared off packer. Circ 1700 psi @ 0.5 bpm to ensure setting tool has fully stroked. POOH with setting tool. Close TRSSSV. PVT 77 Standback MWD assy. LD packer setting assy. MU WS assy w/ normal latch assy and orient lug to 190 deg to WS. Add MWD assy RIH w/ BHA #18 0.36/1180/200 Open TRSSSV PVT 116 Log tie-in down from 8050' 0.36/1180/200 Corr -1'. Up wt chk @ 8076' 29.0k RIH from 8140' @ 5'/min 11k 0.36/1180/200 and had first wt loss at 8153.0' and stack 2k to 8153.5'. PUH slow to 8152.3' @ 29k. RIH and stack 4k to 8153.6', no jar lick. Stack 5.6k to 8154.0'. PUH to 29k. Stack 6.2k to 8154.5', 8.9k to 8154.9'. PUH to 29k and hold at 25k 8151.4. PUH to 31 k and never got above 30k. PUH to 8149' DFAL WEXIT Start over. RIH and stack 9.6k to 8154.3' and jars went off and 61212005 22:30 - 23:30 1.00 STWHIP N 23:30 - 00:00 0.50 STWHIP N DFAL WEXIT 6/3/2005 00:00 - 01:10 1.17 STWHIP N DPRB WEXIT 01:10 - 02:00 0.83 STWHIP N DPRB WEXIT 02:00 - 04:00 2.00 STWHIP N DPRB WEXIT . .04:00- 06:15 2.25 STWHIP N DPRB WEXIT 06:15 - 07:00 0.75 STWHIP N DPRB WEXIT 07:00 - 09:15 2.25 STWHIP N DPRB WEXIT 09:15 - 10:00 0.75 STWHIP N DPRB WEXIT 10:00 - 10:45 0.75 STWHIP N DFAL WEXIT 10:45 - 13:00 2.25 STWHIP N DFAL WEXIT 13:00 - 14:00 1.00 STWHIP N DFAL WEXIT 14:00 - 16:45 2.75 STWHIP N DFAL WEXIT 16:45 - 17:00 0.25 STWHIP N DFAL WEXIT 17:00 - 19:00 2.00 STWHIP N DFAL WEXIT 19:00 - 20:10 1.17 STWHIP N DFAL WEXIT 20: 10 - 22:25 2.25 STWHIP N DFAL WEXIT 22:25 - 22:40 0.25 STWHIP N DFAL WEXIT 22:40 - 23:05 0.42 STWHIP N DFAL WEXIT 23:05 - 23:25 0.33 STWHIP N Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/3/2005 23:05 - 23:25 6/4/2005 23:25 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:20 02:20 - 04:15 04:15 - 04:25 04:25 - 05:15 05:15 - 05:40 05:40 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00 - 10:30 10:30 - 11 :45 11:45-13:15 13:15 - 13:30 0.33 STWHIP N DFAL WEXIT gained 5k string wt. Stack back the 5k, then 1k more to 10k wob at 8155.8' and lug went in with quick string wt gain then loss back to prior wt. PUH to 29k, solid. PUH to 31 k, solid. PUH to 33k, solid. 35k 8150.6' and -3k wob. 37k -4k wob. 39k -5k wob. 41k -6.2k, 43k -7.7k and lost wt back to neutral at 15k and 0 wob. PUH 29k Looks like a good set PVT 115 Preliminary depths of WS are TOWS 8142, RA 8144, BOWS 8151' 0.58 STWHIP N DFAL WEXIT POH 1.0/1500/200 1.00 STWHIP N DFAL WEXIT Fin POOH w/ WS setting tool 1.0/1500/200. Close TRSSSV PVT 76 0.50 STWHIP N DFAL WEXIT LD MWD assy. LD setting tool w/o WS attached 0.83 STWHIP N DFAL WEXIT Reconfigue MWD tools for milling ops and test. MU HCC 3.80" window mill and 3.80" SR on WIS straight motor. Add MWD assy 1.92 STWHIP N DFAL WEXIT RIHw/BHA#19circthrumill 0.3/1250/200 PVT 114 0.17 STWHIPN DFAL WEXIT Parkat8100'andSI@choke. Perform pressure test to 2000 psi. Injected at 0.48 bpm @ 1850 psi for 5 min. Red rate to 0.24 bpm and stabilized @ 1650 psi (which is similar to prior test when ensuring tailpipe was clear) No change to IA and OA, both =0 0.83 STWHIP N DFAL WEXIT Will try to push into place. Open EDC. Chk up wt 32k w/ no pump. RIH 11.2k w/ 0.25/940/0 looking for WS and tag at 8142' CTD and set 6k wob. Stack additional wt in stages to a total of 8.3k wob at 8144.8'. Repressure well bore to 2000 psi and injected 0.46 bpm @ 1550 psi. Red rate to 0.3/2100/1300 PUH 24.7k 20'. Take a run at 25'/min and stack 8.3k wob and no pressure increase. PUH 25k 20'. Take a run in 15'/min increments up to 100'/min and stack max surface CT wt, but still only showing 8.3k wob w/ no WHP incr 0.42 STWHIP N DFAL WEXIT Will try to turn and push into place. Bleed off WHP. Close EDC. Start pump at milling rate w/ open choke 2.5/3600/60 Ease in hole to tag WS at 8.4k at 1 '/min and first MW at 8142.6' and drilled off. Stack 5k quickly. SO pump, PUH 20' and park. Close choke and pressure test to 2040 psi. Looks like we gained a little. SO pump and bled to 1100 psi in 10 min PVT 102 0.33 STWHIP N DFAL WEXIT Bleed off WHP and circ 0.6/1250 w/ open choke while do crew change 1.00 STWHIP N DFAL WEXIT Spud on whipstock with milling assy a few more times. Run into same at 120 fpm. Pressure well to 1800 psi. Well bleeding off to 1000 psi in 15 minutes. No improvement over previous spud/pressure cycle. Discuss situation with town. Decide to pull whipstock tray due to concerns about orientation and how securely ws tray is latched. 2.00 STWHIP N DFAL WEXIT POOH with milling assy. Call for fishing tools from Deadhorse. 1.50 STWHIP N DFAL WEXIT Wait on fishing tools. 1.25 STWRWrq----DFAL-WE)~~r---Mt}-wMi!'>s-stÐ6k__FemevaI-B-Ajt2QChox.1all, mtr. iars, Inteq mwd) 1.50 STWHIP N DFAL WEXIT Stab coil. Get on well. Run in hole. 0.25 STWHIP N DFAL WEXIT 31k#up, 11k#dnwt. Circ 1500 psi @ 0.7bpm. Tag fish at 8144'. Inc rat to 2.0 bpm, set dn 10k#. Jars went Printed: 6/22/2005 2:10:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/4/2005 13:15 - 13:30 13:30 - 15:15 16:00 - 17:00 17:00 - 19:10 19:10 - 19:35 19:35 - 20:00 0.25 STWHIP N 1.75 STWHIP N 1.00 STWHIP N 2.17 STWHIP;N 0.42 STWHIP N 0.42 STWHIP N DFAL WEXIT off down. Set dn 12k# and pump press up to 3000 psi. Pump at 0.7 bpm, 1900 psi. Mtr is stalled. PU 40k#. Jars fired. Set dn to 6k# to re set jars. PU to 44k#. Jars fired. PU to 48k# Set dn to 5k# to re-set jars. PU to 48k#. Jars fire. PU to 52k#. Set down to 5k#. PU to 50k#. Jars fired. PU to 55k#. Set down to 5k#. Re-set jars. PU to 52k#. Jars fired. PU to 55k#. Fish (or something else) came free. Open EDC. DFAL WEXIT Pull out of hole. Hold 200 psi whp. Close TRSSSV. Continue to POH. Parted CT drill DFAL WEXIT MU replacement WS and latch assembly on BHA. Include orienter with lug scribed to HS TF. Stab coil. Test mwd. Get on well. DFAL WEXIT Run in hole @ 70'/min 1.0/1600/200 thru EDC. Open TRSSSV DFAL WEXIT . 8100' Close EDC. Circ 0.3/1170/200 Wt chk 29k. OrientTP' to 190R. RIH at 1 O'/min from 8140' 11.5k and first wt loss at 8154.1'. Continue RIH 10'/min and stop w/-8k surface, -9.4k wob at 8159.5'. Jars went off. Pressure wellbore to 2140 psi and hold for 4 min w/o loss. IA and OA gained 1 psi each. Bleed WHP to zero PVT 99 DFAL WEXIT Circ thru tool 0.5/1100/10 PUH to 2k over and hold to open jars. Work string wt up in stages to 39k. RBIH and stack 10k to close jars. PUH to 40k until jars hit and released from WS. PUH 50'. SI choke and pressure wellbore to 2150 psi and hold for 2 min w/ no loss-good to go, 2.7 days later. . . Preliminary WS depths are TOWS 8142' BOWS 8151' w/ no RA tag. Will use prior tie-in points above window at 8020' POOH circ thru tool 1.0/1400/20. Close TRSSSV PVT 58 LD WS setting tool and MWD tools SI swab. Stab onto lub. Reverse slack back (two attempts and no slack pumped) 3.9/4500 Need more rate Fire drill Fill pit #4 and CT w/ water, then reverse slack back wI water 5.0/4500. Cut off 63' of CT before finding wire. Install CTC, PT 40k. Meg test 59 ohms. PT 3500 psi. Displace water in CT w/ 10# used mud 2.0/1700. Meanwhile, MU milling BHA WEXIT RIH w/ BHA #22 (3.80" window mill/SR). Open TRSSSV WEXIT Tag ws at 8144' with pumps off. PU. 3800 psi fs @ 2.7 bpm in/out. Tag WS at 8143'. Begin time milling at 0.1 ft per 5 or 6 min, or as limited by DHWOB (> 5k#). IAlOAlPVT: 20/24/94 bbls. WHP/BHP/ECD: 81/4115/11.5 ppg. WEXIT Time mill from 8146'. 200-300 dpsi. DHWOB: 4k-5k#. Increase DPSI to 500-600 psi. DHWOB:6k-7k# and make a foot. Reduce DPSI to 200-300 psi. DHWOB: 5k# or less. WEXIT Time / WOB mill from 8146'. 150-300 dpsi. DHWOB: 2k-3k#. Lot~ of metal on magnets. WEXIT Begin swap to 9.2 ppg. Continue to mill. 150-250 dpsi. DHWOB: 2k-3k#. 20:00 - 21 :50 1.83 STWHIP N DFAL WEXIT 21 :50 - 22:30 0.67 STWHIP N DFAL WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 6/5/2005 00:00 - 04:45 4.75 STWHIP P WEXIT 04:45 - 06:45 06:45 - 08:30 08:30 - 10:00 10:00 - 13:00 13:00 - 15:00 2.00 STWHIP P 1.75 STWHIP P 1.50 STWHIP P 3.00 STWHIP P 2.00 STWHIP P Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1F-01 ~'- L 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/5/2005 15:00 - 15:45 0.75 STWHIP P WEXIT Appear to be in formation. Drill to 8160'. Catch btms up sample. A lot of sand noted. Uncorrected window depth: Top: 8145' Btm: 8151' 15:45 - 18:00 2.25 STWHIP P WEXIT Back ream window. Make three up and down passes. Dry drift down. Swap from used 10.0# mud to fresh 9.2# Flopro. PUH to 8000' EOP and flag 18:00 - 18:30 0.50 8TWHIP P WEXIT SO pump, 81 well for crew change. After 25 min WHP=O, DHP 2882 psi (ECD 9.65). Open choke and no flow PVT 149 18:30 - 20:15 1.75 STWHIP P WEXIT POOH circ thru mill w/ open choke 1.0/1425/25. Close TRSSSV. PVT 105 20:15 - 20:45 0.50 STWHIP P WEXIT LD milling assy. Mill and SR gauged 3.80" go, 3.79" no go. Mill had center wear 20:45 - 21 :50 1.08 DRILL P PROD2 Reconfigure MWD assy for drilling and test. MU build assy for 45 DLS 21 :50 - 00:00 2.17 DRILL P PROD2 RIH w/ BHA #23 (3.2 deg motor, HCCbiibit) 6/6/2005 . 00:00,00:15 0.25 DRILL P PROD2 Log tie-in down from 8020' 0.3/1000/0'; Corr -1.5' 00: 15 - 00:25 0.17 DRILL P PROD2 RIH w/ 0.3/1100/0 and clean thru window af 1 OR. Tag TO at 8159'. PUH 30k Start motor 2.6/3300/60 RIH 16k PVT 337 00:25 - 01 :00 0.58 DRILL P PROD2 Drill from 8158' 2.6/2.6/3320/15R w/ open choke and 60 psi induced. DHP 3270 psi w/1 0.8 ECD. Work for a bit to get believable TF. Losing some mud over shaker due to high LSRV PVT 333 01 :00 - 02:00 1.00 DRILL P PROD2 Drill from 8175' 2.6/3280/1 OR at avg 50'/hr contol drilling PVT 325 02:00 - 02:20 0.33 DRILL P PROD2 Drill from 8220' 2.64/3300/15R w/1 k wob, 200 psi diff at DHP 3315/ECD 10.9 Penetration rate incr 100-120'/hr in 'B' shale. Drill to 8262' and differentially sticky PVT 322 02:20 - 02:30 0.17 DRILL P PROD2 Wiper to window, clean both ways 02:30 - 03:45 1.25 DRILL P PROD2 Drill from 8262' 2.6/3300/90R w/1.7k wOb, 300 psi diff at DHP 3335/ECD 10.9 at 80'/hr and guessing 90 deg at bit. Drill from 8320' 15R to 90R in prep for lateral assy. Drill to 8350' EOB PVT 318 03:45 - 04:00 0.25 DRILL P PROD2 Wiper to window 2.6/3150, clean 04:00 - 06:15 2.25 DRILL P PROD2 Park at 8100' and open EDC aftertrapping 500 psi WHP. POOH 2.66/2940 following pressure schedule. Close TRSSSV. Finish POOH to surface. 06:15 - 07:00 0.75 DRILL P PROD2 At surface. Get off well. Unstab coil. LD BHA. Bit has one broken cutter on gauge blade and one broken cutter near center of nose. One jet was plugged between gauge cutter blades. 07:00 - 11 :00 4.00 BOPSUP P PROD2 P¡¡rform weekly BOP equipment test. Witness waived by AOGCC rep J. Jones. 11 :00 - 12:00 1.00 DRILL P PROD2 MU BHA #23 (HYC bi w. 0.8 mtr & resistivity tool). Stab coil. Tets mwd tools. Get well. 12:00 - 13:15 1.25 DRILL P PROD2 Run in hole. Put 500 psi on well. Open TRSSSV. Continue to run in hole. Maintain BHP as per schedule. 13:15 - 14:15 1.00 DRILL P PROD2 Log gr tie in from 8040'. Add 7' correction. MADD pass for resistivity from window to 8350'. 14:15 - 17:30 3.25 DRILL P PROD2 Drill ahead from 8350'. 3300 psi @ 2.7 in/out DPSI: 250-350. DHWOB: 2k-3k#. ROP: 40-80 fph. WHP/BHP/ECD: 73/3301/10.85 ppg. IAJOAJPVT: 45/16/326 bbls. I NC/AZMlTF: Printed: 6/2212005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/6/2005 14:15 - 17:30 3.25 DRILL P PROD2 99.2I237/100R. 17:30 - 18:00 0.50 DRILL P PROD2 Wiper to window, clean both ways PVT 308 18:00 - 20:15 2.25 DRILL P PROD2 Drill ahead from 8500' 2.7/3280175R w/2-3k wob, 150-300 psi diff w/ DHP 3360/ECD 11.0 at 90 deg in 75 api rock at 70'/hr. Lots of stalls (harder rock) and slower penetration rate after 8550'. Also, attempting to push due to directional concerns, but not getting required turn. Drill to 8637' PVT 297 20:15 - 20:35 0.33 DRILL P PROD2 Wiper to window, clean. Open EDC at 8100' trapping 3400 psi DHP w/ 500 psi surface press 20:35 - 22:00 1.42 DRILL P PROD2 POOH for motor bend 2.66/3160 following pressure schedule. Close TRSSSV PVT 251 22:00 - 22:45 0.75 DRILL P PROD2 Change motor bend from 0.8 to 1.8 deg. Chk bit 0-1-1 (one small chip) 22:45 - 00:00 1.25 DRILL P PROD2 RIH w/ BHA #24 following pressure schedule circ thru bit 0.6/1400. Open TRSSSV 61712005 00:00 - 00:15 0.25 DRILL P PROD2 Log tie-in down from 8050'. Corr -1' 00:15 - 00:30 0.25 DRILL P PROD2 Wiper to TD'wl one set down at 8250' 2.0/2500. Tagged TD at .8640' PVT290 00:30 -01:10 0.67 DRILL P PROD2 Drill from 8640' 2.74/3400175Rw/2-3kwob, 300 psi diff w/ DHP 3335, ECD 10.96. Got bottoms up gas back (from UB condition pulling thru window on trip earlier) which set off alarms. Drill to 8685' and stall PVT 287 01:10 - 02:30 1.33 DRILL P PROD2 Drill from 8685' 2.65/3300/45R w/2k wob, 0-300 psi diff, DHP 3340, ECD 11.02. Drill w/ several stalls and may be mapped fault #1. Broke thru at 8695' and back into steady digging sand which cut DLS back to less than 10. Drill to 8800' PVT 278 02:30 - 03:10 0.67 DRILL P PROD2 Wiper to window, clean both ways PVT 270 (changed both shaker screens to 175) 03:10 - 05:15 2.08 DRILL P PROD2 Drill from 8800' 2.68/3325/35R w/2-3k wob, 300 psi diff, DHP 3347, ECD 11.07 at 90'/hr. Drill to 8950' PVT 266 05:15 - 06:00 0.75 DRILL P PROD2 Wiper to window, clean both ways 06:00 - 10:00 4.00 DRILL P PROD2 Drill ahead from 8950'. 3100 psi fs @ 2.7 in/out. 300-400 dpsi. DHWOB: 0.5k-1.0k#. ROP: 40-80 fph. WHP/BHP/ECD: 73/3350/11.0 ppg. IAlOAlPVT: 256/227/264 bbls. INC/AZMITF: 93.9/282175r. Apear to have build established at 93 deg inc. 10:00 - 11 :00 1.00 DRILL P PROD2 Wiper trip to below window. Hole smooth in and out. 11 :00 - 13: 15 2.25 DRILL P PROD2 Drill ahead from 9100'. 3200 psi fs @ 2.4 in/out. 300-400 dpsi. DHWOB: 2.0-3.0k#. ROP: 40-80 fph. WHP/BHP/ECD: 65/3375/11.2 ppg. IAlOAlPVT: 350/326/254 bbls. INC/AZMITF: 88.7/307/100L. 13:15 - 14:45 1.50 DRILL P PROD2 Wiper trip. Hole smooth in and out. Micro motion out plugged off several times. Found several large chunks of rubber material in micro out. PVT 252 14:45 - 18:50 4.08 DRILL P PROD2 Drill ahead from 9250' 2.5/3300/115L w/1-4k wOb, 150-400 psi ditt, DHP 3385, ECD 11.18 at 40'/hr at 91 deg and starting slow drop 18:50 - 20:00 1.17 DRILL P PROD2 Wiper trip to window. No problems. 20:00 - 23:05 3.08 DRILL P PROD2 Directionally drill ahead f/9400' Q=2.57/3400psi TF=160-180L MW=300-400psi WOB= 2-3k Ann= 3371 psi ECD 11.2ppg. Drilled to 9550'. No significant drop in angle for the last 150'. 23:05 - 00:00 0.92 DRILL P PROD2 Wiper trip to window. Discuss apparent inability to drop hole angle with town geo's. Agreed to drill ahead another 30-40'. If Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/7/2005 23:05 - 00:00 0.92 DRILL P PROD2 unable to drop angle will trip for higher bend motor. 6/8/2005 00:00 - 00:30 0.50 DRILL P PROD2 Finish wiper trip. No problems. 00:30 - 01 :30 1.00 DRILL P PROD2 Directionally drill ahead f/9550' Q=2.6/3450psi MW=200-400psi Ann=3390psi ECD=11.23 WOB=2-3k TF=180 ROP=50-60fph Swapping out to new flo-Pro mud system. Drilled to 9592'. Unable to drop angle. 01 :30 - 02:30 1.00 DRILL P PROD2 Wiper trip while preparing to swap hole to new mud system. 02:30 - 05:30 3.00 DRILL P PROD2 TOH following Pressure Schedule. At 700' closed SSSV continue OH. Unalbe to bleed off well. RIH to 200'. Repressure well to 500psi. Cycle SSSV. TOH bleed down well. 05:30 - 07:00 1.50 DRILL P PROD2 Set back injector. PU BHA and inspect motor settings and everything is tight and in spec. Change bit to M09X. Pulled bit was 2-2-1. Also, inspected annular element 07:00 - 08:30 1.50 DRILL P PROD2 RIH w/ BHA #26 (1.8 deg motor, 3.75" M09X bit) circ thru EDC 0.47/1480 following pressure schedule. Open TRSSSV PVT 393 08:30 , 08:50 0.33 DRILl' P PROD2 Log tie-in down from 8050', corr +2' 08:50 - 09:30 0.67 DRILL P PROD2 Wiper thru window, clean. RIH to TO 2.5/3140, clean. Tag at 9595' PVT 403 09:30 - 10:45 1.25 DRILL P PROD2 Drill from 9595' 2.57/3150/170L w/2.5k, 100 psi diff, 3309 psi DHP, 10.94 ECD purposely holding back and letting bit cut probable hard formation interface. Within 30' the NB incl is showing a 3 deg drop 10:45 - 12:30 1.75 DRILL P PROD2 Resume drilling at normal penetration rate while bringing TF up to level out and break extreme downward trend. Drill to 9700' and are back on track at 87 deg incl. See GR change at 9635' and corresponding res change 12:30 - 13:15 0.75 DRILL P PROD2 Drill from 9700' 2.55/3150/90-1 OOL w/3-4k wob, 100-300 psi diff, DHP 3333, ECD 11.0 and now in a shale(?). Have trouble making hole and sticky. Drill to 9717' 13:15 - 15:00 1.75 DRILL P PROD2 Wiper to window, clean both ways. Adding Flo Vis to new mud 15:00 - 16:00 1.00 DRILL P PROD2 Drill from 9717' 2.62/3150/1 OOL w/1-3k wob, 100-300 psi diff, DHP 3314, ECD 10.93 and work to get thru shale. Drill to 9727' and faster penetration PVT 408 16:00 - 16:30 0.50 DRILL P PROD2 Ream and backream to 50' above 9727' and bring TF to right side 16:30 - 19:25 2.92 DRILL P PROD2 Drill from 9727' to 9850'. Q= 2.6/3100psi MW 300-400psi 19:25 - 21 :15 1.83 DRILL P PROD2 Wiper out of window. No problems, clean. Set reel brake. Tighten up backing plates on reel drive plates. Pull up to log depth. 21 :15 - 21 :30 0.25 DRILL P PROD2 Log tie-in. +5 correction 21 :30 - 22:30 1.00 DRILL P PROD2 TIH seen slight motor work at 8245' and 8280' 22:30 - 00:00 1.50 DRILL P PROD2 Directionally drill ahead f/9855' to 9936' Q=2.6/3160psi MW= 100-300 psi Ann= 3750psi ECD 11.18ppg WOB= 2-4k ROP= 30'/hr 6/9/2005 00:00 - 01 :25 1.42 DRILL P PROD2 Directionally drilled from 9936' to 10016'. 01 :25 - 03:30 2.08 DRILL P PROD2 Wiper trip to window. Hole in good shape. 03:30 - 06:10 2.67 DRILL P PROD2 Directionally drill f/1 0016' Q=2.63/ 3200psi MW 200psi Ann=3385 ECD 11.13 WOB 2-3k 20-30'/hr. Hard to make hole and sticky. Drill to 10095' PVT 404 06:10 - 07:40 1.50 DRILL P PROD2 200' wiper and 10k overpulls at 10016'. Continue wiper and go to window, clean. Pull thru window, clean Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/9/2005 07:40 - 08:00 0.33 DRILL P PROD2 Log tie-in down from 8050'. Corr +3' PVT 388 08:00 - 09:00 1.00 DRILL P PROD2 RIH thru window, clean. Wiper to TO. Wt loss beginning at 10023' until set down at 1 0088'. Ream w/ neg wt to 10095' 09:00 - 10:25 1.42 DRILL P PROD2 Drill from 10095' 2.6/3180/90L w/3k wob, DHP 3334, ECD 10.95 w/-8k surface wt at less than 10'lhr to 10103' PVT 400 Geo sees sand in samples, so bit or motor must be shot 10:25 - 11 :30 1.08 DRILL P PROD2 Wiper to window 2.6/2900 w/10k overpull at 10015' 11 :30 - 13:30 2.00 DRILL P PROD2 POOH to check BHA 2.6/2840 following pressure schedule. Close TRSSSV. Check for flow at 300' and had to recycle TRSSSV shut 13:30 - 14:20 0.83 DRILL P PROD2 Change bit and motor. Bit was 3-2-1, motor was okay PVT 143 14:20 -16:00 1.67 DRILL P PROD2 RIH w/ BHA #27 (HCC bi bit, 1.2 deg motor) following pressure schedule. Open TRSSSV 16:00 - 16:15 0.25 DRILL P PROD2 Tie-in down from 8050', corr +2' 16:15 - 17:50 1.58 DRILL P PROD2 RIH thru window, clean. Wiper to 9600' was clean. Precautionary ream at 20'/min to 9935' and had set down and were temporarily immobile. Precautionary reàm5-1 O'/min to set down and sticky pickup at 10018'. Assume siderite streaks. Ream thru this one after 3 tries. Ream to 10089' andset down and became temporarily bit stuck. Ream down slower. MW at 10098' and sticky pickup. Find TO at 10100' and it is hard 17:50 - 18:05 0.25 DRILL P PROD2 Wiper to 9900' and was clean. Wiper back to TO 18:05 - 21 :45 3.67 DRILL P PROD2 Directionally drill ahead f/10100' Q=2.53/3090psi. Ann=3390 ECD=11.15ppg avg 30'/hr w/ 2-3k wob making short 50' wiper trips after stacking out. hard/stacking 10132-10137' then took off drilling good intil10170'. Resistivity dropping GR increasing. Back to slow drilling. wob=2.6k Pumped 20bbl1 OOk sweep. Didn't see excess cuttings across shaker. Drilled to 10210' TO 21 :45 - 22:30 0.75 DRILL P PROD2 Wiper trip to 7900'.. Condition hole for liner. Pump another 20 bbl hi-vis pill. Hole good shape. 22:30 - 22:50 0.33 DRILL P PROD2 Log final tie-in +7' 22:50 - 00:00 1.17 DRILL P PROD2 Wiper trip. Small bobble at 9980' good to revised TO of 10216'. 6/10/2005 00:00 - 00:45 0.75 DRILL P PROD2 Wiper back to 9800' then to TO. Hole good shape. 00:45 - 03:30 2.75 DRILL P PROD2 TOH laying in new Flo-Pro. Flag EOP at 8100'. Once above 2400' closed SSSV trapping 500psi below. Pull to 485' open Baker choke check for flow - dead. TOH 03:30 - 04:15 0.75 DRILL P PROD2 LD BHA #27 04:15 - 04:30 0.25 CASE P PROD2 PJSM review liner running hazards and procedures. 04:30 - 06:00 1.50 CASE P PROD2 PU 2-7/8" 6.16# STL slotted liner. 06:00 - 06:15 0.25 CASE P PROD2 Crew change safety mtg re: run rest of liner 06:15 - 08:50 2.58 CASE P PROD2 Fin MU slotted liner assy, BHA #28. MU BTT 4" GS LRT PVT 250 08:50 - 10:30 1.67 CASE P PROD2 RIH w/ slotted liner on CT following pressure schedule circ thru GS 0.3/1450. Open TRSSSV. PVT 282 10:30 - 11 :00 0.50 CASE P PROD2 8100' 34k114.8k 0.3/1460 RIH thru window, clean. RIH to 10100' w/ nary a bobble at 70'/min w/ final RIH wt 4.3k PVT 293 11 :00 - 11 :40 0.67 CASE P PROD2 Park at 10100' CTD. Incr rate to 1.5/4600 psi and release from liner (two tries) leaving top at 8163' CTD. PUH to 8000'. Log tie-in down and had no corr. RIH to tag and inadvertently latched up at 8163'. Release (in two tries) as before after PUH Printed: 6/22/2005 2: 1 0:34 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-01 1 F-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/23/2005 Rig Release: 6/10/2005 Rig Number: 2 Spud Date: 5/23/2005 End: 6/11/2005 6/10/2005 11 :00 - 11 :40 0.67 CASE P PROD2 47k to 10090' and getting a run at it. TOL @ 8163.7', BOL @ 10100' 11:40 - 13:20 1.67 CASE P PROD2 POOH following pressure schedule. Close TRSSSV PVT 251 13:20 - 13:40 0.33 CASE P PROD2 Standback MWD assy. LD BTT GS assy 13:40 - 14:30 0.83 FISH P PROD2 WO WIS tools-stuck behind Nabors 3S rig move 14:30 - 15:00 0.50 FISH P PROD2 MU WS retrieval BHA 15:00 - 16:30 1.50 FISH P PROD2 RIH w/ SHA #29 circ thru tool 0.5/1400 following pressure schedule PVT 291 16:30 - 16:45 0.25 FISH P PROD2 Log tie-in down from 8050', corr + 1 ' 16:45 - 17:05 0.33 FISH P PROD2 RIH w/o pump and first wt loss at 8142'. Start motor and engage. Use down jars, then PU to 49k and up jars fired. RBIH and lost wt at 8140' 17:05 - 19:00 1.92 FISH P PROD2 Open EDC. POOH 0.7/1500 following pressure schedule. Trap 600psi on well and close SSSV pull to 450' open Baker choke bleed off. SSSV not holding. Repressure and cycle SSSV. Bleed off and holding. Tag up at surface. 19:00 - 20:10 1.17 FISH P PROD2 Setback injector. Confirmwhipstock on. LD BHi tools and Weatherford's retrievable whipstock. 20:10 - 20:30 0.33 CASE P PROD2 PU nozzle stab injector: 20:30 - 22:00 1.50 CASE P PROD2 TIH. Pressure up well to 600psi and open SSSV seeing 350psi on well after opened. TIH to 8100' 22:00 - 00:00 2.00 WHSUR P PROD2 TOH displacing Flo-Pro with seawater to 2400'. Close SSSV. Freeze protect with diesel f/ 2350' to surface. 6/11/2005 00:00 - 00:15 0.25 WHSUR P PROD2 Finish FP well with diesel f/ 2350' to surface. Pumped total of 34 bbls. Close Master and Swab valves. (Spot N2 equipment) 00:15 - 00:30 0.25 DEMOB P POST PJSM: Review procedures for pickling coil. 00:30 - 01 :40 1.17 DEMOS P POST Pump 10bbls of bleach water followed by 60bbls SW then 15 bbls diesel. Taking returns to Tiger Tank. 01 :40 - 01 :55 0.25 DEMOB P POST PJSM: review blow down procedures using N2. 01 :55 - 03:00 1.08 DEMOB P POST Line-up valves. PT to 3000psi. Blow down to TT. Bleed down. 03:00 - 04:30 1.50 DEMOB P POST Break off well with injector. UD BHA. Remove lubricator sections. Cut off CTC. RU pull back cable to secure end of coil to reel. Cleaning centrifuges and mud pits. 04:30 - 08:00 3.50 DEMOB P POST Pull back coil and secure to reel. 08:00 - 11 :00 3.00 DEMOB P POST Load out reel onto lowboy. NO BOPE. Install tree cap and test to 5000psi. Release rig at 1100 hrs 6-11-2005 Printed: 6/22/2005 2:10:34 PM . . Halliburton Sperry-Sun Western North Slope ConocoPhillips 1 F-01 A Job No. AKMW3657484, Surveyed: 7 May, 2005 Survey Report 19 May, 2005 Your Ref: API 500292088901 Surface Coordinates: 5958365.15 N, 539591.86 E (70017' 49.9028" N, 149040' 45.8166" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 119.80ft above Mean Sea Level speI"""I"""Y-sur, DFUL.L.INES seAVlces A Halliburton Company · Halliburton s.ry-Sun Survey Report f¡ 01A Your Ref: API 5002 088901 Job No. AKMW3657484, Surveyed: 7 May, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6204.80 46.980 352.620 4178.17 4297.97 3929.94 N 685.41 W 5962291.42 N 538885.75 E 6253.00 46.230 352.710 4211.28 4331.08 3964.68 N 689.89 W 5962326.14 N 538881.10 E 1.562 6298.75 46.060 348.960 4242.98 4362.78 3997.23 N 695.14 W 5962358.67 N 538875.67 E 5.922 6394.84 40.570 340.220 4312.94 4432.74 4060.70 N 712.37 W 5962422.04 N 538858.11 E 8.450 6486.92 37.010 328.920 4384.79 4504.59 4112.69N 736.84 W 5962473.90 N 538833.36 E 8.592 6581.79 35.980 341.460 4461.16 4580.96 4163.64 N 760.48 W 5962524.73 N 538809.46 E 7.925 6676.31 34.690 353.440 4538.36 4658.16 4216.76 N 772.40 W 5962577.78 N 538797.26 E 7.447 6769.02 31.960 2.920 4615.87 4735.67 4267.51 N 774.16 W 5962628.53 N 538795.23 E 6.335 6861.02 27.480 15.510 4695.83 4815.63 4312.35 N 767.24 W 5962673.40 N 538801.92 E 8.328 6953.80 23.760 30.470 4779.56 4899.36 4349.14 N 752.01 W 5962710.27 N 538816.95 E 8.014 7048.51 23.380 46.530 4866.46 4986.26 4378.54 N 728.67 W 5962739.79 N 538840.13 E 6.774 7142.89 22.530 59.300 4953.42 5073.22 4400.67 N 699.52 W 5962762.08 N 538869.17 E 5.343 7236.57 21.590 72.050 5040.29 5160.09 4415.16 N 667.67 W 5962776.73 N 538900.94 E 5.199 7329.98 18.880 87.590 5127.99 5247.79 4421.09 N 636.19 W 5962782.83 N 538932.39 E 6.419 7422.66 16.060 107.340 5216.46 5336.26 4417.90 N 608.94 W 5962779.78 N 538959.65 E 7.040 7515.51 15.870 134.360 5305.86 5425.66 4405.18 N 587.58 W 5962767.17 N 538981.08 E 7.938 7610.16 17.810 157.460 5396.54 5516.34 4382.73 N 572.76 W 5962744.81 N 538996.02 E 7.308 7699.88 22.030 170.750 5480.92 5600.72 4353.42 N 564.79 W 5962715.54 N 539004.15 E 6.872 7797.06 26.760 186.820 5569.50 5689.30 4313.65 N 564.45 W 5962675.76 N 539004.69 E 8.347 7892.08 32.800 199.680 5652.01 5771.81 4268.08 N 575.68 W 5962630.14 N 538993.70 E 9.221 7985.06 39.330 206.850 5727.17 5846.97 4218.01 N 597.51 W 5962579.95 N 538972.14 E 8.353 8077.49 46.690 211.620 5794.73 5914.53 4163.15 N 628.42 W 5962524.93 N 538941.52 E 8.702 8170.82 53.600 213.440 5854.50 5974.30 4102.81 N 666.97 W 5962464.39 N 538903.29 E 7.553 8263.97 54.830 214.370 5908.97 6028.77 4040.10 N 709.12 W 5962401.46 N 538861.47 E 1.549 8336.00 54.830 214.370 5950.46 6070.26 3991.50 N 742.36 W 5962352.69 N 538828.48 E 0.000 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 349.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8336.00ft., The Bottom Hole Displacement is 4059.95ft., in the Direction of 349.464° (True). 19 May, 2005· 16:18 Page 2 of 3 Western North Slope Comments Measured Depth (ft) 6204.80 6253.00 8336.00 . Halliburton S.ry-Sun Survey Report" 1A Your Ref: API 5002 088901 Job No. AKMW3657484, Surveyed: 7 May, 2005 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) 4297.97 4331.08 6070.26 0.00 4297.97 Comment 3929.94 N 3964.68 N 3991.50 N 685.41 W 689.89 W 742.36 W Tie On Point Window Point Projected Survey Survey tool program for 1F-01A 0.00 6204.80 19 May, 2005 -16:18 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 6204.80 8336.00 4297.97 Good Gyro - FINDER-MS (1 F-01) 6070.26 MWD Magnetic (1 F-01A) Page 3 of 3 TUBING (0-6100. 00:4.500. 10:3.958) SURFACE ~ (0-2630. 00:10.750, W:45.50) ROOUCTION (0-6253, 00:7.000. W:26.00) Gas Lift ldrellDummy Valve 2 (5300-5301. 00:5.984) Gas Lift ldrel/Oummy Valve 3 (5998-5999, 00:5.984) NIP (6042-6043, 00:5.200) SEAL (6085-6086. 00:4.980) PACKER (6086-6087. 00:6.060) HANGER (6111-6112. 00:5.810) LINER (6086-8335, 00:4.500. W:12.60) ConocoPhllllps Allka. Inc. I [ ~ ... API: 500292088901 SSSV Type: TRDP Annular Fluid: Reference Log: 44' RKB Last Tag: Last Tag Date: Casing String - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER WINDOW Tubing String - TUBING Size I Top 4.500 0 Gas Lift MandrelSValves St MD TVD Man Man Type V Mfr V Type V OD Latch Port Mfr 1 3291 2599 CAMCO KBG-2 2 5300 3740 CAMCO KBG-2 3 5998 4161 CAMCO KBG-2 other (plugs, equip., etc.) - LINER JEWELRY Depth TVD Type Description 6086 4219 PACKER ZXP LINER PACKER WITH HOLD DOWNS - HR PROFILE 6111 4235 HANGER FLEX LOCK II HYDRAULIC LlINER HANGER 6120 4241 BUSHING CROSSOVER BUSHING Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 35 35 HANGER 2400 2083 SSSV 6042 4190 NIP 6085 4218 SEAL General Notes Date I Note 5/11/2005 WELL SIDETRACKED 1F~1A . Well Type: PROD Orig Completion: Last W/O: Ref Log Date: , TO: 8336 ftKB Max Hole Angle: 56 deg @ 4405 Size 16.000 10.750 7.000 4.500 4.500 Top o o o 6086 6086 Bottom 80 2630 6253 8335 6087 Bottom 6100 TVD 4228 DMY DMY DMY Description FMC GEN V TUBING HANGER CAMCO TRM-4PE-CF SSSV HALLIBURTON 'X' NIPPLE BAKER LOCATOR/80-40 SEAL ASSEMBLY 1.0 1.0 1.0 KRU Wt 12.60 Angle @ TS: Angle @ TO: Rev Reason: Last Update: TVD 80 2218 4331 6070 4219 I Grade I L-80 BK-5 BK-5 BEK 0.000 0.000 0.000 Wt 65.00 45.50 26.00 12.60 0.00 1 F -01 A deg @ 55 deg @ 8336 Set DMY 5/28/2005 Grade H-40 K-55 K-55 L-80 Thread WELD BTC MOD IBTM Thread IBTM TRO Date Run 5/11/2005 5/11/2005 Vlv Cmnt o o o ID 3.875 3.910 3.970 ID 3.985 3.812 3.813 3.940 ConocJr)hillips ~aker Hughes INTEQ . B~r Hughes INTEQ Survey Repo Fietd: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: KRU 1 F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Levet: Nortbing: Easting: 5958733.30 ft 539521.50 ft 0.00 ft 0.00 ft Well: 1 F-01 Well Position: +N/-S -368.55 ft Nortbing: 5958365.15 ft +E/-W 68.43 ft Easting: 539591.86 ft Position Uncertainty: 0.00 ft Wellpatb: 1F-01A - CTD Current Datum: Magnetic Data: Fietd Strengtb: Vertic at Section: 1 F-01A 2/11/2005 57583 nT Deptb From (TVD) ft 4.80 Heigbt 119.80 ft +N/-S ft 0.00 Survey Program for Definitive Wellpatb Date: 5/12/2005 Validated: No Actual From To Survey ft ft 104.80 6253.00 6298.75 8170.82 8200.00 10533.00 GMS (104.80-8719.80) (0) MWD (6298.75-8336.00) (1) MWD (8200.00-10533.00) Annotation Map Zone: Coordinate System: Geomagnetic Modet: Alaska, Zone 4 Well Centre bggm2004 Latitude: 70 17 Longitude: 149 40 Nortb Reference: Grid Convergence: 53.527 N 47.811 W True 0.30 deg Stot Name: Latitude: Longitude: 70 17 49.903 N 149 40 45.817 W Drilled From: Tie-on Deptb: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1 F-01A - Rotary ST 8170.82 ft Mean Sea Level 24.38 deg 80.73 deg Direction deg 275.00 Version: 2 Toolcode Tool Name CB-GYRO-MS MWD MWD Camera based gyro multishot MWD - Standard MWD - Standard 8170.82 /1249.00 10533.00 5974.05 6019.87 6174.48 TIP KOP TO Survey: MWD Company: Baker Hughes INTEQ Toot: MWD;MWD - Standard Start Date: 6/2/2005 Engineer: Tied-to: Mel Rixse From: Definitive Path ConocriP'hillips ~aker Hughes INTEQ . BJlrr Hughes INTEQ Survey Repo IN"fEQ Survey 8170.82 53.60 213.45 5974.05 5854.25 4103.03 -667.88 5962464.20 538902.45 1022.94 0.00 MWD 8200.00 53.98 213.74 5991.28 5871.48 4083.42 -680.90 5962444.53 538889.52 1034.21 1.53 MWD 8249.00 54.63 214.22 6019.87 5900.07 4050.42 -703.15 5962411.41 538867.46 1053.49 1.55 MWD 8280.65 58.70 222.00 6037.28 5917.48 4029.67 -719.47 5962390.58 538851.24 1067.95 24.22 MWD 8314.52 62.84 233.50 6053.86 5934.06 4009.90 -741.34 5962370.69 538829.49 1088.00 32.03 MWD 8350.29 65.20 245.94 6069.58 5949.78 3993.76 -769.04 5962354.41 538801.87 1114.20 31.94 MWD 8383.13 65.21 255.76 6083.38 5963.58 3984.00 -797.16 5962344.50 538773.80 1141.35 27.14 MWD 8411.20 63.74 265.24 6095.50 5975.70 3979.81 -822.10 5962340.18 538748.89 1165.84 30.92 MWD 8440.85 65.28 274.52 6108.28 5988.48 3979.77 -848.82 5962340.00 538722.17 1192.45 28.72 MWD 8474.73 71.92 282.50 6120.65 6000.85 3984.48 -879.96 5962344.54 538691.01 1223.89 29.40 MWD 8496.43 77.16 287.01 6126.44 6006.64 3989.81 -900.17 5962349.77 538670.77 1244.48 31.36 MWD 8526.54 78.28 294.17 6132.85 6013.05 4000.15 -927.69 5962359.97 538643.20 1272.80 23.53 MWD 8553.34 79.53 286.42 6138.01 6018.21 4009.26 -952.34 5962368.95 538618.51 1298.15 28.76 MWD 8587.24 89.03 282.77 6141.39 6021.59 4017.74 -984.94 5962377 .25 538585.86 1331.36 30.00 MWD 8620.83 93.25 279.24 6140.72 6020.92 4024.15 -1017.90 5962383.49 538552.88 1364.75 16.38 MWD 8650.65 93.95 274.86 6138.85 6019.05 4027.80 -1047.42 5962386.99 538523.34 1394.49 14.85 MWD 8670.21 94.53 272.95 6137.40 6017.60 4029.13 -1066.88 5962388.21 538503.87 1413.99 10.18 MWD 8702.42 94.60 277.41 6134.84 6015.04 4032.03 -1098.85 5962390.94 538471.89 1446.09 13.80 MWD 8730.16 93.70 281.41 6132.83 6013.03 4036.55 -1126.14 5962395.32 538444.58 1473.67 14.74 MWD 8763.73 93.37 286.77 6130.76 6010.96 4044.71 -1158.63 5962403.30 538412.06 1506.74 15.97 MWD 8797.56 92.44 292.67 6129.04 6009.24 4056.10 -1190.42 5962414.53 538380.21 1539.40 17.63 MWD 8824.97 90.26 295.94 6128.39 6008.59 4067.38 -1215.39 5962425.67 538355.18 1565.26 14.33 MWD 8852.62 92.32 300.83 6127.77 6007.97 4080.52 -1239.70 5962438.68 538330.81 1590.62 19.19 MWD 8884.04 92.54 305.25 6126.44 6006.64 4097.63 -1266.01 5962455.65 538304.41 1618.32 14.07 MWD 8913.09 89.98 303.47 6125.80 6006.00 4114.02 -1289.98 5962471.91 538280.35 1643.63 10.73 MWD 8943.43 89.10 299.64 6126.04 6006.24 4129.89 -1315.83 5962487.65 538254.43 1670.76 12.95 MWD 8970.37 90.29 295.71 6126.19 6006.39 4142.40 -1339.68 5962500.03 538230.51 1695.62 15.24 MWD 9001.02 91.18 291.98 6125.79 6005.99 4154.79 -1367.71 5962512.27 538202.42 1724.62 12.51 MWD 9037.66 91.00 287.66 6125.10 6005.30 4167.21 -1402.16 5962524.50 538167.90 1760.02 11.80 MWD 9075.14 92.90 283.75 6123.82 6004.02 4177.34 -1438.21 5962534.45 538131.80 1796.82 11.59 MWD 9106.91 89.92 281.39 6123.04 6003.24 4184.26 -1469.21 5962541.20 538100.78 1828.30 11.96 MWD 9136.28 85.56 280.69 6124.20 6004.40 4189.87 -1498.00 5962546.66 538071.95 1857.47 15.03 MWD 9183.56 84.55 274.06 6128.28 6008.48 4195.92 -1544.69 5962552.46 538025.24 1904.51 14.13 MWD 9214.23 87.13 270.63 6130.50 6010.70 4197.17 -1575.25 5962553.55 537994.68 1935.06 13.97 MWD 9244.63 86.67 273.53 6132.15 6012.35 4198.27 -1605.58 5962554.49 537964.35 1965.37 9.64 MWD 9286.95 88.36 278.64 6133.98 6014.18 4202.75 -1647.60 5962558.75 537922.30 2007.63 12.71 MWD 9322.70 89.09 284.48 6134.78 6014.98 4209.91 -1682.61 5962565.73 537887.27 2043.12 16.46 MWD 9355.04 88.69 290.05 6135.40 6015.60 4219.50 -1713.47 5962575.15 537856.35 2074.70 17.26 MWD 9387.41 86.08 289.98 6136.88 6017.08 4230.57 -1743.85 5962586.06 537825.92 2105.93 8.07 MWD 9416.08 86.24 286.13 6138.80 6019.00 4239.43 -1771.04 5962594.78 537798.68 2133.79 13.41 MWD 9444.17 86.15 282.51 6140.67 6020.87 4246.37 -1798.20 5962601.57 537771.50 2161.45 12.86 MWD 9470.79 87.83 279.49 6142.07 6022.27 4251.44 -1824.29 5962606.50 537745.38 2187.88 12.97 MWD 9497.83 88.02 281.78 6143.04 6023.24 4256.42 -1850.84 5962611.35 537718.80 2214.77 8.49 MWD 9533.42 86.92 286.39 6144.62 6024.82 4265.07 -1885.32 5962619.81 537684.28 2249.87 13.30 MWD 9560.66 88.20 286.94 6145.78 6025.98 4272.88 -1911.39 5962627.48 537658.18 2276.52 5.11 MWD 9590.39 91.06 286.87 6145.97 6026.17 4281.52 -1939.83 5962635.97 537629.69 2305.61 9.62 MWD 9620.32 93.21 288.77 6144.85 6025.05 4290.67 -1968.30 5962644.97 537601.17 2334.77 9.58 MWD 9652.62 90.69 292.24 6143.75 6023.95 4301.98 -1998.53 5962656.12 537570.89 2365.87 13.27 MWD 9681.10 92.60 294.20 6142.94 6023.14 4313.20 -2024.69 5962667.20 537544.67 2392.91 9.61 MWD 9714.65 92.96 290.15 6141.31 6021.51 4325.85 -2055.72 5962679.68 537513.59 2424.92 12.10 MWD 9746.90 91.92 285.97 6139.93 6020.13 4335.83 -2086.34 5962689.51 537482.91 2456.30 13.34 MWD 9781.20 93.98 283.85 6138.17 6018.37 4344.65 -2119.44 5962698.15 537449.77 2490.04 8.61 MWD 9810.47 93.33 281.62 6136.30 6016.50 4351.09 -2147.93 5962704.43 537421.25 2518.98 7.92 MWD ConocJ'Phillips aIaker Hughes INTEQ . BÆr Hughes INTEQ Survey Repo ~"""'-"""'<"""',,"'-"""'- lNTEQ Survey 9842.63 91.21 279.72 6135.03 6015.23 4357.03 -2179.51 5962710.21 537389.65 2550.95 8.85 MWD 9873.08 88.02 278.14 6135.23 6015.43 4361.76 -2209.58 5962714.78 537359.55 2581.33 11.69 MWD 9905.46 85.93 274.85 6136.94 6017.14 4365.42 -2241.70 5962718.27 537327.41 2613.64 12.02 MWD 9938.03 86.42 270.41 6139.12 6019.32 4366.91 -2274.16 5962719.59 537294.95 2646.11 13.68 MWD 9985.92 88.17 271.46 6141.38 6021.58 4367.69 -2321.99 5962720.12 537247.13 2693.82 4.26 MWD 10019.20 86.70 275.77 6142.87 6023.07 4369.78 -2355.16 5962722.04 537213.95 2727.05 13.67 MWD 10060.13 85.78 279.33 6145.55 6025.75 4375.15 -2395.64 5962727.19 537173.44 2767.84 8.97 MWD 10090.56 86.74 281.52 6147.54 6027.74 4380.64 -2425.50 5962732.53 537143.56 2798.07 7.84 MWD 10120.56 87.58 286.68 6149.02 6029.22 4387.94 -2454.55 5962739.67 537114.47 2827.65 17.41 MWD 10153.93 85.10 289.04 6151.15 6031.35 4398.15 -2486.24 5962749.71 537082.73 2860.11 10.25 MWD 10186.00 84.91 292.93 6153.95 6034.15 4409.59 -2516.07 5962760.99 537052.85 2890.81 12.10 MWD 10216.33 84.39 291.29 6156.78 6036.98 4420.96 -2544.04 5962772.21 537024.81 2919.67 5.65 MWD 10246.02 85.53 289.27 6159.38 6039.58 4431.21 -2571.78 5962782.31 536997.02 2948.20 7.79 MWD 10275.76 85.99 287.31 6161.58 6041.78 4440.51 -2599.94 5962791.47 536968.82 2977.07 6.75 MWD 10304.57 85.53 285.64 6163.71 6043.91 4448.66 -2627.49 5962799.47 536941.23 3005.22 6.00 MWD 10331.10 85.65 283.29 6165.75 6045.95 4455.27 -2653.10 5962805.94 536915.58 3031.31 8.84 MWD 10362.02 85.81 281.01 6168.06 6048.26 4461.76 -2683.25 5962812.27 536885.41 3061.90 7.37 MWD 10390.85 86.79 279.85 6169.92 6050.12 4466.97 -2711.54 5962817.33 536857.09 3090.54 5.26 MWD 10432.47 88.91 278.10 6171.48 6051.68 4473.45 -2752.62 5962823.60 536815.99 3132.03 6.60 MWD 10464.59 88.70 277.38 6172.15 6052.35 4477.78 -2784.44 5962827.76 536784.15 3164.11 2.33 MWD 10484.97 87.93 275.84 6172.75 6052.95 4480.12 -2804.67 5962830.00 536763.90 3184.47 8.45 MWD 10533.00 87.93 275.84 6174.48 6054.68 4485.01 -2852.42 5962834.63 536716.13 3232.46 0.00 MWD RE: IF-OIA e e Subject: RE: IF-OIA From: "Flora, Jacob M" <Jacob.M.Flora@conocophillips.com> Date: Tue, 01 Mar 2005 13:59:09 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, Here's what I'm using for 4-1/2" cement cales. Thanks, Jake -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, February 28, 2005 12:58 PM To: Flora, Jacob M Subject: 1F-01A Jake, I was wondering if you have the cement volume information for your 4-1/2" liner?? As part of our review, we put the well specifics (hole/casing/depth) through a spreadsheet and the gage cement volume is one of the outputs. Thanks in advance for you assistance. Tom Maunder, PE AOGCC IF-Ola, 45 Liner Summary, Content-Description: IF-Ola, 45 Liner Summary, V1.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 3/1/2005 2: 19 PM Rig: Doyon 15 Location: Kuparuk Client: CPAI Revision Date: 2/15/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265~205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 5,882' MD < Liner Top at 6,082' MD Previous Csg. 7",26.0# casing at 6,232' MD < 41/2",12.6# casing in 6 1/8" OH TO at 8,379' MD (6,061' TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 40% excess. Displacement is calculated with a 4.0"-14.0# drill string. Tail Slurry Minimum thickening time: 150 min. (pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.03% B155 + 0.35% D65 + 0.2 gps D47 -1.17 ft3/sk Liner Cap: 3 0.1276 ft 1ft x 200' x 1.00 (no excess) = Liner La/?: 3 0.1044 ft 1ft x (6232' - 6082') x 1.00 (no excess) = Annular Volume: 3 0.0942 ft 1ft x (8379' - 6232') x 1.40 (40% excess) = Shoe Volume: 3 0.0854 ft 1ft x 80' x 1.00 (no excess) = Totals: 25.5ft3 + 15.7ft3 + 283.1 ft3 + 7.7ft3 = 332 ft3/1.17 ft3/sk = Round up to 290 sks 25.5 ft3 15.7 ft3 283.1 ft3 7.7ft3 332 ft3 283.8 sks BHST = 143°F, Estimated BHCT = 111°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) 5.0 0.0 5.0 5.0 5.0 0.0 5.0 3.0 5.0 2.0 Stage Volume (bbl) 10.0 0.0 20.0 30.0 58.0 0.0 60.0 10.0 20.6 10.0 CW100 Pressure test lines CW100 MUDPUSH II Liner Drop drill pipe dart Water Slow to plu plug Resume Rate Slow & bump plug MUD REMOVAL Stage Time (min) 2.0 10.0 4.0 6.0 11.6 5.0 12.0 3.3 4.1 5.0 Cumulative Time (min) 2.0 12.0 16.0 22.0 33.6 38.6 50.6 53.9 58.0 63.0 Recommended Mud Properties: 10.2 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 Centralizers: 2525 2 per joint on shoe track 2525 2 per 3 joints to top of C sand 2525 1 per joint to 7850 . @ ~ ill ~ re '~n;-:::;J ® JLA.\J J: lUJ~ . fi:I. - - .-, flj'8\ ¡ IIß\\~' \ ,.' n\ nlÎ ¡"",:=¡ LJ u l::v . . (£\ U~ j j / / / J j FRANK H. MURKOWSK/, GOVERNOR AI,A.~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.o. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IF-OIA ConocoPhillips Alaska, Inc. Pennit No: 205-029 Surface Location: 1161' FNL, 388' FEL, SEC. 19, TUN, RI0E, UM Bottomhole Location: 1976' FNL, 1737' FWL, SEC. 18, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for pennit to redrill the above development well. The new wellbore segments will be drilled using both rotary (Doyon 15) and coil (Nordic 2) drilling rigs. In order to change rigs, well operations will be shut down for a period of a few weeks. Since this shutdown is described in the PTD application, a sundry notice is not required per 20 AAC 25.072(a). Per nonnal practice, your rig representative should contact the Inspector when the coil rig is ready to test BOPs. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to 1 ess any required test. Contact the Commission's petroleum field inspector 07. 9-3 7 ager). DATED thisL day of March, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. conocSt,¡UipS . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com February 14, 2005 Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack w/ CTD lateral, Producer 1 F-01 A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 1 F-01A, a development well. This project will be comprised of a rotary sidetrack followed by CTD laterals utilizing two different rigs. The rotary spud date is expected to be approximately 03-15-2005. The CTD spud date is expected to be 4-01-05 and one of BP's Nordic CTD units will perform the work. ~ "--- -----.--.-------..--..-.- Rotary Scope: ."......-..- ..---..-.-- ------ It is planned to use coil tubing to cement squeeze off the existing perfs, set a CIPB at 6255' MD, place a ') permanent whipstock on top of the CIBP with the whipstock at 6232' MD, and mill a window in the existing 7" \ !'Q~~~_.~~§.iD9.~~_~~~~~~_~:._ "3 D 5"_=-0 ·S;). .___ _f"-'-) A good CBL has been obtained over the KOP and it is believed we have good cement at this point to kick off in. The current plan is to mill the window and perform a FIT test! Leak off, which ever comes first, with a required minimum of 12.5 ppg EMW. ** If the FIT/LOT is too low, a squeeze cement job will be performed placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test the intermediate section will be drilled with a 6-1/8" bit down into the Kuparuk B sand, top-setting the Kuparuk A sand. The completion will be a 4-1/2" liner that will provide a KOP for a CTD multi-lateral. The logging program will consist of a TriPI~ ~~£t ~mma Ray/ Resistivity/ Density/ Neutron for this hole / section. .-_ ............... CTD Scope: , ç. -() \,.1\ '-1- The CTD scope includes adding 2 horizontals laterals, one in the A-sand and the other in the C-sand. The A-sand lateral is included in this permit application since rotary is topsetting the A. This lower leg will be drilled first and will exit the 4-1/2" casing above the landing collar to avoid milling out float equipment. After completing the A-sand lateral, a whipstock will be set at the top of the C-sand and the 1 F-01 AL 1 leg targeting C only will be drilled. The / APD for 1 F-01AL 1 will follow shortly. Both laterals will be completed with 2-7/8" slotted liners with the upper liner dropped just outside the casing exit to facilitate retrieval of the upper whipstock, thereby allowing access to the lower lateral. ___~ ---------- If you have any questions or require any further information, please contact Jake Flora at 265-6040 or Dan Venhaus (CTD engineer) at 263-4372. Sincerely, ~~ Randy Thomas GKA Drilling Team Leader r, U . . "~ , õ1Ji STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: PERMIT TO DRILL 20 AAC 25.005 Exploratory U Development Oil ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1F-01A 6. Proposed Depth: 12. Field/Pool(s): MD: 10550' I TVD: 6138' Kuparuk River Field Redrill ~ 11 b. Current Well Class: Stratigraphic Test 0 P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): 7. Property Designation: ADL 25652 8. Land Use Permit: / Top of Productive Horizon: Surface: 1161' FNL, 388' FELl Sec. 19, T11N, R10E, UM ./ 2490' FNL, 1159' FEL, Sec. 18, T11 N, R10E, UM Total Depth: 1976' FNL, 1737' FWL, Sec. 18, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539592 16. Deviated wells: Kickoff depth: 6232' 18. Casing Program Size Hole Casing 6.125" 4.125" 4.5" 2-7/8" y- 5958365 ft. Maximum Hole Angle: Weight Specifications Grade Coupling 12.6# 6.16# L-80 L-80 L-80 STL 19 Total Depth MD (ft): 8715' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 8206'-8259',8385'-8392',8404'-8442' 20. Attachments: Filing Fee 0 BOP Sketch 0 Property Plat 0 Diverter Sketch 0 PRESENT WELL CONDITION SUMMARY Total Depth lVD (ft): Plugs (measured) 6399' 8059' Length Size 80' 16" 2630' 10-3/4" 8698' 7" 21. Verbal Approval: Commission Representative: Kuparuk Oil Pool 13. Approximate Spud Date: 3/15/2005 ALK 2578 9. Acres in Property: 2560 14. Distance to Nearest Property: 1976' 10. KB Elevation 15. Distance to Nearest Zone- 4 (Height above GL): 39' AMSL feet Well within Pool: 1 F-11 @ 725' , 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3473/3977 psig . Surface: 2814/3314 psig . Setting Depth Quantity of Cement Top Bottom c. f. or sacks MD lVD MD lVD (including stage data) 55° Length 2296' 2315' 6082' 8275' 6032' 6091' 6138' 8378' 10550' 15.8 ppg Class G slotted liner (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth lVD (ft): Junk (measured) 8273' 8297' Cement Volume MD TVD 250 sx AS II 80' 80' 1000 sx Fondu & 250 sx Perma- 2630' 2216' frost C 850 sx Class G & 250 sx PFC 8698' 6383' perfOration Depth TVD (ft): 5935'-5983',6098'-6104',6115'-6150' Drilling Program 0 Time v. Depth Plot 0 Shallow Hazard Analysis 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 requirements 0 Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature ~.......-~-- \ I\.,,-~_ Contact Jake Flora @ 265-6040 or Dan Venhaus @ 263-4372 Title Greater Kuparuk Area Drilling Team Leader Phone "2. G.: ')- ¿--¡j 1c Date 2/1 ~ /01) PreDared bv Sharon AI/suo-Drake Commission Use Only :::~~:oD2D5"-DZ1 I AP~:u02-Cf~~'~/ I ::::itAPprovalv2//-Ý I~~::e~e;e~:~~ments Conditions of approval: Samples required 0 yesp;qNo Mud log required 0 Yes ;g¡ No Hydrogen sulfide measures .KI Yes 0 No Directional survey required N Yes 0 No ~()~ \~~\ \.¡'t)\o.""'t~-1iSOO~ c.~C\ \). ~O\-O-\l ~~ \:<ès\ "'"~ <:..'-.) Y\'\~ W-\I~()~ '=. '"\ ð<:>... 't~" D,re ~/tf APPROVED BY THE COMMISSION ORIGINAL Submit in Duplicate ~ '." . Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 15-Feb-05 Permit It - Kuparuk Well 1 F-01 A Application for Permit to Drill Document Mòximiz!Î We-II VQI!,JE; Table of Contents 1. Well Name ..................................... ........................................... ................ ................ 2 Requirements of 20 AAC 25.005 (f).... ......................... .... ....... ................... ............ ....... ..........................2 2. Location Sum mary .... ........ ....................... ........... ....................... ............................. 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...... ............ ................................................................................. 3 4. Dri II i ng Hazards Information....................... ...... ....................................... ........ ....... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests .......................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 5 Requirements of 20 AAC 25.005(c)(6) ................................... .................................................. ..............5 7. Diverter System Information ................................................................................... 5 Requirements of 20 AAC 25. 005( c)(7) ................................................................................................... 5 8. Drill i ng Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25. 005( c)(B) ........................ ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .. ................................................................................................6 10. Seism ic Analysis ...................................... ....... ..... ......................... .......................... 6 Requirements of 20 AAC 25.005 (c)(10) ........... ....... .............................................................................. 6 11. Seabed Condition Analysis .................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 7 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.................... 10 ORIGINAL 1F-01A PERMIT IT. DOC Page 1 016 . , . Application for Permit to Drill, Well 1 F-01 A Revision No.O Saved: 15-Feb-05 Requirements of 20 AAC 25.005 (c)(14) ..............................................................................................10 15. Attachments.......... ..................................................................... .......... .................. 10 Attachment 1 Well Schematic Attachment 2 Directional Plan Attachment 3 CTD BOPE Schematic 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with muítiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigneä to the welf by the commission. The well for which this application is submitted will be designated as 1 F-01 A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface. at the top of each objective formation, and at total depth, referenced to governmental section fines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the Naiìonal Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposeä äepth of the weil at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,958,365.15 11160' FNL, 388' FEL, Sec 19, T11N, R1OE, UM I RKB Elevation . Eastings: 539,591.86 Pad Elevation 39' AMSL 76.0' AMSL Rotarv Operations: Location at Total Depth NGS Coordinates Northings: 5,962,311. 19 I 2490' FNL, 1159' FEL, Sec 18, T11N, R10E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: '-\ 'I;) \\ \"\ ~{.\ \'0' ~\ Eastings: 538,786.27 8378' 6091' 5976' CTD Operations: Location at Total Depth NGS Coordinates Northings: 5,962,815.03 Eastings: 536,742.40 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: 10550' 6138' 6023' and (D) other information required by 20 AAC 25.050(b): Requirements of 20 AAC 25.050(b) If a wel! is to be intentionally deviated, the appJication for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachments 1 & 3: Directional Plans for Rotary and CTD And (2) for all wells witNn 200 feet of the proposed wellbore (A) list the names of the operators of those weíls, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the appiication by certified maíl; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. ORIGINAL 1F-01A PERM/T /T.DOC Page 2 of 6 ti" .... . Application for Permit to Drill, Well 1 F-01 A Revision No.O Saved: 14-Feb-05 The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the foflowing items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035,20 AAC 25.036, or 20 AAC 25.037, as appiicabfe; Rotarv Operations: Please reference BOP schematics on file for Doyon 15. CTD Operations: Please see attached BOP schematic, Attachment 5. Pipe rams, blind rams and the CT packoff will be pressure tested to 400 psi and 4500 psi. The annular preventer will be tested to 400 psi and 2500 psi. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drm must be accompanied by each of the following items, except for an item aiready on file with the commission and identified in the application: (4) information on drifiing hazards, including (A) the maximum downhole pres..':;ure that may be encvuntereci criteria used to determine it and maximum potential surface pressure based on a methane gradient' Rotarv Operations: ,. BHP data on offset injectors indicates that the current reservoir pressure for 1 F-01A is:s 3500 psi at 5988' TVD, 0.58 psi/ft or 11.2 ppg EMW. The maximum potential surface pressure (MPSP) while drilling 1 F-01 A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5988' TVD: MPSP = (5988 ft)*(0.58 - 0.11 psi/ft) = 2814 psi CTD Operations: CTD will penetrate the A-sand reservoir with expected BHP = 4000psi @ 6026' TVDSS or 12.7 ppg EMW.(0.66 psi/ft) / The maximum potential surface pressure (MPSP) while drilling 1 F-01A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6026' TVD: MPSP = (6026 ft)*(0.66 - 0.11 psi/ft) = 3314 psi ?' (B) data on potential gas zones,' Rotary KOP is Colville Group right below the base of the West Sak, between the base of the West Sak and the K-10 marker mudstones. CTD KOP is within the producing interval, the Kuparuk sands. And (C) data concerning potential causes of hole problems ;",xli as abnormally geo-presslJred strata, lost circulation zone0 and zones that have a propensity r..'Jr differentia! sticking,' 1. Attaining LOT/FIT at 7" window (Rotary operations only) 2. Mud losses in the C sand due to low reservoir pressure, could also have problems while tripping and running the liner with differential sticking (Rotary and CTD operations) 3. H2S is approximately 59 ppm in 1 F-01. The 1 F pad is a designated H2S area with a high H2S reading of 128 ~ ppm on well 1 F-14. Hydrogen sulfide contingency measures will be effect. ORIGiNAL 1F-01A PERMIT IT. DOC Page 3 of 6 · e' Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 14-Feb-05 Intermediate Hole Interval Drillinq Hazards (Rotarv) High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool while drilling higher MW's required across pay interval. Pump and rotate out on trips as a last resort. Differential Sticking Moderate Do not leave pipe static for extended period of time across the C sand. Proper drilling practices and keep connection time to minimum. The C sand should pressure is expected to be +f- 3000 psi. Increased mud weight ONLY as needed let hole dictate use wellplan as guide. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. LOW Reservoir Pressure / Moderate Ii Lost Circulation Moderate Production Interval Drillinq Hazards (CTD) Shale instability at BfA sand High interface Differential Sticking LOW Historically a problem area for aD drilling. Will use managed pressure techniques and proper chemical inhibition. Avoid contact with shales in horizontal section. A-sand perm is moderate and is not expected to cause problems. Minimize by keeping coil moving. Expected A-sand pressure is high (4000 psi). Will have on location 2 wellbore of kill-weight fluid. A-sand is not expected to cause significant loss circulation. LCM will only be used if losses prevent drilling ahead. , Abnormal Reservoir Pressure Moderate / Lost Circulation Low 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo!íowing items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); A procedure is on file with the commission for performing LOT's. During rotary sidetracking operations, a LOT/FIT will be obtained prior to drilling ahead after milling the window in the 7" CSG. ORIGINAL 1F-01A PERMIT IT. DOC Page 4 of 6 . . Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 15-Feb-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol/owing items,. except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perfOl<1ted liner, or screen to be installed Casing and Cementing Program Ho/e Size (in) Weig ht Grade Connection (/blft) Oringial Well bore IF-Ol 7" 18-1/2 I 26 I L-80 1 BTC-Mod I Rotary Plan: Window 6.151" 26# L-80 In the 7" Casing 4-1/2" BTC- Mod Top 8tm Length MO/TVO MO/TVO (ft) (ft) (ft) Cement Program 8698 surface I 8698'/6383 I Original TOC = 2225' MD 17' 6215'/4298' 6232'/4315' Squeeeze shoe if insufficient LOT 2296' 6082' MD 8378'/ 6091' 15.8 ppg Class G displaced 150' above TOL Csglrbg 00 (in) 6.125" 12.6 # L- 1 80 L-80 CTD Plan: 2-7/8" I 4.125" 16;61 L-80 I STL 12315' 18275'/6032' 110550'/61381 No cement, slotted liner 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Orilí must be accompanied by each of the following items,. except for an item already on file with the commission and identified in the appiication: (7) a diagram and description at the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); This rotary sidetrack will exit pre-existing casing at ± 6232' MD. BOPE will be installed prior to exiting the 7" casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application tor a Permit to Orm must be accompanied by each of the following items,. except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluiä systern, as required by 20 AAC 25.033: Rotary drilling will be done using a LSND mud system and CTD will utilize ¡solids-free polymer DIF having the following properties: Sidetrack Hole mud :>roperties Initial Orillout KOP Rotary TO cro Horizontal 1 Chloride F/o-Pro cro Horizontal 1 Formate KWF Depth MOl TVO 6232'/4315' MD 8378'/6091' MD 10550'/6138' 10550'/6138' ORIGINAL 1F-01A PERM/T IT. DOC Page 5 of 6 . . Application for Permit to Drill, Well 1 F-01 A Revision No.O Saved: 14-Feb-05 Density (ppg) 11.7 11.7 10.0 13.2 Funnel Viscosity (seconds) 60,000 cp (LSRV) 60,000 cp (LSRV) Yield Point TBD TBD 22-28 22-28 (cP) Plastic Viscostiy (lb/100 sf) TBD TBD 7-9 7-9 Diagram of Doyon 15 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. During CTD drilling operations, two wellbore volumes of KWF will be on location for well control purposes. " 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An appiication for a Permit to Orilí must be accompanied by each of the following items, except for an item already on file with the commission and identified in the appHcation: (9) for an exploratory or stratigraphic test well. a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25,033(f); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app!ícation for a Permit to Ori!! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Orifí must be accompanied by each of the following items, except for an item already on file with the commission and identified in the applícatíon: (11) for a weil driffed from an offshore platform, mobile bottom-founded structure. jack-up rig. or floating driflíng vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b): N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Orífl must be accompanied by each of the foHowing items, except for an item already on file with the commission and identified in the application: (í2) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 1F-01A PERMIT IT. DOC Page 6 of 6 2. "'" v ... ...;.'- ~2- 3. eyÇ0 ~ "V 4. ~~ 1..- ,~ ¿... 5. ~~ (7 d~a6. -¢ð/ 7. !\.j ~ 8. . . Application for Permit to Drill, Well 1 F-01 A Revision No.O Saved: 14-Feb-05 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drffl must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Pre-Rig Well Work: NOTE: test IA +/- 2 weeks prior to rig moving - Wells to supervise that work Procedure outline: 1. PT wellhead packoffs (Tubing, IC and oq. Cycle Tubing LDS's 2. Pull X plug in tubing. (CMIT passed in Nov. 2004). 3. Perform injectivity test into perfs. 4. Set Cement retainer in 3 V2" tubing at 8030' (just above top straddle packer). 5. RU au, RIH to 8030' and sting into cement retainer. Pump cement until squeeze pressure is achieved... should be about 9 bbls cement to fill tubing and annulus. Attempt to squeeze 2-3 bbls cement into formation. 6. Pull out of cement retainer and lay in SO'cement plug to 7980' md. 7. RU Slickline after 24 hr wait and tag top of cement. PT to 2000 psi with AOGCC witness present. 8. Rig up E-line and chemical cut tubing at approx. 7700'. 9. Set VR and BPV. Remove well house and flowlines. 10. MIRU rig 11. Pull tubing. 12. Set CIBP with E-line at approx. 6230' 13. Set whipstock and drill out 7" widow. Current Wellhead: FMC Gen I, 10-3/4" X 7" X 3-1/2" x 3K Rotarv Riq Work: 1. Take on 8.8 ppg Brine in Brine pits. Pull BPV. RU on tree and circulate 8.8 ppg Brine. Circ through the choke until clean brine returns are observed at the surface. Run and set BPV. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Doyon 15. Install blanking plug on top of the back pressure valve. NU and test the 13-3/8"x 5K" BOPE to 250# I 5000# (**FMC will have double stud adapter). r- f Engage the 3-1/2" tubing with a spear. UD the tubing hanger and pull 3-1/2" tubing to SSSV at 2220' MD. RIH wI storm packer and hang oft 3-1/2" tbg. N/D BOP's. Remove FMC Gen I tubing head, replace pack-ofts, and MU new FMC Gen 5 head. NU Bop's to the 11", 5K flange on the FMC Gen 5 system & test 250 psi & 5000 psi. PU mill, casing scraper, and 4" DP and RIH to +1- 6350' MD. C&C. POOH. 9. RU wireline set a CIBP inside the 7" casing at +1- 6237' MD based on casing collar depth. (Note: CIBP must be ~ 2.0' above a casing collar and ~ 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. Test okay. POOH with wireline. (If not contact Engineer- discuss will have to get packer and RIH and attempt to find hole in casing.) 10. PU and RIH with Baker's "WindowMastef" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 6237' MD. ~ n\~ ~\W\,\ \a ~\.~\ \ \ 11. Orient whipstock 85 degrees Right of high side, shear oft, and POOH. ¡)OS-Od-~ ORIGINAL 1F-01A PERMIT IT. DOC Page 7 of 6 . . Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 14-Feb-05 12. Displace 8.8 ppg Brine from hole with 9.2 ppg LSND new mud to mill window. Mill window and drill 20' new formation. Dress window. Pump super sweep pill. 13. Perform FIT/LOT. POOH and LD window mill etc. 14. PU Intermediate bit & hole opener, BHA, 4.0" DP, and RIH. / 15. Drill the Intermediate hole section to TO just below C sand +/- 8378' MD/6091' TVD. The MW should be approximately 11.7 ppg at TO. I 16. POOH run 4.5" liner and tie back 150' inside the 7" window (The required overlap is?: 150': TOL = 6082' MD). 17. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. Cement the liner bringing cement on top of the liner. 18. Release from liner. Set ZXP packer. C & C. 19. POOH. LD/DP. 20. PU and RIH w/ 4-1/2" tubing. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. NU tree, displace and freeze protect well with diesel, install BPV. 21. RDMO Doyon Rig 15 C) ç>~ \0.\ '\ cD f'...,,",? ') \) ORIGINAL 1F-01A PERM/T /T.DOC Page 8 of 6 . . Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 14-Feb-05 CTD Riq Work: 1. MIRU Nordic 2 CTD rig. NU 7-1/16" BOPE and test. 2. Set 4-1/2" LSX whipstock @ 8285' md (Kuparuk B sand) 3. Mill 3.80" window at 8285' and 10' of openhole. 4. Drill 4-1/8" bicenter hole horizontal A-sand lateral from window to -10550' md. Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction / losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and lor fracturing at the end of the long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (VB pipe rams and 3" slip rams, see attached BOP configuration) and/or the tested tubing retrievable sub-surface safety valve that will be installed during the rotary portion of this sidetrack. The annular preventer will act as a secondary containment during deployment and not as a stripper. Two wellbore volumes of KWF (-325 bbls) will be on location for well control purposes, if necessary. Estimated reservoir pressure: 4000 psi @ 6026' SSTVD, 12.4 ppg EMW / Expected annular friction pressure loss while circulating: 490 psi Planned mud density: 10.0 ppg equates to 3134 psi hydrostatic BHP While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 3624 psi or 11.6 ppg ECD. A surface pressure of -500 psi will be applied to maintain 125 psi overbalance. When circulation is stopped, a minimum of 1000 psi surface pressure will be applied to to maintain constant BHP. / 5. Complete with 2-7/8" slotted liner from TO -10590', up into the 4-1/2" liner to 8275' md. Followinq work is permitted under se1JJilTØte AFD for 1 F-01 AL 1 6. Set Weatherford KSWS packer at -8180' md. 7. Stab into KSWS Weatherford packer with retrievable 4-1/2" whipstock, targeting top of whipstock @ 8165' md. 8. MiI/3.80" window at 8165' and 10' of openhole.- 9. OriI/4-1/8" bicenter hole horizontal C-sand lateral from window to -10325' md. 10. Complete with 2-7/8" slotted liner from TO -10325, up to 5-10' outside the 4-1/2" casing exit- 8165' md 11. PuI/4-1/2" retrievable whipstock @ 8165' md 12. NO BOPE. ROMO Nordic 2. Post-Rig Well Work: 1. Drift and tag to PBTD. 2. Run new GL V design. 3. Install new "S" riser and replace the well house(s). ORIGINAL 1F-01A PERMIT IT.DOC Page 9 of 6 . . Application for Permit to Drill, Well 1 F-01A Revision No.O Saved: 14-Feb-05 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drifl mustc be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the appiication: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request aLlthorization under 20 AAC 25.080 for an annular disposal operation În the wel/.: Doyon rig 15 has a rock washer. There is no ultra-sonic processor or ball mill. The liquid waste fluids generated during the drilling process for both rotary and CTD will be taken to one of the KRU's Class II , disposal wells, and the solids will go to D8-4 in Prudhoe (G&I facility). 15. Attachments : Attachment 1 Directional Plan Attachment 2 Well Schematic Attachment 3 CTD directional plan Attachment 4 CTD schematic Attachment 5 CTD BOPE configuration ORIGINAL 1F-01A PERM/T /TDOC Page 10 of 6 1F-01A SIDET.K Proposed . ConocJ'Phillips COMPLETION n \ ~ '^. '" \Lo....""' d" \,,\,~) 4-1/2" 5M FMC Gen IV Tubing Hanger 4-1/2" 12.6# L-80 IBT Mod TBG to Surface 4-1/2" Cameo TRM-4E SSSV at approximately 2220' MD 4-1/2" Halliburton X nipple at approximately 6052' MD - 3.813" 10 " n n n n n ~ ~ ~ ~ n n n n n n n n n n n 9-5/S" LSO casing .....1 @ 2630' MD /2216' 1 TVD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4.5" x 7" Liner Top ~ 6082' MD /4212' TVD i I I I ~ ~ I ~ ~ I I ~ ~ I I ~ ' ~ I ~ I I i i I I I I ~ Baker"K-1"CIBP@ i ~ +/- 6255' MD ¡r=-::c::::::J,.~ ~ I ~ ~ 3-%" tbg cut and i I pulled from +/- 7700' i _ ^ ~ ~ MD ~ ~ V" ~ ~ I ~ I PKR 8085' MD;' . f I ~ ~ ~ I I I I I I I ~ I ~ i i i i FISH 8280' RKB i I ~ ~ I -t- I I . ~ ~ ~ ~ - ~ I I ~ I ~ Sidetrack KOP @ +/- 6232' MD, +/- 4315' TVD Original Wellbore 7.0" casing 26.0# K-55 8698' MD - 6383' TVD n B ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ if ~ ~ ~ ~ I ~ II d ~ I .n II I ~ I ~ H Ia. 1 1 1 1 I 1 1 I I 1 I '- '- '- I I -~ ~ ~ -9 1 1 1 I i -- ~ I I I I I I ~ I ~ Planned Gas Lift Mandrels 4 Y:z" x 1" Cameo 'KBG-2' mandrels 4 Y:z" x 10' L-80 handling pups installed above & below. IBT Mod Place gas-lift mandrels at the following planned depths- adjust accordingly at TD TVD MD G1, Valve #1 2600 3298 1.0" Camco Bellows #2 3700 5229 1.0" Camco Bellows #3 4175 6022 1.0" Camco Orifice 4-1/2" 12.6# L-80 IBT Mod TBG as necessary 4-1/2" Camco 3.813" DB landing nipple Seal Assembly, w/5" 00 Bullet Seals, 15 ft long (BOT) 4-%" X 7" LINER ASSEMBLY 4-112" X 7" ZXP Liner Top Packer, HRD, w/15' tieback Extension (BOT) 4-112" X 7" FlexLock Hydraulic Liner Hanger, Hydril 521 conn (BOT) Crossover, 4-1/2" Hydril 521 box x 4-1/2" IBTM pin 4-W' 12.6 ppf IBTM liner as needed 4-W' Landing Collar (BOT) One Joint 4-%" IBTM Liner 4-W' Float Collar (BOT) Two Joints 4-%" IBTM Liner 4-%" Float Shoe (BOT) Kup C Sand 8106' MD 15966' TVD Est BHP < 3000 psi TD @ 83781 MD I 60911 TVD 59761 TVDSS Drawn by MDK 1/13/05 ORiGiNAL . . y ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 F Pad 1 F-01 Plan 1F-01A Plan: 1F-01A (wp04) Proposal Report 04 February, 2005 BpE!r-r-Y-BUI1 DRIL.L.ING SERVICES A Halliburton Company ORIGINAL +Ni-S 0.00 +EI-W Northing 0.00 5958365.15 WELL DETAILS: 1F-01 Ground Level: easting 539591.86 76.00 Latittude 7W1T4$.903N 1000 4000 I I I 2500 I I I Vertical Section at 349.000 (500 ftJín) 2750 3000 3250 3500 I I I I I I I I I I I I I I I I I I I I I 1250 I I I 1500 " I I I 1750 I I I ¡ I 2000 I I I I I I I 2250 I I I I I 4250- I Bottom of Whipstock - Assume 15.9° DLS - (6244'MD ,4323'TVD) 4500- I Begin Dir@ 8°/100ft- LH turn & Drop: (6262'MD .4335'TVD) I I Sail @ 37' Ine & 331 Azi (6462'MD . 4485'TVD) 4750- ISail @ 33' Ine & 358' Azi (6712'MD ,4689'TVD) '2 :¡'§ 5000- o o ~ s::: 15. OJ a ~ 'e ~ OJ 2 I-- I Begin Dir@ 8°/100ft (6762'MD, 4731'TVD) I Sail @ 23.3° Inc& 71.4' Azi (7174' MD, 5105' TVD) IBegin Dir @ 8°/10Oft (7233'MD. 5159'TVD) 6500 I I I 1000 I I I I I 1250 I I I 1500 I I I I I 1750 I I I I I 2000 I I I 2250 I I I I I I I I I I I I II I I 2750 I I REFERENCE INFORMATION Longitude 149°4(l·45.817W Co-ordinate (N/E) Reference' Vertical (TVD) Reference: Section (VS) Reference: Measured Depth Reference: Calculation Method: Well 1 F-01, True North 1F-01 @ 115.00ft (1F-01) Slot - (O.OON, O.OOE) 1F-01 @ 115.000 (1F-01) Minìmum Curvature Slot 4000 I I I I I I I 4250 I I I I I 4500 I I I " 4750 I I I I I 5000 I ¡ I 5250 I I I I I I I ~---- 51/2" I I I I I 3750 I I I I I I I I I I I I I I I 4500 5000 I I I I I I I 5250 ! !! I I I I I I 4250 4000 -4250 --4500 -4750 - 5000 ~ < '" ;:¡. 1, Qè -5250 ;? " SO Oi o o -5500 s: 2. -5750 -6000 -6250 6500 -1100 4450 I I I 4400- 4350- 4300- 4250- c ~ o o :s 4200- +' ':E: 1:: o - ~ 4150- ':E: '5 o (f) 4100- 4050- 4000- 3950- 3900 I I I -1100 -1050 -1000 I I II II I I -950 I I I I I I I -900 I I I -850 -800 I I I I I I I I I I I I Begin Dir@ 8"/10Oft (7233'MD. 5159'TVD) I I Sail @ 23.3" Inc & 71.4" Azi (7174' MD, 5105' TVD) I IBegin Dir @ 8"/1 OOft (6762'MD , 4731'TVD) ~/~///~ ISail @ 33° Inc & 358" Azi (6712'MD .4689'TVDU IBegin Dir @ 8"/1 o Oft - RH turn & Drop (6512'MD ,4524'VD) ~ I Sail @ 37" Inc & 331 Azi (6462'MD ,4485'TVD) I 5 I I I -1050 I I I I I I -1000 'I I I I -950 I I I -900 I II I I -850 West( - )/East( +) (100 Win) -750 -700 -650 -600 I I I I I I I I I I I I I I I I I I I I -550 I I I I I -500 I I I -450 -400 I I I I I I I I I I I I -350 I I II I ~~ T . ML\zimuths to True North ¿. Ma:t~:~;;;;;~;;;;; . Dip Angle:f¡O.73' Date: 1/6/2005 Model: BGGM2004 -300 I ¡ I -250 1111, 4450 I J I I I I ¡ I I -800 I I I I I I I I I 'i ' r I I I I I -550 -450 I I I -350 1.(· ! -4400 -4300 -4250 (f) o c: ~ -4200 ~ - 0 ;::¡. ::> ::£ -4150 :: o o <:!:: 2: ~"g~_0r @ 8'/1 o Oft - LH turn & Drop: (6262'MD ,4335'TVD) I -4100 -4050 I Bottom of Whipstock - Assume 15.9' DLS - (6244'MD . 4323'TVD) I -4000 -3950 3900 West(-)/East(+) (2000 ft/in) -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I \ I I 6000- -6000 1F_01/1F-01 11"-1311;:::, ~ -13 5000- -5000 4000- -4000 3000- -3000 2000- -2000 1000- -1000 c: ~ xþ 0 0 0- 0" 0 ë ~ +' ?; 1:: -1000- 0 ~ , ?; '5 -2000- 0 U') -3000- --3000 ,,<,/''9 -4000- x"~ " - -5000- -6000- -7000- 11"-20/1 -- 1"-20 -8000- --8000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1···1 I -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 West(-)/East(+) (2000 ft/in) . . ~ ConocoPhillips Alaska Halliburton Company Planning Report - Geographic ""'''''''I'''''\I-EiUI1 DRIL.LINtI .."VIC.. A Halliburton Company 2003.11 Single User Db Alaska Inc.(Kuparuk) Unit Kuparuk 1 F Pad 1 F-01 Plan 1F-01A 1F-01A (wp04) Local Co-ordinate Reference: 1VD Reference: MD Reference: North Reference: Survey Calculation Method: We1l1F-01 1F-01 @ 115.00ft(1F-01) 1F-01 @ 115.000 (1F-01) True Minimum Curvature Project Kuparuk River LJnit, North Slope Alaska, UnitE¡dStates Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 1F-01 Position Uncertainty 0.00 ft 0.00 ft 0.00 ft Northing: Easting: Wellhead Elevation: 5,958,365.15 ft 539,591.86 ft ft Latitude: Longitude: Ground Level: 700 17' 49.903" N 149040' 45.817" W 76.00 ft Well Position +N/-S +EI-W Plan 1 F-01A 1/6/2005 Declination ¡O) 24.42 Sample Date BGGM2004 80.73 57,578 1F-01A (wp04) Audit Notes: Version: Phase: PLAN Tie On Depth: 6.232.00 39.00 +NJ..s (ft) 0.00 0.00 349.00 vertical Dogleg; Build DePth "'NJooS +EI-W Rate Rate (ft) (ft) (ft) (o/100ft) (o/10Oft) 6,232.00 46.48 352.68 4,315.10 3.953.10 -688.48 0.00 0.00 0.00 0.00 6,244.00 46.68 350.06 4,323.35 3,961.72 -689.79 15.90 1.63 -21.78 275.00 6,262.00 46.68 350.06 4,335.70 3,974.62 -692.05 0.00 0.00 0.00 0.00 6,462.00 36.74 331.05 4,485.42 4.099.44 -733.83 8.00 -4.97 -9.51 225.00 6,512.00 36.74 331.05 4,525.48 4.125.61 -748.31 0.00 0.00 0.00 0.00 6,712.00 32.86 358.46 4,690.69 4.232.90 -778.92 8.00 -1.94 13.71 115.00 6,762.00 32.86 358.46 4.732.69 4,260.02 -779.65 0.00 0.00 0.00 0.00 7,174.34 23.87 69.69 5,104.74 4,404.83 -702.28 8.00 -2.18 17.27 135.28 7,233.19 23.87 69.69 5,158.56 4,413.09 -679.95 0.00 0.00 0.00 0.00 8,162.76 55.00 210.00 5,967.00 4,103.98 -696.32 8.00 3.35 15.09 147.10 8,378.94 55.00 210.00 6,091.00 3,950.61 -784.87 0.00 0.00 0.00 0.00 2/412005 8:59:11AM Page 2 of4 COMPASS 2003.11 Build 50 Of~iG'NAL . . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic !!ipE!l""'.....y-BLJI1 O..ILLING ....VIC.. A Halliburton COmpany Single User Db Inc.(Kuparuk) Local Co-ordinate Referenc&: TVD Reference: MD Reference: North Reference: Survey CalculatiOn Method: We1l1F-01 1F-01@ 115.00ft(1F-01) 1F-01@ 115.00ft(1F-01) True Minimum Curvature 1 F-01A (wp04) TVD SSTVD +NI..s +Ef.l1V fit) 1ft) (ft) (ft) 6,232.00 46.48 352.68 4.315.10 4,200.10 3,953.10 -688.48 5,962,314.18 538.882.64 0.00 4.011.84 Top Of Whipstock - 85 LeftofHS - Drill 0ut61/8" Hole - 2487'FNL & 1062'FEL Sect 18-T11N-R10E : (6232'MD, 4315'TVD) 6,244.00 46.68 350.06 4,323.35 4.208.35 3,961.72 -689.79 5,962,322.79 538,881.28 15.90 4,020.55 Bottom of Whipstock - Assume 15.9° DLS - (6244'MD ,4323'TVD) 6,262.00 46.68 350.06 4.335.70 4,220.70 3,974.62 -692.05 5,962,335.68 538,878.96 0.00 4,033.64 Begin Dir @ 8°/10Oft - LH turn & Drop: (6262'MD . 4335'TVD) 6,300.00 44.57 347.00 4.362.28 4,247.28 4,001.23 -697.43 5,962,362.26 538,873.43 7.99 4,060.79 6,400.00 39.47 337.77 4,436.62 4.321.62 4,064.94 -717.38 5,962,425.86 538,853.14 8.00 4,127.14 6,462.00 36.74 331.05 4.485.42 4,370.42 4,099.44 -733.83 5,962,460.26 538.836.52 8.00 4.164.14 Sail @ 37° Inc & 331 Azi (6462'MD , 4485'TVD) 6,500.00 36.74 331.05 4,515.87 4,400.87 4,119.33 -744.83 5,962,480.09 538,825.41 0.00 4,185.76 6,512.00 36.74 331.05 4,525.48 4,410.48 4,125.61 -748.31 5.962,486.36 538,821.90 0.00 4,192.59 Begin Dir@So/10Oft - RH turn & Drop (6512'MD ,4524'VD) 6,600.00 34.28 342.42 4,597.19 4,482.19 4,172.33 -768.56 5,962,532.96 538,801.41 8.00 4,242.32 6,700.00 32.91 356.69 4,680.61 4,565.61 4,226.39 -778.65 5.962.586.96 538,791.04 8.00 4,297.31 6,712.00 32.86 358.46 4,690.69 4,575.69 4,232.90 -778.92 5,962.593.47 538,790.73 8.02 4,303.75 Sail @ 33° Inc & 358° Azi (6712'MD , 4589'TVD) 6,762.00 32.86 358.46 4,732.69 4,617.69 4.260.02 -779.65 5,962,620.59 538,789.86 0.00 4,330.52 Begin Dlr@ SO/100ft (6762'MD ,4731'TVD) 6.800.00 30.77 2.64 4,764.98 4,649.98 4,280.04 -779.48 5,962,640.60 538,789.92 7.99 4,350.14 6,900.00 26.07 16.31 4,853.00 4,738.00 4.326.76 -772.12 5,962,687.35 538,797.04 8.00 4,394.59 7.000.00 23.10 34.26 4,944.05 4,829.05 4.364.12 -754.87 5,962.724.80 538,814.08 8.00 4,427.97 7.100.00 22.56 54.92 5,036.36 4,921.36 4.391.40 -728.08 5,962.752.22 538,840.73 8.00 4,449.64 7.174.34 23.87 69.69 5,104.74 4,989.74 4,404.83 -702.28 5,962,765.79 538,866.46 8.00 4,457.90 Sail @23.3° Ine & 71.4° AzI (7174' MD, 5105' TVD) 7,200.00 23.87 69.69 5,128.21 5,013.21 4.408.43 -692.54 5,962.769.44 538,876.17 0.00 4,459.58 7,233.19 23.87 69.69 5,158.56 5,043.56 4.413.09 -679.95 5,962,774.17 538,888.74 0.00 4,461.75 Begin Dir@ 8°/10Oft (7233'MD , 5159'TVD) 7.300.00 19.58 78.37 5,220.62 5,105.62 4.420.05 -656.29 5,962.781.24 538,912.36 8.00 4,464.06 7,400.00 14.49 99.76 5,316.30 5,201.30 4,421.30 -627.50 5,962,782.65 538,941.14 8.00 4,459.80 7,500.00 12.73 133.46 5,413.64 5,298.64 4,411.58 -607.15 5,962,773.04 538,961.54 8.00 4,446.38 Minimum Inclination _13° @(7SOO'MD, 5414'TVD) 7,600.00 15.50 164.75 5,510.75 5,395.75 4,391.07 -595.62 5,962,752.59 538,973.18 8.00 4,424.04 7,656.72 18.45 176.61 5.565.00 5,450.00 4,374.79 -593.09 5,962,736.33 538,975.79 8.00 4,407.58 Prognosed Fault Intersection 7,700.00 21.08 183.30 5.605.74 5,490.74 4,360.18 -593.13 5,962,721.71 538,975.82 7.99 4,393.24 7,800.00 27.82 193.80 5,696.76 5,581.76 4,319.49 -599.75 5,962,681.00 538,969.42 8.00 4,354.57 7,900.00 35.07 200.35 5,782.04 5,667.04 4,269.81 -615.34 5,962,631.24 538,954.10 8.00 4,308.78 8,000.00 42.55 204.87 5,859.92 5,744.92 4,212.11 -639.60 5,962,573.42 538,930.15 8.00 4,256.76 8,047.68 46.18 206.59 5,894.00 5,779.00 4,182.09 -654.08 5,962,543.32 538,915.82 8.01 4,230.05 K-1 8,100.00 50.17 208.25 5.928.88 5,813.88 4,147.49 -672.05 5,962,508.64 538.898.04 8.00 4,199.53 2/412005 8:59:11AM Page 3 of 4 COMPASS 2003.11 Build 50 ORIGINAL . y ConocoPhillips Alaska Halliburton Company Planning Report - Geographic Database: Company: Project: SIW: Wèll: Wellbore: Design: EDM 2003,11 Single User Db Çj)nøCOPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 F Pad 1F-01 Plan 1 F-01A 1 F-01A (wp04) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: 1 F-01A SSTVD 1ft) +NI-8 (ft) +E/-W (ft) . -i .~ ·.....Y-BUI1 13.... LING .-..VIC.. A Halliburton Company We1l1F·01 1F-01 @ 115.0Oft(1F-01) 1F-01 @ 115.0Oft(1F-01) True Minimum Curvature Map Northing (ft) 8,162.76 55.00 210.00 5,967.00 5,852.00 4,103.98 -696.32 5,962,465.00 Sail @ 550 Inc & 2100 Azi: 2336'FNL & 1070'FEL Sect 18-T11N-R10E: (8163'MD, 5967'TVD)-1F-G1A T1 (v4) 5,962,462.52 8,166.24 55.00 210.00 5,969.00 5,854.00 4,101.50 -697.75 Top C-Sand 8,200.00 55.00 210.00 5,988.36 5,873.36 4.077.56 -711.57 8.229.01 55.00 210.00 6,005.00 5,890.00 4.056.98 -723.45 Top B-Shale 8,300.00 55.00 210.00 6.045.72 5,930.72 4,006.62 -752.53 8,337.10 55.00 210.00 6,067.00 5,952.00 3,980.30 -767.73 Top B1 8.378.94 55.00 210.00 6,091.00 5,976.00 3.950.61 -784.87 End 6 118" Hole· 2490'FNL & 1159'FEL Sect 18-T11N-R10E (8379'MD, 6091'TVD) - 51/2" Plan 1 F-01A +N/-8 ft ,..tget Nåm' -ShaPe 5,967.00 1F-01A T1 (v4) - Rectangle (sides W200.00 H150.00 DO.OO) 4,103.98 Measured Depth (ft) Casing DIameter (, Vertical Depth (ft) 8,378.92 6,090.99 5-1/2 5.962,438.50 5,962.417.86 5,962,367.35 5,962,340.96 5,962,311.19 Hole DIameter (") 6 Vert SectiOn tfð 538,874.00 8.00 4,161.44 538,872.59 0.00 4.159.28 538,858.89 0.00 4,138.42 538,847.12 0.00 4,120.48 538,818.31 0.00 4.076.59 538,803.25 0.00 4,053.66 538,786.27 0.00 4,027.79 -696.32 5,962,465.00 538,874.00 VertiC<lI Azimuth Depth '!'N/-E +E/-W /0' (ft) {ttl 1ft) 7,656.72 18.45 176.61 5,565.00 4.374.79 -593.09 prognosed Fault Intersection 8,047.68 46.18 206.59 5.894.00 4.182.09 -654.08 K·1 8,166.24 55.00 210.00 5,969.00 4,101.50 -697.75 Top C-Sand 8,229.01 55.00 210.00 6,005.00 4,056.98 -723.45 Top B-Shale 8,337.10 55.00 210.00 6,067.00 3,980.30 -767.73 Top B1 6,094.00 TopA6 2/412005 8:59:11AM Page 4 of 4 ORIGINAL COMPASS 2003.11 Build 50 WEll. DETAILS Naln" 'N-S Northing f.a.:;ting Latillldc Longitude S!ot !F-O! 1>-000 O.OUO 595&:,65.15 5J9591':-\6 70'17'49.9(ßN !4cY4Ü'45.:<:¡7W NiA ANn..cOLUSION SE1TINGS COMPANY DETAILS SU¡(VEY PROGRA¡'A \\'f'l1J'A'IHPET.'IlLS D<p(hFm Dq,¡hT" T",,! From Colour 6232 6750 7750 ToMD 6750 7750 8750 !>"~~I!Wclll'iI!h IF-O\ "í1<;'~1I\.fI): ¡¡~.n:OO() Rig: 1),)\"<:>,,-15 RdD<>t,"n W:O! V,Sectioo Cricit> Origin SlMlinj!; A.!Wo "NT_s '-E.i.\\, From TVD From Colour 6232 6750 7750 ToMD 6750 7750 8750 o -31.4 ""30.0 -467 -25.0 --400 -20.0 -"-15.0 -'100 '5_0 -0 270 90 . 5.0 270 90 --100 --15_0 --20.0 -"25.0 -30.0 -3IA -400 -467 180467 TraveHing Cylinder Azimuth (TFO+AZI) [deg] vs Centr<; to Centre Separation [200ft/in] TravelIing Cylinder Azimuth (TFO+AZI) [deg] vs Centr~to Centre Separation [I5ft/in] SEÇTJON DETAILS s¡.:c MD Inc VSc,; Target Azi TVI) DLeg: TFacto , 2 J 4 5 " 7 g 9 \0 II !F-OIA n(y--l) . . Halliburton Company Anticollision Report . Compan)\~ Conocof,?flinips Alaska Inc. , Field: Kuparuk River Unit ; Reference Site: Kuparuk 1 F Pad Reference Well: 1F-01 ReferenceW ellpatUf"-01 A GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation MethodMD Interval: 25.000 ft Depth Range: 6232.000 to 8378.989 ft Maximum Radiu~D26.399 ft Date: 1/2512005 Time: 12:32:38' Page: 1 Co-ordinate(NE) Reference: Well: 1F-01, True North Vertical (TVD) Reference: 1 F-01 115.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: 1F-01A (wp04) & NOT PLANNED pq:>GRJ ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points TVD I)ia$et e r Hole Size Name ft ft in In 8378.000 6090.433 7.000 8.500 7" Plan: 1 F-01A (wp04) Date Composed: 1/25/2005 Version: 2 Principal: Yes Tied-to: From: Definitive Path Summary -<:__n_n_____n________ Offset Wellpath _u___n____n________> Reference Offset Ctr~Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 F Pad 1 F-01 1 F-01 V1 6249.992 6250.000 0.409 0.001 0.408 Pass: No Errors Site: Kuparuk 1 F Pad Well: 1 F-01 Rute Assigned: No Errors Wellpath: 1 F-01 V1 Inter-Site Error: 0.000 ft ~et~í'ènce Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MÐ" TVD MI) TVD Ref Offset TFO+AZI TFO-HS Casing/HBistanceArea Deviation ft ft ft ft ft ft deg deg in ft ft ft 6249.992 4327.460 6250.000 4327.527 28.130 28.191 92.977 102.914 7.000 0.409 0.001 0.408 Pass 6274.964 4344.654 6275.000 4344.892 28.125 28.321 93.177 104.134 7.000 1.356 0.001 1.355 Pass 6299.877 4362.190 6300.000 4362.379 28.115 28.434 82.533 95.522 7.000 2.797 0.001 2.796 Pass 6324.685 4380.064 6325.000 4379.984 28.080 28.527 73.527 88.640 7.000 4.906 0.001 4.905 Pass 6349.342 4398.213 6350.000 4397.705 28.044 28.603 67.033 84.361 7.000 7.745 0.001 7.744 Pass 6373.799 4416.574 6375.000 4415.539 27.982 28.662 62.313 81.948 7.000 11 .325 0.001 11.324 Pass 6398.013 4435.083 6400.000 4433.487 27.920 28.706 58.753 80.786 7.000 15.644 0.001 15.643 Pass 6421.948 4453.681 6425.000 4451.575 27.834 28.730 56.051 80.570 7.000 20.667 0.001 20.666 Pass 6445.577 4472.316 6450.000 4469.828 27.746 28.740 53.970 81.062 7.000 26.352 0.001 26.351 Pass 6469.161 4491.156 6475.000 4488.243 27.682 28.776 52.473 81.424 7.000 32.649 0.001 32.648 Pass 6493.331 4510.524 6500.000 4506.820 27.699 28.898 51.923 80.874 7.000 39.028 0.001 39.027 Pass 6517.830 4530.161 6525.000 4525.520 27.754 29.062 51.852 80.093 7.000 45.303 0.001 45.302 Pass 6543.597 4550.971 6550.000 4544.303 27.941 29.360 52.040 77 .066 7.000 51.003 0.001 51.002 Pass 6569.694 4572.253 6575.000 4563.171 28.085 29.625 51.904 73.552 7.000 55.910 0.001 55.909 Pass 6596.057 4593.932 6600.000 4582.121 28.216 29.854 51.486 69.601 7.000 60.023 0.001 60.022 Pass 6622.615 4615.926 6625.000 4601.154 28.290 30.045 50.793 65.241 7.000 63.353 0.001 63.352 Pass 6649.297 4638.148 6650.000 4620.269 28.353 30.198 49.814 60.485 7.000 65.918 0.001 65.917 Pass 6676.027 4660.505 6675.000 4639.466 28.350 30.309 48.523 55.334 7.000 67.748 0.001 67.747 Pass 6702.731 4682.904 6700.000 4658.744 28.340 30.380 46.881 49.785 7.000 68.888 0.001 68.887 Pass 6728.178 4704.277 6725.000 4678.129 28.339 30.470 44.583 46.122 7.000 69.524 0.001 69.523 Pass 6753.004 4725.131 6750.000 4697.645 28.363 30.586 42.223 43.763 7.000 70.137 0.001 70.136 Pass 6777.751 4745.983 6775.000 4717.291 28.351 30.668 40.165 40.030 7.000 70.752 0.001 70.751 Pass 6802.283 4766.942 6800.000 4737.067 28.318 30.720 37.789 34.876 7.000 71.436 0.001 71 .435 Pass 6826.581 4787.981 6825.000 4756.960 28.266 30.756 34.912 29.030 7.000 72.283 0.001 72.282 Pass 6850.602 4809.030 6850.000 4776.962 28.214 30.780 31.560 22.515 7.000 73.403 0.001 73.402 Pass 6874.311 4830.026 6875.000 4797.072 28.141 30.793 27.802 15.397 7.000 74.916 0.001 74.915 Pass 6897.674 4850.907 6900.000 4817.288 28.069 30.797 23.723 7.768 7.000 76.941 0.001 76.940 Pass 6920.655 4871.609 6925.000 4837.592 27.979 30.788 19.418 -0.265 7.000 79.616 0.001 79.615 Pass 6943.216 4892.073 6950.000 4857.963 27.888 30.771 15.001 351.429 7.000 83.066 0.001 83.065 Pass 6965.335 4912.246 6975.000 4878.403 27.787 30.748 10.599 343.005 7.000 87.367 0.001 87.366 Pass 6986.987 4932.084 7000.000 4898.911 27.682 30.718 6.323 334.609 7.000 92.564 0.001 92.563 Pass OR1 G\NAl- - 487- 412- 375- 337- 300- 262- 225- g 187- 450- ! ! 6935 , ! 6887 ! ! 6840 , 6745 ! , 6602 , 6555 50- 75- - 2- o . . o ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 F Pad 1 F-01 Plan 1F-01A 1 F-01A (wp04) Sperry-Sun Standard Proximity Anticollision Report 25 January, 2005 HALLIBURTON ORIGINAl- . . HALLIBURTON ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Anticollision Report for Kuparuk 1 F Pad - 1 F-01 - Plan 1 F-01A - 1 F-01A (wp04) Trav. Cylinder North Proximity Scan on Current Survey Data (True North Reference) Offset Design: Kuparuk iF Pad - iF-i8 -iF-i8 -iF-i8 Scan Radius is ft Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Relative Relative Depth Depth Depth Depth +N/-S +EI-W Distance North (ft) (ft) (ft) (ft) (ft) (ft) (ft) Direction 6,101.955 4,227.277 6.200.000 5,168.176 3,125.458 189.462 1.477.986 12.260 6,138.798 4,251.800 6,225.000 5,187.644 3,140.743 192.983 1,484.856 13.691 7,830.534 5,723.504 6,250.000 5,207.190 3,155.838 196.863 1,490.363 15.140 7,852.581 5,742.441 6,275.000 5,226.811 3,170.740 201.099 1,474.498 16.607 7,871.949 5.758.812 6,300.000 5,246.500 3,185.444 205.692 1,459.091 18.090 7,889.029 5,773.032 6,325.000 5,266.234 3,200.037 210.451 1,444.013 18.033 7.904.149 5,785.446 6,350.000 5,285.990 3,214.606 215.186 1,429.123 17.975 7.917.631 5,796.369 6,375.000 5,305.771 3,229.150 219.897 1,414.440 17.918 7,929.729 5,806.053 6,400.000 5.325.574 3,243.671 224.584 1,399.982 17.860 7,940.643 5,814.690 6.425.000 5,345.397 3,258.180 229.224 1,385.742 17.606 7,950.536 5,822.436 6,450.000 5,365.236 3,272.691 233.793 1,371.713 17.351 7,959.548 5,829.423 6,475.000 5,385.089 3,287.203 238.292 1.357.907 17.096 7,967.796 5,835.759 6,500.000 5,404.958 3.301.716 242.720 1.344.336 16.840 7,975.043 5,841.277 6,525.000 5,424.693 3,316.389 247.214 1,331.040 17.214 7,981.082 5,845.842 6,550.000 5,444.140 3,331.381 251.911 1,318.063 17.572 7,986.052 5,849.575 6,575.000 5,463.292 3,346.684 256.808 1,305.431 17.913 7,990.073 5,852.579 6,600.000 5,482.143 3,362.293 261.903 1,293.165 18.240 7,993.567 5,855.178 6,625.000 5,500.864 3,378.050 267.026 1,281.218 17.779 7,996.901 5,857.648 6,650.000 5,519.631 3,393.798 272.006 1,269.534 17.316 8,000.090 5,860.002 6,675.000 5,538.444 3,409.536 276.842 1,258.122 16.849 8.003.152 5,862.252 6,700.000 5.557.301 3,425.265 281.536 1,246.989 16.380 8,006.080 5,864.397 6,725.000 5.576.193 3,440.983 286.121 1,236.173 16.144 8,008.873 5,866.436 6.750.000 5,595.113 3,456.690 290.632 1.225.709 15.907 8,011.543 5,868.378 6,775.000 5,614.058 3.472.386 295.070 1,215.607 15.669 8,014.100 5,870.232 6,800.000 5,633.030 3,488.071 299.435 1,205.878 15.430 8,016.532 5.871.989 6,825.000 5,652.012 3,503.757 303.752 1,196.547 15.347 8,018.824 5,873.641 6,850.000 5,670.989 3,519.454 308.048 1,187.641 15.265 8,020.990 5,875.197 6,875.000 5,689.961 3,535.164 312.323 1,179.169 15.182 8.023.038 5,876.665 6.900.000 5.708.928 3,550.885 316.577 1,171.143 15.100 8,024.964 5,878.042 6.925.000 5,727.880 3,566.630 320.811 1,163.566 14.999 8,026.765 5,879.326 6,950.000 5,746.804 3.582.414 325.025 1.156.443 14.899 8,028.451 5,880.525 6,975.000 5,765.701 3.598.235 329.219 1,149.783 14.799 8,030.028 5,881.644 7,000.000 5,784.571 3,614.093 333.395 1,143.593 14.700 8,031.500 5.882.687 7,025.000 5,803.409 3,629.995 337.550 1,137.880 14.589 8,032.869 5.883.655 7,050.000 5,822.210 3,645.945 341.685 1,132.648 14.479 8,034.142 5.884.554 7,075.000 5,840.975 3,661.944 345.800 1,127.905 14.369 8,035.326 5,885.388 7,100.000 5,859.703 3,677.990 349.894 1,123.657 14.260 8,036.419 5,886.158 7,125.000 5,878.389 3,694.090 353.974 1,119.912 14.177 8,037.424 5,886.864 7,150.000 5,897.028 3,710.247 358.043 1,116.678 14.094 8,038.345 5,887.510 7,175.000 5.915.619 3,726.461 362.101 1,113.960 14.012 8,039.188 5,888.101 7.200.000 5,934.163 3,742.731 366.149 1,111.762 13.930 8,040.044 5,888.700 7.225.000 5,952.756 3,758.954 370.166 1,110.115 13.886 8,049.968 5,895.597 7.250.000 5,971.493 3,775.022 374.132 1,109.109 13.842 8,049.968 5,895.597 7,275.000 5,990.373 3,790.934 378.046 1,108.614 13.796 8,049.968 5,895.597 7,300.000 6,009.395 3.806.690 381.908 1,108.703 13.750 8,049.968 5.895.597 7,325.000 6,028.524 3,822.314 385.776 1,109.417 14.062 8,049.968 5,895.597 7,350.000 6,047.728 3,837.830 389.708 1,110.797 14.378 8,049.968 5,895.597 7,375.000 6,067.006 3,853.238 393.704 1,112.841 14.697 8.049.968 5,895.597 7,400.000 6,086.357 3,868.537 397.762 1,115.544 15.020 8,049.968 5,895.597 7,425.000 6,105.840 3,883.668 401.821 1,118.871 15.013 8,049.968 5,895.597 7,450.000 6,125.510 3,898.571 405.817 1.122.781 15.005 8,049.968 5,895.597 7,475.000 6,145.365 3,913.245 409.749 1.127.269 14.998 8,049.968 5,895.597 7,500.000 6,165.403 3,927.685 413.617 1.132.326 14.990 25 January, 2005 - 15:52 Page 2 of 6 COMPASS ORIGtNAL . . ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit HALLIBURTON Anticollision Report for Kuparuk 1 F Pad - 1 F-01 - Plan 1 F-01A - 1 F-01A (wp04) Trav. Cylinder North Proximity Scan on Current Survey Data (True North Reference) Offset Design: Kuparuk 1F Pad - 1F-18 -1F-18 -1F-18 Scan Radius is ft Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Relative Relative Depth Depth Depth Depth +N/-S +EI-W Distance North (ft) (ft) (ft) (ft) (ft) (ft) (ft) Direction 8.049.968 5,895.597 7,525.000 6.185.633 3,941.878 417.398 1,137.932 14.844 8,049.968 5,895.597 7.550.000 6,206.065 3,955.807 421.070 1,144.062 14.692 8,049.968 5,895.597 7,575.000 6,226.696 3,969.469 424.633 1.150.706 14.535 8,049.968 5,895.597 7,600.000 6,247.522 3,982.862 428.085 1.157.855 14.370 8,063.656 5,904.954 7,625.000 6,268.551 3,995.962 431.429 1.165.340 14.268 8,065.953 5,906.506 7,650.000 6,289.789 4.008.745 434.667 1,173.433 14.161 8,068.360 5,908.128 7,675.000 6,311.233 4.021.209 437.799 1,182.002 14.049 8,070.874 5,909.814 7,700.000 6,332.877 4.033.349 440.824 1,191.033 13.930 8,073.465 5,911.546 7,725.000 6,354.689 4.045.204 443.769 1.200.525 13.979 8,076.105 5,913.305 7,750.000 6,376.641 4.056.812 446.665 1.210.476 14.030 8,078.793 5,915.087 7,775.000 6,398.729 4,068.171 449.509 1.220.873 14.084 8,081.526 5,916.893 7,800.000 6,420.950 4,079.280 452.301 1,231.701 14.140 25 January, 2005 - 15: 52 Page 3 of 6 COMPASS ORIGINAL . . HALLIBURTON ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Anticollision Report for Kuparuk 1F Pad -1F-01 - Plan 1F-01A -1F-01A (wp04) Trav. Cylinder North Proximity Scan on Current Survey Data (True North Reference) Offset Design: Kuparuk 1 F Pad - 1 F-11 - 1 F-11 - 1 F-11 Scan Radius is ft Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Relative Relative Depth Depth Depth Depth +N/-S +EI-W Distance North (ft) (ft) (ft) (ft) (ft) (ft) (ft) Direction 6,102.592 4,227.699 5,950.000 4,440.003 3,460.764 -2.263.496 1,650.836 320.359 6,528.241 4.538.543 5,975.000 4,458.808 3,473.460 -2,273.991 1,660.131 320.485 6,535.961 4.544.782 6,000.000 4,477.632 3,486.164 -2,284.445 1,663.946 320.610 6,549.974 4,556.153 6,025.000 4,496.479 3,498.865 -2,294.861 1,668.015 320.682 6,549.974 4.556.153 6,050.000 4,515.352 3,511.555 -2,305.241 1,672.231 320.754 6,549.974 4,556.153 6,075.000 4,534.251 3,524.235 -2,315.586 1,676.781 320.827 6,549.974 4,556.153 6,100.000 4,553.177 3,536.905 -2,325.896 1,681.660 320.900 6,574.143 4,575.899 6,125.000 4,572.130 3,549.555 -2,336.181 1,686.321 320.878 6,581.685 4,582.092 6,150.000 4,591.110 3,562.177 -2,346.450 1,691.488 320.855 6,599.974 4,597.166 6,175.000 4,610.116 3,574.770 -2,356.705 1,697.007 320.833 6,599.974 4,597.166 6,200.000 4,629.150 3,587.335 -2,366.945 1,702.553 320.810 6,599.974 4,597.166 6,225.000 4,648.151 3,599.926 -2,377.211 1,708.462 320.810 6,599.974 4,597.166 6,250.000 4,667.062 3,612.600 -2,387.543 1,714.748 320.810 6,618.805 4,612.762 6,275.000 4,685.881 3,625.355 -2,397.943 1,721.067 320.810 6,626.087 4,618.811 6,300.000 4,704.608 3,638.192 -2,408.408 1,727.781 320.810 6,649.973 4,638.712 6,325.000 4,723.228 3,651.140 -2,418.926 1,735.002 321.015 6,649.973 4.638.712 6,350.000 4,741.728 3,664.229 -2.429.481 1,741.997 321.216 6,649.973 4,638.712 6,375.000 4,760.107 3,677.458 -2,440.074 1,749.307 321.415 6,649.973 4,638.712 6.400.000 4.778.363 3,690.828 -2,450.704 1,756.927 321.610 6,649.973 4,638.712 6,425.000 4.796.490 3,704.346 -2,461.365 1,764.844 321.866 6,668.649 4,654.326 6.450.000 4,814.481 3,718.023 -2,472.054 1,772.717 322.118 6,675.541 4,660.097 6,475.000 4,832.336 3,731.858 -2,482.769 1,780.914 322.366 6.699.973 4,680.589 6,500.000 4.850.052 3,745.850 -2,493.509 1,789.595 322.610 6.699.973 4,680.589 6,525.000 4,867.635 3,759.970 -2,504.301 1,798.024 322.610 6,699.973 4,680.589 6.550.000 4.885.089 3,774.190 -2,515.169 1,806.793 322.610 6.699.973 4,680.589 6.575.000 4,902.414 3,788.510 -2,526.114 1,815.896 322.610 6.712.000 4,690.688 6,600.000 4.919.609 3,802.928 -2,537.133 1,825.260 322.610 6,724.108 4,700.859 6,625.000 4.936.704 3,817.422 -2,548.211 1,834.823 322.610 6,746.461 4,719.634 6,650.000 4.953.728 3,831.968 -2,559.328 1,844.449 322.610 6.762.000 4,732.687 6.675.000 4.970.682 3,846.565 -2,570.484 1,854.123 322.610 6,774.385 4,743.130 6,700.000 4.987.566 3,861.215 -2,581.681 1,863.938 322.610 6.783.738 4,751.070 6,725.000 5.004.413 3,875.885 -2,592.904 1,873.945 322.557 6.799.973 4,764.956 6,750.000 5.021.258 3,890.546 -2,604.141 1,884.170 322.505 6,799.973 4,764.956 6,775.000 5,038.102 3,905.198 -2,615.392 1,894.520 322.452 6,799.973 4,764.956 6,800.000 5,054.944 3,919.841 -2,626.658 1,905.157 322.400 6,819.938 4,782.204 6,825.000 5.071.773 3,934.499 -2,637.925 1,915.805 322.503 6,828.685 4,789.816 6.850.000 5,088.576 3,949.196 -2,649.181 1,926.676 322.606 6,849.973 4,808.477 6.875.000 5,105.353 3,963.931 -2,660.423 1.937.792 322.708 6,849.973 4,808.477 6,900.000 5,122.104 3,978.705 -2,671.654 1.948.859 322.810 6,849.973 4,808.477 6,925.000 5,138.848 3,993.491 -2,682.879 1,960.173 322.783 6,849.973 4,808.477 6,950.000 5,155.607 4.008.262 -2,694.103 1,971.744 322.755 6,870.602 4,826.730 6,975.000 5,172.380 4.023.017 -2,705.327 1,983.295 322.728 6,878.631 4,833.876 7,000.000 5,189.166 4,037.757 -2,716.550 1,995.111 322.700 6,899.972 4,852.974 7,025.000 5,205.950 4,052.486 -2,727.790 2,007.223 322.602 6,899.972 4,852.974 7,050.000 5,222.716 4,067.208 -2,739.065 2,019.315 322.505 6,899.972 4,852.974 7,075.000 5,239.465 4,081.925 -2,750.376 2,031.674 322.407 6,899.972 4,852.974 7,100.000 5,256.195 4,096.634 -2,761.721 2,044.295 322.310 6,916.896 4,868.218 7,125.000 5,272.854 4,111.398 -2,773.101 2,056.972 322.437 6,924.150 4,874.776 7,150.000 5,289.387 4,126.276 -2,784.517 2,069.859 322.563 6,931.261 4,881.219 7,175.000 5,305.792 4,141.267 -2,795.968 2,082.898 322.687 6,949.972 4,898.231 7,200.000 5,322.069 4,156.371 -2,807.454 2,096.176 322.810 6,949.972 4,898.231 7,225.000 5,338.202 4,171.593 -2,818.988 2,109.449 322.887 6,949.972 4,898.231 7,250.000 5,354.173 4.186.938 -2,830.583 2,122.949 322.962 25 January, 2005 - 15:52 Page 4 of 6 COMPASS ORIGINAL . . HALLIBURTON ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Anticollision Report for Kuparuk 1 F Pad - 1 F-01 - Plan 1 F-01A - 1 F-01A (wp04) Trav. Cylinder North Proximity Scan on Current Survey Data ITrue North Reference) Offset Design: Kuparuk 1 F Pad - 1 F-11 - 1 F-11 - 1 F-11 Scan Radius is ft Reference Well Comparison Well Proximity Measured Vertical Measured Vertical Relative Relative Depth Depth Depth Depth +N/-S +EI-W Distance North 1ft) 1ft) 1ft) 1ft) 1ft) 1ft) 1ft) Direction 6,949.972 4.898.231 7,275.000 5,369.982 4,202.405 -2,842.238 2,136.671 323.037 6,949.972 4,898.231 7,300.000 5,385.627 4,217.993 -2,853.953 2,150.608 323.110 6,970.833 4,917.285 7,325.000 5,401.123 4,233.676 -2,865.740 2,164.490 323.034 6,976.908 4,922.849 7,350.000 5,416.484 4,249.427 -2.877.612 2,178.707 322.958 6.982.838 4,928.287 7,375.000 5.431.709 4,265.247 -2,889.567 2,193.116 322.884 6,999.972 4,944.027 7,400.000 5,446.799 4,281.133 -2.901.605 2,207.801' 322.810 6.999.972 4,944.027 7.425.000 5,461.760 4,297.099 -2,913.698 2,222.499 322.909 6.999.972 4,944.027 7,450.000 5,476.603 4,313.157 -2,925.816 2.237.375 323.007 6,999.972 4,944.027 7.475.000 5,491.326 4,329.305 -2,937.960 2,252.424 323.104 6,999.972 4,944.027 7,500.000 5,505.928 4,345.543 -2,950.129 2.267.642 323.200 6,999.972 4,944.027 7,525.000 5,520.430 4,361.866 -2,962.306 2,283.014 323.354 Survey too/øroaram From 1ft) To 1ft) Survey/Plan Survey Tool 200.00 6,232.00 6.232.00 8.378.92 1F-01A(wp04) FINDER-MS MWD 25 January, 2005 - 15:52 Page 5 of6 COMPASS ORIGINAL Anticollision Report for Kuparuk 1 F Pad - 1 - Plan 1 F-01A - 1 Vertical Depths are relative to 1 F-01 @ 115.0001t (1 F-01). Northing and Easting are relative to 1 F-01 Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meidian is -150.00". Grid Convergence at Surface is: 0.3020 2200 -- C ~ o LO 1650 LO .......... c o :.¡::; ro ..... ro c.. ¿ß 1100 () ..... ..... C () Ü o ..... () J::; 550 c () Ü Ladder Plot ~ ---'---'~~- ~ ,"- ~ - .-'--.- ~ o o 1500 -'-- -- i I 3000 4500 6000 Measured Depth (1500 ftlin) LEGEND Cm:lOcoPhillips Alaska A (wp04) 7500 1F-11, 1F-i1, iF-11 iF-i8, 1F-18, iF-18'" 1F-01A (wp04) COMPASS 1 F-01 (TD) Plan #5 1F-01 L 1 Plan Prudhoe ay, Alaska Rig: Nordic #2 aker ughes I TE ellplanning Report Date: 02/10/05 INTEQ: James Ohlinger INTEQ Operator: Field: Version # 5 4 ConocoPhillips Kuparuk Date . Well: Rig: Well plan Revision Log . 115.0 L. Gantt Include relevant comments including incoming document source & output recipients when appropriate 1F-01A & AL 1 RKB: Nordic 2 Engineer: Description Copy of Lamar's Plan#5 for 1 F-01A (CTD) Copy of Lamar's Plan#4 for 1 F-01 AL 1 WPRevLog ver 1.1 17 -May-99 ORIGINAL r&ii. BAKIR HUGHIS INTEQ Rvsd/Drawn Lamar G. Lamar G. . . BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: KRU 1 F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 5958733.30 ft 539521.50 ft Latitude: 70 17 Longitude: 149 40 North Reference: Grid Convergence: 53.527 N 47.811 W True 0.30 deg 0.00 ft 0.00 ft Well: 1 F-01 Stot Name: Well Position: +N/-S -368.55 ft Northing: +E/-W 68.43 ft Easting: Position Uncertainty: 0.00 ft 5958365.15 ft' Latitude: 539591.86 ft ' Longitude: 70 17 49.903 N 149 40 45.817 W Wellpath: Plan #51F-01A - CTD +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1F-01A - Rotary ST 8200.00 ft Mean Sea Level 24.38 deg 80.73 deg Direction deg 349.00 Current Datum: Magnetic Data: Fietd Strength: Vertical Section: 1 F-01 RKB 2/11/2005 57583 nT Depth From (TVD) ft 0.00 Height 115.00 ft Targets Annotation 8200.00 8285.00 8305.00 8601.20 10550.00 5989.11 6037.87 6049.11 6139.69 0.00 TIP KOP 3 - end of 9 DLS 4 - end of 28 DSL TO Plan: Plan #5 Date Composed: Version: Tied-to: 2/11/2005 2 From: Definitive Path Principat: Yes ptan Section Information 8200.00 55.00 210.00 5989.11 4076.47 -713.12 0.00 0.00 0.00 0.00 8285.00 55.00 210.00 6037.87 4016.17 -747.93 0.00 0.00 0.00 0.00 8305.00 56.56 211.08 6049.11 4001.92 -756.34 9.00 7.82 5.39 30.00 8345.00 62.65 222.00 6069.39 3974.34 -776.90 28.00 15.21 27.29 60.00 8445.00 66.07 252.90 6113.53 3926.95 -851.79 28.00 3.42 30.91 90.00 8601.20 95.00 286.56 6139.69 3928.20 -1001.96 28.00 18.52 21.55 53.00 8687.00 95.10 299.48 6132.11 3961.55 -1080.45 15.00 0.11 15.06 89.00 8887.00 92.42 269.53 6118.70 4010.88 -1271.45 15.00 -1.34 -14.97 266.00 9127.00 91.96 305.56 6109.22 4081.99 -1496.36 15.00 -0.19 15.01 90.00 9277.00 94.10 283.12 6101.19 4143.36 -1631.94 15.00 1.43 -14.95 276.00 9402.00 90.06 264.80 6096.62 4151.92 -1756.00 15.00 -3.23 -14.66 258.00 9652.00 87.61 302.23 6101.88 4209.26 -1994.72 15.00 -0.98 14.97 94.00 ORJ G,I:N,Al . . BP-GDB Baker Hughes INTEQ Planning Report ptan Section Information 9932.00 87.56 260.19 6114.23 4262.44 -2263.00 15.00 -0.02 -15.01 269.00 10212.00 87.52 302.23 6126.82 4315.61 -2531.26 15.00 -0.01 15.01 91.00 10287.00 88.15 313.47 6129.67 4361.52 -2590.34 15.00 0.84 14.99 87.00 10550.00 88.57 274.01 6137.51 4465.27 -2826.25 15.00 0.16 -15.01 270.00 Survey 8200.00 55.00 210.00 5874.11 4076.47 -713.12 5962437.40 538857.35 4137.64 0.00 0.00 MWD 8285.00 55.00 210.00 5922.87 4016.17 -747.93 5962376.93 538822.86 4085.09 0.00 0.00 MWD 8300.00 56.17 210.81 5931.35 4005.49 -754.19 5962366.22 538816.65 4075.81 9.00 30.00 MWD 8305.00 56.56 211.08 5934.11 4001.92 -756.34 5962362.64 538814.53 4072.71 9.00 29.54 MWD 8320.00 58.74 215.33 5942.14 3991.33 -763.28 5962352.01 538807.64 4063.64 28.00 60.00 MWD 8340.00 61.84 220.70 5952.06 3977.66 -773.98 5962338.29 538797.02 4052.26 28.00 57.72 MWD 8345.00 62.65 222.00 5954.39 3974.34 -776.90 5962334.95 538794.11 4049.56 28.00 55.06 MWD 8360.00 62.73 226.72 5961.27 3964.81 -786.22 5962325.38 538784.85 4041.99 28.00 90.00 MWD 8380.00 63.08 233.00 5970.39 3953.35 -799.82 5962313.84 538771.31 4033.32 28.00 87.83 MWD 8400.00 63.71 239.23 5979.36 3943.39 -814.65 5962303.80 538756.52 4026.38 28.00 84.97 MWD 8420.00 64.60 245.37 5988.08 3935.03 -830.58 5962295.36 538740.64 4021.21 28.00 82.18 MWD 8440.00 65.74 251.41 5996.49 3928.35 -847.45 5962288.60 538723.81 4017.88 28.00 79.50 MWD 8445.00 66.07 252.90 5998.53 3926.95 -851.79 5962287.17 538719.48 4017.33 28.00 76.96 MWD 8460.00 68.63 256.50 6004.31 3923.30 -865.14 5962283.46 538706.15 4016.30 28.00 53.00 MWD 8480.00 72.17 261.11 6011.02 3919.66 -883.62 5962279.71 538687.69 4016.24 28.00 51.61 MWD 8500.00 75.82 265.54 6016.53 3917.43 -902.70 5962277.39 538668.62 4017.70 28.00 50.07 MWD 8520.00 79.54 269.82 6020.80 3916.64 -922.22 5962276.50 538649.11 4020.65 28.00 48.84 MWD 8540.00 83.31 274.00 6023.79 3917.31 -941.98 5962277.06 538629.36 4025.07 28.00 47.93 MWD 8560.00 87.12 278.12 6025.45 3919.41 -961.79 5962279.06 538609.54 4030.92 28.00 47.30 MWD 8580.00 90.95 282.21 6025.79 3922.94 -981.46 5962282.48 538589.84 4038.14 28.00 46.96 MWD 8601.20 95.00 286.56 6024.69 3928.20 -1001.96 5962287.63 538569.32 4047.21 28.00 46.89 MWD 8625.00 95.05 290.14 6022.60 3935.66 -1024.46 5962294.98 538546.78 4058.83 15.00 89.00 MWD 8650.00 95.09 293.91 6020.39 3945.00 -1047.54 5962304.19 538523.66 4072.40 15.00 89.31 MWD 8675.00 95.10 297.67 6018.17 3955.83 -1069.96 5962314.90 538501.19 4087.31 15.00 89.65 MWD 8687.00 95.10 299.48 6017.11 3961.55 -1080.45 5962320.56 538490.66 4094.92 15.00 89.98 MWD 8700.00 94.96 297.53 6015.97 3967.73 -1091.83 5962326.68 538479.25 4103.16 15.00 266.00 MWD 8725.00 94.67 293.77 6013.87 3978.51 -1114.29 5962337.35 538456.74 4118.03 15.00 265.83 MWD 8750.00 94.37 290.03 6011.90 3987.80 -1137.40 5962346.52 538433.58 4131.56 15.00 265.51 MWD 8775.00 94.05 286.28 6010.06 3995.57 -1161.09 5962354.16 538409.85 4143.71 15.00 265.22 MWD 8800.00 93.71 282.54 6008.37 4001.78 -1185.25 5962360.23 538385.67 4154.41 15.00 264.94 MWD 8825.00 93.36 278.80 6006.83 4006.39 -1209.76 5962364.72 538361.13 4163.62 15.00 264.69 MWD 8850.00 92.99 275.06 6005.44 4009.40 -1234.54 5962367.60 538336.34 4171.30 15.00 264.46 MWD 8875.00 92.61 271.32 6004.22 4010.79 -1259.46 5962368.86 538311.41 4177.42 15.00 264.25 MWD 8887.00 92.42 269.53 6003.70 4010.88 -1271.45 5962368.88 538299.42 4179.79 15.00 264.07 MWD 8900.00 92.42 271.48 6003.15 4011.00 -1284.44 5962368.93 538286.44 4182.39 15.00 90.00 MWD 8925.00 92.41 275.24 6002.09 4012.46 -1309.37 5962370.26 538261.50 4188.58 15.00 90.08 MWD 8950.00 92.39 278.99 6001.05 4015.55 -1334.15 5962373.22 538236.71 4196.34 15.00 90.24 MWD 8975.00 92.35 282.74 6000.02 4020.26 -1358.68 5962377.80 538212.16 4205.64 15.00 90.40 MWD 9000.00 92.31 286.50 5999.00 4026.56 -1382.84 5962383.98 538187.96 4216.44 15.00 90.55 MWD 9025.00 92.26 290.25 5998.00 4034.43 -1406.55 5962391.72 538164.22 4228.69 15.00 90.71 MWD 9050.00 92.20 294.00 5997.02 4043.84 -1429.68 5962401.01 538141.03 4242.34 15.00 90.86 MWD 9075.00 92.13 297.75 5996.08 4054.74 -1452.16 5962411.79 538118.51 4257.33 15.00 91.00 MWD 9100.00 92.05 301.50 5995.17 4067.09 -1473.87 5962424.02 538096.73 4273.60 15.00 91.14 MWD 9127.00 91.96 305.56 5994.22 4081.99 -1496.36 5962438.80 538074.17 4292.51 15.00 91.28 MWD 9150.00 92.31 302.12 5993.36 4094.79 -1515.45 5962451.50 538055.01 4308.72 15.00 276.00 MWD OR\G\NAL . . BP-GDB Baker Hughes INTEQ Planning Report Survey 9175.00 92.69 298.39 5992.27 4107.37 -1537.02 5962463.96 538033.38 4325.18 15.00 275.87 MWD 9200.00 93.06 294.65 5991.02 4118.52 -1559.36 5962474.99 538010.98 4340.39 15.00 275.71 MWD 9225.00 93.41 290.91 5989.61 4128.18 -1582.36 5962484.53 537987.93 4354.26 15.00 275.52 MWD 9250.00 93.75 287.17 5988.04 4136.32 -1605.95 5962492.55 537964.31 4366.75 15.00 275.31 MWD 9277.00 94.10 283.12 5986.19 4143.36 -1631.94 5962499.45 537938.28 4378.62 15.00 275.08 MWD 9300.00 93.38 279.74 5984.69 4147.91 -1654.43 5962503.88 537915.76 4387.38 15.00 258.00 MWD 9325.00 92.58 276.08 5983.40 4151.34 -1679.16 5962507.18 537891.02 4395.47 15.00 257.78 MWD 9350.00 91.77 272.41 5982.45 4153.19 -1704.07 5962508.90 537866.11 4402.03 15.00 257.59 MWD 9375.00 90.95 268.75 5981.86 4153.44 -1729.05 5962509.02 537841.12 4407.05 15.00 257.45 MWD 9402.00 90.06 264.80 5981.62 4151.92 -1756.00 5962507.36 537814.18 4410.70 15.00 257.36 MWD 9425.00 89.82 268.24 5981.64 4150.53 -1778.96 5962505.84 537791.24 4413.71 15.00 94.00 MWD 9450.00 89.56 271.98 5981.78 4150.58 -1803.95 5962505.76 537766.24 4418.53 15.00 94.00 MWD 9475.00 89.30 275.72 5982.03 4152.26 -1828.89 5962507.31 537741.30 4424.94 15.00 93.98 MWD 9500.00 89.04 279.46 5982.39 4155.56 -1853.67 5962510.48 537716.51 4432.90 15.00 93.94 MWD 9525.00 88.79 283.21 5982.86 4160.47 -1878.17 5962515.26 537691.99 4442.40 15.00 93.88 MWD 9550.00 88.55 286.95 5983.44 4166.97 -1902.30 5962521.63 537667.83 4453.39 15.00 93.81 MWD 9575.00 88.31 290.69 5984.13 4175.03 -1925.95 5962529.57 537644.14 4465.81 15.00 93.73 MWD 9600.00 88.07 294.44 5984.92 4184.62 -1949.02 5962539.03 537621.02 4479.63 15.00 93.62 MWD 9625.00 87.85 298.18 5985.81 4195.69 -1971.41 5962549.99 537598.57 4494.77 15.00 93.51 MWD 9652.00 87.61 302.23 5986.88 4209.26 -1994.72 5962563.43 537575.19 4512.54 15.00 93.37 MWD 9675.00 87.56 298.78 5987.85 4220.92 -2014.52 5962574.99 537555.34 4527.76 15.00 269.00 MWD 9700.00 87.51 295.02 5988.92 4232.22 -2036.79 5962586.17 537533.01 4543.10 15.00 269.15 MWD 9725.00 87.47 291.27 5990.02 4242.04 -2059.75 5962595.86 537510.00 4557.12 15.00 269.31 MWD 9750.00 87.44 287.52 5991.13 4250.33 -2083.30 5962604.03 537486.40 4569.75 15.00 269.47 MWD 9775.00 87.42 283.76 5992.25 4257.06 -2107.35 5962610.64 537462.32 4580.95 15.00 269.64 MWD 9800.00 87.41 280.01 5993.38 4262.21 -2131.78 5962615.65 537437.87 4590.66 15.00 269.81 MWD 9825.00 87.42 276.26 5994.51 4265.74 -2156.50 5962619.05 537413.13 4598.85 15.00 269.98 MWD 9850.00 87.43 272.50 5995.63 4267.65 -2181.40 5962620.83 537388.23 4605.47 15.00 270.15 MWD I 9875.00 87.46 268.75 5996.74 4267.92 -2206.37 5962620.97 537363.26 4610.50 15.00 270.31 MWD 9900.00 87.50 265.00 5997.84 4266.56 -2231.30 5962619.47 537338.33 4613.92 15.00 270.48 MWD 9925.00 87.54 261.24 5998.93 4263.56 -2256.09 5962616.35 537313.56 4615.71 15.00 270.65 MWD 9932.00 87.56 260.19 5999.23 4262.44 -2263.00 5962615.19 537306.67 4615.92 15.00 270.81 MWD 9950.00 87.51 262.89 6000.00 4259.79 -2280.78 5962612.45 537288.89 4616.72 15.00 91.00 MWD í 9975.00 87.46 266.65 6001.10 4257.51 -2305.65 5962610.04 537264.04 4619.23 15.00 90.88 MWD 10000.00 87.42 270.40 6002.21 4256.87 -2330.61 5962609.27 537239.09 4623.36 15.00 90.72 MWD 10025.00 87.39 274.15 6003.34 4257.86 -2355.56 5962610.13 537214.13 4629.10 15.00 90.55 MWD 10050.00 87.37 277.91 6004.49 4260.49 -2380.39 5962612.62 537189.29 4636.41 15.00 90.38 MWD 10075.00 87.36 281.66 6005.64 4264.73 -2405.00 5962616.73 537164.67 4645.27 15.00 90.21 MWD 10100.00 87.37 285.42 6006.79 4270.58 -2429.27 5962622.45 537140.36 4655.64 15.00 90.04 MWD 10125.00 ·87.38 289.17 6007.93 4278.00 -2453.11 5962629.75 537116.49 4667.47 15.00 89.86 MWD 10150.00 87.41 292.92 6009.07 4286.96 -2476.42 5962638.59 537093.14 4680.72 15.00 89.69 MWD 10175.00 87.44 296.68 6010.20 4297.44 -2499.09 5962648.94 537070.42 4695.33 15.00 89.52 MWD 10200.00 87.49 300.43 6011.30 4309.37 -2521.02 5962660.76 537048.42 4711.23 15.00 89.35 MWD 10212.00 87.52 302.23 6011.82 4315.61 -2531.26 5962666.94 537038.15 4719.30 15.00 89.19 MWD 10225.00 87.62 304.18 6012.38 4322.72 -2542.13 5962673.99 537027.25 4728.36 15.00 87.00 MWD 10250.00 87.83 307.93 6013.37 4337.42 -2562.32 5962688.59 537006.98 4746.64 15.00 86.92 MWD 10275.00 88.04 311.67 6014.27 4353.41 -2581.51 5962704.47 536987.71 4766.00 15.00 86.77 MWD 10287.00 88.15 313.47 6014.67 4361.52 -2590.34 5962712.54 536978.83 4775.65 15.00 86.63 MWD 10300.00 88.15 311.52 6015.09 4370.30 -2599.92 5962721.27 536969.21 4786.09 15.00 270.00 MWD 10325.00 88.16 307.77 6015.89 4386.24 -2619.16 5962737.10 536949.89 4805.41 15.00 270.06 MWD 10350.00 88.17 304.02 6016.69 4400.89 -2639.40 5962751.64 536929.58 4823.65 15.00 270.18 MWD 10375.00 88.20 300.27 6017.49 4414.18 -2660.55 5962764.82 536908.36 4840.73 15.00 270.30 MWD 10400.00 88.23 296.51 6018.27 4426.06 -2682.53 5962776.58 536886.32 4856.59 15.00 270.42 MWD jORJGI~JAL . . BP-GDB Baker Hughes INTEQ Planning Report Survey 10425.00 88.27 292.76 6019.03 4436.47 -2705.24 5962786.87 536863.56 4871.15 15.00 270.54 MWD 10450.00 88.32 289.01 6019.77 4445.38 -2728.58 5962795.66 536840.17 4884.34 15.00 270.65 MWD 10475.00 88.37 285.26 6020.50 4452.74 -2752.46 5962802.89 536816.26 4896.13 15.00 270.77 MWD 10500.00 88.43 281.51 6021.20 4458.52 -2776.76 5962808.55 536791.92 4906.44 15.00 270.87 MWD 10525.00 88.50 277.76 6021.87 4462.71 -2801.40 5962812.60 536767.27 4915.25 15.00 270.98 MWD r 10550.00 88.57 274.01 6022.51 4465.27 -2826.25 5962815.03 536742.40 4922.50 15.00 271.08 MWD rlR' JG-I~J'AI UJ'~'·.¡j'. ._ . . BP-GDB Baker Hughes INTEQ Planning Report Field: Kuparuk River Unit North Slope UNITED STATES Map SystentJS State Plane Coordinate System 1927 Geo DatumNAD27 (Clarke 1866) Sys Datum:Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: KRU 1F Pad North Slope Site Position: From: Map Position Uncertainty: Ground Level: Northing: 5958733.30 ft Easting: 539521.50 ft Latitude: 70 Longitude: 149 North Reference: Grid Convergence: 0.00 ft 0.00 ft Well: 1 F-01 Slot Name: Well Position: +N/-S -368.55 ft Northing: 5958365.15 ft +E/-W 68.43 ft Easting: 539591.86 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan #4 1F-01AL1 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: 1F-01 RKB Magnetic Data: 2/11/2005 Fietd Strength: 57583 nT Vertical Section: Depth From (TVD) ft 0.00 Heigh t 115.00 ft +N/-S ft 0.00 Targets Alaska, Zone 4 Well Centre bggm2004 17 53.527 N 40 47.811 W True 0.30 deg 70 17 49.903 N 149 40 45.817 W 1F-01A - Rotary ST 8165.00 ft Mean Sea Level 24.38 deg 80.73 deg Direction deg 349.00 Annotation 8100.00 8165.00 8185.00 8365.00 10325.00 5929.77 5969.19 5980.40 5996.97 0.00 TIP KOP 3 - end of 9 DLS 4 - end of 38 DLS TO Plan: Plan #4 Date Composed: Version: Tied-to: Principat: Yes Plan Section Information 2/11/2005 1 From: Definitive Path 8100.00 50.31 208.33 5929.77 4146.46 -673.49 0.00 0.00 0.00 0.00 8165.00 55.00 210.00 5969.19 4101.36 -698.68 7.50 7.22 2.57 16.32 8185.00 56.77 210.37 5980.40 4087.05 -707.01 9.00 8.87 1.87 10.00 8289.46 96.00 216.78 6004.54 4004.42 -762.43 38.00 37.55 6.13 10.00 8365.00 95.26 245.61 5996.97 3957.83 -820.39 38.00 -0.98 38.18 90.00 8515.00 95.24 268.21 5983.06 3924.23 -964.93 15.00 -0.01 15.06 89.00 8615.00 95.32 283.27 5973.80 3934.16 -1063.71 15.00 0.08 15.06 89.00 8765.00 92.82 305.69 5963.02 3995.81 -1198.97 15.00 -1.67 14.95 95.50 9030.00 92.17 265.91 5951.01 4066.43 -1448.62 15.00 -0.25 -15.01 270.00 9180.00 92.61 288.43 5944.68 4085.01 -1596.36 15.00 0.30 15.01 88.40 9340.00 92.79 312.45 5937.02 4165.38 -1733.14 15.00 0.11 15.02 89.00 9705.00 85.91 258.10 5941.47 4258.04 -2071.94 15.00 -1.89 -14.89 263.00 OR\G\~jA1- Plan: Plan #5 (1F"()1/Plan #5 1F~1A -CTD) Created By: Brij Potni! Date: 2/1112005 Contact Information: '6t~~~ ~S~~4'41D2 Hughes I~E~I~ ~~~~~:ðåro Azimuths 10 True North Megnelic North: 24.38· Megnelic Field Strength: 57583nT D~e~~g~; ~g'Jg~ Model: bggm2004 T ~~:g~ H~:g~Å-Rcn.rysrl' M 1F~1 (PlanI41F-ÐIAL1) A PlantS1F-Ð1A-CTD ,L Pion" e ConocÓFÍhillips Inc. ConocoPhillips Alaska, "LLP.TH DDAtU P'" NU..,. . en u..,....~ ST ....... No__ ,.....,.. : ~?.:: . Bake INTI!:Q 5200 500, 4801 .... c ;:¡ 4701 ... o 04801 ... .... _501 + :ë 4400 1:: o ! 4300 - :æ-4200 .. ð4101 II) 4001 ~ REFERENCE INFORMATION Co-orclinate ~~ Reference: Well Centre: 1F~1, True North Vertical ( D Reference: srcstem: Mean Sea Level Mea~:=~~~~ ~::~~~~ ~F~; ~~N,O·~~~oo Calculation Method: Minimum Curvature -- ....... - .. ... .. 1YD - .- -- -- , aøa.. ILOO ".... ..,..." ....... ·71:1.'1 .... 0.. 4'IU." 2 ..... II.IID..... -.117 .....'7 ·7.,..0 .... .... ...... :I ........ 21'. SD4." 4D01.n ....... LOa ... 4ImL71 · -.00 __ t2&DCI ...... ..,&U .ne..eou.oa_._ · ..... -.ør 2tII.M ....a ..... ......n .... _. 11III17..2:1 · ...... KOO..... .-aL. .... ....0D1... ILOCI DoOO -..J'-I1 7 ...,.. .,..... "'7." ................. ,s.oG .._ ........ · ....,.00.... 211D.a ...ua.70 ...ca.u -1171.... 'LDCI __. .n..:n · ...17...........,.. .....12 """M -1.... '&00 IILOO ...... ,. 1IZ77.. ....,. 2U.11 _i' ...... -1D'1'" 1..00 an.oo on.a 11 NØI.OO .......... 1H'I.12 ........ -1H1.111 1&00 -.ao ......n '1 ...... ..,.... --.a _.. ..... -1.....12 1&00 14.00 81..... ,:1 -.00 ..,.. -.1. -.aa ....... .zaa.oo ,&. -.00 ....... '4 10111.00 "''':MZ.D eo11.12 01"" -IID1.a ,&. ....ao .,.,-.- is 101Ø.1IO 1&.,. 3'I:a.G' ........, ....ø --.u ,&. ..,.ao 47I'LM ,. 1_ -.w 17...... -" ...-.a7.-U '&.øa.oo-.. .NNOT.TION. TAAGET DETAU N~ ... ..- .... -- -..... "'4.77 .,..... TIP. '....'.L' ..... .....N .,..... KOP· ,....'.L' Hzz..7 U..... UP. ,....,. HMo11 UO.... J·..."'.DU "14." ...,.1. .·....r H HL .".... ,....... TD ...,4." U..... TIP. ,....,. 5450 5500 5550 P.-.......... t1e...1h ... ........... v.._ - _H' . -400 5750 5800 5850 2/11/2005 10:31 AM -500 IT -600 -700 I I"I'Î I T I -3000-2900-2800-2700-2600-2500-2400-2300-2200-21 00 -2000-1900-1800-1700-1600 -1500-1400-1300-1200-11 00-1 000 -900 West, . P--'-T--'--'--r r--~--'-Î 4850 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 Vertical Section at 349.00' [50ft/in] ë5600 æ 5650 o ~570(} .c 'S.s750 GI Q 5800 ¡¡ U 5850 1: :: 5900 ë 5950 ... 6000 o ;0 ~., G) -' z » r 6050 610(} 6150 . aD rrrJ KRU 1F-01A & L1 Producer Proposed Com pletion ¡¡¡ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 0 3/4" 45.5# @ 2630' o ;cJ ~ (j) - z » r 7" 26# K-55 Window @ -6232 MD' 2-7/8" liner top @ ¡ +1- 8175' MD , I............ ~ 0 I', 0 I . ~...., I_~_';~"'~ J"'''''~ Weatherford retrievable whipstock @ 8165' md (with plug) ~ Weatherford KS perm packerllatch +/-8180' MD = ~ 2-7/8" Camco 0 nipple, 2.25" min 10 (or HES XN, 2.25" min 10) @ 8200' md ¡¡¡ I I lit.' lit.' ~ ~ ~ ~ [ 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ í!! ~ ~ í!! ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ í!! ~ ~ ~ ~ ~ ~ ~ ~ í!! ~ ~ í!! í!! ~ ~ j¡1 ~ ~ ~ í!! í!! í!! í!! ~ ~ í!! í!! ~ ~ í!! í!! ~ ~ ~ ~ ~ ~ ill ~ j¡1 j¡1 ..J í!! í!! ~ L 1 KOP 8165' MD Window in 4-1/2" C - Sand KOP 8285' MD A - Sand 4-1/2" 12.6# L-80 @ 8378' MD o - - 4 W' Cameo TRM-4E SSSV 3.812" Min. I.D. 4-1/2" 12.6# L-80 IBT Mod Tubing 4-W' Cameo KBMG GLMs at 2600',3700', & 4175' MD 4-'V2" Cameo DB nipple, 3.75" min ID Baker ZXP liner top paeker/hangerlseal assembly at 6082' MD 4-1/8" openhole o o 0 o o o o ~ ConocoPhillips Alaska, Inc. . -# 1ßFAYJe~ fe.rty1\ 1F-01AL 1 ~teral, TD @ 10,325' md 0000 ~oooooo 0000 ~ 2-7/8" slotted liner o 0 0 0 0 :1J o 0 0 0 0 ~ o o t- 2-7/8" Baker deployment sub @ 8275' md o I.. 4-1/8" openhole ~o:oo o 0 0 000 ~ 0 0 ~4-W' LSX WS o o o o o o o o o 0 o o o o o o o o o o o o o 0000 000 '~ :-718" slotted line, o vi 1".5 r-" rr1:-t /fv. 1 F-01A,TD @ 10,550' md .,;/ ooooooooooo~ o o o o o 0 02/11/05 Kuparuk DOBCTD BOP configuration 2-3/8" Coil v Floor ~ Swab Valve Tree Size SSV Master Valve Base Flange A 21241200e 2,000 SFD , o N t SHARON K. ALLSUP-DRAKE 1091 CONOCOPHILLlPS A TO 1530 /' ( 11Q.. zø:;;S- 700 G ST. DATE f'eJ),~ V 62-14/311 ANCHORAGE AK 99501 I ~~::' {k ~ ~ ¿'1~- I::: ~~.:: . ~.... CHASE Chose Manhattan aank USA. N.A. Valid Up To 5000 Dollars U _.,.,,,-,,, -"""" r1 ~.. _m~~JJ~ I: 0 3 ¡. ¡. 0 0 ¡. ~ ~ I: 2 ¡. B ~ 7 ¡. q 0 7 q 2 7 b II' ¡. 0 q ¡. . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME k/?tl / F- all.:-7 PTD# 2-05'-0 ~c¡ V· Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (1f API Dum ber last two. (2) digits are between 60-69) Exploration Stratigraphic "CLUE"· The permit is for a Dew weJlbore 'segmeDt of existiDg well'. . Permit No, .' API No. . Production. should cODtinue to be reponed as a function' of the origiDal API number. stated above. . HOLE In accordance with' 20 AAC 25.005(f), all records, data and logs acquired for the pilot bole must be clearly differentiated In both name (name on permit plus PH) aDd API Dumber (SO 70/80) from records, data aDd loes acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25..055~ Approval1o peñorate and produce is contingeDt UpoD issuance of ~ conservatioD order approving a spaciDg exceptioD. (CompaDY Name) assumes tbe liabillt)' of aD)' protest to tbe spaciDg .exceptioD tbat ma)' occur. AU dry ditcb sample sets submitted to tbe Commission must be in DO greater 1baD 30' sample in1ervals from below tbe permafrost or from wbere samples are fint caught aDd 10' sample biter:vals tbrougb target :zones. Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1F-01A ____~~_Program DEV Well bore seg PTD#: 2050290 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 1 P.ßrmit fee attached. . . . . . _ . . . . . . . . . . . . .. ...... Yes . . . . . . . . . . . . . . . . . .. ....................... 2 .Leas.ßnumberappropriate. .............. ..................... .. Y.ßs . . . . . . . _ . . . . . . . . . . . . . . 3 .U.n[que well.n.a!T1J'!.a!1d ou.mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.ßs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WellJQcat.ßd [nad.efjneøpool. . . . . . . . . . . . . . . . . . . . . . . . . . . Y.ßs. . Kup.aruk Rjver Oil F'Qol, gov.ernJ'!d by Con.seryatip!1 Order \o. .432C . . . . . . . . . . . . . . . . . . . . . . . . . 5 WelUQcated prpper .d[sta!1ce. from driJling unitb.ound.al"Y. . . . . . . . . . . . Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 WelUQcat.ßd properd[stance from otber welJs. . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . 7 .S.uffjcienLacreage.aYailable indrilliog unjL . . . . . . . . . . . . . . . Y.ßs . . . . . . . . . . . . . . . . . . . . 8 Jf.d.ßviated, js. weJlbQre plalincJuded . . . . . . . . . . . . . Y.ßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 .Operator only affected party. . . . . . . . . . . . . . . . .. ..................... Yes. . . . . . .. ................ . . . . . . . . . . . 10 .Oper.atof bas. appropriate. Qond inJorce . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . .Y.ßs. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 P.ßrmitC<inÞeissu.edwitbQutconserva.tionorder......................... Y.ßs .............. ...... Appr Date 12 P.ßrmitc.anÞei.ssu.edwitbQutactministratille.approvaJ. ........ Y.ßs .................. ........................ SFD 2/24/2005 13 Can permit be approved before 15-day wait Yes 14 WellJQcated w[thin area alld.strata authorized by lojectioo Ord.ß r# (putlO# in.c.ommeots) (For NA. ...... ....... 15 .AJlweIJs.wit]1i.n.1l4J'TJile.area.ofreyiewjd.ßoUfied(ForservjC.ß-""'ellonlyL.............. .NA. _ _................................................ _..... 16 Pre-produ.cect injector; øuratiQnof pre-proøuctioo l.ßsS than. 3 months (For service well QnJy) . . NA . . 17 .ACMP. Fillding .of Con.sistency. h.as bee.n issued. for.tbis project . . . . . . . . . . . . . .NA 18 .Cpodu.ctor strillg.provided . . . . . . Y.ßs. 19S.urfac.ß.casing.pJotects. all known USDWs . . . . . . . . . . NA 20CMT vol adeQuate.to circulateoncond.uctor & SUJf.csg . . . . . . . . NA 21 .CMT vol adeQuate.to tie-in JQngstring to surf csg. . . . . No. 22 .CMTwilJ coyer.aU koown.Pfo.ductiYe borizon.s. . . . . . . . . No 23 .C.asiog desig!1s actequate for C,T, B&permafrost . . . . . . . . . . . . . . Y.ßs. 124 .Aøequate.tan.kage.or re.seI'Ye pit. . . . . . . . . . . Y.ßs . . . Rigs are eQu.ipped with steel pits, No JesJ'!rve pit plann.ßd.. ,ð.ll waste.to Class] wells. . . . . . . 25 Jf.a.re-ørilt bas.a to:403 fQr abandOllment be.ß!1 apprQved . . . . . . YJ'!s . . .30.5:0.32. . . . . . . . . . . . . . . . . . . . . . . . . 26 .Aøequ.ateJl\1ellbore.separatío.n-Pfoposed..... _...... .................... Y.ßs...... .l?rp~im[tyan.alysiSPe.rtorme.d, O.nlyw.ßUb_ore.Qfjssue.isabandQnJ'!dportiQn.of1f-OL................. 27 Jf.diverter req.uire.d, dQes it meet reguJa.tioos. . . . . . . . .. .... .NA . BOI? wiJlalreaøy be in place.. . . . . . . . . . . . . . . . . . 28 .Drilliog fluid. program sc.hematic.& eq.uip Jistaøequat.ß. . . . . .. ...... YJ'!s . . .. . Max. expected BtlF',.1 L2.(r.otary) and. 12.7 (coil). . F'lan.ned MW t 1.7. ppg .aod 13.2 pP-Qwith øynamic. Qverbalallc~k 29 BOPEs,dpthey meet reguJation . . . . . . . . . . . . . . . . . . . Y.ßs . . . . . M.t\SI? rotaI)' 28.14 psi, M,ð.SF' coiI33t4psi.350Q psj appropriate for rotary" 400.0 psi appropriate forC9iJ. 30 .BOPE.pre.ss rati!1g appropriate; test to (put psig in.comments). . . . . . . . . . . . Y.ßs. . . . . CI?,ð.lplans toJest to.5.00Q psj rotaI)' anø.45QO.psi coil.. . 31 Choke manifold compJies. w/APIRF'-53 (May 64). Yes. . . . . . . Botb maoi{olds comply. . . . . . . . . . . . . . . . . . . . . . . . 32 WQrk will occ.ur withoutoperatjon .sbutdown. . . . . . . . . . . . . . . . No Ope.ratiO!1S will be SO in. order toswith rigs, Li.ner. will be C.ßmJ'!oted, te.steø .a!1d OQt perforated, . . . . . . . . . . . . 33 .Is presence. Qf H2S gas. proQable. . . . . . . . .. . . . . . . Yes. . . tl2S has been. repQrted .on 1 = pa.d, Mud sho.uld.preclude tl2S .on rjgs_ Both rigs. have sensors aod. alarms.. . . 34 Mechan[caicoodjUonO{Wellswithin,ð.ORyerified (for service we I] onJ y) . . . . . . . . . . . . . NA . . . . . . . . . .. . . . . . . . . . . .. .................... Administration _._-----~-~- Engineering Appr Date TE;( _ 2/.28/2005 ~þ~ Geology Appr SFD Date 2/23/2005 ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . CondUGtorstring set jn. Qrigina'-w.ell1 f-Ot (162-2t9). . . . . ,ð.ll aquifers exempted,AOCFR 1<47.'1 Q2(b)(3).. . . . . . . Surface ca.sing selin Qrigina1well.. . . . . . . . I?rodu.ction. C<iSi!1g se.t [norigioal welJ. . _ . . Slotted Jioer .completio!1 plaoned. - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - 35 P.ßunit C<iO be issu.ed wfQ hydrogen. s.ulfide meas!Jœs . . . . . . No . 1 =-I?adis a designated H2S Pad.. . . . . . . . . . . . . . . . . 36 .D.ata preseoted on Rote.ntialpverRresSurezones. ......... ............. YJ'!s..... .Kup"A'~r.eservojrsaodisexpectedto.be.12.7ppgEMW;willbedrilied with.u.nder.pre.ssu.re with.CQiled Tubing 37 .S.ßismic.analysjs. Qf shaJlow gaszpoes. . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 38 .S.ßabed .conditioo survey.(if off-sh.ore) . . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . 39 . CQntact namelp]1OlleforJl\1eekly progress.reports [exploratoryo!1ly] . . . . . . . . . . . .. . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Geologic Engineering Commissioner: Date: \ Commissioner: OrIginal Signed By 3 \ (t] DAN SEAMOUNT· ~ne' ß~ J Date D D . . . . 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 fìnding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Dec 15 13:44:28 2006 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments........ ........ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number... ...01 Previous Tape Name..... ..UNKNOWN Comments......... ....... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1F-01A PB1 500292088970 ConocoPhillips Alaska, Inc. Sperry Drilling Services 15-DEC-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0003657484 P. SMITH N. SCALES MWD RUN 2 W-0003657484 P. SMITH F. HERBERT MWD RUN 3 W-0003657484 P. SMITH G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 10E 1161 388 119.80 79.40 <9DS--o~9 tt;./~3~1f . . # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 6253.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE 1F-01 WELLBORE AT 6253'MD / 4331'TVD, BY MEANS OF A WHIPSTOCK. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIP- STOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3 REPRESENT WELL IF-01A PB1 WITH API#:50-029-20889-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8336'MD/6070'TVD. 8. THIS DATASET WAS REVISED DUE TO A WELL NAME CHANGE. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name... ......... .STSLIB.001 Service Sub Level Name. . . Version Number....... ....1.0.0 . . Date of Generation...... .06/12/15 Maximum Physical Record..65535 File Type............ ....LO Previous File Name... ....STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPX RPS RPM FET ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6206.0 6244.5 6244.5 6244.5 6244.5 6250.5 6254.5 STOP DEPTH 8290.5 8295.0 8295.0 8295.0 8295.0 8295.0 8336.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 6206.0 6285.0 7064.0 MERGE BASE 6285.0 7064.0 8336.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type. ....0 Logging Direction.... ..... ... .....Down Optical log depth units.... ..... ..Feet Data Reference Point... .......... .Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6206 8336 7271 4261 6206 8336 RPD MWD OHMM 0.56 2000 9.4492 4102 6244.5 8295 RPM MWD OHMM 0.58 2000 8.47406 4102 6244.5 8295 RPS MWD OHMM 0.34 945.72 3.49777 4102 6244.5 8295 RPX MWD OHMM 0.21 1460.12 3.76517 4102 6244.5 8295 FET MWD HOUR 0.46 184.92 6.86754 4090 6250.5 8295 GR MWD API 47 517.6 135.296 4170 6206 8290.5 ROP MWD FT/H 0.1 2460.66 48.2348 4164 6254.5 8336 First Reading For Entire File........ ..6206 Last Reading For Entire File....... ... .8336 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..06/12/15 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name......... ....STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .06/12/15 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR 2 header data for each bit run in separate files. 1 .5000 START DEPTH 6206.0 STOP DEPTH 6237.0 . ROP $ 6254.5 6285.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB!G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................. ...60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 28-APR-05 Insite 66.37 Memory 6285.0 6253.0 6285.0 .0 .0 TOOL NUMBER 87224 6.125 6253.0 Water Based .00 .0 .0 o .0 .000 .0 .000 .0 .000 .0 .000 .0 . . Service Order Units FT API FT/H Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT GR ROP MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6206 6285 6245.5 159 6206 6285 GR MWD010 API 62.98 79.81 70.993 63 6206 6237 ROP MWD010 FT/H 2.87 171.45 25.5023 62 6254.5 6285 First Reading For Entire File. .... .... .6206 Last Reading For Entire File....... ... .6285 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/12/15 Maximum Physical Record..65535 File Type........... .....LO Next File Name.. ........ .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..06/12/15 Maximum Physical Record..65535 File Type............ ....LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6237.5 6244.5 6244.5 6244.5 6244.5 STOP DEPTH 7016.0 7023.0 7023.0 7023.0 7023.0 . FET ROP $ 7023.0 7064.0 6250.5 6285.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ........ ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point. ........... ..Undefined Frame Spacing........... ......... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value..................... .-999 . 01-MAY-05 Insite 66.37 Memory 7064.0 6285.0 7064.0 23.7 46.1 TOOL NUMBER 87224 130908 6.125 6253.0 Water 10.60 70.0 9.0 8000 6.0 Based .820 .560 .650 1. 200 72.0 101. 2 72.0 72.0 . . Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6237.5 7064 6650.75 1654 6237.5 7064 RPD MWD020 OHMM 1. 26 2000 19.2983 1558 6244.5 7023 RPM MWD020 OHMM 1. 25 2000 16.768 1558 6244.5 7023 RPS MWD020 OHMM 0.34 945.72 3.6299 1558 6244.5 7023 RPX MWD020 OHMM 0.21 1460.12 4.26254 1558 6244.5 7023 FET MWD020 HOUR 0.46 184.92 10.3334 1546 6250.5 7023 GR MWD020 API 47 181. 47 98.9495 1558 6237.5 7016 ROP MWD020 FT/H 0.1 223.38 55.917 1558 6285.5 7064 First Reading For Entire File......... .6237.5 Last Reading For Entire File.......... .7064 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..06/12/15 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation...... .06/12/15 Maximum Physical Record. .65535 File Type............... .LO . Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPD RPM FET RPS ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 7016.5 7023.5 7023.5 7023.5 7023.5 7023.5 7064.5 STOP DEPTH 8290.5 8295.0 8295.0 8295.0 8295.0 8295.0 8336.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 07-MAY-05 Insite 66.37 Memory 8336.0 7064.0 8336.0 15.9 54.8 TOOL NUMBER 87224 130908 6.125 6253.0 Water 10.20 51. 0 9.5 2800 4.0 Based .610 .320 .540 .910 60.0 121. 2 60.0 60.0 . . HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................. ...60 .1IN Max frames per record......... ....Undefined Absent value............... ... ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7016.5 8336 7676.25 2640 7016.5 8336 RPD MWD030 OHMM 0.56 43.48 3.41741 2544 7023.5 8295 RPM MWD030 OHMM 0.58 41. 99 3.39469 2544 7023.5 8295 RPS MWD030 OHMM 0.62 46.38 3.41686 2544 7023.5 8295 RPX MWD030 OHMM 0.61 49.17 3.46058 2544 7023.5 8295 FET MWD030 HOUR 0.55 71. 42 4.76131 2544 7023.5 8295 GR MWD030 API 47.58 517.6 159.101 2549 7016.5 8290.5 ROP MWD030 FT/H 0.31 2460.66 44.0841 2544 7064.5 8336 First Reading For Entire File...... ....7016.5 Last Reading For Entire File.......... .8336 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... . . Version Number......... ..1.0.0 Date of Generation.... ...06/12/15 Maximum Physical Record..65535 File Type.......... .... ..LO Next File Name......... ..STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... .... ..UNKNOWN Continuation Number.... ..01 Next Tape Name.. ........ .UNKNOWN Comments....... ......... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/12/15 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~ . **** REEL HEADER LDWG 06/12/15 **** AWS 01 **** TAPE HEADER **** LDWG 15/12/06 01 *** LIS COMMENT RECORD *** RECE\VED DEC 28 2006 AlaSka 011 & Gas eons· commlsSiOO Anct\()1'8ge . \/¡SED C()Py !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 1F-01A 500292088901 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 15-DEC-06 MWD RUN 6 6 E. AGUI RRE D. HILDRETH MWD RUN 9 9 D. BARBA G. GOODRICH MWD RUN 7 7 D. BARBA G. GOODRICH MWD RUN 8 8 E. AGUIRRE D. HILDRETH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING :dOO - 0;11 tt f4~c}'ì 19 11N 10E 119.80 00.00 00.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 10.750 7.000 DRILLERS DEPTH (FT) 2630.0 6232.0 . . 3RD STRING PRODUCTION STRING 4.500 8336.0 10533.0 4.25 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 49.903" LONG: W149 DEG 40' 45.817" LOG MEASURED FROM K.B. AT 119.8 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are real time data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, and vibration stick-slip), a Gamma and Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC (7) through a milled window for well 1F-01A. The 1F-01A wellbore was drilled from 1F-01PB1 in 4.5" liner. Top of window 8251.1 ft. MD (5902.3 ft. SSTVD) Bottom of window 8259.4 ft. MD (5906.0 ft. SSTVD) (8) The interval from 10491 ft. to 10533 ft. MD (6053 ft. to 6054 ft. SSTVD) was not logged due to bit to sensor offset. (9) The 1F-01A wellbore was tied to 1F-01 at 8022 ft. MD (5754.9 ft. SSTVD). (10) The interval from 8243 ft. to 8600 ft. MD (5896 ft. to 6021 ft. SSTVD) was recorded in a MAD PASS. $ Tape Subfile: 1 85 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 . . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8259.0 STOP DEPTH 10533.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 6 7 8 9 MERGE TOP 8259.0 8571. 0 9125.0 10146.0 MERGE BASE 8571. 0 9125.0 10146.0 10533.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1F-01A 5.xtf 150 ConocoPhillips Alaska, Inc. 1F-01A Kuparuk River North Slope Borough Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 ROP ROP ROPA 0.0 . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 127 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8259.000000 10532.500000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 170 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! LDWG File Version 1.000 Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: 2 log header data for each bit run in separate files. 6 .2500 . # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 8259.0 $ STOP DEPTH 8571. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 26-MAY-05 ADVANTAGE 3 CTK MEMORY 8600.0 8259.0 8571.0 o 55.0 80.0 TOOL NUMBER 10023579 1068825 10079128 4.25 8259.0 FIo-Pro 9.90 .0 .0 160000 .0 .000 .000 .000 .000 111.0 .0 .0 .0 .00 .000 .0 o BIT RUN 6 (MWD Run 6). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS . . MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT IF-OIA.xtf 150 ConocoPhillips Alaska, I IF-OIA Kuparuk River North Slope Bora Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 35 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8259.000000 8571.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 117 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes . **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 7 .2500 START DEPTH 8571.0 STOP DEPTH 9125.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL 28-MAY-05 ADVANTAGE 3 CTK MEMORY 9156.0 8571.0 9125.0 o 89.1 94.6 TOOL NUMBER 10023579 1068825 10079128 4.25 8259.0 Flo-Pro 10.0 .0 .0 185000 .0 .000 .000 .000 .000 119.0 .0 .0 .0 . . MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 7 (MWD Run 7) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT IF-OlA.xtf 150 ConocoPhillips Alaska, I IF-OlA Kuparuk River North Slope Bora Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 . 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 62 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8571.000000 9125.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 144 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 8 .2500 START DEPTH 9125.0 STOP DEPTH 10146.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MPR MULT. PROP. RESIST. 30-MAY-05 ADVANTAGE 3 CTK MEMORY 10178.0 9125.0 10146.0 o 84.6 94.0 TOOL NUMBER 10023579 . GRAM DIR $ GAMMA RAY DIRECTIONAL # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 1068825 10079128 4.25 8259.0 Flo-Pro 10.0 .0 .0 178000 .0 .000 .000 .000 .000 117.0 .0 .0 .0 .00 .000 .0 o BIT RUN 8 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1F-01A.xtf 150 ConocoPhillips Alaska, I IF-01A Kuparuk River North Slope Boro Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) . . Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 114 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9125.000000 10146.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 196 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE014.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # 5 log header data for each bit run in separate files. 9 .2500 . FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 10146.0 $ STOP DEPTH 10533.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ BOTTOM) TOOL TYPE MULT. PROP. GAMMA RAY DIRECTIONAL RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . 31-MAY-05 ADVANTAGE 3 CTK MEMORY 10533.0 10146.0 10533.0 o 84.4 88.9 TOOL NUMBER 10023579 1068825 10079128 4.25 8259.0 F1o-Pro 10.0 .0 .0 178000 .0 .000 .000 .000 .000 127.0 .0 .0 .0 .00 .000 .0 o BIT RUN 9 (MWD Run 9). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU . . -------------------------------- WDFN LCC CN WN FN COUN STAT 1F-01A.xtf 150 ConocoPhi11ips Alaska, I 1F-01A Kuparuk River North Slope Boro Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 ------- 24 Total Data Records: 43 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10146.000000 10532.250000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 125 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes ~ . **** TAPE TRAILER **** LDWG 15/12/06 01 **** REEL TRAILER **** LDWG 06/12/15 AWS 01 Tape Subfile: 7 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes . . ~ ,.- t\?v ~ o )' \J Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 26 07:41:33 2005 \) )J > /" / Reel Header Service name.. ...........LISTPE Date.................... .05/07/26 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number......01 Previous Reel Name...... . UNKNOWN Comments... ..............STS LIS Writing Library. Scientific Technical Services Tape Header Service name...... ...... .LISTPE Date.................... .05/07/26 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . ...... . . ... .UNKNOWN Continuation Number. . . . . .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1F-01A 500292088901 ConocoPhillips Alaska, Inc. Sperry Drilling Services 26-JUL-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003657484 P. SMITH N. SCALES MWD RUN 2 MW0003657484 P. SMITH F. HERBERT MWDRUN 3 MW0003657484 P. SMITH G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 10E 1161 388 119.80 79.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 6253.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE 1F-01 WELLBORE AT 6253'MD / . . 4331'TVD, BY MEANS OF A WHIPSTOCK. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIP- STOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 2 & 3 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL 1F-01A WITH API#:50-029-20889-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8336'MD / 6070'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name. ...... ......STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/07/26 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6154.0 6244.5 6244.5 6244.5 6244.5 6250.5 6254.5 STOP DEPTH 8290.5 8295.0 8295.0 8295.0 8295.0 8295.0 8338.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 6154.0 6285.0 7064.0 MERGE BASE 6285.0 7064.0 8338.0 . . # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. ......... .......0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point.... ......... .Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6154 8338 7246 4369 6154 8338 ROP MWD FT/H 0.1 2460.66 48.3011 4168 6254.5 8338 GR MWD API 47 517.6 134.593 4213 6154 8290.5 RPX MWD OHMM 0.21 1460.12 3.76517 4102 6244.5 8295 RPS MWD OHMM 0.34 945.72 3.49777 4102 6244.5 8295 RPM MWD OHMM 0.58 2000 8.47406 4102 6244.5 8295 RPD MWD OHMM 0.56 2000 9.4492 4102 6244.5 8295 FET MWD HOUR 0.46 184.92 6.86754 4090 6250.5 8295 First Reading For Entire File......... .6154 Last Reading For Entire File.......... .8338 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/07/26 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/07/26 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 header data for each bit run in separate files. 1 .5000 START DEPTH STOP DEPTH . GR ROP $ 6154.0 6254.5 6237.0 6285.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point....... ...... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Rep 68 68 68 Code Units FT FT/H API Size 4 4 4 Nsam 1 1 1 MWD010 MWD010 . 28-APR-05 Insite 66.37 Memory 6285.0 6253.0 6285.0 .0 .0 TOOL NUMBER 87224 6.125 6253.0 Water Based .00 .0 .0 o .0 .000 .0 .000 .0 .000 .0 .000 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6154 6285 6219.5 263 6154 6285 ROP MWD010 FT/H 2.87 171.45 25.5023 62 6254.5 6285 GR MWD010 API 59.2 79.81 69.1299 106 6154 6237 . . First Reading For Entire File..........6154 Last Reading For Entire File.......... .6285 File Trailer Service name............ .STSLIB.002 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/07/26 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . . LO Next File Name...........STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/07/26 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPX RPS FET ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6237.5 6244.5 6244.5 6244.5 6244.5 6250.5 6285.5 STOP DEPTH 7016.0 7023.0 7023.0 7023.0 7023.0 7023.0 7064.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 01-MAY-05 Insite 66.37 Memory 7064.0 6285.0 7064.0 23.7 46.1 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 87224 130908 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 6253.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): Water Based 10.60 70.0 9.0 8000 . . FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 6.0 .820 .600 .650 1. 200 72.0 101.2 72 .0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ ......0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Cha=el DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6237.5 7064 6650.75 1654 6237.5 7064 ROP MWD020 FT/H 0.1 223.38 55.917 1558 6285.5 7064 GR MWD020 API 47 181.47 98.9495 1558 6237.5 7016 RPX MWD020 OHMM 0.21 1460.12 4.26254 1558 6244.5 7023 RPS MWD020 OHMM 0.34 945.72 3.6299 1558 6244.5 7023 RPM MWD020 OHMM 1.25 2000 16.768 1558 6244.5 7023 RPD MWD020 OHMM 1.26 2000 19.2983 1558 6244.5 7023 FET MWD020 HOUR 0.46 184.92 10.3334 1546 6250.5 7023 First Reading For Entire File......... .6237.5 Last Reading For Entire File.......... .7064 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......05/07/26 Maximum Physical Record..65535 File Type................LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name.. ....... ....STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....05/07/26 . Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 7016.5 7023.5 7023.5 7023.5 7023.5 7023.5 7064.5 STOP DEPTH 8290.5 8295.0 8295.0 8295.0 8295.0 8295.0 8338.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA Electromag RAY Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ........0 Data Specification Block Type. ....0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet 07-MAY-05 Insite 66.37 Memory 8336.0 7064.0 8336.0 15.9 54.8 TOOL NUMBER 87224 130908 6.125 6253.0 Water 10.20 51. 0 9.5 2800 4.0 Based .610 .320 .540 .910 60.0 121. 2 60.0 60.0 . . Data Reference Point............. . Undefined Frame Spacing.... ......... ...... ..60 .1IN Max frames per record............ . Undefined Absent value......................-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7016.5 8338 7677.25 2644 7016.5 8338 ROP MWD030 FT/H 0.31 2460.66 44.199 2548 7064.5 8338 GR MWD030 API 47.58 517.6 159.101 2549 7016.5 8290.5 RPX MWD030 OHMM 0.61 49.17 3.46058 2544 7023.5 8295 RPS MWD030 OHMM 0.62 46.38 3.41686 2544 7023.5 8295 RPM MWD030 OHMM 0.58 41.99 3.39469 2544 7023.5 8295 RPD MWD030 OHMM 0.56 43.48 3.41741 2544 7023.5 8295 FET MWD030 HOUR 0.55 71.42 4.76131 2544 7023.5 8295 First Reading For Entire File......... .7016.5 Last Reading For Entire File.. ....... ..8338 File Trailer Service name... ...... ....STSLIB.004 Service Sub Level Name. . . Version Number.... .......1.0.0 Date of Generation.......05/07/26 Maximum Physical Record..65535 File Type..... .......... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date.................... .05/07/26 Origin.. .................STS Tape Name.. . . ........... . UNKNOWN Continuation Number. . ... .01 Next Tape Name.......... . UNKNOWN Comments.......... ...... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.. ....... ........... .05/07/26 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number......01 Next Reel Name.......... . UNKNOWN Comments.... .............STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . .