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205-142
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Q-02B KUPARUK RIV UNIT 1Q-02B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 1Q-02B 50-029-21248-02-00 205-142-0 G SPT 5103 2051420 1500 3400 3400 3400 3400 0 0 0 0 4YRTST P Bob Noble 8/10/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Q-02B Inspection Date: Tubing OA Packer Depth 810 2000 1920 1915IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250811103612 BBL Pumped:0.9 BBL Returned:0.9 Monday, September 22, 2025 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3 Subject:10-426 forms for 1D-101 Witnessed & 1Q-pad non-witnessed MIT-IA"s 7/15/25 Date:Wednesday, July 16, 2025 8:07:58 AM Attachments:image001.png MIT KRU 1D-101 7-15-25.xlsx MIT KRU 1Q-PAD SI TESTS 07-15-25.xlsx Morning, Please see the attached 10-426 forms from the AOGCC witnessed MIT-IA on 1D-101 and the non-witnessed MIT-IA’s on 1Q-pad that were performed on 7-15-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .584% 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2051420 Type Inj N Tubing 1190 1200 1220 1250 Type Test P Packer TVD 5100 BBL Pump 1.1 IA 265 2000 1890 1880 Interval 4 Test psi1500BBL Return1.1OA0000 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1951210 Type Inj N Tubing 1680 1680 1680 1680 Type Test P Packer TVD 5894 BBL Pump 1.0 IA 1030 3300 3200 3180 Interval V Test psi 3000 BBL Return 1.0 OA 20 210 210 210 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1Q Pad Non-witnessed Beck/Cook 07/15/25 Notes: Notes: 1Q-02B 1Q-24 Notes:MITIA every 2 years at maximum anticipated injection pressure per AIO 2C.017 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2025-0715_MIT_KRU_1Q-02B 9 9 9 9 999 9 9 99 9 9 -5HJJ 1Q-02B MEMORANDUM TO: Jim Regg P.I. Supervisor��/l; FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 15, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 Q -02B KUPARUK RIV UNIT 1Q -02B Src: Inspector Reviewed By: P.I. Supry J Comm Well Name KUPARUK RIV UNIT IQ -0213. API Well Number 50-029-21248-02-00 Inspector Name: Brian Bixby Permit Number: 205-142-0 Inspection Date: 7/12/2021 Insp Num: mitBDB210713094626 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IQ -02B Type Inj w- TVD 5072 Tubing 2175 2175 2175 - 2175 PTD 2051420 Type Test SPT Test psi 1500 - IA 830 2990 - zsso BBL Pumped: 1.6 ` IBBL Returned: 1.6 OA so rIo _ I Io 110 Interval 4YRTSTJ— p P V-- -- - Notes: Thursday, July 15, 2021 Page I of I 7" r s J° g r N _. 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N NLLI CO CO y, Z N Q O N r, U np tp -, a E E F- 7.6 Ol L ,- O O O y a H a s • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Tuesday,July 18,2017 P.I.Supervisor e1/4T1/t 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Q-02B FROM: Jeff Jones KUPARUK RIV UNIT 1Q-02B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry L)5-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Q-02B API Well Number 50-029-21248-02-00 Inspector Name: Jeff Jones Permit Number: 205-142-0 Inspection Date: 7/8/2017 Insp Num: mitJJ170718114242 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Q-02B Type Inj G `TVD 5072 - Tubing 3530 - 3530 - 3510 . 3510 PTD 2051420 " Type Test SPT Test psi 1500 . IA 400 - 2480 - 2380 ' 2370 - BBL Pumped: 1.5 BBL Returned: 1.6 OA 186 - 204 204 - 205 - Interval 4YRTST P/F P ,/ Notes: 1 well inspected,no exceptions noted. SCANNED SEP 2 5 2017 Tuesday,July 18,2017 Page 1 of 1 • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 06, 2011 3:38 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly failed MIT report for November 2011 Attachments: CPAI Failed MITIA Monthly Data 11- 11.zip Tom, Jim, Guy Attached is the monthly failed MIT report for November 2011. 1Q -02B delete(after patch was set across CMU, witnessed MITIA performed and 10 -404 were submitted in October). 2T -28 and 3K -30 were added 1 Q -11 was inadvertently deleted from October's report after it had its AA cancelled. It has been added back into November's report and will remain on future reports. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 12/7/2011 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i� DATE: Thursday, October 27, 2011 P.I. Superv ~��� r' I � '{ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1Q-021:3 FROM: Bob Noble KUPARUK RIV UNIT 1Q -02B Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, r q.-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IQ -02B API Well Number: 50- 029 - 21248 -02 -00 Inspector Name: Bob Noble Insp Num: mitRCN111025184907 Permit Number: 205 - 142 - Inspection Date: 10/25/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' 1Q -02B 'IType mi. W ' TVD 5060 - IA I 1550 3300 ' 3180 , 3120• 3110 . P.T.Di 2051420'I IypeTest2 Test psi 1500 LOA 400 . 620 - 600 600 — 600 ' Interval REQVAR - P/F P . Tubing 2500 2500 2500 2500 2500 Notes: Thursday, October 27, 2011 Page 1 of 1 • TATE OF ALASKA ALASKA OIL AN +4S CONSERVATION COMMISSION itECEIVED REPORT OF SUNDRY WELL OPERATIONS OCT 2 g 2011 1. Operations Performed: Abandon r Repair w ell I✓ Rug Rerforations r Stimulate r Other r Alter Casing r Rill Tubing r Perforate New Pool r Waiver kiskiiiiiPireteCcris, Commission Change Approved Program r- Operat. Shutdow n r Perforate r Re-enter Suspended 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 205 -142 3. Address: 6. API Number: Stratigraphic r Service I✓ P. O. Box 100360, Anchorage, Alaska 99510 — 50- 029 - 21248 -02 - Oa 7. Property Designation (Lease Number): 8. Well Name and Number: ALD 025634 ' 0 o (p 9' 1 I D ag 1Q-02B 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 11500 feet Plugs (measured) None true vertical 6750 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6009, 6062 true vertical 0 feet (true vertucal) 5023, 5060 Casing Length Size MD TVD Burst Collapse CONDUCTOR 64 16 100 100 0 0 SURFACE 3794 12 3830 3529 0 0 PRODUCTION 8086 7 8119 6259 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9623' - 11499' Slotted liner True Vertical Depth: 6698' - 6750' I.; Li ' `r' 4. u k „ Tubing (size, grade, MD, and TVD) 4.5, L -80, 6079 MD, 5060 TVD Weatherford ER retrievable patch from 5991' MD - 6024' MD Packers & SSSV (type, MD, and TVD) SLEEVE -C - BAKER CMU SLIDING SLEEVE - CLOSED 6/24/2011 @ 6009 MD and 5023 TVD SEAL ASSY - BAKER SEAL ASSEMBLY @ 6062 MD and 5060 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after work: c Copies of Logs and Surveys run Exploratory r Development r Service r - Stratigraphic r X 15. Well Status after work: Oil r Gas r \NDSPL r y Daily Report of Well Operations GSTOR r WINJ r WAG p' GINJ r SUSP r SPLUG r 16. 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: 311 -272 Contact Brent Rogers /Kelly Lyons Printed Name &/ye BBrentRogers Title Problem Well Supervisor Signature Ph one: 659 -7224 Date 10/26/11 R BOMS OCT 2 8 /o •31.1( Form 10-404 Revised 10/2010 Submit Original Only • • 1Q-02B • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/19/11 BRUSH'n FLUSH TBG f/ 5900' TO 6100' MD WITH 3.79" GAUGE & BLB. UNABLE TO DRIFT TREE WITH 3.80" x 12' SOLID DUMMY DRIFT. DRIFTED TBG TO CMU © 6008' RKB WITH 3.735" CENT, 2.125" SPACERS & 3.82" CENT (OAL =12'); NO PROBLEMS ENCOUNTERED. READY FOR E/L SET PKR. 10/05/11 PERFORMED SETTING OF ER PACKER USING HALLIBURTON 3.59" O.D. MEMORY DPU. CORRELATE TO HALLIBURTON MIT LOG DATED JULY 6, 2011. STOPPED AT CCL DEPTH OF 6010.6'. CCL TO MID - ELEMENT OFFSET = 13.4'. SET MID ELEMENT @ DEPTH OF 6024'. 10/12/11 SET 31' 4" PATCH ASS'Y (ER PKR, SPACER & SNAP LATCH ASS'Y) @ 5991' RKB. SET TEST TOOL IN UPPER PKR. MIT TBG 3000 PSI, PASSED. PULLED TEST TOOL. MIT IA 3000 PSI, PASSED. MITT TO 3000 PSI, INITIAL T /I /0= 250/250/0, TEST T /I /0= 3025/275/0, 15 MIN T /I /0= 2975/275/0, 30 MIN T /I /0= 2925/275/0, 45 MIN T /I /0= 2920/275/0. MITIA INITIAL T /I /0= 250/275/0, TEST T /I /0= 260/3000/0, 15 MIN T /I /0= 260/2700/0, FAILED, RETEST, TEST T /I /0= 260/3010/0, 15 MIN T /I /0= 260/2975, 30 MIN T /I /0= 260/2970/0 COMPLETE. 10/20/11 Pre SW MITIA (Passed), Initial T /I /O= 2550/2200/500. IA FL @ NS. Pressured up IA to 3250 psi with 1 bbl of diesel. Start MITIA T /I /O= 2550/3250/620, 15 min T /I /0= 2550/3150/620, 30 min T /I /O= 2550/3125/620. Bleed IA down, Final T /I /O= 2550/1000/400. ( j.0125/11 STATE WITNESSED ( BOB NO LE) MIT -IA ( PASSED ), IA FL @ SF, T /I /O= 2500/1550/400. Pressure with 1.1 bbls diesel, T /I /O= 2500/3300/620. 15 min T /1 /0= 2500/318oib min T /I /O= 2500/3120/600, 45 min T /I /O= 2500/3110/600. Bled IA, and final T /I /O= 2500/1200/360. Summary Set 33' Weatherford ER retrievable patch from 5991' to 6024'. State witnessed MITIA passed following the patch set. UP 1Q-02B •• s ConocoPhdllp5 Well Attribl Max Angle D TD AI;1tiK;f. 11n Wellbore API /UWI Field Name Well Status Inc! ( °) MD (166B) Act Btm (MB) CornmPtallIpa 500292124802 KUPARUK RIVER UNIT INJ 95.09 9,976.94 11,501.0 Comment H2S (ppm) Date Annotation End Date KB-63rd (N) Rig Release Date Well cone9. - 10 oze.lon 3r2011 1033.12 AM SSSV: NIPPLE 5 6/18/2006 Last WO: 30.10 4/11/1985 Schematic - Actual Annotation Depth (EKG) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: SET PACKER ASSEMBLY ninam 10/13/2011 Casing Strings Casing Description String 0... String ID ... Top (51(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 21 CONDUCTOR 16 15.062 36.0 100.0 100.0 62.58 H-40 WELDED I mop Casing Description String 0.,. String 10 ... Top (fBKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 35.3 3,829.5 3,528.9 36.00 J BTC Cuing Description String 0... String ID ... Top (8168) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • PRODUCTION 7 6.276 33.1 8,118.7 6,258.8 26.00 J BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 1OA 4 1/2 3.958 6,112.9 9,010.0 6,650.6 12.60 L-80 NSCT Liner Details CONDUCTOR, Top Depth 38-100 )TVD) Top Inc! Noml... Top (WEB) IRKB) 11 item Description Comment ID (In) III 6,112.9 5,108.0 45.66 SLEEVE BAKER LINER PACKER SETTING SLEEVE 5.500 NIPPLE, 503 nr 6,119.0 5,112.3 45.64 PACKER BAKER HYFLO III LINER TOP PACKER 5.063 • 6,121.4 5,113.9 45.64 SBE BAKER 80-47 SEAL BORE EXTENSION 4.750 • 6,135.9 5,124.0 45.59 HANGER BAKER CMC MECHANICAL LINER HANGER 4.125 6,145.1 5,130.5 45.56 XO Redudng CROSSOVER 5 x 4.5, ID 3.958, #12.60, L-80, NSCT 4.500 7,974.6 6,165.5 50.66 NIPPLE OTIS X LANDING NIPPLE 3.812 SURFACE, 8,451.8 6,469.1 47.31 MARKER JT 3.958 ` Cuing Description String 0... String ID ... Top (WEB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd ° t ■ ` WINDOW 4 3.958 8,539.0 8,540.0 6,528.9 6.16 L PACKER. 5.991 �� Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (WD) ... String Wt... String ... String Top Thrd UPPER L1 TOP 3 3/16 2.810 8,496.0 8,705.0 6,618.9 6.16 L TCII I Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I PATCH 5,994 LOWER L1 TOP 2 7/8 2.441 8,705.0 9,609.0 6,696.2 6.16 L STL SLEEVE - C, Casing Description String 0... String ID ... Top (f9KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 6,009 SLOTTED LINER 2 7/8 2.441 9,609.2 11,501.0 6.16 L -80 STL Liner Details PACKER, E024 Top Depth cal (TVD) Top Inc! Noml... Top (FMB) (RKB) 11 Item Description Comment ID (In) 9,609.2 6,696.2 82.83 BILLET WEATHERFORD LINER BILLETw /GS PROFILE 8 3.5' PUP 2.441 Z Tubing Strings LOCATOR, Tubing Description String 0... !String ID ... Top (B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 6,061 TUBING I 4 1/2 I Str ftM 3.795 I 21.5 6,078.7 5,084.0 I 12.75 L - 80 I ABM - EUE AL ASSY, Completion Details glei Top Depth (TVD) Top Intl 800,, . Top (WEB) IRKB) ( °) Rem Description Comment ID (In) 21.5 21.5 -2.54 HANGER FMC GEN IV TUBING HANGER 4.500 1 500.2 500.2 0.60 NIPPLE CAMCO DB LANDING NIPPLE 3.875 6,008.8 5,035.4 46.04 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 6/24/2011 3.812 • 6,061.4 5,071.9 45.81 LOCATOR BAKER LOCATOR 3.880 • 6,061.8 5,072.2 45.81 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top )BKB) (RKB) ( °) Description Comment Run Date ID (in) 5,991 5,023.0 46.12 PACKER WEATHERFORD PB PACKER 10/12/2011 2.375 5,994 5,025.1 46.10 PATCH SPACER PIPE 8 SNAP LATCH ASSEMBLY 10/12/2011 2.250 6,024 5,045.9 45.98 PACKER WEATHERFORD ER PACKER 10/5/2011 2.375 1 Perforations & Slots Shot Top (TVD) 91m (TVD) Dens Top (MKS) Bbn )RKB) (8169) (RKB) Zone Date WA- Type Comment 9,623 11,499 6,697.9 A -3, A4, A -5, 11/18/2005 99.0 SLOTS STL SLOTTED LINER • • 10-028 PRODUCTION, 33 -8,119 8,203 -8,205 Notes: General & Safety Squeeze Pods, End Date Annotation e RPERF, _ 11/27/2005 NOTE: MULTI - LATERAL WELL w /SIDETRACK 10 LATERAL LEG 1O 8,381 - 8.384 RPERF, 6/4/2011 NOTE: CONFIRMED ISO LEAK @ 6009' RKB 8,38&8,384 RPERF, 8,389-8,384 _ 8,440.8,442 _ Shot Sq. Perk. .. 6,440 WINDOW, B 539.8,540 UPPER L1 TOP. 8,496-8,705 1 1 LINER 10A 8,113 -9,010 LOWER L7 TOP, 8,705 -9,609 SLOTS, 9.823-11499 SLOTTED LINER, 9,63311,501 TO (10-028), 11,501 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoa(alaska.aov; doa. aoacc.prudhoe.bavCcaalaska.uov; phoebe.brookst alaska.aov; tom.maunder(6alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 1Q DATE: 10/25/11 OPERATOR REP: Mouser /Bybee /Jensen AOGCC REP: Robert Noble Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Q -02B Type Inj. W TVD 5,072' Tubing 2,500 2,500 2,500 2,500 2500 Interval V P.T.D. 2051420 Type test P Test psi 1500 Casing 1,550 3,300 3,180 3,120 3,110 P/F P Notes: MITIA per Sundry #311 -272 post tubing patch OA 400 620 600 600_ 600 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT KRU 1Q - 02B 10 25 11.xls • • Tr LASSEh SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brent Rogers Problem Well Supervisor v /� c-- ConocoPhillips Alaska, Inc. 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Q -02B Sundry Number: 311 -272 Dear Mr. Rogers: ' S E P 2 011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • %'• L Daniel T. Seamount, Jr. Chair P1 DATED this 2 day of September, 2011. Encl. • STATE OF ALASKA • , ,i , I I I a ALASKA OIL AND GAS CONSERVATION COMMISSION �\ elk APPLICATION FOR SUNDRY APPROVALS or CEP 1 2011 20 AAC 25.280 *aka 011 & Gas c 1. Type of Request: Abandon F Plug for Redrill r Perforate New Pool fl Repair well IV • Change A proved I ogra * Suspend r Plug Perforations r Perforate r Rill Tubing r 4 riftlagasion "" Operational Shutdow n r Re -enter Susp. Well r Stimulate [ Alter casing r g � Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r r 205 - 142 3. Address: 6. API Number: Stratigraphic r Service . P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21248 - 02 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No iv 1Q -02B • 9. Property Designation (Lease Number): 10. Field / Pool(s): ALD 025634 • 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): 11500 . 6750 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 64 16 100' 100' SURFACE 3794 9 5/8 3830' 3529' PRODUCTION 8086 7 8119' 6259' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9623' - 11499' Slotted liner 6698' - 6750' 4.5 L - 6079 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SLEEVE -C - BAKER CMU SLIDING SLEEVE - CLOSED 6/24/2011 MD= 6009 TVD= 5023 SEAL ASSY - BAKER SEAL ASSEMBLY MD= 6062 TVD= 5060 12. Attachments: Description Summary of Proposal Pi 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch (" Exploratory r Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/5/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG 17 • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brent Rogers /Kelly Lyons Printed Name Brent Rogers Title: Problem Well Supervisor Signature j 7t,r.•-•'" Phone: 659 -7224 Date 08/29/11 Commission Use Only Sundry Number:t t ala Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Subsequent Form Required: /0 ,_ L/0 LL - 1 f APPROVED BY /� Approved by: COMMISSIONER THE COMMISSION Date: / ;1-, Form 10 -- s -- 1/iii10 7 t _ 2011 7 7 y•, ORIGJNIAL A • • IPPv • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 1 August 29, 2011 maka ()I1& Gas CM. GtmmiSSron i YK�N Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr.Seamount, Enclosed please find the 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1Q -02B (PTD 205 -142). The request is for approval to patch a tubing leak above the top packer. Please call Kelly Lyons or myself at 659 -7224 or M J Loveland./ Martin Walters at 659 - 7043 if you have any questions. Sincerely, A■r Brent Rogers Problem Well Supervisor Attachments t • • • • ConocoPhillips Alaska, Inc. Kuparuk Well 1Q -02B (PTD 205 -142) SUNDRY NOTICE 10 -403 TUBING REPAIR 08/29/11 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk Well 1 Q -02B (PTD 205 -142) with a tubing patch. On July 13, 2009, the AOGCC was initially notified of suspected TxIA communication. Subsequent diagnostics have identified a tubing to IA leak at the Baker CMU sliding sleeve. Multiple attempts have been made to repair the communication by exercising the sleeve with only temporary success. The plan is to set a retrievable patch over the sliding sleeve, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 30' 4.5" retrievable patch over the Baker CMU sliding sleeve at 6009'. / 2. MIT as per AOGCC requirements (0.25 x TVD to packer). 3. Submit 10 -404 post- repair. N ' hc 2.`{ k, r o iot^ NSK Problem Well Supervisor • • WELL LOG c PROAcrivE DiAgNosTic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road 1 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1 ; A, 0 ZUVI ti AU t , fi t$,,, f ?a Z 1) Caliper Report 06-Jul-11 1Q-0 2B 1 Report/ 1 CD `� 50-029-21248-02 2) Caliper Report 06- Jul -11 2K -28 1 Report/ 1 CD 50 -103- 20385 -00 �ar�- -� Date : v L Signed : � �"'� r l Print Name: \'4,61/4s3. - dk L_J— PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAX: (907)245 - 8952 E -MAIL : PDSANCHORAGEGWMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \Conocophillips_Transmit.docx as.Iclo I • • IN - r Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1Q -02B Log Date: July 06, 2011 Field: Kuparuk (CPF -1) U Log No.: Run No.: 10258567 ZX70 State: Alaska 3 API No.: 50- 029 - 21248 -02 Pipet Desc.: 4.5" 12.75 Ib. L -80 ABM -EUE Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 6,102 Ft. (MD) I Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : 1 This caliper log is correlated to the Tubing Tally. This log was run to assess the condition of the 4.5" tubing with respect to corrosive and mechanical damage. 1 The caliper recordings indicate the 4.5" tubing appears to be in good to fair condition with respect to corrosive and mechanical damage, with wall penetrations ranging from 20% to 36% wall thickness recorded in 7 of the 196 joints logged. Recorded damage appears as isolated pitting, at times forming a line. No other 1 significant wall penetrations, areas of cross - sectional wall Toss or I.D. restrictions are recorded. This is the third time a caliper has been run in this well and the 4.5" tubing has been logged. A comparison I of the current and previous log (August 9, 2009) indicates no increase in corrosive damage from surface to — 3,500' and an increase in corrosive damage from — 3,500' to — 6,000'. The increase appears as deeper isolated pitting. A graph illustrating the different in maximum recorded wall penetrations on a joint-by-joint basis between Togs is included in this report. t This summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: 1 Isolated Pitting ( 36 %) Jt. 114 @ 3,613 Ft. (MD) Line of Pits ( 35 %) Jt. 179 @ 5,632 Ft. (MD) Isolated Pitting ( 26 %) Jt. 154 @ 4,844 Ft. (MD) I Isolated Pitting ( 24 %) Jt. 141 @ 4,454 Ft. (MD) Isolated Pitting ( 21%) Jt. 144 @ 4,536 Ft. (MD) I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall Toss (> 3 %) are recorded. I MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 1 1 Field Engineer: N. Sanders Analyst: C. Waldrop Witness: B. Boehme I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS(dmemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 I ao tc-o- I • • Correlation of Recorded Damage to Borehole Profile I ® Pipe 1 4.5 in (22.4' - 6082.0') Well: 1 Q -02B Field: Kuparuk (CPF -1) I Company: Co nocoaska, Inc Country: USA Survey Date: July 06, 2011 PhilipsAl I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 25 1 25 - 792 7. J 50 1577 • 75 7 2362 I 100 - 3148 1 `1= Z s I o 125 _ 3933 v o 0 I 150 471 7 I 175 _ 5501 I 191.5 6082 0 50 100 Damage Profile (% wall)/ Tool Deviation (degrees) i I I Bottom of Survey =1 91.5 I I I • • I Maximum Recorded Penetration LS Comparison To Previous I Well: 1Q-02B Survey Date: July 06, 2011 Field: Kuparuk (CPF -1) Prey. Date: August 09, 2009 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 40 No. 10003738 I Country: USA Tubing: 4.5" 12.75 lb L -80 ABM -EUE Overlay Difference I Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0 50 100 150 200 250 100 50 0 50 100 0.1 10 1• I 17 17 27 27 I 37 37 47 47 57 57 67 67 a 77 77 g 87 g 87 I Z 97 = Z 97 c 0 107 S 107 I 117 4 ' 117 127 127 137 137 147 147 157 157 I 167 _ 1671 177 177 i 1 — ' 187 i 1 191.4 191.4 I -52 -26 0 26 52 • July 06, 2011 • August 9, 2009 Approx. Corrosion Rate (mpy) I I I I • • I PDS Report Overview Body Region Analysis I Well: 1Q -02B Survey Date: July 06, 2011 Field: Kuparuk (CPF -1) Tool Type: UW MFC 40 No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 4.5 ins 12.75 ppf L-80 ABM -EUE Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4.5 ins 12.75 ppf L -80 ABM -EUE 3.958 ins 4.5 ins 6.0 ins 6.0 ins I I Penetration(% wall) Da mage Profile (% wall) 200 Penetration body Metal loss body 0 50 100 0 I 150 100 50 0 I 48 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 196) 1 189 7 0 0 ; I Damage Configuration ( body) 98 40 I 30 20 I 148 1 10 0 I Isolated General line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total = 37) 37 0 0 0 0 Bottom of Survey = 191.5 I I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.8 ppf L -80 ABM -EUE Well: 1Q-02B Body Wall: 0.271 in Field: Kuparuk (CPF -1) I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: July 06, 201 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 22 0 0.01 6 1 3.92 Pup 1 25 0 0.04 14 2 3.92 Shallow Pitting. 2 57 0 0.03 11 2 3.91 NI 3 88 0 0.02 9 I 3.92 I 4 119 0 0.03 11 3.90 5 151 0 0.03 I 0 3.90 6 182 0 0.02 8 I 3.90 IN 7 214 0.04 0.03 11 1 3.91 8 245 0 0.03 9 2 3.91 I 9 277 0 0.03 10 1 3.90 10 308 0 0.03 11 1 3.90 11 340 0 0.03 0 1 3.89 12 370 0 0.03 10 1 3.92 I 13 401 0 0.03 9 3.91 14 432 0 0.03 10 2 3.90 15 464 0 0.02 8 2 3.91 15.1 495 0 0.01 6 0 3.92 Pup I 15.2 502 0 0 0 0 3.85 Camco DB Landing Nipple 15.3 503 0 0.02 7 1 3.85 PUP 16 509 0 0.02 8 1 3.91 17 540 0 0.02 7 1 3.92 U I 18 572 0 0.02 0 1 3.91 M 19 603 0 0.02 8 1 3.92 20 635 0 0.02 6 I 3.92 21 666 0 0.02 0 1 3.92 III 22 698 1.04 0.03 12 , 3.88 I 23 24 729 760 '' 0.03 11 3.91 0.02 7 3.90 r 25 792 0 0.03 11 1 3.91 r 26 823 0 0.03 11 1 3.93 I 27 855 0 0.03 10 I 3.89 28 886 0.04 0.03 11 2 3.91 r IN 29 918 0.04 0.03 12 1 3.89 IN 30 949 0 0.03 0 2 3.92 I 31 980 0.03 0.03 11 1 3.91 32 1012 0 0.03 9 I 3.89 NI 33 1043 0 0.03 10 1 3.92 1 34 1075 0 0.03 10 1 3.89 35 1106 0 0.03 11 1 3.92 I 36 1137 0.04 0.03 11 1 3.91 ■ 37 1169 0 0.02 8 2 3.91 ■ 38 1200 0 0.03 11 2 3.90 39 1231 0 0.02 8 1 3.93 I 40 1263 0 0.03 10 3.91 41 1294 0 0.03 11 3.90 42 1326 0 0.03 10 1 3.89 43 1357 0.02 8 I 3.90 I 44 1389 0 0.03 10 1 3.90 45 1420 0 0.03 11 1 3.90 U illi 46 1452 0 0.02 8 I 3.92 I neiody I Pe Metal trat Loss n Body Page 1 I 1 I . • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.8 ppf L -80 ABM -EUE Well: 1Q-02B Body Wall: 0.271 in Field: Kuparuk (CPF-1) I Upset Wall: 0.271 in Company: ConocoP Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: July 06, 2011 hillips I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Iris.) (Ins.) % (Ins.) 0 50 100 I 47 1483 9 0.02 7 1 3.91 48 1514 0.03 I 1 2 3.91 49 1546 0 0.02 8 1 3.91 50 1577 0 0.04 13 I 3.90 Shallow Pitting. I 51 1609 0 0.03 11 I 3.91 IN 52 1640 0 0.03 I1 3.90 N 53 1672 1) 0.04 14 3.90 Shallow Pitting. IN 54 1703 O 0.03 10 3.88 MI 55 1735 0 0.03 10 I 3.89 r I 56 1766 0 0.03 11 i 3.90 57 1798 O 0.02 8 1 3.90 58 182 9 0.03 0.03 11 I 3.90 59 1860 O 0.02 9 1 3.89 I 60 1892 0 0.03 10 1 3.89 61 1923 0 0.03 9 3.91 62 1955 0 0.05 17 3.90 Shallow Pitting. IN 63 1986 0.04 0.03 12 3.91 I 64 2017 0.04 0.03 12 3.90 I 65 2049 0 0.03 11 3.89 66 2080 0 0.03 II 3.89 a 67 2111 0 0.03 10 I 3.91 1 68 2143 0 0.02 9 I 3.92 1 I 69 2174 0 0.03 10 I 3.89 70 2206 0 0.02 9 2 3.90 * r 71 2237 0 0.02 9 1 3.89 72 2268 0.04 0.03 12 3.90 I 73 2300 0 0.02 7 3.89 74 2331 0 0.02 7 I 3.91 75 2362 0 0.02 8 2 3.90 76 2394 0 0.02 6 I 3.88 I 77 2425 0 0.03 Il 3.87 78 2457 0 0.03 11 I 3.90 79 2488 0 0.03 12 1 3.89 80 2520 0.02 7 2 3.88 I 81 2551 11 1 3.90 82 2582 a 0.02 I 3.91 83 2614 O 0.03 1 3.87 • 84 2645 0 0.02 1 3.89 85 2677 0 0.03 3.87 an I 86 2708 0 0.03 11 3.89 r NI 87 2740 0 0.03 10 1 3.87 88 2771 0 0.03 11 1 3.90 IN 89 2802 0 0.02 6 I 3.91 il I 90 2834 0.03 10 I 3.88 91 2865 O 0.02 7 3.88 IN 92 2897 • 0.03 9 I 3.90 ■ 93 2928 0 0.03 10 1 3.91 N I 94 2960 0 0.03 10 I 3.89 95 2991 • 0.03 9 I 3.89 96 3022 0 0.03 11 1 3.87 Vil eratdy I Pen Meta Loss ion Bo Body II Page 2 I I PDS REilkRT JOINT TABULATION SHE• I Pipe: 4.5 in 12.8 ppf L-80 ABM -EUE Well: 1Q-0213 Body Wall: 0.271 in Field: Kuparuk (CPF -1) Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA I Survey Date: July 06, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I. D. (I Comments (% wall) Ins. (Ins.) % (Ins.) 0 50 100 97 3054 0 0.02 8 1 3.90 98 3085 0 0.03 9 1 3.88 ■ I 99 3116 0 0.03 10 1 3.90 100 3148 0 0.02 7 1 3.88 101 3179 0.04 0.03 11 1 3.87 ■ 102 3210 0 , 0.04 16 1 3.89 Shallow Pitting. ■ I 103 3242 0 0.03 11 1 3.88 ■ 104 3273 0 0.03 10 1 3.89 ■ 105 3305 0 0.03 10 1 3.88 ■ 106 3336 0 0.03 12 2 3.89 I 107 3367 0 0.02 7 1 3.89 108 3399 0 0.03 12 1 3.88 al 109 3430 0.04 0.03 10 1 3.90 110 3462 0 0.02 7 1 3.89 I 111 3493 0 0.02 8 1 3.88 112 3524 0 0.02 6 1 3.89 113 3556 0 0.02 9 1 3.89 114 3587 0 0.10 36 1 3.89 Isolated Pitting. ■ 15 3618 0 0.04 13 1 3.86 Shallow Pitting. IN I i 116 3650 0 0.03 13 1 3.89 Shallow Pitting. NI 3681 () 0.03 11 1 3.88 ■ 118 3713 0.03 0.03 11 1 3.88 ■ 119 3744 0 0.05 18 1 3.88 Shallow Pitting. ■ I 120 3776 0 0.03 10 1 3.88 ■ 121 3807 0 0.03 11 2 3.87 122 3838 0 0.02 8 1 3.89 123 3870 0 0.02 8 1 3.88 I 124 3901 0 0.03 10 1 3.88 ■ 125 3933 0.04 0.03 11 2 3.88 ■ 126 3964 0 0.03 11 1 3.89 ■ 127 3996 0 0.03 11 1 3.88 ■ 128 4027 0 0.03 10 1 3.90 I 129 4058 0 0.02 9 1 3.89 130 4090 0 0.03 11 2 3.87 131 4121 0 0.02 7 1 3.90 132 4152 0 0.03 12 1 3.87 ■ I 133 4184 0 0.03 11 1 3.86 ■ 134 4215 0 0.03 13 1 3.87 Shallow Pitting. IN 4246 0 0.05 18 1 3.89 Shallow Pitting. ■ 136 4278 0 0.05 20 1 3.85 Shallow Pitting. ■ 137 4309 0.04 0.04 15 1 3.86 Shallow Line of Pits. ■ I 138 4341 0 0.05 19 2 3.88 Shallow Line of Pits. 0 4372 0.02 7 1 3.86 140 4403 0 0.03 9 2 3.89 141 4435 0 0.07 24 2 3.88 Line of Pits. I 142 4466 0 0.03 13 1 3.90 Shallow Pitting. 143 4497 0 0.05 19 2 3.88 Shallow Line of Pits. ■ 144 4529 0 0.06 21 1 3.85 Line of Pits. ■ 145 4560 0 0.04 15 I 3.87 Shallow Pitting. IN I 146 4592 0 0.04 13 I 3.88 Shallow Pitting. I Penetration Body Metal Loss Body 1 Page I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.8 ppf L-80 ABM -EUE Well: 1Q-02B Body Wall: 0.271 in Field: Kuparuk (CPF -1) I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: July 06, 2011 I Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % t_oss I.D. Comments (% wall) (Ins.) (Ins.) (Ins.) 0 50 100 I 147 4623 0 0.05 182 3.86 Shallow Pitting. 148 4655 0 0.05 20 3 3.88 Shallow Line of Pits. 149 4686 0 0.04 16 2 3.86 Shallow Pitting. 150 4717 0 0.02 9 1 3.88 • 151 4749 0 0.03 10 1 3.88 • I 152 4780 153 4812 0 0.04 17 1 3.85 Shallow Pitting. 0 0.03 11 1 3.84 IN • 154 4843 0 0.07 26 2 3.87 Isolated Pitting. NM 155 4874 0 0.03 12 I 3.87 • I 156 4906 0 0.03 10 1 3.86 • 157 4937 0 0.03 11 1 3.86 • • 158 4968 0 0.03 12 1 3.88 159 4999 0 0.03 12 2 3.87 • I 160 5031 0 0.04 17 1 3.86 Shallow Pitting. 161 5062 0 0.02 7 1 3.86 um 162 5094 0.04 0.03 11 1 3.88 • 163 5125 0 0.04 14 1 3.88 Shallow Pitting. IN I164 5156 0 0.05 18 1 3.86 Shallow Pitting. 165 5188 0 0.03 11 1 3.87 • 166 5219 0 0.04 15 1 3.88 Shallow Pitting. N 167 5251 0 0.03 12 1 3.87 • 168 5282 0 0.03 10 2 3.86 • I 169 5313 170 5344 0 0.02 9 1 3.86 • O 0.03 11 1 3.86 • 171 5376 0.04 0.03 10 2 3.88 • 172 5407 0 0.04 14 2 3.88 Shallow Pitting. im I 173 5439 0 0.03 10 1 3.87 174 5470 0 0.02 9 2 3.77 • • MN 175 5501 0 0.05 18 2 3.86 Shallow Pitting. 176 5533 0 0.03 11 2 3.86 I 177 5564 0 0.03 11 1 3.87 178 5595 0 0.02 8 1 3.87 • 179 5627 0 0.10 35 2 3.88 Line of Pits. • 180 5658 0.06 0.03 12 1 3.87 • 5689 0 0.03 11 1 3.87 • I181 182 5721 183 5753 0 0.03 12 1 3.84 • 0 0.03 10 1 3.88 • 184 5784 0 0.05 17 1 3.88 Shallow Pitting. IN 185 581 5 0 0.05 17 2 3.87 Shallow Pitting. MN 186 5846 0 0.03 13 I 3.87 Shallow Pitting. 187 5878 0 0.03 12 1 3.87 • im 188 5909 0 0.04 13 2 3.86 Shallow Pitting. 189 5941 0.03 0.03 11 1 3.87 • I 190 5972 0.04 0.03 11 1 3.86 190.1 6004 0.05 0.04 17 1 3.89 Pup Shallow Line of Pits. 190.2 6010 0 0 0 0 3.76 Baker CMU Sliding Sleeve 191 6015 0 0.03 11 1 3.90 • 191.1 6046 0 0.02 9 1 3.86 Pup I 191.2 6061 0 0 0 0 0 3.81 Tieback Sleeve 191.3 6063 0 0 0 3.81 Baker Seal Assembly ' Penetration Body Metal Loss Body Page 4 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.8 ppf L -80 ABM -EUE Well: 1Q-02B Body Wall: 0.271 in Field: Kuparuk (CPF -1) I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc Nominal I.D.: 3.958 in Country: USA Survey Date: July 06, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 191.4 6079 0 191.5 6082 0 0 0 0 4.17 4.5" Tubing Tail 0 0 0 3.98 Baker CMC Mechanical Liner Hanger ' Penetration Body Metal Loss Body I I I I I I I I I 1 I Page 5 I 1 • 1 PDS Report Cross Sections ' Well: 1 Q 02B Kuparuk (CPF -1) Survey Date: July 06, 2011 Field: Tool Type: UW MFC 40 No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 4.5 ins 12.75 ppf L -80 ABM -EUE Analyst: C. Waldrop 1 1 Cross Section for Joint 114 at depth 3613.277 ft Tool speed = 50 Nominal ID = 3.958 Nominal OD = 4.5 Remaining wall area = 98% Tool deviation = 41° 1 1 1 1 1 / 1 Finger = 36 Penetration = 0.098 ins Isolated Pitting 0.10 ins = 36% WaII Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • I d:i PDS Report Cross Sections I Well: 1Q-02B Kuparuk (CPF -1) Survey Date: July 06, 2011 Field: Tool Type: UW MFC 40 No. 10003738 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 4.5 ins 12.75 ppf L -80 ABM -EUE Analyst: C. Waldrop 1 1 Cross Section for Joint 179 at depth 5632.027 ft Tool speed = 49 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 98% \ Tool deviation = 45° \ / 1 \ 1 1 1 \ 1 1 1 Finger = 34 Penetration = 0.094 ins Line of Pits 0.10 ins = 35% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 ' KUP I Q -02B ConoeoPhillips s a ttributes ogle & MD T W embore API/UWI I FIem Name Well Status • Intl (9 MD pti(8) Act Bbn (RKB) tnroadNirpa 500292124802 KUPARUK RIVER UNIT !NJ 95.09 9,976.94 11,501.0 ' Comment H2S (ppm) Date Annotation End Date KB-DIA (R) Rig Release Date I Well Cor4e -13- 0206/25/20111244:04 PM A NIPPLE SV: NI 5 6/18/2006 Last WO: 30.10 4/11/1985 schematic - Actual SSSV: I Depth IRKS) End Date Ama[atinn Last moo ... 809 Date Last Tag: Rev Reason: PULL ISO SLEEVE & INJ VALVE ninam 6/25/2011 Casing Strings Casing Description String 0... String ID... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt.. String... String Top Thrd HANGER. 21 CONDUCTOR 16 15.062 36.0 100.0 100.0 62.58 /1 WELDED i rr gamin / \ goomming. Casing Description Sing 0... String ID ... Top (N(B) Set Depth (f... Set Depth (TVD) ... String WL.. String... String Top Thrd SURFACE 95/8 8.921 35.3 3,829.5 3,528.9 36.00 J BTC Casing Description String 0... String ID... Top MKS) Set Depth p... Set Depth (TVD) ... String Wt.. String... String Top Thrd PRODUCTION 7 6.276 33.1 8,118.7 6,258.8 26.00 J BTC Catalog Description String 0... String ID ... Top (RIB) Set Depth (L.. Set Depth (rvD) ... String Wt.. Stung ... Stung Top Thrd LINER 1QA 4 1!2 3.958 6,112.9 9,010.0 6,650. 12.60 L-80 NSCT I Liner Details • I CONDUCTOR, Top Depth 36 -100 (TVD) Top Ind Nam... Top (MB) (MB) ( °) Rem Description C omment ID (In) 6,112.9 5,108.0 45.66 SLEEVE BAKER UNER PACKER SETTING SLEEVE 5.500 NIPPLE, 500 1,nt: I 6,119.0 5,112.3 45.64 PACKER BAKER HYFLO 10 LINER TOP PACKER 5.063 I ., 6,1214 5,113.9 45.64 SBE 6,135.9 5,124.0 45.59 HANGER BAKER 80 -47 SEAL BORE EXTENSION 4.750 BAKER CMC MECHANICAL LINER HANGER 4.125 O 6,145.1 5,130.5 45.56 XO Reducing CROSSOVER 5 x 4.5, ID 3.958, #12.60, L-80, NSCT 4.500 7,974.6 6,165.5 50.66 NIPPLE OTISX LANDING NIPPLE 3.812 8,451.8 6,469.1 47.31 MARKER JT 3.958 336 /255 / Casing Description String 0... String ID... Top IRKS) Set Depth n... Set Depth (TVD) ... Stu String Stung WL.. String... Sng Top Thrd asaea0 WINDOW 4 3.958 8,539.0 8,540.0 6,528.9 6.16 L Casing Description Stung 0... Stung ID... Top (RIB) Set Depth M... Set Depth (TVD) ... String Wt.. String... String Top Thrd UPPER L1 TOP 3 3/16 2.810 8,496.0 8,7050 6,618.9 6.16 L TCII Casing Descdptton String O... Sing ID... Top (ti(B) Set Depth (f... Set Depth (TVD) ... String WL.. Stung... Stung Toplhrd LOWER L1 TOP 2 7/8 2.441 8,705.0 9,609.0 6,696.2 6.16 L STL I SLEEVE C. Casing Description String 0... String ID ... Top (RIB) Set Depth (1.. Set Depth (TVD) i D) ... String WL.. String ... Sing Top Thrd 6 000 SLOTTED LINER 2 7/8 2.441 9,609.2 11,501.0 6.16 L-80 STL Liner Details Top Depth (TVD) Top Ind Nomi... Top (RIB) MD) P) Item Description Comment ID (In) I LOCATOR. 9,609.2 6,696.2 82.83 BILLET T ubing Strings WEATHERFORD LINER BILLET w /GS PROFILE & 3.5' PUP 2.441 6,061 SEAL ASSY. 6,062 Tubing Description String 0... String ID ... Top pap Set Depth (f... Set Depth (TVD) ... Sing Wt.. Stung... Sing Top Thrd TUBING 41/2 3.795 21.5 6,078.7 5,084.0 12.75 L -80 ABM -EUE Completion Details I Tap Depth iii ( TVD) rap Ind p Top lam) (B) P) Rem Description Commell Rani_ pn) 21.5 21.5 -2.54 HANGER FMC GEN IV TUBING HANGER 4.500 . 500.2 500.2 0.60 NIPPLE CAMCO DB LANDING NIPPLE 3.875 6,008.8 5,035.4 46.04 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 6/24/2011 1812 i 6,061.4 5,071.9 45.81 LOCATOR BAKER LOCATOR 3.880 6,061.8 5,072.2 45.81 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 Perforations & Slots Shot Top(TVD) Bbn(TVD) Dena 1 Top MKS) Bh 1 ( B) IRKS) ( B) Zone Date (sR.. Type Comment 9.623 11,499 6,697.9 A -3, A -4, A -5, 11/18/2005 99.0 SLOTS STL SLOTTED UNER 1Q -02B I S; E Notes: General & Safety Annotation i 11/27/2005 NOTE: MULTI-LATERAL WELL w /SIDETRACK 1Q -02B, LATERAL LEG 1 Q -02BL1 6/4/2011 NOTE: CONFIRMED ISO-SLEEVE LEAK@ 6009' RKB PRODUCTION, 33-8,119 8.2035205 Somoza Pens. i 8103 RPERF. 6.369-6 RPERF. 6.369-8384 -88384 RP ERF, 8,3694384 i 8,4404442 - Shot Sty Pens. 8,440 I WNDO _ I 8.539-8540 UPPER 11 TOP, 84965.705 1 1 LINER 10A, 9113-9910 LOWER Li TOP, 9705-9909 SLOTS, ill 1 i 9,623-11,499 SLOTTED LINER, 9.609- 1 028) TD (10 -02E9, • 11,501 Page 1 of/ • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, June 28, 2011 11:26 AM To: 'NSK Problem Well Supv' Cc: Schwartz, Guy L (DOA); Lyons, Kelly A; CPF1 DS Lead Techs; CPF1 Prod Engr; Driscoll, Michael D Subject: RE: 1Q-02B (PTD# 205 -142) Update Thanks Martin. Hopefully manipulating the sliding sleeve has solved the communication issue. Keep us informed regarding the performance. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, June 28, 2011 10:47 AM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Lyons, Kelly A; CPF1 DS Lead Techs; CPF1 Prod Engr; Driscoll, Michael D; NSK Problem Well Supv Subject: 1Q -02B (PTD# 205 -142) Update Tom, This is to give you an update on where we are with the 1 Q -02B. In the past week, we have been able to operate the CMU sliding sleeve which was the suspected leak point, and achieve a passing TxIA CMIT, MITT, and MITIA. We put the well on injection the afternoon of 06/27/11 and plan to monitor it and perform another MITIA once it is online and stabilized provided that it exhibits no TxIA communication. Martin °qtr. JUN 2 8 201 From: Maunder, Thomas E (DOA) <tom.maunder @alaska.gov> To: NSK Problem Well Supv <n1617 @conocophillips.com> CC: "Schwartz, Guy L (DOA)" <guy.schwartz @alaska.gov >, "Lyons, Kelly A" < KeIIy .A.Lyons @conocophillips.com >, CPF1 DS Lead Techs <n1140 @conocophillips.com >, CPF1 Prod Engr <n1269@conocophillips.com >, "Driscoll, Michael D" < Michael .D.Driscoll @conocophillips.com> Date: April 5, 2011 8:59:58 AM AKDT Subject: RE: 1Q -02B (PTD# 205 -142) request approval to restart injection 03 -08 -11 Martin, It is acceptable to keep the well in operation for the additional 2 weeks you propose. Please keep us informed. A couple of questions /observations, only 8 minutes to bleed off 2600 psi seems a little quick. Was anything other than diesel bled back? What was the reported bleed volume? Thanks in advance. Tom Maunder, PE AOGCC well Supv 04, 2011 10:16 AM palaska.gov' 6/28/2011 Page 1 of 7 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 05, 2011 9:00 AM To: NSK Problem Well Supv Cc: Schwartz, Guy L (DOA); Lyons, Kelly A; CPF1 DS Lead Techs; CPF1 Prod Engr; Driscoll, Michael D Subject: RE: 1Q -02B (PTD# 205 -142) request approval to restart injection 03 -08 -11 Martin, It is acceptable to keep the well in operation for the additional 2 weeks you propose. Please keep us informed. A couple of questions /observations, only 8 minutes to bleed off 2600 psi seems a little quick. Was anything other than diesel bled back? What was the reported bleed volume? Thanks in advance. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Monday, April 04, 2011 10:16 AM To: Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); Lyons, Kelly A; NSK Problem Well Supv; CPF1 DS Lead Techs; CPF1 Prod Engr; Driscoll, Michael D Subject: RE: 1Q -02B (PTD# 205 -142) request approval to restart injection 03 -08 -11 Tom, CPAI initiated seawater injection on 1Q -02B on 03/23/11. Once the well was online and stabilized an IA drawdown test was performed which failed. Considering that the IA was bled from 2720 psi to 100 psi in 8 minutes during the test, we intend to continue injection and bleeds for an additional 14 days (until 4/20/11) to confirm that the pressure is not thermal in nature. Should it be determined that the well has TxIA communication, the well will be shut in and freeze protected. It is possible that the isolation sleeve set across the CMU sliding sleeve is leaking so slickline would likely replace it as a first step. We will also use DHD, slickline, and electric line to locate and repair the communication if possible. The well is already on the Monthly Injector Report and will remain so until further notice. Attached is an updated TIO plot and welibore schematic. Martin From: Maunder, Thomas DOA) <tom.maunder @alaska.gov> To: "Lyons, Kelly A" <Kelly.A. s @conocophillips.com >, "Schwartz, Guy L (DOA)" <guy.schwartz @alaska.gov> Date: March 8, 2011 10 :20:42 AM AKST Subject: RE: 1Q-02B (PTD# 205 -142) request approva . -start injection 03 -08 -11 Hi Kelly, Please note the correct well name is 1 Q -02B. I last exchanged messages wi • - rtin /Brent on January 4 regarding the entry in the monthly report. Our records show the well had 15 operatin. s April — June, 2010. Has there been any well work performed since then? Your request seems appropriate for t - - eek period you plan for diagnostics. The record inciates that the well passed an MIT IA on 7/12/09. I will look for a . •date prior to March 25. Call or message with any questions. Tom Maunder, PE AOGCC 6/28/2011 Well Name 10-02B Notes: OZ - Inj - FTP & IA within 500 psi Start Date 1/1/2011 Days 120 End Date 5/1/2011 Annular Communication Surveillance 3000 80 WHP __ IAP OAP 70 WHT 2500 – 60 2000 • t / - 50 LL im Q 1500 4 – 30 1000 I - 20 500 - I – 10 0 — 0 Mar -11 Apr -11 3000 '..11" 1 111 r il 2500 - •■■ MGI O 2000_ 'M.....PWI m �swl 1500 •BLPD U • 1000 500 0- Mar -11 Apr -11 Date • • Maunder, Thomas E (DOA) From: kelly.a.lyons @conocophillips.com Sent: Tuesday, March 08, 2011 11:08 AM To: Maunder, Thomas E (DOA); Lyons, Kelly A; Schwartz, Guy L (DOA) Subject: RE: 1Q-02B (PTD# 205 -142) request approval to restart injection 03 -08 -11 Hi Tom, You are so right about the B designation. Thanks for catching me. Anyway, we shut in the well on 06 -08 -2010. And then performed a drift on 06 -12 -2010 in hopes of performing an IPROF on the well when it came back on line. But there has been no other wellwork performed since then. Thanks so much Kelly Original Message: !!c MAR 9 ` B1 FROM: tom.maunder @alaska.gov TO: "Lyons, Kelly A" <Kelly.A.Lyons @conocophillips.com >, "Schwartz, Guy L (DOA)" <guy.schwartz @alaska.gov> DATE: March 8, 2011 10:20:42 AM AKST SUBJECT: RE: 1Q -02B (PTD# 205 -142) request approval to restart injection 03 -08 -11 Hi Kelly, Please note the correct well name is 1Q -02B. I last exchanged messages with Martin /Brent on January 4 regarding the entry in the monthly report. Our records show the well had 15 operating days April - June, 2010. Has there been any well work performed since then? Your request seems appropriate for the 2 week period you plan for diagnostics. The record inciates that the well passed an MIT IA on 7/12/09. I will look for an update prior to March 25. Call or message with any questions. Tom Maunder, PE AOGCC From: Lyons, Kelly A [mailto: Kelly .A.Lyons @conocophillips.com] Sent: Tuesday, March 08, 2011 9:48 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: 1Q -02 (PTD# 205 -142) request approval to restart injection 03 -08 -11 I've amended the subject to include the date. (newbie growing pains). Kelly From: NSK Problem Well Supv Sent: Tuesday, March 08, 2011 9:44 AM To: 'Maunder, Thomas E (DOA)'; 'guy.schwartz @alaska.gov' Subject: 1Q -02 (PTD# 205 -142) request approval to restart injection Tom and Guy, I am forwarding this note because I can find no response in our files regarding our request to receive approval to flow 1Q -02. CPAI would still like to proceed with diagnostic testing. I have attached the 90 day plot sent with 1 • • the original email and an additional 90 T /I /O plot for your review. Thanks so much Kelly Kelly Lyons for Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone: 907 - 659 -7224 Pager: 907 -65 -7000 pgr 909 From: Ives, Ian C (ASRC Energy Services) Sent: Thursday, June 10, 2010 9:57 AM To: 'guy.schwartz @alaska.gov'; 'tom.maunder @alaska.gov'; 'jim.regg @alaska.gov' Subject: FW: 1Q -02 All, Kuparuk injector 1Q -02 ( PTD # 205 -142 ) is exhibiting signs of possible T X IA communication after being returned to injection. Previously the well was reported to the AOGCC on 2/25/10. Diagnostics indicated the CMU were leaking. An isolation sleeve was set and a passing MIT -IA and IA -DD test were performed.. Those results were reported to the AOGCC on 4/20/10. The well was placed on injection 6/2/10 and exhibited signs of T X IA. TIO= 1600/1600/460. The well has since been shut in and freeze protected. ConocoPhillips requests permission to bring the well back on injection for a minimum of 14 days to allow thermal stabilization . The pressures will be monitored daily. Further diagnostics will be performed as needed. An update will be sent with the results once the test or any diagnostics are completed. The well will also be added to the monthly report. Attached is a 90 day TIO trend. Please let me know if this is acceptable or if you have any questions. Ian Ives Problem Well Supervisor 659 -7224 2 CHOKE FTP FTT IAP OAP T/I/0 Plot - 1 Q -02 • f- , . 2000 - - -_—_ 150 2 1500 ei) DI U \ .._ ___ 7- 1 - 100 _Ne 1000 - I I o : , r' 1 50 0 500 1 _....-- ._-• 0 I I I I I I 1 0 01-Apr-10 01-May-10 01-Jun-10 Date CHOKE FTP I P FIT , CHAP Tnia Plot - Q -02 350 200 a 300 _.__ __ — -- — 250 `x 200 . 4 ' - E -- ; .. cu 0- 1 00 150 �3 , , o s ;. 100 0 p A 4'4 5 0 a k 0 08 -Dec -10 21 -Dec -10 03- Jan -11 16- Jan -11 29- Jan -11 11- Feb -11 24 -Feb -11 Date • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 10:53 AM A 1 LO1 To: NSK Well Integrity Proj Cc: NSK Problem Well Supv' Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 D-ac - t `-) All, I am continuing to review the December Monthly Injector report. I am through a total of 13 wells. I wanted to send this latest message due to what I have found or not found on 1Q -02B. As I continue to work through the report, I plan to send interim messages as I get 7 - 10 new wells reviewed. Call or message with any questions. 13. 1 Q -02B - Well name is 1 Q -02B. Well last injected 9/10. I do not show having received any specific notification /request in June, 2010 regarding this well. There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containing a statement that you intend to return the well to injection and remove it from the waiver report in May. 12. 1L-05 - AA 2B.054 issued 10/22/2010. Well last injected 9/10 11. 1 L -03A - Well name is 1 L -03A. Permit to Drill # is 199 -037. MITIA failed 09/25/2010. Well last injected 9/10. 0. 1G-01 - AA 2B.035 issued 7/30/2008. 9. 1 .A - Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have pass-: since. Well last injected • 007. AA 2B.018 was issued in October 2007, but no injection has occurred in he well. Looking at the pressure : ot, it is shown that the IA pressure appears to have been bled off in Oct..er and November. Was there well work ducted, maybe plug setting? There is email traffic exchanged r- :arding "what if" for an OA pressure sensor. . h have been installed on other wells, is that possible here ? hat are the plans for the well? 8. 1D-40A - Well name i D -40A. MITIA failed - 10/1/2009. Well last ected 9/09. 7. 1D-119 - Single casing well. I ITIA failed 7/16/2010. Well las ' jected 6/2010. 6. 1D-106 - Single casing well. MITIA led 7/16/2010. W- last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1 C -133 - Single casing well. MITIA failed 5/2 .. $ 10. Well last injected 5/2010. 4. 1 C -10 - AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 20 11:13 AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity P Subject: RE: Conoc. illips Monthly Injector Report - Dec 2010 Martin, et al, I am condu. ing a review of December's Monthly report. I have just gotten started and wante. o pass back the comme /questions I am developing. I als.. m doing some editing /formatting on the spreadsheet to facilitate printing it off when necessar . I have only e.' ed the 1A -07, 1A -12 and 1B -02 in the attached spreadsheet. The edits are highlighted in yellow. C. • these 1/4/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] •5— ` LAD Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 - 7000 #909 • • ConocoPhillips Well 1Q-02B Injection Data • Tbg Psi • IA Psi • O Psi 4000 3500 3000 - I 2 2500 Cl) Q . 2000 - 2 1500 - 1000 - 500 . . 0 09/10 10/10 11/10 12/10 01/11 Date PTD 205 -142 Reason: Suspect TxIA Suspect communication due to thermal responses Well last operated 06/10. 06/10/10 - Requested AOGCC approval to BOI • • ConocoPhillips Well 1Q-02B Injection Data ♦ Water Injection *Gas Injection 4000 3500 3000 .2 2500 u) a a 2000 x 1500 1000 500 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 31- Dec -10 0 0 -9 300 -14 30- Dec -10 0 0 -10 300 -14 29- Dec -10 0 0 -12 300 -14 28- Dec -10 0 0 -13 300 -14 27- Dec -10 0 0 -11 300 -14 26- Dec -10 0 0 -9 300 -13 25- Dec -10 0 0 -8 300 -13 24- Dec -10 0 0 -7 300 -12 23- Dec -10 0 0 -7 300 -10 22- Dec -10 0 0 -4 300 -9 21- Dec -10 0 0 -2 300 -9 20- Dec -10 0 0 -4 300 -9 19- Dec -10 0 0 -7 300 -9 18- Dec -10 0 0 -8 300 -9 17- Dec -10 0 0 -7 300 -8 16- Dec -10 0 0 -6 300 -8 15- Dec -10 0 0 -6 300 -8 14- Dec -10 0 0 -6 300 -7 13- Dec -10 0 0 -5 300 -7 12- Dec -10 0 0 -7 300 -6 11- Dec -10 0 0 -7 350 -5 10- Dec -10 0 0 -5 350 -5 9- Dec -10 0 0 -5 350 -4 8- Dec -10 0 0 -6 350 20 7- Dec -10 0 0 -7 350 20 6- Dec -10 0 0 -6 350 20 5- Dec -10 0 0 -5 350 20 • • 4- Dec -10 0 0 -5 350 -2 3- Dec -10 0 0 -5 350 -1 2- Dec -10 0 0 -5 350 -1 1- Dec -10 0 0 -5 350 4 30- Nov -10 0 0 -7 350 9 29- Nov -10 0 0 -3 350 10 28- Nov -10 0 0 0 350 11 27- Nov -10 0 0 2 350 11 26- Nov -10 0 0 37 350 11 25- Nov -10 0 0 262 350 50 24- Nov -10 0 0 495 350 50 23- Nov -10 0 0 593 350 12 22- Nov -10 0 0 319 350 12 21- Nov -10 0 0 199 350 12 20- Nov -10 0 0 105 350 12 19- Nov -10 0 0 11 350 12 18- Nov -10 0 0 37 350 11 17- Nov -10 0 0 4 350 11 16- Nov -10 0 0 -1 350 12 15- Nov -10 0 0 -2 350 13 14- Nov -10 0 0 0 350 13 13- Nov -10 0 0 1 350 14 12- Nov -10 0 0 2 350 14 11- Nov -10 0 0 3 350 14 10- Nov -10 0 0 3 350 15 9- Nov -10 0 0 104 350 15 8- Nov -10 0 0 317 400 15 7- Nov -10 0 0 238 400 15 6- Nov -10 0 0 307 400 16 5- Nov -10 0 0 264 400 17 4- Nov -10 0 0 54 400 19 3- Nov -10 0 0 5 400 26 2- Nov -10 0 0 99 400 34 1- Nov -10 0 0 296 400 36 31- Oct -10 0 0 465 400 37 30- Oct -10 0 0 501 400 38 29- Oct -10 0 0 392 400 38 28- Oct -10 0 0 265 400 38 27- Oct -10 0 0 474 400 39 26- Oct -10 0 0 566 400 39 25- Oct -10 0 0 651 400 39 24- Oct -10 0 0 594 400 40 23- Oct -10 0 0 551 400 40 22- Oct -10 0 0 498 400 41 21- Oct -10 0 0 350 400 41 20- Oct -10 0 0 276 400 42 19- Oct -10 0 0 481 500 42 18- Oct -10 0 0 433 500 42 17- Oct -10 0 0 441 500 43 16- Oct -10 0 0 398 500 44 15- Oct -10 0 0 408 500 44 14- Oct -10 0 0 435 500 45 0 • 13- Oct -10 0 0 386 500 45 12- Oct -10 0 0 303 500 46 11- Oct -10 0 0 240 500 46 10- Oct -10 0 0 140 500 47 9- Oct -10 0 0 119 500 47 8- Oct -10 0 0 192 500 48 7- Oct -10 0 0 385 500 49 6- Oct -10 0 0 459 550 50 5- Oct -10 0 0 494 550 50 4- Oct -10 0 0 451 550 50 3- Oct -10 0 0 386 550 51 2- Oct -10 0 0 272 550 51 • Conoco~Phillips ~u P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri123, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~~~~. . ~ ,; .. ~P~R.:2. ~. 201Q.... grid a~5~~~~~ ~ ~. tea.- Enclosed please find a spreadsheet with a list of wells from the Kupaxuk field (KRil).. 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 March 21, 2010. The corrosion inhibitor/sealant was pumped April 1 thru April 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Since ~._ Perry 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 4/23/10 1A.1 F. 1Q ~ 1Y PAD's l Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off da#e Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-01 50029205900000 1810590 SF ri/a 4" n/a 2.55 4/5/2010 1A-02 50029205990000 1810710 SF n/a 9" n/a 4.25 4/8/2010 1A-05 50029206270000 1811040 SF n/a 6" n/a 4.25 4/7/2010 1A-08 50029203130000 1780400 SF n/a 10" n/a 13.7 4/17/2010 1A-09 50029206690000 1811520 SF n/a 4" n/a 2.55 4/2/2010 1A-15 50029207110000 1820170 SF Na 4" Na 2.55 4/4/2010 1F-15 50029210250000 1831490 21" n/a 21" Na 4.25 4/1/2010 t Q-02 50029212480200 2051420 22" Na 22" Na 7.2 4/6/2010 1 Q-03 50029212490200 1842330 27" n/a 27" n/a 3.4 4/6/2010 1Q-05 50029212330000 1842170 32" n/a 32" n/a 3.4 4/1/2010 1 Q-06 50029212240000 1842080 32" Na 32" Na 2.12 4/1/2010 1Q-10 50029212150000 1841980 32" Na 32" Na 3.82 4/1/2010 1Q-15 50029213080000 1850460 22" n/a 22" n/a 2.97 4/1/2010 1Q-16 50029213090000 1850470 25" n/a 25" n/a 3.82 4/1/2010 1Y 21 50029223870000 1931020 23" n/a 23" n/a 3.82 4/1/2010 1Y-24A 50029223717100 2041250 26" n/a 26" n/a 3.82 4/1/2010 1 Y-28 50029223800000 1930890 28" n/a 28" Na 5.52 4/1/2010 1 Y 31 50029223810000 1930900 6'8" 0.65 24" 3/21/2010 5.52 4/1 /2010 • • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, April 20, 2010 7:48 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 10-026 (PTD# 205-142) Report Of TxIA Communication Attachments: MIT KRU 10-026 02-24-10.x1s Guy, Tom, Jim Page 1 of 1 Following up on the diagnostics that have been performed. Slickline set and isolation sleeve in the CMU @ 6009' after they were unable to engage the CMU to shift it. Following the sleeve set, a passing MITIA was performed (see attached form). A passing IA drawdown test was also performed with the following results: Initial T/I/0=860/850/0. Bled IA down, start IA DD test T/I/0=860/150/0 30 min T/I/0=860/180/0 60 min T/I/0=860/180/0 2 hour T/I/0=860/180/0 5 hour T/I/0=860/180/0 7 hour T/I/0=860/180/0 With passing results on both tests, it is ConocoPhillips intention to return the well to injection under normal well status. As per Rule 7, any future indications communication will be reported and further diagnostics will be done at that time. Currently the well is on the monthly report and will remain on the report for another month for monitoring purposes. If there is no further indication of communication, it will be removed from the monthly report in May. Please let me know if you have any questions or if this is unacceptable. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~d~~~ ~~I~ ~ `~~. 2G~ From: NSK Problem Well Supv Sent: Saturday, February 06, 2010 5:04 PM To: 'Schwartz, Guy L (DOA)'; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPFS Prod Engr; CPFl DS Lead Techs; Kovar, Mark Subject: 1Q-02B (PTD# 205-142) Report Of TxIA Communication Guy/Tom/Jim, Kuparuk injector 1Q-026 (PTD# 205-142) is suspected of having TxIA communication based upon failed MITIA and IA drawdown tests. Slickline will be scheduled to perform initial diagnostics as soon as reasonably possible. The well will be shut in and added to the monthly report. Attached is a wellbore schematic and 90 day TIO plot. « File: 1 O-02B Wellbore Schematic.pdf » « File: 10-026 TIO Plot.pdf » Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/21 /2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1Q 02/24/10 VanCamp-HES Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Q-02B Type Inj. N TVD 5,072' Tubing 1,525 1,525 1,525 1,525 Interval O P.T.D. 2051420 Type test P Test psi 1500 Casing 800 3,000 2,920 2,885 P/F P Notes: Diagnostic MITIA OA 60 60 60 50 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 10-02B 02-24-10.x1s . • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, February 06, 2010 5:04 PM To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark Subject: 10-02B (PTD# 205-142) Report Of TxIA Communication Attachments: 1 O-02B Wellbore Schematic.pdf; 1 Q-02B TIO Plot.pdf Guy/Tom/Jim, Kuparuk injector 1Q-02B (PTD# 205-142) is suspected of having TxIA communication based upon failed MITIA and IA drawdown tests. Slickline will be scheduled to perform initial diagnostics as soon as reasonably possible. The well will be shut in and added to the monthly report. Attached is a wellbore schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 r (y~~ ~~~ Nom! ~~~'~ ~ ~~ 4/21 /2010 Well Name 1Q-026 Notes: Report ~° FxIA to AOGCC End Date 2115%2010 Days 120 Start Date 3 0 18 2009 Annular Communication Surveillance 3000 ._._. _____ __~.__.~, ~.._____. ___,_._..__.._---- -----__- 80 WHP IAP ,OAP 70 WHT 2500 _ 60 2000 - - 50 LL r fn ~ - ~ 4 ~ ~ ono a 30 1000 - 20 _ 500 10 0 0 Oct-09 Nov-09 Dec-09 Jan-10 Feb-10 aooo _ _ ~DGI - ssoa ~MGI sooo ~PWI a zsoo o ~SWI zooo ~BLPD ~ isoo iooa - - son 0 -.. I~ LJ • ~~L ~~i ~~~~~~ "_ PrtoAcrive D'uylvosric SeavicES, INC_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Air ort Road ~~ , ~.~~ ~ ~~ E Suite C P ~~'~ ~ ~~ ..~ ~~' Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Leak Detection - WLD 24 Aug-09 10-02B EDE 50-029-21248-02 2] ~~ /~3 - - ~? i'°~i - _~ ~ I'r Signed Print Name: Date : _. - - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : - WEBSITE '? C?,Documents and Settings\Diane Williams\Desktop`~Transmit_Conoco.docx WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 2, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1Q -02B Run Date: 7/29/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 O -02B Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 21248 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto U 5 C 9c6 141 3 6900 Arctic Blvd. Anchorage, Alaska 99518 Q 61' Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton. com Date: Signed: Aii NOV 3 n i a ~y PrtoAnive Dinynosric SEnvic~, Inc. • • ~~`LL E.fJ~ ~°RA~~~~T~Q~ To: A~C Christine Mahnken 333 West 7th Auenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MT1~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed eopy of this transmittal letter to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907] 245-8952 1} Caliper Report Q9 Aug-09 1 C~--02B 1 Report / EDE 50-029-212 ~ 2) r,'~'1 ~ 31,JuF09 2L-311 1 Repor~/ EDE 50-029-20469~00 ~ } J ~ ,t~ ,,{j , , r'~ ' '~ ~ ~~ t~~,~ _J~~ et~:ad'~+'~'s~i~"~aW'" ~ t) ;' ^«.' / '~ ;~ ~~~ _ /~' ~- C' ~C'~` ~ ~' . ~ ~ - ~ ~ ~ Signed : i~' ~~( ,~J~- Date ~ - _ ~ _ Print Name: PROACTIVE DIAGNOSTIC SERVICE3, INC., 138 W. INTERNATIOPIAL AIRPORT RD SU{TE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : : ~ nt ,a ~i~:' r. 3; ~~. , : WEBS{TE i;V, ~ ,_~ C:~Documents and Settirigs\Owner~Desktop\ltansmit_Canoco.docac • i Memory Mul~i-~inger Caliper s Log Resulfi,,S Summary Company: ConocoPhitlip~ Alaska, Inc. Well: 1Q-026 Log Date: August 9, 2009 Fi~id: Kuparuk Log No. : 10578 State: Alaska Run No.: 2 API No.: 50-029-2324$-02 Pipe1 Desc.: 4.5" 12.75 Ib. L-80 ABM-EUE Top Log Intvl1.: Surtace Pipe1 Use: 7ubing and Liner Bot. Log Intvl1.: 6,150 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMEIVTS : This caliper data is tied into the boftom of the Muleshoe @ 6,078.70' (Casing Tally dated 01-23-96). This log was run to assess the condRion of the tubing and liner with respect to corrc~sive and mechanical damage. The caliper recordings indicate the 4.5" tubing and liner logged are in good to fair r:ondition, with a maximum recorded wali penetration of 32% recorded at an isolated pit in joint 108 (3,422'). Recorded damage appears as scattered pitting. No significant areas of cross-sectional wall loss ar I.D. restrictions are recorded throughout the tubing and tiner logged. The catiper recordings indicate intermittent areas of slight buckli~g from ~4,000' to ~5,650'. This is the second time a PDS caliper has been run in this well and the 4.5" tubing has been logged. A comparison of the current and previous log (September 23, 2005) indicates no increase in corrosive damage during the time between logs. A comparison graph illustrating the difference of ma~cimum recorded penetrations on a joint-by joint basis between the current and previous log is included in this report. 4.5" TUBING ~ LINER - MAXIMUM RECORDED WALL PENETRATIONS: I~olated pitting ( 32%) Jt. 108 @ 3,422 Ft. (MD) Isolated pitting ( 29%) Jt. 185 @ 5,82$ Ft. (MD) Isolated pitting ( 22%) Jt. 143 ~ 4,494 Ft. (MD) Isolated pitting ( 21%) Jt. 114 @ 3,581 Ft. (MD) No other significant wall penetrations (> 18°k) are recorded throughout the tubing and liner logged. 4.5" TUBING ~ LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas o# cross,sectional wall loss (> 5%) are recorded throughout the tubing and liner togged. 4.5" TUBING 8~ LINER - MAXfMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. Fie1d Engineer; G. Etherton Analyst: C. Waldrop Witness: C. Kennedy ProActive Diagnostic Serrices, Inc. / P.Q. Box 1369, Staffard, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PQS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-23D7 Fax: (907) 659-2314 V ~C- ~~S - I~lc~ ! `6~1~~ • Correlation of Recorded Dama~ ~ Pipe 1 4.5 in (12.2' - 6138.2') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 1 Q-02 B Kuparuk ConocoPhillips Alaska, Inc. USA August 9, 2009 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 15 25 782 50 1569 75 ~ 2355 O 10O 3141 ~ v ~ ~ " ~ .S Z .c c 125 ~ 3928 ~ o p 15t) 4714 17i 5499 191.8 6138 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 191.8 • . ~ Maximum Recorded Penetration ~.- ` ~~ Comparison To Previous Well: 1Q-026 Survey Date: August 9, 2009 Field: Kuparuk Prev. Date: September 23, 2005 Company: ConocoPhillips Alaska, Inc TooL UW MfC 40 No. 213120 Country: USA iuhing: 4.5° 12J5 Ib L-80 ABM-FUE Overlav Max Rec. Pe n. (mils ) 0 5 0 10 0 1 50 20 0 25 U 0.1 10 17 27 37 47 57 fi i 77 8~ ~ ~ 97 z 0 1(~7 _ 117 127 137 147 157 167 1 77 187 - 191 ^August 9, 2009 ^September 23, 2005 (~ iffPrPnrP -100 -5 Diff. in Max. Pen. (mils 0 0 5 ) 0 10 0 ~ ~ 10 ; ~ 17 ~ 27 ~ i 37 ~ 47 ~ ~ ¢ 57 ~ +i 3 6~ ~ 77 ~ 87 ~ ~ ~ 97 Z 0 107 117 ~ 127 137 147 157 th7 177 ~ 187 191 ~E 13 fl 13 26 ~ ~ rp~~l • • PDS Report Overview ~--~ ~. Body Region Analysis Well: 1 Q-026 Survey Date: August 9, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C Waldro -Iubing: Nom.OD Weight Grade & lhread Nom.ll~ Nom. Upset Upper len. Lower len. 4.5 ins 12J5 f L-80 ABM-EUE 3.958 ins 4.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over 1°/~ 10% 20% 40% 85% 85% Number of ~oinls anal sed total = 197 pene. 0 73 120 4 0 0 loss 88 109 0 0 0 0 Damage Confiiguration ( body ) 10 0 isola[ed general line rir~ hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 7 7 0 0 0 0 Damage Pr~le (°~ wall) ~ penetration body ~ metal loss body 0 50 100 0 48 98 148 Bottom of Survey = 191.8 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.8 ppf L-80 ABM-EUE Well: 1 Q-026 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 9, 2009 Joint No. Jt. Depth (Ft.) I'~~n. UF~s~~i (Irn.) Pen. Body (Ins.) I'c~n. °i~~ ~1c~i.il I~~ss ,~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 12 1) 0.02 7 1 3.89 PUP 1 15 ~ 1 O.Q4 14 ! 3.91 2 47 ~~ 0.04 16 4 3.91 3 78 u 0.02 t3 ~ 3 90 4 110 U 0.03 1~~ ~ 3.89 5 141 ~~ 0.03 1~ 3 3.90 6 172 ~~ 0.03 13 1 3.90 7 204 t1 0.04 14 5 3. 9 8 235 ~~ 0.03 ~~ Z 3.89 9 267 ~~ 0.04 1(~ ~t 3.88 10 298 (~ 0.03 1~s _' 3 90 11 330 (1 0.03 11) I 3.8 1 360 ~~ 0.02 ~~ I 3.90 13 391 u 0.02 t, 3.89 14 423 ~~ 0.0 ~~ 3.90 15 454 t~ 0.03 1 t) I 3.88 15.1 486 u 0.0 9 I 3.90 PUP 15.2 492 U 0 0 l) 3.88 4.5" Camco D Ni le 15.3 494 U 0.0 7 ' 3.85 PUP 16 499 U 0.02 ~) I 3.90 17 531 ~) 0.02 ~~ I 3.90 18 562 ~~ 0.03 1 U _' 3.90 19 594 ~~ 0.02 ') I 3.90 20 625 t) 0.02 ~) 1 3.90 21 657 l) 0.03 1 Z _.91 22 688 U 0.03 lu s 3.86 23 719 t) 0.03 12 _' 3.90 24 751 (~ 0.03 11 1 3.88 5 782 (1 0.03 11 ' 3.88 26 814 c~ 0.03 I~~ 3.90 2 7 845 U 0.04 I-1 s 3.90 28 877 ~ 1 0.04 I 5 ~1 3.89 29 908 ~~ 0.03 1 I -J 3.88 30 940 ~) 0.03 1~) _' 3.90 3 971 U 0.03 1 ~ ' 3.89 32 1002 U 0.03 11 _' 3.89 33 1034 l) 0.03 10 ~' .92 34 1065 t 1 0.03 1 l 1 ' 3.88 35 1097 ~~ 0.02 ') I .90 36 1128 U 0.03 Il) -t 3.87 37 1160 u 0.03 1(1 ~ 3.91 38 1191 u 0.02 9 I 3.88 39 1223 U 0.03 I s ~ 3.91 40 1254 l7 0.02 ~) ~' 3.88 1 1286 i~ 0.02 ~> ~ 3.89 42 1317 ~ 1 0.03 11 ~ 1 3.89 43 1349 ~~ 0.02 9 1 3.87 44 1380 i~ 0.03 1 I 1 3.89 45 1411 ~' 0.03 II 3.90 46 1443 0.03 I'> I 3.91 ~ Penetration Body Metal Loss Body Page 1 ~ PDS REPORT JOINT TABI, Pipe: 4.5 in 12.8 ppf L-80 ABM-EUE Well: Body Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: ~ iLATION SHEET 1 Q-02 B Kuparuk ConocoPhillips Alaska, Inc. USA August 9, 2009 Joint No. Jt Depth (Ft.) P~~n. UF~s~~I (In~.) Pen. Body (Ins.) F'c~n. °io ~~1~~I,il I~~ss °~~~ Min. I.D. (Ins.) Comrnents Damage Profile (%wall) 0 50 100 47 1474 ~~ 0.03 I U ' 3.91 48 1506 ~~ 0.04 14 I 3.89 49 1537 U 0.03 ll) I 3.88 50 1569 i? 0.03 11 3.88 51 1600 i~ 0.03 11 3.89 52 1632 U 0.03 1 t~ I 3.88 53 1663 ~! 0.03 1(1 I 3.89 54 1694 ~~ 0.03 1 U ~ 3.86 SS 17 6 t) 0.03 1t1 i 3.89 56 1758 U 0.03 1 U 1 3.90 57 1789 U OA2 9 I 3.88 58 1820 (~ 0.04 15 t 3.90 59 1852 ~~ 0.03 11 I 3.89 60 1883 [ ~ 0.02 8 I 3.90 61 1915 l~ 0.03 1;t ~ 3.89 62 1946 ~~ 0.04 1 b 1 3.90 63 1978 ~~ 0.04 I i '~ 3.90 64 2009 U 0.0 1(1 > 3.88 65 2 41 U 0.03 13 I 3.87 66 2072 U 0.03 11 ~ 3.89 67 2103 ~) 0.03 12 I 3.90 68 2135 t) 0.04 I~ I 392 69 2166 l) 0.02 .' 3.90 70 2198 ~~ 0.03 1 1 ? 3.87 71 2229 l~ 0.04 19 I 3.87 72 2261 U 0.03 12 ~1 3.88 73 2292 ~~ 0.03 13 I 3.91 74 2324 t) 0.03 11 t 3.87 75 2355 O 0.03 11 1 3.88 76 2386 l) 0.04 16 1 3.88 77 2418 ~) 0.03 lu _' 3. 9 78 2449 ~ l 0.03 1 1 I 3.88 79 2481 U 0.02 ~) _' 3.90 80 2512 u 0.04 1~ ~' 3.87 81 2544 tl 0.05 17 3.89 82 2575 U 0.03 13 I 3.89 83 2 06 U 0.03 I t I 3.88 84 2638 i~ 0.03 l;i I 3.88 85 2670 U 0. 3 1 U 1 3.89 86 2701 0 0.03 11 I 3.89 87 2732 U 0.03 12 1 3.86 88 2764 U 0.05 17 I 3.82 8 2796 ~~ 0.02 ~) I 3.91 90 2827 (1 0.04 15 ~' 3.89 91 2858 U 0.04 1(~ I 3.85 92 2890 t~ 0.03 llt I 3.90 93 2921 U 0.03 1 U ? 391 94 2953 ~~ 0.03 111 ' 3.91 95 2984 u 0.03 1~1 3.89 96 3015 u 0.04 16 I 3.87 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 4.5 in 12.8 ppf L-80 ABM-EUE Well: Body Wall: 0.271 in Field: Upset Wail: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • -LATION SHEET 1 Q-02 B Kuparuk ConocoPhillips Alaska, Inc USA August 9, 2009 Joint No. Jt. Depth (R.) I'~~n. I I~„c~t Iln~ j Pen. Body (Ins.) Pen. °4> tilctal I oss `;~> Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 SO 100 97 3047 i~ 0.03 1 1 3.89 98 3078 t J 0.04 1 i 1 3.89 99 311 1 ~ 1 0.03 1O 1 3.91 100 3141 U 0.04 15 1 3.89 101 3173 ~) 0.03 lU I 3.87 102 3204 O 0.04 1 S _' 3.88 103 3236 u 0.05 I i 3 3.88 104 3268 t~ 0.03 i l I 3.88 105 3299 l) 0.05 1; ~ 3.88 106 3330 (1 0.04 1(i I 3.88 107 3362 U 0.03 13 I 3.86 108 3393 O 0.09 i2 -1 '3.8 ~ Isolated ittin . 109 3424 t) 0.03 1 U I 3.89 110 34 6 ~~ 0.03 1~) 1 3.91 111 3488 l~ 0.04 1 E~ 1 3.88 112 3519 ~~ 0.02 ~! i 3.90 113 3550 (~ 0.02 ~i 3.90 114 3581 l~ 0.06 ~l 1 3.88 Isolated ittin . 115 3614 t) 0.03 10 2 3.91 116 3644 ~> 0.04 14 1 3.89 117 3677 c~ 0. 3 9 1 3.93 118 3707 i.1 OA5 17 ? 3.87 1 9 3739 u 0.04 1 ~ i 3.88 120 3770 ~~ 0.02 ti _' 3.90 121 3802 U 0.03 I_' ' 3.88 122 3833 u 0.03 I~~ ' 3.89 123 3865 ~~ 0.02 ts 3.89 124 3896 U 0.04 13 ~i 3.88 125 3928 t~ 0.03 11 > 3.88 126 3959 l) 0.04 15 4 3.90 Sli ht bucklin . 127 3991 U 0.03 10 1 3.89 128 4022 t) 0.03 13 ~'~ 3.87 129 4054 U 0.03 10 _' 3.89 130 4085 ~ 1 0.04 1 i 3.87 131 4117 ~~ 0.02 ti 1 3.90 132 4148 ~~ 0.04 15 > 3.87 133 4180 U 0.0 1 U 1 3.89 134 4211 l) 0.03 ll) 1 3.87 135 4242 l~ 0.04 14 3 3.86 13E> 4274 1) 0.03 1 1 1 3.86 Sli ht bucklin . 137 4305 ~~ 0.04 16 1 3.91 138 4336 ~~ 0.04 I 4 I 3.89 139 4368 ~~ 0.03 I1 I 3.88 140 4399 ~ ~ 0.03 ~I O 3.88 141 4431 U 0.05 18 ~ .90 Shallow ittin . 142 4463 n 0.03 13 ~t 3.92 143 4494 l~ 0.06 21 2 3.87 Is lated ittin . 144 4526 O 0.05 1 i ~~ 3.90 145 4556 ~.! 0.05 1£~ 1 3.84 Shallow ittin . 14b 4588 ~' 0.04 13 1 3.89 ~Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.8 ppf L-80 ABM-EUE Well: 1 Q-02B Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: August 9, 2009 Joint No. Jt. Depth (Ft.) I'~~n. i lF,u~t (In..) Pen. Body (Ins.) Pen. % ~1c~ial I cns ~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 147 4619 ~~ 0.05 1f3 I 3.87 Shallow ittin . 148 4651 (~ 0.04 16 ~ 3.88 149 4683 ~~ 0.03 1 1 1 3.90 150 4714 ~ 1 0. 3 1 1 I 3.89 151 4745 ~~ 0.02 9 I 3.87 15 4777 t~ 0.04 13 ~t 3.87 153 4808 ~~ 0.03 11 5 3.85 154 4840 U 0.0 14 I 3.88 15 4871 U 0.03 I Z ~s 3.89 156 4903 I) 0.0 I I 1 3.86 Sli ht bucklin . 157 4 33 ~~ 0.03 1.~ ~s 3.86 1 8 4965 ~~ 0.04 14 1 3.90 159 4996 U 0.03 1~) 4 3.t38 ~ 160 5028 U 0.04 1 i i 3.86 161 5059 t~ 0.03 1~l I 3.86 162 5091 t~ 0.03 1.? I 3.88 Sli ht bucMi . 163 5122 t~ 0.04 I> ' 3.89 164 5154 ~~ 0.04 I(, ' 3.86 165 5185 ~? 0.04 I> _' 3.89 Lt. De osits. 166 5217 O 0.04 16 1 .88 167 5248 O 0.03 1l1 3 3 84 168 5279 ~~ 0.04 15 U 3.85 Sli htbucklin . 169 5311 ~? 0.03 1~ 1 3.89 170 5342 i~ 0.03 13 ~3 3.86 171 5374 ~> 0.04 13 ~ 3.88 172 5406 ~~ 0.03 13 ~ 3.88 173 5436 l~ 0.04 1~ I 3.87 174 5468 ~) 0.04 14 s 3.85 175 5499 U OA i s 3.86 176 5531 (1 0.02 ti _' 3.87 177 5562 U 0.04 ~14 3.88 178 5594 t) 0.04 13 ' 3.86 179 5625 cl 0.03 1" ? 3.F31 Sli htbucklin . 180 5657 O 0.03 1 i -1 3.89 Sli ht bucklin . 181 5688 U 0.05 I7 3.87 182 5720 ti 0.04 14 ~ 3.89 183 5752 O 0.03 13 ~ 3.87 184 5783 tl 0.03 11 1 3.87 185 5815 t~ .08 <'9 _' 3.89 Isolated ittin . 186 5845 u 0.04 13 ! 3.85 187 5877 ~.) 0.03 11 ~ 3.88 188 5908 ~ 1 0.03 1"3 ' 3.92 189 5939 ~ ~ 0.02 - ' 3.89 190 5971 ~~ 0.02 ~ ' 390 190.1 6003 U 0.02 - I 3.90 PUP 190.2 6009 t~ 0 t) ~.! 3.81 Baker CMU Stidin sleeve 191 6014 i 1 0.04 14 3.87 191.1 6045 U 0.02 9 1 3.87 PUP 191.2 6061 U 0 U i~ N A Tieback 191.3 6063 O 0 O i~ 3.88 Baker Seal Assembl ~ Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 4.5 in 12.8 ppf L-80 ABM-EUE Wel~: E3ody Wall: 0.271 in Field: Upset Wall: 0.271 in Company: Nominal I.D.: 3.958 in Country: Survey Date: • ~LATION SHEET 1 Q-02 B Kuparuk ConocoPhillips Alaska, Inc USA August 9, 2009 Joint No. Jt. Depth (Ft.) I'c~n. ll~~~~~i (In~.) Pen. Body (ins.) Pc~n. `%> ~t~~t,~l Ic~tis `i~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 191.4 6078 c~ 0 l) U N A 4.5" Tubin Taii 191.5 6081 c? U U 4.13 Baker MC Liner Han er 1 1.6 6104 c~ 0.03 11 I 392 PUP 191 J 61 19 ~~ 0 (1 ~~ 3.88 Baker Se I Assembl 191.8 6138 (~ 0 (1 U 550 Baker I_iner Pac,ker Penetration Body Metal Loss Body Page 5 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~S PDS Report Cross Sections ~ Well: 1 Q-02B Survey Date: August 9, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.75 f L-80 ABM-EUE Anal st: C. Waldro ~ Cross Section for Joint 108 at depth 3421.993 ft Too4 speed = 43 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % Tool deviation = 43 ° Finger 20 Penetradon = 0.087 ins ~solated pitting 0.09 ins = 32% Wal) Penetration HIGH SIDE = UP • ~ Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ! ~ ~~ PDS Report Cross Sections ~ Well: 1Q-02B Survey Date: August 9, 2009 Field: Kuparuk Tool Type: UW MFC 40 No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin : 4.5 ins 12.75 f L-80 ABM-EUE Anal st: C. Waldro Cross Section for Joint 185 at depth 5827.543 ft Tool speed = 43 Nomina~ ID = 3.958 Nominal OD = 4.500 Remaining wall area = 99 °/a Tool deviation = 47 ° Finger 32 Peneiration = 0.079 ins ~solated pitting 0.08 ins = 29% Wall Penetration HIGH SIDE = UP L~ • Cross Sections page 2 Aug 09 3~ 03~Sp ARC{7 Ataska, Inc. Sv~sidlary a} Atlar~c Rfefitfafd l3omDa~v CQRP 9DT p.3 ~ W~1.L: 1Q-2A KR!! C}AT~. '1Pt6/88 f A~ 1 Pdt:~C # 17Elfi~ . ~ ~AMPLE7~ DESCRtPI'tC}N OF L~QUlPMEAt7 RUN i.ENG'!'F1 DEPTH 70PS ~ RKB ta Tubin Head/Han er Loclcdown Screws -~lord'~c Ai #T 2i .47 ~MC Gen !Y, 4-7l2" 7ubin Ha er wt dbl in , 4-yt2" EUE fand thd 3.t}7 2f.47 8ce OuE Pu M1tane Needed 24.54 4S JTS 4-1l2°, 12.?5#, L-SQ, ABM-~UE TubE 469.39 24.54 Pu Jac~t 4-1~2", 12.7~#, L-80, A6M~~l~~ Tubin 6,27 . 493.93 i),e~-Ni te ~AMC4 4-ti2" a8 t.and3n N€ le .3.563" O[5> 3_9i4~ Na Go ~.875" #D i.34 5t3p,20 CAMG~S 4•112" ~1ow C~u in , 5.563" OC~, 3.558" ~D 6.27 501.54 175.JTS -ii2' 12.75# L•80 ABM-EUE 7ubin 5484.81 507.8i P Jolnt, 4•1f2" 12.75#, E•80, ABM-E~lE Tubin 6.22 6402.62 S ~ft~+e~Y 6Af~ER GM~J $lidi Sleeve wt GAPACO 3.8l2" iD D8-P~vfile. 3.8~43" EVo Go 4.47 8008=8~ I J'f ~1-1l2.", ~ 2.?5# L-8ti ABM-EUE Tubin' 31.A2 6t113.3 ~ X~ Pu Joint 4•112" 12,~~#, L-8~ 7ub(n , ASM-EUE Sox X BTC f''m 1~.37 $044.73 XQ, 4-i12" A~M-~TC Box X BakerACME Pin 1.~'8 tsOfa{}.TQ, tSA BAKcR Locator, 5-7f16" 40 Lands at btm af l.iner Pkr Settin Sleave' .43 6~&i .3.$ ~ 9AKER Senl Assembi , 2' ot 4-3~4" OD seats at battom S-7,~8" ID --16.88 606i .8i Boitom of Mutesh~e ~>} ~t178.'It? Nota: aced Lc~cator & +AlS ~1' U Seais are 8tabbed into 4-314~ tt~ Seal ~ore near of 4-1t2" Uner. 888 ti25f~6 Liner E}atail. Rem : Stri ~'Yei hts wtth B{oCks: 72144~ tJ . 53K# Dowr~, 6K# Bioeks. Ran ~9i ' ints oi tub; , t~ttifted tt~btnq, s~e~k essemblv, 8 Isant~er v~ti;h 3.&3;3~ pI~S~IC ~~Il~ll. LIS~d B2SC O-LI~ B ~OOO AIP@ dQpe Qn tubin~ T~bu~ is non-caated. ~ ~^ Norrllc R. "#i L?rilli S ervisor. tJorr ~ Breeder.rr i~C~I~08/~9/28~9 18:38 281~327125 PDS Inc ~ ~. ~ CAStNG ! TUBING f LINER C~ETAit, 4-1lz" Manonnre~~jtl~p~ R""cCEIV~ 08109l2009 ~$:3~ 2$24317125 Aug Q9 09 (J3:4Qp PQS lne .. . ~, r, . , CASJNG ! TUBfNG / ~tNEA aETAtL ~T(2" Prodcrcifon LFner . A~CO Ataska, ~nC. . Suk~dlaN o) Auandc tilohBeld Comnan~ DS ~RP 907 6~ p.5 WELL: 't C~-t1ZA KRtJ DA7E: 1 tZ5196 . t n~ 1 Dat':t?C # tTEM ; CQMPLEI'E DESCRIi~I'[~iN OF EGtIlIPMENT RUN ~ I.ENG'1'H DEPTH R~tB to T~~tin Han er Lockddwn Screu+s = 21.47' - NardlC Ri #1 'i'OPS R+F*Il~R }J~ ; ~ 7 ~ ttR+Ff~t rr~Fi~s 'BAKER U~er Pkr Settir Sleeve, 6" Ot~.5-712" It3 8.# 8 ~ 6QS5.09 BA~C~R 4f ~to I!i LEner To Packer, 5-15/18" OD 5-1116" Ib 2.35 Bp81.~? $A~C~f~ ~eai ~ore ~xt~nsiorr, ~.87$" t31~~ ~4.750" (Q - 1+~.49 6063_62 ~" 1~#, L-@0. }~andlin P~u 5" E7f}, 4-1/~'" !L? 10~97 B07B.i 1 BAK~R 'CMC' t~n~r Ha er ~et . 3-3f4" ~? , 4-118" ID 7,~+4 • 6fl89.R~ ~~KER Liner 5wivet, 3-TI8'" 4D, 4-11~2" If3 2.51 5096.52 ?CQ, 5" LTC Bflx X 4-it2" 1~SC7 Pfq .95 5499.t13 XO PU 51oin ~-i t2', ':2.fi#„ L-84 ~..inef [VSCT Box X B7C PiR 15,1 D fi099.99 XO. 4-112" B7C 8ox X Baker AGM~ Ptrt 1.28 ~ 6 t 15.t}& BAKER. ~ocatar, 5-7~1~" G~ Lands ~t t~ottom of Seitin Sleeve .43 5116.35 BAKER Seal !~ssemb . 2' of 4•3/4` ~D s~ats at baitom. 3-7l8" ID - i'T.49 8416.79 ~otWm a# 4-23132' OD Half•1Vluleshoe sef ±2' above Ha~ er belc~w .~» 6133.88 x~-~~~i r t . ~..... .::..:x BAKE~k Uner Pkr Sst~ln Slaeve 6" ~~J, a"-1/2" ID B.i 7 6112.8$ 8Ah(ER 5-1J2" X 7~ '~-i Tto I11' Lcr 7o Pkr 5•T5rtfi" Gb, 5-tl16" ID 2.33 61 i9.03 ~ BAK~R '8a•47' Sea1 Bbre ~xter~sian (5.8?5" OD, 4.75a" !D ~ t 4.52 Bt 21.56 B~K~R 5" X 7" 'CiVEC' Me~han~Cal ! iner k~an er 5-3l4" ~D, 4-1f8" I11 6.75 ~] 35.88 l.in~r' Swivsl a'-7/8" OD, ~-~1~2" ID -2'.46 Bi42,63 5" X 4-iR" Xt~ and X3 Fu 1.~fl 61~5.11 PUP JOIM' ~-il2", 12.6#r L~80; N~GT ~ 8.i5 614fi.11 57 JTS 4-1f2". 1~.6# !.-8Q. t~lSCT l.iner 1822,29 61~2.25 ~7'!~ '3C' t.~ndi~ Ni te 3.812" IQ~ i.15 7974,55 #5 JTS 4i12' 92.6#, l-8a, NSCT Llner 478.0~ 797'5.70 MAR'KEA PlJP Jt?INT, 4•1l2" 1~^.6#~ L~$0~ NS~~' 8.65~ ~ 945f .78 14 „TS 4-1f2", y2.~# L•$a, N8C7 Linec ~ 448.37 @461.43 BAKER l.~rrdln Collar 5" t7D 3.992' :D 1.04 8~~8.80 1 J'f 4-i 72~, ~! 2.f # i.-8~, NSC ~ Liner ~2.1 ~ 891 d.80 BAi4EFt [~au~I~ ~alue Ffvat Coit~r ~" CD, 3.9~2" ID i.04 8942.97 2JT5 +#-1l2° 1~.6~ L-80, NSCT Liner $4.23 8943.97 9AKER Ftaat Shae 5' OQ, 3.992" !t? i.8~ 90t38.2U BUTTOM ~JF LIiV~R SHC}~==> 9C~ t7.flU D 9D1 T aAQ ' Remarks: ~an 89 ~oit~ts 4-1I2" liner. All lirer drifted wit4t 3.833" rabbit. Ail ~infs fi tted with on~ each ROTCC3 6" 8 ttiid Snk~i bt~c38 t~tttralizer a,-~:1 sfatt Caligt exe~~t three icrints t:nm 6248' to 834d'_ Unsr ~a^ ekef CDntai[~1, hpld-t~ow~! sii is set. L.tt~t~R HANCER 131~1tJT ENGACED, l.itt~f was tttft t~f!'~enled. iM~tna Tie.G,e,nL LJnw:-.nr :.. ..... n.,..~,..tr ... ..,.~ o~....:....i ~., ornn .,.,. • MEMORANDUM 'ro: Jim Regg ~~~~~ ~~Z~~~~ P.I. Supervisor FROM: John Crisp Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 14, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Q-02B KUPARLJK RIV UNIT ]Q-02B Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .J~~-- Comm Well Name: KUPARUK RIV i1NIT 1Q-02B Insp Num: mitJCr090713073407 Rel Insp Num: API Well Number: 50-029-21248-02-00 Permit Number: 205-142-0 Inspector Name: John Crisp Inspection Date: ~~12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weil 1Q'02B Type Inj. N TVD so6o IA ao i9oo - isoo i6so ,~ P.T.D 2051420 TypeTest SPT TCSt ~SI 1900 QA 50 380 380 360 Interval 4YRTST P~ F / Tubing 650 700 650 650 NOtes• ~•3 bbl's pumped for test. / ~ ~ . '~'~~ ~'t~~5 i~v-~ I ~U~~.s; ~.~. ~ ~~ ' ~~~ ._ ,~~;~„~._'s~ ~_ ~ ~~ ~~~~ ,t ,~ j Tuesday, July 14, 2009 Page 1 of 1 ~ MEMORANDUM To: Jim Re ? ~Z7,~ P.L Supgrvisor ~~ "/ ~ ~ FROM: John Crisp Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 14, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Q-02B KUPARUK RIV LTNIT 1Q-02B Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV UNIT 1Q-02B Insp Num: mitJCr090713073843 Rel Insp Num: API Well Number: 50-029-21248-02-00 Permit Number: 205-142-0 i Inspector Name: John Crisp Inspection Date: ~/12/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Q-o2B Type Inj. N T~ 5060 jA iizo 203o tsso i~so .~ P.T.D 2051420 TypeTest SPT Test psi 1900 QA 260 370 370 350 Interval 4YRTST P~ F / Tubing 6S0 650 650 650 Notes: •~ bbl pumped for retest. I allowed retest after previous 73 bbl's was pumped & had time for IA to stabilize. No success. ~ ` _ _1 ~ ~1+~, `-~5 pt~SSl.t;~ ~ s~ d p ~~-~ ~.'; ~ ~s /tl~y4` ...3i~, ' l.. ,. Tuesday, July 14, 2009 Page 1 of 1 1Q -02B (PTD 205-142) Report o * ed MITIA Page I of I • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [nl617@conocophillips.com] Sent: Monday, July 13, 2009 3:12 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: 1 Q-02B (PTD 205-142) Report of failed MITIA Attachments: 1 Q-02B schematic.pdf; 1 Q-02B 90 day TIO plot.jpg Jim, Kuparuk injector 1 Q-02B (PTD 205-142) failed an MITIA during the witnessed pad testing on 07/12/09. The well was shut in at the time of testing and will remain shut in while diagnostics are performed. The TIO prior to the test was 650/40/50. The well has been added to the monthly report. It is ConocoPhillips intention to perform diagnostics to identify the leak. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted at that time for continued injection. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters NOV 0 ZUIC Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 <<1 Q-02B schematic.pdf>> <<1 Q-02B 90 day TIO plot.jpg>> - 11/9/2010 CHOKE FTP FTT SAP - OAP T /l/0 Plot - 1Q-02 200 2000 ........... .................................................................... `-- ............................ 150 • 1500 ....................................................................................................................... ............................... E a� 5 100 L ,Y 1000 .................................................................................................. ............................... O .0 U 500 .................. .............� 50 0 1111 1111 jill 144 fill fill i 44i HH 0 i 13- Apr -09 26- Apr -09 09- May -09 22- May -09 04- Jun -09 17- Jun -09 30- Jun -09 Date DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051420 We11 Name/No. KUPARUK R1V UNIT 1Q-02B Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21248-02-00 MD 11501 TVD 6751 Completion Date 11!27!2005 Completion Status 1-OIL Current Status WAGIN UIC~Y~`" REQUIRED INFORMATION ~~ Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR / RES Well Log information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc Directional Survey l ~~ ~ 'I ~ ~~"J" Directional Survey ED D Asc Directional Survey " Directional Survey ~'-'~~ 15269 ~ fSa~6`( LIS Verifcation ~~~. '~og 15269 Induction/Resistivity ;-Log 15269 Induction/Resistivity ~ 15270 LIS Verification 1~ G 1s~~o T~~( V..og 15270 Induction/Resistivity ~bg 15270 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORM/LION Well Cored? YI[~fl \J Chips Received? -Y_L~Ls Analysis `1~-Fa+1-- Received? Samples No Directional Su (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH Scale Media No Start Stop CH Received Comments 0 11500 Open 1 Q-02B, 1 Q-026 PB1, 1 Q- 026 L1 on diskette 0 11500 Open 10-02B 0 10552 Open 1 Q-028, 1 Q-026 P61, 1 O- 026 L1 on diskette 0 10552 Open 1Q-02B PB1 8548 11501 Open 7/6/2007 LIS Veri, GR, ROP w/Graphics TIF and META 25 Blu 8548 11501 Open 7/6/2007 MD Ind. Res, GR 25 Blu 8548 11501 Open 7/6/2007 TVD Ind. Res, GR 8548 10552 Open 7/8/2007 PB1 LIS Veri, GR, ROP w/Graphics TIF and META 25 Blu 8548 10552 Open 7/6/2007 P61 TVD Ind. Res, GR 25 Blu 8548 10552 Open 7/6/2007 P61 MD Ind. Res, GR Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops Y / N DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051420 Well Name/No. KUPARUK RIV UNIT 1Q-02B Operator CONOCOPHILLIPS ALASKA INC MD 11501 TVD 6751 Completion Date 11/27/2005 Completion Status 1-OIL Current Status WAGIN Comments: API No. 50-029-21248-02-00 UIC Y • i Transmittal Form INTEQ To: AOGCC 333 West 7`h Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 1Q-02B, 1Q-02BL1,1Q-02BPB1 L7 r/.i111 BAKER HUGHES Anchorage GEOScience Center Contains the following: 3 LDWG Compact Disc (Includes Graphic Image files) 3 LDWG lister summary 3 bluelines - MPR-DIR_md Log 3 bluelines - MPR-DIR tvd Log LAC Job#: 1011834 Sent By: Cosetta Todirica D 0 '~~ ~ q ~~ ~ ~ ZQQ7 Received By: ~ Date: ~ 3J ~ 1 ~ Gag Cans. rr-is~cra AnC41~C~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY _ FAX: (907) 267-6623 ~ ~''"`~ ~~'~ _ ~~ ~ Baker Hughes INTEQ 7260 Homer Drive ~ ~~~ 1 Anchorage, Alaska _ 99518 ~ 1 ~ ~~-% Direct: (907) 267-6612 ~,~~. ~ ~~~ Y ~,~~ PAX: (907) 267-6623 -:( pmrwu~uw»nm rru .,.,.. ~.~ ~.. ul . ~~~ ___ ___ _~:~~ ~~ ,` ~~ ~- k. _. ~'_ ,, ~~_.., u.:.~__ t S'~,_ ~: ~~ - - ~" `~ 4~ ~~~` IV~V • STATE OF ALASKA ALASKA OlL AND GAS CONSERVATION COMM{SSION ;,,~t REPORT OF SUNDRY WELL OPERATIONS - 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^/ Prod to WAG' .Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory . ^ 205-142 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21248-02 7. KB Elevation (ft): 9. Well Name and Number. RKB 78' 1Q-02B 8. Property Designation: 10. Field/Pool(s): ALD 025634 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 11439' feet true vertical 6735' feet Plugs (measured) Effective Depth measured 11501 ' feet Junk (measured) true vertical 6751 ' feet Casing Length. _ Size MD TVD Burst _ _ .,~. _._ Collapse Structural CONDUCTOR 100' 16" 100' 100' SURFACE 3752' 9-5/8" 3830' 351 T PRODUCTION 6190' 7" 6268' 5205' LINER 10-02A 2955' 4-1 /2" 9010' 6639' WINDOW 1' 3-1/2" 8540' Perforation depth: Measured depth: 8369-8384', slotted liner 9623-11499' true vertical depth: 6407 - 641 T, 6686' - 6750' Tubing (size, grade, and measured depth} 4-1/2" , L-80, 6061' MD. Packers &SSSV (type & measured depth} no packer SSSV=NIP SSSV= 500' _ 12. Stimulation or cement squeeze summary: , Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl Casin Pressure. Tubin Pressure Prior to well operation 51 451 9 200 173 Subsequent to operation 4134 1100 1714 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 17. l hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 306-317 contact .Bob Christensen /Bob Buchholz Printed Name be . Chri ensen Title Production Engineering Technician Signature ~Gr~~~)aSd Phone 659-7535 Date 1~ ~ ~ ~ , Form 10-404 Revised 04/2004. ~ ~ ~ ~ ~ ~ ; Submit Original Only. • 1 Q-02B DESCRtPTiON OF WORK COMPLETED SUMMARY " Date Event Summary 10!19/06 Comrrienced'Injection Service I Q-02B (PTD 2051420) MITIA Subject: 1Q-02B(PTD 2051420) MITIA From: NSK Problem Well Supv ~n1617@conocophillips.com> llate: Fri, 10 Nov 200619:05:38 -0900 To: Thomas \launder ~=ton1 maunder(u';admin.state.ak.us==, t~ob fleckenstcinla::admin.state.ak.us, ,Iamcs Ke«<~~ ~ jim _rc~~~~~r;admin.statc.ak.us ~ _ Tom, Jim, & Bob, Attached is a passing MITIA for 1 Q-02B (PTD 2051420) as witnessed today by John Spaulding. This is an initial MITIA post conversion from production to injection. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «MIT KRU 1Q-02 11-10-06.x1s» _ Content-Description: MIT KRU 1Q-02 11-10-06.x1s MIT KRU 1Q-02 11-10-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 I of 1 11/27/2006 9:59 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSfON Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT! PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1 Q 11 /10/06 Rogers !Noble John Spaulding Packer De th Pretest Initial 15 Min. 30 Min. Well 1 Q-02B T e In'. W TVD 5,060' Tubing 1390 1400 1400 1400 Interval I P.T.D. 2051420 Ty e test P Test si 1500 Casing 350 2050 1960 1940 P!F P Notes: Converted from prod to inj. Started injecting 10/19/06. OA 530 650 700 700 45 min T/I/O: 1400 / 1930 / 700 Well Ty e In~. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. T etest Test si Casin P/F Notes: OA Well T pe In". TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well T pe In~. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e Inj. TVD Tubing {nterval P.T.D. T etest Test si Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. T etest Test si Casing P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. Ty etest Test si Casin P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test I =Initial Test 4 =Four Year Cycie V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9(1105 MIT KRU 1Q-02 11-10-06.x{s • 1 ,~ ~ , ~~ j ~, '~ ` ' - - FRANK H. MURKOWSKI, GOVERNOR ~a tp~1[~-7~A OIL A1~D G~-,S 333 W. T" AVENUE, SUITE 100 COI~TSERQA~`IO11T CODi1~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1Q-02B Sundry Number: 306-317 Dear Mr. Buchholz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~i` Cathy P. Foerster Commissioner DATED this 13 day of October, 2006 Encl. w5 _ ~~(a • Conoco/Phillips September 11, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 • Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 14E~ErVEQ SEP 1 2 Zoos Alaska Oil & Gas Cons. Commission Anchorage Subject: Sundry Applications for Proposed Change of Well Class ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1 Q-02B and 1(~IJ 1. ~ 4 , ~ ~` --- ~t~ -az.8 L / .~ ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on West Sak wells 1J-127, 1J-127L1, 1J-127L2, 1J-184, 1J-184L1. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Robert W. Buchholz Attachments: 10-403 Forms ~ ST ~, a ~ RE~EIVE~ ATE OF ALASKA ~ Z ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 2 c.ill~~ APPLICATION FOR SUNDRY APPROV Arska qil & Gas Cons. Commission 20 AAC 25.280 ~ _~_.... 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ /~ Qf' Time Extension ^ ~ / f ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ l Re-enter Suspended Well ^ '~"'' C./Q •~ 'D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill umber: ConoCOPhillips Alaska, Inc. Development ^/ Exploratory ^ 205-142 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21248-02 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 1Q-02B - 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field/Pool(s): ALD 025634 RKB 78' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total a th D (ft : Total De th D (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11501' 6751' Casing !t't ~ Length Size MD TVD Burst Collapse CONDUCTOR 100' 16" 100' 100' SURFACE 3752' 9-5/8" 3830' 3517' PRODUCTION 6190' 7" 6268' 5205' LINER 10-02A 2855' 4-1/2" 9010' 6639' WINDOW 1' 3-1 /2" 8540' 6517' Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8369-8384', slotted liner 9623-11499' 6407' - 6417', 6686' - 6750' ~-1 i2" (_-80 6061' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 7, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature ~~ Phone 659-7535 Date y/~~o 6 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~~ ' 3` Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~5 ~~~- ~ ~ ~ ~. 1006 Subsequent Form Required: L•.-~ 1 ~` CIO' ~t APPROVED BY /p( / D ` Approved by: (~._ t/l - COMMISSIONER THE COMMISSION Date: lU ( Form 10-403 Revved 06/2006 ~ Q ~ Submit in D plicate 1 Q-02B DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Alternating Gas (WAG) Injection service in Kuparuk Dual-lateral Well 1Q-02B. This well was pre-produced since January 15, 2006. Lateral 1Q-026 will provide pressure support to offset producers. / The 9-5/8" Surface casing (3830' and ! 3517' tvd) was cemented with 1000 sx Coldset III followed by 420 sx Coldset I. The 7" Intermediate casing (8119' and / 6247') was cemented with 550 sx Class G followed by 250 sx Coldset I. The injection tubing/casing annulus is isolated via Baker 5-1/2" X 7" HyFlo III Liner Top Packer with Baker Sealbore Extension located @ 6061' and / 5060' tvd. Following a liner setting sleeve, this well also contains a Baker 5-1/2" X 7" HyFlo III Liner Top Packer with Baker 80-47 Sealbore Extension located @ 6119' and / 5100' tvd. ~s: :t~ TUBING lasost, OD:4.500, ID:3.958) • ~a~c~~~h~~[ips ~~~ska ~~~> TTL --- Isosasost, OD:4.500) Per( 'f ;, KRU 1 Q-02B API: 500292124802 Well T : PROD Angle TS: deg SSSV T e: NIPPLE Ori Com letion: 11/27!2005 An le TD: 75 d 11439 Annular Fluid: Last WlO: Rev Reason: Show TVDs Reference Lo Ref Lo Date: Last U date: 7l25I2006 Last Ta _ TD: 11501 itK6 Last Tag Date: Max Hole Angle: Casin~Strin~COMMON STRINGS Descri ion Size To 95 deg 9.97.7 _ Bottom ~ND Wt Grade ~ Thread CONDUCTOR 16.000 0 100 100 62.50 H-40 WELDED SURFACE 9.625 0 3830 3517 36.00 J-55 PRODUCTION 7.000 0 6268 5205 26.00 J-55 LINER 10-02A 4.500 6055 9010 6639 12.60 L-80 LINER 10-02BL1 TOP 3.188 8496 8705 6607 6.16 L-80 TCII WINDOW 4.000 8539 8540 6517 6.16 L-80 LINER 10-02BL1 TOP 2.875 8705 9609 6684 6.16 L-80 STL LINER 1 O-02B Tobin Stringy UBING 5 9- Size ~_ T~ 4 500 0 Perforations Summa - - - Interval ND 2.875 9609 _ 11501 11501 6.16 ~ - ~ I - - _ ~ - Bottom ND Wt Grade I 6061 5060 12.75 L-80 ~ - T Zone Status Ft ~ SPF Date T e L-80 STL _ Thread ABM E U E Comment 8369 - 8384 6407 - 6417 15 4 10119!1998 RPERF 1Q-02A Perfs above 1 O-02B liners 9623 - 11499 Other (plus, De th ND 6686_-11499 _ 1876 9.9 11/1812.005 SLOTS STL SLO_ TT__ED LINE_ R _ a uip., etc.) -COMMON JEWELRY ~ - - - -- - - T e Descri tion ID 500 500 NIP CAMCO'DB' LANDING NIPPLE 3.875 6009 5024 SLEEVE-C BAKER CMU SLIDING SLEEVE -CLOSED 2/16/2006 3.812 6009 5024 PUMP 4 1/2" CAMCO D-6 LOCK ON JET PUMP (SN# PH-1135) 67" OVER ALL 10C-RATIO, 10 NOZZLE , #12 THROAT set 1/8/2006 0.000 6055 5056 TIEBACK BAKER 5.500 6060 5059 TTL TUBING TAIL 3.958 6061 5060 PACKER BAKER'HYFLO' III' PACKER 5.063 6113 5096 Setting Sleeve BAKER LINER SETTING SLEEVE 5.500 6119 5100 PACKER BAKER'HYFLO' III' PACKER 5.063 7975 6154 NIP OTIS'x LANDING NIPPLE 3.812 8705 6607 XO 2.875 8883 Other ( De th 6635 plu s, ND RETAINER equi ., etc T e BAKER CEMENT RETAINER (2/3/1996) _ _ . !O-02B LINER JEWELRY _ Descri tion _ _ 0.0. 00 _ ID 9609 6684 BILLET WEATHERFORDLINER BELLET w/GS PROFILE & 3.5' PUP 2.441 11499 Gener ..Date 11499 SHOE ~_ al Notes Note _ - - - - - - - 1.000 - 1/27/200 MULTI-LATERAL WELL w/SIDETRACK 10-02B, LATERAL LEG 10-02BL1 MEC:iANICAI, INTEGRITY :Z:PORT ~ ~®~~ `~ 1 BUD u:.__ : OPER ~ FZELD C1~(~S 1L~po.N~ .G n.r~~~,. ~ i.~LL NIJMEF,R ~~-O~C~ - ~~..~ n~ LL DAT~_ TD : Imo.. TVD ; ?BTD : ?ID =T`~TD ~..Z~-car'" a~~- ~~1~" Shoe: ~®LC~ MD TVD; "~: ~f~SS?~ :4"i ~_.-:er . r~2~4s'" Shoe : t~bS7C '~ TVT ; :CP . ?•~ ~'~J _ ~ ,~ -:iD'-='o ~ ~~ PaC1Cer / p toOtp` ''~ T'J~i ; Set at ~~ ~ t ole Size ~ ~~~ and ~7'~~1 Perfs `'!®1~~ 11 ~ctrS to ta y ~ j ~~o~-W~~ ~ ~~53~ ' WS,1 } ~ o .. ~ , ~ R ~ ~Cr..P?3 =C~_._, iNTEGRSTY - P 4~T # I rnrulus Press Test: _~ 15 min ~0 min Comments '_~' CHP N ± C~~ '_NTEGRTTY _ PART # Z ~ ~ ._..~ ~ .~ J~~ ! el~,~o t r c.. ~ S~vrc~Z. Cement Volumes r r~~t. Liner ~-1~~~a`~ Cs~ DV ~~ C~,t -ro1 to cover oer_s _ _eoretical TOC Cement Bond Log (Yes or No) L. In AOGCC File ~j C9L Evaluation, zone above perfs G.~'C' c,~JV~~ w~~ O~~ ~-~1 ~ 1145" ~ S ins ~~ ~ S~ wS`~ P: ~ `i0 P P ~~ ~ 1n~~ ~7~c'i'F-pe`p:~~o~S Sc ~ C~ ~cJ ~"C Production Log: Type Evaluation ~ ZS s b Fpo c~c' ~ c~. i ~~ e~'vU. S CONCLJS ~ Ot3S j Part #1 ?ar~ T2. ~~0~ TOE -~ .. ~ • ~u ~ ~-~-- o?A q 5 -o s q g- '~-•-_ MECHANICAL INTEGRITY REPORT• SPUD DATE : : ~ f•31 ~ b (,5 7~ OPER ~ FIELD ~~~ -L.~.y RIG RELEASE : 8~ 11 ~ q !~ kTELL NUMBER 9S' OI L1't _,~ WELL DATA TD:_ 9~~~ .MD.. 6~3o TVD; PBTD: 8$~,~ 1'ID 6~ S TVD Casing : ~" ~+~ ~ Shoe : {,Z6'~ MD TVD; DV : MD -TVD 1~'aa 9a-o T~ Liner :.~ Z•b~ _ Shoes boys MD TVD; TOP ; MD ' TVD Tubing: `l~ Z, Packer b~~3 • I~ID TVD f Set at S'.S Hole Size 8%i b'/~ and 6•;zS = Perfs 84~}o to e~z,~ MECHANICAL INTEGRITY - PART #1 • Annulus Press Tests IP = 15 mi ; 30 min Comments: MECHANICAL INTEGRITY -PART #2 Cement Volumes : Amt. Line ~ 1~ s~ z Csg `30o Sx DV Cmt vol to cover perfs 9.3 ~ 900 - ss~~JX .o ~~~ ~'~i -~.6~'= •x331 Theoretical TOC 6'/g , . i~ ~ a s'~I~ C ~fl~-F' Cement Bond • CBL Evaluat~t ,.z. 9ololx •14`6 -i 5~.~ --- T~J•' - ~ C J 13' S~.4~ y . o't3oS-'~ _ 4S --- ~og (Yes or No)~_; In AOGCC File L.(i? ion, zone above perfs ~ES~~gZ~, cx•.i~ fl~o t~E. Produ~.tion Log: Type ; Evaluation ~CONC SIONS : ~~••- TS` Z~~<cr.~~c) ~ ~©v~,~E---~~ P t # 1 : (~ ~ u~G C"'- CT"`-5f~ ~ ..- ~c-`t tr~f e ~ C~CIh'\~C1(~^ic' \ tl~-C ~ ~~-\~ ~~tb v~ ~'~~~ -O Cam. rev, 05/20/87 1 ~v~~CQd~S . /Part #2: MI ~5 (n,dycr~i-t 6,p il~S~t~~'2~'L. ~~~ C.028 • ~or~ocoPh ~ I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 2, 2006 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'" Avenue Suite 100 Anchorage, Alaska 99501 Dear Tom: ~~~~u~~ ~cro~zoas Alaska Uil & Gas Cons. COQmission Anchorage Recently you requested information for a cement squeeze operation performed on 1 Q-02A (PTD# 95-194). Please see the attached Well History Report for the dates 1/29/96 through 8/11/96. This information should complete your records for this operation. Please note also that a high pressure breakdown was pumped on the A Sand perforations on 9/19/96. Information for this job is also included in the Well History Report. The A Sand perforations were subsequently squeezed under Sundry number 305-287. While reviewing the 1 Q-02A well file to answer your request above, I could not find a 10-404 for perforating the C-sand from 8369' to 8384' RKB. This interval was perforated on 10/19198, and the perforations were subsequently squeezed under Sundry number 305-287.. The well was sidetracked under this Sundry and became 1 Q-02B. I have attached the Well Service Report for the perforating operation in 1998 for your records. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. Gober Wells Engineer CPAI Drilling and Wells ~ • C~'11 Well History 1Q-02A :500292124801:10/2/2006 10/19/1998 PERFORATE C SANDS FROM 8369' TO 8384' W/ 2 1/2" HSD, 4 SPF. 180 DEGREE PHASING +/- 90 FROM LOW SIDE. 10/18/1998 DRIFT TUBING WITH 2.62" X 20' HOLLOW CARRIER TO 8720'WLM. [TAG] 09/19/1996 PUMPED HIGH PRESSURE BREAKDOWN WITH 2240 BBLS SEAWATER AND 11,976# 20/40 PROPPANT. HAD GOOD BREAKDOWN IN FIRST HPBD STAGE. 08/11/1996 SHOT'A' SAND PERF INTERVAL 8662'-8673', 8676'-8681', 8686'-8720', & 8802'-8808' USING 2-7/8" HSD W/ DP CHARGES, 4 SPF, AND 180 DEG PH. 08/07/1996 RAN CEMENT BOND LOG FROM 8879 TO 7400'---HAD SEVERE PULL AT 8000'---CEMENT QUALITY IS POOR EXCEPT FOR FROM 8842' TO 8846', FROM 8294' TO 8327', AND FROM 8202' TO 8212'. '~ -~ ~ ~ '° ~~ CEMENT IS FAIR FROM 8100' TO 8230' 08/06/1996 RUN CEMENT BOND LOG---UNABLE TO OBTAIN LOG; WELL WASN'T DEAD. SWS HAD NO PRESSURE CONTROL EQUIP TO HANDLE 600 PSI; PERFS ARE LEAKING. 08/01/1996 DRILLED THE CEMENT RETAINER @ 8700' & PUSHED TO 8883'. REAMED AND BACKREAMED FROM 7750 TO 8883'. FREEZE PREOTECTED WITH DIESEL FROM 2500' TO SURFACE. 07131!1996 DRILLED 154' OF CEMENT FROM 8231 TO 8385'. DRILLED CEMENT RETAINER @ 8385'. DRILLED 60' OF CEMENT FROM 8385 TO 8445'. DRILLED BRIDGE PLUG @ 8470' & PUSHED TO 8700' (8705' CTM). PRESSURE TESTED SQUEEZE PERFS (8203-8205 & 8440-8442') TO 2800 PSI. BLED OFF TO 2500 PSI 1N 15 MINUTES. UNABLE TO ESTABLISH INJECTION INTO SQUEEZE PERFS. (IN PROGRESS) 07/30/1996 DRILLED CEMENT FROM 8000' TO 8231' CTM. PRESSURE TESTED SQZE PERFS 8203-8205' TO 2800 PSI. UNABLE TO ESTABLISH INJECTION INTO PERFS. PRESSURE BLEEDS OFF FROM 2800 PSI TO 2540 PSI IN 15 MNUTES. 07/29/1996 DRILLED OUT CEMENT FROM 7808' TO 8003', PUMPED 15 BBLS BIOZAN FOLLOWED BY SLICK SEAWATER FOR CLEAN UP PULLING OUT OF HOLE. PUMPED 1185 BBBLS SLICK SEAWATER 07/07/1996 DRILL HARD CEMENT FROM 7720' - 7800' CTM W/3.75" MILL AND 2-7/8" MOTOR. AVERAGE ROP = 15 FT/HR. FREEZE PROTECT TUBING FROM 2000' TO SURFACE W/DIESEL. • • 07!06!1996 SQUEEZED PERF5 FROM 8203' - 8205' RKB. PUMPED TOTAL OF 21 BBLS CEMENT. SQUEEZED AWAY 14 BBLS AND BUILT SQUEEZE PRESSURE TO 3000#. ATTEMPT TO CLEAN OUT REMAINING CEMENT W/BIOZAN AND TAGGED UP AT 7730' RKB (2 HRS BEFORE THICKENING TIME OF CEMENT). 07/05/1996 TAGGED X-NIPPLE @ 7956' WL 7975' RKB. TD WITH 2.80" SWAGE IS 8232' WL 8251' RKB. 06129/1996 PRESSURE TESTED UPPER SQUEEZE PERFS. ABLE TO INJECT 0.6 BPM AT 3000 PSI. 06/27/1996 CEMENTED THE 4-1/2" LINER W/10 BBLS CL G BY CIRCULATING THROUGH PERFS 8440-8442' & TAKING RETURNS OUT THE PERFS 8203-8205'. FREEZE PROTECTED THE 4-1/2" TBG FROM 2100' TO SURFACE W/DIESEL. 06/26/1996 SET HES FAS-DRILL BRIDGE PLUG @ 8470', SHOT SQZ PERF F/ 8440'-8442' USING 3-3/8" HOLLOW CASE CARRIER W/ BH CHARGES, 6 SPF, & 60 DEG PH, AND SET HES FAS-DRILL CEMENT RETAINER @ 8385' 06/1511996 STUNG INTO CR @ 8700' RKB. UNABLE TO PUMP INTO PERFS 8725 - 8727' W/4000 PSI SURFACE PRESSURE. POH W/STINGER & FREEZE PROTECTED 4-1/2" TUBING FROM 2300' TO SRFACE W/DIESEL. 06/14/1996 SHOT SQUEEZE PERF @ 8725'-8727' (REF GR DATED 1/29/96) USING 3-3/8" HOLLOW CASE CARRIER W/ BH CHARGES, 6 SPF, AND 60 DEG PH. RAN 3.75" GAUGE RING /JUNK BASKET TO 8700', AND SET HES 4-1/2" FAS-DRILL CMT RETAINER @ 8700' (REF GR DATED 1/29/96) 05/04/1996 SPOT 3.5 BBL - 17 PPG BARITE/BIOZAN PILL OFF BOTTOM (8880' CTM}; TOP OF PILL @ 8610'. 02/04/1996 SET CEMENT RETAINER @ 8883' ,TAGGED MUD AT 8885', TIGHT SPOT AT 6100'. ATTEMPT TO CEMENT LINER THRU RETAINER AT 8883' RKB. UNABLE TO ESTABLISH INJECTION RATE BELOW RETAINER. 02/03!1996 ATTEMPT TO CEMENT LINER THRU RETAINER AT 8883' RKB. UNABLE TO ESTABLISH INJECTION RATE BELOW RETAINER. 02/02/1996 BAIL DRLG MUD & FM SAND TO 8901'. DRIFT TUB. W/ 3.773" SWAGE TO 8896'. 02/01/1996 COULD NOT GET PAST 6100'JUST BELOW SEAL BORE WITH 3.63 JUNK BASKET AND GAUGE RING. TIED INTO JEWELRY AND CORRELATED SET DOWN DEPTH BACK TO TBG. TALLY. UNABLE TO SET RETAINER. 01/31/1996 CLEANED OUT MUD/SAND DOWN TO 8910' CTM. PUMPED TOTAL OF 416 BBLS (290 BBLS SW, 126 BBLS DIESEL). RETURNS TOTAL 410 BBLS. SUSPEND JOB DUE TO HIGH WINDS. • • 01130/1996 BAILED DRLG MUD & FINE FM SD FROM 8755' TO 8816' WLM. 01/29/1996 PERF INTERVAL 8903'-8905' AND 8203'-8205' USING 3-3/8" HOLLOW CARRIER W/ BH CHARGES, 6 SPF, & 60 DEG PH. UNABLE TO SET CMT RETAINER; COULD NOT GET GAUGE RING/JUNK BASKET BELOW 8875'. • • Gober, Howard From: Alisup-Drake, Sharon K Sent: Thursday, September 14, 2006 10:20 AM To: Gober, Howard Subject: FW: 1 Q-O2A (195-194) Thanks, Sharon office phone: 263-4612 fax: 265-6224. -----Original Message----- From: Thomas Maunder [mailto: Sent: Thursday, September 14, To: Allsup-Drake, Sharon K Subject: 1Q-02A (195-194) tom maunder@admin.state.ak.us] 2006 9:48 AM Sharon, I was reviewing sundry applications to convert 1Q-02B (205-142) and 1Q-02BL1 (205-186) from producers to injectors. As part of that review I was looking at 1Q-02A specifically the liner operations and particularly the squeeze necessary due to problems. There is not a lot of information in the file on the squeeze performed sometime around February 1996. Sorry to ask for such old information. Can you get me the information on this activity? It is important as I complete the assessments I need to do to recommend approving the conversion. Your assistance is greatly appreciated. Tom Maunder, PE AOGCC DECEIVED STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMSION !=Erg 0 2 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG fsska Oil ~IrG~So~uc~~~01t ~nc~iar 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 zoAAC2s.,lo ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 11/27/2005 ' 12. Permit to Drill Number 205-142 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 11/8/2005 13. API Number 50-029-21248-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11!18/2005 ~ 14. Well Name and Number: Kuparuk 1Q-02B ' 1206 FNL, 1175 FEL, SEC. 26, T12N, R09E, UM Top of Productive Horizon: 560' FSL, 2264' FEL, SEC. 24, T12N, R09E, UM g. KB Elevation (ft): 78' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 3126' FSL, 3192' FWL, SEC. 24, T12N, R09E, UM 9. Plug Back Depth (MD+TVD) 11501 + 6751 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528448 ~ y- 5984667 "Zone- ASP4 10. Total Depth (MD+TVD) ~ 11501 + 6751 Ft 16. Property Designation: ADL 025634 TPI: x- 532631 y- 5986450 Zone- ASP4 Total Depth: x- 532795 y- 5989017 Zone- ASP4 11 • Depth where SSSV set 500' MD 17. Land Use Permit: ------ ----- --------- ----------~ f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness o Permafrost 1380' (Approx.) 21. Logs Run: ~~~o-,,~, MWD GR/RES 8539 ~/r~D~ 6~~G ' 7-VD ,~-, z•3•oh 2. ASING, LINER AND EMENTING ECORD CASING ETTINCi' EPTH MD ETTINO EPTH TVD HOLE - OUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE .CEMENTING RECORD PULLEp 2-7/8" 6.16# L-80 9609' 11501' 6684 6751 4-1/8" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-718".Slotted Section Note: 4-1/2", 12.75#, L-80 6061' 6061' MD TVD MD TVD 9623' - 11499' 6686' - 6750' Well Branch Well Branch 1Q-02B Departs 1Q-02B is not 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. FrDm Well DlreCtly h ibl B DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ranc Access e 1Q-o2Bt_1, PTD Freeze Protect with 20 Bbls of McOH # 205-186, at 8539' MD (6516' TVD) 26. PRODUCTION TEST Date First Production: Reported on 10-02BL1 Method of Operation (Flowing, Gas Lift, etc.): See 10-026L1 10-407 (Dated 01-27-06, PTD 205-186) for Production & Test Data Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULAreD 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). i_ Submit core chips; if none, state "none". - - s None ~ ~~~ ~c ~ (? ~ ~1)~6 ~ -~~- ~-Za .",~ Form 10-407 Revised 12/2003 ' ~ g"`~ ~ /1 ~ ~{ (;~I~IUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk A6 8647' 6580' None Kuparuk A5 8660' 6586' Kuparuk A4 8678' 6595' Kuparuk A3 8702' 6606' Kuparuk A4 (Invert) 10272' 6685' Kuparuk A3 (Invert) 10745' 6693' Kuparuk A4 10947' 6692' Kuparuk A4 1 i 050' 6696' Kuparuk A3 11240' 6706' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed ~ ~ O~ e Title Technical Assistant Date l O V~ Terrie Hubbl Kuparuk 1 Q-026 205-142 Prepared ey Name/Number Terrie Hubble, 564-4628 Well Number permit No. / A royal No. Drilling Engineer: Aras Worthington, 440-7692 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 above 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 welt 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, or Other (explain). ITEM 27: If no cores taken, indicate "None". 1rEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of i:6 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!27/2005 Rig Name: NORDIC 2 Rig Number: Date `From - To Hours' Task Gode NPT Phase Description of Operations 11/6/2005 00:00 - 01:30 1.50 MOB P PRE ND BOPE and secure in cellar for move. NU tree cap. Pressure test to 500 psi and 4000 psi with diesel. Passed ok. 01:30 - 01:45 0.25 MOB P PRE Prepare to move rig off of 10-04 and onto 10-02. Spin tires to warm moving system. Move cuttings box, and other equipment out of the way. Break hardline to tiger tank. 01:45 - 02:00 0.25 MOB P PRE Hold PJSM Re: Moving from 10-04 to 10-02. Discuss job assignments. Place block between rig and wellhead. Note -Due to time adjustment, Accept rig at 02:00. 02:00 - 02:45 0.75 MOB P PRE Move rig from 10-04 and stage in front of 10-02. 02:45 - 03:30 0.75 MOB P PRE Place Herculite around wellhead. Move rig mats from 10-04 to 10-02. Shut in well on driller side of 10-02 (Pad Operator). 03:30 - 03:45 0.25 MOB P PRE PJSM prior to moving over well. Attended by all rig hands, MWD hand, TL, TP, WSL, DSO. 03:45 - 04:15 0.50 MOB P PRE Move rig over well 10-02. 04:15 - 05:00 0.75 RIGU P PRE Set rig down over well. Begin rigging up. 05:00 - 05:45 0.75 BOPSU P PRE Begin NU ROPE. 05:45 - 06:15 0.50 BOPSU P PRE Hold Safety Standdown with day crews in conjuction with Tech Limit meeting. Discussed recent field accidents, increased safety awareness with the cold/dark winter weather conditions. Reviewed our commentment to safety on the rig and present working tasks and conditions. Also reviewed hazards we will need to deal with on this particular well concerning pressure deployment of tools. 06:15 -06:30 0.25 BOPSU P PRE After crew changeout held PJSM and reviewed "SiMOPS Plan" guide to swapping rig over to 2-3/8" coil and NU BOP's. Gave out job assignments to individual crew members and or teams. 06:30 - 12:00 5.50 BOPSU P PRE Install XO flange to BOP stack for this well. Lift reel into reef house and secure. (Will need to allow it to warm-up). Take on 480 bbls of 8.9ppg used Flo-Pro that was in storage at MI. NU BOP stack. Start working on injector changing out gripper blocks from 2" to 2-3/8". 12:00 - 13:30 1.50 BOPSU P PRE Nordic crew change day. Oncoming crews briefed about present work and reviewed SIMOPS Plan. Continue NU BOP choke/kill lines. Continue with injector gripper block swp. Grease choke manifold valves. Prep to test BOP's. Empty 2 upright Flo-Pro tanks in Tank Farm and prep to move tanks to new Tank Farm location which will be out of the way of Nordic #3 operations. 13:30 - 17:30 4.00 BOPSU P PRE Test ROPE. AOGCC witnessing waived by Chuck Shelve. Test 250/low 4000/high. Suspend working on injector until all rams were tested then resumed changing gripper blocks. Finished Tank Farm move. Install internal grapple & pull cable into end of coil. Drawdown test accumulator. Finished installing gripper blocks. 17:30- 18:QO 0.50 RIGU P PRE Start on gooseneck change over. 18:00 - 18:20 0.33 RIGU P PRE Pre spud meeting with oncoming night tour and Aras Worthington from Anchorage office. 18:20 - 18:45 0.42 RIGU P PRE Crew change. 18:45 - 19:45 1.00 RIGU P PRE Hold Safety Stand down with night tour. Discuss recent inicidents in the rotary world that could have resulted in serious injuries. Discussed complacency, and how safety is a journey, Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 2 of 16 Opelratons Summary Report Legal Well Name: 10-02 Common Well Name: 10-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Houls 'Task Code NPT Phase Description; of Operations 11/6/2005 18:45 - 19:45 1.00 RIGU P PRE and not a destination. Asked hands to have a renewed commitment to satety. Each hand was asked to make a rig walkaround in an area he does not normally work in and write 2 stop cards. Good participation from all hands on rig. 19:45 - 22:30 2.75 RIGU P PRE Slip and cut 50' of drilling line. 22:30 - 0.00 RIGU P PRE PU injector. Attach packoff. Attach gooseneck. Change packoff elements and brass inserts. 11/7/2005 00:00 - 00:20 0.33 RIGU P PRE PJSM prior to stabbing coil. 00:20 - 01:00 0.67 RIGU P PRE Pull coil off reel and stab into injector. 01:00 - 02:30 1.50 RIGU P PRE Make up hose to reverse circulate. Stab injector onto well. 02:30 -04:05 1.58 RIGU P PRE Reverse circulate 25 bbls of methanol, followed by water spacer then mud to perform slack management. Good audible indication of slack aline moving in the coil. 04:05 - 06:00 1.92 RIGU P PRE SD pumps. Blow back end of coil with rig air to FP. Rig up hardline in reelhouse, and Jupiter cable. 06:00 - 06:30 0.50 RIGU P PRE Held TL meeting and Pre-Spud meeting with daylight crews. 06:30 - 08:45 2.25 RIGU P PRE Continue MU inner reel hardline and a-line junction box. 08:45 - 09:00 0.25 RIGU P PRE PJSM review coil cutting procedures and hazards. 09:00 - 09:15 0.25 RIGU P PRE Attempt to check well pressures before unstabbing injector. Master vavte is pressure locked. Call valve shop. 09:15 - 11:00 1.75 RIGU P PRE Slowdown kill line to prevent freezing. Unstab injector. Seen 11' of a-line beyond end of coil. Trim back 8' of coil. Install Kendal CTC. Pull test to 40K 11:00 - 14:00 3.00 RIGU P PRE MU Baker UOC. CuUslip 60' of .125" slickline then rehead. PU BHA to mousehole and motor/mill to well. Check WHP...slight but enough to flow 1 ° stream. 14:00 - 14:15 0.25 RIGU P PRE PSJM review "Pressure Deployment" procedures. 14:15 - 16:30 2.25 RIGU P PRE Pressure deploy 8HA #1 following guideline steps.Shut-in well and pop off lubricator seen we've mismeasured spaceout of double ball valves. Too high. Stab lubricator open well and slackoff to lower set depth. Shut-in well again. Remove lubricator and standback. PT UOC assembly to 3500psi. MEG test tools. Stab injector. Open BOP's. Tag-upset depth. 16:30 - 18:00 1.50 RIGU P PRE RIH w/ BHA #1 18:00 - 18:30 0.50 CLEAN P W EXIT Continue RiH with mill and motor. Clean thru 7370' where eline had trouble with whipstock. Clean to dry tag up at 8612' CTM. Kick on pumps. Start displacement of welt to mud. 18:30 - 19:35 1.08 CLEAN P W EXIT Log tie in pass down over RA character at 8200'. Make -14.5' correction. RIH at 25 fpm and pumps at 2 bpm. Found hard bottom at 8688'. 19:35 - 21:00 1.42 CLEAN P W EXIT Pick up off bottom. Kick on pumps to full rate. 4300 psi at 2.5 bpm. Seems high. SD pumps, open EDC. Kick on pumps circ press at 2.5 bpm is 3200 psi. Mud appears to be vis'ed up a bit. SD pumps, shut EDC. Come on tine with pumps, POOH pumping at 2.3 bpm, 4000 psi. Got a fair amount of pipe scale/cement chunks while POH. Good call to run the cleanout run. 21:00 - 21:20 0.33 CLEAN P W EXIT Tag up at surface. Start to flow check well. Hold PJSM. Discuss 2 options. Well is dead, Well is not dead and we need to undeploy. Review undeployment proceedure in detail. Assign individuals to tasks on undeployment proceedure. 21:20 - 21:55 0.58 CLEAN P WEXIT Flow check of well confirms that well is dead. Break injector. Printed: 11/28/2005 72:59:04 PM ' BP EXPLORAT{ON Operations Summary Report Legal Well Name: 10-02 Common Well Name: 10-02 Event Name: DRILL+COMPLETE Start: 11!5/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27!2005 Rig Name: NORDIC 2 Rig Number: Page 3 of 16: Spud Date: 11/5/2005 End: 11 !27/2005 Date From - To Nours Task Code NPT Phase Description of Operations 11/7/2005 21:20 - 21:55 0.58 CLEAN P WEXIT Lay down BHA #1, clean out mill and motor. 21:55 - 22:50 0.92 STWHIP P WEXIT MU BHA #2, WF WS setting BHA. WS tray face scribed to 22:50 - 00:00 I 1.171 STWHIPI P 11/8/2005 00:00 - 01:00 1.00 ~ STW HI P P 01:00 - 01:20 0.33 STWHIP P 01:20 - 01:55 0.58 STWHIP P 01:55 - 02:05 f 0.171 STWHIPI P 02:05 - 03:30 I 1.421 STWHIPI P 03:30 - 04:45 I 1.251 STWHIPI P 04:45 - 06:30 1.75 STWHIP P 06:30 - 13:30 7.00 STWHIP P 13:30 - 13:10 23.67 STWHIP P 13:10-13:40 0.50 STWHIP P 13:40 - 14:15 0.58 STWHIP P 14:15 - 15:40 1.42 STWHIP P 15:40 - 16:00 0.33 STWHIP P 16:00 - 17:30 1.50 STWHIP P 17:30 - 20:15 I 2.751 DRILL I P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 20:15 - 22:30 2.25 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 23:15 0.25 DRILL P PROD1 23:15 -00:00 0.75 DRILL P PROD1 11!9/2005 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 05:00 I 2.001 DRILL I P I I PROD1 orienter. RIH with BHA #2 to set WF whipstock. Pumping at 0.5 bpm thru an open EDC. RIH at 70 fpm. Continue RIH with BHA #2. Log tie in pass down from 8220'. Make -11' correction. Log CCL pass down from 8260'-8540'. Confirmed on depth. Move set depth up to put W S top at 8540' to avoid casing collar deeper. Check PU weight, and found at 32500 lbs. Bring pumps up. Pressure up on setting tool. Saw indication of set. Set 50001bs on whipstock. Good inciation of set. PU at 31000 lbs. Confirmed set whipstock. WS tray oriented to 30 deg left of high side. Top of whipstock at 8540' Bot of whipstock at 8553'. Open EDC. Pump at full rate while POOH. Pumping at 3076 psi at 2.3 bpm. Lay down BHA #2, whipstock setting BHA. PU BHA #3, window milling BHA. Running WF 0 deg motor, HCC string reamer, WF window mill. RIH with BHA #3 to mill window. Tagged at 8540.3' Mill window f/ 8540.3' to 8547'. 2.70/2.70 free-spin 3950psi 100-150psi motorwork following time milling schedule. Max wob 6k most time 2-3k. Milled to 8547'. Shut-in well trapping 1000psi. Held for 5min. No leak-off. Called town to confirm pressures and wait times. Drill open hole from 8547' to 8558'. Make 2 up and down reaming passes thru the window. No motor work or problems observed. Dry drift window up and down. No problems observed. POOH to pick up build section BHA. Hotd PJSM and review undeployment proceedure. Trap 550 psi on wellhead. Pressure undeploy window milling BHA. Mills recovered in good shape. WF whipstock mill recovered at 3.79" Go, 3.78" No-Go, and had the proper swirl pattern on the face. HCC string reamer recovered at 3.80" Go, 3.79" No-Go. Make up BHI MWD tool for build section. (2.3 deg mtr w HTC bi-center) (Electrically test same. Pressure deploy BHA. Found 305 psi on well. Had trouble getting bit past tbg hanger. Get off well and turn bit 180 deg. Get through tbg hanger ok. Stab coil. Test mwd. Get on well. Run in hole following WHP schedule. Log gr tie in from 8210 to 8250'. Subtract 16' correction. Continue to RIH. Orient to 40L to pass through window. Drill ahead from 8558'. 3535 psi fs ~ 2.6 bpm. Drill build from 8570'. 3550 psi fs at 2.6 in/out. DSPI:100-200. DHWOB: 1.0-1.5 k#. WHP/BHP/ECO: 66/3651!10.9 ppg. IA/OA/PVT: 260/146/320 bbls. Several stalls just outside window. ROP averaging 25-30 fph. Continue to drill build section from 8700'. Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 4 of 16'_ Operations Summary Report Legat We11 Name: 1Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!27/2005 Rig Name: NORDIC 2 Rig Number: Date 1 From - To'Hours I Task I'Cotle l NPT I -Phase I Descriptiorr of Operations' 111/9/2005 06:00-100:00 4.00 DRILL P 10:00 - 12:35 I 2.58 {DRILL I P 12:35 - 14:00 I 1.421 DRILL I P PROD1 Wiper trip to window. PROD1 Drifl. PROD1 Continue drilling build section. Free spin pressure 3480 psi at 2.6 bpm. Drilling ahead in Ankorite at 2.61/2.64/3776 psi. ROP=5 fph. PVT=320 bbls. IAP=515 psi, OAP=396 psi. BHP=3690 psi. ECD=10.91 ppg. WOB=7000 lbs. String wt = 62001bs. PROD1 Broke thru Ankorite finally! Geo reports 5-6' TVD of Ankorite. Continue drilling to land build and turn. PRODi Build section of well landed. POOH to pick up lateral section BHA. No problems in open hole on wiper trip to window. Pull thru window with pumps down, and holding WHP. Open EDC. Pump at full rate while POOH. 14:105 - 14:30 0.251 DRILL N I RREP PROD1 14:30 - 16:30 I 2.00; DRILL I P I { PROD1 16:30 - 18:00 1.50 ~ DRILL I P l PROD1 18:00 - 18:30 I 0.501 DRILL P I I PROD1 18:30 - 21:00 I 2.501 DRILL I P I I PROD1 22:30 - 23:00 1 0.50 DRILL P I PROD1 23:00 - 00:00 1.00 DRILL P 111/10/2005 100:00 - 06:00 I 6.OOI DRILL I P I I PRODi 06:00 - 08:45 I 2.751 DRILL I P I ~ PROD1 08:45 - 09:25 09:25 - 10:05 0.67 DRILL I P I I PROD1 0.67 DRILL N RREP PRODt 10:05 - 13:00 2.921 DRILL I P I I PROD1 'Note -Mud is a used system from a previous well and contains 14 ppb Kta-Gard. PJSM Re: Undeployment of build section BHA. Found leaking swab on pump #2. Take a few minutes to isolate and clean up mud in pump room. Undeploy BHA #4. Left 400 psi on well at start of undeployment. Bit recovered graded 1,2, with 1 chipped cutter on the wing. Bit is rerunab{e. Hold Safety stand down with Nordic crew #3. Topic of stand down was recent spate of injuries that we have had in the past 3 weeks. Discussed the dangers of getting complacent, and the need to stay focused on the job. MU lateral BHA with reistivity mwd tool. Hold PJSM with night crew to discuss. Discuss positions, assignments, hazards. Evaluate if slickline can handle BHA weight (yes, it can). MU lateral assembly with UPR tool. (1.0 deg xireme mtr w/ new HTC bi-cent) Slow going due to tool length. Found 200 psi trapped on well. Stab coil. Test mwd. Get on welt. Run in hole. Maintain BHP foNowing pressure schedule. Log gr tie in from 8220'. Subtract 16.5' correction. Log build section with resistivity tool. 5 fpm. 3450 psi fs at 2.42 iN2.7 out. Grill lateral from 8900'. 3510 psi fs ~ 2.43 iN2.66 out. DPSI: 100-200. DHWOB: 1.5-2.5k#. WHP/BHP/ECD: 8413770/11.1 ppg. IA/OA/PVT: 378/254/316 bbls. 1NC/AZM/TF: 8$.111 6.4/95L. ROP averaging 25 fph. Slow drilling. Continue drilling lateral section. Free spin 3690 psi at 2.5 bpm. Drilling at 2.56/2.62/3750 psi. PVT=3i 3 bbls. IAP=760 psi, OAP=626 psi. BHP=3804 psi. ECD=11.2 ppg. Wiper trip to window. Slight overpull on pickup. PU weight 30 klbs. Clean to window. Clean back in hole. Back on bottom. Nordic hands need to do maintenance on pump #2. Can't drill with 1 pump. Make slow wiper trip toward window while they sort it out. Resume drilling. Start swap to new mud. Free spin with new mud 3527 psi at 2.6 bpm. Drilling at 2.67/2.72/3710 psi. New mud made a big improvement in drilling. We went from 35 fph to 60 fph. Printed: 1128/2005 12:59:04 PM 'BP EXPLORATION Page 5 of 16 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code- NPT Phase Description of Operations 11/10/2005 13:00 - 17:00 4.00 DRILL P PROD1 Drilled into the Ankorite. Point tool face straight down. Geo thinks we faulted into it. ROP 5 fph. Gnawing away at it. 17:00 - 19:15 2.25 DRILL P PROD1 Made 18' in 4 hours 4.5 fph. Geo says at minimum we have 19:15 - 21:30 I 2.251 DRILL P 21:30 - 23:30 23:30 - 00:00 11 /11 /2005 00:00 - 03:00 2.00 DRILL i P 0.50 DRILL IP 3.00 DRILL ~ P PROD1 PROD1 PRODi PROD1 03:00 - 03:20 0.33 DRILL P PROD1 03:20 -06:00 2.67 DR1LL P PROD1 06:00 - 06:15 0.25 DRILL P PROD1 06:15 - 06:30 0.25 DRILL P PROD1 06:30 - 08:15 1.75 DRILL P PRODi 08:15 - 10:00 1.75 DRILL P PRODi 10:00 - 10:20 0.33 DRILL P PRODt 10:20 - 10:40 0.33 DRILL P PROD1 10:40 - 11:40 1.00 DRILL P PROD1 11:40 - 14:00 2.33 DRILL P PROD1 14:00 - 15:15 1.25 DR{LL P PRODi 15:15 - 16:30 i 1.251 DRILL I P l I PROD1 16:30 - 17:10 I 0.671 DRILL I P I I PROD1 17:10 - 19:00 I 1.831 DRILL I P I PROD1 19:00 - 22:00 1 3.00 DRILL P 75' more measured depth of Ankorite to cut. POOH to pick up tricone to get back down thru it. i Hold PJSM to discuss un-deployment. At surface. Shut in well with 500 psi WHP. Undeploy BHA. HTC bi-center graded 3-3, with several broken and/or worn nose cutters. MU HTC tricone STXM20DX2 3.75" bit. Deploy BHA. Found 150 psi on well head. Perform inspection of blocks before picking up injector. Stab coil. Get on well Run in hole following BHP pressure schedule. Log gr tie in from 8535'. Subtract 17' correction. Continue in hole. Drill ahead from 9183'. 3500 psi fs ~ 2.66 in/out. DPSI: 150. DHWOB: 5-6k#. WHP/BHP/ECD: 66/3676110.8 ppg. 1A/OA/PVT: 710/388 bb1s. INC/AZM/TF: 86.6/354.71180 deg. Start out with 500 # WOB to break in bearings. Slowly increase to 5-6k#. Could not get any more than this for DHWOB. Made 5' in three hours. Wiper trip to window. Hole smooth. Circulate out of hole. Jog in hole near surface to try and clean out cuttings. By pass micro motion to avoid plugging. SD operations for crew change. Hold PJSM with day tour crew to discuss Undeploy and redeploy of BHA. Undeploy BHA #6. Change out tricone bit for Hycolog concentric reamer bit (CRXE1005). Redeploy BHA. RIH with BHA #7 to continue drilling Ankorite. Log tie in pass over RA tag in whipstock. Make -18.5' correction. Run to bottom. Pumping at full rate in open hole. Free spin 3280 psi at 2.56 bpm. Tag bottom at 8188.1'. Begin drilling. PVT=337 bbls. IAP=O, OAP=O, BHP=3677 psi. ECD=10.8 ppg. Initial ROP=15 fph. Yee haw. Drilling great in Ankorite. Best we've ever done. Made 14' in the last hour. ROP seems to be slowing down slightly. Bit is hanging in at 10 fph. Good ROP compared to 2-5 fph with the bicenter. Continue chugging away. Making some hole anyway. Drilling break. Got down out of the Ankorite finally. Drilling ahead at 80 fph in good A3 sand. Holding 83 deg INC for the time being to get down below the Ankorite. This bit drills sand good too! Wiper trip to window. Clean PU off bottom. Clean in open hole up. Pump 15 bbls of 100 klsrv mud to help hole cleaning. Continue trip up to window. Clean back down to bottom. Drill ahead in ankorite to 9380'. Appear to out of ankorite and into sand. Drill to 9500'. 3250 psi fs ~ 2.47 in/out. DSPI: 200-300 DHWOB: 2-3k#. WHP/BHP/ECD: 60/3700/10.9 ppg. Printed: t 1/28/2005 12:59:04 PM BP EXPLORATION Page of 1'6' Operations Summary Report- Legal Well Name: 1Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!2712005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/11/2005 19:00 - 22:00 3.00 DRILL P PROD1 IA/OA/PVT: 200/1031346 bbls. INC/AZMlfF: 85.6/312.5/908. ROP avg 10 fph in ankorite, 40-60 fph in sand. 22:00 - 23:00 1.00 DRILL P PROD1 Wiper trip to window. Hole smooth. 23:00 - 00:00 1.00 DRILL P PRODi Drill ahead from 9500'. 11!12/2005 00:00 - 00:30 0.50 DRILL P PROD1 Drill lateral to 9564'. Lost ability to read tool face and near bit inc. Trouble shoot tools & re boot computers etc. Unable to re-establish TF or inc. 00:30 - 03:30 3.00 DRILL N DFAL PROD1 Wiper trip to window. Circulate out of hole at max pump rate, following BHP schedule. 03:30 - 04:30 1.00 DRILL N DFAL PROD1 PJSM. At surface. Shut in well on BHA. Get off well. Unstab from coil. Undeploy BHA. Lay down mwd tools. WHP has bled to zero psi. 04:30 - 06:30 2.00 DRILL N DFAL PROD1 Test mwd tools on rig floor /catwalk. Found bad HOT. Replace same. 06:30 - 06:50 0.33 WHSUR P PROD1 Function test BOPE. All passed ok. 06:50 - 07:05 0.25 ' DRILL N DFAL PROD1 PJSM Re: Deployment of BHA #8. Rerunning same Hycalog CRX bit as used on last run. Bit examined for micro dulling, I and found to be in great shape. Graded 0,0 when recovered 07:05 - 08:15 1.17 DRILL N DFAL PROD1 from last run. Heck of a good bit we have here. Pressure deploy BHA #8 following SOP. 08:15 - 09:35 1.33 DRILL N DFAL PROD1 RIH with BHA #8. Shallow hole test ok. Continue RIH. 09:35 - 09:55 0.33 DRILL N DFAL PROD1 Log tie in pass over RA tag. Make -19' correction. 09:55 - 10:25 0.50 DRILL N DFAL PROD1 Run to bottom. Free spin 3480 psi at 2.57 bpm. 10:25 - 10:45 0.33 DRILL P PROD1 Tag bottom and resume drilling. Trying to drill down out of Ankorite as per Geo. PVT=370 bbls. IAP=O, OAP=O, BHP=3810 psi, ECD=11.12 ppg. WOB=6800 lbs. String wt = 3200 psi. ROP=10-15 fph. 10:45 - 13:15 2.50 DRILL P PROD1 Drilling break. Drilling 90 fph. Pump 15 bbl high vis sweep. Seem to be getting a lot of cuttings back now, although it is too soon for bottoms up from the high ROP stuff. 13:15 - 14:25 1.17 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. Clean in open hole. Clean back to bottom. Still pumping sweeps 1 per hour. 14:25 - 16:30 2.08 DRILL P PROD1 Free spin 3570 psi at 2.57 bpm. Tag bottom. Resume drilling. TF = highside. Going to invert and drill back up thru the Ankorite to land the invert section in the A4 sand. Current NB INC=87 deg. 16:30 - 19:00 2.50 DRILL C PROD1 Hit the Ankorite again. Intentionally this time. ROP 9-12 fph. INC=54 deg. Going to drill up thru it and roll it over in the A4 sand. Note -Time code change from "P" to `C' at this point due to decision to drill the 2nd lateral. (As per Aras Worthington) 19:00 - 22:00 3.00 DRILL C PROD1 Drill ahead form 9820'. 3500 psi fs at 2.55 iN2.55 out. 200-300 DPSI. DHWOB: 5-6k#. WHP/BHP/ECD: 7013821/11.14 ppg. IA/OA/PVT: 327/186/363 bbls. ICWAZM/TF: 94.8/347.3/408. ROP averaging 8-10 fph in ankorite. Continue climb up through A3 ankorite zone. 22:00 - 23:30 1.50 DRILL C PROD1 Wiper trip to window. Hole smooth. 23:30 -00:00 0.50 DRILL C PROD1 Drill ahead from 9850'. 11/13/2005 00:00 -06:00 6.00 DRILL C PRODi Drill ahead from 9855'. 3600 psi fs at 2.65 iNout. 200-300 DPSI. DHWOB: 5-6k#. WHP/BHP/ECD: 7013837111.20 ppg. IA/OA/PVT: 487/336/352 bbls. INC/AZMlTF: 94.2/350.4/908. Printed: 11(28/2005 12:59:04 PM 'BP' EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 10-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 11!13/2005 00:00 - 06:00 6.00 DRILL C PROD1 Continue to drill at 8-12 fph while climbing up through A3 ankorte. 06:00 - 06:20 0.33 DRILL C PROD1 Continue drilling up in Ankorite. We have cut 9' TVD so far. The Ankorite thickness in the parent well was 5' TVD. We have either crossed a fault, or found thicker Ankorite here. Drilling at 2.65/2.65/3820 psi. PVT=348 bbls. IAP=536 psi, OAP=377 psi. BHP=3838 psi. ECD=11.2 ppg. WOB=5550 lbs. String wt=2400 lbs. ROP=8-10 fph. 06:20 - 07:25 1.08 DRILL C PROD1 Drilling break. Popped up thru the Ankorite. Now drilling 80 fph in the A4 sand. Rolling TF over to land it. Resume pumping 15 bbl high vis sweep 1 time per hour to help in hole cleaning. 07:25 - 08:10 0.75 DRILL C PROD1 Wiper trip to window. Clean PU off bottom at 32 klbs. 08:10 - 08:25 0.25 DRILL C PROD1 Log tie in pass accross RA tag in whipstock. Make +4' ~ correction. 08:25 - 09:05 0.67 DRILL C PRODi Continue back in the hole on wiper trip. Smooth while RIH. 09:05 - 11:30 2.42 DRILL C PROD1 Resume drilling lateral section in the A4. Free spin 3470 psi at 2.44 bpm. Drilling at 2.44/2.41/3713psi. WOB=4000 lbs. String wt = 6600 lbs. ROP=60 fph. 11:30 - 13:10 1.67 DRILL C PROD1 Wiper trip to window. Clean PU off bottom at 33 klbs. Clean to window and back in the hole. 13:10 - 15:35 2.42 DRILL C PROD1 Continue drilling. Holding 90 deg INC. ROP=60 fph. WOB=2400 lbs. String wt = 80001bs. Mud drill solids are up to 1.0%. Call for trucks for a mud swap. 15:35 - 17:30 i.92 DRILL C PROD1 Wiper trip to the window. Clean PU off bottom at 32 klbs. Clean in open hole. 17:30 - 20:00 2.50 DRILL C PROD1 Drill ahead from 10,300'. 3650 psi fs at 2.46 iM2.47 out. DPSI: 200-300. DHWOB: 2.5 - 3.5k#. WHP/BHP/ECD: 62/3951/11.56 ppg. IA/OA/PVT: 532/380/328 bbls. ROP averaging 50-60 fph in A4/A3 zone. Not sure if we are in A4 or not. Sand quality mediocre at best. 20:00 - 22:00 2.00 DRILL C PROD1 Wiper trip to window. Hole very smooth. 22:00 -00:00 2.00 DRILL C PROD1 Drill ahead from 10535'. Increase angle to 94-95 deg climb up through section. 11/14/2005 00:00 -00:45 0.75 DRILL C PROD1 Drill ahead from 10535'. Discover we have drilled across a fault into A6. 00:45 - 01:30 0.75 DRILL C PROD1 Wiper trip to window. Discuss sidetrack plan with town. 01:30 - 03:15 1.75 DRILL C PROD1 Circulate out of hole to pick up side track assembly. 03:15 - 03:40 0.42 DRILL C PROD1 Stop at 1000'. Circulate at max rate to clean hole. Getting lots of shale across shaker. 03:40 -06:00 2.33 DRILL C PROD1 At surface. PJSM. Get off well. Unstab coil. Undeploy BHA assembly. LD resistivity tool. MU replacement 1.8 deg mtr with R-60 ST bit w/ brass nose. Deploy BHA. 06:00 -06:45 0.75 STKOH C PROD1 Continue reconfiguring BHA for sidetrack run. 06:45 - 07:00 0.25 STKOH C PROD1 PJSM prior to deploying sidetrack BHA. 07:00 - 08:20 1.33 STKOH C PROD1 Deploy BHA #9, sidetrack BHA. 08:20 - 10:30 2.17 STKOH C PROD1 RIH with BHA #9. Repair powerpack on way in the hole. Stop and tighten drive plates on way in the hole. 10:30 - 10:45 0.25 STKOH C PROD1 Log tie in pass over RA tag in whipstock. Make -19' correction. 10:45 - 12:15 1.50 STKOH C PRODi Run to bottom pumping 0.25 fpm thru the bit. Set down slightly Printed: 11/28/2005 12:59:04 PM BP EXPLORATION '' Page-8 of i6'' Operations Sulmmary Report Legal Well Name: 1 Q-02 Common Well Name: 10-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of'Operations -, 11/14/2005 10:45 - 12:15 1.50 STKOH C PROD1 at 8666', but bounced thru. Set downs at 9885', but bounced thru. Kicked on pumps at 10450', and had ratty weight the rest of the way to bottom. Tag up hard with pumps on at 10476'. Pull up hole to start sidetracking. 12:15 - 14:30 2.25 STKOH C PROD1 Trough hole from 9980'-9995'. Make 3 troughing passes down. Tool face = lowside. Trough while RIH at 15 fph. 14:30 - 15:00 0.50 STKOH C PROD1 Stationary drill at 9995'. 15:00 - 15:40 0.67 STKOH C PROD1 Time drill at 3'fir. Started seeing WOB after 1.0' of coil movement at surface. 15:40 - 16:00 0.33 STKOH C PROD1 Time drill at 6'/hr. WOB constant at 500 lbs. 16:00 - 16:15 0.25 STKOH C PROD1 Control driN at i0 fph. WOB constant at 10001bs. 16:15 - 16:30 0.25 STKOH C PROD1 Drill at 35 fph. WOB = 1250 Ibs, 150 psi motor work. 16:30 - 17:15 0.75 STKOH C PROD1 Confirmed sidetracked from directional information. Backream window area at 90 deg, 0 deg, 270 deg. 17:15 - 21:00 3.75 STKOH X STUC PROD1 Wlper trip to window. Reduce pump to min rate to go through window. Shut down pump at 8505' to close open EDC. Unable to re-establish circulation afer opening EDC. Unable to move pipe either. Able to circulate down coil. BHP approx 4400 psi before injecting into formation. Stop pumps and allow BHP to bleed off to 3850 psi. Push down on pipe and/or leave in ~ neutral weight. Do this several times. Eventually pipe began to move down. Able to RIH at 14k# do wt, which is normal RIH weight. Pressure still trapped below BHA. Circulate across wellhead to verify nothing is plugged at surface. RIH to below build to 8875'. Able to move up and down hole freely. 37k# up, 14k# do weight. But pressure is still trapped below BHA !!!! Plan is to cycle up and down 10' to try and loosen what ever is packing off coil. POOH to try and reduce bore hole pressure below BHA by removing coil volume from well below pack off. Draw BHP down to 8.8 ppg . 21:00 -00:00 3.00 STKOH X STUC PROD1 Pressure wellhead to 200 psi with BHP reduce to 2980 psi while RIH. Bleed WHP. Repeat this several times while RIH and POH, with up to 500 psi WHP. Continue to be able to run in and out of hole. 14k# do wt, 38k# up wt, which varies a little depending on BHP or WHP. None of this seems to have any effect. Begin to cycle pipe from 8800' to 9200' while maintaining a constant BHP using to pump to try and minimize pressure fluctuations on open hole. 11/15/2005 00:00 - 00:30 0.50 STKOH X STUC PRODi Continue to run in and out of hole from 8800' to 9200' to try and loosen material packed off around coil. 00:30 - 03:00 2.50 STKOH X STUC PROD1 Pipe became stuck at 9078'. Pull to 42k#, slack off to -4k#. Continue to work pipe, mostly from neutral to do wt. Came free. Continue to work pipe up and down. from 8800' to 9200'. Pressure wellhead to 300 psi. Bleed off quickly several times. 03:00 -04:15 1.25 STKOH X STUC PROD1 Continue to move pipe between 8800' and 9200'. Put 500 psi on well head, and dump pressure. Maintain 11.0 to 12.2 ppg pressure on open hole to help kep shales stable. Do this while moving pipe up and down. Plpe continues to move freely. 14k# do wt, 35k# up wt. Pipe moving freely most of the time. Have pulled as much as 50k# up wt to keep pipe moving. May Printed: 11/28/2005 12:59:04 PM 'BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common Wetl Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11 /27!2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task "'Code NPT Phase Description of Operations 11/15/2005 03:00 - 04:15 1.25 STKOH X STUC PROD1 be starting to break up pack off. 04:15 - 05:00 0.75 STKOH C PROD1 Began to get a small trickle of returns. Stopped, then started again a few times. Slowly increasing pump rate, starting to get 1:1 rtns. Pump pressure coming down. Yahoo !!!! 05:00 -06:30 1.50 STKOH C PROD1 Continue to circulate while POH slowly. Getting large amount of cuttings & shale across shakers. Having to bypass Choke and micro motion. Through window ok at 1 bpm. Continue to POH circing at 2.76 bpm. 06:30 - 07:15 0.75 STKOH C PROD1 2675', while POOH retums went to 0, we plugged off the choke or micromotion with cuttings. Bypass same to get returns back. Pump a high vis sweep to help clean the hole. Pump bottoms up prior to continuing to POH. 07:15 - 09:00 1.75 STKOH C PROD1 Got lots of rocks out while circulating bottoms up. Retums clean now. Continue POH. 09:00 - 09:20 0.33 STKOH C PROD1 PJSM prior to undeploying BHA. Discuss clearing choke, micromotion, and bypass lines also. Make job assignments. Review tasks to ensure that there would be no interference between operations. 09:20 - 11:00 1.67 STKOH C PRODi Undeploy sidetrack BHA. 11:00 - 13:30 2.50 DRILL C PRODi Reconfigure BHI BHA to add resistivity to it. Rig crew blowing down all tines, checking choke, micromotion and bypass lines as well as BOP stack to ensure that all rocks and cuttings are cleared out. Found rocks in cavity of lower set of TOT's. 13:30 - 13:40 0.17 WHSUR C PROD1 Pressure test 80P stack and hardline in choke room to 250 psi and 4000 psi. Passed ok, no leaks. 13:40 - 15:30 1.83 DRILL C PROD1 Pressure deploy BHA #10. Lateral BHA with RES. BHA has a 1.0 deg motor and CRXE concentric reamer bit. Stab coil and get on well. 15:30 - 18:45 3.25 DRILL C PROD1 Run in hole circulating at 2.42 bpm. Maintain BHP as per schedule. Perform weight checks every 2000'. Monitor shakers for excess cuttings. 18:45 - 19:00 0.25 DRILL C PROD1 Log gr tie in across RA tag at 8547'. Subtract 19' correction. 19:00 - 19:50 0.83 DRILL C PROD1 Circulate in hole. Choke open. Monitor weight and circulating pressure closely due to concerns regarding pssible cuttings bed and hole condition. 3430 psi fs at 2.56 in. 1:1 rtns. PVT: 288 bbls. 19:50 - 20:45 0.92 DRILL C PROD1 Hole was clean to set down at 9668' w/ TF 180 out. Essentially clean up hole from 9666' to 9704' as follows-PUH from 9668' for 50' w/.high MW. RBIH and set down at 9666'. Try to drill it, but got MW instead. PUH 8k over and sli packing off. Drill it at 458 2.58!2.5213500 w/ 250 psi MW, 3k wob w/ 11.2 ECD at 3840 psi DHP PVT 292. Get to 9681' and stacking. Wiper back up hole w/ 10k over and MW. Ream back down to 9704'. Wiper back to 9630' and had MW and 5k overpull at 9650' 20:45 - 21:20 0.58 DRILL C PROD1 Wiper back to 9704' was clean. Wiper slowly to TD tagged at 10017', clean. Drill 3' just to be sure on bottom 21:20 - 22:15 0.92 DRILL C PROD1 Wiper to window to test the waters, clean. PUH thru window at 1.0 bpm at midway point of hi vis pill exiting bit, clean. Wiper to 8400' at 2.6 bpm, clean. No rocks, but excessive small pieces of shale in retums 22:15 - 23:15 1.00 DRILL C PROD1 Wiper back to TD was clean, PVT 286 23:15 - 00:00 0.75 DRILL C PROD1 Drill from 10020' 2.69/2.63/3600/908 w/ 200-500 psi dill, 3-5k wob w/ 11.3 ECD at 60-90'/hr in A4 Printed: 11/28/2005 12:59:04 PM BP EXPLORATION. Page to of 16 Operations Summary Repor# Legal Well Name: 10-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALiSTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From. - To Hours. 'Task Code NPT Phase Description of Operations 11/16/2005 00:00 - 01:25 1.42 DRILL C PROD1 Drill from 10060-170' at 50-80'/hr 01:25 - 03:20 1.92 DRILL C PROD1 Wiper to window was clean both directions w/ no excessive cuttings or shales in returns PVT 282 03:20 - 06:00 2.67 DRILL C PROD1 Drill from 10170' 2.66/2.61/3600/75-1008 w/ 300-500 psi dill, 2.5-4.5k wob w/ 11.48 ECD holding 89 deg at 6606' TVD PVT 281 06:00 - 07:15 1.25 DRILL C PROD1 Wiper to window. Hole smooth on the way out. 07:15 - 07:30 0.25 DRILL C PRODi Log gr tie in. Add 6' correction. 07:30 - 08:00 0.50 DRILL C PROD1 Wiper trip back to btm. Hole smooth and apparently clean. 08:00 - 11:30 3.50 DRILL C PROD1 Drill ahead from 10,320'. 3770 psi fs at 2.65 in/2.6 out. DSPI: 200-350. DHW06:2.0-3.Ok#. WHP/BHP/ECD: 29/3944/11.52 ppg. IA/OA/PVT: 398/242!270 bbls. Avg ROP: 50 fph. Mostly in sand. A4 is only about 1' thick. 11:30 - 13:30 2.00 DRILL C PROD1 Wiper trip to window. Ho{e smooth. 13:30 - 16:30 3.00 DRILL C PROD1 Drill ahead from 10,470'. 3750 psi fs at 2.66 in/out. PVT: 256 bbls. Inc: 89-91 deg 16:30 - 19:30 3.00 DRILL C PROD1 Wiper trip to window was clean. Wiper to TD had wt loss, MW I at 8700' and rest of hole was clean PVT 248 19:30 - 22:10 2.67 DRILL C PROD1 Drill from 10620' 2.6/2.54/3600/90L w/ 200-500 psi dill, 2-3k wob w/ 11.7 ECD at 88 deg at 6614' TVD. Adding brine to thin 80k LSRV back to 65k and lower ECD's 22:10 - 23:30 1.33 DR1LL C PROD1 Wiper to window 23:30 - 23:45 0.25 DRILL C PROD1 Log tie-in down from 8570', add 6' 23:45 - 00:00 0.25 DRILL C PROD1 Wiper back to TD 11/17/2005 00:00 - 00:55 0.92 DRILL C PROD1 Continue wiper back to TD. Hole was clean both ways PVT 316 00:55 -04:05 3.17 DRILL C PROD1 Drill from 10770' 2.63/2.56/3600/85L w/ 100-300 psi dill, 2-3k wob w/ 11.34 ECD at 90 deg at 6614' ND PVT 308 04:05 - 05:25 1.33 DRILL C PROD1 Wiper to window was clean 05:25 -06:45 1.33 DRILL C PROD1 Wiper to TD. Hole smooth. 06:45 - 08:45 2.00 DRILL C PROD1 Drill ahead from 10920'. 3550 psi fs at 2.45 iN2.38 out. DPSt: 150-300 DHWOB:2.0-2.5k# WHP/BHP/ECD: 26/ 3973111.58 ppg IAIOA/PVT: 5241367!303 bbls INC/AZMlfF: 88.5/4.2/100L. Drilling ahead smoothly at 50-70 fph. 08:45 - 12:00 3.25 DRILL C PROD1 Wiper trip. Hole smooth in both directions. Log gr tie in. 12:00 - 16:45 4.75 DRILL C PROD1 Drill ahead from 11,070'. 3850 psi fs at 2.60 iN2.54 out. 2-3k# DHWOB PVT: 289 bbls. 16:45 - 18:10 1.42 DRILL C PROD1 Wiper trip to window was clean 18:10 - 20:10 2.00 DRILL C PROD1 Wiper to TD was clean except for numerous setdowns 10970-11000'. Spent 20 min cleaning up this area PVT 265 20:10 - 21:30 1.33 DRILL C PROD1 Drill from 11220' 2.6/2.51/3760/908 w/ 100-300 psi dill, 2-3k wob w/ 12.1 ECD at 87 deg at 6625' TVD. Roll TF to 1308 at 11250' to begin drop to find the A3 ankerite and penetration rate 100'1hr 21:30 - 21:55 0.42 DRILL C PROD1 Wiper to 11200' after cutting fast hole and while swap to fresh mud. Also, repairing pump #1 swab 21:55 - 22:10 0.25 DRILL C PROD1 Drill from 11335-350' and pump #2 cap started Leaking .. . 22:10 - 23:40 1.50 DRILL C PROD1 Wiper to window {early) due to pump probs and while continuing to displace to fresh mud. Fresh mud from outside tanks was 55 deg and cooled off IA from 600 psi to -17 psi vac, and OA dropped from 350 to zero psi .. Wiper was clean 23:40 -00:00 0.33 DRILL C PROD1 Log tie-in down from 8570' after swapping to repaired pump #1. Printed: 11/28/2005 12:59:04 PM 'BP EXPLORATION Page 11 of 16- Operations Sumrniary Report Legal W e11 Name: 1 Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task. <Code NPT Phase. Description of'Operations 11/17/2005 23:40 -00:00 0.33 DRILL C PROD1 Corr +5.5' 11/18/2005 00:00 - 01:55 1.92 DRILL C PROD1 Wiper back to TD was clean until set down at 11250'. Ream to 11260' for 20 min w/ 10k overpulls. Slow ream to TD tagged at 11352' Swap to repaired pump #2 PVT 250 01:55 -04:05 2.17 DRILL C PROD1 Drill from 11352' 2.57/2.50/3530/1408 w/ 200-300 psi dill, 2-3k wob w! 11.3 ECD and continue drop to find A3 ankerite. Drill to 11500' and noseeum PVT 246 04:05 - 05:40 1.58 DRILL C PROD1 Wiper to window, 33k while geo confirms this is deep enough 05:40 -06:30 0.83 DRILL C PROD1 Pull thru window and wiper to 7000' 2.7/3600 06:30 - 08:30 2.00 DRILL C PROD1 Run back in hole. Wipe hole to TD. Log gr tie in from 8575'. Add 5' correction. Continue wiper trip to TD tagged at 11501'. 08:30 - 10:15 1.75 DRILL C PROD1 Displace hole to 9.9 ppg KWF with 3 ppb coarse beads. 10:15 - 12:30 2.25 DRILL C PROD1 Continue to POH. Displace tbg to 9.9 ppg kwf. Get a moderate amount of cuttings back as BHA neared surface. 12:30 - 13:00 0.50 DRILL C ~ PROD1 Slow coil speed to allow hole to clean up. Monitor flow while holding PJSM to discuss BHA handling and ~ running liner. Well appears to be stable. 13:00 - 14:15 125 DRILL C ~ PROD1 Get off well. Unstab coil. Purge BHA tools. LD MWD components and re-configure for liner running assembly. Rig up floor to run lines 14:15 - 18:40 4.42 CASE C RUNPRD Make up 57 jts 2-718" 6.16# L80 STL slotted finer w/ indexing guide shoe and Weatherford 3.25" aluminum billet liner top. Found several jts with bad box threads. Replace with additional pipe on location. MU GS and BHI MWD assy PVT 17 18:40 - 19:55 1.25 CASE C RUNPRD RIH w/ liner on CT w/o pump 19:55 - 21:00 1.08 CASE C RUNPRD 34k ~ 8500', PVT 50. RIH thru window, clean. RIH 50-70'/min in OH w/ one minor wt loss at 8800' to TD tagged at 11852' CTD?? (CT counter was also off on prior POH). EOP counter for this run was close to planned TOL depth. PUH 45.4k, clean. Set liner back at TD. Pump 2.0/4000 and GS released from liner at 31 k. Left bottom of liner at 11501' and top of aluminum billet at 9609' PVT 64 21:00 - 21:30 0.50 CASE C RUNPRD POH w/ setting assy thru OH at 0.56/0.3 21:30 - 23:00 1.50 CASE C RUNPRD Open EDC above window. POH sirs 1.4/1970 PVT 10 23:00 - 23:30 0.50 CASE C RUNPRD Flowcheck while conduct safety mtg re: LD BHA & ELSM LD WS setting BHA. Close master/swab 23:30 - 00:00 0.50 DRILL C PROD2 Cut off CTC and remove lower lub from injector 11/19/2005 00:00 - 02:15 2.25 DRILL P PROD2 RU cutter and cut 800' of CT/eline. RD cutter, dispose of CT 02:15 -04:00 1.75 DRILL P PROD2 Replace nearly empty slickline drum w/ new 0.125" wire and PT 04:00 - 05:00 1.00 DRILL P PROD2 Install Kendal CTC. Meg test, PT's 05:00 -06:15 1.25 DRILL P PROD2 Pump stack forward while changing out CT footage counter wheel 06:15 -06:30 0.25 STWHIP P PROD2 PJSM to discuss making up BHA. 06:30 - 07:00 0.50 STWHIP P PROD2 MU sidetrack assembly. 1.5 deg mtr w/ 3.75 HTC SPR335 bit 07:00 - 08:15 i.25 STWHIP P PROD2 Run in hole. Circ at min rate. 08:15 - 08:30 0.25 STWHIP P PROD2 Log gr tie in from 8575'. Subtract 3' correction. 08:30 - 09:15 0.75 STWHIP P PROD2 Continue to run in hole. Circ at 1 bpm in/1.07 out. Tag TOL at 9609' 09:15 - 12:15 3.00 STWHIP P PROD2 Begin time milling on billet at 9609'. 0.1' per 6 minutes. Displace 9.9 KWF to 9.0 flo pro. 3540 psi fs at 2.56 in/2.49 out. TF: 608 NB Inc: 80.53 deg Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 10-02 Spud Date: i 1/512005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: i 1/27/2005 Rig Name: NORDIC 2 Rig Number: Date From -'To Hours Task ' ;,Code NP7 Phase Description of Operations 11/19/2005 09:15 - 12:15 3.00 STWHIP P PROD2 WHP/BHP/ECD: 70/3880/11.34 ppg. IA/OA/PVT: 0/0/115 bbls. Drill to 9635'. 12:15 - 13:00 0.75 STWHIP P PROD2 Back ream at 65R, 15R and 160R. Dry drift. Hole/billet smooth. 13:00 - 15:00 2.00 STWHIP P PROD2 Wiper trip to window. Circulate out of hole. lots of aluminum in retums while POOH, near 1500'. Plugged of choke and by pass tines. Eventually cleaned up. 15:00 - 17:30 2.50 STWHIP P PROD2 At surface. Hold PJSM. Get off well. Unstab coil. Un-deploy BHA. LD BHA tools. 17:30 - 21:30 4.00 STWHIP N MISC PROD2 Clean out surface choke lines. Clean out micro motion. Clean out bypass lines. Also, cleanout aluminum in Baker choke 21:30 - 00:00 2.50 BOPSU P PROD2 Biweekly BOPE test. The right to witness was waived by AOGCC 11!20!2005 00:00 - 02:00 2.00 BOPSU P PROD2 Fin BOPE test 02:00 - 03:00 1.00 DRILL P PROD2 Check well for pressure and on sli vac. Fill hole w/ < 1 bbl Open-hole MU lateral drilling assy w/ res tool 03:00 - 05:10 2.17 DRILL P PROD2 Prep to RIH w/ BHA #13, but return line in cellar was frozen (-44F amb). Circ CT thru Baker choke whiie thaw line. RIH after 20 min and circ thru bit 0.4/1300. Out MM plugged off from more aluminum pieces. Open EDC and circ 2.0/2450 w/ 'out' MM bypassed white RIH. Cleaned up good by 5000' 05:10 - 05:35 0.42 DRILL P PROD2 Park at 8500'. Close EDC, route returns thru 'out' MM Log tie-in down from 8570', corr -10' 05:35 - 06:15 0.67 DRILL P PROD2 Wiper to TD. Hole smooth. 06:15 - 08:45 2.50 DRILL P PROD2 Drill ahead from 9635'. 3600 psi fs at 2.67 in/2.68 out. DPSI; 200-300. DHWOB: 2-3k#. WHP/BHP/ECD: 62/3829/11.2 ppg. IAlOAlPVT: 010!372 bbis. INC/AZMlTF: 82.21-f70R. ROP avg: 55 fph. 08:45 - 10:15 1.50 DRILL P PROD2 Wiper trip to window. 28.5 k# up wt off btm. 3550 psi fs at 2.67 in. PVT: 371 bbls. Hole smooth in both directions. 10:15 - 13:15 3.00 DRILL P PROD2 Drill ahead from 9785'. 3560 psi fs at 2.65 iNout. PVT: 367 bbls. 13:15 - 14:45 1.50 DRILL P PROD2 Wiper trip to window. Hole smooth. 3500 psi fs at 2.63 in/out. PVT: 365 bbls. 14:45 - 17:45 3.00 DRILL P PROD2 Drill ahead from 9935'. Finally found sand around 9960'. 17:45 - 18:30 0.75 DRILL P PROD2 Wiper trip to 7500' 18:30 - 18:55 0.42 DRILL P PROD2 Log tie-in down from 8570', corr +4.5' 18:55 - 19:40 0.75 DRILL P PROD2 Wiper to TD was clean except for wt loss and MW at 8663' PVT 356 19:40 - 23:35 3.92 DRILL P PROD2 Drill from 10085' 2.6112.57/3550/80-100R w/ 100-300 psi dill, 1-5k wob at 89 deg at 6631' TVD in mostly sand w/ minor ankerite streaks. Swap to left at 10200'. Drill to 10245' and stacking PVT 354 23:35 -00:00 0.42 DRILL P PROD2 Wiper to window 11/21!2005 00:00 - 01:25 1.42 DRILL P PROD2 Finish wiper to window, clean both directions PVT 352 01:25 - 03:15 1.83 DRILL P PROD2 Drill from 10245' 2.6/2.57/3580/85-100L w/ 100-350 psi dill, 1-3.5k wob w! 11.4 ECD at 90 deg at 6632' TVD PVT 347 03:15 - 05:15 2.00 DRILL P PROD2 Wiper to window, clean both directions PVT 341 05:15 -08:00 2.75 DRILL P PROD2 Drill from 10400' 2.60/2.56/3600/85-110L w/ 100-350 psi dill, 1-3.5k w/ 11.46 ECD at 91 deg at 6631' TVD 08:00 - 10:15 2.25 DRILL P PROD2 Wiper trip to window. Log GR tie in. Add 3' correction. 3644 Printed: 71!28/2005 12:59:Q4 PM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 10-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/21/2005 08:00 - 10:15 2.25 DRILL P PROD2 psi fs at 2.65 bpm. PVT: 335 bbls. 10:15 - 15:00 4.75 DRILL P PROD2 Drill ahead from 10,550'. 3700 psi fs at 2.68 in/2.64 out. PVT: 326 bbls. 90.5 deg at 6628' TVD. Hit a few slow spots. Possibly ankorite. 15:00 - 17:15 2.25 DRILL P PROD2 Wiper trip to window. 3730 psi fs at 2.67 bpm. Load trucks for mud swap. Thaw upright valves. 17:15 - 21:00 3.75 DRILL P PROD2 Drill ahead from 10700'. Get into ankerite at 10738' and point TF down 21:00 - 21:50 0.83 DRILL P PROD2 Start new mud at 10757' 2.6/2.57/3630/165L w/ 200 psi dill and 5.4k wob w/ 11.46 ECD and still drilling ankerite 21:50 - 22:55 1.08 DRILL P PROD2 Break out of ankerite at 10762' and drill 2.6/2.58/3400/85L w/ 100-400 psi dill and 1.5-2.5k wob w/ 11.0 ppg ECD after hole ~ displaced 22:55 - 00:00 1.08 DRILL P PROD2 Wiper to window was clean 1 i/22/2005 00:00 - 01:25 1.42 DRILL P PROD2 Wiper back to TD was clean 01:25 - 03:20 1.92 DRILL P PROD2 Drill from 10850' 2.6/2.56/3500/90L w/ 100-300 psi dill, 1.5-2.5k wob w/ 11.2 ECD at 88 deg at 6641' TVD 03:20 - 05:15 1.92 DRILL P PROD2 Wiper to window, clean. Pull thru window and wiper to 8000', clean. Wiper back in hole 05:15 - 05:30 0.25 DRILL P PROD2 Log tie-in down from 8570', corr+4.5' 05:30 - 06:45 1.25 DRILL P PROD2 Wiper back to TD. Hole smooth. 06:45 - 10:45 4.00 DRILL P PROD2 Drill ahead from 11,000'. 3410 psi fs at 2.57 in/out. 200-300 DPSI DHWOB: 2k-3k#. WHP/BHP/ECD: 66/3854111.19 ppg. IA/OAJPVT: 143/44/390 bbls. INC/AZM/TF: 89.1/4.5/105L. ROP: 30-50 fph. Some short hard spots, mostly good looking sand. 10:45 - 13:45 3.00 DRILL P PROD2 Wiper to window 13:45 - 17:25 3.67 DRILL P PROD2 Drill from 11150' 2.6/2.57/35000/70-90L w/ 1-3.5k wob, 100-300 psi dill w/ 11.32 ECD at 90 deg at 6642' TVD. Swap to right at 11220' 17:25 - 19:35 2.17 DRILL P PROD2 Wiper to window. Setdown at 9624' pick-up once and went through. Okay to bottom. 19:35 - 22:05 2.50 DRItL P PROD2 Drill ahead fl 11300' to 11305' then hit Ankorite stringer 2.66/2.60 3450 fs 2-300 mw 4-5k wob 10'/hr 22:05 - 22:15 0.17 DRILL P PROD2 Short wiper trip to 11200' 22:15 - 00:00 1.75 DRILL P PROD2 Drill Ankorite f/ 11319' to 11330' 4k wob. 11/23/2005 00:00 -04:10 4.17 DRILL PROD2 Drilling ahead f/ 11330'. Came out of Ankorite at 11336' then back in at 11341'. Adjust TF to 1258 to aggressively drop below Ankorite. Still in Ankorite at 11356'. Set TF to 180. 2.65/2.60 3500fs 2-300 mw 5k wob 11.4ppg ECD 04:10 - 05:15 1.08 DRILL PROD2 Drilling ahead in good sand. 3k wob 90'/hr positive 6-7k coil wt. Bring TF to 508 05:15 - 07:20 2.08 DRILL PROD2 Wiper trip to window was clean. Pull thru window and wiper to 8000', clean. Wiper back in hole 07:20 - 07:35 0.25 DRILL PROD2 Log tie-i~ down from 8570', corr +6.5' 07:35 -09:00 1.42 DRILL PROD2 Wiper back to TD was clean PVT 319 09:00 - 13:05 4.08 DRILL PROD2 Drill from 11452' 2.63/2.58/3490/1658 w/ 200-400 psi dill, 2-3k wob w/ 11.56 ECD at 6641' TVD at 92 deg. Find ankerite at 11472' and 11565', but otherwise drill at 60'/hr w/ 6.8k str wt w/ 2.8k wob. Swap to left at 11550' PVT 311 13:05 - 16:20 3.25 DRILL PROD2 Wiper to window, clean both directions 16:20 - 19:00 2.67 DRILL PROD2 Drill from 11598' 2.6/2.54/3530/60L w/ 200-400 psi dill, 2-3k wob w/ 4k str wt w/ 11.59 ECD at 89 deg at 6638' TVD Printed: 11M28/2005 12:59:04 PM BP EXPLORATION Page t4 of '16 Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 1 Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: 'Date From - To Hours .'Task Code NPT 'Phase Description of Operations 11/23/2005 19:00 - 22:45 3.75 DRILL PROD2 Wiper trip to window. Hole in good condition. 22:45 - 00:00 1.25 DRILL PROD2 Directionally drill ahead f/ 11738' 2.62/2.57 3820fs 200-300 mw, 2-3k wob 80'/hr 4k CT wt. ECD 11.7ppg Presently at 6644' tvd plan is to drop to 6660' tvd by 11900'. Ran into Ankorite at 11780'. 11/24/2005 00:00 - 03:30 3.50 DRILL P PROD2 Drill f/ 11783' to 11808' in Ankorite w/ 180 TF. Swapped to new 9.2ppg FloPro mud system. 2.60/2.63 3550fs <50psi mw 11.6ECD 4.5k wob 03:30 -04:00 0.50 DRILL P PROD2 Short wiper trip to 11200'. 04:00 - 06:00 2.00 DRILL P PROD2 Drill ahead on Ankorite section. Same parameters. ECD dropping with new mud system 11.42ppg Seeing small pieces of motor's stator rubber occassionally coming across shaker since midnight. 06:00 - 07:45 1.75 DRILL P PROD2 Final check of parameters while attempting to drill at 11811' 2.64/2.6/3560/179L w/ 50-100 psi dill, 4k wob w/ -13k surface wt at 11.41 ECD at 89 deg w/o progress (assume motor and bit are shot). PVT 250 Wiper to window w/ minor overpult and MW at 9637' 07:45 - 09:10 1.42 DRILL P PROD2 POH, circ thru bit 2.85/3500 following pressure schedule 09:10 - 09:25 0.25 DRILL P PROD2 Safety mtg while flowcheck PVT 180 09:25 - 10:50 1.42 DRILL P PROD2 LD drilling assy. Reconfigure for tractor run wIo resistivity. Sit was rung out on nose (had first two cutter visible) and motor was loose 10:50 - 11:05 0.25 DRILL P PROD2 Safety mtg re: MU/test tractor assy 11:05 - 13:00 1.92 DRILL P PROD2 RU to use standpipe line for surface test of tractor. MU motor w/o bit and attach tractor. Close bag. Bring rate up in stages and find that wheels turn at 1.5 bpm and open at 2.0 bpm. RD test setup/MU used CRXE bit. MU MWD on tractor assy 13:00 - 14:20 1.33 DRILL P PROD2 RIH w/ BHA #14 (1.2 deg motor, used CRXE bit w/ Weltec tractor tool) circ 0.3!1200 thru bit following pressure schedule 14:20 - 14:35 0.25 DRILL P PROD2 Log tie-in down from 8570', Corr +10' 14:35 - 16:00 1.42 DRILL P PROD2 Wiper in hole at 1.5/2490 was clean 16:00 - 16:30 0.50 DRILL P PROD2 Start motor/tractor at 11700' 2.47/2.47/3988 and ream while zeroing wob sensor while RIH 11'/min. Tag TD ~ 11810'? at 1.0 bpm. PUH 36k. Start motor, ease in hole looking for TD. Seem to find it at 11811', but have 11.4k pos string wt, zero dill PVT 317 16:30 - 17:45 1.25 DRILL P PROD2 Drill ahead from 11813' while teaming how to drill w/ tool 2.44l2.43l3900(110L w/ 2.5k wob, 0-150 psi dill w/ 11.5 ECD at 88 deg at 6646'. In and out of ankerite 17:45 - 18:35 0.83 DRILL P PROD2 Drilled to 11830' motor started to stall and SLB trips shutdown pump at 4600psi. May be out of Ankerite. 18:35 -00:00 5.42 DRILL P PROD2 Stabilizer pressures at 1000psi. PU string to 11800'. Slowly RIH pum at 2.47 stop and check Tractor function/pull test 9201bs -good. Slowly RIH tag bottom. Resume drilling at 55'/hr 2k wob 9600# CTW 2.47/2.44 3900fs 200mw 11.45ppg ECD Back into Ankerite at 11840' 15ppsi mw 4k wob -5000# CTW. TF 180 11/25/2005 00:00 - 01:50 1.83 DRILL P PROD2 Have been drilling on Ankerite last 6 hrs. No progress last 1-1/2 hrs. (bit maybe) Slowdown pump to relax Tractor wheels. PU off btm 36.2k. Open EDC. Pump at 2.55bpm short trip to 11000'. RIH to 11650' and close EDC. BHi surface equipment indicates the EDC has a "position missed error". The EDC is Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page_ 15 of 16 Operations-Summary Report Legal Well Name: 1Q-02 Common Well Name: iQ-02 Spud Date: 11!5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!27/2005 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours TasK Code 'NPT Phase Description of Operations 11/25/2005 00:00 - 01:50 1.83 DRILL P PROD2 closed but no attempt to open it again should be made or it could go into the "disconnect" mode. Only option is to TOH. This EDC has 340hrs on it. 01:50 -04:45 2.92 DRILL N PROD2 TOH. EDC is closed. Having the Tractor in the string we can only pump at 1.5bpm maximum. 04:45 - 05:00 0.25 DRILL N PROD2 PJSM for changing out BHA componets and monitor well. 05:00 - 06:00 1.00 DRILL N PROD2 LD BHA. Bit was rung out on nose w! one cutter visible on nose. Tractor wheels were wom, tool was full of cuttings and profusely leaking hydraulic fluid. Welter elected not to run backup tool due to hole conditions 06:00 - 08:00 2.00 DRILL P , PROD2 Discuss w/ Asset and will drill to planned TD of around 12050' while looking for A3 marker w/ GR. Scribe motor, load out tractor tools while wo new CHXE bit (to keep test conditions I similar). MU BHA 08:00 - 09:30 1.50 DRILL P ~ ~ i PROD2 RIH w/ BHA #15 (1.2 deg motor, used 1-1-I CHXE bit from I L5-17) circ thru bit 0.3/1190 following pressure schedule 09:30 - 09:50 0.33 DRILL P PROD2 Log tie-in down from 8570', Corr +12' 09:50 - 11:45 1.92 DRILL P PROD2 Wiper back to TD and normal rates 2.4!3300 ~ 35'/min. Had several setdowns between 11450-550'. Tag TD at 11846' 11:45 - 15:30 3.75 DRILL P PROD2 Resume drilling ankerite 2.54/2.51/3585/90-170L w/ 3.5-4.Ok wob, 250 psi dill at 11.5 ECD at 80 deg. Get out of ankerite at 11855' and back to 50'/hr. Drill to 12000' (6665' TVD) 15:30 - 17:25 1.92 DRILL P PROD2 Wiper to window 17:25 - 18:00 0.58 DRILL P PROD2 Log tie-in down from 8570' +2.5' 18:00 - 19:35 1.58 DRILL P PROD2 Wiper back to bottom. No problems 19:35 - 21:00 1.42 DR1LL P PROD2 Driil ahead f/ 12000'. 2.63/2.62 3740fs 350mw ECD 11.7ppg, 2k wob +3500 CTW 50'/hr Drilled to 12050' TD 21:00 - 00:00 3.00 DRILL P PROD2 Wiper to window. Clean pu off bottm 33.6k. Clean to window. RIH 11/26!2005 00:00 - 01:00 1.00 DRILL PROD2 Finish wiper trip to bottom 12050'. No problems. 01:00 -04:10 3.17 DRILL PROD2 TOH for liner. Spot new 9.2ppg Flo-Pro pill with 3ppb Alpine Beads in openhole. Stop at 100' flow-check well. Hold PJSM for UD BHA same time. Well dead. 04:10 -04:45 0.58 DRILL PROD2 Tag-up. Unstab injector. UD BHA #15 04:45 - 05:00 0.25 CASE RUNPRD PJSM review liner running procedures, and potential hazards. Review liner running order and liner jewelry. 05:00 - 05:15 0.25 CASE RUNPRD RU tongs and 2-7/8" elevators. MU TIW to solid jt 2-7/8". 05:15 - 12:10 6.92 CASE RUNPRD MU 103 jts 2-7/8" 6.16# L-80 STL R2 slotted liner, plus 6 jts 3-3/16" 6.2# L-80 TCII R2 solid liner w/ guide shoe, o-ring sub, LSL sub and 3-1/2" BTT Deployment sub (3553.44' OA). MU BHI MWD assy 12:10 - 13:00 0.83 CASE RUNPRD RIH w/ BHA #16 (liner on CT). Initial CT surface wt 11 k. Circ thru GS 0.35/1500 following pressure schedule 13:00 - 14:00 1.00 CASE RUNPRD Wt chk ~ 8500'=37k. RIH thru window clean. RIH in OH w/ liner at 70'/min and tag TD at 12034'. PUH 55k for 40', clean. RBIH and set liner at TD 14:00 - 14:10 0.17 CASE RUNPRD Incr pump and bleed off WHP 1.7!4200. PUH 30.5k and released GS from liner leaving TOL at 8496.56' w! shoe at 12050'. Open EDC 14:10 - 15:45 1.58 CASE RUNPRD POH circ 1.5/2150 following pressure schedule 15:45 - 16:30 0.75 CASE RUNPRD Check well for flow. LD BTT GS and MWD tools 16:30 - 17:00 0.50 WHSUR POST MU nozzle assy w/ stinger Printed: 1128/2005 12:59:04 PM BP EXPLORATION Page 16 of 16 Oper-ations Summary Report Legal Well Name: 1 Q-02 Common Well Name: 1 Q-02 Spud Date: 11 /5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date From- To -Hours Task Code 'NPT Phase Description_of Operations 11/26/2005 17:00 - 20:00 3.00 WHSUR POST RIH following pressure schedule while circ 30 bbls rig water followed by 160 bbls diesel to 8400'. TOH displacing tbg with diesel. Shut MV/SV trapping 950psi on well. 20:00 - 20:45 0.75 WHSUR POST RU N2 equipment. 20:45 - 21:00 0.25 WHSUR POST PJSM review blowdown procedures and hazards. 21:00 - 23:20 2.33 ~ WHSUR POST PT N2 lines to 4000psi. Load coil with 20 bbls methanol. ~; Seeing higher than normal pump pressures at fow pump rate. Unstab injector. Find both BHI check valves trash. Lower check valve's baffle worn off stem that holds it in place. Upper/lower valve both had high errosion wear. ' Stab back on well. Pump remaining meth and blow down reel 23:20 - 00:00 ~ 0.67 ~ WHSUR POST with N2. Bleed off pressures. LD nozzle BHA and BHI upperllower quick connect. Cut-off j ` Kendle connector. 11/27/2005 i 00:00 - Oi :30 1.50' RIGD P POST Install internal grapple to end of 2-3/8" coil. Prep to unstab from injector and secure end to reel. 01:30 - 01:45 0.25'!, RIGD P POST PJSM review procedures and hazards for unstabbing coil. 01:45 - 02:15 0.50; RIGD P POST Pull back coil to reel and secure. Prep to lower reel , 02:15 - 07:30 5.25 i RIGD P POST Lower reel. Remove pack-off from injector and secure to rig floor. Change out BOP rams to 2". NDBOP stack and install tree cap. Clean rig pits. Empty cuttings and Tiger tank. ~ ~ RREL C~3 0730 hrs Additional comments found on 1 L-25 report of same date Printed: t t/28/2005 12:59:04 PM ' ~ BP Alaska '~ Baker Hughes INTEQ Survey Report BAKER NYGHE$ INTEQ Company: ConocoPhillips Alaska, Inc. Uate: 1 /1 212 0 06 Time 05:38:24 Page: l Field: Kuparuk River Unit Co-ordinate(\E) Reference: Well: 2, True North Site: KRU 1Q Pad Vertical ('fVD) Refereuce: Datum 2 78.0 i Well: 2 Section (VS) Reference: Well (O.OON,O.OOE,50.91Azi) Wellpath: 1Q-02BPB1 Survey Calculation Method: Minimum Curvature Dh: Sybase _~ - - Field: Kuparuk River Unit - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1Q Pad UNITED STATES: North Slope Site Position: Northing: 5985877.04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 2 Slot Name: Well Position: +N/-S -1206.00 ft Northing: 5984666.52 ft Latitude: 70 22 9.094 N +E/-W -1175.00 ft Easting : 528447.63 ft Longitude: 149 46 7.777 W Position Uncertainty: 0.00 ft Wellpath: 1Q-02BPB1 Drilled From: 1Q-02A Tie-on Depth: 8546.11 ft Current Datum: Datum 2 Height 78.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/14/2005 Declination: 24.10 deg Field Strength: 57607 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E!-W Direction ft ft ft deg 78.00 0.00 0.00 50.91 Survey Program for Definitive Wellpath Date: 9/14/2005 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 88.00 6300.00 GMS (88.00-8564.00) (0) Good gyro Good Gyro 6392.91 7625.15 MWD (6392.91-8345.00) (1) MWD MWD -Standard 7677.06 8418.17 MWD (7677.06-9017.00) (2) MWD MWD -Standard 8539.00 10552.00 MWD (8539.00-10552.00) MWD MWD -Standard Annotation ~IU iVD ft ft 8418.17 6438.52 TIP ___ 8539.00 6516.27 KOP 10552.00 6670.21 TD Survey: MWD Start Date: 11/15!2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey DID ft tncl deg Azim deg TVD ft Sys'fVD ft N/S ft E/W ft D7apN ft MapE ft VS ft DLS "fool deg/100ft 8418. 17 49 .87 89 .98 6438. 52 6360. 52 1712. 26 3977. 34 5986393 .71 532418 .04 4166 .72 0.00 MWD • 8539. 00 50 .03 87 .81 6516. 27 6438. 27 1714. 05 4069. 80 5986395 .85 532510 .49 4239 .62 1.38 MWD 8560. 53 50 .70 87 .30 6530. 01 6452. 01 1714. 75 4086. 37 5986396 .62 532527 .05 4252 .92 3.61 MWD 8589. 96 53 .01 77 .30 6548. 21 6470. 21 1717. 88 4109. 25 5986399 .83 532549 .91 4272 .65 27.83 MWD 8620. 69 56 .88 67 .30 6565. 89 6487 .89 1725. 56 4133. 14 5986407 .60 532573 .77 4296 .04 29.44 MWD 8650. 19 59 .31 58 .30 6581. 50 6503. 50 1737. 01 4155. 37 5986419 .13 532595 .95 4320 .51 27.17 MWD 8678. 91 62 .59 50 .29 6595. 46 6517. 46 1751. 67 4175. 71 5986433 .87 532616 .24 4345 .54 26.91 MWD 8710. 67 66 .28 41 .67 6609. 19 6531. 19 1771. 57 4196. 26 5986453 .85 532636 .71 4374 .04 27.09 MWD 8740. 83 69 .73 31 .31 6620. 51 6542. 51 1794. 03 4212. 84 5986476 .37 532653 .20 4401 .07 33.83 MWD 8772. 70 77 .15 30 .30 6629. 59 6551 .59 1820. 25 4228. 46 5986502 .64 532668 .73 4429 .73 23.48 MWD 8801. 76 84 .39 27 .45 6634. 24 6556. 24 1845. 35 4242. 30 5986527 .80 532682 .46 4456 .30 26.73 MWD 8830. 11 90 .20 23 .97 6635. 58 6557. 58 1870. 85 4254. 57 5986553 .34 532694 .64 4481 .90 23.88 MWD 8858. 80 91 .73 16 .43 6635. 10 6557. 10 1897. 76 4264. 47 5986580 .28 532704 .44 4506 .55 26.81 MWD 8890. 35 88 .60 15 .50 6635. 01 6557. 01 1928. 08 4273. 15 5986610 .63 532713 .00 4532 .41 10.35 MWD BP Alaska ~ BAKERS HUGHES Baker Hughes INTEQ Survey Report iNTEQ - - -_ __ Company: ConocoPhillips Alaska, Inc. Date: 1/12/2006 Time: 05:38:24 Nage: ? Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 2, True North Site: KRU 1Q Pad Vertical (TVD) Reference: Datum 2 78.0 ~i'ell~ 2 ~ Section (VS) Reference: Well (O.OON,O.OOE,50.91Azi) y V1'~ll ath: 1Q-02BPB1 _ Survev Calculatimi Method_ Minimum Curvature. llb: S base Sur~'cv MD Incl Azim TVD Sys"I'VD N/S F/W MapN 19apE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft ~___ _ _ _ __ __ _ _ _ - - __- _ _ - _ - _ _ --I 8921.11 88.88 11.68 6635.68 6557.68 1957.97 4280.37 5986640.55 532720.11 4556.86 12.45 MWD 8950.70 88.51 9.17 6636.36 6558.36 1987.06 4285.73 5986669.65 532725.35 4579.35 8.57 MWD 8981.47 87.92 4.57 6637.32 6559.32 2017.59 4289.40 5986700.19 532728.91 4601.46 15.06 MWD 9016.14 86.78 2.57 6635.92 6560.92 2052.15 4291.56 5986734.76 532730.93 4624.92 6.63 MWD 9046.43 87.59 358.02 6640.41 6562.41 2082.40 4291.72 5986765.00 532730.97 4644.11 15.24 MWD 9075.31 85.21 356.61 6642.22 6564.22 2111.18 4290.37 5986793.78 532729.52 4661.22 9.57 MWD 9106.68 87.62 354.71 6644.18 6566.18 2142.40 4288.00 5986824.98 532727.03 4679.06 9.78 MWD 9136.55 88.71 351.50 6645.14 6567.14 2172.03 4284.41 5986854.60 532723.33 4694.96 11.34 MWD 9166.75 87.10 349.38 6646.24 6568.24 2201.79 4279.40 5986884.34 532718.21 4709.84 8.81 MWD 9195.13 85.03 347.51 6648.19 6570.19 2229.53 4273.73 5986912.05 532712.43 4722.92 9.82 MWD 9226.49 83.28 344.30 6651.39 6573.39 2259.78 4266.14 5986942.27 532704.72 4736.10 11.61 MWD 9255.68 82.94 340.75 6654.89 6576.89 2287.42 4257.44 5986969.87 532695.92 4746.78 12.13 MWD 9286.31 84.88 337.36 6658.14 6580.14 2315.86 4246.55 5986998.27 532684.93 4756.26 12.70 MWD 9315.28 85.93 335.62 6660.46 6582.46 2342.34 4235.03 5987024.70 532673.31 4764.01 7.00 MWD 9345.11 86.48 332.12 6662.44 6584.44 2369.05 4221.92 5987051.36 532660.10 4770.68 11.85 MWD 9375.67 85.10 329.91 6664.68 6586.68 2395.71 4207.16 5987077.96 532645.23 4776.03 8.51 MWD 9404.99 85.93 325.75 6666.97 6588.97 2420.45 4191.60 5987102.64 532629.58 4779.55 14.43 MWD 9436.86 86.85 321.84 6668.98 6590.98 2446.11 4172.81 5987128.22 532610.70 4781.15 12.58 MWD 9466.44 86.39 321.87 6670.72 6592.72 2469.33 4154.57 5987151.37 532592.38 4781.63 1.56 MWD 9499.46 86.94 326.74 6672.65 6594.65 2496.09 4135.35 5987178.06 532573.05 4783.58 14.82 MWD 9530.65 85.84 328.56 6674.61 6596.61 2522.39 4118.69 5987204.29 532556.30 4787.24 6.81 MWD 9560.40 84.49 331.65 6677.12 6599.12 2548.08 4103.92 5987229.93 532541.43 4791.97 11.30 MWD 9589.64 80.48 333.37 6680.94 6602.94 2573.79 4090.54 5987255.58 532527.95 4797.80 14.90 MWD 9627.01 82.63 338.66 6686.43 6608.43 2607.55 4075:52 5987289.28 532512.81 4807.43 15.14 MWD 9663.12 82.23 340.37 6691.19 6613.19 2641.08 4063.00 59$7322.76 532500.16 4818.85 4.82 MWD 9700.10 85.63 343.97 6695.10 6617.10 2676.08 4051.74 5987357.71 532488.77 4832.18 13.35 MWD 9730.65 87.71 345.27 6696.88 6618.88 2705.48 4043.66 5987387.08 532480.57 4844.44 8.02 MWD 9760.07 91.67 347.28 6697.04 6619.04 2734.06 4036.68 5987415.62 532473.49 4857.04 15.09 MWD 9790.41 94.02 350.45 6695.53 6617.53 2763.78 4030.82 5987445.32 532467.52 4871.24 13.00 MWD 9821.97 94.87 351.29 6693.08 6615.08 2794.85 4025.83 5987476.37 532462.41 4886.95 3.78 MWD 9850.23 93.09 355.33 6691.12 6613.12 2822.84 4022.55 5987504.34 532459.02 4902.05 15.59 MWD 9880.58 92.63 356.16 6689.61 6611.61 2853.07 4020.30 5987534.56 532456.66 4919.37 3.12 MWD 9913.50 93.30 359.16 6687.90 6609.90 2885.91 4018.96 5987567.40 532455.19 4939.04 9.33 MWD 9946.00 94.35 2.24 6685.74 6607.74 2918.34 4019.35 5987599.82 532455.47 4959.78 9.99 MWD 9976.94 95.09 5.42 6683.19 6605.19 2949.10 4021.41 5987630.58 532457.41 4980.78 10.52 MWD 10005.09 94.84 7.53 6680.75 6602.75 2976.96 4024.58 5987658.46 532460.46 5000.80 7.52 MWD 10035.58 92.38 8.63 6678.83 6600.83 3007.09 4028.85 5987688.59 532464.63 5023.12 8.84 MWD 10069.77 89.40 9.26 6678.30 6600.30 3040.85 4034.17 5987722.3$ 532469.81 5048.53 8.91 MWD 10100.38 89.25 11.74 6678.66 6600.66 3070.94 4039.74 5987752.49 532475.27 5071.83 8.12 MWD 10130.84 89.37 14.11 6679.03 6601.03 3100.63 4046.56 5987782.19 532481.97 5095.84 7.79 MWD 10161.07 89.80 16.68 6679.25 6601.25 3129.77 4054.58 5987811.36 532489.89 5120.44 8.62 MWD 10191.22 89.49 19.25 6679.43 6601.43 3158.45 4063.88 5987840.07 532499.07 5145.74 8.59 MWD 10221.72 90.51 21.87 6679.43 6601.43 3187.00 4074.59 5987868.66 532509.67 5172.06 9.22 MWD 10250.04 90.91 24.08 6679.08 6601.08 3213.07 4085.64 5987894.77 532520.63 5197.07 7.93 MWD 10291.22 92.38 27.05 6677.90 6599.90 3250.20 4103.40 5987931.97 532538.24 5234.27 8.04 MWD 10322.66 90.66 28.25 6677.07 6599.07 3278.04 4117.99 5987959.86 532552.72 5263.14 6.67 MWD 10352.94 90.26 31.48 6676.82 6598.82 3304.29 4133.06 5987986.16 532567.70 5291.39 10.75 MWD 10382.50 90.69 33.66 6676.58 6598.58 3329.20 4148.97 5988011.13 532583.51 5319.45 7.52 MWD 10412.72 90.41 35.49 6676.29 6598.29 3354.08 4166.12 5988036.07 532600.56 5348.45 6.13 MWD 10441.26 90.20 38.26 6676.14 6598.14 3376.91 4183.25 5988058.97 532617.60 5376.13 9.73 MWD 10471.20 92.32 41.21 6675.48 6597.48 3399.92 4202.38 59$8082.05 532636.64 5405.49 12.13 MWD 10503.30 94.14 43.78 6673.67 6595.67 3423.55 4224.02 5988105.76 532658.19 5437.19 9.80 MWD 10552.00 94.00 43.78 6670.21 6592.21 3458.63 4257.63 5988140.96 532691.67 5485.39 0.29 MWD Baker Hu ConocaPhillips ghes INTEQ Baker Hughes INTEQ Survey Report ~; { $l~Yi~R ti!UGHES 1~*~1 t+~fy Company: ConocoPhillipsAlaska, Inc. Date: 1/13/2006 'time: 12:52:13 Pale: t Field: Kuparuk River Unit Co-ordmate(NF,) Reference: Well. 2, True North f ,Site: KRU 1Q Pad Vertical ("fVD) Reference: Datum 2 78.0 ~ Well: 2 Section (VS) Reference: Well (O.OON,O.OOE,45.23Azi) I Wellpath: 1 Q-02B Survey Calculation Method: Minimum Curvature llb: Oracle Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ~ Geo Datum: NAD27 (C{arke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004 Site: KRU 14 Pad UNITED STATES: North Slope Site Position: Northing: 5985877.04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 2 Slot Name: Well Position: +N/-S -1206.00 ft Northing: 5984666.52 ft Latitude: 70 22 9.094 N +E/-W -1175.00 ft Easting : 528447.63 ft ~ Longitude: 149 46 7.777 W Position Uncertainty: 0.00 ft Wellpath: 1Q-026 Drilled From: 1Q-02BPB1 Tie-on Depth: 9976.94 ft Current Datum: Datum 2 Height 78.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/16/2005 Declination: 24.02 deg Field Strength: 57614 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 78.00 0.00 0.00 45.23 Survey Program for Definitive Wellpath Date: 11/16/2005 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 88.00 6300.00 GMS (88.00-8564.00) (0) Good gyro Good Gyro 6392.91 7625.15 MWD (6392.91-8345.00) (1) MWD MWD -Standard 7677.06 8418.17 MWD (7677.06-9017.00) (2) MWD MWD -Standard 8539.00 9976.94 MWD (8539.00-10552.00) (3) MWD MWD -Standard 9981.04 11500.00 MWD (9981.04-11500.00) MWD MWD -Standard Annotation ~ - ~ ~ 1'ID __- _ __ __ __- _ -- _ _- ~ _ ~~~ TVD ft ft 9976.94 6683.19 TIP 9981.04 6682.86 KOP Survey: MWD Start Date: 11/16/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ConocoPhillips ~ Baker Hughes INTEQ ~ ~~~~~~' ~~~~~~ Baker Hughes INTEQ Survey Report , ~ ~ €:. ~, -- ~ Company: ConocoPhillips Alaska, Inc. Date: 1/13/2006 Timr. 12:52:13 P~ =e: 2 Field: Kuparuk River Unit Co-ordinate(\EI Reference: Well: 2, True North Site: KRU 14 Pad Vertical (TVD) Reference: Datum 2 78.0 Well: 2 Section (VS) Reference: Well (O.OON,O.OOE,45.23Azi) i Wcllpath: 1Q-02B Survev Calculation Method: Minimum Curvature D6: Oracle Survev J9D Inc{ Azim l'VD SS TVD N)S E/~'~' - V1ap\ b1apE VB ULS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9976.94 95.09 5.42 6683.19 6605.19 2949.10 4021.41 5987630.58 532457.41 4931.88 0.00 M W D 9981.04 94.20 5.27 6682.86 6604.86 2953.17 4021.79 5987634.65 532457.77 4935.02 22.01 MWD 9991.74 91.95 5.19 6682.28 6604.28 2963.81 4022.77 5987645.29 532458.71 4943.20 21.04 MWD 10021.06 88.05 7.12 6682.28 6604.28 2992.95 4025.91 5987674.45 532461.74 4965.96 14.84 MWD 10050.51 88.08 10.25 6683.28 6605.28 3022.04 4030.35 5987703.55 532466.07 4989.60 10.62 M W D 10080.76 87.84 12.34 6684.35 6606.35 3051.69 4036.27 5987733.22 532471.88 5014.69 6.95 MWD 10110.21 87.25 15.43 6685.62 6607.62 3080.24 4043.33 59$7761.80 532478.83 5039.81 10.67 MWD 10141.23 89.31 18.94 6686.55 6608.55 3109.86 4052.49 5987791.45 532487.87 5067.17 13.12 MWD 10171.03 90.29 20.67 6686.65 6608.65 3137.90 4062.59 5987819.52 532497.86 5094.08 6.67 MWD 10200.56 91.06 24.70 6686.30 6608.30 3165.13 4073.98 5987846.80 532509.14 5121.35 13.89 MWD 10233.69 91.12 27.78 6685.67 6607.67 3194.84 4088.62 5987876.56 532523.67 5152.67 9.30 MWD 10276.03 90.66 30.90 6685.01 6607.01 3231.74 4109.36 5987913.53 532544.27 5193.38 7.45 M W D 10305.12 89.55 34.05 6684.96 6606.96 3256.28 4124.98 5987938.12 532559.79 5221.75 11.48 MWD 10335.35 89.68 37.58 6685.16 6607.16 3280.79 4142.66 5987962.70 532577.38 5251.57 11.68 MWD 10365.05 88.97 40.10 6685.51 6607.51 3303.92 4161.29 5987985.90 532595.92 5281.08 8.81 MWD 10395.18 89.80 43.95 6685.84 6607.84 3326.29 4181.45 5988008.35 532616.00 5311.15 13.07 M W D 10425.27 89.80 46.64 6685.94 6607.94 3347.46 4202.84 5988029.59 532637.30 5341.24 8.94 MWD 10455.01 89.68 49.46 6686.08 6608.08 3367.34 4224.95 5988049.55 532659.34 5370.94 9.49 MWD 10485.13 88.76 48.39 6686.49 6608.49 3387.13 4247.66 5988069.42 532681.96 5400.99 4.68 MWD 10515.44 89.12 45.03 6687.05 6609.05 3407.90 4269.71 5988090.28 532703.94 5431.28 11.15 MWD 10546.08 87.04 41.79 66$8.08 6610.08 3430.14 4290.75 5988112.60 532724.89 5461.88 12.56 MWD 10575.19 86.21 38.45 6689.79 6611.79 3452.36 4309.48 5988134.89 532743.53 5490.82 11.80 MWD 10604.94 87.25 35.98 6691.49 6613.49 3476.01 4327.44 5988158.61 532761.40 5520.23 9.00 MWD 10634.25 88.79 33.26 6692.50 6614.50 3500.12 4344.08 5988182.77 532777.94 5549.02 10.66 MWD 10663.99 88.20 31.11 6693.28 6615.28 3525.28 4359.91 5988207.99 532793.68 5577.98 7.49 MWD 10694.09 89.46 28.39 6693.90 6615.90 3551.40 4374.84 5988234.16 532808.51 5606.98 9.96 MWD 10724.43 91.06 25.40 6693.76 6615.76 3578.45 4388.57 5988261.27 532822.13 5635.78 11.18 MWD 10754.89 91.64 23.18 6693.04 6615.04 3606.21 4401.09 5988289.07 532834.55 5664.22 7.53 MWD 10783.42 91.37 20.95 6692.29 6614.29 3632.64 4411.80 5988315.53 532845.16 5690.43 7.87 MWD 10813.25 90.48 16.65 6691.81 6613.81 3660.87 4421.41 5988343.50 532854.66 5717.14 14.72 MWD 10843.71 90.78 14.02 6691.47 6613.47 3690.24 4429.47 5988373.19 532862.60 5743.54 8.69 MWD 10873.38 90.11 8.78 6691.24 6613.24 3719.31 4435.33 5988402.29 532868.35 5768.18 17.80 MWD 10905.56 90.05 4.19 6691.20 6613.20 3751.28 4438.96 5988434.26 532871.87 5793.27 14.26 MWD 10936.89 88.97 1.05 6691.47 6613.47 3782.57 4440.40 5988465.56 532873.18 5816.32 10.60 MWD 10965.79 88.11 358.34 6692.20 6614.20 3811.45 4440.24 5988494.44 532872.91 5836.56 9.84 MWD 10995.72 87.35 355.75 6693.39 6615.39 3841.32 4438.70 5988524.30 532871.26 5856.50 9.01 MWD 11025.07 86.97 353.43 6694.84 6616.84 3870.50 4435.94 5988553.46 532868.39 5875.09 8.00 MWR 11055.27 85.78 349.89 6696.75 6618.75 3900.32 4431.57 5988583.26 532863.90 5892.98 12.34 MWD 11086.36 86.06 346.60 6698.97 6620.97 3930.67 4425.25 5988613.59 532857.47 5909.88 10.59 MWD 11125.10 85.84 342.42 6701.70 6623.70 3967.90 4414.93 5988650.78 532847.01 5928.77 10.78 MWD 11155.34 88.82 339.80 6703.11 6625.11 3996.48 4405.15 5988679.31 532837.13 5941.96 13.11 MWD 11185.48 87.84 342.92 6703.99 6625.99 4025.02 4395.53 5988707.81 532827.39 5955.22 10.85 MWD 11219.29 87.84 345.61 6705.27 6627.27 4057.54 4386.36 5988740.29 532818.11 5971.62 7.95 MWD 11249.15 86.82 348.89 6706.66 6628.66 4086.63 4379.78 5988769.35 532811.41 5987.43 11.49 MWD 11279.11 84.79 349.82 6708.85 6630.85 4115.99 4374.26 5988798.69 532805.78 6004.20 7.45 MWD 11311.63 82.52 352.64 6712.44 6634.44 4147.93 4369.33 5988830.61 532800.73 6023.19 11.09 MWD 11343.70 82.16 355.41 6716.72 6638.72 4179.53 4366.02 5988862.20 532797.31 6043.10 8.63 MWD 11374.71 80.05 357.42 6721.51 6643.51 4210.11 4364.11 5988892.76 532795.27 6063.27 9.34 MWD 11407.95 77.88 0.74 6727.88 6649.88 4242.72 4363.58 5988925.37 532794.62 6085.87 11.78 MWD 11439.08 75.36 2.21 6735.08 6657.08 4272.99 4364.36 5988955.64 532795.28 6107.74 9.31 MWD 11500.00 75.36 2.21 6750.48 6672.48 4331.89 4366.63 5989014.54 532797.33 6150.83 0.00 MWD KRU 'I Q-02B Injector Proposed CTD Completion E. 4-1/2" Camco DS nipple, 3.875" min ID at 500' MD 9-5/8" 38# J55 3830' ~r.-' ot'1C~~'1[~~~~5 Alaska, Inc. u D. 4-1/2" Baker CMU sliding sleeve @ 6009' MD w/ 3.812" min ID 7" 28# J-55 6268 MD' 2-3/8" liner top @ +/-8400' MD Window in 4-1/2" KOP at 8550' MD Squeezed A3/ A4-sand perFs~ 8662' - 8808' and 4-1/2" 12.6# L•80 ~ 9010 MD' Fill B. Baker "Hyflo III" liner top packer/SBE/seal assembly at 6119' MD 1 Q-02BPB1 A4 Lateral, TD @ 1 10,552' MD/6596' TVD A. 3-%2" Otis "X" nipple, 3.812" min ID at 7975' MD Sgz'd C-sand perfs ° ® 8369'-8384' and 4 1 /8" / 3 3/a" Openhole ° ° ~ ° O 1 Q-02B A4 Lateral, TD @ 11,500' MD/6674' TVD; ~~ `o~a~ ° KOP @ 9975' MD/6605' TVD; P/N: 205-142 3 3,16 ~e~ ° O p O O O p O O O O O O O O O O O O O O O p O O O O O O O O O O O O O O O O 0 O O O O O O 1 Q-026L1 A3 Lateral, TD @ 12,050' MD/6680' TVD; = KOP @ 9609' MD/6605' TVD; P/N: 205-186 2-7/8" slotted liner, 4 holes/ft, 3/8" hole size 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: .13f'3... rf'4~ ~~r~'i~t_s~~~~ _~K c~ti~~~,'€; ~:'E.E~~i`!L?£? i3r.'.V~C`~''7.~c'.E l~'P`~~e~1. ~i~~~.c~k.~,e$ I'3~~i'~ E;£?u~E`t~S~82tA~+~,7~J~ ~3~t~'Ei~3_~~c~:l_~_~?C.~S Contractor: Nordic Rig No.: 2 DATE: 11/20/05 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 _ Rep.: Goodrich /Sevcik E-Mail ~i~~c~~~c~ri~rt~_;~ic "~c?~1~?gs~E~r~ri~~;? _~_~=3 Well Name: ~:Q ~ PTD # 205-142 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 300/4000 Annular: 300/4000 Valves: 300/4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual. Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 3" Slips P Meth Gas Detector P P #3 Rams 1 2 3/8" X 3.5" P H2S Gas Detector P P #4 Rams 1 2 318" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 0:30 P No. Valves 14 P Full Pressure Attained 1:35 P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2000 Test Results Number of Failures: 0 Test Time: 4.5 Hours Components tested 29 Repair or replacement of equi pment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~ir~3,-rf~g~~ !~~r~i~3_~~~_kf_.~K:u Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X NO c - Oper./Rig Waived By John Spaulding. c -Database Date 11!18!05 Time 0800 c -Trip Rpt File Witness Chuck Sevc ik c -Inspector Test start 2100 Finish 0130 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-20-05p.xls a ,s 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO DE Test Report Submit to: ,€~E"3..C~'g~~~~rfi~3_s~~tc,~K,us s~(iC~~.::; ~''~ 1EC~i~L?~? . i3c:ZiI~c1C~'T1Bf1: ~i3ik3_ce~f.EiS ~3~_i:2...E£?u~E`l~S~£3Ef~ +~Zl~~~£~"_3~3,S~c~lf_-~_~?C.~i~4 Contractor: Nordic Rig No.: 2 DATE: 11/6/05 Rig Rep.: Holmes-Igtanloc Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Feketi-Sarber E-Mail~~.E~c~~~~c~rl~rt~tic_^fc?~:i~;~us~E~E_~~~?:~_~.3 Well Name: 1Q-02B PTD - Operation: Drlg: XXX Workover: Explor.: Test: .Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-4000 Annular: 250-4000 Valves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 3" Slips P Meth Gas Detector P P #3 Rams 1 2 3/8"x3.5" P H2S Gas Detector P P #4 Rams 1 2 3/8" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve N/A NA TimelPressure Test Result System Pressure 3050 P CHOKE MANIFOLD: Pressure After Closure 2150 P Quantity Test Result 200 psi Attained 25 sec P No. Valves 14 P Full Pressure Attained 96 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2050 Test Results Number of Failures: 0 Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3.,rE~t~~~i~c~s~?i3,s~~~kf_~X,u~. Remarks: Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES X)OC NO c - Oper./Rig Waived By Chuck Sheave c -Database Date 11/5/05 Time 07:00 c -Trip Rpt File Witness Sloan / Feketi c -Inspector Test start 13:00 Finish 17:30 Coil Tubing BFL 11/09/04 Nordic 2 BOP 11-6-05p.xls H 7 Ra t$ i ~ s..~ 3 s..$ ~, ''h '.. ~ ~ a ..~ ~a ~ ;~ ~ ~ r a~~ ~ ~ ~~ ~' ~ FRANK H. MURKOWSK/, GOVERNOR ~ ~+ 3 ~~ O~ ~ t=~17 ~~ 333 W. 7TM AVENUE, SUITE 100 C011T5ER'Q~TIOI~T COMA'I15SIO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Aras Worthington CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: KRU 1Q-02B Conoco Phillips Alaska Inc. Permit No: 205-142 Surface Location: 1206' FNL, 1175' FEL, SEC. 26, T12N, R09E, UM Bottomhole Location: 3767' FSL, 3243' FWL, SEC. 24, T12N, R09E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits 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 terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this ~ day of October, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RE~~! V C~ ALASKA OIL AND GAS CONSERVATION OMISSION PERMIT TO DRILL SEP ~ 9 209 ~~'{~ 20 AAC 25.005 .~__~,., na ~ r,~s Cons. ~~i"s~ik~,~,~.,~.. 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development OiI~B~~~jBle Zone ^ Stratigraphic Test ®Service ^ Development Gas in a Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: Kuparuk 1Q-02B 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: i MD 12100 ' TVD 6641ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 1206' FNL 1175' FEL SEC 26 T12N R09E UM 7. Property Designation: ADL 025634 River Pool , , . , , , Top of Productive Horizon: 503' FSL, 2632' FEL, SEC. 24, T12N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 10, 2005 Total Depth: 3767' FSL, 3243' FWL, SEC. 24, T12N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 22,675' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528448 ' y- 5984667 ~ Zone- ASP4 10. KB Elevation (Height above GL): 78' feet 15. Distance to Nearest Well Within Pool 1 Q-22 is offset by 265' 16. Deviated Wells: Kickoff Depth: 8550 ~ feet Maximum Hoie Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3500 ~ Surface: 2870 ~ 1 Casing'Program: Size Specifications Setting Depth T Bottom uantity of ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD inGudin sta a data 4-1/8" 2-7/8" 6.16# L-80 STL 3560' 8540' 6434' 12100' 6641' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND r tions) Total Depth MD (ft): 9017 Total Depth TVD (ft): 6830 Plugs (measured): 8883 Effective Depth MD (ft): 8720 Effective Depth 6633 An O~~lu-~k (measured): Casing Length Size Cement Volume MD 100' 16" 240 sx Coldset II 100' 100' 3830' 9-5/8" 1000 sx Coldset III, 420 sx Coldset I 3830' 3517' 6268' 7" 550 sx Class 'G', 250 sx CSI 6268' 5205' P i 2955' 4-1/2" 113 sx Class 'G' 6055' - 9010' 5056' - 6822' Perforation Depth MD (ft): 8369' - 8905' Perforation Depth TVD (ft): 6406' - 6753' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 440-7692 Printed Name Aras Worthington Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone Cell: 440-7692 Date ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill ~ / Number. '- _.,-~' lY API Number: ~F ~. 3~~ c_; 50- 029-21248-~00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples quired ^ Yes ~,No Mud Log Required ^ Yes (~ No Hydrog ulfide Measures c~~ Yes ^ No Directional Survey Required ~ Yes ^ No Other: `t--~~~~~5 ~~` ~ ~~ ~ G.'~i ~ ~O.nhC~Cl ~ M ~ ~ V~~'~a~c~.~~ ~~~f cl~C~l~nS ~ ~~° ~\Q ~.~ / ~, ~ I ~ ~, THE OMMISSION ~©6 D~ A roved l3 : ~ ~- Date Form 10-401 Re`Jised 06/2004 ~'-'-"'~ ~ ~ ~.-. SuSmit'In Duplicate • KRU 1Q-026 Sidetracks - CoiledTubing Drilling Summary of Operations: Coiled tubing drilling will drill 1 lateral in injector KRU 1Q-02A using Dynamically Overbalanced pressure drilling technique (DOBCTD, see description below). The horizontal lateral will target Kuparuk A sand for injection. The existing Kuparuk A & C Sand perforations in the existing well l Q-02A, will be cement squeezed and abandoned for injection control into the new lateral. CTD Drill and Complete 1Q-02B program: Planned for Nov 10, 2005 1. Pre CTD MIT-IA, MITT 2. Pre CTD test MV & SV 30~ ~-~~ 3. Pre CTD CT cement squeeze of A & C sand perforations 4. Pre CTD CT Mill out cement 5. Pre CTD drift tubin~ner with dummy whipstock 6. MIRU Nordic 2. NU 7-1/16" BOPE, test 7. Set 41h" whipstock at 8550' and ~ ''~.h\S ~-~~~, 8. Mi113.80" window at 8550' and and l0' of openhole 9. Dri114 1/8" bieenter hole horizontal lateral from window to --12,100' and targeting Kuparuk A sands ' 10. Kill well with Brine (-llppg) 11. Complete with 2 7/8" slotted liner from TD, up into the 4 1/2" liner to 8540' 12. Recover Brine. 13. ND BOPE. RDMO Nordic 2. 14. Post CTD rig. BOL. Mud Program: • Step 8&9: 9.5 ppg Chloride based Flo-Pro mud • Step 10&11: Chloride based Flo-Pro mud (~11 ppg) Disposal: • No annular injection on this well • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drillsite 4 • Class I wastes will go to Pad 3 for disposal Casing Program: • 1Q-02B: 2 7/8", 6.16#, L-80, STL slotted liner from -8540' and to 12,100' and Well Control: • Two wellbore volumes (--370 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. • The annular preventer will be tested to 400 psi and 2500 psi. `~"------~ Directional See attached directional plans for 1Q-02B. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ~ The nearest well to 1Q-02B is 1Q-22, which is offset by 265'. KRU boundary is 22675' away. ~ Logging • MWD Gamma Ray & Resistivity will be run. ~ Hazards i • 1Q is an H2S pad, the highest H2S measurement on the pad is 220 ppm. All H2S monitoring equipment will be operational. i KRU 1Q-02B Sidetracks - CoiledTubing Drilling Reservoir Pressure • The expected reservoir pressure of 1Q-02B pressure is 3500 psi at 6300' TVD, .10.7 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 2870 psi. DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 9.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used 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/or 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 (2-3/8" rams,. see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated max reservoir pressure: 3500 psi at 6300' TVD, 10.7 ppg EMW. ~ Expected annular friction losses while circulating: 500 psi. Planned mud density: 9.5 ppg equates to 3110 psi hydrostatic bottom hole pressure. While circulating 9.5 ppg fluid, bottom hole circulating pressure is estimated to be 3600 psi or l ]ppg ECD: '`~ When circulation is stopped, a minimum of 500 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements and shale behavior while drilling. - 1 • >a8'u~~ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 1 Q-B~ NIP (500-501, 3„ API: 500292124801 Well T e: INJ 'ff '" SSSV Type: Nipple Orig 8/1 OD:4.500) - Com letion: Annular Fluid: Last W/O: Reference Loa: Ref Loa Date: SLEEVE-C (60098010, OD:4.500) TUBING (0-6061, OD:4.500, ID:3.958) TTL (6060-6061, OD:4.500) SETTING SLEEVE (6113-6114, OD:6.000) PKR (6119-6120, OD:5.875) NIP (79757976, OD:3.828) Squeeze Perfs (8203.8205) Perf (8369.8384) Shot Sqz Perfs (8440.8442) Pert (8662-8673) Perf (86768681) Perf (86868720) Shot Sqz Perfs (87255727) Perf (8802-8808) RETAINER (888&8884, OD:4.500) KRU 1 Q-02A Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 6061 5060 12.75 L-80 ABM EUE Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8203 - 8205 6301 - 6302 UNIT D C 2 0 7/6/1996 S z 8369 - 8384 6406 - 6416 C-1 15 4 10/19/199 RPERF 2.5" HSD, 180 deg ph, +/- 90 de from low side 8440 - 8442 6452 - 6453 UNIT B 2 6 6/26/1996 SHOT SQUEEZE PERFS; 3 3!8" Hollow Carrier; 60 deg. hasin 8662 - 8673 6595 - 6602 A-4 11 4 8/11/1996 APERF 180 de h; 2 7/8" HSD 8676 - 8681 6604 - 6608 A-3 5 4 8/11 /1996 APERF 180 de h; 2 7/8" HSD 8686 - 8720 6611 - 6633 A-3 34 4 8/11/1996 APERF 180 dep. ph; 2 7/8" HSD I V/JL-V/JJ I I I L I V II/GJ/haul l IVV UC}y. yII,JJ/u I stimulations 8~ Treatmer-ts- Interval Date T e Comment 8725 - 8727 6/14/1996 Shot S z Perfs 8440 - 8442 6/26/1996 Shot S z Perfs 8203 - 8205 7!6/1996 S ueeze Perfs Pum ed 21 bbls of Cmt; S ueezed awa 14 bbls )they lu s, a ui .; etc. =JEWELRY )e th TVD T e Descri tion ID 500 500 NIP Camco'DB' Landin 3.875 6009 5024 SLEEVE-C Baker'CMU' Slidin 3.812 6055 5056 TIEBACK Baker Settin Sleeve 5.500 6060 5059 TTL 3.958 6061 5060 PKR Baker'H o III' 5.063 6113 5096 SETTING SLEEVE Baker Liner Setting Sleeve 5.500 6119 5100 PKR Baker'H to III' 5.063 7975 6153 NIP Otis 'X' Landing 3.812 Perf (89035905) KRU 1 Q-02A Injector t3 Proposed CTD Completion CO-1'1t3Ct~P'~"11~t~,lS Alaska, Inc. E. 4-1/2" Camco DS nipple, 3.875" min ID at 500' MD 3830' D. 4-1/2" Baker CMU sliding sleeve @ 6009' MD w/ 3.812" min ID B. Baker "Hyflo III" liner top packer/SBE/seal assembly at 6119' MD 7" 26# J-55 @ 6268 MD' A. 3-'/2' Otis "X" nipple, 3.812" min ID at 7975' MD Sgz'd C-sand perfs 8369'-8384' and 2-3/8" liner top @ \a~~ '~~~ \~ +/-s4oo' MD 3~16~ et ~`~ et~ro A3/A4 Lateral, TD @ 11750' and 3' ~~~ o~ Window in 4-1/2" KOP at 8550' MD o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ° 0 0 0 0 0 0 0° o° o° o° o° o° 0 0 0 0 0 0 0 0 0 0 0 Squeezed A3/A4-sand 2-7/8" slotted liner liner, 4 holes/ft, 3/8" hole size perfs 8662' - 8808' and . ~ 4-1/2" 12.6# L-80 Fill! 9010 MD' DEV 9/21/05 Conocc~~;llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~-C~,~= ' Company: ConocoPhitlips Alaska, Inc. Date: 912 312 0 0 5 Time: 11:07:57 Page: 1 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 2, True North ~ Site: KRU 1 Q Pad ~ Vertical (TVD) Reference: Datum 2 78.0 I Wcll: 2 Seetion (VS) Reference: W elt (0.OON.O.OOE,S.OO Azi) 1Vcllpath: Plan 5, 1Q-02B Survey Calculation Method: Mi nimum Curvature ~ Db: Oracle - Field: Kuparuk River Unit - __ North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1Q Pad UNITED STATES: North Sl ope Site Position: Northing: 5985877 .04 ft Latitude: 70 22 20.956 N From: Map Fasting: 529617 .73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 2 Slot Name: Well Position: +N/-S -1206.00 ft Northing: 5984666 .52 ft ~ Latitude: 70 22 9.094 N +Et-W -1175.00 ft Fasting : 528447 .63 ft i Longitude: 149 46 7.777 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, 1Q-026 Drilled From: 1Q-02A Tie-on Depth: 8546.11 ft Current Datum: Datum 2 H eight 78 .00 ft Alwve System Datum: Mean Sea Level Magnetic Data: 9/14/2005 Declination: 24.10 deg Field Strength: 57607 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 78.00 0.00 0.00 5.00 Plan: Plan #5 Date Composed: 9/14/2005 Copy Lamar's Plan 5 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets V1ap A1ap <---- Latitude ---> <--- Longitude ---> Name Description TVD +~~/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1Q-026 Polygon 78.00 1663.98 4128.13 5986346.00 532569.00 70 22 25.448 N 149 44 6.995 W -Polygon 1 78.00 1663.98 4128.13 5986346.00 532569.00 70 22 25.448 N 149 44 6.995 W -Polygon 2 78.00 1824.09 4365.77 5986507.00 532806.00 70 22 27.021 N 149 44 0.040 W -Polygon 3 78.00 2146.18 4350.99 5986829.00 532790.00 70 22 30.189 N 149 44 0.467 W -Polygon 4 78.00 2949.92 4178.02 5987632.00 532614.00 70 22 38.095 N 149 44 5.515 W -Polygon 5 78.00 3486.05 4423.09 5988169.00 532857.00 70 22 43.366 N 149 43 58.334 W -Polygon 6 78.00 4057.38 4614.28 5988741.00 533046.00 70 22 48.984 N 149 43 52.728 W -Polygon 7 78.00 4447.58 4573.76 5989131.00 533004.00 70 22 52.822 N 149 43 53.907 W -Polygon 8 78.00 4850.62 4573.29 5989534.00 533002.00 70 22 56.786 N 149 43 53.914 W -Polygon 9 78.00 5191.04 4472.57 5989874.00 532900.00 70 23 0.134 N 149 43 56.856 W -Polygon 10 78.00 5046.87 4251.00 5989729.00 532679.00 70 22 58.718 N 149 44 3.344 W -Polygon 11 78.00 4733.58 4317.82 5989416.00 532747.00 70 22 55.636 N 149 44 1.394 W -Polygon 12 78.00 4412.65 4291.59 5989095.00 532722.00 70 22 52.480 N 149 44 2.167 W -Polygon 13 78.00 4010.43 4338.07 5988693.00 532770.00 70 22 48.524 N 149 44 0.813 W -Polygon 14 78.00 3460.17 4125.96 5988142.00 532560.00 70 22 43.113 N 149 44 7.030 W -Polygon 15 78.00 2981.18 3849.11 5987662.00 532285.00 70 22 38.404 N 149 44 15.139 W -Polygon 16 78.00 1858.09 4103.87 5986540.00 532544.00 70 22 27.357 N 149 44 7.702 W -Polygon 17 78.00 1748.27 4052.44 5986430.00 532493.00 70 22 26.277 N 149 44 9.209 W 1Q-02B Target 1 6641.00 1995.00 4131.39 5986677.00 532571.00 70 22 28.704 N 149 44 6.895 W 1 Q-026 Target 2 6657.00 2660.47 4026.91 5987342.00 532464.00 70 22 35.249 N 149 44 9.941 W 1Q-026 Target 3 6718.00 3516.74 4241.18 5988199.00 532675.00 70 22 43.669 N 149 44 3.657 W 1 Q-026 Target 4 6718.00 5021.30 4399.92 5989704.00 532828.00 70 22 58.465 N 149 43 58.986 W CC)C1C)CC~~"1I ~ ~! }~5 • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ^ Companp: C onocoPhillip s Alaska, Inc. Date: 9/23/2005 Timc: 11:07:57 Pagc: 2 Field: K uparuk Rive r Unit Co-o rdinate(1VE) R eference: W ell: 2, True North Site: KRU 1 Q Pad Verti cal ('fVD) Re ference: Datum 2 78.0 well: 2 Secti on (VS) Refer ence: Well (O.OON,O.OOE,S.OO Azi) ~I Wcllpath: Plan 5, 1Q-02B Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD - - ---- - -~---- ft ft ~ ~ ~ 8546.11 6520.84 TIP ~~~~ ~~~~ ~~ ~~ ~ ~~~ ~ ~~~~ ~~ 8550.00 6523.34 KOP 8570.00 6535.98 End of 9°/100' DLS 8847.03 664120 End of 30°1100' DLS 9150.00 6646.07 5 9430.00 6652.19 6 9630.00 6652.96 7 9930.00 6678.55 8 10130.00 6700.45 9 10455.00 6716.45 10 10550.00 6718.72 11 10850.00 6718.77 12 11400.00 6718.83 13 11700.00 6718.84 14 12000.00 6718.86 15 12100.00 6718.86 TD Plan Section Information ~ Mll Incl Azim TVD +N/-S +>v/-~~ DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10 0ft deg 8546.11 50.04 87.68 6520.84 1714.26 4075.25 0.00 0.00 0.00 0.00 8550.00 50.01 87.78 6523.34 1714.38 4078.23 2.12 - 0.77 2.57 111.41 8570.00 51.57 86.63 6535.98 1715.14 4093.71 9.00 7.82 -5.74 330.00 8847.03 90.00 5.44 664120 1891.46 4242.15 30.00 1 3.87 -29.31 275.50 9150.00 88.22 329.12 6646.07 2182.03 4176.59 12.00 -0.59 -11.99 267.00 9430.00 89.35 2.71 6652.19 2449.68 4109.46 12.00 0.40 12.00 88.50 9630.00 90.22 338.73 6652.96 2645.62 4077.43 12.00 0.43 -11.99 272.00 9930.00 80.28 13.50 6678.55 2938.87 4056.83 12.00 -3.31 11.59 107.00 10130.00 87.30 36.60 6700.45 3117.53 4140.61 12.00 3.51 11.55 74.50 10455.00 87.28 357.55 6716.45 3421.86 4234.10 12.00 - 0.01 -12.01 269.00 10550.00 89.99 8.63 6718.72 3516.54 4239.21 12.00 2.86 11.66 76.40 10850.00 89.99 44.63 6718.77 3780.32 4371.48 12.00 0.00 12.00 90.00 11400.00 90.00 338.63 6718.83 4289.74 4476.31 12.00 0.00 -12.00 270.00 11700.00 90.00 14.63 6718.84 4584.32 4458.96 12.00 0.00 12.00 90.00 12000.00 90.00 338.63 6718.86 4878.90 4441.61 12.00 0.00 -12.00 270.00 12100.00 90.00 350.63 6718.86 4975.14 4415.15 12.00 0.00 12.00 90.00 Survey MD Incl Azim SS TVD <\7S E/~V MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 8546.11 50.04 $7.68 6442.84 1714.26 4075.25 5986396.08 532515.93 0.00 2062.92 0.00 MWD ~ 8550.00 50.01 87.78 6445.34 1714.38 4078.23 5986396.21 532518.91 2.12 2063.30 111.41 MWD 8570.00 51.57 86.63 6457.98 1715.14 4093.71 5986397.03 532534.38 9.00 2065.40 330.00 MWD 8575.00 51.73 84.73 6461.08 1715.43 4097.62 5986397.34 532538.29 30.00 2066.04 275.50 MWD 8600.00 52.98 75.38 6476.37 1718.86 4117.07 5986400.84 532557.73 30.00 2071.14 276.68 MWD 8625.00 54.93 66.42 6491.10 1725.48 4136.13 5986407.53 532576.77 30.00 2079.40 282.40 MWD 8650.00 57.51 57.94 6505.02 1735.18 4154.47 5986417.30 532595.07 30.00 2090.66 287.68 MWD 8675.00 60.61 49.98 6517.89 1747.80 4171.78 5986429.98 532612.32 30.00 2104.74 292.40 MWD 8700.00 64.17 42.53 6529.48 1763.11 4187.74 5986445.36 532628.23 30.00 2121.39 296.50 MWD 8725.00 68.08 35.53 6539.61 1780.87 4202.11 5986463.16 532642.52 30.00 2140.33 299.96 MWD 8750.00 72.27 28.91 6548.10 1800.76 4214.62 5986483.10 532654.96 30.00 2161.23 302.80 MWD 8775.00 76.67 22.61 6554.80 1822.44 4225.07 5986504.82 532665.32 30.00 2183.74 305.04 MWD 8800.00 81.22 16.53 6559.59 1845.54 4233.27 5986527.95 532673.43 30.00 2207.47 306.74 MWD 8825.00 85.87 10.60 6562.41 1869.68 4239.08 5986552.10 532679.16 30.00 2232.02 307.90 MWD 8847.03 90.00 5.44 6563.20 1891.46 4242.15 5986573.90 532682.14 30.00 2253.99 308.57 MWD 8850.00 89.98 5.08 6563.20 1894.42 4242.43 5986576.86 532682.40 12.00 2256.96 267.00 MWD 8875.00 89.82 2.09 6563.25 1919.37 4243.99 5986601.81 532683.87 12.00 2281.95 267.00 MWD 8900.00 89.67 359.09 6563.36 1944.36 4244.25 5986626.80 532684.04 12.00 2306.88 267.01 MWD 8925.00 89.51 356.10 6563.54 1969.34 4243.20 5986651.77 532682.89 12.00 2331.66 267.02 MWD i Canoh~thps Baker Hughes INTEQ ~ . ~ Baker Hughes INTEQ Planning Report ~~r ' Company: ConocoPhillips Alaska, Inc. Datc: 9/23/2005 Timc: 11.07:57 Pagc: 3 Ficld: Ku paruk Rive r Unit Co-ordinate(NE) Re ference: Well: 2, True North Site: KRU 1 Q Pad Verti cal (TVD) Refe rence: Datum 2 78. 0 Well: ?_ Section (VS) Referen ce: Well (O.OON ,O.OOE,5.OOAzi) ~ Wellpath: Plan 5, 1Q-02B Survey Calculation Method: Minimum C urvature Db: Oracle Survcv MD Incl Azim SS TVD 1\/S E/W MapN Maps llLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 8950.00 89.36 353.10 6563.78 1994.22 4240.84 5986676.64 532680.44 12.00 2356.25 267.04 MWD 8975.00 89.20 350.10 6564.10 2018.95 4237.19 5986701.36 532676.70 12.00 2380.56 267.07 MWD 9000.00 89.05 347.11 6564.48 2043.45 4232.26 5986725.84 532671.67 12.00 2404,54 267.11 MWD 9025.00 88.91 344.11 6564.92 2067.66 4226.04 5986750.02 532665.37 12.00 2428.12 267.15 MWD 9050.00 88.76 341.11 6565.43 2091.51 4218.57 5986773.84 532657.81 12.00 2451.23 267.21 MWD 9075.00 88.62 338.12 6566.00 2114.94 4209.87... 5986797.23 532649.01 12.00 2473.80 267.27 MWD 9100.00 88.48 335.12 6566.63 2137.87 4199.95 5986820.12 532639.01 12.00 2495.79 267.34 MWD 9125.00 88.35 332.12 6567.32 2160.26 4188.85 5986842.46 532627.82 12.00 2517.12 267.41 MWD 9150.00 88.22 329.12 6568.07 2182.03 4176.59 5986864.19 532615.48 12.00 2537.74 267.49 MWD 9175.00 88.30 332.12 6568.83 2203.80 4164.33 5986885.91 532603.14 12.00 2558.36 8$.50 MWD 9200.00 88.39 335.12 6569.55 2226.19 4153.23 5986908.25 532591.96 12.00 2579.70 88.41 MWD 9225.00 88.48 338.12 6570.24 2249.12 4143.32 5986931.15 532581.96 12.00 2601.68 88.32 MWD 9250.00 88.57 341.12 6570.88 2272.55 4134.61 5986954.54 532573.17 12.00 2624.26 88.24 MWD 9275.00 88.67 344.12 6571.48 2296.40 4127.15 5986978.36 532565.61 12.00 2647.37 88.16 MWD 9300.00 88.77 347.12 6572.04 2320.61 4120.94 5987002.54 532559.31 12.00 2670.94 88.09 MWD 9325.00 88.88 350.12 6572.55 2345.11 4116.01 5987027.02 532554.29 12.00 2694.92 88.02 MWD 9350.00 88.98 353.12 6573.02 2369.83 4112.37 5987051.73 532550.55 12.00 2719.23 87.96 MWD 9375.00 89.10 356.11 6573.44 2394.72 4110.02 5987076.60 532548.11 12.00 2743.82 87.91 MWD 9400.00 89.21 359.11 6573.81 2419.69 4108.98 5987101.56 532546.98 12.00 2768.60 87.86 MWD 9425.00 89.32 2.11 6574.13 2444.68 4109.25 5987126.56 532547.15 12.00 2793.52 87.81 MWD 9430.00 89.35 2.71 6574.19 2449.68 4109.46 5987131.55 532547.34 12.00 2798.52 87.77 MWD 9450.00 89.43 0.31 6574.40 2469.67 4109.99 5987151.54 532547.79 12.00 2818.48 272.00 MWD 9475.00 89.54 357.31 6574.62 2494.66 4109.47 5987176.53 532547.18 12.00 2843.33 272.03 MWD 9500.00 89.65 354.32 6574.80 2519.59 4107.64 5987201.45 532545.26 12.00 2868.01 272.05 MWD 9525.00 89.76 351.32 6574.93 2544.39 4104.52 5987226.23 532542.04 12.00 2892.44 272.07 MWD 9550.00 89.87 348.32 6575.02 2568.99 4100.10 5987250.82 532537.53 12.00 2916.56 272.09 MWD 9575.00 89.98 345.32 6575.05 2593.33 4094.40 5987275.13 532531.74 12.00 2940.31 272.10 MWD 9600.00 90.09 342.32 6575.04 2617.34 4087.43 5987299.11 532524.68 12.00 2963.62 272.10 MWD 9625.00 90.20 339.33 6574.97 2640.95 4079.22 5987322.69 532516.38 12.00 2986.43 272.10 MWD 9630.00 90.22 338.73 6574.96 2645.62 4077.43 5987327.35 532514.57 12.00 2990.92 272.09 MWD 9650.00 89.52 341.02 6575.00 2664.39 4070.55 5987346.10 532507.62 12.00 3009.03 107.00 MWD 9675.00 88.64 343.89 6575.41 2688.23 4063.02 5987369.90 532500.00 12.00 3032.11 106.99 MWD 9700.00 87.77 346.76 6576.19 2712.40 4056.69 5987394.04 532493.58 12.00 3055.64 106.95 MWD 9725.00 86.90 349.64 6577.35 2736.84 4051.58 5987418.46 532488.38 12.00 3079.54 106.86 MWD 9750.00 86.04 352.52 6578.89 2761.49 4047.71 5987443.09 532484.42 12.00 3103.76 106.72 MWD 9775.00 85.19 355.40 6580.80 2786.27 4045.09 5987467.86 532481.70 12.00 3128.22 106.55 MWD 9800.00 84.36 358.30 6583.08 2811.13 4043.72 5987492.71 532480.24 12.00 3152.86 106.33 MWD 9825.00 83.53 1.20 6585.72 2835.98 4043.61 5987517.57 532480.03 12.00 3177.62 106.06 MWD 9850.00 82.73 4.11 6588.71 2860.78 4044.76 5987542.36 532481.09 12.00 3202.41 105.76 MWD 9875.00 81.94 7.03 6592.04 2885.43 4047.16 5987567.02 532483.40 12.00 3227.19 105.41 MWD 9900.00 81.17 9.96 6595.72 2909.89 4050.81 5987591.49 532486.95 12.00 3251.87 105.02 MWD 9925.00 80.43 12.91 6599.71 2934.07 4055.70 5387615.69 532491.75 12.00 3276.39 104.59 MWD 9930.00 80.28 13.50 6600.55 2938.87 4056.83 5987620.49 532492.86 12.00 3281.26 104.12 MWD 9950.00 80.93 15.84 6603.81 2957.96 4061.83 5987639.60 532497.78 12.00 3300.71 74.50 MWD 9975.00 81.76 18.75 6607.58 2981.55 4069.17 5987663.22 532505.04 12.00 3324.86 74.12 MWD 10000.00 82.62 21.66 6610.97 3004.80 4077.73 5987686.49 532513.50 12.00 3348.76 73.68 MWD 10025.00 83.49 24.55 6614.00 3027.62 4087.46 5987709.35 532523.15 12.00 3372.34 73.28 MWD 10050.00 84.38 27.43 6616.64 3049.96 4098.36 5987731.73 532533.96 12.00 3395.55 72.93 MWD 10075.00 85.28 30.30 6618.89 3071.76 4110.38 5987753.57 532545.89 12.00 3418.32 72.63 MWD 10100.00 86.19 33.17 6620.75 3092.96 4123.49 5987774.82 532558.92 12.00 3440.58 72.37 MWD 10125.00 87.12 36.03 6622.21 3113.51 4137.66 5987795.42 532573.01 12.00 3462.28 72.16 MWD 10130.00 87.30 36.60 6622.45 3117.53 4140.61 5987799.45 532575.96 12.00 3466.55 71.99 MWD ~onncv~;ll~s Baker Hughes INTEQ ~ Baker Hughes INTEQ Planning Report ~-~;~-- ~ Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Sitr. KRU 1O Pad Well: 2 Wellpath: Plan 5 1O-02B Survcv Date: 9/23/2005 Time: 11:07:57 Page: Co-ordiuate(VE) Reference: Well: 2, True North Vertical (CVD) Reference: Datrtm 2 78.0 Section (VS) Reference: Well (O.OON,O.OOE,5.OOAzi) Survey Calculation ~Lethod: Minimum Curvature Dh: - - -~ - - ~- - - 4 racle R1D Incl Azim SS Ty%D YlS F!W ~tap,A MapE llLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 10150.00 87.26 34.20 6623.40 3133.81 4152.19 5987815.78 532587.46 12.00 3483.78 269.00 MWD 10175.00 87.22 31.19 6624.61 3154.83 4165.67 5987836.84 532600.87 12.00 3505.88 269.11 MWD 10200.00 87.19 28.19 6625.83 3176.52 4178.04 5987858.57 532613.15 12.00 3528.57 269.26 MWD 10225.00 87.16 25.19 6627.06 3198.82 4189.25 5987880.92 532624.28 12.00 3551.77 269.40 MWD 10250.00 87.14 22.18 6628.30 3221.69 4199.28 5987903.82 532634.22 12.00 3575.42 269.55 MWD 10275.00 87.13 19.18 6629.55 3245.04 4208.10 5987927.21 532642.95 12.00 3599.46 269.70 MWD 10300.00 87.12 16.17 6630.81 3268.83 4215.68 5987951.02 532650.44 12.00 3623.81 269.85 MWD 10325.00 87.13 13.17 6632.06 3292.98 4222.00 5987975.19 532656.67 12.00 3648.42 270.00 MWD 10350.00 87.14 10.17 6633.31 3317.43 4227.05 5987999.66 532661.62 12.00 3673.22 270.15 MWD 10375.00 87.16 7.16 6634.55 3342.11 4230.81 5988024.35 532665.29 12.00 3698.14 270.30 MWD 10400.00 87.19 4.16 6635.79 3366.96 4233.28 5988049.20 532667.66 12.00 3723.10 270.45 MWD 10425.00 87.22 1.16 6637.01 3391.90 4234.43 5988074.15 532668.72 12.00 3748.05 270.60 MWD 10450.00 87.27 358.15 6638.21 3416.87 4234.28 5988099.11 532668.48 12.00 3772.91 270.75 MWD 10455.00 87.28 357.55 6638.45 3421.86 4234.10 5988104.10 532668.27 12.00 3777.86 270.89 MWD 10475.00 87.84 359.89 6639.30 3441.83 4233.65 5988124.07 532667.75 12.00 3797.72 76.40 MWD 10500.00 88.55 2.80 6640.08 3466.81 4234.24 5988149.05 532668.24 12.00 3822.66 76.30 MWD 10525.00 89.27 5.72 6640.56 3491.73 4236.09 5988173.98 532670.00 12.00 3847.65 76.21 MWD 10550.00 89.99 8.63 6640.72 3516.54 4239.21 5988198.79 532673.03 12.00 3872.63 76.15 MWD 10575.00 89.99 11.63 6640.72 3541.14 4243.61 5988223.41 532677.33 12.00 3897.52 90.00 MWD 10600.00 89.99 14.63 6640.73 3565.49 4249.29 5988247.77 532682.92 12.00 3922.27 90.00 MWD 10625.00 89.99 17.63 6640.73 3589.50 4256.23 5988271.81 532689.77 12.00 3946.80 90.00 MWD 10650.00 89.99 20.63 6640.74 3613.12 4264.42 5988295.45 532697.87 12.00 3971.04 90.00 MWD 10675.00 89.99 23.63 6640.74 3636.27 4273.84 5988318.64 532707.20 12.00 3994.92 90.00 MWD 10700.00 89.99 26.63 6640.75 3658.90 4284.46 5988341.31 532717.72 12.00 4018.40 90.00 MWD 10725.00 89.99 29.63 6640.75 3680.95 4296.24 5988363.40 532729.42 12.00 4041.38 90.00 MWD 10750.00 89.99 32.63 6640.75 3702.35 4309.16 5988384.84 532742.26 12.00 4063.83 90.00 MWD 10775.00 89.99 35.63 6640.76 3723.04 4323.19 5988405.59 532756.21 12.00 4085.66 90.00 MWD 10800.00 89.99 38.63 6640.76 3742.97 4338.28 5988425.57 532771.22 12.00 4106.83 90.00 MWD 10825.00 89.99 41.63 6640.76 3762.08 4354.39 5988444.74 532787.26 12.00 4127.27 90.00 MWD 10850.00 89.99 44.63 6640.77 3780.32 4371.48 5988463.05 532804.28 12.00 4146.94 89.99 MWD 10$75.00 89.99 41.63 6640.77 3798.57 4388.57 5988481.36 532821.29 12.00 4166.60 270.00 MWD 10900.00 89.99 38.63 6640.77 3817.68 4404.68 5988500.53 532837.33 12.00 4187.05 270.00 MWD 10925.00 89.99 35.63 6640.78 3837.61 4419.77 5988520.51 532852.34 12.00 4208.21 270.00 MWD 10950.00 89.99 32.63 6640.78 3858.30 4433.79 5988541.26 532866.29 12.00 4230.05 270.00 MWD 10975.00 89.99 29.63 6640.79 3879.70 4446.71 5988562.70 532879.13 12.00 4252.49 270.00 MWD 11000.00 89.99 26.63 6640.79 3901.74 4458.50 5988584.79 532890.83 12.00 4275.48 270.00 MWD 11025.00 89.99 23.63 6640.79 3924.38 4469.11 5988607.46 532901.35 12.00 4298.95 270.00 MWD 11050.00 89.99 20.63 6640.79 3947.53 4478.53 5988630.65 532910.68 12.00 4322.84 270.00 MWD 11075.00 89.99 17.63 6640.80 3971.15 4486.72 5988654.29 532918.78 12.00 4347.08 270.00 MWD 11100.00 89.99 14.63 6640.80 3995.16 4493.67 5988678.33 532925.63 12.00 4371.61 270.00 MWD 11125.00 89.99 11.63 6640.80 4019.50 4499.34 598$702.69 532931.22 12.00 4396.35 270.00 MWD 11150.00 89.99 8.63 6640.81 4044.11 4503.74 5988727.31 532935.52 12.00 4421.25 270.00 MWD 11175.00 89.99 5.63 6640.81 4068.92 4506.84 598$752.13 532938.53 12.00 4446.23 270.00 MWD 11200.00 89.99 2.63 6640.81 4093.85 4508.64 5988777.06 532940.23 12.00 4471.22 270.01 MWD 11225.00 89.99 359.63 6640.81 4118.84 4509.13 5988802.06 532940.63 12.00 4496.16 270.01 MWD 11250.00 89.99 356.63 6640.82 4143.82 4508.32 5988827.03 532939.72 12.00 4520.98 270.01 MWD 11275.00 89.99 353.63 6640.82 4168.73 4506.20 5988851.93 532937.50 12.00 4545.61 270.01 MWD 11300.00 90.00 350.63 6640.82 4193.49 4502.77 5988876.68 532933.99 12.00 4569.98 270.01 MWD 11325.00 90.00 347.63 6640.82 4218.04 4498.06 5988901.20 532929.18 12.00 4594.02 270.01 MWD 11350.00 90.00 344.63 6640.83 4242.31 4492.06 5988925.45 532923.09 12.00 4617.68 270.01 MWD 11375.00 90.00 341.63 6640.83 4266.23 4484.81 5988949.34 532915.75 12.00 4640.87 270.01 MWD 11400.00 90.00 338.63 6640.83 4289.74 4476.31 5988972.81 532907.16 12.00 4663.55 270.01 MWD 11425.00 90.00 341.63 6640.83 4313.25 4467.82 5988996.29 532898.58 12.00 4686.23 90.00 MWD • Cortotv~iiips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~rF~c~ - Company: ConocoPhillips Alaska, Inc. l+'ield: Kuparuk River Unit Site: KRU 1 Q Pad Well: 2 Wellpath: Plan 5, 1Q-02B Sur~~ey Date: 9/23/2005 Timc: 11:07:57 Pagc: 5 Co-ordinate(14E) Reference: WeII: 2, True North Vertical (TVD) Reference: Datum 2 78.0 Section (4S) Reference: WeII (O.OON,O.OOE,5.OOAzi) Survey Calculation !Method: Minimum Curvature Db: Oracle E/N ft MD Incl Azim SS TVll N/S ft deg deg ft ft 11450.00 90.00 344.63 6640.83 4337.17 11475.00 90.00 347.63 6640.83 4361.44 11500.00 90.00 350.63 6640.83 4385.99 11525.00 90.00 353.63 6640.84 4410.75 11550.00 90.00 356.63 6640.84 4435.66 11575.00 90.00 359.63 6640.84 4460.64 11600.00 90.00 2.63 6640.84 4485.63 11625.00 90.00 5.63 6640.84 4510.56 11650.00 90.00 8.63 6640.84 4535.37 11675.00 90.00 11.63 6640.84 4559.98 11700.00 90.00 14.63 6640.84 4584.32 11725.00 90.00 11.63 6640.85 4608.66 11750.00 90.00 8.63 6640.85 4633.27 11775.00 90.00 5.63 6640.85 4658.07 11800.00 90.00 2.63 6640.85 4683.01 11825.00 90.00 359.63 6640.85 4708.00 11850.00 90.00 356.63 6640.85 4732.98 11875.00 90.00 353.63 664D.85 4757.89 11900.00 90.00 350.63 6640.85 4782.65 11925.00 90.00 347.63 6640.85 4807.20 11950.00 90.00 344.63 6640.86 4831.47 11975.00 90.00 341.63 6640.86 4855.39 12000.00 90.00 338.63 6640.86 4878.90 12025.00 90.00 341.63 6640.86 4902.41 12050.00 90.00 344.63 6640.86 4926.33 12075.00 90.00 347.63 6640.86 4950.60 . 12100.00 90.00 350.63 6640.86 ~ 4975.14 4460.56 4454.57 4449.85 4446.43 4444.31 4443.49 4443.99 4445.79 4448.89 4453.28 4458.96 4464.64 4469.04 4472.14 4473.94 4474.43 4473.61 4471.49 4468.07 4463.35 4457.36 4450.11 4441.61 4433.11 4425.86 4419.87 4415.15 MapN MapE DLS VS TFO Tool ft ft deg/100ft ft deg 5989020.18 532891.24 12.00 5989044.42 532885.15 12.00 5989068.95 532880.34 12.00 5989093.69 532876.83 12.00 5989118.59 532874.61 12.00 5989143.57 532873.70 12.00 5989168.56 532874.10 12.00 5989193.50 532875.80 12.00 5989218.31 532878.81 12.00 5989242.93 532883.11 12.00 5989267.29 532888.70 12.00 5989291.66 532894.28 12.00 5989316.28 532898.58 12.00 5989341.09 532901.59 12.00 5989366.03 532903.30 12.00 5989391.02 532903.69 12.00 5989416.00 532902.78 12.00 5989440.89 532900.56 12.00 5989465.64 532897.05 12.00 5989490.17 532892.24 12.00 5989514.41 532886.16 12.00 5989538.30 532878.81 12.00 5989561.77 532870.23 12.00 5989585.25 532861.64 12.00 5989609.14 532854.30 12.00 5989633.38 532848.21 12.00 5989657.91 532843.41 12.00 4709.43 4733.08 4757.13 4781.50 4806.12 4830.94 4855.88 4880.88 4905.86 4930.75 4955.50 4980.24 5005.14 5030.12 5055.12 5080.06 5104.87 5129.50 5153.87 5177.91 5201.57 5224.77 5247.44 5270.12 5293.32 5316.97 5341.02 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD BP Amoco WLLLVATN ORAlLB vl.~ s. ~o-osa r•• •e~W'ro. asaiaL~,i sm: La. Daum: o:wm z Ta.oon I LEGEND T Plan: Plan #5 (2rPlan 5, ta02B) - z 1G oz1 Azimuths to True North ~~~~ I - 2s1G-ou) M MagnetlcNorth:24.10° Create08y:BIIIMkhaelson Date:9232005 ~~~~ 2(10~02APBi) ~;~~ ~p - Plen 5, iQd)28 Magnetic Field Con;acc mtormation~. Il~f - Plan#5 Stren the 57607nT 9 Bill Michaelson ` ~ Dip Angle: 80.78° Direct (907)167624 1:.. Date: 9/14/2005 Celc (9D7)301-73570 Model: bggm2004 E-mail: bill.michaelson~inteq.com • • • • ~,~ ConocoPhillips Alaska, Inc. ~ ~- BAKER Location: North Slope, Alaska Slot: slot #2 C~11000~'1~~~1pS HUGFIES Field: Kuparuk River Unit Well: 2 INTF.(,1 Installation: Pad 1Q Wellbore: 1Q-026 PIanS Scale 1 inch = 150 ft East (feet) -> 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200 4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450 5250 5100 4950 4800 4650 4500 4350 4200 4050 3900 3750 3600 ~: 3450 d 4) 3300 L Z 3150 3000 2850 2700 2550 2400 2250 2100 1950 180D r ~ 1650 c 1500 i$ ~ 1350 5250 5100 4950 4800 4650 4500 0350 4200 4050 3900 3750 3600 3450 :~ Z O 3300 ~ N 3150 v 3000 2850 2700 2550 2400 2250 2100 1950 1800 N 1650 m 1500 1350 x' kale 1 inch = 150 ft East (feet) -> f• ~ , ~ • Kuparuk DOBCTD BOP configuration 2-3/8" Coil Well 1Q-02B Rig Floor 0 I~~ ~ Tree Size on 7 1/16" 5000 psi (RX-46) or ~- 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee -- SSV Master Valve Base Flan e Page 1 TERRIE L NUBBLE - . BP EXPLORATION AK INC ~~ ss-si~25z 225 PO BOX 1966.12 MB 7-5 Mastercard Check" ANCHORAGE, AK 99519-6612 ~~~_oS DATE T PAY TO THE ORDER OF $ `f~.~ w First National ank Alaska DOLLARS Anchorage, AK 99501 MEMO . ~ ~~ V~~ ~:L25200060~:99L4~~~S227~~~L556~~• 0225 ~~ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /C.~~ l~ :~.~ ~' PTD# ~~'-~ - CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80} from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL -490100 Well Name: KUPARUK RIV UNIT 10-02A __.__ Program SER Well bore seg ^ PTD#:2051420 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit fee attached - - - Yes - -- - 2 Lease number appropriate_____________________________________ ___ Yes_ __-.--$urfacelocationinADL 025411;top_prod-interval&-TD inADL025634._-__.___._-_________--__-- 3 Unique well-name and number-- -- --- - -- ------------ -- Yes --- ------- ----- ------- ------ - -- ------------------ - --- -- - 4 Well located in a_d_efinedpool- _ _ - _ _ Yes KUPARUK RIVER,_KUPARUK RVOIL - 490.10D, ,governed by Conservation Order No. 432C_ _ - - 5 Well located proper distance_f[om drilling unit-boundary_ - _ _ - - ... Yes Conservation Order No. 4320 ~ntains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance-from other wells- _ - - - - . - Yes _ _ _ - - - -Conservation Order No. 432C has no in_terwell-spacing_restrictions_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in drilling unit_ . _ - - - _ _ _ - _ - _ - . _ . - Yes - - Conservation Order No. 4320 has.no intenyell_spacing-restrictions, Wellbo[e will be-more than 500' from - - - _ - 8 If deviated, iswellbore plat_included - - - _ - - _ _ - - _ _ - - _ _ - - _ . - Yes an-external property line where_ownership or_landownership changes. 9 Operatoronlyaffectedparty---------------------------------------- Yes- -___-__--_ - -- i 10 Operatorhas_appropriate_bondinforce_________________________________ Yes. .___-__- 11 Permit can be issued without conservation order NA Appr Date 12 Permit-can be issued without administrative-appr_ova_I________________________ NA_- -__--__-.__--__--___-_--__--__--__-__-__---__--__-_---_--_-_-__-_----_-_- 5FD 9/30/2005 13 Can permit be approved before 15-day wait NA 14 Well located within area and-strata authorized by Injection Order # (put-10# in_cornments)_ (For_ Yes - _ - . _ Area Injection Order No.-26- - _ _ - . _ _ - - _ _ . 15 All wells within 1!4_mile area_of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - - _ KRU 1Q-22,_KRU_ 1_Q-04L1 ~KRU 1Q-04L1-01 _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ - _ _ - - _ _ _ _ _ _ _ - _ _ _ - 16 Pre-produced injector; duration of pre production less than_ 3 months_(For service well only) - Yes Aras Worthington, CT Engineer, 9130!2005: wel_I will be pr_e-produced beyond normal-clean-up operations. - - - . 17 AC_M_P_FindingofConsistency-h_asbee_nissued_for_ihisproject________________ ___ NA__ __--__Pr_e-existing well__-___-__--____-_--_-.__,-______- ------------------------- Engineering 18 Conductor string-provided - _ - - - . - - - - - NA_ . _ _ - - - Conductorset_inoriginal_well~1_Q-02 184-232.- . ~ ) - - 19 Surface casing_protectsall-known_USDWS________________________--.--- NA__ -__---All aquifers exempted,4l)CFR-147.102(b)~3).--_..-.-.--____--__--__--__--__--_-_--__- 20 _C_MT-v_ol_adeguale_toci[culate-o_nconductor&surf-csg------------------------ NA_- -___-_Surfacecasing setin_originalwell.--___-_--__,-_.--__--__-__--__-____---___-__- 21 CMT-v_oladequ_ate-to tie-in long stringtosurfcsg---------------------------- NA_- -___-_Production-casing satin-originalwell.__--__-_-__---_-._____------_-____._-_-,__- 22 _C_MT-will coverall known_protluctive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - _ _ - - _ Original well cemented satisfactorily, NA-withslotted-liner. - - _ _ - - _ _ - _ _ _ - . - . _ - _ - . _ - - - _ - . - _ _ - 23 Casing designs adequatef_orC,_T,B&_permafrost--------------------------- Yes- ------------_--------------------_-- -----------------.--------- -- -- 24 Adequate tankage-or reserve pit - , - Yes - Rig is-equipped with steel_pits. No reserve-pitplanned: All waste to_approve_d disposal wells.- - - - - ... . 25 If_a_re-drill,has_a-10-403 for abandonment been approved______________________ Yes_ ___..-305-287.- _________.---.-_____--__---_ -_____--_---._.-__.-__---__-`__ 26 Adequate wellbore separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - . _ Proximity analysis performed, 1 close approach, within reservoir, _ _ _ _ _ _ _ _ - - _ _ - - _ _ - - _ _ _ _ _ _ _ - . _ _ 27 Ifdiverterrequired,doesitmeetregulatioris------------------------------- NA__ -___--BOPstack.willalready_beinglace,_-__--_--__,-__-__--_____- -------------------- Appr Date 28 Drilling fluid-program schematic & equip list adequate- _ _ - - _ - - Yes - Maximum expected formation pressure 19.7 EMW.-Dynamic overbalance with 9.5 ppg.fluid and trapped pressure. TEM 101512005 29 BOPEs, do they meet-regulation _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ - . _ _ .2 wellbore volumes-of X11:0 ppg fluid will_be on _location-for_contingen_cy._ _ - - _ - ~~ 30 _BOPE-press rating appropriate; test to-(put psig m comments) . _ _ _ Yes - . - . , _ MASP calculated at 2870 psi 4000_psi BOP testplanned, _ _ 31 Choke-manifold complies wlAPt RP 53 (May 84) Yes _ _ 32 Work will occur without operationshutdown _ Yes _ _ _ _ _ _ _ _ _ _ 33 Isere&enoe-of H2S gas_probable_ _ _ ___ _ __ _ _ _ _ _ _ _ _ _ _ _ ____ _ _ __ _ _ _ _ _ _ _ _ _ Yes _ - - - _ - _ H2$ is reported.on 1Q_pad._ Mud should preclude-H2$on_rig, Rig_has sensors and alarms._ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mechanical-condition of wells within AOR verified (Far-service well only) - _ _ _ - _ _ _ Yes _ - _ _ _ - - Proximate wells_encountered breathing and high res._ptessure, but no AOR issues identified_ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Pe[mitcan be issued w/o hydrogen_sulfideineasures.. _ - - - - - - _ - - - No_ - - H2S up to 200ppm has been measured_on-1QPad. H2$ measures_required- - -- - - - - - - -- - - - 36 Data_presented on-potential overpressure zones. _ - - _ - - - - Yes Estimated reservoir pressure is 10,7 ppg EM_W; will-be_tlrilled with 9,5-ppg mud and-using overbalanced_p_ressure Appr Date 37 Seismic analysis of shallow gas-zones- - - _ . - _ - NA- _ _ -drilling technique to maintain 1,0-ppg equiv_alerit_circulatingd~nsity. - - _ _ . - - - SFD 9130!2005 38 Seabed condition survey.(ifoff-shore) NA- 39 _COntactnamelphone_forweeklyprogress-reports[exploratoryonly]----------------- NA_- _-___--__--_--__--__--_--__--__-___---------__, Geologic Engineering Public Commissioner. Date: Commissioner: Date missioner ate ~~ ~p~s ~~~r~-~© S-D.S~ ~~ b • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, iniormalion 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. { **** REEL HEADER **** LDWG 07/06/13 AWS Ol **** TAPE HEADER **** LDWG 07/06/14 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! 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: SURFACE LOCATION 1Q-02B 50029212480200 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 13-JUN-07 MWD RUN 4 MWD RUN 5 MWD RUN 7 4 5 7 T. STURDIVANT D. BARBA D. BARBA G. SARBER G. SARBER G. SARBER MWD RUN 8 MWD RUN 10 8 10 T. STURDIVANT D. LABRECQUE G. GOODRICH G. GOODRICH SECTION: 26 TOWNSHIP: 12N RANGE: 09E FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 78.00 DERRICK FLOOR: 00.00 GROUND LEVEL: 00.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 3830.0 2ND STRING 7.000 6268.0 t 3RD STRING 4.500 9010.0 PRODUCTION STRING 3.75 11501.0 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 22' 9.094" LONG: W149 DEG 46' 7.777" LOG MEASURED FROM K.B. AT 78 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) A11 Gamma Ray data are realtime 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 for well 1Q-02B. (7) The 1Q-02B wellbore was drilled from 1Q-02 through a milled window in 4.5" liner. Top of window 8541.1 ft. MD (6439.5 ft. SSTVD) Bottom of window 8548.4 ft. MD (6444.0 ft. SSTVD) (8) The interval from 11471 ft. to 11501 ft. MD (6665.9 ft. to 6674.3 ft. SSTVD) was not logged due to bit to sensor offset. (9) The 1Q-02B wellbore was tied to 1Q-02 at 8190 ft. MD (6214.2 ft. SSTVD). (10) The interval from 8518 ft. to 8868 ft. MD (6424.8 ft, to 6556.9 ft. SSTVD) was recorded in a MAD PASS. (11) Well 1Q-02B was sidetracked from 1Q-02BPB1 at 9985 ft. MD (6604.6 ft. SSTVD). Time drilled to 10015 ft. MD (6604.1 ft. SSTVD). Tape Subfile: 1 88 records... Minimum record leng th: 8 bytes Maximum record leng th: 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8548.0 11501.0 S BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 4 8548.0 5 8871.0 7 9156.0 8 9532.0 10 9985.0 MERGE BASE 8871.0 9156.0 9532.0 9985.0 11501.0 REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1Q-02B 5.xtf LCC 150 CN ConocoPhillips Alaska, Inc. WN 1Q-02B FN Kuparuk River COUN North Slope Borough STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - - ODEP ------------- -- ----- GR ------------------ GR ------ --- GRAX -- - 0.0 RPD RPD RPCL 0.0 RPS RPS RPCH 0.0 RAD RAD RACL RAS RAS RACH ROP ROP ROPA * FORMAT RECORD (TYP E# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (val ue= 255) Optical Log Depth Sc ale 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: FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Sampl es Units 1 GR MWD 68 1 GAPI 2 RPD MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RAD MWD 68 1 OHMM 5 RAS MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR Total Data Records: 165 o.o 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8548.000000 Tape File End Depth = 11500.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 209 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8548.0 8871.0 LOG HEADER DATA DATE LOGGED: 09-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8900.0 TOP LOG INTERVAL (FT): 8548.0 BOTTOM LOG INTERVAL (FT): 8871.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 50.7 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 68000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 115.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 4 (MWD Run 4). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OH MM) 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 1Q-02B.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02B FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP -------- --- ----- GRAX ------------------ GRAX ----------- GRAX ----- -- 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RAC L MGTD 6 8 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 36 Tape File Start Depth = 8548.000000 Tape File End Depth = 8871.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 118 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8871.0 9156.0 LOG HEADER DATA DATE LOGGED: 10-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9188.0 TOP LOG INTERVAL (FT) 8871.0 BOTTOM LOG INTERVAL (FT): 9156.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 88.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8598.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 66000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 117.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 '~ MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 5 (MWD Run 5). 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 1Q-02B.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02B FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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 1 GRAX MVJD 6 8 1 GAP I 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 32 Tape File Start Depth = 8871.000000 Tape File End Depth = 9156.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 114 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** LDWG File Version 1.000 Extract File: FILE013.HED FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9156.0 9532.0 LOG HEADER DATA DATE LOGGED: 12-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9564.0 TOP LOG INTERVAL (FT): 9156.0 BOTTOM LOG INTERVAL (FT) 9532.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 69000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 123.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 7 (MWD Run 7). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OH MM) 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 1Q-02B.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02B FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM -- ODEP ----------------- ----- GRAX ------------------ GRAX -------- - GRAX - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH ROPA ROPA ROPA * 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 42 o.o 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9156.000000 Tape File End Depth = 9532.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 124 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: 5 RAW MWD ~ ~ Curves and log header data for each bit run in separate files. BIT RUN N0: 8 DEPTH INCREMENT: .2500 FIL E SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9532.0 9985.0 LOG HEADER DATA DATE LOGGED: 14-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10015.0 TOP LOG INTERVAL (FT): 9532.0 BOTTOM LOG INTERVAL (FT}: 9985.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 133.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN}: .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 8 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OH MM) 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 1Q-02B.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02B FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - - ODEP ----- ------- --- ----- GRAX ------------------ GRAX ----- --- - GRAX - - - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH M[nTD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MVTD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 51 Tape File Start Depth = 9532.000000 Tape File End Depth = 9985.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 133 records... ~ ~ Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED FILE HEADER FILE NUMBER: 6 RAW MGJD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9985.0 11501.0 LOG HEADER DATA DATE LOGGED: 18-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11501.0 TOP LOG INTERVAL (FT): 9985.0 BOTTOM LOG INTERVAL (FT) 11501.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 70.8 MAXIMUM ANGLE: 91.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 9.1 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 139.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 ~ ~ MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 10 (MGdD Run 10). 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 1Q-02B.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02B FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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: r Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHNIM 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: 169 Tape File Start Depth = 9985.000000 Tape File End Depth = 11500.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 7 251 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** LDWG 07/06/14 01 **** REEL TRAILER **** LDWG 07/06/13 AWS 01 Tape Subfile: 8 Minimum record length Maximum record length 2 records... 132 bytes 132 bytes • **** REEL HEADER **** LDWG 07/06/13 AWS 01 **** TAPE HEADER **** LDWG 07/06/14 01 *** LIS COMMENT RECORD *** LDWG File Version 1.000 Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: 1Q-02BPB1 API NUMBER: 50029212487000 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 13-JUN-07 JOB DATA MWD RUN 4 MWD RUN 5 MWD RUN 7 JOB NUMBER: 4 5 7 LOGGING ENGINEER: T. 5TURDIVANT D. BARBA D. BARBA OPERATOR WITNESS: G. 5ARBER G. BARBER G. BARBER MWD RUN 8 JOB NUMBER: 8 LOGGING ENGINEER: T. 5TURDIVANT OPERATOR WITNESS: G. GOODRICH SURFACE LOCATION SECTION: 26 TOWNSHIP: 12N RANGE: 09E FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 78.00 DERRICK FLOOR: 00.00 GROUND LEVEL: 00.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 3830.0 2ND STRING 7.000 6268.0 M- 3RD STRING 4.500 9010.0 PRODUCTION STRING 3.75 10552.0 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 22' 9.094" LONG: W149 DEG 46' 7.777" LOG MEASURED FROM K.B. AT 78 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 realtime 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 for well 1Q-02BPB1. (7) The 1Q-02BPB1 wellbore was drilled from 1Q-02 through a milled window in 4.5" liner. Top of window 8541.1 ft. MD (6439.5 ft. SSTVD) Bottom of window 8548.4 ft. MD (6444.0 ft. SSTVD) (8} The interval from 10520 ft. to 10552 ft. MD (6594.5 ft. to 6592.2 ft. SSTVD) was not logged due to bit to sensor offset. (9) The 1Q-02BPB1 wellbore was tied to 1Q-02 at 8190 ft. MD (6214.2 ft. SSTVD). (10) The interval from 8518 ft. to 8868 ft. MD (6424.8 ft. to 6556.9 ft. SSTVD) was recorded in a MAD PASS. Tape Subfile: 1 85 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** LDWG .001 • 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOOI.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH MWD 8548.0 all bit runs merged. STOP DEPTH 10552.0 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 MERGE TOP MERGE BASE 4 8548.0 8871.0 5 8871.0 9156.0 7 9156.0 9532.0 8 9532.0 10552.0 REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1Q-02BPB1 5.xtf LCC 150 CN ConocoPhillips Alaska, Inc. WN 1Q-02BPB1 FN Kuparuk River COUN North Slope Borough STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ------------- --- ----- GR ------------------ GR ----------- GRAX - - 0.0 RPD RPD RPCL 0.0 RPS RPS RPCH 0.0 RAD RAD RACL 0.0 RAS RAS RACH 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: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 GAPI 2 RPD MWD 68 1 OHMM 3 RPS MWD 68 1 OHMM 4 RAD MwD 68 1 OHMM 5 RAS MWD 68 1 OHMM 6 ROP MWD 68 1 FPHR Total Data Records: 112 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8548.000000 Tape File End Depth = 10552.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 155 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .2500 • i FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8548.0 8871.0 LO G HEADER DATA DATE LOGGED: 09-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8900.0 TOP LOG INTERVAL (FT): 8548.0 BOTTOM LOG INTERVAL (FT): 8871.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 50.7 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 68000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 115.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: ..000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 4 (MWD Run 4). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API.) RPCL - DEEP PHA5E'RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CON5 • MNEM VALU WDFN 1Q-02BPB1.xtf LCC 150 CN ConocoPhillips Alaska, I U7N 1Q-02BPB1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - ODEP ---- -------- - --- -------------------------- --- GRAX GRAX GRAX --- - - - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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 (val ue= 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 Sampl es Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MfnTD 68 1 OHMM 4 4 3 RPCH MVJD 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: 36 Tape File Start Depth = 8548.000000 Tape File End Depth = 8871.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 118 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes • ~ • **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 _ RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N0: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8871.0 9156.0 LOG HEADER DATA DATE LOGGED: 10-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9188.0 TOP LOG INTERVAL (FT): 8871.0 BOTTOM LOG INTERVAL (FT): 9156.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 88.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 66000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 117.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL . • • MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 5 (MWD Run 5). 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 1Q-02BPB1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BPB1 FN Kuparuk River COUN North Slope Boro STAY Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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 GAPI 4 4 n U 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 32 Tape File Start Depth = 8871.000000 Tape File End Depth = 9156.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 114 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .004 1024 24 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9156.0 9532.0 LOG HEADER DATA DATE LOGGED: 12-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9564.0 TOP LOG INTERVAL (FT): 9156.0 BOTTOM LOG INTERVAL (FT): 9532.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 4 4 4 4 4 4 4 4 4 4 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 1007912$ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 69000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 123.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ) 0 REMARKS: BIT RUN 7 (MWD Run 7). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MGTD-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 1Q-02BPB1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BPB1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - - ODEP ------------- -- ----- GRAX ------------------ GRAX ---- --- -- GRAX - -- 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) i 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 42 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9156.000000 Tape File End Depth = 9532.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 124 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE014.HED FILE HEADER FILE NUMBER: 5 RAW MGTD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9532.0 10552.0 LO G HEADER DATA DATE LOGGED: 14-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 10552.0 TOP LOG INTERVAL (FT): 9532.0 BOTTOM LOG INTERVAL (FT): 10552.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM. GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 133.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: 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) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BPBl.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BPB1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM -- CHAN DIMT - - CNAM - ODEP - - ---- --- GRAX ----------- ----- GRAX ----- ----- GRAX ------ ----- - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 114 Tape File Start Depth - 9532.000000 Tape File End Depth = 10552.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 196 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 **** TAPE TRAILER **** LDWG 07/06/14 01 **** REEL TRAILER **** LDWG 07/06/13 AWS O1 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes
