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187-112
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-09 KUPARUK RIV UNIT 3H-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-09 50-103-20086-00-00 187-112-0 W SPT 5861 1871120 1500 2231 2230 2230 2230 510 570 580 580 4YRTST P Austin McLeod 6/1/2025 MITIA. 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 3H-09 Inspection Date: Tubing OA Packer Depth 900 1710 1680 1680IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602191028 BBL Pumped:0.7 BBL Returned:0.5 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 TO: Jim Regg P.I. Supervisor�ee, bI11(70z SUBJECT: Mechanical Integrity Tests LL CosocoPhiflips Alaska, Inc. 3H-09 FROM: Brian Bixby KUPARUK RIV UNIT 311-09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry txIZ- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 311-09 API Well Number 50-103-20086-00-00 Inspector Name: Brian Bixby Permit Number: 187-112-0 Inspection Date: 6/12021 Insp Num: mitBDB210602040512 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 311-69 IType Inj I w TVD - 5861 Tubing 824 1825 - PTO 1871120 Type Test I SPT Test psi 1500 1A 680 2500 - 2455 2440' BBL Pumped: 11.6 BBL Returned: 1.6 OA 420 - 540 - 540. 540 - Interval 4YRTST P/F I P Notes: Tuesday, June 8, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 30,2017 TO: Jim Regg P.I.Supervisor Vtc f /- 6(3 t 11 SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA,INC. l 3H-09 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-09 API Well Number 50-103-20086-00-00 Inspector Name: Chuck Scheve Permit Number: 187-112-0 Inspection Date: 8/26/2017 ✓ Insp Num: mitCS170827081354 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-09T ype Inj W 'j'�TVD —.. — ' 5861 Tubing 2340 2340 • 2340 2340 " PTD 1871120 Type Test SPT Test psi 1500 - IA 500 1800 " 1760 " 1750 " BBL Pumped: 1.1 ' BBL Returned: 1.1 - OA 120 ' 128 ' 128 " 128 ' Interval 4YRTST P/F P ✓ Notes: SCANNED -2; Wednesday,August 30,2017 Page 1 of 1 • • K2kik. 314 -09 Prb Regg, James B (DOA) I 671t70 From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> / / Sent: Tuesday,June 27, 2017 8:19 AM 1� 1 j 7 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: Recent KRU MITs Attachments: MIT KRU 3H-22 &24 06-24-17.xlsx; MIT KRU 3M-06 06-24-17.xlsx; MIT KRU 3K-15 06-24-17 .xlsx; MIT KRU 2K PAD 06-24-17.xlsx; MIT KRU 2S-13A 06-24-17.xlsx; MIT KRU 1C-150 & 152 06-25-17 .xlsx; MIT KRU 1B PAD WSW-05&06 06-25-17.xlsx; MIT KRU 3H PAD 06-24-17.xlsx Hello All— Attached, please find completed 10-426 forms for several recent MITs completed in KRU. Let me know if you have questions or comments. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 $CANHED ::EP P 1 4 01,1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rea alaska.gov AOGCC.Inspectors(a4alaska.gov; phoebe.brooksaalaska.aov chris.wallacenalaska.gov OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/3H Pad I` CY 6l�i7/�' DATE: 06/23/17 11 l OPERATOR REP: Arend/Sumrall AOGCC REP: Waived by Chuck Scheve Well 3H-02 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1871070 Type In] N Tubing 1160 1160 1160 1160 Type Test P Packer TVD 5759 BBL Pump 2.4, IA 150 2000 1910 1900 Interval 4 Test psi 1500 BBL Return 2.1 OA 110 130 130 130 Result P Notes: / Well 31409 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1871120 ' Type In] N Tubing 1375- 1375- 1375 . 1375 ' Type Test P Packer TVD 5861 - BBL Pump 1.6 - IA 110 2100 ' 2050 - 2045- Interval 4 Test psi 1500 - BBL Return 1.8 ' OA 90 100 _ 100- 100 ' Result P Notes: Well 3H-12 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2110810 Type Inj N Tubing 1700 1700 1700 1700 Type Test P Packer ND 5878 BBL Pump 0.7 IA 1575 2500 2460 2455 Interval 4 Test psi 1500 BBL Return 0.7 OA 180 180 180 180 Result P Notes: Well 3H-18 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1880090 Type In] N Tubing 1500 1500 1500 1500 Type Test P Packer TVD 5831 BBL Pump 2.0 IA 735 2200 2140 2130 Interval 4 Test psi 1500 BBL Return 1.8 OA 65 240 250 245 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In] Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 3H PAD 06-24-17 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ;777f DATE: Wednesday,June 12,2013 P.I.Supervisor (/ '("4' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-09 FROM: John Crisp KUPARUK RIV UNIT 3H-09 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-09 API Well Number 50-103-20086-00-00 Inspector Name: John Crisp Permit Number: 187-112-0 Inspection Date: 6/9/2013 Insp Num: mitJCr130610083800 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-09 'Type In' C TVD 5861 I IA 610 2170 2150 I 2120 2110 -, PTD 1871120 Type Test, Test psi 1500 OA 25 80 • _ 77 76 72 • Interval 4YRTST P/F P "'Tubing; 3397 i 3396 " 3396 3398 3401 Notes: 1.4 bbls pumped for test. - 'DEB 2 b `ak SatkIktp Wednesday,June 12,2013 Page 1 of 1 Y g ' • • sorE ATAEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.009 Ms. Kelly Lyons Problem Well Supervisor • ConocoPhillips Alaska, Inc. ' fn P.O. Box 100360 Anchorage, AK 99510 -0360 RE: Cancellation of Administrative Approval AIO 2B.009 Kuparuk River Unit Well 3H -09 (PTD 1871120) Kuparuk River Oil Pool Dear Ms. Lyons: Pursuant to ConocoPhillips Alaska Inc. (CPAI)'s request dated September 17, 2011, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 2B.009, which allows continued water injection in Kuparuk River Unit (KRU) well 3H -09. This well exhibited tubing by inner annulus (TxIA) communication due to a packer leak and CPAI did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. CPAI has since performed a rig workover and repaired the well. The well successfully passed a witnessed MIT on September 6, 2011. Consequently, Administrative Approval AIO 2B.009 no longer applies to operation of this well. Instead, operation of KRU 3H- 09 will be governed by provisions of the underlying AIO No. 2B. DONE at Anc i orage, Alaska and dated September 21, 2011. Daniel T. `eamount, Jr. Cathy Foerster Commissioner, Chair Commissioner • • RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within l0 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsi- deration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the appli- cation for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or deci- sion on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That ap- peal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distri- butes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 1 . . . ConocoPhps Alaska P.O. BOX 100360 % .0 ANCHORAGE, ALASKA 99510 -0360 ° ser September 17, 2011 Commissioner Dan Seamount g ir Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Subject: 3H -09 (PTD 187 -112) Request for Cancellation of Administrative Approval AIO 2B.009 Dear Commissioner. Seamount: ConocoPhillips Alaska requests the cancellation of Administrative Approval (AA) AIO 2B.009 and allow the well to be returned to normal status and be available for WAG injection. The AA approval, originally issued June 21, 2006, and corrected on June 27, 2006, was for continued water injection with TxIA communication due to a packer leak. The well had a rig workover performed in June 2011, during which time the packer was successfully pulled and replaced. Please call Brent Rogers or myself at 659 -7224 if you have any questions. Sincerel Kelly Lyons ConocoPhillips Problem Well Supervisor • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, September 12, 2011 TO: Jim Regg � P.I. Supervisor ' q` 1 C(X7/1, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H -09 FROM: Lou Grimaldi KUPARUK RIV UNIT 3H -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -lee-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3H -09 API Well Number: 50- 103 - 20086 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110906110303 Permit Number: 187 - 112 - Inspection Date: 9/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3H -09' Type Inj. W' TVD 5861 - IA 902 3310 3238 3222 P.T.D 1871120' TypeTest SPT Test psi i 1500 - OA 470 580 580 580 Interval INITAL p/F P • Tubing 2760 2737 2736 2736 Notes: 1.9 Bbl's pumped and returned. Good test. - F f 1 Monday, September 12, 2011 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair w ell r Plug Perforations r Stimulate I- Other '"" Alter Casing f Rill Tubing r Perforate New Pool I Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f - 187 -112 3. Address: 6. API Number: Stratigraphic I Service , P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 20086 - - Oo 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25531 . • 3H -09 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7314 feet Plugs (measured) None true vertical 6387 feet Junk (measured) None Effective Depth measured 7168 feet Packer (measured) 6785, 6952 true vertical 6241 feet (true vertucal) 5861, 6026 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3465 9.625 3500 3040 PRODUCTION 7225 7 7260 6331 SEP 0 9 ?O1 Perforation depth: Measured depth: 6870' 6926', 6957'- 6967', 6978'- 6998', 7000'- 7006', 7008' -7030' True Vertical Depth: 5946- 6000', 6031'- 6041', 6052'- 6072', 6074'- 6080', 6082' -6104' Alaska) Oil & Gas Cons. Commission Annardwe Tubing (size, grade, MD, and TVD) 3.5, L - 80, 6970 MD, 6044 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 6785 MD and 5861 TVD PACKER - BAKER 85 -40 F1 PERMANENT PACKER @ 6952 MD and 6026 TVD SSSV - SCSSSV TRMAXX- CMT -SR -5 @ 1798 MD and 1758 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 6945' -7040' Treatment descriptions including volumes used and final pressure: 10 bbls 15% HCI 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation 3168 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service® 17 Stratigraphic fl 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX e r GSTOR WIND r WAG ri GINJ '-'° SUSP r SPLUG E 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: none Contact John Peirce C 265 -6471 Printed Name John Peirce Title Wells Engineer Signature . , Phone: 265 -6471 Date —! /i7/jj DIMS SEP 0 9 201P4) �r •/f S ubmit Original Onl y Form 10-404 Revised 10/2010 q�2- g ✓,, 9//� 3H -09 Well Work Summary DATE SUMMARY 8/14/11 HPBD: Pumped a total of 880 bbl o ck seawater in 4 stages. Intial injection ra 10.5 bpm @ 3200 psi, final injection rate of 11.0 bpm @ 3100 psi. SI pressure of 1700, well put back on injection. KUP • 3H-09 Co OC I # i 1 •:'; Well Attnu e bs _ . -_. _.. -. -. _ Max Angle & MD TD - ---_ Ai&ask7 Inc I wellbora 37 Fald N ame Well Status Inc/ ( °) [MD (ftKB) Act Btm (kKB) t.< x aYNUIm 501032008600 I IKUPA RUK RIVER UNIT INJ 4262 2 7,314.0 t Comment H2S (ppm) Date An otation 'End Date KB-Grd (ft) Rig Release II a Data wgq �oleg rJ „4(s/R411Z3D;21 AM SSSV: TRDP Last WO: 6/22/2011 _ 42.40 11/30/1987__ Srn /8/20 1.2:.. A notation Depth (ftKB) End Date [Annotation Last Mod ...) End Date 1 1 Last Tag: SLM 7,098.0 7!22011 Rev Reason' TAG, GLV C/O, CLOSE SLEEVE ninam 9/6/2011 BANGER, 30 - Casing Strings w Casing Description String 0... String ID ... Top (kKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thtd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED 11 / --- S Casing g Description String String O._ String ID ... Top (ftKB) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 35.2 3,499.8 3,039 7 36.00 J - 55 BTC Casing Description String 0... String ID... Top (111(8) Set Depth (f.. Set Depth (TVD) . String Wt... String ... String Top Thtd PRODUCTION 7 6.276 35.2 7,259.9 6333.0 26.00 J -55 BTC ILE Tubing Strings --- CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... Siring ._ String Top Thrd 36 - 115 TUBING WO 31/2 2992 300 � . -- 69/00 6044.3 9.30 L-80 EUE8RDMOD Completion Details SAFETY VLV, - OM Top Depth 1,798 M (ND) Top Ixl lir Top (kKB) Nomi... (flK6) (7 lam Description comment ID (in) IF 30.0 30.0 0.41 HANGER FMC HANGER w/ 2.50' PUP 3.500 1,797.8 1,758.3 32.17 SAFETYVLV SCSSSV - TRMAXX- CMTSR-5 w /2.813" °X" PROFILE 2.812 GAS LIFT. 2.912 _ - 6,754.2 5,829.6 6.36 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 6,762.2 5,837.5 6.28 SBR BAKER PBR - -- - -.- 4.000 6,785.4 5,860.5 6.06 PACKER BAKER FHL PACKER 2.970 6,925.1 5,999.5 5.41 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.813" X PROFILE; CLOSED 2.813 7/1/2011 SUR35 - 3.FACE, i 6,951.2 6,025.5 5.37 SEAL ASSY BAKER 8040 GBH 22 SEAL ASSEMBLY w/ LOCATOR 2.950 509 - 6,952.0 6,026.3 5.37 PACKER BAKER 85-40 F1 PERMANENT PACKER 4.000 GAS LIFT. :: -J..- 6,954.5 6,028.8' 5.37 SBR BAKER 80 -40 SBE 4.000 4 • 6,963.9 6,038.1 5.35 NIPPLE CAMCO ID NIPPLE - - -- - -- 2.750 6,969.3 6,043.5 5.35 SOS CAMCO SHEAR OUT SUB- NOT SHEARED 2.950 4,709 I _, Perf orations & S o p )TVD) Btm (TVD) -. ' . . Sh GAS LIFT, Top (kKB) Bhn (Mgt) (ftKB (ftKB Zone Date h. Shot Type Command 6,870 6,926 5,944.7 6,000.4 C-4, C -3, 3H -09 5/12/1988 12.0 APERF 2 1/8" Enerjet; 60 deg ph 6,957 6,967 6,031.3 6,041.3 A-3, 3H-09 5/12/1988 12.0 APERF 2 1/8" Enerjet 60 deg ph GAS 6IF 6,978 6,998 6,052.2 6,072.1 A -2, 3H-09 1/102001 3.0 APERF 2 1/8" Enerjet 90 deg CCW - - - -- Uhighside 6,978 6,998 6,052.2 6,072.1 A -2, 3[1.09 1/11/2001 3.0 RPERF 2 1/8" Enerjet 180 deg CCW f/highside GAS LIFT, _ __ - � 7,000 7,006 6,074.1 6,080.1 A -2, 3H-09 12/11/1987 2.0 IPERF 4" Densi Jet 120 deg ph - 7,008 7,010 6,082.1 6,084.1 A -2, 311-09 1/10/2001 3.0 APERF 2 1/8" Enerjet 90 deg CCW f /highside 7,010 7,016 6,084.1 6,090.1 A -1, 311-09 12/11/1987 2.0 IPERF 4" Densi Jet 120 deg ph SEAL ASSY•;' 7,010 7,016 6,084.1 6,090.1 A -1, 311-09 1/5/2001 3.0 RPERF 21/8" Enerjet 90 deg CCW 6,754 f /highside SBR,6,762 - � 7,010 7,028 6,084.1 6,102.0 A -1, 3H-09 1/10/2001 3.0 RPERF 21/8" Enerjet 90 deg CCW - f/highside PACKER, 6.785 .'... 7,016 7,030 6,090.1 6,104.0 A -1, 311-09 1/5/2001 3.0 APERF 2 1/8" Enerjet, 90 deg CCW t f /hlghside Stimulations & Treatments GAS LIFT, Bottom 6,839 Min Top Max Btm Top Depth Depth . Depth Depth (TVD) (TVD) (ftKB) (MB) (kKB) (ftKB) TYp• Date Comment 6945.0 7,040.0 6,019.4 6,114.0 Acid Wash 8/11/2009 Acid Wash w /10 bbls 15 %HCL 6: 0-69 Notes: General & Safety End Date Annotation 9/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SLEEVE-C, ____..___.. 6,925 SEAL ASSY, 6,951 PACKER, 6,952 ., SBR, 6,954 APERF, 6,957 -6,967 _ r _ SOS, 6,969 APERF,_ M andrel Details -�� -� -� 6,978-6,998 RPERF, 6,9786,998 Aad Wash, 6.945 Top Depth Top Port IPERF. '- (TVD/ Inc! OD Valve Latch Size TRO Run 7,000-7,006 Ap Sto T p {ftKB) (kKB) ( "1 Make Model (IN) Sere Type Type (On) (psi) Run Daa Con_. 7,008 1 2 ,912.1 2603.0 42.41 CAMCO MMG 1 12 GAS LIFT DMY R0 0 0.0 622/2011 IPERF, I 7,010 - 7,016 2 4,633.5 3,910.5 37.94 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/22/2011 RPERF, 7,010 --- 3 5,699.9 4,811.0 23.12 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 RPERF, - 7,010 i 4 6,322.1 5,403.1 12.16 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 ' APERF, t 7,016 5 6,697.7 5,773.4 6.90 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/1/2011 6 6,838.6 5,913.4 5.54 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/22/2011 PRODUCTION, 35.7,260N TD, 7,314 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Correlation Record: 3H -09 Run Date: 6/19/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20086 -00 -1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 15 alai Signed: (A. STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate J Other r Alter Casing r Rill Tubing f Perforate New Pool r Waiver E Time Extension f Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ ` 187 -112 3. Address: 6. API Number: Stratigraphic r Service f P. O. Box 100360, Anchorage, Alaska 99510 • 50- 103- 20086 -00 A cry 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25531 - - 3H -09 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7314 feet Plugs (measured) None true vertical 6387 feet Junk (measured) None Effective Depth measured 7168 feet Packer (measured) 6785, 6952 true vertical 6241 feet (true vertucal) 5861, 6026 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3465 9.625" 3500 3040 PRODUCTION 7225 7 u i . 9 2011 6331 Perforation depth: Measured depth: 6870'- 6926', 6957'- 6967', 6978'- 6998', 7000' -7030' True Vertical Depth: 5945'- 6000', 6031'- 6041', 6052'- 6072', 6074' - 6104' µ s ; `: � Nal, ; „ trt11SS 10R Aii_, :gpr .gas Tubing (size, grade, MD, and TVD) 3.5, L -80, 6969 MD, 6044 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 6785 MD and 5861 TVD PACKER - BAKER 85 -40 F1 PERMANENT PACKER @ 6952 MD and 6026 TVD SAFETY VLV - SCSSSV - TRMAXX CMT - SR - 5 @ 1798 MD and 1758 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 3561 Subsequent to operation _ shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service I✓ Stratigraphic F 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR ;r WINJ r WAG r 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 -142 Contact J. Brett Packer 265 -6845 Printed Name J. Brett Packer Title Wells Engineer Signature 7Ty"4-71,e-1. Phone: 265 -6845 Date 7/z 5- it / Form 10 -404 Revised 10/2010 RBDMS JUL 2 7 1011 1 7 Z ' "" Submit Original Only elf . t �- • _ KUP III 3H-09 (� a ,. We 1 Att r tes . Max Angle MD Jka.tr1C ' _ Wellbore APWW1 Field Name Well Status Inc/ C) IMO (ftKB) Act Btm (ftKB) c.c �ocBN n,.an 501032008600 KUPARUK RIVER UNIT INJ 42 62 1 2,700 00 7,314.0 Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date "' SSSV: TRDP Last WO 6/22/2011 I 42.40 11/30/1987 Scha+fetic- •- 'r Annoation (Depth (KKB) End Date Anno !Last Mod ... End Date Last Tag: I 7,058.0 5/13/2011 RevReason WORKOVER I ninam 6/26/2011 HANGER, 30 - ` : Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.. Set Depth (TVD) ... String Wt... 'String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.,. Set Depth (ND) ... String Wt... String .. String Top Thrd SURFACE 9 5/8 8.921 35.2 3,499 8 3,039 7 36.00 J-55 BTC i w. Casing Descdpton String 0... String ID... Top (ftKB) Set Depth (f.. Set Depth (ND) ... String Wt.. String ... String Top Thrd P _ __ 7 6.276 35.2 7,259.9 6 333.0 26.00 J -55 BTC Tubi St CONDUCTOR, Tubing Description String 0.. Stang ID .. Top (ftKB) (Set Depth (f...ISet Depth (ND) ... String Wt... String . Stang Top Thrd 36 - 115 TUBING WO 3 1/2 2.992 30 0 6,970.0 6 044.3 9.30 L-80 EUEBRDMOD ilk SAFETY VLV,_ ;. Completion l)etails 1,798 (TVD) Top not Nomi... Top Poi) (KB) (1 harm Description Comment ID(in) 30.0 30.0 0.41 HANGER FMC HANGER w/ 2.50' PUP 3,500 1,797.8 1,758.3 32.17 SAFETY VLV SCSSSV- TRMAXX- CMTSR -5 W/ 2.813" "X" PROFILE 2.812 GAS LIFT._ ____._._ 2,912 _ 6,754.2 5,829.6 6.36 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 6,762.2 5,837.5 6.28 SBR BAKER PBR 4.000 rrr��I 6,785.4 5,860.5 6.06 PACKER BAKER FHL PACKER 2.970 - y 6,925.1 5,999.5 5.41 SLEEVE BAKER CMU SUDING SLEEVE w/ 2.813" X PROFILE 2.813 / t ` 6,951.2 6,025.5 5.37 SEAL ASSY BAKER 80-40 GBH 22 SEAL ASSEMBLY w/ LOCATOR 2.950 SURFACE, . 6 5.37 PACKER BAKER 85-40 F1 PERMANENT PACKER 4.000 35 - 3.500 it 6,954.5 6,028.8 5.37 SBR BAKER 80-40 SBE 4.000 GAS LIFT, 6,963.9 6,038.1 5.35 NIPPLE CAMCO D NIPPLE 2.750 4.630 _ .'. 6,969 .3 6 043.5 5 35 SOS Perforations & Slots CAMCO SHEAR OUT SUB NOT SHEARED 2.950 - -- -- -- - shot -- -.`- - GAS LIFT, Top (TVD) Btm (TVD) O ens 5,700 Top (ftKB) Rim (ftKB) (ftKB) (ftKB) Zone Date (Si Type Comment 6,870 6,926 5,944.7 6,000 4 C-4, C-3, 311-09 5/12/1988 12.0 APERF 2 1/8" Enerjet, 60 deg ph 6,957 6,967 6,031.3 6,041.3 A-3, 311-09 5/12/1988 12.0 APERF 2 1/8" Enerjet 60 deg ph ill GAS LIFT, 6,978 6,998 6,052.2 6,072.1 1- A -2, 309 1/10/2001 3.0 APERF 2 1/8" Eneljet, 90 deg CCW 6,322 f/highside Ilk 6,978 6,998 6,052.2 6,072.1 A -2, 3H-09 1/11/2001 3.0 RPERF 2 1/8" Eneljet; 180 deg CCW f/highside GAS LIFT, 7,000 7,006 6,074.1 6,080.1 A -2, 31-09 12/11/1987 2.0 IPERF 4" Densi Jet 120 deg ph - - 6,698 _ 7,00 7,010 6,082.1 6,084.1 A -2, 3H -09 1/10/2001 3.0 APERF 2 1/8" Enerjet 90 deg CCW f/highside at. 7,010 7,016 6,084.1 6,090.1 A -1, 311-09 12/11/1987 2.0 IPERF 4" Densi Jet, 120 deg ph IMF 7,010 7,016 6,084.1 6,090.1 A -1, 3)409 1/5/2001 3.0 RPERF 2 1/8" Eberlet 90 deg CCW SEAL ASSY, ,754 f /highside 6,754 7,010 7,028 6,084.1 6,102.0 A - 1, 311 1/102001 3.0 RPERF 2 1/8" Enerjet 90 deg CCW SBR, 6,762 -- f/highside PACKER, 6,765 K � 7,016 7,030 6,090.1 6,104.0 A -1, 311 -09 1/5/2001 3.0 APERF 2 1/8" Ener)et 90 deg CCW _ _ = f/highside It Stimulations & Treatments Bottom GAS LIFE D) Min Top Max 131m Top Depth Depth 6,839 Depth Depth (N (TVD) It (ftKB) (ftKB) I (ftKB) (ftKB) Type __. Comment 6,945.0 7,040.0 6,019.4 6,114.0 Acid Wash 8/11/2009 Acid Wash w/10 bbls 15 / HCL APERF, - Notes: General & Safety 6,870 -6,926 - End Date Annotation M .: - 9/1/2010 NOTE: View Schematic w/ Alaska Schematic9 0 SLEEVE, 6,925 - SEAL ASSY, Co w i 6 oix• 6,951 / PACKER, 6,952 - cy 7, 27 f, SBR, 6,954 APERF, 6,957 -6,967 NIPPLE, 6,966- SOS, 6,969 APERF,_ 6,978-6,998 ':ii- RPERF, - -.. 6,978- 6,998 Add wash, Mandrel Details - -- 6,945 Top Depth Top Port IPERF, (TAD) Inc/ OD Valve Latch Size TRO Run 7,000-7 006 APERF, Stn To. ftKB (ftKB) Cl Make Model (in) Soon Type Type ( (psi) Run Date Com... 7,008 - 7,010 1 2,912.1 2,603 0 42 41 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 MERE, 7,010 - 7,016 2 4,633.5 3,910.5 37.94 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 RPERF, 7,010 3 5,699.9 4,811.0 23.12 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 RPERF, 7,010 _ - - 4 6,322.1 5,403.1 12.16 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6222011 APERF, 7,016 - 7,030 5 6,697.7 5,773.4 6.90 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 6222011 6 6,838.6 5,913.4 5.54 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/22/2011 PRODUCTION, 35- 7,260 TD, 7,314 3H -09 Well Work Summary DATE SUMMARY 5/13/11 TAGGED @ 7058' SLM.EST 55' ROIOLE.PERFORMED 30 MIN SBHPS @ 6411, RKB =3568 PSI W/ 15 P MIN GRADIENT @ 6898' = 3525 PSI.SET 2.79" CATCHER ASSY @ 6690' RKB.PULLED 1.5" DV @ 6594' RKB ** *OPEN POCKET* *PULLED CATCHER ASSY.IN PROGRESS 5/16/11 LOCKED OUT OTIS SERIES 10 SSSV @ 1807' RKB.RAN FLAPPER CHECKER COMPLETE 7/1/11 GAUGED TBG TO D- NIPPLE @ 6963' RKB W/ 2.77 G.RING, SET CAT STANDING VALVE IN D- NIPPLE @6963' RKB OPENED CMU @ 6925' RKB, MEASURE C -SAND SBHP @ 6900' RKB (3510 PSI) AND 6800' RKB, PULLED SHEARD SOV & REPLACED WITH DGLV IN STA # 5 @ 6697' RKB, SHIFTED CMU CLOSED @6925' RKB PRESSURE TESTED TBG TO 1500 PSI AND PULLED CAT STANDING VALVE FROM D- NIPPLE, JOB IN PROGRESS Q� 7/2/11 SHEARED SOS @ 6969' RKB, TAG BTM @ 7098' SLM. EST 90' OF RATHOLE, MEASURED SBHP @ 6987' 1� RKB (4092 PSI) AND 6886' RKB. JOB COMPLETE II • ConocoPhitlips Time Log & Summary We!Mew Web Reporting Report Well Name: 3H - 09 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/15/2011 4:00:00 PM Rig Release: 6/23/2011 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/14/2011 24 hr Summary Move 1/2 of pipe shed fom 31 pad to 3B pad. Continue move rig from 31 -08 to 3H -09 20:00 00:00 4.00 0 0 DEMOB MOVE MOB P Held PJSM with Peak & Rig crew. MOve 1/2 of pipe shed from 31 -08 pad to 3B pad. Continue rig down, and move rig componenets 3H -09. Note: Rig was released from 31 -08 at 20:00 HRS. 06/15/2011 Continue move rig from 31 -08 tp 3H -09. Spot over well. Set rig modules. Wait 3 HRS on Halliburton Slickline on Nordic 3 to allow spotting of rig. Rig accepted at 1600 HRS as per rig acceptance checklist. Rig up lubrictaor and pull BPV. Observed tbg pressure at 1400 PSI, Annulus at 1300 PSI. Install double annulus valve. Rig up Slop tank, and hardline from cellar manifold. Test same to 2500 PSI. Rig up lines, and displace well with 260 BBLS of 11.7 PPG mud, observed taking 201 BBLS to Tiger tank. Rig on hi -line power at 1630 HRS. 00:00 14:00 14.00 0 0 DEMOB MOVE MOB P Continue move rig and components form 31 -08 to 3H -09. Wait on Halliburton Slickline on Nordic 3 (3 HRS) to complete job and move unit. Set mating boards and Spot sub base over well. Spot and rig up all rig modules. Note: Use of only 1/2 of the pipe shed. 14:00 16:00 2.00 0 0 DEMOB MOVE MOB P Remove Spery Sun MWD shack form top of rig utilize crane. Work on Rig acceptance checklist installing handrails and stairs. Rig accepted at 1600 HRS. 16:00 22:15 6.25 0 0 DEMOB RPEQP1 RURD P Install double annulus valve. Rig up lines to cellar manifold. Rig up hard lines and slop tank for well kill. Test gas alarms. Rig up FMC lubricator and pull BPV. Observed tbg pressure at 1400 PSI, annulus at 1300 PSI, and OA at 200 PSI. Pressure test hardline to 2500 PSI. Held PJSM for well kill. 22:15 00:00 1.75 0 0 DEMOB WELCTL KLWL P Pump down annulus with 11.7 PPG mud, taking returns through tbg, out to slop tank. Hold back pressure on choke. Pump a total of 260 BBLS of mud, taking a total of 201 BBLS to slop tank. ICP = 1550 PSI, FCP = 275 PSI. Crew change Page 1 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/16/2011 24 hr Summary Complete well kill with 11.7 PPG mud all around. Observed fluid losses of 24 - 45 BBLS /HR. Monitor well.Wait on LCM. Mix & spot 60 PPB LCM at 2 BPM. Allow to set. Observed static losses at 4 BPH. Install BPV. Nipple down Tree. Install blanking plug. Nipple up BOP's. Momnitor well via annulus with 0 losses. Total losses for the day = 339 BBLS. 00:00 05:15 5.25 0 0 SURPRI WELCTL KLWL P Line up on choke lines on rig. Blow down hardlines to slop tank. Continue pumping 11.7 PPG mud down tbg, taking returns through annulus to pits until good 11.7 PPG all around. Observed rates of 1.7 BPM - 3 BPM with fluid losses of 24 - 45 BBLS / HR. . 05:15 06:00 0.75 0 0 SURPRI WELCTL OWFF P Monitor well for losses. Initial shut in pressure = 110 PSI. After 30 minutes, bled down to 30 PSI. Attempt to circulate - losses at 0 BPH. 06:00 12:00 6.00 0 0 SURPRI WELCTL OWFF P Shut in well, monitor. Tbg pressure bled form 110 PSI to 0 PSI in 1 HR. Continue monitor well, while wait on LCM products to be delivered. Crew change. 12:00 14:00 2.00 0 0 SURPRI WELCTL OWFF P Continue wait on LCM products to be delivered. Mix 35 BBLs pill. 60 PPB. SIMOPS: Load pipe shed with 4" DP, DC; s. 14:00 15:45 1.75 0 0 SURPRI WELCTL CIRC P Pump & spot LCM pill. Pumped @ 2 BPM - 500 PSI. Chase & spot with 650 strok3es @ 3 BPM - 700 PSI. Observed 66% losses while pumping. Shut in well. 15:45 17:00 1.25 0 0 SURPRI WELCTL OWFF P Monitor well with static losses now at 4 BPH. 17:00 17:45 0.75 0 0 SURPRI RPEQP1 NUND P Install BPV as pe FMC rep. Blow down all lines, and rig down same. Clear cellar area of lines. Continue monitor well via annulus and trip tank. 17:45 19:30 1.75 0 0 SURPRI RPEQP1NUND P Held PJSM. Nipple down tree and adapter spool. Pull adapter flange studs. Install blanking plug. Hanger threads inspected and looked good. 19:30 22:45 3.25 0 0 SURPRI RPEQP1 NUND P Held PJSM. Nipple up BOP stack, with adapter flange and spadce spool. SIMOPS: Blow down hard lines to tiger tank. Rig down same. 22:45 00:00 1.25 0 0 SURPRI RPEQP1 NUND P Change out upper ams installing 3 1/2" x 6" VBR's as planned. Total fluid losses for the day = 339 BBLS. Static loss on well = 0 BBLS.Crew Change Page 2 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/17/2011 24 hr Summary Continue install VBR's in upper set of rams. Rig up and test BOP's. All test to 250 / 4000 PSI. Recorded on chart. Witness of test waived by AOGCC rep Bob Nobles. Pull BPV & Blanking plug. Install landing joint. Pull tbg hanger to rig floor. Upweight 87K. Lay down tbg hanger. Rig up and break circulation with no gas on bottoms up. Observed 20 BBLS loss while CBU. POOH, breakout & lay down 214 jnts of 3 1/2" tbg, 7 GLM's SSSV and control line. Recovered 32 SS bands.. Total loss for the day = 52 BBLS. Total losses for well = 391 BBLS.. 00:00 01:30 1.50 0 0 SURPRI RPEQP1NUND P Continue change out upper ams installing 3 1/2" x 6" VBR's as planned. Static loss on well = 0 BBLS 01:30 08:00 6.50 0 0 SURPRI RPEQP1BOPE P Rig up. Install test joint. Fill BOP's & Choke with water. Test BOP's. test BOP stack, Manual and HCR valves. Test choke manifold and all valves. test all rig floor safety valves. All test 250 / 4000 PSI. All test recorded on chart. Perform koomey test with /30P initial 200 PSI obtained in 33 secs. Full 3000 PSI obtained in 209 Secs. /, 5 Nitrogen bottles with an avg PSI of 2100. Rig down BOP test equipment. Blow down lines. Line up choke manifold. Witness of test waived by AOGCC rep Bob Nobles. 08:00 09:00 1.00 0 0 SURPRI RPEQPI PULD P Make up LH acme running tool. RIH, ehgae blanking plug. Back out, and lay down same. Observed no pressure under BPV. Observed 10 BBL loss during test. Monitor well, fluid slowly falling in stack. 09:00 10:00 1.00 6,638 6,630 SURPRI RPEQP1PULD P Install landing joint. Rig up double stack power tongs. BOLDS. Pull hanger to rig floor with 87K straight pull. Observed no overpull. Breakout & lay down tbg hanger. 10:00 12:00 2.00 6,630 6,630 SURPRI RPEQP1CIRC P Make up head pin, and CBU x 2 staging pumps to 2 BPM - 300 PSI. Observed 20 BBLS loss while CBU. Mud wt = 11.7 PPG. Crew change 12:00 13:00 1.00 6,630 6,630 SURPRI RPEQP1CIRC P Complete CBU x 2 as above. Monitor well - fluid dropping. Mud weight = 11.7 PPG. Pump Slug. Rig up control line spooler. 13:00 15:30 2.50 6,630 4,824 SURPRI RPEQP1 PULL P POOH, breakout & lay down 3 1/2" tbq and control line to the SSSV recovered 32 SS bands. Observed tbg in good shape. 15:30 17:30 2.00 4,824 4,824 SURPRI RPEQP1SVRG P Service rig. Rig down Control line. Repair bad hydraulic hose on skate. Page 3 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 4,824 0 SURPRI RPEQP1 PULL P Contiinue POOH, breakout & lay down 3 1/2" BTC tbg, and 7 GLM's. Breakout & lay down seal assembly. Obtain OD measurement on seal assembly - 4 ". Observed proper hole fill, with 23 BBLS loss while POOH. Total fluid loss for the day = 52 BBLS, Total for well = 391 BBLS. Crew Change 06/18/2011 Clean & clear rig floor. Send tools out. Install test plug and 4" test joint. Test rams and annular to 250 / 4000 PSI. record on chart. Pull tools to rig floor. Held PJSM. Make up BHA #1, Spear assmy. TIH with BHA #1 single with 4" drill pipe. Tag & engage fish (PBR) at 6631' DPM. Pull PKR free with 180K. Monitor well. CBU- No Gas. POOH breakout & lay down fish. Fish = PBR, 2 jnts, and SOS. Observed PKR hanging on collars on TOH. Make up 6" Mill and 7" Scraper assembly. TIH to 6166'. Obtain parameters. Fluid loss for day = 76 BBLS. Total for well = 467 BBLS 00:00 01:30 1.50 0 0 DEMOB RPEQP1 RURD P Clean & clear rig floor area. Send tools out. 01:30 03:00 1.50 0 0 DEMOB RPEQP1 BOPE P Install test plug and 4" test joint. Test rams and annular to 250 / 4000 PSI. Record on chart. Pull and lay down test plug and joint. Install wear bushing with 6 3/8" ID. RIDS. 03:00 03:15 0.25 0 0 DEMOB RPEQP1SFTY P Held PJSM with crew and BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up and run BHA #1. Monitor well - static. 03:15 05:45 2.50 0 311 DEMOB RPEQP1PULD P Make up BHA #1, Spear assembly with 4.010 Spear grapple. MU jars, and Pump out sub. Pick up 9 Crill Collars. Total BHA length = 311.29' 05:45 12:00 6.25 311 6,631 DEMOB RPEQP1TRIP P RIH with BHA #1, single in hole with 4" drill pipe from shed, to 6631' DPM. Obtain paramters. Tag & Engage fish. UP WT = 140K, SO WT = 90K. Observed proper displacement on TIH - Fluid losses = 20.6 BBLS for the tour. Crew Change 12:00 12:30 0.50 6,631 6,631 DEMOB RPEQP1 FISH P Verify fish engage with overpull tg 120K. Set down 40K, repeat pull to 180K and observed PKR free. UP WT now - 177K. Allow PKR element to relax. Pick up and pull to verify fish free, but hanging up on collars. 12:30 14:00 1.50 6,631 6,631 DEMOB RPEQP1CIRC P Circulate bottoms up, 2 BPM - 450 PSI. 48 BBL loss while ciculating and no gas observed. 14:00 14:15 0.25 6,631 6,631 DEMOB RPEQP1OWFF P Monitor well - static. 14:15 19:30 5.25 6,631 0 DEMOB RPEQP1TRIP P POOH with PKR. Work PKR through ✓ casing collars, pulling up to 90K over early on. Continue POOH to surface. Lay down fish. Recovered PBR & PKR 20.82', 2 jnts - 30.77', and 31.71'. Nipple - 1.43', and SOS - .79'. Observed 6 BBLS loss on TOH. Page 4 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:00 0.50 0 0 DEMOB RPEQPI PULD P Clean & cleazr rig floor area. Send tools out. 20:00 20:15 0.25 0 0 DEMOB RPEQP1SFTY P Held PJSM with crew & BOT Rep. Discuss safety & hazard recognition issues. Discuss procedure to make up and run clean out assembly. 20:15 20:45 0.50 0 298 DEMOB RPEQPI PULD P Make up 6" mill and 7" Scraper assembly. Total BHA length = 298'. 20:45 00:00 3.25 298 6,696 DEMOB RPEQP1TRIP P Trip in hole form 298' - 6696' DPM. UP WT = 145K, SO WT = 90K. Observed 29 BBL Loss on TIH. Crew Change 06/19/2011 Continune run Clean out assembly through perfs with no issues. Tag up at 7076' DPM. Continue wash down to 7111' DPM. Observed hard tag, packing off. Circulate sweep around with 50% increase in cuttings on shakers and lots of sand. Monitor well. POOH, lay down clean out assembly. Make up Lower packer assembly with SOS & Plug. TIH to locate PKR depth at 6958' MD. RU Halliburton E -Line. RIH with GR -CCL to correlate PKR depth. On depth. Verify with 2 strips. POOH, RD E -Line crew. Pick up 6' to set PKR on depth as per program at 6952' DPM. Drop ball & set PKR. Release from PKR. POOH with running tool. Fluid loss for the day = 180 BBLS. Total loss for well - 647 BBLS. 00:00 01:15 1.25 6,696 7,111 DEMOB RPEQP1TRIP P Conitnue RIH with clean out assembly. Tag up at 7076' DPM. Wash down to 7111' DPm. Qbserved hard tag, and assembly packing off. Pump rate at 34 BPM - 860 PSI. 60 RPM's - 6K TQ. 01:15 02:45 1.50 7,111 7,111 DEMOB RPEQP1CIRC P Pump Hi Visc sweep, and increase rate to 4.5 - 5 BPM - 900 PSI. Circulate bottoms up, observing fluid losses form 28 - 34 BPH. Observed 50% increase in cuttings across shakers, with sand returns. Reciprocate & rotate drill string while circulating. 02:45 03:00 0.25 7,111 7,111 DEMOB RPEQP1 OWFF P Monitor well - static. 03:00 08:00 5.00 7,111 0 DEMOB RPEQP1TRIP P Pump Dry Job. POOH with clean out assembly. Breakout & lay down mill and scaper. Observed 14 BBL Loss on TOH. 08:00 09:30 1.50 0 70 DEMOB RPEQPI PULD P Make up Lower F -1 Packer assembly with running tool. Total length = 26.61'. 09:30 12:00 2.50 70 2,875 DEMOB RPEQP1TRIP P Trip in hole at slower string speed as per BOT rep to 2875' DPM. Observed proper hole fill. Crew Change. 12:00 14:00 2.00 2,875 6,732 DEMOB RPEQP1 TRIP P Continue trip in hole with F -1 Pkr assembly at slower string speed from 2875' - 6732' DPM. 14:00 15:00 1.00 6,732 6,732 DEMOB RPEQP1OTHR T Wait on E -line crew. 15:00 16:00 1.00 6,732 6,732 DEMOB RPEQPI ELOG P Held PJSM with Halliburton E -line crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run GR -CCL assembly with lubricator on DP. Rig up sheaves and lubricator with packoff assembly. Page 5 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 6,732 6,958 DEMOB RPEQP1TRIP P Continue trip in hole with packer assembly from 6732' - 6968'. Pull for stretch on upstroke to locate packer at 6958' DPM. 16:15 19:45 3.50 6,958 6,958 DEMOB RPEQP1 ELOG P Make up and torque all crossovers fr4om DP to Lubricator. Test all connections and lubricator - grease head to 200 PSI. WLIH with GR -CCL to verify depth of PKR. Run 2 stips for verification packer on depth. WLOH, lay down tools. Breakout & lay down lubricator & grease head. ��A " "" Breakout all crossovers. 19:45 20:30 0.75 6,958 6,952 DEMOB RPEQPI PACK P Pick up drill string 6' to put F -1 540, 0, packer on depth at 6952' DPM. Drop 1 7/16" ball pumping down at 2 BPM - 580 PSI, allow to seat. Pressure to 1800 PSI observing packer set., Continue pressure up with straight pull to 60K over. UP WT = 140K, SO WT = 95K. Verify released form running tool. Pull up 10'. Pressure DP to 3500 PSI to verify full flow through opening port. Pump 15 BBLS. 20:30 20:45 0.25 6,952 6,952 DEMOB RPEQPI OWFF P Monitor well - static. 20:45 00:00 3.25 6,952 2,403 DEMOB RPEQP1 TRIP P POOH with BOT running tool from 6952' - 2403'. Observed 5 BBL loss on trip. Total loss for the day = 180 BBLS. Crew Change. 36/20/2011 Continue POOH lay down BOT running tool. Clean & Clear rig floor. Make up Baker Model L Test packer assembly with running tool. TIH. Set Test PKR @ 6935' DPM. Test down drill string to test lower packe at 1000 PSI - 10 minutes. Release PKR, Pull up to locate PKR at 6850' DPM. Set PKR and test annulus to 1000 PSI - 10 Min. Record all test on chart. POOH, breakout & lay down test PKR. Make up upper packer assembly. Baker 7" FHL. TIH to locate. Pump 25 BBLS of corrosion inhibitor with 11.7 PPG fluid. Sting into lower PKR, and set upper PKR assembly at 6785' DPM. Test annulus to 1500 PSI - 15 min. Pick up, Shear PBR and release from PKR. POOH to 5959'. Make storm packer. UP WT 120K, SO WT = 80K. RIH & set Storm valve at 95' DPM. Release form strom valve. POOH breakout & lay down running tool. 00:00 01:30 1.50 2,403 0 DEMOB RPEQP1TRIP P Continue POOH with BOT running tool from 2403' - surface. Inspect and lay down same. Observed proper displacement. 01:30 02:00 0.50 0 0 DEMOB RPEQPI PULD P Clean & clear rig floor area. Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up and run Model L test packer. 02:00 02:30 0.50 0 20 DEMOB RPEQP1 PULD P Make up BOT Model L test packer assembly. Total length with XO's = 20.36'. 02:30 08:15 5.75 20 6,935 DEMOB RPEQP1TRIP P Trip in hole with test packer assembly at slower string speed as per BOT rep. Locate PKR at 6935' DPM. Observed 19 BBLS loss on trip. Page 6 of 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:30 1.25 6,935 6,850 DEMOB RPEQPI PRTS P Set test PKR. Test lower packer assembly pumping down drill string to 1000 PSI. 10 minutes on chart. Release PKR. Pull up to set PKR at 6850' DPM. Test annulus to 1000 PSI - 10 minutes on chart. release PKR. 09:30 09:45 0.25 6,850 6,850 DEMOB RPEQPI OWFF P Monitor well - static. 09:45 12:00 2.25 6,850 4,350 DEMOB RPEQP1TRIP P POOH with test packer form 6850' - 4350' . Observed 6 BBL Loss on TOH. Crew Change 12:00 13:45 1.75 4,350 0 DEMOB RPEQP1TRIP P Continue POOH, breakout & lay down test PKR asembly. 13:45 14:15 0.50 0 0 DEMOB RPEQPI PULD P Clean & clear rig floor area. RU to 3 1/2" tbg equipment. 14:15 20:15 6.00 0 6,952 DEMOB RPEQP1 PULD P Make up Upper packer assembly. Bake 7" FHL with Camco Injection Mandrel & Sliding Sleeve. Total assembly length = 206'. Trip in hole with assembly at slower string speeds. Slowly tag lower PKR assembly and sting into same at 6952' DPM. Pull to ynsting, and stay 2' above PKR. UP WT = 140K, SO WT = 90K. 20:15 22:15 2.00 6,952 6,952 DEMOB RPEQP1 PACK P Line up and pump 25 BBLS of 11.7 PPG Brine with Corrosion inhibitor. Pump to spot on annulus. Sting into lower packer assembly on depth. Pick up to neutral wt. Pressure down, drill string to 2500 PSI to set PKR on depth at 6785' DPM. Bleed pressure. Pressure down annulus to test at 1500 SPI for 15 minutes. Record on chart. Bleed pressure. Pressure DP. to 1800 PSI. Staright pull string to shear PBR and verify free of packer. 22:15 00:00 1.75 6,952 5,959 DEMOB RPEQP1 PACK P POOH with running tool to 5959' DPM. UP WT = 120K, SO WT = 80K. Make up Storm valve assembly. RIH to set storm valve at 95' form Za ,;,J�' Rotary table. Release form packer. Aj Crew Change. 1' 06/21/2011 Test Storm packer to 1000 PSI. Blow down lines. Nipple down BOP stack & lines. ND Tubing head utilizing Hydra -Tite tools for 6.5" of casing expansion. Nipple down tubing head, Spear casing and pull to 75K , with extra 8.5" of casing stretch, set emergency slips. Cut off 15" of casing as per FMC rep. NU tbg head. Install packoff & test same. NU BOP's & adapter flange. NU BOP's & test same. Witness of test waived by AOGCC rep Bob Nobles. Retrieve Storm valve. No pressure. POOH lay down storm valve. Continue POOH breakout & lay down upper seal assembly. Slip & cut Drilling Line. Rig up, and run 3 1/2" completion strin• 90 'nts. 00:00 00:30 0.50 5,959 5,959 DEMOB RPEQP1 PACK P Pressure test storm valve to 1000 PSI - 10 minutes. Bleed pressure. 00:30 03:30 3.00 5,959 5,959 DEMOB RPEQP1 NUND P Drain stack. Blow down lines. Nipple down BOP stack & lines. 1 Page7of9 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 05:30 2.00 5,959 5,959 DEMOB RPEQP1 NUND P Nipple down tubing head. Utilize Hydra Tite tools for 6 1/2" of casing expansion. Rig down Hydra tite tools. 05:30 08:30 3.00 5,959 5,959 DEMOB RPEQPI NUND P Pull Tubing head off. Spear casing. Pull 75K tension. Set emergency slips. Rig up WACHS cutter & cut 15" of casing as per FMC rep. Install 7" Packoff. Test packoff to 250/ 3000 PSI. - 10 minutes. 08:30 12:00 3.50 5,959 5,959 DEMOB RPEQPI NUND P Nu Adapter flange, tbg head and BOP's. Crew Change 12:00 14:00 2.00 5,959 5,959 DEMOB RPEQPI BOPE P Rig up test equipment. Test body break on ROP:s .test tubing spool and choke lines. 250/ 4000 PSI. record on chart. Witness of test waived by AOGCC rep Bob Nobles. Rig down test equipment and install wear bushing. RILDS. 14:00 14:45 0.75 5,959 5,959 DEMOB RPEQPI PULD P Make up retrieving tool. RIH to 95', retrieve storm valve. No pressure observed. POOH, breakout & lay down same. Monitor well - static. 14:45 17:15 2.50 5,959 0 DEMOB RPEQP1TRIP P POOH, breakout & lay down seal assembly. Observed proper displacement. 17:15 17:45 0.50 0 0 DEMOB RPEQPI PULD P Clean & clear rig floor area. 17:45 18:45 1.00 0 0 DEMOB RPEQPI SLPC P Slip & cut drilling line. Service Top Drive & draw works. 18:45 19:45 1.00 0 0 DEMOB RPEQP1 RURD P Rig up 3 1/2" tbq equipment._ Held PJSM. Discuss safety & hazard recogniiton issues. Discuss procedure to make & run 3 1/2" completion string. MAke up safety valve and pull wear bushing. 19:45 00:00 4.25 0 2,800 DEMOB RPCOM RCST P Make up seal assembly. RIH with 3 1/2" completion string with GLM's as per detail. 90 jnts. Observed proper displacement. UP WT = 55K, SO WT = 50K. Crew change 06/22/2011 Continue run 3 1/2" completion string with GLM's & SSSV. Tag and spaceout seal assembly. Install space out pups. Make up landing jonit & jhanger. Land tbg. Test tbg & casing. Shear SOV. ND BOP's. NU Tree & test same. Displace well, and freeze protect with Little Red pumping 90 BBLS. Allow to U -tube. Install BPV. Secure well & cellar. Rig up to lay down Drill pipe. 00:00 06:00 6.00 2,800 6,785 DEMOB RPCOM RCST P Continue run 3 1/7" r.nmplPtinn string to the SSSV. Make up SSSV, and control line. Test control line to 5000 PSI. Run string to tag packer, sting in and locate. UP WT = 90K, SO WT = 67K. 06:00 08:15 2.25 6,785 6,785 DEMOB RPCOM RCST P Locate top of PBR with pump. Fullu locate into PBR with seals. Pressure to 500 PSI to verify. POOH lay down full joint. Install space out pups. Installed 2 -10' pups, and a 4' pup, with a full joint under hanger. Page 8 of 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 09:00 0.75 6,785 DEMOB RPCOM RCST P Make up landing joint & hanger. Land tubing. RILDS. Total SS bands run with control line = 63. 09:00 11:00 2.00 6,785 6,785 DEMOB RPCOM PRTS P Rig up test equipment. Test tbg to 3000 PSI - 10 minutes. Bleed tbg to 2500 PSI. Pressure annulus to 3500 PSI- 30 minutes. Bleed pressures. Pressure annulus to 2800 PSI to shear SOV. Bleed all pressures. Close SSSV. Pressure on annulus to 1000 PSI to test SSSV. All pressures recorded on chart. 11:00 12:00 1.00 0 0 DEMOB RPCOM PULD P Rig down test equipment. Blow down lines. Install BPV. Crew Change. 12:00 13:00 1.00 0 0 DEMOB RPCOM PULD P Continue rig down completion running equipment. Clean & clear rig floor. 13:00 15:30 2.50 0 0 DEMOB RPCOM NUND P Nipple down BOP's. NU Tree & test packoff seals to 5000 PSI. 15:30 17:00 1.50 0 0 DEMOB RPCOM PRTS P Pull BPV. Install TWC. Test tree to 250 / 5000 PSI with diesel. Good test recorded on chart. 17:00 18:00 1.00 0 0 DEMOB RPCOM PULD P Pull TWC. Rig up to displace well. 18:00 20:45 2.75 0 0 DEMOB RPCOM CIRC P Displace well, pumping 33 BBLS of spacer, 40 BBLS of fresh water with Safe Surf W, 110 BBLS of seawater, and 180 BBLS of seawater with 1% CRW -132 corrosion inhibitor at 2.5 - 3 BPM. ICP 600 PSI. 20:45 21:00 0.25 0 0 DEMOB RPCOM SFTY P Held PJSM with crew & Little Red reps. Discuss safety & hazard recognition issues. Discuss procedure to rig up, and pump freeze protect diesel. 21:00 21:45 0.75 0 0 DEMOB RPCOM FRZP P With Little Red, Pump 90 BBLS of freeze protect diesel down annulus. 21:45 22:45 1.00 0 0 DEMOB RPCOM FRZP P Allow well to U -tube diesel until dead. SIMOPS: Clean pollution pan , blow down lines, and offload fluid from rig. 22:45 23:30 0.75 0 0 DEMOB RPCOM RURD P Blow down and Rig down all surface lines. Install BPV. Close all valves and secure tree and cellar. 23:30 00:00 0.50 0 0 DEMOB RPCOM PULD P Held PJSM with crew. Discuss laying down DP. Rig up to lay down Drill pipe form Derrick. Crew Change 06/23/2011 Lay down 4" drill pipe & DC's from derrick. Continue prep rig for move. Blow down rig, and modules. Rig released • 0600 HRS. 00:00 05:00 5.00 0 0 DEMOB RPCOM PULD P Breakout & lay down 4" drill pipe from derrick. Continue prepare rig for move. Clean pits. Secure location. 05:00 06:00 1.00 0 0 DEMOB RPCOM OTHR P Blow down rig and rock washer. Disconnect lines btween complexes. Rig Released at 0600 HRS Page 9 of 9 Page 1 of 1 • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Monday, June 06, 2011 9:29 AM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: RE: 3H -09 Upcoming testing and RWO deferral of required MIT is acceptable Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, June 04, 2011 9:01 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Subject: 3H -09 Upcoming testing and RWO Jim, Kuparuk injector 3H -09 (PTD 187 -112) is due for the AA required (AIO 2B.009) testing on 06/07/11. Currently the well is secured and prepped for the upcoming RWO that is tentatively scheduled to start in the next two weeks. Following the WO and passing initial tests, ConocoPhillips will be requesting to cancel the AA and continue injection under normal well status. Due to the configuration of the well for the WO, testing will not be able to be done until after the rig has completed the tubing swap. The pre- injection MITIA will be performed and the initial test once the well has been brought on injection. Please let me know if this is acceptable. Thank you Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 6/8/2011 • • [04 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 J. Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360' 4y, `U1'+ Anchorage, AK 99510 ,itaiitiseo Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -09 Sundry Number: 311 -142 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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, Daniel T. Seamount, Jr. Chair DATED this 2 day of May, 2011. Encl. ` • • RECEIVE" ConocoPhillips AfN' ?III Alaska Aria C 3 Oil & Ga cons. C am. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 Aflap April 27, 2011 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 3H -09 (PTD 187 -112). 3H -09 was originally completed in November 1987 as a single A & C sand injector. Several slugs of MI were injected between October 2001 and December 2003, but after 2003, the well was no longer capable of / MI injection due to minor tubing x IA communication while injecting gas. Since then, the well has remained a "water- only" injector to this day. This well is in an area that contains a thick, highly permeable C -sand, capable of delivering high rates of injection, but due to the single completion, there is no way to restrict the C -sand flow. The A -sand has a much lower permeability, and historical injection profiles indicate that little or no injection is going into the A -sand. The purpose of this workover is to pull the 3 ' /2" single completion and install a 3 ''/2" selective completion allowing for mechanical restriction or isolation of the C -sand, in order to increase A -sand injection and improve sweep efficiency. The current SBHP measures —3600 psi at the mid -perf depth, equivalent to 11.5 ppg EMW. 11.9 ppg KWF will be used during the workover. The well passes an MIT -IA and MIT -OA, but the IA fails a drawdown test due to a one -way packer leak. This packer will be replaced during the workover. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, .77 7?". J. Brett Packer Wells Engineer CPAI Drilling and Wells STATE OF ALASKA 11 E EJV ALASK� AND GAS CONSERVATION COMMISSI• , APPLICATION FOR SUNDRY APPROVALS LP , €' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Aa r d f$8sia issio18 Suspend fl Rug Perforations r Perforate r Pull Tubing ✓ . ,1:Firep4xtf ion Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 187 - 112 3. Address: Stratigraphic ` ` Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20086 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 3H -09 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25531 • Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7310 6382 ' 7168' 6241' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 3465 9 -5/8" 3500' 3040' PRODUCTION 7225 7 7260' 6331' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6870' 6926', 6957' - 6967', 6978' - 6998', 7000' - 7030' 5946- 6000', 6031'- 6041', 6052'- 6072', 6074' -6104' 3.5 J -55 6724 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BROWN PACKER MD= 6652 TVD= 5728 SSSV - OTIS SERIES '10 MD= 1807 TVD= 1766 12. Attachments: Description Summary of Proposal ; r 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/15/2011 Oil r Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ r GINJ r WAG J • Abandoned Commission Representative: GSTOR r SPLUG " " ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer © 265 -6845 Printed Name J. Brett Paccker Title: Wells Engineer Signature 7 7Z. Phone: 265 -6845 Date G �4 ?"" //f Commission Use Only Sundry Number:3 `- 1 "1 a Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test K Mechanical Integrity Test tie Location Clearance Other 35D j os,. 13 r° "C s+ ) . W ;4.�esse M c 7' — //4 �" ( Subsequent Form Required: APPROVED BY / J Approved b -/ COMMISSIONER THE COMMISSION Date: �` / z DMS lA 1 ,s75 ci z? d Form 10 -403 Revised 1/2010 7.29. Submi in uplic to , • • 3H -09 Rig Workover, Install Selective (PTD #: 187 -112) Current Status: Kuparuk well 3H-09 is an A/C sand single injector. The C -sand is quite prolific in this -area and as a result, the A -sand sees very little injection if any at all. The well will pass an MIT -IA and MIT -OA, but fails an IA drawdown test due to a suspected one -way packer leak. The well is currently online. Scope of Work: Pull the 3 ' /z" single completion and install a 3 ' /2" selective completion to allow for mechanical restriction/isolation of the C -sand. General Well info: MASP: 2,995 psi '/ Reservoir pressure/TVD: 3,571 psi / 5975' TVD (11.5 ppg) as measured on 9/3/10. Wellhead type /pressure rating: FMC Gen 4, 7- 1/16" 5K psi top x 11" 3K btm Doyon 141 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA— passed on 6/7/09, MIT -OA— passed on 10/15/10. Well Type: Injector Estimated Start Date: May 15, 2011 Production Engineer: John Tonello / Len Janson Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre -Rig Work: 1. RU Slickline: a. RIH w/ dual Panex gauges and obtain 30 min. mid A -sand SBHP at 6993' RKB, PUH to 6898' RKB and obtain 30 min. mid C -sand SBHP (for gradient calculation). b. Pull DV at 6594' RKB, leave pocket open. c. Lock out SSSV @ 1807' MD. 2. PT tubing & IA packoffs. 3. Set BPV. Proposed Procedure 1. MIRU Doyon 141. 2. Pull BPV, circulate 11.9 ppg KWF around until 11.9 ppg fluid returns at surface. Bullhead an additional 25 bbls to the formation. SI and monitor well for 30 min. Record SITP & SICP, verify well is dead. ' 3. Set BPV & FMC blanking plug. ND tree, NU BOPE & test BOP's to 4000 nsi, test annular to 3000 psi. • 4. Pull blanking plug & BPV. Circulate bottoms up. ° �� 5. MU landing joint, BOLDS, and attempt to pull tubing from the PBR. a. If tubing does not pull free, RU E -line and RIH w/ the RCT and cut the tubing at 6,629' RKB (middle of the full joint above the PBR). POOH. RD E -line. 6. POOH laying down 3 ' /2" EUE 8rd J -55 tbg spooling up control line. • 7. MU overshot and single in on 4" XT -39 drillpipe. a. If tubing was cut, latch onto tubing and jar seal assembly from the PBR. POOH standing back drillpipe, lay down fish. RBIH w/ overshot dressed for 5.125" OD PBR. 8. Latch onto PBR and jar `HB' packer free. POOH standing back drillpipe, lay down fish. 9. RU E -line: MU Baker `FI' lower packer assembly with short tailpipe and RIH w/ GR and CCL. Tie into 7" marker joint at 6910' RKB or A -sand perfs, set lower packer above A- sandperfs at –6940' RKB. POOH. RD E -line. 10. MU Baker `FHL' packer and selective completion and RIH on drillpipe to –6940' RKB. • • 11. Spot corrosion inhibited brine below FHL. 12. Sting into SBE until fully located, pull up lft, drop ball & rod, set the FHL w/ 2500 psi. PT the IA to 2500 psi. Shear the PBR. POOH laying down drill pipe. 13. Unload old tbg, load & strap new 3 'h ", 9.3 #, L -80 8rd EUE tbg into pipe shed. 14. Redress seal assy. (if needed) and single in w/ new 3 ' /2" tubing. Install SSSV at 2000' MD. Continue RIH to just above the PBR. Sting into PBR, space out 7 ft from fully located, mark pipe and pull out of PBR. • 15. Load IA w/ corrosion inhibited brine. 16. Space out final completion ensuring full joint of tubing below the hanger. MU tubing hanger, feed control • line through hanger and secure w/ swage -lock fittings. Land the hanger. RILDS. 17. PT the tubing to 3,000 psi, bleed tbg to 2500 psi, PT the IA to 3500 psi for 30 min and record on chart • recorder. Bleed the IA to zero, then the tubing to zero. Ramp up the IA pressure quickly to shear the SOV. Function test the SCSSSV and pressure test from below. 18. Pull landing joint, set two -way check, NDBOP. 19. NU and test tree. Pull two -way check, freeze protect, and set BPV. 20. RDMO Doyon 141 Post -Rig Work: 1. Pull BPV. 2. Pull ball & rod. Pull SOV and install DV. Pull RHC plug body. 3. Turn well over to operations. • • Cono+COPhiiii S Well: 3H -09 Proposed 3 -1/2" Selective Completion Conductor: 16 ", 62.5 #, H-40 to 115' MD 3 1 /:" Selective Completion sv Surface Casing: • Tubing = 3%", 9.3 ppf, L -80, 9.625 ", 36.0#, J -55 BTC to 3500' MD 8rd EUE J Prod Casing: • SSSV. 7 ", 26.0#, J -55 BTC to 7258' MD • Baker 20' PBR. • Baker FHL Packer. ' J • Injection Mandrel. J • CMU Sliding Sleeve. • Baker 'F1' packer w/ SBE. - y 4/ 4 20' PBR 4 FHL Packer J 4 — Injection mandrel O • CMU Sliding Sleeve Z /— Baker 'F1' Packer w/ SBE Mow- 4 11 K IUP 0 3H -09 ConocoPhillips ! , $ } Well Attributes Max Angle & MD STD , , ; ; Welibore APUUWI Field Name Well Status Inc!() IMO (10(13) Act BM (ftK8) `' a'( LFmrnc*z}tathps 501032008600 iKUPARUK FIVER UNIT INJ 4 42.62_ 2,700.00 7,314.0 Comment H25 (ppm) Date Annotation End Date KB Rig Release Date .. "- We 39,09 6152/3009,275.1 N -__` SSSV TRDP ! -.. .. Last WO: L 42 -4 0 11/30/1987 2nd......,. _-_ _ _ ., $di?mekt AMUai • �. A t too Depth (*KB) Entl Date Mnota Last Mod By End Data L, - .1 I aq RKB 7 012.0 1 3/28/2009 LRev Reason ACID TREATMENT Imosbor 8/12/2009 Casing Strings String O String ID Sot Depth Set Depth (TVD) String Wt String CONDUCTOR, c C_asi_n Des roman_ (in) (in) Top (ftKB) (ftK6) (ftK6) (Ibs/*) Gra String Top Thrd 115 CONDUCTOR 16 15.062 0.0 115.0 115.0 62.50 H -40 SURFACE 95/8 8.765 0.0 3,500.0 3,039.9 36.00 J-55 SAFETY VLV, ( PRODUCTION 7 6.151 0.0 7,258.0 6,331.1 26.00 J -55 1,807 - Tubing Strings -__ c s '. String OD String ID Set Depth Set Depth (TVD) String Wt String robing Descpt'c n (in) (n) T ftK8 (RK (f� (DaM1) Grade Stri n ng Top Thrd GAS LIFT, - - TUBING 3 1/2 2 992 0.0 6,724.0 5,799.5 9.30 J -55 EUE8rdABMOD 2.475 _Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth SURFACE, _ (ND( Top Intl 3,500 - Top (RKB) (RKB) (") Deudption Comment Run Date ID (in) 1,807 1,764.9 33.34 SAFETY VLV Otis Series '10 SSSV 12/15/1987 2.813 GAS LIFT, _ 2,475 2,278.9 41.40 GAS LIFT CAMCO /KB UG /1 /DMY /BK/ // Comment STA 1 12/15/1987 2.875 4,334 4,334 3,674.8 38.58 GAS LIFT CAMCO /KBUG/1 /DMY /BK/// Comment STA 2 12/15/1987 2.875 5,295 4,451.5 31.34 GAS LIFT CAMCO/KBUG/1 /DMY /BK/ // Comment STA 3 12/15/1987 2.875 5,695 4,806.5 23.22 GAS UFT CAMCO/KBUG/1 /DMY /BK/ / /Comment STA4 12/15/1987 2.875 GAS LIFT -�. j 6,266 6,031 5,121.8 17.44 GAS UFT CAMCO /KBUG /1 /DMYBK/ / /Comment. STA5 12/15/1987 2.875 6,370 5,449.8 11.39 GAS UFT CAMCO/KBUG /1/DMYBK/ // Comment STA 6 12/15/1987 2.875 6,594 5,6706 8.12 GAS LIFT OTIS/LBX/1.5/DMY /T -2/// Commerd: STA 7 12/22/1987 2.907 GAS 5.695 LIFT, _ 6,638 5,714.2 ; 48 PBR Baker PBR 12/15/1987 2.992 6,652 5,728.1 ; 34 PACKER Brown PACKER 12/15/1987 2.992 6,690 5,765.8 6.98 NIPPLE Camco '121* Nipple NO GO 12/15/1987 2.750 GAS LIFT, _ .;iii 6,723 5,798.5 0 66 SOS Camco 12/15/1987 2.992 6,031 6,724 5,7995 6.65 12/15/1987 2.992 Perforations & Slots r GAS LIFT, Shot 6,370 ,„ Top(TVD) Btm (TVD) Dens Top (ftKB) Ban (ftK6) (RKB) (MB) Zone Date (sh -• Type Comment 6,870 6,926 5,944.7 6,000.4 C C -3, 3H -09 5/12/1988 12.0 APERF 2 1/8" Enerjet 60 deg ph GAS LIFT, 6,957 6.967 6,031.3 6,041.3 A-3, 3H -09 5/12/1988 12.0 APERF 2 1/8" Enerjet; 60 deg ph T". 6,594 _ - - -._.__ - --- y;; 6,978 6,998 6,052.2 6,072.1 A -2, 3H -09 1/10/2001 3.0 APERF 2 1/8" Enerjet; 90 deg CCW f/highside 6,978 6,998 6,052.2 6,072.1 A -2, 3H -09 1/11/2001 3.0 RPERF 2 1/8" Enerjet; 180 deg CCW -_ - f/highside PBR, 6,638 - - 1 _ 7,000 7,006 6,074.1 6,080.1 A -2, 311-09 12/11/1987 2.0 IPERF 4" Densi Jet 120 deg ph 7,008 7,010 6,082.1 6,084.1 A -2, 3H-09 1/10/2001 3.0 APERF 2 1/8" Enerjet 90 deg CCW f /highside 7,010 7,016 6,084.1 6,090.1 A -1, 3H-09 12/11/1987 2.0 IPERF 4" Densi Jet; 120 deg ph PACKER, 6,652 7,010 7,016 6,084.1 6,090.1 A -1, 3H -09 1/5/2001 3.0 RPERF 2 1/8" Enerjet 90 deg CCW 1 f /highside 7,010 7,028 6,084.1 6,102.0 A -1, 3H -09 1/10/2001 3.0 RPERF 2 1/8" Enerjet 90 deg CCW NIPPLE, 6,690 -- - {. 9 f/hi hside '.: 7,016 7,030 6,090.1 6,104.0 A -1, 31-09 1/5/2001 3.0 APERF 2 1/8" Enerjet, 90 deg CCW f/highside sus, 6,723 , Stimulations & Treatments ......... _ Bottom Min Top Max Btm Top Depth Depth TTL, 6,724 \. Depth Depth (TVD) (TVD) (660) (ftK8) (*KB) (MB) Type Date Comment 6,945.0 7,040.'; 6,019.4 6,114 OlAcid Wash 8/11/2009 ' Wash w /10 bbls 15 %HCL Notes: General & Safety APERF, End Date - - -- Annotation 6,870 - 6,926 12/18/2003 NOTE WAIVERED WELL: T x IA COMMUNICATION APERF, 6,9576,967 APERF, 6,978£,998 RPERF, 6,978 -6,998 Add Wash, 6,945 IPERF, 7,000-7,006 ERR, APERF, 7,008 -7,010 IPERF, I 7,010 -7,016 RPERF, 7,010 -7,016 t RPERF, 1 F 7,010 -7,028 APERF, 1 1 7,016 -7,030 PRODUCTION, 7,258 TO, 7,314 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 20, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RAJOW NOV I62010 RE: Injection Profile: 311-09 Run Date: 10/4/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -103- 20086 -00 Injection Profile Log 1 Color Log 50- 103 - 20086 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 v a Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wt011butno, Date: Signed: • STATE OF ALASKA . . . ,. .. ~t'' ~ ,». ~.. °%~~(/ / • ALASKA OIL AND GAS CONSERVATION COMMISSION _ ~ ~,, , .., .~. .e. ., t~ '1J.„~ ij 4~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandOn ^ Repair Well ^ Plug Pertorations ~ Stimulate ^~ Other ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, 111C. Development ^ Exploratory ~ 187-112 /- 3. Address: Strati ra hic g p ^ Service ~ ^ ` 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20086-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' ~ 3H-09 - 8. Property Designation: 10. Field/Pool(s): ADL 25531 ~ Kuparuk River Fieid / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7310' ' feet true vertical 6382' ~ feet Plugs (measured) Effective Depth measured 7168' feet Junk (measured) true vertical 6241' feet Casing Length Size MD ND Burst Collapse Structurat CONDUCTOR 115' 16" 115' 115' SURFACE 3424' 9-5/8" 3500' 3040' PRODUCTION 7182' 7" 7258' 6331' Pertoration depth: Measured depth: 6870'-6926', 6957'-6967', 6978'-6998', 7000'-7006', 7008'-7030' true vertical depth: 5945'-6000', 6031'-6041', 6052'-6072', 6074'-6080', 6082'-6104' Tubing (size, grade, and measured depth) 3.5", J-55, 6724' ~~ a ~ ~~~ ~~~~~~~ ~`~ ~~ i`( ~~ ~ ~0~~ Packers & SSSV (type & measured depth) Brown pkr ~ 6652' Otis series 10 SSSV @ 1807' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6945'-7040' acid wash 10 bbls 15% HCI 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 1234 Subsequent to operation 2722 - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~~ Daily Report of Well Operations _X 16. Well Status after work: - Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact Reid Ed s@ 265-6020 Printed Name r R' ~ar ` ' Title Drillsite Petroleum EngineerA ~ ~ ~ 0~ Signature ,/ r.-~ / % Phone: 265-6020 Date 7 ~ ~~ ~ ~ r%'~ ""'~ Pre red b aron All u Or k 26 -4612 ~`` X' SM~+fI 3~ ~; ~ P , - ~z._~ ~~~ i '; 7`~(}C Form 10-404 Revised 04/2006 ~,~p Submit Original Only III 3H-09 Well Events Summary DATE SUMMARY 8/10/09 RIH & CLEAN DOWN TO HARD (a~ 7154' CTMD WHILE MAINTAINING ~EURNS THROUGHOUT CLEAN OUT ESTIMATE 120~ OF RATH(~l F RFI (~W RTIIA PFRF LOCATED @ 7030' RKB. RETURN IN A.M. FOR ACID TREATMENT, JOB IN PROGRESS. 8/11/09 PERFORM A TWO STAGE ACID TREATMENT WITH 10 bbls OF 15% HCL ON EACH STAGE FROM 7040' CTMD TO 6945' CTMD ON THE A SAND PERF.TURN WELL OVER TO DSO, TO RETURN WELL TO INJECTION.JOB COMPLETE. KUP ~ 3H-09 s __ I Fieltl Name Well Status IMax Angle 8 MD _ Incl (°) MD (fiKB) ~TD ~Act Btrn (flK8) '~,KUPARUK RIVER UNIT INJ 42.62 I 2,700.00 i_ 7,314.0 ' H2S(ppm~ IDale 'IMnotation EnGOale KB-Grd(H) ~ IRigRaleaseDa7 I ILast WO~ I .. . . i 42.40 ~ 1 1 /3 011 98 7 apth (kKB) End Data Mno~ation I I ~ Last Mod By I ~Entl Date 7(11~ (1 'i/7R/~(1(19 Rav Rrac~n~ ACID TREATMENT Imos6or ~ 8/12/2009 GAS LIfT. 2.0]5 SURFACE, 3.500 GAS LIFT. d.334 GAS LIFT, 5?95 GAS LIFT, 5.fi95 GAS LIFT. 6.031 GAS LIFT, 6,370 GAS LIFT. 6.590 PBR,6.638 PACKER.6.652 NIPPLE, fi,690 SOS, 6,123 TTL.6.720 APERF. 6.870~6.916 APERF, _ 6,951-6,96] APERF. 6.578-6.596 RPERf, fi.978.6.998 Aatl Wes~, 6.945 IPERf. 7.000-7.006 APERf, 7.008~7.010 IPERF, ],010-'/,Ot6 RPERF, 7.010-7.016 '-' - RPERF, ],010-],028 ~~ APERF. 7,016-'I.030 PRODUCTION, ],258 \ TD,1,31 / TUBING I 31/21, 2.9921 0.01 6.7240~ 5.799.SI 9.30IJ55 ;tUtBrtlF Top(HKB) Top Depth'~, ~D) ~li Top Incl ~ryKg~ (°) Dascription I Comment RunData 1,807 1,769.9 ~'~ 3334 SAFETYVLV OtisSeries'10SSSV iZ15/1987 2,475 2,278.9 41.40~~. GASLIFi I CAMCOIKBUG/i/DMY/BK///CommentSTA1 12/15/1987 ~ 4,334 3,674.8 38.58~ GASLIFT CAMCO/KBUG/i/DMY/BK/!/Comment:STA2 1Z75l1987 ~ 5,295 4p5L5 31.34 GAS LIFT CAMCO/KBUG/1/DMY/BK/// Commenc STA 3 12/15/1987 ._._.. 5,695 4,806.5 2322 GAS LIFT . . .. CAMCO/KBUG/1/DMY/BK/// Commem: STA 4 _ 12/15/1987 ~ 6,031 5,121.SI 17.44I GASLIFT '~, CAMCO/KBUG/t/DMY/BK/uCommentSTAS 12/15/1987 6,370 ~ 5.449.8, 11.39 GASLIFT ' CAMCO/KBUGl1IDMY/BK///Commenl:STA6 1Z75/1987 6,594 5,670.6~j ~8.12 GAS LIFT OTIS/LBX/LS/DMY/T-2/// Comment STA 7 12/22/1987 6,638 i 5,7142I . 748 PBR BakerPBR 12/15/1987 ~~ 6,652 5,728.1 7.34 PACKER Brown PACKER 12/15/1987 Top (ftK8) Bbn (kK8) Top (ND) (ftK8) etm (NU) (kKB) ~ Zone ~ Date ~~s (s~-~~ Type Comme~rt 6,870 6,926 5,944J 6,000.4 C-0, C-3, 3H-09 ! 5112l1988 12.0 APERF 2 1!8" EnerjeT, 60 deg ph 6,957 6,967 6,031.3 6,0413i A-3,3H-09 ~ 5/1217985 ~ 120;APERF 21/8"Enerjet;60degph 6,978 6,998 6,0522 6,072.7 A-2, 3H-09 1/10(2001 ~~, 3A~APERF 2 118" Enerjet; 90 tleg CCW f/highside 6,978 6,998 6,0522 6,072.1 A-2, 3H-09 1/112001 3.0 RPERF 2 1/8" Enerjet; 180 deg CCW ~ f/highside 7,000~ 7 006~ 6 074_7 6 080.1 A-2, 3H-09 12/11l1987 ~' 2D IPERF 1 4" Densi Jet, 120 deg ph 7,008~ 7,010 6,082.1 6,084.1 ~ A-2, 3H-09 7l Wl2001 ~~~ 3.O,APERF 2 1/9" Enerjet; 90 deg CCW Nhighslde 7,010 7,016 6,084.1 6,090.1 A-1, 3H-09 12/17/198% 2.0 IPERF 4" Densi Jet; 120 deg ph ~ _.- __ ... 7,010 . 7,016 ._ 6,084.1 6 090J A-1, 3H-09 ~ . I V52001 . 3.0 RPERF . 2 1/8" Enerjet; 90 deg CCW I Uhighside _-- 7,010 7,028 6,084.1 6,102.0 A-1, 3H-09 i 1l10/2001 'I 3.0 RPERF -_ _ 2 1/8" Enerjet 90 deg CCW ~ . Uhighside 7,016 1,0301 ~ 6,090.1 6.704.0 A-1, 3H-09 7/572001 3.0 APERF 2 1/8" Ener~eT 90 deg CCW Stimula . tions & Treatme nts ~ . _ _ . . _ ___._ . ... t/hlghslde _.... __.___ . _.....__ l Bottom Min Top Max ebn Top Depih Dep[h ~ Depth Depth (ND~ (TVD) , (ftK8) (ftK6) ~ (kK6) (HKB) ~. Type Date Commeik __ _ Si11(2009 IAcid Wash w/10 bbls 15% HCL Q945.0, 1.G40 0! 6 019.4 6,114.OIACid Wash , , _- Notes: General 8 3afety _ , _ End Date Annolation 12118I2003 INOTE: WAIVERED WELL T x IACOMMUNICATION _'_.....__. ~. - ~ ~ C01'1 ~ . . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder ~ l 1~` Alaska Oil & Gas Commission ~ ~ ~ 333 West 7~' Avenue, Suite 100 ~ b(~ Anchorage, AK 99501 ~ ~ / ~, ~, > r~ F ~ j. . ^ ~iti9>wM{~F 'i; Dear Mr. Maunder: ~ ~ - Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. 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 treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~`, 9~' and 10~' 2009. The atta.ched 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. Sincerely, v~~~` ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor I~ ~ l___I ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-ofF Report of Sundry Operations (70-404) Kuparuk Field Date 08/11/09 ~.. ~~ ~~ o ", ~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ...x Corrosion inhibitor ~ Corrosion inhibitoN sealant date bbls a~ 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'S" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" Na 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" Na 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" _ n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9l2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 27" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8l2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 ~ MEMOR.ANDUM TO: Jim Regg P.I. Supervisor ~@'~ Ct 7'ZZ' ~1~ r FROM: Chuck Scheve Petroleum Inspector I~ ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-09 KUPARUK RIV LJNIT 3H-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV iJNIT 3H-09 Insp Num: mitCS090608142145 Rel Insp Num: API Well Number: 50-103-20086-00-00 Permit Number: 18~-112-0 Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Init'tal 15 Min. 30 Min. 45 Min. 60 Min. Well 3x-o9 Type Inj. ~' TVD 5~2~ ' IA io9o ~zoo " izzo iz2o P.T.D~ lsnizo ~TypeTest SPT Test psi Interval ~Qv~ p~ r isoo , pA _ Tubing iao L ~o~s »60 ~ ton i~oo io~s i~oo io~s _ ~ Notes: MITOA required by AIO 2B.009 ~ ~` ~~~•}` *r-°... ~": ~;. ~< <,`~Jo,`~i,i Wednesday, June 10, 2009 Page 1 of 1 ~ MEMORANDUM 'ro: Jim Regg ~ P.I. Supervisor ~/ ~ ~(ZZ-~ ~ ~ C FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integriry Tests CONOCOPHILLIPS ALASKA INC 3H-09 KUPARUK RIV LTNIT 3H-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv J~ Comm Well Name: KUPARUK RN i1NIT 3H-09 Insp Num: mitCS090608141733 Rel Insp Num: API Well Number: 50-103-20086-00-00 permit Number: 187-112-0 ' Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3x-o Type Inj. ~' TVD P.T.D is~112o TypeTest SPT Test psi s~~~ ' isoo IA pA ~ iaao zoo za6o zaz o zao zao zazo Zao ~ Interval ~QvaR p~ r ~ Tubing lo~s io~s io~s io~s Notes: MITIA required by AIO 2B.009 i .~4l~-~ ~ r `; €ti / f~~ti ; ~,i c,. , . 1r 4 . Wednesday, June 10, 2009 Page 1 of 1 � v -vim `i I" 10- ri -77v) . Lam vviuiwacu iviii vri yci rxiv z_u.vi•r vi J Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MA ©P %IYP AA # 2C-07 7" 26 ppf K-55 4980 3000 60% AIO 28.007 2G-03 7" 26 ppf J -55 4980 3000 60% AIO 28.014 3A-06 7" 26 ppf J -55 4980 3000 60% AIO 28.008 3A -11 7" 26 ppf J -55 4980 3000 60% AIO 28.022 3A -14 7" 26 ppf J -55 4980 3000 60% AIO 28.026 ki 3H-09 7" 26 ppf J -55 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 26.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. NOV 1 2010 Office 907 - 659 -7224 Cell 907 - 943 -1720 Pager 907- 659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 213.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 /.v -vJ `L 11! 10 tIJ7v) ULGLLV W1L11V33L.LL 1Y111 VA FVl .J The AIO 213.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 2B.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. 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 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 1-v -vJ kr i L 10-t i JYV) aLULU wiuic�,ncu ivii i vri Fci ruv 1.13.v i-r r agv J vi J 0 9 Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 2B.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 2B.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 213.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xls>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 1\lE MORAND lJ M . State of Alaska . \Iaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor o \IT:lucsd~¡\ June I' 2!)(j7 -:::> ..! cII'7' \~'Y~ b! ¡"LJ SlB-lFCT: \'echanlc:\llntegrll\ lèsts CO'iOU)PHILLiPS INC FRO:\I: John Crisp Petroleum Inspector KUPARljK RIV UNIT 3H-09 \ ~l"- \ I ()- Src: Inspector Reviewed By: P.I. Suprv C;&.e.- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3H-09 Insp Num: mitJCr070612134909 ReI Insp Num: API Well Number: 50-103-20086-00-00 Permit Number: 187-112-0 Inspector Name: John Crisp Inspection Date: 6/8/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---_..._~_._------ .----_.~- ~~._..__....._-~--- --- --,' ----..------- -- Well í 3H-09 [Type Inj. ¡ N I TVD . . , I -~--·-I·-~ ; -.1 - i ·----------~-~--··-·--·-~--·-·T--···-----·- P.T.D, )871120 iTypeTest, SPT I Test psi )500 OA 50 70 _______._l___._.._..~_._._.___..,_._ L--..__~_'---.____. ____..1.___ __L.._______ ,__ ___.. .__L __ ___ ____ _._. Interval REQVAcR P/F P ;/' Tubing 990 990 --==-------_.._-------_.._-----~------ ----_.~~------- --- Notes: 1_8 bbl's pumped for test. 2 year test, variance A10 2B.009. SI since 4115/07 due to CPF 3 SWI shutdown for facility work 5728 IA 14)0 2950 --~_._--_._---_._-~---~-~~--------.-,-~,._---_.._---- " , 2870 [ 70 I , 29)0 2880 ------~---- ~..._-- ìO 70 990 990 I 990 ! v/· 5CANNED JUN 2 1 2007 Tuesday, June 12,2007 Page 1 of 1 • ~-7~ ®~! ~~1dT~EYt~1l1`I®1~T C®SSI®1~T L_J FRRIVOC ~l. ftiYURPfO~!/S4Cl, GOi1ERMOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99507 -3539 PHONE !907) 279-1433 FAX (907) 275-7542 AI)NIINISTRATIVE APPR®i~'AL ~i®. AIO 2B.009 L•Ir. Jerry Dethlefs Problem ~~'ell Supervisor ConocoPhillips Alaska, Inc. F.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: KRU 3H-09 (PTD 187-1 12) Request for Administrative Approval Dear Nlr. Dethlefs: ~~NE~ JAN (~ 4 2DD~S On Play 28, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO"} 2B to allow continued water injection in service well Kuparuk River Unit (~`KRU") 3 H-09. The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below-. 3H-09 was originally reported to have tubing x inner annulus (`'T x I4") pressure communication in December 2003 and a sundry was obtained for continued operation. Diagnostic testing determined that the IA pressure communication is due to a teak at the packer and that a rig workover is necessary to repair the well. CPAI has elected not to perform corrective action on 3H-09 to restore full integrity. The Commission finds that, based upon reported results of CP:AI's diagnostic procedures, 3H- 09 exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. Where freshwater is not affected, 20 AAC 2~.~30 gives the Commission authority to approve less stringent well integrity and operation requirements. Per Rule 9 of AIO 2B, the Commission hereby grants CPAI's request for administrative approval to continue water injection in KRt1 1 H-07 on the following conditions: 1. Injection is limited to WATER ONLY; 2. CPAI shall monitor and record tubing, inner annulus and outer annulus (T'h'O) pressures and injection rate daily; AD~~4INISTR.aTI~%'E ~PPRO~L A[O ti`O. 2B.009 Jung Z t. 2006 Page Z of 2 3. CPAI sha11 submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; ~. CPAI shall perform an Combined Mechanical Integrity Test ~C~IITI of the tubing and inner annulus (T x IA) every two years; ~. CPAI shad perform an NIIT-OA every two years; 6. CPAI sha11 immediately shut in the w'e11 and notify the Commission upon any measurable change in the we11s mechanical condition: and 7. ~=after well shut in due to a change in the well's mechanical condition. Commission approval shall be required to restart injection. 8. The MIT anniversary date is December 6, 200. As provided in AS 31.03.80, 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 x: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. DONE at ~,r~fc~orage, Alaska and dated June 21, 2006. Th Al sk 'and Gas Conservation Commission /~, /~ ~~ j% i i ~~ f! ~~ rma Daniel T. S,eamount, Jr. Chairman Commissioner O a ~"~ ~ a y y 4I "~ t. ? ~~~ ~ 1 ~ ~~ t \' ~ Z L1 ~ :~ A vl _~~ e'~' ~ y - ~ i~ Viid- " _ .:., i /_; f ,, ~ ~~-~ Cathy . Foerster Commissioner MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~~~ S~::'~isor 'Ker1 t zl ¡z-J Ý>' DATE: Monday, December 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-09 KUPARUK RIV UNIT 3H-09 \ t61~ 11'1/ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3H-09 Insp Num: mitJCr051209120508 ReI Insp Num API Well Number 50-103-20086-00-00 Permit Number: 187-112-0 Inspector Name: John Crisp Inspection Date: 12/6/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. fil-r~~:~~-~~f~~~~ s;[~:~ psi I ::~~-r~:l-2:~:-I:iz:;---r-~2:8~-~~-r====-f~-~-~~~-== fut'~,; ~~';' - p¡;;- ,-,,"-l - ~ubi';g 1- ¡,"O-G80 I 1,"0 T- "" +-~ i -- - _..____.~__._.__________________~~____ _____.___~_._--'--~__.~____L_____.~____L___________J_._________ Notes The well was found with 1750 psi on IA ThdA was pressured to 3000 psi - 15 min. 2890 - 30 min. 2810 - 45 min. 2750. 1 requested the Operator to repressure IA The test data in the report reflects the re-pressure test ~GA~~~~~L ( (. Monday, December 12,2005 Page 1 of 1 7j¿7 09/24/04 Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: 8eth Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date 8L Color ~'f -O'i2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 :tS -05' 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 1t{- 038 28-12 10802934 INJECTION PROFILE 09/10/04 1 ~ If- 1(~4 J 2X-11 10802933 PRODUCTION PROFILE 09109/04 1 '~l- ~S 18-10 10922467 PRODUCTION PROFILE 09/21/04 1 . () .-. "5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 '''-0% { 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 cg'i - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 f ~2. -,~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 1 2.- If 1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~ß~ -D!o 1A-14 10802938 INJECTION PROFILE 09/13/04 1 t &t~ 070 2H-03 10802945 INJECTION PROFILE 09/18/04 1 lß?I-05' 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 r~... olflf 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H?. 3H-09 10922468 INJECTION PROFILE 09/22/04 1 1 'ii' -¡tit 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 ~9()- /(,~1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD .~ ~ Sl€;~ I. k~ ~ÇANNED NOV {) íJ 2DlJ4 DATE: /f ¡Þ¿ Please sign and returle copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (;h ) reg 7-- os'?' t~'7-ÐZ.C; / C¡¡0--(Cofo J 'ifg' - 0'1 ( {~rl- 1£2. Page 1 of 2 Conoc;r;hillips Transnlittal #383 Detail Date: 9/29/2004 To (External Party): Email: Howard_Okland@admin.state.ak.us Fron1 (I' AI Contact): Email: Sandra.D.Lemke@eonocophiIIips.com First Sandra Name: N Last Lemke ame: Phone 265-6947 Number: Company: ConocoPhillips Alaska Address: 700 G Street, A TO 1486 City: Anchorage State: Ak Zip Code: 99510 First Name: Howard Last Name: Oakland Phone Number: Company: Address: City: c State: Zip Code: Sent Via: hand delivery Transn1ittal Info: Tracking #: Justification: per 9/26/2004 request from Helen Warman, AOGCC Librarian Quantity 1 1 1 1 1 1 . Data Detail: Description Core Analysis report-KRU 30-12; Core Labs CL BP-3-1281; 8/9/1988 Core Analysis KRU 3M-09; 7/21/1987; Core Labs Core Analysis Report; KRU 3H-09; 2/22/1988; Core Labs Core Analysis Report; KRU 3K-09; Core Labs; 1/19/1987 Core Analysis Report; KRU 3M-16; Core Labs 8/19/1987 Type paper / paper / paper / paper J paper / paper / Core Analysis Report- KRU 21'-09; Core Labs; 9/30/1988 http://www.ak.ppco.com/transmi ttal/pri ntasp ?transno=3 83 9/29/2004 ) Attachments: Filename: None Received ByY::::==V~ h j J / Sign~~~. ./(fM~ Approver: Signature: http://www.ak.ppco.com/transmi ttal/pti n tasp ?transno=3 83 Filesize: N/ A Date: ¥~ cf Date: Page 2 of 2 Q/?QI?OO4. v ~ It VIC File Review Date: December 15,2003 Subject: CPAI KRU Well3H-09 PTD#: 187-112 403--303-371 Orders: AIO 2B ~"'Y'1~ Reviewers: Tom Maunder, P.E. Initiating Action: Application for Waiver to Continue Injection with Slight T x IA Communication Review Summary 1. This well was drilled in December 1987. 2. The surface hole was drilled with no reported problems. Difficulties were encountered attempting to run logs even with a wiper trip. The casing was run and cemented with no reported problems. There is no comment on cement to surface, which was not uncommon at the time. It is reported that a top job was performed. Again, this was not uncommon at the time and in some cases top jobs were performed regardless of getting cement to surface. 3. No difficulties were reported with the production hole section. Cores were obtained in the Kuparuk, the well was logged and 7" casing was successfully run and cemented. 4. There is no report of the well being Arctic Paked, although it is stated in the permit application that the OA would be after disposing of drilling waste. 5. In the completion report, it is reported that a 200-sx squeeze was performed through perforations at 8514' - 8515'. According to the formation depths given on the 407, this would between the two Kuparuk sands. Final injection rate is given as .25 bpm at 3000 psi. 6. It is reported that a CBL was run and it is noted "Good Bond". I have performed the MIT II spreadsheet calculation and examined the bond log. Sufficient cement was pumped. The bond log does look "good". 7. The well was fracture stimulated in January 1988. No problems were reported. 8. In September 1988, a 403 was submitted proposing to convert the well to water injection service. 9. There is a report of the initial witnessed MIT, 11/14/88. 10. A 404 is in the file reflecting a change to WAG service in November 2001. 11. A record of the witnessed MIT performed in June 2002 is in the file. THE MIT was successful. 12. CPAI reported possible TxIA communication on December 1,2003 with a request to perform diagnostics. This request was granted. 13. CP AI has performed the diagnostics, however the results are inconclusive as far as locating a leak. 14. In the sundry application, CP AI has proposed to keep the well in water only service, submit the monthly monitoring information and perform a MIT-IA every 2 years. Review Conclusions: 1. No problems were reported drilling any hole section or cementing any casing. It is not clear if the surface casing was cemented to surface. A top job was done, although that cannot be used to ç. '((-'t'À¡~'Rti.t . IJ:".::["""'" I:'.)!:" It'\) li)¡ l' ~no") ",,~~¿¡,\~t\~¡¡""!.;, tJ¡c:.~J <.i)) afJJ oJ 't ( determine whether or not cement was circulated. According to the cement spreadsheet, more than sufficient cement was pumped to get cement to surface. 2. A bond log was run in the 7" casing. TOe is evident at about 5100'. Based on the volume pumped, more than sufficient cement was pumped. I have reviewed the bond log and agree that integrity is indicated. 3. John Spaulding witnessed the most recent MIT performed in June 2002. The MIT was successful; 4. CP AI reported potential T x IA communication December 1, 2003 and proposed to keep the well in water service while performing diagnostics. Their request was granted. 5. CP AI has performed the diagnostics that have proven inconclusive. There is communication, however the leak rate is not large enough to precisely determine the location. 6. CPAI has proposed to add this well to the monthly monitoring list and perform a MIT-IA every 2 years. These are the standard conditions that have been applied to wells with small leaks. Recommendation 1. I recommend approval of CPAI' s request. ~ \ ( Con 0 cciPh ill i pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 11, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK. 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we1l3H-09 (PTD 1871120). The request regards continued injection with a failed MIT. Please call Nina Woods or MJ Loveland 659-7224, or me at 659-7043 if you have any questions. Sincerely, (-::~f?P[f ConocoPhillips Problem Well Supervisor Attachments RECEIVED DEC 11 Zoo] Allakl 'Oil & Gas Cons. COmn1ssíOIl AnchoJ age ( ( ( ,! I ;)-¡"s .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL O?::S ¡ z!¡?,ß 20 AAC 25.280 ~ \l/1,.7 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 187-112 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-1 03-20086-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' 3H-09 8. Property Designation: 10. Field/Pool(s): Kuparuk Unit Kuparuk 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): 7314' 6387' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115 SURF CASING 3424' 9-5/8" 3500' 3040 PROD CASING 7182' 7" 7258' 6331 /I tR ~ 0 1£ "1.. \()I LS f'e~;:on Depth MD (It): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6780-6 26,6957-6967,6978-6998, 5945-6000,6031-6041,6052-6072, ~. 7006, 7008-7030' 6074-6080, 6082-6104' 3-1/2" J-55 67241 Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BROWN pkr= 6652' SSSV= SSSV SSSV= 1807' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Immediately Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: 12/09/03 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Tom Maunder (email) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Woods 1 Loveland 659-7224 Printed Name derry Dethlefs 0 C2(¿;I Title: Problem Well Supervisor Date / ~A ¿;? ~ Signature ~.M C ---.. /". Phone 659-7043 /" U Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ....503..,3 71 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearanc~C E I ~ . VED Other: ~"Iç,:~, ~\\\ N\O~\-\...\'- ~~'\"\ 0 ~)\\'i~c..~,> ~~"\t.'">.'¡,~ 52003 ~ ~ "\ Së:Q c) ~ '- '\ Subsequent Form Required: (\O'('..x S\CA\~NE[) DEe 3 1 2003 Alaska Oil & Gas Cons. Commission Anchorage QE1~!~ A L Origins' Signed By BY ORDER OF 1'~ _\-/ ~~ Approved by: Sarah PaU,., THE COMMISSION Date: Form 10-403 Revised 2/2003. >'. ,"Ii>' . ',"~' SUBMIT IN DUPLI t:AT ," ,.".', ".. ~ ~lt'L DEC 17. ( (' ConocoPhillips Alaska, Inc. Kuparuk We1l3H-09 (PTD 1871120) SUNDRY NOTICE 10-403 VARIANCE REQUEST 12/11/03 The purpose of this Sundry Notice variance request is for approval to continue water-only injection with a failed MIT. DS 3H-09 is a WAG injection well that was reported to show signs of T x IA communication 11/29/03. The AOGCC was notified on 12/01/03 of this condition. Diagnostics verify that a small level of T x IA communication exists, but it is unknown at this time what the communication mechanism is. On 11/30/03 an MITIA passed @ 3000 psi. A subsequent drawdown test failed. A tubing plug was set on 12/08/03, and again the MITIA passed and draw down test failed. The tests were inconclusive as to whether there is a leak in the tubing or packer, and the leak rate was too small to measure. Packoff tests do not indicate a surface equipment problem. The following Action Plan is proposed to support the variance request for continued injection: ACTION PLAN 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform MIT-IA every 2-years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut-in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 12/11/03 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3H-09 12/08/03 £!gpatrick NA Packer Depth Pretest Initial 15 Min. 30 Min. Well 3H-09 Type Inj S T.V.D. 5728 Tubing 1500 2500 2400 2350 Interval 0 P.T.D. 1871120 Type Test P Test psi 1500 Casi ng 2450 2450 2450 2450 P/F P Notes: MIT-Tubing with tubing plug in hole Well 3H-09 Type Inj S TV.D. 5728 Tubing 2350 2050 1950 1850 Interval 0 P.T.D. 1871120 Type Test P Test psi 1500 Casing 2450 1000 1060 1100 P/F F Notes: Drawdown test on IA equal to 10% of starting pressure Well Type I nl TV.D. Tubing Interval P.TD. Type Test Test psi 1500 Casing P/F Notes: Well Type I nj T.V.D. Tubing Interval P.TD. Type Test Test psi 1500 Casing P/F Notes: Well Type I nj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: Diagnostics will continue to determine if TP was leaking and/or if there is a tubing leak or packer leak. TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting 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 Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3H-09 12-08-03.xls 12/11/2003 ( ~,( ~,. ConocoPhiUips Alaska, Inc. KRU 3H-O9 .. 3H-Ð9 API: 501032008600 Well Type: INJ Anale @ TS: 6 deç¡ @ 6869 SSSV SSSV Type: TRDP Orig 11/30/1987 Angle @ TD: 5 deg @ 7314 (1807-1808, Completion: 00:3.500) Annular Fluid: LastW/O: Rev Reason: Delete SSSV note Reference Log: Ref Log Date: Last Update: 2/7/2003 Last Taa: 7011 ELM TD: 7314 ftKB IŒ:" Last Taa Date: 9/30/2001 Max Hole Angle: 43 deç¡ @. 3000 Casino String . ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 .. SURF CASING 9.625 0 3500 3040 36.00 J-5S 1.-. PROD CASING 7.000 0 7258 6331 26.00 J-5S Tubina String. TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread "'.. 3.500 I 0 I 6724 I 5800 I 9.30 I J-55 I EUE 8RD AB MOD I~ Peñorations Summarv Interval TVD Zone Status Ft SPF Date Type Comment 6870 - 6926 5945 - 6000 C-4 C-3 56 12 5/12/1988 APERF 2 1/8" Eneriet; 60 deç¡ ph 6957 - 6967 6031 - 6041 A-3 10 12 5/12/1988 APERF 2 1/8" Eneriet; 60 deç¡ ph 6978 - 6998 6052 - 6072 A-2 20 6 1/11/2001 RPERF 2 1/8" Enerjet; 180 deg CCW f/highside III} 7000 - 7006 6074 - 6080 A-2 6 2 12/11/1981 IPERF 4" Densi Jet; 120 deg ph 7008 - 7010 6082 - 6084 A-2 2 3 1/10/2001 APERF 21/8" Enerjet; 90 deg CCW >...-...... :-""" f/hiç¡hside 7010 - 7016 6084 - 6090 A-1 6 8 1/10/2001 RPERF 21/8" Enerjet; 90 deg CCW f/hiç¡hside 7016 - 7028 6090 - 6102 A-1 12 6 1/10/2001 RPERF 21/8" Enerjet; 90 deg CCW I.r'..-.....:... f/hiç¡hside 7028 - 7030 6102 - 6104 A-1 2 3 1/5/2001 APERF 2 1/8" Enerjet; 90 deg CCW f/highside Gas Lift MandrelsNalves St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv I.~~'~.-'~ Mfr Type Run Cmnt 1 2475 2279 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 2 4334 3675 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 3 5295 4452 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 4 5695 4807 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 .~.._-_...:;,.. 5 6031 5122 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 6 6370 5450 Cameo KBUG DMY 1.0 BK 0.000 0 2/15/198 7 6594 5671 Otis LBX Merla DMY 1.5 T-2 0.000 0 2/22/198 Other ¡»Iuaseauip;,etc. .. JEWELRY : Depth TVD Type Description ID i 1807 1766 SSSV Otis Series' 1 0 2.813 PBR 6638 5714 PBR Baker 2.992 ' (6638-6639, i 6652 5728 PKR Brown 2.992 00:3.500) 6690 5766 NIP Cameo 'D' Nipple NO GO 2.750 6723 5799 SOS Cameo 2.992 6724 5800 TTL 2.992 PKR (6652-6653, 00:6.151) NIP I i LI (6690-6691, 00:3.500) TUBING (0-6724, I --- , 00:3.500, 10:2.992) - r-- Perf - r-- (6870-6926) - r-- - r-- = ~ Perf - ¡-- (6957-6967) - r-- - ¡-- - ¡-- Perf - ¡-- (7000-7006) - r-- - ~ Perf == (7008-7010) = Þ= - r-- - r-- Re: KRU 3H-09 (PTD 1871120), 2E-14 (PTD 1841970) . (- t Subject: Re: KRU 3H-09 (PTD 1871120), 2E-14 (PTD 1841970) From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Tue, 09 Dec 2003 13:42:15 -0900 , ", , T'1\.TPT)':"",T?-.'..",'"t,;,.I"'" . "'W,,.' ,'.'.""'1. ,.1' "','S', ','."<2...1£1'""@',",,, "'",',.".'.'.,."",,>'. ""L':l'l.~c ",,", ,.",,' .'~> ' ..l.Ö,:,lNC)~ri,OUem."""""e -",UP¥"ß; 'UI ""conocopl11 lps.com'".",.,.' CC: jim _regg@admin.state.ak.us Nina, I/we can answer a couple of your questions/points and have at least one of our own. 1. Keeping the well in water only service is appropriate. 2. MITIA on annual basis 3. No need to schedule a new test just for a witness. 4. Yes, add the well to the monthly list. 5. It would be appropriate to have the pressure information (MIT and drawdown test) on an excel sheet. Questions: How was the drawdown test conducted?? What was/did it.show?? Does CPA have a standard procedure?? T om Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom - Today, Slickline went out to perform an MITT and Drawdown test on KRU injector 3H-09 (PTD# 1871120). With a plug set in the tubing, an MITT to 2500 passed. The Drawdown test on the IA - passed. (It was within 10%) The detailed results are as followed: MITT to 2500 psi: Initial T/I/O = 2500/2450/120psi. 15 min reading, T/I/O = 2400/2450/120. 30 minute reading, T/I/O = 2350/2450/120psi. Drawdown test: Initial T/I/O = 2050/1000/120psi. 15 min reading, T/I/O = 1950/1060/120. 30 minute reading, T/I/O = 1850/1100/120psi. This injector appears to have a slow TxIA communication leak although it is 10f4 12/17/2003 1 :30 PM Re: KRU 3H-09 (PTD 1871120), 2E-14 (PTD 1841970) . - ~- ( able to pass both an MITT and an MITIA. Since the leak is probably too small to detect, my suggestion would be to Waiver for Water Injection only and monitor yearly or every 2 years with an MITIA. Would you like to schedule a State Witnessed MITIA to verify? Should this well be included with the Monthly failed MITIA report? Let me know if you have any problems with allowing continued injection and submitting an Internal Waiver for WI only. Thanks, Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Thomas Maunder '<tom maunder@admin. state. ak. us> 12/04/200308:26 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Jim Regg <jim regg@admin.state.ak.us> Subject: Re: KRU 3H-09 (PTD 1871120), 2E-14 (PTD 1841970) MJ, Sorry I didn't get back to you sooner on this. Yes, it is appropriate to add these wells to the list. What sort of diagnostic schedule do you propose?? Will it be possible to have any determinations by Dec 19 (-2 weeks)?? Tom Maunder, PE AOGCC 2 of4 12/17/2003 1 :30 PM Re: KRU 3H-09 (PTD 1871120), 2E-14 (PTD 1841970) ~ ' ( ( NSK Problem Well Supv wrote: Tom: 3H-09 (PTD # passed a MIT at 3000 psi, after the IA was bled off start diagnostics narrow 1871120) appears to have TxIA communication. It however, it also increase 250 psi in 30 minutes to 1000 psi during a build up test. Our plan is by setting a TTP and completing a draw down test to down whether the ANN COM is from the tubing or from the packer. Depending on the results we will most likely want to pursue a waiver/variance since it is unlikely that we would be able to pin point the communication without a much larger leak rate. to leave the well on-line until the diagnostics can be schedule. In the mean time we would like approval 2E-14 (PTD # 1841970) appears to have IAxOA communication, as well as known OAxOOA communication. This is one of the wells that we pumped a SealTite treatment on the surface casing in May 2003 to repair OAxConductor ANN COM. The treatment broke down and the OAxOOA ANN COM returned 11/29/03. We started an MITIA today for well integrity -diagnostics, however aborted it because the OA had to be continuously bled to avoid a surface breach out 3 of4 12/17/2003 1 :30 PM Re:J<RU 3H-09 (PTD 1871120), 2E-~4 (PTD 1841970) ( ( the OOA while the IA had pressure on it. The MIT may have passed had we given it time, but we felt it would be better to do diagnostics with a no spill contingency plan on site (vac truck). Initial T/I/O = 2500/200/0+, first PT 2500/1500/0+, 5 Min reading 2500/1460/0+, Second PT 2500/2050/0+, 5 min reading 2500/2000/0+, about 10 gal of diesel was bled from the OA during the 2000 psi test on the IA. Then bled IA back to 250 psi and OA fluid slowed down, but took additional 30 minutes to bleed to 0 psi. IA appears to have slight communication with GA. Final pressures; 2500/230/0. At this time we are going to SI the well and secure it with a TTP, after which pursue more IAxOA diagnostics. Please let me know if you would like the wells added to the Monthly Failed MIT report. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3H-09 11-30-03.xls) 4 of4 12/17/2003 1 :30 PM ',-, " MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor \.5)-;\ Chair ~<ryJ¡ SUBJECT: Mechanical Integrity Tests THRU: Tom Maun~er ' I Phillips Alaska Inc. P.I. Supervlso ~ \ ..-0) 3H \ \0 multiple FROM: John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL DATE: June 27,2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well 3H-02 Type Inj. N T.V.D. 5759 Tubing 750 700 700 700 Interval 4 P.T.D. 1871070 Type test P Test psi 1440 Casing 1225 2100 2075 2075 P/F P Notes: Well is currently shut in Well 3H-06 Type Inj. G T.V.D. 5795 Tubing 1450 1350 1350 1350 Interval 4 P.T.D. 1870780 Type test P Test psi 1449 Casing 1025 2050 2050 2025 P/F P Notes: Well 3H-07 Type Inj. G T.V.D. 5790 Tubing 3150 3150 3150 3150 Interval 4 P.T.D. 1870790 Type test P Test psi 1448 Casing 2350 1950 1950 1950 P/F P Notes: Draw down was performed versus pressure build up Well 3H-09 Type Inj. G T.V.D. 5728 Tubing 3600 3600 3600 3600 Interval 4 P.T.D. 1871120 Type test P Test psi 1432 Casing 2125 2750 2750 2750 P/F P Notes: Well 3H-12 Type Inj. G T.V.D. 5878 Tubing 3700 3700 3700 3700 Interval 4 P.T.D. 1871290 Type test P Test psi 1470 Casing 2850 3300 3300 3275 P/F P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test T est's Details Page 1 of 3 Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) M.I.To's performed: § Attachments: none Number of Failures: Q Total Time during tests: 3 hrs. cc: none MIT report form 5/12/00 loG. m it( 1) kru 3h 6-27 -02js.xls 7/16/2002 " ,.,...- »,,- -", I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.9p~r~~§r~pØ:rf()iXr)~i) .... ...,.. )R~~w.tlAr:~~~!9~~A:,.,. :::?"ffflW~t~>: , ".R41HlJbi1iØU.....'..'..".'" .:::AltMç~$1@¿' 5. Type of Well: ---, , -- - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface Development - Exploratory - Stratigraphic - Service X 1344' FNL, 4997' FEL, Sec. 12, T12N, R8E , UM At top of productive interval 1447' FSL, 1690' FWL, Sec. 12, T12N, R8E, UM At effective depth (asp's 498655, 6000310) At total depth 3846' FNL, 3553' FEL, Sec. 12, T12N, R8E , UM 12. Present well condition summary Total depth: measured true vertical (asp's 500100, 5997809) 7314 feet 6387 feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing CONDUCTOR SURF CASING PROD CASING Length 115' 3424' 7182' Size 16" Cemented 225 sxAS II 9-5/8" 1200 sx AS III & 400 sx Class G, 1 300 sx Class G & 200 sx AS I 7" P)~n~WP~r1or~t~,-, , ,:." . .:, .: ..:, . . .':R~þåitWeJL .. .,()the(:..x.WltòWAGlhjø~tiön,: 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-09 9. Permit number / approval number 187-112/ 10. API number 50-103-20086 11. Field I Pool Kuparuk Oil Pool Measured Depth 115' 3500' 7258' True vertical Depth 115' 3040' 6331' Perforation depth: measu red :681Q;.6926'695t.6967;6918~6998;iöÖQ;.1006;.7Ò()8~101Ö;' : ."lÓjbH:()16¡7()16;'7()¿~¡7Ó28.7()3()'.::"'::::":':':" .':. :... :.:...:.':.:..., RECEIVED , " ,-- true v e rticat~Q4$~~P9;~q~i~~()# 1;~p 5~~~qt.?; .~974~?()~9;~d~2H 60~4. . §o'8f-69fjþ;§D@i6JP4; 51Q?mtP4. .': " Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. : . ÅlalkåOH & Gas ConS. Commission AnctKrage Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - - - --- - , - - - - ' , , - - , , . ' , Daily Report of Well Operations _XPH.--~a.s~$Üsp'el1(ied~ ServÎce~)(WAG njection.. . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed fÎ ~. ,¡ c. ~ Tí~e~~U: Êng~~~ ~ Date /~ ¿"..ð /.. ,.- Jeff A. spen¿ -c Prepared by Robert Christensen 659-7535 OR \ G\ NAL Form 10-404 Rev 06/15/88. ØI6f)~5 3 ì\Ir'\ I n r. ",.' (,. SUBMIT IN DUPLICATE .. -- -~~, f 3H-O9 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11n1O1 Commenced EaR InJection ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Pull tubing - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 9951 0-(}36 0 4. Location of well at surface 1347' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1447' FSL, 1690' FWL, Sec.12, T12N, R8E, UM At effective depth At total depth 1431' FSL, 1726' FWL, Sec.12, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURF CASING Length 115' 3424' Size 16" 9-5/8" PROD CASING 7182' 7" Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Stimulate - Alter casing- 5. Type of Well: Development - Exploratory - Stratigraphic- Service X (asp's 498654, 6000313) (asp's 500064, 5997826) (asp's 500100,5997810) 7314 feet 6387 feet Plugs (measured) 7030 feet 6104 feet Junk (measured) Plugging - Perforate _X Repair well- Other - 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-09i 9. Permit number / approval number 187-112 10. API number 50-103-20086 11. Field / Pool Kuparuk Oil Pool Tagged PBTD (1/10/00) @ 7030' MD. Cemented Measured Depth True vertical Depth 225 SxAS I 115' 115' 1200 Sx AS 111,400 Sx 3500' 3040' CI G, & 85 Sx AS I 300 Sx CI G & 200 AS I 7258' 6331' Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations X Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVE-r' 6870 - 6926'; 6957 - 6967'; 6978 - 6998'; 7000 - 7006'; 7008 - 7030' i) APR 09 2001 5945 - 6000'; 6031 - 6041 '; 6052 - 6072'; 6074 - 6080';Æ082 - 6104' laska Oil & Gas COilS. LOinn'lr.(::¡, í 3-1/2",9.3#, J-55 Tbg @ 6724' MD. Anchorage '~.",J Brown Packer @ 6652' MD. Otis Series '10' @ 1807' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Signed Form 10-404 Rev 06/15/88. 16. Status of well classification as: Title: Casing Pressure Tubing Pressure 2016 1984 5003 5103 Suspended Service (Water Inj) Date 1!3!P) Prepared by Jotin Peirce 265-6471 SUBMIT IN DUPLICATE ... /-, 3H-O9i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/4/01 : RIH & tagged Fill @ 7044' MD. 1/5/01 : MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Reperforated: 7010 - 7016' MD Added perforations: 7016 - 7030' MD Used 2-1/8" carriers & shot the perfs at 3 spf at zero degree phasing. POOH w/guns. Rigged down. 1n/01 : MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Reperforated: 7010- 7030' MD Used 2-1/8" carriers & shot the perfs at 3 spf at zero degree phasing. POOH w/guns. Rigged down. 1/10/01 : MIRU & PT equipment. RIH w/perforating guns & tagged PBTD at 7030' MD. PU & shot 40' of perforations as follows: Added perforations: 6978 - 6998' M D 7008 - 7010' MD Reperforated: 7010 - 7028' MD Used 2-1/8" carriers & shot the perfs at 3 spf at zero degree phasing. POOH w/guns. Rigged down. 1/11/01 : MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations as follows: Reperforated: 6978 - 6998' MD Used 2-1/8" carriers & shot the perfs at 3 spf. POOH w/guns. Rigged down. Returned the well to Water injection and obtained a valid injection rate. --~ ARCa Alaska, Inc. ' Post Office i.... ~ .()0360 Anchorage, Alaska 99510 Telephone 907 276 1215 S~IPLE TRANS~IITTAL ---,- band-carried ~~ ~~ . . . SHIPPED TO: State of Alaska . DATE: . . ., O).1r-'\& Gas Cc;>nservation Commission \' '1 \~. {) ,13 pOll! Porcup1ne Dr ." f\. . . Anchorage, Ak. 99501 Attn: John Boyle APPR.DVED OPERATOR: .' ARCO . NMIE: see below SAHPLE TYPE: core Chip~- .' ---:--;-: '~')Nu¡.Ji¡ER OF BOXES: ~I:~SENt- / ~ ) '.". . I I . ",:,;../ ,..~' ~'J'~ Bay.iew Facility Coordinator OF THESE S~IPLES, PLEASE~OTE ANY DISCREPANCIES AND ~~IL A SIGNED FORN TO: ----- . .',.' '~ .! . ~..;...- I' :j',- ..1- '-. .j, :: ----- "'", , .' '-~;~'" ,i", , KRU JH:-g~-9 boxe:~ \. ~,,:--~ . 6868 - 6908 \ ;. -:. ' ,r 6911 - 6958 . " ;'. 6971 - 7llGQ .-, ) I .. . ---------' - --------------"'-~----'----- \ ,; , - ,. , , . , " SHIPPED BY: UPON RECEIPT COpy' OF THIS A p. 11 H 0 V E Ð ARCO ALAS~~, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab, '. ABV /l...C 0 , ARca Alaska, Inc. Is a SubsIdiary of AtlanllcRlchlleldCompany 5-12-88 ~.' '\ APPRO ... .-. f '--. ARCO Alaska, (. Post OW~...iBVA i 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 "'- - ~~ ~~ I> August 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys Spinner Documentation In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting the sepia reproductions of the spinner documentation for the injectivity surveys for Kuparuk water injection wells for the Second Quarter, 1989. ( If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, 7Þ11k~ Þ¿¡ ;/.~: M. H. Kraly Operations Engineer MHK:LLP Attach ment ) ~ ARCO Alaska, Inc. is a Subsidiary 01 AtlanticRichfieldCompany ,¡ ARGO Alaska, 1. ~. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 -~ --,~-~ ~~ ~~ August 16, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys Spinner Documentation In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting the spinner documentation for the injectivity surveys for Kuparuk water injection wells for the Second Quarter, 1989. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, 1Jt;! tr~ /~ . M. H. Kraly Operations Engineer MHK:LLP ~...; ,1"'8 pB ~ . "'",~.',,,"',"~ '~;""¡;,,.:. '~, r:'~,~ ~ ",~,.;: 'rt' .,' ¡'", -...; :!J"{¡. 'If'- ""\"'"> ~"'~,~1ri;{! 1 ;1,,'-)~;"t ..... ", "'} '.. : "",,1,-;:; G it c (.~"", f. (' ' . ",;')!\U. .S t~ ,¡os¡,nr!s. ,omm;:'" Anchorage Attach ment ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany DATe- i f) \ A' - ~ . f'1A.M~ - I<.J.J~ - Ii ~ ~V Ò. J- BI \/£ LI~t; . kr{lJ 3H- 9 - S-..-.J 7- ~q ANa 1- se?:r:~ I CONc,fG~rJ-rtJ(., ""H~ k ~¡) J '( - ~ {, - 3 -<ff ;::'0/ /ovJzf'/(r wELLS # G~J ----------------- - --_. --- k RW_- -- 1'( ~--~---_._.__.- ---- 6- ~ _-:J'9 --------------- -- -.--.--- - - ___m--- kRU 3 /-I-l_~ ----- --.--. .-- 6 - JS- --~ 1 ---------------... ------k~U - .~w-:J-._._. __n - b-/ð'-ð"J ------- - - - ~ ~ Ù J G~ I? 5 -I 7 -? 7 . kRtJ ~?:-lø 6 -~-/?~ --.-.---------------------------- -k RL..1.. ---~ e-.....~ -- ---- - 6 - I-~ 1 -----'--____n_'-__----- k \;ù- ~ c-_S- ~ -..¡ -89 --.---.--------nu_-.---------------kRù_--j-r--æ-------------~----7-31-~3 -- -n.- _. --- d__- '----------"----'- --.--- k ~ Ù ---._.___1 . '( ~_l ~--_._-----_.._-- ----- ~~- .!J_=-~-~ ..----------------. ---- -- -- ---- -_.._--_._------------------_._----~.~.Ù._____--_I_'f~.\S----- ,< . d. e~/l--~?__._-- . _.... - . - -------------..----------.--_____kR¿). ." .~)(.- ~. . S -10 -e L ----------------- - ._-----.._------_..--------._----.. ___h______--- - ø -------- ------__----__n- - -.----.--------------,..-..--- -k \< 1)._---- I r ---_.g---- ... ----u -- - ~ ~.l_-:-~ ~. -- -- - -- --. 'ì, --------_...__._----_...._---~w -.-- -- -_\y--:t~___n.___n____.~ --lP -~~ .------ --- . - -- d - ---- '_'____n_- _.._--_.-----~--------------_._------kR u_.._._._f_'(~_'_.s_--__------------_. q~={.§_:-~~ ------.. ------ ,.d- -. .- --..----------------- .. --'_.------.---------------.------- _ok 'Ru d__- d_~_.J '(- :J... ----_u_----- .CJ"":'" r2.3......~~--- ___--d --- -- - - - - --- ._- ----------------_.-._--, ----------.._____kRt.J----.____--1 A~/I___"__---------_'__'d6 ~-_1~n~9..._--- -....- -- ..._----- .. - ---'- -----------------------.-.------------..--1< R ù..._-- ._-_.l~:-_~..__.- -. .d____S"" - JC .--~7 -...- --..- ---- - - .--- - . --. . - . _d_' dn - -. _.- . --------------_.._-- --.-------.-- -'< R t.J - . - - ~ w - 9 _Wd_- - - - ~ - ~ 0 -~ c¡ . kRLJ Qf2-ltf (p- 3- ~1 -"------------'----"-'--_d_-_._----..=--kRL.J___.<~...?-- . _n- ~ -g/~ ~'1 ---n_____-- .----- _~___d- _k R u. .. ---- E H-I S-- - -- - S -~()-(? 9 _...kRu- . :<c -_to ~-13 -rrr . - - --- n______--___--nk~Ù_.__.J H-17___S"" - l.. t:t- J? <1 . -- kRÙ .:2C - ~ ~-I'1-rP? - "------------ I" ~LJ --:;. O-l'-f ~ -~3-~9 J(f{U 3H'- ~ 5-~ t¡-~? K~JJ ~:¿,:"';II {¡'-'-f? k~LJ ffl- 7 S-~-~9 kRLJ J 1'-1 (P-?-~? k~J.J ~t;J -s- CD -/7- ~9 11- ..,~ /" --- ! . - 8-J.Y-'l9 -- ,~ c:i e~ (j- A oc,-c.c.....- ( _.- ----- - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown - Pull tubing - Alter casing - Repair 2. Name of Operator AR 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1347' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1447' FSL, 1690' FWL, Sec. 12, T12N, R8E, UM At effective depth 1437' FSL, 1714' FWL, Sec. 12, T12N, R8E, UM At total depth 1431' FSL, 1726' FWL, Sec. 12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 731 0' true vertical 6382' Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7168' true vertical 6241' Length Size 80' 16" 3420' 9 5/8" 7225' 7" ()...; -1 f~, Stimulate - Plugging - Perforate - Convert well ;tl well - Pull tubing - Other.lL to WI 5. Type of Well: 6. Datum elevation (DF or KB) Development - Exploratory Stratigraphic - Service X W I K 7. Unit or Property name Kuparuk River Unit 8. Well number feet feet teet 9. Permit number/approval number - 2 10. API number 1 -2 11. Field/Pool Kuparuk River Field Ku aruk River Oil Pool REcrl\ff~-R"'" . (iv, ~ ~i t'.'" .~..; "" i!i tf g..." L)1 Plugs (measured) Cement: 7168'-7310' feet feet lì!1J~p 1 "> íQ,;Q Junk (measured) , . None Alaska OiJ & Gas Cons C. '" --.j .. . . ' a omrmSSlfm Measured depth "'~'"TÆneCQßmggl depth Cemented 225 Sx AS I 1 1 5' 1 1 5 ' 1200 Sx AS III & 3500' 304 0 ' 400 Sx Class "G" Top Job w/85 Sx AS I 300 Sx Class G 7260' 6333' 200 Sx AS I measured 6870'-6926', 6957'-6967' 7000'-7006', 7010'-7016' true vertical 5944'-6000',6031'-6041',6074'-6080',6084'-6090' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55, set at 6724' Packers and SSSV (type and measured depth) Baker FHL Packer @ 6652', Otis Series 10 SSSV @ 1807' 13. Stimulation or cement squeeze summary 12 SPF 60 degree phasing 2SPF 120 degree phasing Intervals treated (measured) Treatment description including volumes used and final pressure Well was converted from oil producer to water injector. Procedure and MIT record are attached. 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 2930 3700 0 0 0 -11770 16. Status of well classification as: 500 psi 450 si 190 psi 1950 si Service Water Injector Prior to well operation Subse uent to aeration 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. {).'\ 1 . ' ~ Aj ì" {) ~~)!~".. ~ L /\/1 Date ¡VeL,. ~, 'I r ,. .,ARCO Alaska, In~ <> ... Subsidiary of Atlantic Richfield Comp WELL SERVICE REPOF WELL paCT DAYS / DATE //-/y- 88 3 CONTRACTOR . A C- REMARKS ~¿é~(1 (;1"1"' (;Þ6" 896B9B , .. føJr €j¡; : :r ~ 0 £1.1 AI ~/.r: /5"2ð .... ~/,r'V /!¡tJc ~l-J~~ VA) '" /530 R "'~ N./. /. 4-',. r",JI'.r.rt' Þ jy c. ~ . ):>.'4f'S' A.:Þ. ~~..J' ¿.AI'? ./rÂ~ 4"t: ,4'AS,lé";, /600 PA././t.trÞ #/:r. R.J> A'Pc JZ~ ,¿J UJr R-fft111n) MAf?--:L ? J ::: !' ') ij!J$ka .Oil & Gas Cons' C ." """,(. . , a omrmsswn ""'I, Aooherage 0 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility i Wind Vel. Signed Report of OF miles I knots Ç, 6'" , REMARKS CONTINUED: --- --- --- --- ---- --. h- - - - -- ---------.. -----_u- -- -- ------- -------- -..--.--.--------- ------ - ---- ---- --__Uh -- --------- -------- --.---- - ---- - --- ~1 DESCRIPTION DAILY ACCUM. " TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-A TLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision -- - -- I i I I I i I I I I I I I I I i I I ! 30 ~ -- -- A Pc PuAA:iD Pre-Job Safety Meeting AFE 996 888 U¿A.J I ï 2 ?ó .- - TOTAL FIELD ESTIMATE ~ .320 __h. ; Signed I 6-, £" . ])0'- é J" /-" ARCO Alaska, Inc. Date: December 15, 1988 RETIJRN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~~ ~~ -'- Transmittal #: 7375 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. . 3H-14 -3H-15 .3H-17 e3M-19 .3H-06 .3H-09 .3H-21 .3K-06 ~3H-21 .1Y-06 . 30-07 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report BHP Report Receipt Acknowledged: --------------------------- ~ f' State of Alaska D&M Unocal 12-10-88 12-09-88 12-09-88 12-09-88 12-08-88 12-13-88 12-13-88 12-12-88 12-12-88 12-12-88 11-27-88 SAPC Date: Chevron Casing Tubing Casing Casing Tubing Casing Casing Casing Casing Casing . ,r"'.,' ::¡'!¡./:~f\. .' ,I ~ ¡ . /..¡ - , ~, Del 1988 Alaska Oil & G~C' C"...... C"mm' , ......... , jo". ~ ISSlon Ancrwraga ------------ Mobil ST A TE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS cu. -'!~ .IA{ Pé ð3 Abandon - Suspend - Operation Shutdown - Re-enter suspended well - Alter casing - Repair w.el~ - Plugging - Time extension - Stimulate- Change approved program Pull tubing Variance Perforate Other X 5. Type of Well: 6. Datum elevation (DF or KB) Development II Exploratory Stratigraphic Service eet 1. Type of Request: 2. Name of Operator AR 3. Address P, 0, Box 100360, Anchorage, AK 99510 4. Location of well at surface 1347' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1447' FSL, 1690' FWL, Sec. 12, T12N, R8E, UM At effective depth 1437' FSL, 1714' FWL, Sec,12, T12N, R8E, UM At total depth 1431' FSL, 1726' FWL, See, 12, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number 10. AP I number -1 -2 11. Field/Pool Kuparuk River Field Ku aruk River Oil Pool Effective depth: measured true vertical 7310' 6382' 7168' 6241 ' feet Junk (measured) feet None feet Plugs (measured) feet Cement: 7168'-7310' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 3420' 1 6" 9 5/8" 225 Sx AS I 1 1 5 ' 1200 Sx AS III & 3500' 400 Sx Class G Top Job w/85 Sx AS I 300 Sx Class G & 7260' 200 Sx AS I 11 5' 3040' 7225' 7" 6333' measured 6870'-6926', 6957'-6967' 7000'- 7006', 7010'-7016' true vertical -,-, ," ~-' 5944'-6000', 6031 '-6041', 6074'-6080', 6084'-6090' TVD-~ "-'-- Tubing (size, grade, and measured depth 3 1/2", J-55, set at 6724' Packers and SSSV (type and measured depth) Baker FH L Packer @ 6652', Otis Series 10 SSSV 1807' 13. Attachments Description summary of proposal - Detailed operation program .2l Convert well from oil roducer to water in'ector. Wellbore schematic attached, 14. Estimated date for commencing operation 15. Status of well classification as: m r 1 Oil - Gas - Suspended - 16. If proposal was verbally approved 12 SPF 2 SPF -' 60 degree phasing ..- , 4 .,~'- 120 degree phasing' ,~, , .< .",.. ' - - .. BOP sketch - Date approved Service Water s true and correct to the best of my knowledge. Title 5". <1:». Ch¡-. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test - Location clearance - Mechanical Integrity Test x, Subsequent form require 1 O-~(p ORIGINAL SIGNED BY Approved b the order of the Commissioner Form 10-403 Rev 06/15/88 Injector Date Approval ~o. -, '~;/ i, I L) - ,';-'" K- Commissioner Date 1- 7- 7- -S B SUBMIT IN TRIPLICATE r¡ ...;,pproved Copy 1 Re~r!1e~d(~, 9 - ~?\<,3 3¿ - Well 3H-09 Conversion to Water Injection 1. The proposed procedure is attached. 2. No BOPE will be necessary to convert the well to water injection service. 3. The static bottomhole pressure will be acquired by taking a WHP/FL prior to the well's conversion. The reservoir pressure is estimated to be 2300 psi based on the producing GOR. 4. No workover fluid will be used. , , . ; " -..... ",,"', ~ ' ~ '-" Ii... ~~, ,) ... , 1 . 2. 3. 4. 5. 6. .- ~, 3H WA TERFLOOD CONVERSIONS GENERAL PROCEDURE Obtain final 12 hour well test. Check to insure that the sundry notice for converting the well to water injection has been approved by the State (Erin: ext. 6523). SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2" meter runs, and calibrate instrumentation. Notify the State of the upcoming Mechanical Integrity Test. After 72 hour shut in, contact Engineering (ext. 7525) to record wellhead pressure and shoot tubing fluid level. Conduct MIT. Packer depths and required 7" annular pressures are shown in the table below. Bleed the annulus to 500 psi after completing the test. Send a copy of the WSR and the State's MIT form to S. Twiggs at ATO 1130. WELL ~ 3J::lJl.9 3Ji:..1.2 3l:L:..2.2 DEPTH (TVD) OF PACKER 5789' 5727' 5877' 5950' REQUIRED CSG PRESSURE 2084 2062 211 5 2142 FOR MIT (PSI) The targeted injection rates and estimated set pressures are summarized below. After the initial trial, modify the injection set pressure to more closely match the desired rates (+/- 500 BPD is fine). WELL ~ 3J::lJl.9 3Ji:..1.2 3l:L:..2.2 DESIRED INITIAL INJECTION RATE 5000 7000 5000 3000 (BWPD) ESTI MATED SET PRESSURE (PSI) 1200 1200 1500 1500 The above set pressures and rates will apply only until the STP begins winter time operation. Then the injection rates will be increased. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company ,"'-' ::: ¿~ ';'" j ~ 0.- - AR3B-6001-A <, "'- ~ 'ilf WELL 3H-O9 SURFACE LOCATION:1347'FNL, 281'FWL, SEC 12, T12N, R8E, UM TREE: FMC 3-1/8" 5000 PSI API #: 5010320086 DEPTHS: REFERENCED TO 0' RKB REVISION: 9/9/88 TUBING SPOOL ELEV: 31' RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3500' PBR: BAKER 2.992" 10 PKR: BAKER FHL 2.992" 10 @ 6652' NOGO: CAMCO '0' NIPPLE 2.75" 10 @ 6690' SHEAR OUT: 2.937" 10 @ 6723' @ 6638' c B A3 A2 A1 7": 26# J-55 @ 7258' ~ 5/4/88 ,"""""""""""""""'" ......................."......... """,,""""""""""""" "",,"""""""""""""" . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ........---""...."" .......... l . . . . . . . . SSSV: OTIS SERIES 10 10 2.813" @ 1807' GLM1: 2475' / 1.0" GLM2: 4334' / 1.0" GLM3: 5295' / 1.0" GLM4: 5695' / 1.0" GLM5: 6031' / 1.0" GLM6: GLM7: 6370' / 1.0" 6594' / 1.5" MAX HOLE ANGLE = 42° AT 3000' MO IS' SHAPED WELL BORE 3.5" 9.2# J-55 BTC ABMOO IPC TUBING TAIL @ 6724' HOLE ANGLE ACROSS KUP ARUK = 5° 6870' 6926' 12 SPF 12 SPF 6957' 6967' 7000' 2 SPF 7006' 7010' 2 SPF 7016' FILL @ 7042' (26' RATHOLE) PBTO: 7168' /~ -. ARCO Alaska, Inc. ~ August 8,1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission SUBJECT: 3H-9 Core Description Dear Mr. Chatterton: Enc 1 osed is a copy of the 3H-9 Core Descri pt i on to i nc 1 ude wi th the Well Completion Report. If you have any questions, please call me at 263-4944. Sincere ly , j~ ~/)UI- J. Gruber Associate Engineer JG:hf Enclosures cc: 3H-9 Well File GRU14/020f RECE\VED J\UG lJ 198ß Alaska Oil & Gas Cons. Commission Anchorage CO 1\1"3';8., ,n': - ,\; i;' ~-...~ "" ~ -1 ð<, I/J( /lfG ," " ARCO ALASKA, INC. CORE DESCRIPTION CORE #1 6868'-6911 ' CORE #2 6911 '-6921.5' 6921.5'-6948' CORE #3 6948'-6971 ' 6971'-7031' CORE#4 7031'-7055' 7055'-7058.6 ...-- - KRU 3H-09 SEC. 12, T12N, R8E, UMIAT Sandstone, medium grey, fine to coarse, pebbly near top and of interval. Bioturbated, glauconitic, friable and oil-stained where not cemented. Locally hard and sideritic, some vertical fractures. Sandstone, medium grey, very fine to coarse, pebbly at base of interval. Bioturbated, glauconitic, friable and oil-stained where not cemented. Locally hard and sideritic, some vertical fractures. Shale, dark grey, silty, thinly laminated, very hard, some siderite cemented zones. Interbedded very fine-grained sandstone, siltstone and shale. Sandstone oil stained. Siltstone and shale medium to dark grey. Lenticular to wavy bedding. Sandstone quartzose with fair to good porosity; well indurated. Interbedded very fine-grained sandstone, siltstone and shale. Sandstone oil stained. Siltstone and shale medium to dark grey. Lenticular to wavy bedding. Sandstone quartzose with fair to good porosity; well indurated. Wavy and lenticular bedded, very fine-grained sandstone interbedded with siltstone and shale, medium to dark grey. Shale, dark grey to black, firm to very hard, thin lenses of siltstone. RECEiVED AUG 1 u 198ß Alaska on & Gas Cons. Commission A'" hOrri(j-C' . I \t~ - !. L ~C1 '.' ""'~ ",. /r_, ... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ::::(~ WELL COMPLETION OR RECOMPLETION REPORT AND LOQ'.~ ! 1. Status of Well Classification of Service Well ~-.a - ~ OIL II GAS D SUSPENDED D ABANDONED D SERVICE D ) ~- A)( 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-112 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 103-20086 4. Location of well at surface 9. Unit or Lease Name 1347' FNL, 281' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1447' FSL, 1690' FWL, Sec. 1 2, T12N, R8E, UM 3H-9 At Total Depth 11. Field and Pool 1431' FSL, 1726' FWL, Sec.12, T1 2N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool RKB 76' ADL 25531 ALK 2657 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/18/87 11/27/87 01/15/88* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7310'MD, 6382'TVD 7168'MD, 6241'TVD YES XJ NO D 1807 feet M Ò"--"---L 1600' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/LSS, DIL/SP/GR/SFL, FDC/CNL, FMS, RFT, CBL, Gyro, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 225 sx AS I 9-5/8" 36.0# J-55 Surf 3500' 12-1/4" 1200 sx AS III & 400 sx Class G Top job w/85 sx AS I 7" 26.0# J-55 Surf 7260' 8-1/2" 300 sx Class G & 200 s ~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 0° phasing / 3-1/2" 6724' 6652' .?- 6870'-6926'MD 5944'-6000'TVD 6957'-6967'MD 6031'-6041 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perforated w/2 spf, 1200 phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7000'-7006'MD 6074'-6080'TVD See Addendum attache d to Well Comoletion 7010'-7016'MD 6084' -6090 'TVD report. dated 2 /1/88. for fracture data. 27. N/ A PRODUCTION TEST Date First Production Method of Operation (F lowi ng, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD. Flow Tubing Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOUR RATE. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. t. D Core description to be submitted when received. ,t C t. \ \I ~" ,.< 2. ... \(' '.'\ j\r" '., .,,'.' \';. , l'Of\\\{\\Ss\on as conS. \J ' . ~o\\&.G ~ *Note: Drilled RR 11/30/87. Perforated well & ran tubing 12/12/87. Worko.;A\aSpeJìt..9;r:m\&iC~~1, /87. Fractured well 1/15/88. Perforations added 5/13/88. . Form 10-407 Rev. 7-1-80 WC4/63:DANI CONTINUED ON REVERSE SIDE Subm;t;n dUPI;ca~ 29. »- ( .. 30. GEOLOGIC MARKERS FORMATION TESTS .. NAME MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A Hydro. Shut-in 6870' 5944' Depth Press. Press. 6928' 6002' 6879.0' 3134 psi 2870 psi 6949' 6023' 6884.51 31 09 psi 2870 psi 7062' 6135' 6879.1' 3100 psi 2869 psi 6896.5' 3111 psi 2872 psi 6908.6' 3114 psi 2876 psi 6916.5' 3120 psi 2897 psi 6918.5' 3112 psi 2918 psi 6964.0' 3142 psi 2971 psi 6966.0' 3143 psi 2972 psi 6979.9' 3148 psi 2977 psi 6985.5' 3155 psi 2980 psi 7003.4' 3161 psi 3034 psi 7014.0' 3166 psi 3044 ps i 7026.9' 3174 psi 3045 psi 31. LIST OF ATTACHMENTS Signed TitleAssoci ate Engi neer Date &-/4 -88 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: I ndicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~ "'" > WELL : 5/12/88 thru 5/13/88 3H-9 ADDENDUM -------- ,-- RU Otis, make 2.70" GR rn & tag fill @ 7042'. Original PßID @ 7154'. RU Gearhart. Tst lubr to 3500 psi. Make 6 perf t1ms @ 4 SPF. Perf A-3 sand 6967' -6957' & "C" Sand @ 6926'-6906',6906'-6870'. Each interval perf'd 12 SPF w/-300 & +30° and 0° phasing. Release well to Production. Q Ðo~ ~ \) ~C\. \\J \. \> ',\'- - .',' ; '. I} \r;,'. ~ \.)(, r...- t' Q\\\'(\\\~s\Q\\ '3.5 (',O\\S. v ,- , 0\\ &. G ~().<1~ 1\\~$\~~:\Jà~\,.\t.\\(j\\U .. ~~~/ !if{ SHIPP~P TO: ,~ ;; ;, :; . ,-------- ,~- ARCO Alaska, Inc. Post Office B, - 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 hand-carried ~~ ~~ SANPLE TPA~SÌ\IITTAL State of Alaska Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE: Commission 5-12-88 NMIE : see below OPERATOR: " ARca S¡\NP LE TYP E : SAMPLES SENT: Lisb L5-21: 11 boxes 12088/89 - 12133/34 12123 - 12144 12145/46 - 12149/50 12151/52 - 12198/99 12151/52 - 12198/99 12200/01 - 12223/24 12230/31 - 12288/89 12290/91 - 12371/72 12373/74 - 12390/91 12396/97 - 12406/07 12422/23 - 12425/26 12435/36 - 12445/46 12449/50 - 12463/64 12467/68 - 12471/72 12473/74 -" 12581/81.5 12482/83 - 12490/91 12492/93 - 12510/11 12520/21 - 12614/15 SHIPPED BY: UPON RECEIPT COPY'OF THIS Nill-1BER OF BOXES: 63 core chips, plug ends .. "" KRU 2T-9; 1 box KRU 3J-9: 12 boxes ~r:;S'<? oS- 2150.8 - 2258.05 6320 - 6393 T2250 & 2315 are 6395- 6436 preserved - no 6438 - 6453 samples are available)6459.- 6503 6507 - 6545 6548 - 6570 . KRU 3M-9: 5 boxes 6531 - 6577.0 6579 - 6618 6637 - 6650 "KRU 3M-16: 7 boxes KRU .3H"r,9,:< 9.oQxes 7580 - 7614 7617 - 7690 " 6868 - 6908 6911 - 6958 6971 - 7058 KRU 3H-11: 2 boxes KRU 3K-9: 16 boxes 3365.2 - 3501.3 6967 - 7009 7027 - 7060 7060 - 7099 7102 - .7174 7199 - 7243. 3941 - 3954 3970 -"3974 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 4061 - 4081 --~ ,~ ~. ~ Bayview Facility Coordinator" OF THESE S~1PLES, PLEASE~OTE ~~Y DISCREPANCIES AND ~~IL A SIGNED FORM TO: ARCO ALASK~, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 9'9510 ATTN: Paleo Lab. '. ABV/ 0 ."# .Þ ARca Alaska. Inc. is a Subsidiary of AtlantlcRlchfieldCompany ---'. ---~ Date: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1988 TransmittalU: 7094 ~~ ~~ RETURN TO: , ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-8 Kuparuk Well Pressure Report(Otis) 12-23-88 Static IG-16 Kuparuk Well Pressure Report(Otis) 2-8-88 Static 'c' Sand r 'e Data Frac Pressures 1-15-88 BHP Data Worksheet 1-3-88 1194225 3A-15 Kuparuk Well Pressure Report(Otis) 1-15-88 Static 'A' Sand 3A-15 Kuparuk Well Pressure Report(Otis) 1-15-88 Static 'c' Sand DISTRIBUTION: , Da t e :. Cg1J'{f.\(~:~. - :. . t'-';'SCJ~15. -~\(a ûi\ c.:. ~": ( \"~~a<de . .,-- ¡',.'" HAPPy VALENTINE'S DAY Receipt Acknowledged: D & M State of Alaska Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a SubsidIary of AllanticRichfieldCompany ..-... . '. STATE OF ALASKA -- rI~ / ~ ALASKA OIL AND GAS CONSERVATION Cv,'lÌMISSION ~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG ! ~ \J p) 1. Status of Well Classification of Service Well (S OIL lX GAS D SUSPENDED D ABANDONED D SERVICE D )k 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-112 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 103-20086 4. Location of well at surface 9. Unit or Lease Name 1347' FNL, 281' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1447' FSL, 1690' FWL, Sec. 1 2, T12N, R8E, UM 3H-9 At Total Depth 11. Field and Pool 1431' FSL, 1726' FWL, Sec.12, T12N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Pool RKB 76' ADL 25531 ALK 2657 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/18/87 11/27/87 01/15/88* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7310'MD, 6382'TVD 7168'MD, 6241'TVD YES ~ NO D 1807 feet M 0 1600' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/LSS, DIL/SP/GR/SFL, FDC/CNL, FMS, RFT, CBL, Gyro, CCL ,eeL/Temp log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Tb" 62 .5~ H-L .U Surf 115' 24" 225 sx AS I 9-578" 36.0# J-55 Surf 3500' 12-1/4" 1200 sx AS III & 400 s Class G Top job w/85 sx AS I 7" 26.0# J-55 Surf 7260' 8-1/2" 300 sx Class G & 200 ~x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/2 spf, 1200 phasing 3-1/2" 6724' 6652' 7000'-7006'MD 6074'-6080'TVD 7010'-7016'MD 6084'-6090'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached Addenc urn, dated 1/21/88, for fracture c ata. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR 01 L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD. Flow Tubing Casing Pressure CALCULATED 01 L-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (carr) Press. 24-HOUR RATE. 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R E C E 'V ED Core description to be submitted when received. . F[~J 05 198B k Oil & Gas Cons. Commission A\as a Anchorage *Note: Drilled RR 11/30/87. Perforated well & ran tubing 12/12/87. Workover performed 12/16/87. Fractured well 1/15/88. vvv¡'¡ b,j :UJ-\N I Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit ;0 duplocate ~ 29. 30. . . GEOLOGIC MARKERS FORMATION TESTS .... MEAS. DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NAME Hydro. Shut-in Top Kuparuk C 6870' 5944' Depth Press. Press. Base Kuparuk C 6928' 6002' 6879.0' 3134 psi 2870 psi Top Kuparuk A 6949' 6023' 6884.5' 31 09 psi 2870 psi Base Kuparuk A 7062' 6135' 6879.1' 3100 psi 2869 psi 6896.5' 3111 psi 2872 psi 6908.6' 3114 psi 2876 psi 6916.5' 3120 psi 2897 psi 6918.5' 3112 psi 2918 psi 6964.0' 3142 psi 2971 psi 6966.0' 3143 psi 2972 ps i 6979.9' 3148 psi 2977 psi 6985.5' 3155 ps i 2980 psi 7003.4' 3161 psi 3034 psi 7014.0' 3166 psi 3044 psi 7026.9' 3174 psi 3045 psi 31. LIST OF ATTACHMENTS Addendum dated 1/21/88 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed dAJ ()/ì1/Uj ~W./ (} Title Assoc i ate Engi neer Date 2 -1-88 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Subm it a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: I nd icate whether from ground level (G L) or other elevation (0 F, K B, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njection, Shut-in, Other-explain. Item 28: If no cores taken, indicate JJnone". Form 1 0-407 "- --- ADDENDUM -------- WELL: 3H-9 12/8/87 RU Gearhart & run 6.125" GR/JB to 7159' WLM. RIH w/CBL & log f/7162'-5550', good bond. RIH w/gyro from surface to 7150'. ' 12/13/87 Pulled BPV. RU Gearhart and ran CCL f/6800'-6236'. Collar log showed PBR. Tailpipe is not present. POH. RD Gearhart. Set BPV and secured well. 1/15/88 Frac Kuparuk A sand perfs 7000'-7006' & 7010'-7016' per procedure dated 1/5/88 as follows: (1/14/88) Prop 20 bbls 104.~ diesel w/ 5% Musol, followed w/68 bbls warm diesel @ 1/3 - 1 BPM, 2500-2700 psi (1/15/88) PU Dowell & DA w/Plano' s quartz pressure tool, TIH w/pressure tool to 6950'. Prop 100 bbls slick diesel w/no prop @ 20 BPM, 5800-5304 psi. Prop 50 bbls slick diesel w/no prop @ 20 BPM,4509'-5250'. Prop 50 bbls slick diesel w/no prop @ 20 BPM, 5300-5400 psi. Stage 1: 1.25 bbls slick diesel w/no prop @ 1/4 BPM, 2056-2086 psi Stage 2: 2.5 bbls slick diesel w/no prop @ .5 BPM, 2160-2300 psi Stage 3: 3.0 bbls slick diesel w/no prop @ 1.0 BPM, 2430-2538 psi Stage 4: 7.5 bbls slick diesel w/no prop @ 1.5 BPM, 2580-2587 psi Stage 5: 10 bbls slick diesel w/no prop @ 2 BPM, 2611-2629 psi Stage 6: 20 bbls slick diesel w/no prop @ 4 BPM, 2794-2855 psi Stage 7: 18 bbls slick diesel w/no prop @ 6 BPM, 3020-3063 psi Stage 8: 30 bbls slick diesel w/no prop @ 10 BPM, 3500-3783 psi Stage 9: 600 bbls YFOO III w/no prop @ 20 BPM, 4729-3527 psi (First 550 bbls had RA tracer) Flush 68 bbls slick diesel w/no prop @ 20 BPM, 3527-5291 psi. POOH w/pressure tool. RIH w/temp tool/GR & ran 4 temp passess. Fluid to Recover: csg. 1050 bbls w/no sand in zone and no sand in REC£\VED ~~~ r c ~~; c c, .;:.t.; ::~ g ~ ",-,.,~ïS'c-¡W~ ..." Cor\'",'" ~)mlÌl!l ..J..l" ,., O' . GaS) .it"" .\'-"'" ,(Å I, Änchorage ,~, ~~ '-- þ tf J--//~ N.. 1'~ December 21,1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.o. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70109 Well: 3H-9 Field: Kuparuk Survey Date: December 8, 198,7 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. ,.>~ Ie "Î .;7 '¡, 4 (..'1' {) rJD ~ tð1D~~ Ken Broussard District Manager Enclosure ""'", r,"",,' I'" ',' "" ¡' [j ~'" L?'"-> , ~\, ,"'1 --- '.... ð '0 " r n.,;., J ¡',\ '-' ~: ,~" , -" C ->-" P",'n,.-p'¡'C'('.:"r; , r.~(>,c'.':'S ""."JUilí¡¡¡,;;;)!WH ,-, i,,;i¿ ~-., >..l,<' VI."'. '" ,oW~' imchorage NL Sperry.Sun/NL Industries, Inc. p.o. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ,f :::;P RRY-:=;II :=; I 'V ANCHORAGE ALASKA ARGO ALASKA, INC. _3H-9.tê.EÇJ~. .J.L2N BQ~E.~ I<UPARU~:: ALASKA COMPUTATION DATE DECEMBER 10, 1987 ..-,.. -.- -----,-- ---~----,"'-"'-'-"-,""..._--_. ,,- ", '., .il '- ..-,-_. (~,YE.gTICAL SECTION CALCU~~T'fl,:ALONG CLOSURE DATE OF SURVEY DECEM8~R 08~ -IS -: p . ~ I ' JOB NUMBER Ak-BO-70109 KELLY BUSHING ELEVp - OPERATOR-H RGER . ¡' ~¡¡ PAf;E 1 1 9:=: 7 . ..- ....... .--.. --.- 76.00 FT. ~-- "'~ "f' '~'I' ,:~, ',,' ,', , \'to, , ,~., " , COURSE '--"- DOG-LEG DIRECTION SEVERITY DEGREES DEG/I00 1.QI.8J.. .: . ' .'" RECTANGULAR COORDINATE~ NORTH/SOUTH EAST/WEST . . ... -, . ~A_- ,-_. .~~~.ÇlURSE VERTICAL INCLINATION DEPTH DEG MIN TRUE , . --. 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MEASURED DEPTH -,--- -....-- -- ----...,- :::: 0 0 (; :~:100 ::::200 ..._--,.,--- ... :3 :::: 0 0 3400 :;:500 "---'-"-" :3600 :3700 :3800 ..-..-....-..'- ::::';'00 4000 41QQ- 42ØO 4==:00. 440.Q.___.. 4~500 4600 4700 ,... , '41> 4:300 4'::Jo"') .. - '.. 5000 5100 5200 5::::00 :.",::,: 'C::-4" ~," ~ .'..' ' (HJ ~J5()O 5fSOO --"",-,--.,'-"" . !5700 .. "":--':" ~:~::::oo ~::;900 "... -.--. .' .. ----- CLOSURE COMPUTAT DECEMBER DA TE OF SURVEY DECEMßEf<, BOSS GYROSCQE:J C S~V: JOB NUMBER AK-BO-70109 KELLY BUSHING ELEV. OPERATOR-HARGER . PfiGE .'-:, ..;..- 1'::¡'-'7 .' ';:i TJlU~..._.. -- VERT I C{'.)L DEPTH ,../, ~;~~Si..A_._.- cou~_eOI,IR$I;....- VERTICAL INCLINATION DIRECTION DEPTH DEG MIN DEGREES 2667.67 2741..47 '-"-'1 C' 4C' .,::. '::' '-'. '-' :~:~:::':::::9. 59 2964,. 26 :;:0::':9 II 66 ::::11 5" 1:3 :3190.. 47 ::::26,!;. ...:;:é~.._.. 3::::41 .. ~i:::: 08, l'ì'-""", :: '::. DOG:-LEG ~=;EVERITY DEG/1.00 . 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ANCHORAGE ALASKA "",VERT I CAL ~=;EÇT I ON CALCULATED ALONG CLOSURE .. n." ..._m_._.__--. , , ,--- '-"'-- " -" IHI~I[:~ MEASURED VERTICAL DEPTH DEPTH _nO' ._,--- -- 6000 6100 6,200 --....-,---" , 6 :::: 0 (> 1..-.,400 6500 ---,----..-- .. '" 6600 6700 :; 6:::00 ---'-'-'-------'--- ,', " ',' .." .. . , .. , 5<Y;i 1 .. 66 I". 1 - 71 ' .:' ::::: D Ö ~:¡2:;::3.. 56 " --, C',.',,-," 77 ,..1.,:"::' (} a ¡.- '1 .7 - ,.- .:) t", :::: a {.:. :;:: ~i~::¡77 j '-;, ., .,., a, d- !:j67~i.. 9"7 ~:i77~ï" 1:2 I~"'. '7' II 1..1'" .:):;::' l,t.. -t '-;I ~t, VERTICAL DEPTH ._-.",., i9:37 DATE OF SURVEY DEC~~~~~. 08, ss , S I 'J: JOB NUMBER AK-BO-70109 KELLY BUSHING ELEVa = ';1 --, ,.. ....Ç.:QUf§t~ --- ..ç:J:HÆß.E- _. ... _L~ÇIl~:-~_EJ:L.. ..__...IC!.IfU....___- INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEG MIN DEGREES DEG/l00 NORTH/SOUTH EAST/WEST .....- --, ,---,-_......__._-~-,._.~-- -'-'-"----'..- '.._~--_.. ---- 5015.66 18 13 5111.16 16 15 52.9Z,!..5~__..___-1.1,- :32 --. 5304.77 12 31 5402.68 10 54 t.:~ 1::' . 1 1 .-, "..1...10 D ..:: .-.-"...-.----..,........ 5599.97 c.j ¡.. 1::1 ':-., 'I '-:' ',.. .,'.' .' .. ,.":.. c""'" ""- '~ ., '1/ '..1'...' L 'n} '.. " '-,'. " --'-- '.", HORIZONTAL DISPLACEMENT - 9 17 '::- 4' .-;:, '¡. '::-J, E '-' ,-",;", -" ~=; 44. 10 E 1 1:,",-, . a._I.':, 1 '::-/7 . " ,"', t.::" 1 ,'...-, E '::' ,..1 . '::':; -_...~=; _46. J. 9 E_.._.__-1.,. ::;::0 c 47 00 E ,'.:.','.(,",>~ '.,' " a'-,',' . ç 1 . 80 .'. c:-I.':' ¡." 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'::' (~, .::' '7147.':1 .-;"'1.1 C ...... .-'a,....T ;;;:; ,",":',4" "7',,, '::-,/ l' 1 ""', ...,:., .. " ,:;. """4'::"-' "":07, ~. ..::.' ';;:;":" '! ..L .;:, '-'4'-"¡' '-'4 ,-. .i:, '::. ':'. '::' '::' '-'i"-/(-) "-'LI ,-. ,'::"t::...,':'t .::' ,-:, iI'::) .-, 7 ,-) ,-, '_~":'D ',',' ~ ,'::' ",'. 6A:,';?~.ç;~~ .';;~ "'¡'ÀO7"l;:l.), ,;:, ,-..:,.~:.z ,II! ,..,:h'~, :0,;,:.", '~,Y," '.,' -'"iB,-" ,,;:.' ",,',Jl .;ot¡;,' .~.' '-,I::" (..) 1 I ¡. ,-, ..::. ,_I .. . t.:..:. ,;:. 2:;::77. 44;, '-"-"'-'1 ,..),-, ..::. Q '::' ..l '.:' ,,;, q::::: :::: 1 '7, ..,- 28::::::":: ø --.-. ,---,....--.. ..... THE Cf~LCUI.Jfr 1 ON PJ::.:c.ICEDURE~:; nF<E BP,SED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURV('.ITUHEMETHOD. é, I:~. ¡;::- c:;- ..:.::1. .. ..__._I.:-:l.--", ... .., " . ""'" .......,-..----...-..--------. .-- '... ..---..-,----. -.---- '--'-- "'--"'-'-' -- ,.....'_.... ......,.._-"_..,-,,--,~~_..-...---,-,,...._-_.....,-- "'-.""-"".' --"""'-'--"- --,. , ---_.. ,-- ..-..,..--.-,...............,..--,-..-,- ,:,,:,:::,:,," ::::::):\-:::-: ,:.-::ARCO ALASKA, INC. :":::"'. 3J:t-9 (sgc t'? T l'-:N RO8~) . .~- -_._.~-- -.........~,- ~::UPARUK ALASf<A -----".- MEA~::;URED DEPTH --------.- .-----.. 0 _. ...._199Q 2000 :3000 4000 ~--"'--'5 âÖ 0 6000 7000 7:310 ,¡,:,::,:::" '-".. ,,' ,:",:,.>:",," THE .--.---..--..--..-,----.-- - -. -_..' TRUE VERT I Ct-':1L DEPTH OaOO -:¡ q .::/ '::-/ c.~ ," " ,- .. ,'~ ~". 1 ")--'1 .),-, .,::,.:: . <..::. 2é,/:.. 7 a/:..7 :3417. ~54 .. -.. -. ..' , ... 420:3 a Oé, ~~O91 . 66 ~~ P 7:;: !!.;..;:!.:~_.._. I- -:"::"-:0 ,'-"'7 ..,1 ...."...'..~", '.::S . ,-, , ,-, .. -..- .., , ,...".......... . . ,.. - . ANCHORAGE ALASKA - - , ' .. - , . - - - " . . DA"VE..OESUR\lEYDECEMBEB 1987 OS, '-'- .. -------... .~.Qt1E.1[[åI.I~... DECEMBER 10, 1987 ~OB NUMBER AK-BO-70109 KELLY BUSHING ELEV. OPERATOR-HARGER "--' "--"-- -- 7/.:...00 FTa - ,'to T t'. "t~¡ .. T. . h"~ ,~':< (, ..;: '.; , , "f. ,¡¿, .~ ~ ,- INTERPo'LATED VALUES FEET FOR EVEN 1000 OF MEASURED DEPTH , -'-------"'" - ,-. .--.-.. -. .. ---.- '_.._n ,-----.---..--.. --,-----,-- -.---- ,_. ..._, n.- SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES .__I}~F:JH,_-.____NOI3TH~~;OUTH EA:::;T /WEST VERTICAL CORRECTION (" MD-TVD DIffERENCE "-- .----- ..,- 7 I':,. 00 0.00 0.00 0..00 --.-.----. Q_'!. 05 ---.--.--.-,.--. -_.---" -,.- ..-- ,...., '1~~:J! ~5 ..,..,"-,. -'_.-,..m .., ..,. .__..L!..93 -j\l_..__.._-__...,~l_'!...~:~l,_¥L,._..__-- 1845.08 2/:..7.40 S 181.50 E 4(:,0.. 62 E 7 '::"::1 /:::. ,.-::. E-- .r-,' .. '- ._, E E E 1444..77 E 7:'=: . 92 0.05 7':' '::'7 ,_,.. ,_, .::'t::¡,:-"1 , I- 7 ..,.'- -- ..-' '::'7 (") ':. .:' ,_, ... '..,"_, ,-. .:' ,-. .-. ,-, ,-, .-, '.:' '.:'..::. . ..':1..;:0 ,"',/:::,-, 41 ..::. ...1 .':1 a ,-"".....,.:;~}4,,1. ~~lL.. .--- 147~5.. 16 4127aO6 20f9..86 5015.6(:, ,-, .::. 5:::::2.. 46 7'?".I/':"..,'E'/4 'Î'O:a. 34 92é, II 45 927. 6::;:: ,-. t::' (") 1 .-. ..::. ,.,1 ... ..:' ,.~ '1""4'4"""' ,'-:",'",.."~ ..._----,--, '-----"-'.----.--. c. .;::. 1021..17 1'-;'8,'1 4,:-, ...:......',', ," ' ,a;;;¡ ,J.42Ct.1B .-::,.-;:..::;.1:. '7' '":' '~'._"'"' ,~I. . ,.:;. ,-, ;::. 111 II 40 1, ',',,'Gf. .', '1', ,,1 I;:;¡ .. , 1 19 II .' .,";3~~/97.!' Q~t._._.__.,.- 2490 It :34 $ -----.- 6:306 n :37 '-,C'() 1 " L."'.I .. . II (:'(:' ,-. '::. "',', ç () L C~:11:(tII, ON_or R QC~~ D t:!B.f~, f:) R f:~- Bf) ~::;E D ._~---~----' '-'-C:""'-" . ....---.,..-,.,..,........----....... ON THE I ":'E "' '-' -.. OF THHEE DlfYIEN::;IONAL R{ŒI I US OF CURV¡f.) TURE l'1ETHOQ u ""'-..,., ""'--"..'- ""'----'--"--"~-'-----' '~ . . . . . . '.':"\//":"'" ::.,. .'::-"-:C:"":.. .::,',:':::, ....:.::::..::';:"':',:,' ., "":::':.., .'.,:' .' ", '."." .. "'. ,. .. ., .. .' . , ------"-'-"""'. ---'-"--.--,. '--O'----~~~ ,..--.--.--...",,- - .-----..,...--.-. ... .,," , .... - .... .. . --'-'--.- _. --.--- ----- --- -- - ,-- , --"---'-"'--.'-.--'----' ,_.. - .. --.-.--....---.- ""."-- .-----..--...--.-- .---.-. -.-...-----.-....----.-..-. ...-.--... ."-:1 .. :~. ,. '--"'-"--... .. '--..----.--..-,........'" ,."-,,-,---,----,..-...-.-...,--......,,.. ."-'" ....--....-......,,---,---...--..-- .. ----~._-,---,_._,....- ------- --'--"'--"--"""""-""'-"""""""""""""""""'-"'--""""""-"-""""","""..0"'._"""""""""'....-..-.....--.._....0.""""",,,,","'...-"---"'""""""'-~-"-"-""""-"""'-"--""""""'""""""""""""""'-""'------""""""""""""'."-".."""""---""""'~""'-""'-""'---"-"-"""'-""'","""",.....-.,,.,,_.,,-,.""",-,-"".",,~,,--~-,-."-"-"""'-""'--_"".'-"-""-'----., " ::t"\: ':';:":' ---~,-_. .. " ANCHORAGE'ALASKA .., ".... ", "..' , ....E:8.QE ~=¡ MOl.... ..f ."" CO~ DECEMBER 10, 1987 DATE Qf: SURVEY,' PP;ÇEttiif$.., 9~ ' , , ' ,'}tfttNHt.'[;V ~~{,::'. JOB NUMBER AK-BO-70109 KELLY BUSHING ELE~~, '"'". ," 1987 . ¡:::;:/, ARGO ALASKA, I NC . ,",',',-'-';', :I\t>3H-9 ( SEe 12.... IJ 2N RO8E) I<UPARUK ALAS.:::A ,::"::\:;'-' ----,- '"' 'ør::~{\t I NTERPÒJ..,A'ED VALUES FOR EVEN' '10Q'FEETOF $I..JB-=;;EA ',: DEPTH ,~~ ,:~,;:,,;,:_,' - .. .. - -...-----. .., -, ..........' .- ------ ., .,.. .-...--- ,,!':\:¡**)}f~:::~:m~;:::;;::,;~~'r .1 ".,- .-..,_..- ..._- MEASURED - DEF::TIi.__. --. ,- TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD P ;,t'TJ:I- .. -....---..- _PEF:,TH --_.~Of<TIi/:::';OU1JL_---. E{1ßJ /t.JE;;:.L. D I F:FERENCE " C' """"""" ,-,,-._-_.. 0 0 . 00 -- 7/::.. .. 00 0.. 00 O. 00 " 76 76.00 0.00 0.01 N 0.17 W --.-------..- ".. --......- ...-..-.----'" ..._- ,---,",'" .---- 176 176..00 100.00 0.01 S 0880 W 276 276.00 200~00 0.13 S 1.38 W .....--.---..--..:-;:.7 6 376.. 00 :3qg. QO --, ---- O. 14 S :2. 1 :::;: 1L-.-. 47l:. 47/::....00 400.00 0..0:::: S :~:.O7 W 576 576.00 500.00 0.36 N 4.03W ~;: -------,_.~~.76 67~,.,Q.o"" bOO,~ qQ".".---:..Q. ¿~~Z_-~,._-_.._---_....;ï!L~?;6, -~-- 776 776.00 700.00 0.97 N 6.43 W 876 876.00 800.00 1.05 N 7.75 W 97.~.,.. ,.."._" 926 ù. 0,0 -..-.. _,..2,!20 ,,-QQ---..- ..... ..._,_--1. o..~ N :~:.. 64 l~ 10761076.. Dc) 1000. ÜO 0.. 0::: N 7" 72 W '1176 117~'n, 00 1100.00 4,,'-;'4"'$, t~77:~,' ) :;;:~Z? - ,-_._,. .. t~~'?<~.~--Q.Q.._. ., ,t:~~(~Q,!! .Q.Q--,------- 15.. 01 ::=.; :=:. :;:5 E 1. :::: 79 ' 1. ::::: 7 is .. 00 1 300 II 0 0 ::~: 1 . 7::': :::=.; 22. 51 E 1484 1476.001400.00 55.26 S 41.28 E 1591 157é.ù 00 1500. on ::::6. :3:=? !::; 64..76)1:: , I 1702 1676.00 1600.00 125.82 S 92..67 E 1818 1776.00 1700.00 175.10 S 125.00 E 0.00 0..00 0.00 0.00 0..01 0..01 0.02 o. 0:::: 0 . 0 :::: 0.04 ,---_..--- ----- ,-..-.. 0.00 0.00 0.00 0.00 () on -' . '. '. 0.01 () ~J;!L-.-,--._,.,. ' 0.01 0.01 0..00 0,,02 , (', ") , .,'-;':,.,'1" .. .. "...,i "-' -.-- ,,-.., "'.,..-.- .,;:),\:(:: 0 . O~5 0.07 .--., ...--- -.-,-,...-,--..-- , C""""'~ ' ,d," ,:.,,~;,!;;¡f .. , ".,..:'.~"~;;" ,.. ' ~ :3.84 1.(1'7 2.40 4. 4t. 7 "-'7 .. .~ 11 . 09 1/-. "L .:;, .. . . ~-- _. """'-"""'----C-- :3. ::::0 . ,..; ,I §,6 7 26 ~'.75 42 . t3E:~ ....""-"" " ' .., ,." - 'm."'_'--- --- ....,...... ..' ,.,. --,- ,-......-.----.----- ..- ..--..,-- -..--..____n' -.... .nn. -- ..---.....,... . ,,"""", ..,,-,----_._--,..,--- ..,--...------- '{:"'::::' -~""-~'-"-"'-'-'-"'--- --. ""-"'---""""-""'.- ,~".."_,N,' """, ........--". ','.'. .~=;~RY-:~;~I~G . . "'. 'ÅN~ORAGE ALASKA . - .. ¡;:;I:~::::.::¡i~.~cÞ . A~ASKA 7 I NC. ~C 1 2 .- TJ ;z.~Ln MßE.l .:~UPARUJ< ALASKA .. .. ... .. .. ---- MEASURED --.Q E F~r I:i.-- -_.- 1941 ----. ._;2071 .-, .-, ( 4 ..::..::' ., ,-. ,-, .-'. _7 ..::..'.::,..::' -. --~~tZJ., 2605 ,'," ")74' () .... , . .. . . '-"-'71;;:".. .. ..::..;:¡ '-.'._- .. ::::0 11 :3146 ,,:, .,:, '::' 1 '-'..:"'..' .,..."",...- '-'4.1'J:;:'. .';"'...".",,1 .-, £::'4'7 .,;:,;,..t .'. .-,./-. ,-. <..~) ~,;:"':'ç:'..__... .'.,,-, 1."-' ..:.,::' ',:' '-".'14 1::- ":',:: . ,,_1 .::i::: '." 4076 4206 4:;::35 _.__._--- _u_.-.-. .-... -_u ...... -"'-"-'-"--""" -_._------- -.- ---.._---, TRUE VERT I C:AL DEPTH , . ::::476.00 :3576. 00 . :367(:. ..00 I DECEMBER .IE 1 ':":37 CO~Y . E:flQE 1-. '!". in - ') i¡ ,', >þ':. .-....-.......-.... , , '-,' u. INTEAPOI,.ATED , VALUES FOR EVEN 100 FEET OF .. ..r:~'i')O .. <:~'f&i~¡I. JOB NUMBER AK-BO-70109 KELLY BUSHING ELEV. OPERATOR- RGER 1 '-:', :3.7 .. 1;;. _.. .-. ..,..--.-------.-,.-.--.".. -----.--..-... - SIIB-C.Ei\ .... - ....' ,r" VERTICAL ...-. PfE~T~H TOTAL RECTANC;uLAR COC RDIN(~TES NORTH/SOI.JTH EAST /l~E:=;T - 76.00 FT. SUB-SEA DEPTH " - -- --.- --- MD-TVD DIFFERENCE VERTICAL. CORRECTION c:. ..----- 66.. 00 97 1 ,::¡ .' j .-.. . ..:.. 1 ':;J .."",,'.4,. ..:.. ..--..---.....--'----"-' .- . .-:..':>.". 1'.-:' .,;....:;.0, . .0:.. 29..97 1 :::7{,:,.. 00 197~.,. PO 207/.:...00 :? 1 7/.:. II 00 ~227 é~" Q9._.. ,-.. 2376. 00 2::::00.. 00 2476..00 2400.00 _.~::!:;;~,7f.:,....QQ. .2~QQ!!.JdQ, 2676..00 2/.:.00,,00 277/.:..00 2700.00 962u33 ""-' _...~~:~~Z_1-~-QO ___,_l~~:QQ~,OO_---_o_-_.._:t 04~S. 21 2976.. 00 2';I()O..QO l.t2~~,..:;:1 3076..00 3000.00 1205.43 :;!.lZ~~~HDQ.....,..,._- .;~JQQ.L~~,Q- H--...-....,_."12:B5. 20 3276..00 3200..00 1364..55 3376.00 3300uOO 1442..82 :3400.00......_--_---.__.1520. ::-::7 3500 ~oo 159~i" 50 :3600...00 1669. l~~ 16:3.30 E '-- ::::<):;:. :3.1..;2____- 2Q:3. ~2_.~_,...__. ._--- 9.;~. 242" :30 E 279. :37 E 5~t:, ..:::(:L_-~~---- :::: 15.. ~):;:L.E:...___... ---- ::::50. 24 E 711,,42 S :3:39. é,l E 264.. 74 ___2:::/:::: !!..,7~ "..~:; -__.___427.Jf.?:. E____,_....3299. 70 46::~. 56 E 4 ':;J:::. 1 /.:. E I::- .:. L':' 1'::' E ',.1..., ',-, .. '..' P 7.4!~.. P;¡ E ISOl.50E 643.2'rd. 679.29 E 714.79 E 750. 12_E 785.51 E ::321 . 3:2 E 1 :::00. 00 t'~~QQ.'!_Q-Q.....---- .' :2000.00 2100..00 '::"')on no --=:':!;.-;..::. H"' ~""';':'...:: -.......,-,- ,-,,-,£::, 7.-, ..::.. ..;:\.;"1. '::. .-. .;:. 3::::5.6:::: .-. .::. ----,---",-",-""....._0....." 1." I- e- (") .-, f' -' ,_I. "..::.. .-, .::' 1.-,,::, "::"-' " .-..-. ""...-. ..:"'::" . ,0:..":' é;.2E:. 92 .-. .::;, :::37'7 . 9~5 ,"'. .::. .-. ,-, çJ .:. ":,,r::... .' '-' 1 t;.1 II .L ';J c¡ " " '- . --. ."'. """ ..::..::':: .. ..._- 34.06 :34. Oé. :35.50 ,-', ,:;:. .-. .::' c. "~" ;;;:4" i?é. ::::5. 62 ....-.. ._,-_..~_.- ..............._~..._.._._--, ,-. ,:;:. ' ,-. .::. ::::; r'. .::' ,-, :2-- .::. '-' .-. .~~. ,-,.-.e- .-,.-, ..:' '.:' ....1" .;,...::. :37 0.. /.:. /.:. 405.7:2 ,.. " .. .. 4~~¡,~§p 472..00 fi()4. Elr;: -.-. "'4 .,- .. ..:"_'. ..:' ::::~5.. 0(:, -----"-"- ..;¡t;~t. 9:;: .:. .., "~t:: '-'~,. .,;J,-' .-;:,..,:... I"".~ ...1";... O..;:¡ .-. ."', ¡. "-, '.:'..::.." .:; .t ......- '-~------C::'-- 5:3'7 . 4 '7 569.. :3:::: 31.. :;::é;. 6ÇH) " 7:::: 6:30.71 .'. ~I':¡ '::, ~ c.".. " .. .' c. :3h.1..l-____..,.. ..."---.--.",.--.....--,-"......--,.,--.-,,..,-,-- 29.97 29 . 2~:i . ..__._.. ..... ..---....-.--.....-- -- -. ..__n.. ..--------... " -. '-- ..- --Oo.. -..-.-- '---""~- ._-...._,..,..__.~-~....- ","-"""'" ,--. ",..---,,- .-...-.,..".., '-'--"'. ,,---.- -_._"u ...-..-."... ..------ - .-...._u- . -. -.. -""'-"-'- - ... . ...-.. . .:.;.: ;.,"':.ý",: . ... ."W"k¡;¡pII ..._n"_'- , """"'-"""-""-'" '-'..-.-.-"" Oo,......-......-...-..,.."---....---.-......,,.- ""-----"."""""-'---'--'.-' ....-.----.,-.- . -...-... ..' "...--...,--..-,....- .. -. .... ,--.- 0: ARC£) ALASKA, I NC" 3H--9 (SEe t~ T. L;;:~~,., RQ.~.:;:E1. KUPARUK ALASI-:::A ::,"':. " - . .,-~",--- -.--...-..--. "."'--"'-' ..-,--."..--..---,. MEASURED DEPTH 4463 45-;::/0 ---", , 4716 4:::':42 iJ -:;1 I-, '7 "r, .. I ---.....-' 50:;:::::': 5206 c:..:".:, LI ...1.--..:.. t c...".", ,_,l'r :.:: ',;' ¡::"c;-t-,., ,_".) .,) .,::~ !:i662 , , :',::<i;,';"- e="?-Z( ,,;..,," ",J , t:::" ',::' -. '7 ....",-,j 60:;:::;:: f..1 -:¡ .-;, ..' .' ~;.. I '-"i t:: (:::..t:..,:: ,_, 6-:397 (:, L . ';::, :::: . .-..". ..... TRUE VERTICAL DEPTH . ,--_. --.. .. ---,. .....- 377é,.. 00 '3876.. 00 . , ... ,- -.'. 3976..00 407 (:'" 00 4176..00 ..-, ,... -"., - -...-.. 4276..00 4:376..00 44 7.1;.~ '" QQ-.- ., I'.' "..., ( ) , ) Å't.:)!Ö.. :( 467é'h 00 .. ,-.- cop' - , ',-.--' 1987 ..---......--. COMPUTATION DATE DECEMBER 10, 1987 ""'r'...,)..~..~¡.,!,~~, INTERFOCATED VALUE:; FOR EVEN 100 FEET OF SUB-SEA ..-..--...-...- ..,-...--...---....-.....-.--.---,--- --.--- -.. -...-..- -. .-- ...--- SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST '---"'- _.._---~------,- .-~.~-- ---,-- .,E:àa£;' 7.. -- - . , -., " DATE:;OF :..9:URVEY .,"'DEGctaB~~oa, '----""'- JOB NUMBER AK-BO-70109 KELLY BUSHING ELEV. OP 0 'f;E .' 76.00 FT. - DEPTH " .',',' . -'-'-'-"-"--'-'- VERTICAL CORREC:T I ON ~--,--_c_..._.. MD-TVD .I!J FF:EF<ENCE '-":;:7 ~",~- E ':::"...' . '."'.:' ~ C"=I{. 7 c;;" E Ç".:-~..!!...-..::L_-=- , E E::. 20(_):_~.},3{_~ ~ 101,1?Q E~ .. .... -::,' ,------,;::..---,...:.-.~.::""::""_......::-...._-_. ---.. 1047.14 E 10::: 1 . 22 E 21é:i7~5~~.._..8 ,--_._..,-~.~:::: E 1146. 24 E 11. 76.. ::::0 E ~E 1'~.~(!'\ '. e:::,¡" ' 'm-, . ',','4:.;.;,::¡,,'#:IÎ"';~":' :~, g :3700.00 :;::::':OQ~- 00_.___.,..,..- 1 =::=07.. 05..- 8. :39'00.. 00 4000.00 4100.00 ..." ""-""""""""'" ~-'---' 4~¿~OO.. 00 4:300 II 00 .!t40P.~J~tq, 4,500.. 00 11,600.. 00 ........".~17] (:.-!'..,~~~.~~~----_--___,4]QQ.!'.,OO 4Æf76. . ÜO4800 .oø. 4976..00 4900.00 59E:::;:: :í07 6. 00 5ÙOO..OO 2:1::::= -,'.---,.,.---..,-...- ',...,--. '. ,""'~'---"--'-""-""~-"'" 5176..0D 5100.00 5276.00 5200.00 -g.::::? 6.!!...QL_,- 5,::::00. 00 5476.00 5400.00 5576.00 5500JOO 17':>'9 ~',,::' '-,' . ...-- ,-. ':' l. ':'7 I:j'::' _",~I .. ',. '-' --;'7 62 ";,,. 26;... 79 2(:,.. 1::7 -.J 26:,.. O~5 ,-, ':::' 9:35.. 71 97::-::.. 91 ......-.____..71:4.. 37_____.-- 740.94 766.98 :1.::::74. 14 1940..69 ,-, '::. .2061.7:5: 2115.. 'W2 s ,-, ,:;a ,-_..._----,.. ""---',""--"".' "7 '::¡ 1 ()il ..' " , .. .,'" :; 4.. (; (:. .---....---.- ---~_.._.."._--------,- ::;:12.05 21, .. 01 1:3.71 __.........J.Za...:3 5 1 5. ::::0 ......--------.-----..--...------,-.-- -..... ':',','-' (~) , 7 7 ,-,..;:¡ ~.. ' .-, ,-, 1, t:: ,-, 1 ..::, ~:~ ,_I n '.:' ::;; ':'11-='""'-',, , --'" 1 '-:', ...._._-~~ 12. 1;,2 '-::'-::'£::','7 4' _,7 ':::' ~... ~-..'.,. '..,' '::' '::' '~ì 4 64 ."', -",,-..---..,' ,'*,.~'.- ,," -':::', ,'-,' .-, 4" ':::' f.:.1 '.:' .. ,;~ :376..04 -:::":::. I- ":'l- '~"-',,-~,", '~',"1" , to .3L--___~ $...4$ 2:356.2;3 .S .,"',",-, "'.",-;'",'"7','",,,, 'It", ..::.: -.::.~""..E!v. f"'..:.. .:;:, 'i9 ,:;. '.' '::'4(')4 '7'-:' .,- ~ .. ,_, 2424.44 ,-. '::;. 1 .:-.r ,-:¡ ,':) 7/-,:, "",' ,'" - 1:319.. 40 E E :::.; . 24.ÆLf... O!:i ::; --.J:3:~7 "UL.E 2454..54 S 1353.00 E 2465.15 S 1367..37 E S'?'!4- ..79: 901\0 6,::;: , " .. "9 ) -::;. 1 .-.. .-, 7 " ,.:... ':.' 916.19 9 1..2.....1) 921.27 4 ", J .. bc, ~ -----~_..-C~~- ,-, '-'1 '.-:'. .;::, ,-;- ':/"-;, ..:... .' ..:... 2.16 1 .. ~)9 922.86 ..--..-...-.,.....---...- .. - ........ .- .--...--------.... .....,-,-.....-.--,--.....-. -.--....-.-.--....,-.--------. -~- .. -. on .-..".. ...... ._......... ". ----------------,..----.". " :"'<""':" '~ .. - _m . ,.-.--,-----. --..-.-, -----.-----.--."".. .,,-...-.--..-..., -~-""'-~",-,~~~,-",~~"~",,--,,--,,,,-,,,,""-"--""'-""- -'" ..""'-..'".._""~..-."_......,,.."-" "'-......-....." ""'..."'-""" ""-..."..-,, '"eo'" '""""".'--"""'.." ,.".."-",,, ,. "..".." "..."", ",. "....". . F' () CiE__3_- --- .'--- .---..--... -- ------..--.. -- ,.',-- ------.- ._._--_.._~E£El:(J¡-':;;;I..,f \ ~.~:;I.,IR~.EYl1:~UL.C.Qt1E:{¡NY ANCHORACiE f~LASKA DATE OF SURVEY DECEMBER 08, 1987' ARCO ALASKA, INC. i :"::;J:f-9 ( ~::;EL-: i-::' -1-l"~'I\' F-';n:=:E) '"'- . .~ .-. ,,=.--- '- r,=L~ -, '"\ ~.. - I<UPAF<UK ALA:=;KI~'~ -...-, .- ... ...-.... --.-....- -- , ""' E"":'-~::;(I[:;'I:::.n I ..I~...__r,......- DE~F'T "'I _.-_._--- _. -, (,,(,00 ..::.lOO (. C: 0 1 (. .:;;. () :2 7002 71 o::? ï:?OJ '7" :':: i (' ... .. ) . .-. .-.-'." ..-.---.---.-.-. ~ATION DATE DECEMBER 10, 1987 ------.- ~OB NUMBER ~K-BO-70109 KELL... Y BU:::;H I NO EL.EV. == 7/:;.,. ()O F'r" OPER(i TOR-H?)F~C'iI:::R ',,' '". ".,,-- -.., -. .., '.. ' ',' '. ,', , ,"',.,.' ' _.-._- .-.-,.' .._. .. '---"'--'-----' -----.---__.__n___- .'IIB - f'" .. :::; - - ~:; ::, n VEF<T I C{)L., D F r' T H . - .. ~::;6UO" 00 !j700 ~ 00 !~;; c: 0 0 " 0 0 ~:::i')OO" O() (:,OO() " 00 (:,:1. 00" ()O 6200.00 (:,::::0(;." 37 -""..~..- , .. ..-.... --, ,..--.-- --..-... -..-.-------..-" INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH -- -------....----.-.... ....----. . T.RU[ ¡ I ¡""I"" ..,.. 'I. ,'.', :'.. I V ,~, n" I ",..,, ... .... 'r" t"""'.' ~I"I I ...1 .::, " ,.., ~::; to )' (... () () ~::; "7'7 (;:'" 0 0 ~j:;::: '7 (, " () 0 ~::; ';;;' l (:. " 0 0 ('o'? ('" ()() (~, 1'7 /:... 00 6::;;:7 (',,00 /::. ::::.::;::::? .. ::::: '7 1. :.-:::::;:(>. :::::0 E 1 .'::..:¡ " ':-/.::' E-..:.', .. '",'.' -, . " '..' . . . :I. il,!):?. ::;:::::;: E :1, Ii. 1. :1, .. .S (:. E: " .:1, '::'n "::q I,:,:".', ,. ',.,..,.. u ',.. " .... " '...... "" " I' '::' ::: -'~' o:¡ I::,,' .. t.."..... .' " - 14:36 a ~:; 1. E ,.,. ..... !.!J4:9~.~ ZZ... C ,I T (I T ?i I... ¡::;:FCT{'~INGUI...,¡::ìF: C()OI::;:D I \ {~iTE:~; "IO"- TVD VE~nT' leAL 1"'\/ Q r:: T 1"'1 /' S.QE'r H_- --- f {i ~::::.I/.HL: ~=:J . ,P JJ:l~ F f:~J\Jrk:..__.,.._C: Q!:< F.{E C I J çlt~------ -,-- --- .-.... . ... ( 924..03 1.1() ,.. 'I ..7' ..' 'n 'I .., :¿.tr,:.:::.:¿'" ~:::: ") 4' .j'-' o::¡ 1 t::¡ '::; ...., ,'", '.,. '-, 24::::::::;:" 3:? ~::: ''::',(, :::: /:, .:¡ '. -=: .".. r '.. .., .. " ,L '.., 24')0.. 4:~:;: ::::; 249:::;:. :::::9 ::~; 2 ii, ,) '7 .. 6 ::;;: ::::; :;;::~:;iOJ ~t:~6. ~;~;.w ",¡ ,-', 4 ...'...-/ :: '¿'... .. ,'::' :: (¡ :::::/"" .-.. -_...-._.::..~...~::,"~,_""""",_-"""",,- 92~j u ~:;2 0.. 6::::: ':) 2 ,~, .. 0 1. ().. il. '~) 0 u l . ~5 9:2(. u 46 .....-.". ..-.." .....-...... ..._.... .""...--..-...-....,--.-...-....,..-.--..,... ...,-............,-....----....' . ........".. 926M8..::. 0"40 "')'-'-7 ,-,."', () . 7 ::~::. ..'::"'::- :.:~~.'"' . ,.__.."l,2.~Z!. t:~;..._,-_. ....-,.,_. .__....(>!!. ~LQ_..__.. _.. . .. T'H[~~ C:(~II...,C:IJI,.("~IT'IC I\¡ ¡:::'F~C)C:F:DI...II::;:L::~:::; I...I~:::;F PI I....TI',.IE:(:ìF< I/\IT'r::¡::;:F'OI....(ìT'IC)N ÐE~Tl.JE:E:N -_.~...._..,.._..T' "'lf. .I";!F('!F?E~:::::T :?Qr'/)C)T' fv'lf:¡ Lf¡:::,:¡:..,I'-'j ¡::;,~()I)J LL~;:; ...Q,[ ç:I.Œ\VfLIL!.E[.L.J~Q,Lf\..JI:;:;_....._--_._.,--_....__.._--..,-,.....---.,..--.-.-.--,-........."...,...,.-- .....--.....,-,-..-..--.. ........ -_.._-----.._~-",~- . .' ".' ...--.-,.."""".' ....-..---.--.,---...-,-------, ,~-"".,-"."........". .".. . -'~"".-~' ...""",.-..",,'- ...,.. .. '. -"-"""-'" -....--..-'-'-" ."" ."""'.""", ...., "....-...".. -....." """'-""""'.-- ...__........_,-,,-_._--,---'.""'" ,.."-.-..."...........-,-..,,,,------.--.....--.-....,..-......-...,,---, "'-' .............._... .......,_... ..- "'.'-, {' . , ----.,.-- , , .'. --_.....- ..-._---~--'-- ~_.._~ '.'. "".. , .. ".......",..".. """""."""",,',........-...-......--........-,.... .._...,-_.........,._-_..._,.~_._..._--,_.._.,.._" ....""""""" ... ...."""'-""'--"" ",..""""-.......-..-,.,,,..,.. "'..--..-"..-." ""..--..,.,...- . . . . . , .'" . ., . , ,,~{::.::::;:<:>:,,¡}:~, ....".-,.."...,-....,.......".......--.,...-----.,-,.,..........--... "."....-......"... ." . ,""""",..-- ....-..,-...--....".."-.,,....- . ..-... .-... --................-...........,.".., .------.. .".... ............-.."..--........-..-...--......-,-.---..--.....",-.-...., . -"."".-."-"'.'-. ""-""-'" '...' .."-.' .. . . "".... .. ...". .. .........-.......-.......-..-....-..",-. .....,-_.......,-,....... "'--"""'-~"" """--'" ......"...-.....,...,..--.-."...-.--..-..-'-.--"-""'-----'--"---....,.-,...................".-.........,.........".,....""......-,," . . .' .. . , .. , :AACÇI. ALASI<A, INC. ~H-O(CErl? '-l?N Rl1AE) ,.::> ,...::.0 :.':':',-."'-=- - --'~' ',. .::~UPARUK ALAS.:::A , .. , . ,'-",: ':.:':-' '-~=;I , '."- ,--... "', ,-.., -",. . -- -. ,--.. . " - ,.... -. -- . - . . , ,,' :"ANC:HORAÜE "AI.,.ASI<A " ÐATEOF' SLfRVEy,,'DPCE;M8ER 0$, . ~: 1 9::::7 . !I'! -------.. _.- .._,-_.,._--,., -., -,_. ,.-- ---- -----------.--- ---..--- SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES DEPTH NORTH/SOUTH EAST/WEST . '_....,-'--~-----_.,._~----- -- ¡;;: '::' I~ '::' 1 ,:;. '-' '..,' ....' ,_, . '-' ,-, II ,-,I:;". 74 I-' ,.::. TO:;:',..,'..' ,:;:, ..-..........._... .. f'~)'-iF ,=} --'. - COMPUTATION DATE DECEMBER 10, 1987 , , ~ --.-.- ". . ~ !". " "", JOB NUMBER AK-BO-70109 KELLY BUSHING ELEV. = 76.00 FT. O- '.'!'f:¡{¡~ ~,Ð.~~' ' --'---'---'- "", ;~~ r" ,~,..',..!::,." '" f~ I NTERPOLATED V{~LUES FOR SPEC I AL SURVEY PO I NTS .. .. ---..-------.. ,- _. ,,- .. MEA~=;URED DEPTH TRUE VERTICAL DEPTH .-.-.-. _.- "'" ....0.....- é,870 !=-~ ':;1 4 ~1, 1 ::: .., . ",. , . .. 1 -'7 t..:,OO "b .. ---- , I-, o;r::' :::: ---- --.-":.:...=-.:"" ,'.. ':'jL'i 0::;' ..,',' -t" /- Cr":I'-;' '7 7 ..,' . .,;" .,:.. u 7062 7150 I: " .'::,r.7 ':r{) -,' ., ....1,...'" '._, '.. ".'...I,'...?,'..',;..'.',~,'.,'n(..,1",'..". {¿iðL 0".. ~flOC, {'..~ c ..'.I."t'_,'U.'..' ..:..1',"..."-',... '...' .. .. , -.... ....-.........' -",....",..~_..-,-- ....-----.- -.--.---..-...--- é,::::O,~:,.. 37 .",..-----,---,--.. --.... - 7 11- '-, ' ,.":' 6240..90 7. .:'1 () '-' '. l, ;:: :=:-::' ;'::'7' ... .., '. ..... U -. "',:,' !.~... . ----...--,..---- ......._---_.- 140::;:..85 E . _.~~'?'..;'~;i~ E:L:...__._- ~::48?J...E:7' ..!E; -_....J..~ 1 :3.. 94 E 1415. 7::::: E 14:;;-~5.. 44 E 1l1 ":"';, ":',(':j E-.- ..1"...' ,...... '.. " 143:~:. 7::': E 14~t4,..7'7 E !::~'i'll.6.. 77 ,6()59. ;~:O .-. 4 I-""', "1 ,-. ..:, 'C"::'" (:. .c./, '::' '-'4"'¡.-' 44 ,-, ~::. ;:' .,::"" .::' 1-.1/:,4 ,=,r(",) ..., o. H,' ~ '.:'4/:::'!-" """'n r...""',', ... .,'.,' II ,..,' .. -, '",;11::;', (,..) 1('... /,., ':,' .':;,'- '. ..... Çl,..., '"""",--...-.. -_._._-_.._-_._-~.. ,.-...............-.-.......-...-.--,-.....- '-----.-.. ,..- .. .- Mj)RKER (- ._------.., - ...- TOP ~:::UPARUK C' ..- BASE.. I<UPARUK C' TOP KUP{-)F<UK (4 Bf4~=;f'::, KUP",1RUK {% :::;f,..IHVEY DEPTH . PLI.../CiBACK TD TOTAL... DEPTH DRILLEH ._........... .. ....-------,-.-......-. '-'--------' ....-....----...-...-....- , -'-'-"'-'-""""""'--.""""-'" " """-""""-""'" """.'.-"-.-'..-.....-------......-.--..,.-- ...--....-.--... ~._-~-_.._..._(:. - "-"""'."'" ""'-"'-_._"""--"-_."-"""'---~-'-" ¡:,,<:\:: . " "".," - '-"'--"'.'-"""--""--"-"" ..., ..... .. ...---... ....-.....---.-..--- - """---'-'-"".~~~-" -.-..--....--..... ..,... ..-.." ..-.-.-"'" ....--- "-'--'--'" --'-..-......",.....",.- ""'" .-... """"'-"""--'-"" . '/~~}1_: .--..--..-..-.. ......._---_. . ....---.----........-.-- .",' . . "--'---"--'-"'-""",--- ...........u. ............,.--."'-'-'- '-""'---.....' ..-.-.-...... .----.-. "'----....-- .....--..-..-.-..................-....... ...,,-...,,-...- ,...". ..__...-..~.. """".-""-"""'--'-'- '-"""--"--'", ""'-----..-...---.--.----..,---.-.- ----.-----.- -.....--..--..-- '....._.,. ------------------------------------------------------------------------------------------------------- -.-. DEHIVED ARCO ALASf<t:~, INC" ::::1-1";"9 ($1;(:12 r'12NRQ8E) °A [IlL DEPTHS AND SPERRY .... - .-. <:; :-'" :. .:.<~"'. .... .. n'_",,'-"""-'-'. ..- USING SUN SURVEY DATA ---------------------------------------------------~--------------------------------------------------- :,::.:. :'. ::::'.' . . '. B.:::e E;UB...;;$EA . TH ¡ CI<NE$S '. VERTICAL.. . ATE:::: WELLHEAD 281FWL) ROSE .1 .'.'-:c. ... . --.....----MARKER--"'-'-'-"-'."- DEPTH ----~~~TVD------- - . ....------ . .."'- --- ....--..--..-- ----.---.- 6':::'2::: ._-~~.- 6001.87 6,022. 71 /:..1 :~:5. 30 c::-,-,,-,c::- '-'7 ,_,I:: "::".). ':' '-"4 ':'7 ':'7':' ..:- '-.' . '-' '-' ill n ::::: r(. ."" .t - '" U .. 1 4 1 .-, r', :--2.!.~_:.:.:.:..._..~ 1.41:5.7::::':E 14:25..44F TOP KUPf=4RUK C B{'~~:;E KI...IP{')F~UK C .-.---.- TC.lF' ~:::UPPIRUK A BASE VI...IPARI...IK {.i . PLUGBACK TD -.....-.-.---. .' TOTAL DEPTH DRILLER 6870 1:::".'-::1/14 1'::' '_.0 'r . '-' 5 :::: /::..:::: II 1:3 '-'4"-'1:" 74c- ot::' ,:;. ._1 " '.;;0 ..---...--.- ... '-.--'.","'_0.__-' 7062 5946.77 6059.30 '-'4'::"-' ¡. 4,-, ~. ""-',::.. -, .-, - --.".- - . '-)4'-} (", ~ - -. .' '"':'4'~ '-'. . 44'::' ..:.. '7";;'.' --' 7 1 ~?O --.---..-- .----.-----.... ---____._é,~ 9.~~~.! 90. .-..--- 61 64~~q - ..-- -.----...-.-- 24_96 II :30~i--_. .....1~1:~:;.~~_:!J;~~: 2501.66S 1444.77E 7 :::: 1 (> 6 :;::::: 2. :;:7 ¡.. 0:' C') ¡.. .:' 7 ...' '..' .. -.'. '...' ........----- ------.-..... -",,-""""--""---"-""--'-.--.--"-""""" '.---'.'-"----"--"'-""".'" -..-...-..-.-..-..-....--... ...,......-------....-.-..---,-.-..--- ................, ...-..-.-..--...... .-.-...'-". ........,.-.-.. .......--..----.-..---....- _...._0_"_,-",,,----,-,,---""',"_0_"._-"-' .... - .'--'-""""'---'--"'-'.""'-'-"""""--'--'--""--'..-.....--.---- . . . . ...i...--..-- -- {: .' ., . I: . .""'-"-. . ~. .............,. ........._._._.._-_.__..~....- '-'-C~:.. .~ ---- ---.....-......-.-.--.......--...-.. _.on.. .on. ..- .....-.......-......, ...- ..... ........- .-....-.... "-""""" ---...... "'_00- """-,--,-,,,-"'-"""_'_000 ......----------.---.------..---...----.-.------...---'....-- __00."'."--'---' .-.,.... ""..on ......... ..... ......., ...- ......".. -.... .._, ..... "'. - ---.... . '_'_0"- \10. ...."" vl) FROM LINEAR EXTRAPOLATION BELOW DEEPEST STATION. ') 0- - MPI JT'E-'F oR- - .. f- /\M ... F [-f- F' Y -. /IN "r'uF' EE'" [ .[ ....1'~-Nt'" I .. NAL RA[~ I U-. :.... I...:U .. ::. ( I". U'j"Ú-, ~::;-"':'-< (:::;... n <...:. .I. '-1-" Ó. U .- J S ~ ATA -. -l -"111 - .r J' - 1\1 ANI-' I Nl-E=-R'F' '.l .- -," r rt"l 'C."V R - [ I IIC: n_F ."'UR'Vð'T' tJ:'E:E ¡..I ._~:f-~....=.~:~'..::: ::.~). .-'n.')- ...,.. ...-. ..-:....--.,:=-.-....!-"....:.:.t% :_:::.E.....F..~....._._._H.l,...._=...:~L.-=:. t. r~.-~ OF CURVATURE.. -.----...-.--.-.....---.- ..-.-..- -.......---- .-,"'--'-'.""-----"'- ------------------------------------------------------------------------------------------------------- ... ........ .-....-.. [/n TF.:: ......... ...............-.....-............---..--""'" .----...- --..--.- OF SURVE y' ¡"IE::' f:E:',..1F/':'r.' , -.... .~ ... L.\ (.-.) :-.-.': ., -I ,-:,":' 7 , ....:L..:..~:_..~_."o_. ...- "-" ..' _0-'_'-"--'- ---- r:nMI::-~1 '1"".~.1"'[ 'ìt\1 n:\'l.E"~' .-- .. tl ,I.... ....(1.... . . . .. r;¡fiç;E',lvtBEF:;: 10, 19::::7 ..JOB ~"'::--BO-'7010';' .. ..._-~-_.~_......__.. .. .....-...... ....---..--..- ..._._---_.__...._--_._---_r.];L~~.C;...ELEV~.__.=-_..76.00 F "(..!-----_... ---..-..-- .--..- ..--...-.... .... ... .................-...".,,-n.-_-__..-.---.....-'-"""""----""'--"""-",,""""""""'.-,,.-..,......--"....' ~ -- SPERRY -SUo UPARUK 5CALE : - 1 INCH T~ 500.00 / 500.0 -so . 00 -1000.00 -1500.00 -2000.00 -2500.00 HORIZONTRL -3000. 00 T12N A08El AACO ALASKA. INC. DECEMBER 08. 1987 500.00 100 . 00 -1:. ~~, \~ \ ~ ;..>- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .'fp PROJECTION ,~" " ~, 7310 ,'- j:~~;;~~~:~ "'¡'; .:.:'~"" -¡,'< p,.' '; , .. . '--'. 0.00 1500.00 3000.00 4500.00 7500.00 r -~~~.;. . -, " 5 PER R Y - 5 U ~'c: :, ,"" KUPARUK SCALE: - 1 I NCH T~ 1500. 0Q;:¡'~,.1500. 0 ,:;, . 3H-9(SEC12 T12N R08E) AK -B~ -70 1 09 \ 6382.37 r 1500. 00 VERTICRL PROJECTION -':;'.', ;lX" ~". ARC~ ALASKA. I NC. 't'P'" tð<~ , {;t;',: DECEMBER 08. 1987 ~,'" ;;;;.: . '~ . -,1:(:, -, ',;1"", ;~.,*-? 't!-o- ~;;':~::' '*", . ~}.,~ 1""" . '; /i.',. ~~?," :,¡" 7310 1 3000.00 --- ~ '. .---- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~", Date: January 11, 1988 Transmittal If 7059 RETURN TO: ARea Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. --, 3H-ll MWD Formation Evaluation Log West log 11-21-87 12-15-87 3534-7340 115-4085 Receipt Acknowledged: JA~V~ ~ æWë- .. Anchorage DISTRIBUTION: NSK Drilling Franzen D&M State of Alaska(+sepia) Lucille Johnston Joann Gruber ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ---, /' ' ,.--- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ Date: January 11, 1988 Transmittal II 7061 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-4 BHP Data Worksheet 12-17-87 Cameo 3H-5 Kuparuk Well Pressure Report 12-18-87 Static Otis 3H-5 Kupaurk Well Pressure Report 12-18-87 Static Otis 3H-6 Kuparuk Well Pressure Report 12-19-87 3H-7 Kuparuk Well Pressure Report Static 3H-8 Kuparuk Well Pressure Report 12-23-87 Static Otis 3H-8 Kuparuk Well Pressure Report 12-21-87 Static Cameo '" ~~, Kuparuk Well Pressure Report 12-22-87 Static 'c' Sand Otis 3H-I0 Kuparuk Well Pressure Report 12-22-87 Otis Receipt Acknowledged: / ¥!:~~ .>' Date: ~ 0,' & Gas cons. \JU.....---- 'Alas1<a 11 Anchorage DISTRIBUTION: D & M .m:!Q~~~ BPAE Chevron Mobil SAPC Unoca'~ ARca Alaska. Inc. is a Subsidiary of AtianticRichfieldCompany Date: ~' ARca Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 January 11,1988 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.o. Box 100360 Anchorage, AK 99510-0360 ~-, ,- - ~~ ~~ Transmittal n 7056 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~~2V-4 ~ ~3H-6 ~ --..J 3H- 7 '-.j --..... 3 H - 5 --..:) --- 3H-8 ~ ~ 3H-IO ~ '-.. 3H-l '-..J ~3H-2 ~ ~ 3H-4 ---., ----- ~ 3H-3 ok - J ~ " Cement Evaluation Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Pulse Echo Log Cement Bond Log Pulse Echo Log Receipt Acknowledged: ~ ~ 12-29-87 11-27-87 11-28-87 11-25-87 12-3-87 12-9-87 12-3-87 11-23-87 11-25-87 12-8-87 11-26-87 5987-7253 5300-7866 6000-8516 4900-7020 4600-6756" 5128-6633 5700-7978 6100-8184 5600-7986 5550-7162 4400-9354 ~ ~?~)V!?~ C/ Date: . I Alaska Oil & Gas Cons. Gul,hiU5S en Anchorage DISTRIBUTION: NSK Drilling State of Alaska(+sepia) ARca Alaska. Inc. is a SubsidIary of AtlanticRichfieldCompany I< ~ STATE OF ALASKA -- ALAL. . OIL AND GAS CONSERVATION corv. \SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown 0 Stimulate 0 Plugging 0 . COMPLETE Alter Casing 0 Other rx 2. Name of Operator ARCO Alaska, Inc. 3. Address P.o. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1347' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1447' FSL, 1690' FWL, Sec.12, T12N, R8E, UM At effective depth 1437' FSL, 1715' FWL, Sec.12, T12N, R8E, UM At total depth 1431' FSL. 1726' FWL. Sec.12. T12N. R8E. UM 11. Present well condition summary Total depth: measured 7310'MD true vertical 6382' TVD Effective depth: 7168'MD 6241 'TVD measured true vertical Casing Conductor Surface Length 80' 3465' Size 16" 9-5/8" Production 7225' 7" ~~ \.It, ...... Perforate ~ Pull tubing 0 it 5. Datum elevation (DF or KB) RKB 76' 6. Unit or Property name Kuparuk River Unit Feet 7. Well number 3H-9 8. Approval number 7-963 9. API number 50- 103-20086 10. Pool Kuparuk River Oil Pool feet feet Plugs (measured) None feet feet Junk (measured) None Cemented 225 sx AS I 1200 sx AS I I I & 400 sx Class G Top job w/85 sx AS I 300 sx Class G Measured depth 115 ' MD 3500'MD True Vertical depth 115'TVD 3040'TVD 7260'MD 6332'TVD Perforation depth: measured 7000'-7006'MD,7010'-7016'MD 6074'-6080'TVD,6084'-6090'TVD true vertical Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail @ 6724' Packers and SSSV (type and measured depth) HB pkr @ 6652' & Otis SSSV @ 1807' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) REtE I VED J A f J ~'. f"" . n "\ ,'. ,p.l',-}i<>-,~¡ ., I -" ...,' "I OJ Treatment description including volumes used and final pressure J\!aska on & Gas Cons. CommissIon Anchorage 13. N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History) Daily Report of Well Operations ex Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~;1: I ¡) ,.j 6-' [~j Signed d)()JflIM./ ~ 111M A . Form 10-404 Rev. 12-1-85 (/ Title Associ ate Engi neer (Dani) SWO3/31 Date 12-~J-87 Submit in Duplicate/) I V 1 j , " . . -- ARCO Oil and Gas Company ~~ .", Well History - Initial Report - Dally Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. ARCO Alaska, Inc. NORTH SLOPE-KUPARUK District Counly. parish or borough /Slale AK Field KUPARUK RIVER FIELD Lease or Unit ¡Well no. ADL: 25531 3H-9 COMPLETE & PERFORATE Auth. or W.O. no. AK2521 Title 50-103-20086 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 12/12/87 ( TD: 7310 PB: 7159 SUPV:SS/DJ 12/13/87 ( TD: 7310 PB: 7159 SUPV:SS/DJ 12/14/87 ( TD: PB: 7159 .' SUPV:SS/DJ 12/15/87 ( TD: PB: 7159 SUPV:SS/DJ ~ -'- The above is correct Signature For form preparation seè Procedures Man Drilling, Pages 86 an API: ARCO W.I. 56.0000 rate Hour Prior status if a W.O. 12/11/87 1815 Complete record for each day reported NORDIC 1 ) RUNNING COMPLETION 7"@ 7260' MW:10.0 NaCl/NaBr MOVE RIG FROM 3H-8 TO 3H-9. ACCEPT RIG @ 1815 HRS, 12/11/87. NU BOPE. PERFORATE 7" CASING @ 7000'-7006', 7010'-7016'. (W/2 SPF 120 DEGREE PHASING) RUNNING 3-1/2" COMPLETION ASSEMBLY. DAILY:$51,898 CUM:$1,150,361 ETD:$1,150,361 EFC:$1,603,000 ) RIG RELEASED 7"@ 7260' MW:10.0 NaCl/NaBr FINISH RUNNING 3-1/2" AB-MOD COMPLETION ASSEMBLY. ATTEMPT TO SET PACKER. BALL NOT ON SEAT. WORK TBG TO GET BALL ON SEAT. ATTEMPT TO PRESSURE UP FAILED. PU ON TBG. APPEARED TO HAVE LOST PACKER. NU BOPS. NU AND TEST TREE. OPERATIONS SUSPENDED. RIG RELEASED @ 2200 HRS 12/12/87. DAILY:$127,977 CUM:$1,278,338 ETD:$1,278,338 EFC:$1,603,000 ) POOH WITH TUBING 7"@ 7260' MW:10.0 NaCl/NaBr MOVE BACK ON 3H-9 FROM 3H-IO. ACCEPT RIG @ 1945 HRS 12/13/87. NU BOPS. CIRC OUT DIESEL. POOH WITH 3-1/2" COMPLETION ASSEMBLY. DAILY: $36, 075 CUM:$1,314,413 ETD:$1,314,413 EFC:$1,603,000 ) RIH TO LDDP FINISHED POH WITH 3-1/2" TAIL PIPE ASSEMBLY. FULL SAME. DAILY:$26,925 7"@ 7260' MW:10.0 NaC1/NaBr COMPLETION ASSY. FISH OUT PACKER AND RECOVERY. RIH WITH 3-1/2" DP TO LD CUM:$1,341,338 ETD:$1,341,338 EFC:$1,603,000 '.\ . :,~' ';S-'<. ~ ."w ~r" ~ \i.,!i ~'" '1. ~ Rt\,t\ ~ \,.~\b .^' " \ r\ r \ .' .'. l) .j ,<-\.' ,,: 'o} ',,-"';' COnliH\SSlUn ;1 rro,s C-.Jì!"'" u. Ì~~cnotalJe Date Associate Engineer Title /2-21 -8 Ifi' . - --- .. ~ ARCO Oil and Gas Company ~, "', Daily Well History- Final Report !~~tructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an oHiclal test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation If space is available. Accounting cost center code District ARCO Alaska, Inc. County or Parish NORTH SLOPE-KUPARUK State AI< Field Lease or Unit KUPARUK RIVER FIELD ADL: 25531 3H-9 Iwell no. Auth. or w.o. no, Title COMPLETE & PERFORATE API: 50-103-20086 12/11/87 [Total number of wells (active or inactive) on this cost center prior to plugging and abandonment of this well Hour 181.5 I Prior status If a W.O. Operator ARCO A.RCo. W.I. 56.0000 Spudded or W.O. begun ACCEPT Date Date and depth as of 8:00 a,m. Complete record for each day reported NORDIC 1 12/16/87 ( TD: 7310 PB: 7159 (WLþ) SUPV:SS/DJ ) RIG RELEASED 7"@ 7260' MW: 6.9 DIESEL POOH LDDP. RAN 213 JTS 3-1/2" 9.21 J-55 BTC AB-MOD IPC TUBING. TAIL @ 6724'. ND BOPE. NU TREE & TEST. DISPL. W/DIESEL. RELEASE RIG @ 0300 HRS 12/16/87. (SSSV @ 1807', HB PKR @ 6652') DAILY:$29,606 CUM:$1,370,944 ETD:$1,370,944 EFC:$1,603,OOO ~!~:(~E\ 'ED .,... """ Þ. PC! \ ..J;' \.. .' t.,' . , :-. () Old TD New TD r. """"",,"SSk.n " ',"'j (t. (."15 Cone. l./u¡¡HH ¡VU ,~,""",'.:¡C.'-"" - PB Depth C ,.~ 1\nc..-.., Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoi r Producing Interval all or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signature k /xc.; Date /2,21 -8 Title Associate Engineer For form preparation d distribution, see Procedures Manu, Section 10, Drilling, Pages 86 and 87. ------ .~ -^- ARCO Alaska, Ir,í~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ Date: December 24, 1987 Transmittal II 7041 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-lll9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3H-9 ~ 3H-9 '",. 3H-8 '--.....; 3 H - 8 Colville Stratigraphic High-Resolution Dipmeter Colville MSD Computations Colville MSD Computations Colville Stratigraphic High-Resolution Dipmeter 11-27-87 11-27-87 10-23-87 10-23-87 1172530 1172530 1/72476 1172476 DISTRIBUTION: f) /'~~. ~ 2 ~c§it-) L'~"'~ 'í D.t0a9 Cons. commission ..'-4 Anchorage Receipt Acknowledged: BPAE (+sepia) State of Alaska (+sepia) Unocal (+sepia) SAPC (+sepia Dick Owens/Jerry Veldhuis AReo Alaska. Inc. is a Subsidiary 01 AtianticRichlieldCompany ARCO Alaska, In! Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ( ~~ ~~ Date: December 24,1987 Transmittal": 7035 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3H-9 ~ 3H-9 "-.; 3H-9 .~ Martin- 3H-8 "'" 3H-8 . Colville OH Lis Tape Colville SEDT Result Tape Colville PSI EDT Tape 3H-9 Colville FMS Field Tape Colville SHDT PSIEDT Tape Colville Results Tape 11-27-87 11-27-87 11-27-87 11-28-87 10-23-87 10-23-87 1/72528 ...,..,,- 1172530 i' . 1/72530 .,t.' 1/7'253,-'~~/ " "72476-" 1/724 76.~e. ,) ',,' \)~~ ~~ '\' 0 . \ ~ t. t t \'v t 311 - r Eá£J3J2J: #-tJ 3<5" '/ 7 - ð rYJ - S - :3 7 tJ rJ - 4t ð ð"Ò 3 H-C¡ SflJ)T Resttlf '# tJ3S7?'- tJ¡Oen-s - .3 7¿Tð- </ðð""õ ðf!--9 ~ #-0.35;>9 - Ó)?~n -S - '174 ~ '7J,;z 311-8' ~dF{J35¿::Ò-C? £ Et~."V~~ 30 r g-óc (3 ~E67i8 ,,_>C. 0 ;3 J./--- Ff s II [). T f:/ s:r £ D # . J"."jaska on & Gas Gems. Commission YI/V1'---¡--"-l~I (/3 $R / - 0 Pen -- Anchorage / ¿;~Jd ??-3$¿Lþ Receipt Acknowledged: Date: DISTRIBUTION: M. Stanford BPAE SAPC Unocal State of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ,~ ~ STATE OF ALASKA ALAS. ." OIL AND GAS CONSERVATION COMh...:>SION APPLICATION FOR SUNDRY APPROVALS 99510-0360 5. Datum elevation (DF or KB) KB 7 ' 6. Unit or Property name Ku aruk River Unit 7. Well number 3H-9 ~ vf;. ~o £ IÚ( 1. Type of Request: Abandon [] Suspend [] Operation Shutdown rX Re-enter suspended well D Alter casing 0 Time extension [] Change approved program 0 Plugging 0 Stimulate [] Pull tubing [] Amend order C Perforate 0 Other !~ 2. Name of Operator ARCO Alaska Inc. 3. Add ress P. O. Box 100360 Anchorage, AK 4. Location of well at surface 1347' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1341' FSL, 1808' FWL, Sec.12, T12N, R8E, UM (approx) At effective depth 1454' FSL, 17831 FWL, Sec.12, T12N, R8E, UM (approx) At total depth 1444' FSL, 1801' FWL, Sec.12, T12N, R8E 11. Present well condition summary Total depth: measured true vertical feet 8. Permit number rox) 9. API number 50- 10. pool Ku aruk River Oil Pool 7310'MD 6377'TVD feet feet Plugs (measured) None Effective depth: Conductor Surface measured 7168'MD true vertical 6236'TVD Length Size 80' 16" 3465' 9-5/8" feet feet Junk (measured) None Casing Cemented Measured depth True Vertical depth 7" 225 sx AS I 1200 sx AS III & 400 sx Class G Top job performed w/85 300 sx Class G 115'MD 3500'MD 115'TVD 3034'TVD Production 7225' sx AS I 7260'MD 6327'TVD Perforation depth: measured None R~ECE\VED true vertical None ". ", (, ,> 'f" ,-,.c"l"./I'~lì " "t, ,-', , I" Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None , 0., & Gas Cons. Commïssio Þ\\3ska II '] Anchoraae 12.Attachments Description summary of proposal D Detailed operations program C BOP sketch C Well Hi stor 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Date 12.,/~..B Title A Commission Use Only (Dani) SA3/28 Notify commission so representative may witness Approval No. -J ~ 9 3 D Plug integrity Ap~r~ T~py D Location clearance Returned ~ W'-orh ~ /;; - /18 - 81 48 J'òra NoliL-jj¡¿'j. t)~;~ l~i3L/.¿?/ ORIGINAL SIGNED BY by order of' , Approved by LONNIE C. SMITH Commissioner the commission Date/cf-/8 - If Form 10-403 Rev 12-1-85 ~ Submit in triplicate 10/ Conditions of approval .' .':"'""," ~7,' .. . :", ._.:.. .".""1:-. .' ... ;." . well '8 IPiiClded '0'. WorkOM' opellltlona ... 81---' ; ;;~;c¥~s:::~~> ,ìi};,%;; /:~; '. ':; . ".'.'?"7ç;Jr;!f/!FilÆ¥~;,: ',. .~~~~~«,,-~:': -- ¡';J~I~"i/íIIII1iiri " ..", ' ¡~;:~~,~~'ì:~\.:>;. ' """,p'l'i~'iï: "Y"':>~" ',,:"'1'1120/"" ( 3 !D1 3534' ( 10 9) SUPV:HP ",'" "; 11/21/87 ( TD: 3534' ( SUPV:HP 4 11/22/87 ( 5 Tth 4833' ( 12 9) SUPV:RP 11/23/87 ( 6) TD: 6101' ( 12 8) SUPV:HP 11/24/87 ( TD: 6868'( SUPV:HP 7) 7 7) 11/25/87 ( TD:6911' ( SUPV:HP 8) 4 ) --"'-, SIGnature , , . " .. '.. St...:.~. ,.' .. .' " "':',0.::';. ".i'" ": . '. ,"', ", 'c.,," ,"4.iIIt....a-'" "',-:",' :":".~;¡O:" , "',.,._~~~~!.~-*'~,;:' :D".~.)J..u Í1øå,:'rl 242' TO 1155,1.' '~..', . :",' .~~:DaItLBD.FI,1155" TO 2455'. " D~ILY.:$U..271 CtJM:$110,301 £1'0:$110',301 , 'J ' ,,'" ' .,<~ " f >," MAKING CONDo RUN 16" 8 115' MW: 9.2 VIS: 4-' NAVI-DRILLED 12-1/4" HOLE TO 3534'. CIRC. & CONDo HOLE FOa LOGS. DROPPED SURVEY AND PUMPED DRY JOB. POR & LD BHA. RIH W/DIL/SFL/SP/GR/LSS. HIT TIGHT SPOT/BRIDGE @ 2683'. POH. MU CLEAN-OUT BHA & RIH. HIT BRIDGE @ 2683'. WORK PIPE AND RUN TO BOTTOM. CIRC. TO BOTTOM. DAILY:$50,042 CUM:$160,343 ETD:$160,343 EFC:$1,763,343 0) PUMPING TOP JOB 9.875"@ 3500' MW: 8.5 VIS: CIRC HOLE CLEAN. ATTEMPT TO LOG COLVILLE SANDS. COULD NOT GET LOGGING TOOLS BELOW 2850'. RD LOGGERS. RUN 88 JTS 9-5/8" CSG. 36# J-55 BTC. FC @ 3418 FS @ 3500. CMT WITH 1200 SX AS III LEAD CMT AND 400 SX CLASS G TAIL CMT. CIP @ 0330 HRS. PUMPING TOP JOB. DAILY:$54,734 CUM:$215,077 ETD:$215,077 EFC:$1,603,000 DRILLING PUMP 85 SX ASI 4833. DAILY:$172,774 f'" 9.875"@3500'MW:8.9VIS:33Íí,é ß"" TOP JOB. TEST BOPE. NAVIDRILL 8 1/2" HOLE TO ~ on " 1 CUM:$387,851 EFC:$1,603,000 ETD:$387,851 DRILLING 9.875"@ 3500' NAVIDRILL 8 1/2" HOLE TO 6101. MW: 9.0 VIS: 31 ',,:" DAILY:$45,686 CUM:$433,537 ETD:$433,537 EFC:$1,603,000 POOH FOR CB NAVIDRILL 8 1/2" NAVIDRILL 8 1/2" DAILY:$92,174 9.875"@ 3500' MW: 9.9 VIS: 48 HOLE TO 6513'. CHANGE OVER TO KCL MUD. HOLE TO 6868'. CUM: $525,711 ETD:$525,711 EFC:$1,603,000 CORING 9.875"@ 3500' MW:10.0 VIS: 51 POOH LD DRILLING ASSEMBLY. PU CORING ASSEMBLY. CORE 8- 1/2" HOLE TO F~- 6911'. DAILY:$66,747 CUM:$592,458 ETD:$592,458 EFC:$1,603,OOO Title Associate Engineer 1 ! ¡ ¡ /~. 8- ~~ ~, Daily Well History-Interim A tla nticRichfieldCom pan y Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State ARCO Alaska, Inc. NORTH SLOPE-KUPARUK AK Field Lease or Unit Well no. KUPARUK RIVER FIELD 3H-9 Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress DOYON 14 11/26/87 ( TD: 6971' ( SUPV:JP L/D CORE FINISHED TIH. LD SAME. DAILY:$59,540 ) 60) 9.875"@ 3500' MW: 9.9 VIS: 45 CORED FROM 6911'-6971'. POOH WITH CORE AND --- ETD:$651,998 EFC:$1,603,000 CUM:$651,998 11/27/87 ( 1 ) TD: 7059' ( 88) SUPV:JP MU BRA 9. 875"@ 3500' MW: 10.0 VIS: 44 FINISHED LD CORE '2. MU NEW CORE BBL AND TIH. CORED FROM 6971'-7031'. POH. LD CORE 13. MU NEW CORE BBL AND TIH. -. CORED FROM 7031'-7059'. POH AND LD CORE 14. MU NEW BRA. DAILY:$42,664 CUM:$694,662 ETD:$694,662 EFC:$1,603,000 11/28/87 ( 1 ) TD: 7310' ( 51) SUPV:JP E-LOGGING W/SCHLUMBERGER 9.875"@ 3500' MW:10.0 VIS: 52 TIH. DRILLED FROM 7059'-7310'. CIRC. AND CONDo HOLE. SPOTTED DIESEL PILL & ATTEMPTED TO POH. TIGHT @ 7100'. WORKED PIPE. TIH. CIRC. AND CONDo MUD. SPOTTED DIESEL PILL. POOH. RU SCHLUMBERGER AND RAN DIL/SFL/SP/CAL/GR/FDC/CNL. DAILY:$86,112 CUM:$780,774 ETD:$780,774 EFC:$1,603,000 11/29/87 ( 1 ) TD: 7310' ( 0) SUPV:JP REAMING 9 . 875 " @ 3500' MW: 9. 9 FINISHED RUNNING OPEN HOLE LOGS. TIH, CUT DRILL TO 6800'. REAM TO BOTTOM. (RAN FMS & RFT) DAILY:$51,417 CUM:$832,191 ETD:$832,191 VIS: 39 LINE. TIH EFC:$1,603,000 11/30/87 ( 1 ) TD: 7310' ( 0) SUPV:JP FINAL CUT ON 7" CASING 7"@ 7260' MW: 9.9 VIS: 40 FINISHED REAMING TO BOTTOM. CIRC. AND CONDo MUD. SPOT DIESEL PILL. POH & LD DP AND BHA. RU AND RUN 7" CASING (166 JTS, 26#, J-55, BTC) WITH SHOE @ 7260'. CMTD W/300 SX CLASS G CMT. BUMPED PLUG TO 3500 PSI. CIP @ 0300 HRS, 11/30/87. ND BOPE. MAKE FINAL CUT ON 7". DAILY:$258,272 CUM:$1,090,463 ETD:$1,090,463 EFC:$1,603,OOO '.~ é"" ,"'"' ~ f"", t j ¡ 'Y' ~ ~,"' . \ ~....' ~ "C.-" ..,. " . f'\. ~ i -~-. "ø' , ,\'\ --"J- . i.- '" . COL..", -, ' L~JÍ\'.J> , ,\ &. l1~i~'¡ - " \,.. ,,'It':'-, \J ,I :"':; ~\\,;.._-", The above is correct Signature /z q-8 For form preparation and see Procedures Manual Drilling, Pages 86 and Associate Engineer Date " Titie ~ ~, ~' i .. Å:> ~< . ~. -"1.1" j";,.',, ,,--: . <'- ,,>' , --:.-"'-1 " ; )' ..j j '-"I ," ::;'L~~; '."C~'_:'.""-.-,.','I~,-.,',".[,c,.','" ' " - ;:;:':' -': ","'-", ,,' ~",,~,,' ,~",',' ;,~: " "'¡ ,. ~ ~ J. [- -. /~ .~ ~ 1 'i , d WGo.:t I..VV ~vuy QU~ WQ.:t U""Q""=~. ARca:ro1l*ånd Gas Company <> Daily Well History - Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "FInal R.porr' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not requir~d upon eompletlon, report completion and representative test data in blocks provided. The "Fina' Report" form may be used for reporting the entire operation If space is available. Accounting cost center code District County or Parish NORTH SLOPE-KUPARUK Lease or Unit ADL: 25531 Title DRILL API: 50-103-20086 State AI< ARCO Alaska, Inc. Iwell no. Field KUPARUK RIVER FIELD Auth. or W.O. no. 3H-9 AK2521 Operator A.RCo. W.I. 56.0000 otal number of wells (active or inactive) on thls cost center prior to plugging and abandonment of this well Hour I Prior status if . W.O. 0500 I ARCO Spudded or W.O. begun Date SPUD Date and depth as of 8:00 a.m. 11/18/87 Complete record for each day reported DOYON 14 12/01/87 ( 1) TO: 7310'( 0) PBTt>: 71.8' SUPV: JP RELEASED RIG 7"@ 7260' MW: 10.0 VIS: -- INSTALLED PACKOFF. NU TREE AND TESTED TO 3000 PSI. INJECTED 60 BBLS DIESEL INTO 3H-6 FOR FREEZE PROTECTION. SECURED WELL AND RELEASED RIG @ 0945 HRS, 11/30/87. DAILY:$8,000 CUM:$1,098,463 ETD:$1,098,463 EFC:$1,603,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM .X'iength Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature Date Title /2J1-ð7 Associate Engineer For form preparatlo see Procedures Man Drilling, Pages 86 an ~ -"'~~ -.'~ e" w ~,~ Date: ARCO Alaska, Inc. .---, Post Offi/-" " 100360 Anchora~_, . ,.dska 99510-0360 Telephone 907 276 1215 December 10, 1987 Transmittal # 7033 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 .~/---. Transmitte4 herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ....... 3 H - 9 ~ 3H-9 '-'3H-9 ~ 3H-9 ~ 3H-9 ~ 3H-9 ~3H-9 '" 3H-9 ........ 3 H - 9 ~ 3H-IO ........ 3 H -1 0 ~3H-IO Cyber1ook 11-29-87 Formation Micro-Scanner 11-27-87 5" Dual Induction 11-27-87 2" Dual Induction 11-27-87 2" & 5" Porosity FDC 11-27-87 Interpretation Repeat Formation Tester 11-29-87 Raw Data Repeat Formation Tester 11-29-87 2" & 5" Raw Data FDC 11-27-87 Raw Data Repeat Formation Tester 11-29-87 2" & 5" Dual Induction 12-5-87 2u & 5" Porosity FDC 12-5-87 21: & 5" Raw FDC 12-5-87 6700-7200 6750-7074 1000-7306 1000-7306 6650-7280 6873-7051 3808-3881 6650-7280 6873-7051 3021-6740 3021-6715 3021-6715 ~~ ~~ Alaska 011 & Gas Cons. CoIlUJÜSSl8l1 . Anchorage Receipt Ac~now1edged: DISTRIBUTION: NSK Date: ~ Drilling D & M State of Alaska (+sepia) Franzen L. Johnston (vendor package) ARC a Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany ~~ , ARCO Alaska, In" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: December 10, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-lll9 P.O. Box 100360 Anchorage, AK 99510-0360 .-_. Transmittal # 7030 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2" Dual Induction .... 11-27-87 1000-7306 '0..... '( l,',. T "- ,--. - Receipt Acknowledged: ~~ ~~ '.I\.bsk'U au & Gas Cons. GommiSSlolW Anch~rag6 . Date: DISTRIBUTION: BPAE (+sepia) SAPC (+sepia) .-!!!118 .. - Unocal (+sepia) ~~12'a~¡?ttJi7Jr-. ~.~,%1~~.!~~~.i. ARca Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany ~ ~.. , ----, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ Date: December lOt 1987 Transmittal # 7028 RETURN TO: ARCO A1askat Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchoraget AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. " 3H-3 ~ 3H-9 OH Lis Tape and Listing Oh Lis Tape and Listing 11-15-87 11-27-87 #72501 1/72527 1\1aska 011 & Gas ~ons.Gommlâo.n Anchorag.$ Receipt AcKnowledged: Date: DISTRIBUTION: M. Stanford State of Alaska .' ARCO Alaska, Inc. is a Subsidiary 01 AtianticRlchlieldCompany ~- ------ ARCO Alaska, In\. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: December 10, 1987 Transmittal #7031 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. " 3H-9 - 3H-9 -.... 3H-9 , 3H-9 3700-4001 1000-7306 3700-4000 3700-4000 Colville Colville Colville Colville ()., ~ L( . ,\-,,- .. .... ~~ ~~ J\!aska Oil & Gas Cons. Commisaløn Anchorag~ Receipt Acknowledged: Date: DISTRIBUTION: NSK Drilling Geology D & M Plano BPAE (+sepia) SAPC (+sepia) Unocal (+sepia) State of Alaska (+sepia) ARCO Alaska. Inc. is a Subsidiary of AtianticRichfieldCompany ,~'" - -- October 28,1987 Telecopy: (907) 276-7542 Mr. J. B. Kewin Regional Drilling ARCa Alaska, Inc. P. o. Box. 100360 Anchorage, Alaska Engineer 99510-0360 Re: Kuparuk River Unit 3H-9 ARCO Alaska, Inc. Permit No. 87-112 Sur. Loc. 1347'FNL, Btmhole Loe. 1265'FSL, 281'FWL, Sec. 12, T12N, R8E, UM. 1852'FWL, Sec. 12, T12N, R8E, TIM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ;;tver;,; t.r. .Ul. ~'irrs ~ t .'~, { ,¿/ \ >. 1- (-.{~."V^\./VV--.t""'-' .' ,. V\, Lonnie C. SrrÜ. th Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Mr. Doug L. Lowery Littan Core Lab /~7 -//;¿ 8005 Schoon Street Anchorage. Alaska 99518-3045 (907) 349- 3541 U~ P"" ""R' r ~,/ II ï i ;,,t r,"" , . ,,,- \.Ut ¡'i. ".U., "',..\ In ("\,P f",~.tN. 'T ' ;.¡",,}t'inf... p"! -~ 'q""'r"- "', '"" . c.,';" CORE ANALYSIS REPORT Arco Alaska, Inc. KRU #3H-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska 22-Feb-88 - , ~ I TABLE OF CONTENTS 1 --1 I. SECTION A - SUMMARY OF PROCEDURES 1.} Introduction ...J 2. } Methodology a. Core Gamma Surface Log b. Laboratory Sampling -~ c. Laboratory Procedures 3.} Special Conditions .-J II. SECTION B - CORE ANALYSIS RESULTS - TABULAR DATA _J 1.} Conventional Analysis Results 1 2.} CMS-200 Overburden Pressure Analysis Results 3.} Detailed Lithological Descriptions , III. SECTION C - CORE ANALYSIS RESULTS - GRAPHIC DATA 1.} Correlation Coregraph IV. SECTION D - APPENDICES 1.} Refractive Index vs. API Gravity Plot 2.} oil Correction Chart 3.} Technical Paper - Automated Core Measurement System for Enhanced Core Data at Overburden Conditions (Keelan) 4.) Wellsite Core Report 5.) Well site Handling Procedure 6.) Shipping and Receiving Transmittals 1 Littan Core Lab 8005 Schoon Street Anchorage. Alaska 99518- 3045 (907) 349- 3541 1 1 ~ ¡ I 1 1 SECTION A SUMMARY OF PROCEDURES , Arco Alaska, Inc. KRU #3H-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska 22-Feb-88 .~ , 1 1 ,-. ..:a... ..:a... .-1-" INTRODUCTION ...... ..L. Core Lab personnel at the drill site supervised the processing and preservation of the KRU #3H-9 core. Well site handling procedures are explained in the Appendix. Whole core samples from the KRU #3H-9 well were brought to the Core Laboratories Anchorage facility for core analyses. The following is an outline of the procedures used in analyzing the KRU #3H-9 core samples. ,-1. METHODOLOGY ..L Core Gamma Surface Log ....J.. Gamma radiation was measured on the entire core using the Core Lab Surface Gamma Logger instrument. The results are reported on the Core Analysis Correlation Coregraph. ....L Laboratorv Sampling Plugged Samples ~ , A one inch diameter plug sample was removed at half foot intervals in cores number one and two. The first plug from each foot had fluids determined by Dean-Stark extraction, and the second plug was for porosity and permeability measurements only. This was to minimize damage and any removal of core sections that is required for the Conventional Summation of Fluid Analysis which was performed on cores number three and four. One inch diameter plugs were drilled at one foot intervals for porosity and permeability measurements on cores number three and four. All plugs were taken from the center of each section and parallel to the bedding strike, with brine (KCL) used as the bit coolant. .-l - Retort samples - Approximately 150 gram sample was removed adjacent to the plug for fluid saturation and API gravity measurements by retort in cores number three and four only. To minimize invasion effects the sample was taken from the center of the core. ~ ..:a... Laboratory Procedures ,.JL.. Porosity .-L. Grain volumes were determined by a Boyle's Law - Heise Gauge Helium Porosimeter. Bulk volumes were measured by mercury displacement. .-L Permeability ~ Horizontal permeability to air was measured using a steady state permeameter with a 400 psig. boot pressure. ..L. Porosity and Permeability - Overburden Conditions , In order to simulate reservoir stress conditions, plug samples were run at requested overburden pressures in the CMS-200 Automated Core Measurement System. For each sample, a measured Klinkenberg equivalent liquid permeability, an estimated air permeability, and a helium porosity is reported for overburden pressures of 1000 and 3000 psig. ..L , Core Laboratories is pleased to provide the overburden porosity and permeability data performed on these plug samples at no additional charge. These values should prove most helpful in the evaluation of the KRU #3H-9 well, as they are more representative of porosity and permeability at formation depth. - - Fluid Saturation Measurements Cores Number One and Two ---1 - Fluid saturations were performed by the Dean-Stark method. Plug samples were cleaned of all fines resulting from the sampling process. Fresh weights were measured, samples were placed in thimbles, and then loaded into plug size Dean-Stark equipment for water recovery a minimum of 48 hours. Samples were removed and hydrocarbon extraction was performed following the guidelines listed under Hydrocarbon Extraction. Cores Number Three and Four Of the 150 gram sample, 100 grams was broken into "peanut" size pieces for the retort process. The 100 gram samples were retorted in a conventional retort oven at 400 deg. f. for 40 minutes , when an initial water reading was measured. The temperature of the oven was then increased to 1200 deg. F. for approx. 40 minutes. The remaining piece is used for bulk and gas ,..... volume measurements. Bulk volume for each sample was measured by mercury displacement. Gas volume for each sample was determined by mercury injection at 750 psig. ~ * Observed oil readings were corrected for coking using the oil correction chart in section D. -"- -->-- oil Gravity Analysis (cores three and four only) The refractive index of the recovered oil was measured every fifth foot and the API gravity (60 deg. F.) was determined using the appropriate correlation chart derived from previously analyzed Kuparuk crude samples. See section D. ~ Hydrocarbon Extraction . -->- The plug samples were placed in a toluene centrifuge extractor for hydrocarbon removal a minimum of three days, or until no fluorescence was visible. Once cleaned, the samples were dried in a convection oven for a minimum of 24 hours at 220 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. - Special Conditions - Wellsite core photography was performed on each core by the Core Lab technician utilizing the Wellsite CorePhoto unit. The core was photographed in white light with 12 feet of core per 8 x 10" print. One set of wellsite photographs was submitted. Arco Alaska representatives were present for the sampling of cores number one and two at the Anchorage laboratory. The cores were depreserved, quickly sampled and described, and then represerved following the core preservation guidelines found in the appendix. As directed, selected preserved whole core sections were removed and shipped to Terra Tek Inc. Actual depths of the core sections shipped are found in the appendix. -, .....JI I Littan Core Lab ~ I ,-JI. .....;J. J J J , , - - 8005 Schoon Street Anchorage. Alaska 99518-3045 (907) 349- 3541 SECTION B CORE ANALYSIS RESULTS - TABULAR DATA Arco Alaska, Inc. KRU #3H-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska 22-Feb-88 /g7 -/(2 KRu 311 ~ 9 r .. r- j. Conventional Analysis Results COR E LAB 0 RAT 0 R E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP- 3 -1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts TLS,TDT A sTAR.K North Slope, Alaska Location : API No : -7l)EAtJ - CONVENTIONAL CORE ANALYSIS EO'(Lt.s L-AW Á SAMPLE E ~ DEPTH PERM MD He OIL % WTR % API GRAIN - 'DE¡.J.S" I,Y K NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCR I PT! ON ---.....- - -.. .. - .. .. ---......... - - -... - .... .. .. - .. -..... .. .. .. .. ..--~-_..........._........... - .. .. - ... ....- .-............... ./ 101A 6868.2 <0.01 14.9 56.3 41.4 3.39 SS,LTOLV BRN,VF-VCGR,PRED FGR,MNR GRNLS,PSRTD,SBRS-RS,WCONS,POSS SID-ANK 1018 6868.7 <0.01 13.3 3.23 SS,GYOLV,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCMTD,POSS SID-ANK 102A 6869.2 0.02 13.5 56.2 42.8 3.10 SS,GYBlK,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCMTD,POSS SID-ANK 102B 6869.7 0.01 12.2 3.06 SS,GYBLK,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCMTD,POSS SID-ANK 103A 6870.2 0.02 13.5 61.3 28.1 3.12 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCMTD,POSS SID-ANK,MNR VUGS 1038 6870.7 0.03 11.7 3.01 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCMTD,POSS SID-ANK,MNR VUGS 104A 6871.2 0.10 18.8 35.0 43.0 3.17 SS,OLVGY,VF-CGR,PRED FGR,MOD SRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 1048 6871.7 0.78 22.6 3.14 SS,OLVGY,VF-CGR,PRED FGR,MOD SRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 105A 6872.2 0.49 21.3 33.6 48.0 3.18 SS,OLVGY,VF-CGR,PRED F-MGR,MOD-WSRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 1058 6872.7 0.06 19.5 3.13 SS,OlVGY,VF-CGR,PRED MGR,MOD SRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 106A 6873.2 5.02 27.9 30.3 45.6 3.16 SS,OLVGY,VF-CGR,PRED F-MGR,MOD-WSRTD,SBANG-SBRD,MOD CONS,POSS SID-ANK,MNR VUGS 106B 6873.7 27.27 27.4 2.97 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBANG-RD,Sl FRI,POSS SID-ANK 107A 6874.2 51.88 30.0 38_6 37.0 3.03 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SlFRI-FRI,POSS SID-ANK 1078 6874.7 1.73 20.0 3.14 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SLFRI-WCMTD,POSS SID-ANK 108A 6875.2 0.93 21.9 32.7 47.2 3.18 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 1088 6875.7 0.09 18.2 3.09 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 109A 6876.2 1.48 22.9 30.3 50.8 3.14 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 1098 6876.7 12.66 22.5 3.12 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,S8RD-RD,MOD CONS,POSS SID-ANK 110A 6877.2 12.11 23.5 33.0 48.6 3.12 SS,OlVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,MOD CONS,POSS SID-ANK 1108 6877.7 43.66 25.3 3.05 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,MOD CONS,POSS SID-ANK 111A 6878.2 62.18 24.1 27.8 49.9 3.12 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,MOD-WCONS,POSS SID-ANK 1118 6878.7 44.99 21.8 3.11 SS,OLVGY,VF-CGR,PRED F-MGR,WELL SRTD,SBRD-RD,MOD-WCONS.POSS SID-ANK ** = Denotes fractured sample Page Î .. COR E LAB 0 RAT 0 R E S [ N C . Arco Alaska, Inc_ Date : 26-Feb-88 Fi le No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M_ DESCRIPTION --...---- ..... ..... .. .. .. .. .. ...... .. ..... .. ...... .. .... ....... ... ---- ...... .. .. ..- .....--- ...............oo __.... .. .... .. .. ...... .. 112A 6879.2 123.94 27.0 21.1 53.0 3.12 SS,OLVGY,VF-CGR,PRED F-MGR,WELL SRTD,SBRD-RD,MOD CONS,POSS SID-ANK 112B 6879.8 117.91 25.9 3.07 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS-SLFRI,POSS SID-ANK 113A 6880.2 218.63 28.1 40.0 37.5 3.07 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SLFRI-FRI,POSS SID-ANK 113B 6880.7 134.20 25.1 3.04 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SLFRI-WCONS,POSS SID-ANK 114A 6881. 2 66.72 22.5 32.8 45.2 3.12 SS,OLVGY,VF-CGR,PRED F-MGR,MOD-WSRTD,SBRD-RD,WCONS,POSS SID-ANK 114B 6881. 7 21.36 21.6 3.11 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK 115A 6882.2 8.57 16.1 32.7 43.2 3.19 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK,VUGS 115B 6882.6 200.40 29.7 2.99 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,FRI,POSS SID-ANK 116A 6883.2 69.46 26.8 26.4 48.8 3.08 SS,LT OLVGY,VF-CGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 116B 6883.8 183.01 28.0 3.04 SS,OLVGY,VF-MGR,PRED F-MGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 117A 6884.2 17.49 21.4 29.0 46.2 3.13 SS,LT OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,WCONS,POSS SID-ANK 117B 6884 . 7 4.64 18.5 3.11 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK 118A 6885.2 10.92 21.6 26.6 52.6 3.14 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK 118B 6885.7 16.86 24.2 3.16 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,WCONS,POSS SID-ANK 119A 6886.2 124.83 27.4 34.2 48.1 3.10 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 119B 6886.8 123.66 22.1 3.06 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,SLFRI-WCONS,POSS SID-ANK 120A 6887_2 51.40 21.1 37.2 43.8 3.06 SS,LT OLVGY,VF-MGR,PRED F-MGR,WSRTD,SBRD-RD,WCONS,POSS SID-ANK 120B 6887.7 346.25 27.6 2.98 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 121A 6888.2 1875.69 33.2 28.8 41.2 2.87 SS,OLVGY,VF-CGR,PRED F-MGR,PSRTD,RD-WRD,FRI,POSS SID-ANK 121B 6888.7 879.54 30.4 2.89 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,RD-WRD,FRI,POSS SID-ANK 122A 6889.2 1864.39 32.4 17.4 58.1 2.73 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,RD-WRD,FRI,POSS SID-ANK 122B 6889.6 18.46 18.5 3.00 SS.OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,VWCONS,POSS SID-ANK ** = Denotes fractured sample Page 2 ) J J J __,J ,-,_1 '-- L COR E LAB 0 RAT 0 R E S , I N C . Arco Alaska, Inc. Date : 26-Feb-88 FIle No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCR I PTI ON ........ ...... .. .... .... .... --....--..- ---........ .....-.. ... .. .... ---- _..---- ..-- --..-.. -......... .. .. .... .. .. ........ .... .. ......... .. '-- 123A 6890.2 2407.07 29.1 31.2 47.2 2.68 SS,OLVGY,VF-CGR,PRED F-MGR,MOO SRTD,RD-WRD,FRI 123B 6890.8 582.57 27.9 2.78 SS,OLVGY,VF-CGR,PRED F-MGR,MOO-PSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 124A 6891.3 625.92 27.9 26.7 54.0 2.79 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1248 6891.7 344.54 27.8 2.76 SS,LT OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FRI ** 125A 6892.2 874.57 29.3 23.4 51.1 2.71 SS,LT OLVGY,VF-CGR,PRED F-MGR,MOO SRTD,SBRD-RD,FRI,POSS SID-ANK 125B 6892.7 243.57 26.7 2.80 SS,LT OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS MNR SID-ANK 126A 6893.2 37.77 11.7 28.3 41.1 2.94 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBANG-SBRD,WCMTD,POSS SID-ANK ** 1268 6893.7 94.27 23.2 2.84 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 127A 6894.2 302.56 26.2 29.7 47.2 2.77 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1278 6894.8 232.34 26.0 2.88 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK ** 128A 6895.2 223.39 24.0 33.9 58.9 2.66 SS,OLVGY,FGR,VWSRTD,SBRD-RD,FRI 128B 6895.7 135.32 25.5 2.84 SS,OLVGY,FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 129A 6896.2 55.30 23.5 27.2 48.1 2.87 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 1298 6896.7 69.35 25.2 2.88 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK 130A 6897. 1 223.71 27.5 16.5 36_0 2.77 SS,LT OLVGY,VF-MGR,PRED FGR,VWSRTD,RD-WRD,FRI,POSS MNR SID-ANK 1308 6897.8 0.05 13.4 3.03 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD-WCMTD,POSS SID-ANK,GLAUC 131A 6898.3 0.05 10.4 36.8 38.8 3.02 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK ** 1318 6898.7 0.01 10.4 3.02 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK ** 132A 6899.3 88.35 25.7 29.9 53.1 2.89 SS,OLVGY,VF-MGR,PRED VFGR,VWSRTD,RD-WRD,FRI-MOO CONS 132B 6899 . 6 213.87 30.3 2.76 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK,A8NT GLAUC ** 133A 6900.2 116.23 28.3 28.0 59. 2.79 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1338 6900.9 131.60 27.4 2.99 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK,VUGGY FRAC ** ** = Denotes fractured sample Page 3 1 I ..... ..- j ) ~-, ,~ ~ _d ____~-_....-I COR E LAB 0 RAT 0 R E S I N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % IITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .. .... .. .. .... ....--...... ..-..........-.. .. .. .... .. ..... ......- .. ...... ......... ........ .. .. .. .. .. .. .. .. .. .... .... .... ............ .... .. 134A 6901.2 251. 74 30.7 19.0 62.9 2.68 SS,DK GRNGY,VF-MGR,PRED FGR,IISRTD,SBRD-RD,FR 134B 6901. 7 152.65 29.6 2.72 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI ** 135A 6902.2 0.05 6.5 33.4 58.9 3.05 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK 135B 6902.7 4.15 11.4 3.00 SS,OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VIICMTD,POSS SID-ANK,ABNT GLAUC. 136A 6903. 1 13.88 20.5 38.6 37.2 2.90 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBANG-SBRD,IICONS,POSS SID-ANK 136B 6903.7 130.45 27.8 2.68 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI 137A 6904.2 197.53 27.1 19.5 56.5 2.72 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI ** 137B 6904.7 164.90 29.1 2.71 SS,DK GRNGY,VF-MGR,PRED F-MGR,IISRTD,SBRD-RD,FRI 138A 6905.3 19.81 24.3 27.4 58.2 2.79 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 138B 6905.8 <0.01 7.4 3.17 SLTST,LT OLVGY,VSDY,VWCMTD,POSS SID-ANK,ABNT GLAUC 139A 6906.4 38.23 26.1 24.5 56.3 2.81 SS,OLVGY,VF-MGR,PRED, FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 139B 6906.7 <0.01 10.2 3.16 SS,LT OLVGY,VF-FGR,VWSRTD,SBANG-SBRD,WCMTD,POSS SID-ANK,ABNT GLAUC 140A 6907.3 18.07 23.0 22.1 53.7 2.97 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,WCONS-SLFRI,POSS SID-ANK,ABNT GLAUC 140B 6907.7 12.22 25.5 2.87 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK,ABNT GLAUC 141A 6908.0 NO ANALYSIS - RUBBLE 141B 6908.5 1.91 18.5 3.09 SS,OLVGY,VF-FGR,PRED FGR,IISRTD,SBANG-SBRD,SLFRI-WCONS,POSS SID-ANK,ABNT GLAUC Core #2 6911.0 - 6958.0 201A 6911.2 <0.01 4.7 10.8 68.2 3.15 SS,OLVGY,VFGR,VWSRTD,SBANG,VWCMTD,POSS SID-ANK,ABNT GLAUC,CALCXL FRAC 201B 6911.7 <0.01 4.3 3.17 SS,OLVGY,VFGR,VWSRTD,SBANG,VWCMTD,POSS SID-ANK,ABNT GLAUC 201C 6911.8 3.43 21 2.86 SS,OLVGY.VF-FGR.IISRTD.SBANG.IICONS,POSS MNR SID-ANK,ABNT GLAUC ** = Denotes fractured sample Page 4 I I I I 1 J I ~ ...... .-. .......h".. _ 0.., .....,.---0IIII -- ..... ---....- ~ COR E LAB 0 RAT 0 R E S , I N C . Arco Alaska, Inc. Date : 26-Feb-88 Fi le No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, ALaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .. .. ........ .. .. .. .. .... .... .. .. --.... .. .. .. ...... .. .... ...... .. .. ...... .. .... .. .. .. .. .... .. .. .. .. .. .. ........ .... .. .. .........--......---- ..... ...... - . 202A 6912.2 1.98 19.5 43.1 40.2 2.72 SS,OLVGY,VF-FGR,PRED VFGR,VWSRTD,SBANG-WCONS,GLAUC 202B 6912.7 8.41 21.9 2.67 SS.OLVGY.PRED VF-FGR,WSRTD.SBANG-SBRD,W-MOD CONS,GLAUC ** 203A 6913.2 1.69 19.9 38.4 42.5 2.65 SS.LT OLVGY,VF-FGR,PRED VFGR,WSRTD,SBANG-SBRD,W-MOD CONS,GLAUC 203B 6913.7 1.77 20.3 2.66 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,W-MOD CONS,GLAUC 204A 6914.2 2.09 20.1 39.6 42.7 2.66 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD.W-MOD CONS,GLAUC 204B 6914.8 <0.01 0.7 3.16 SLTST,LT OLVGY,VSDY,VWCMTD,POSS SID-ANK,ABNT GLAUC,CALCXL FRAC 205A 6915.2 0.04 12.4 30.5 57.3 2.72 SS,LT OLVGY,VF-FGR,PRED VFGR,VWSRTD,SBANG-SBRD,WCONS CALC 205B 6915.8 0.04 12.5 2.89 SS,LT OLVGY,PRED VFGR,VWSRTD,SBANG-SBRD,VWCONS,POSS MNR SID-ANK 20M 6916.2 0.10 16.1 38.7 47.4 2.69 SS,LT OLVGY.VF-FGR,PRED VFGR,WSRTD,SBANG-SBRD,WCONS,SL CALC,GLAUC 206B 6916.7 4.82 18.1 2.75 SS,OLVGY,VF-FGR,PRED VFGR,W-MOD SRTD,SBANG-SBRD,WCONS,GLAUC ** 207A 6917.2 0.36 17.6 35.9 47.5 2.63 SS,LT OLVGY,VF-CGR,PRED VFGR,WSRTD,SBANG-SBRD,WCONS,GLAUC 207B 6917 .7 0.30 16.6 2.77 SS,OLVGY.VF-MGR,PRED FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS MNR SID-ANK ** 208A 6918.2 0.34 17.3 37.0 46.0 2.91 SS,OLVGY,VF-MGR,PRED FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS MNR SID-ANK 208B 6918.7 0.17 17.7 3.00 SS,OLVGY,VF-MGR,PRED FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS MNR SID-ANK 209A 6919.2 0.05 7.4 25.4 51.2 3.21 SS,LT OLVGY,VF-MGR.PRED VF-FGR,MOD SRTD,SBANG,VWCMTD,POSS SID-ANK,GLAUC 209B 6919.6 0.32 18.1 2.88 SS.OLVGY,VF-MGR,PRED VF-FGR,W SRTD,SBANG-SBRD,WCONS,POSS SID-ANK,GLAUC 210A 6920.2 <0.01 6.1 40.4 41.9 3.22 SS,LT OLVGY,VF-MGR,PRED FGR,W-MOD SRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK,GLAUC 210B 6920.7 3.09 23.2 2.93 SS,OLVGY,VF-MGR,PRED VF-FGR,W-MOD SRTD,SBANG-SBRD,WCONS,POSS SID-ANK,GLAUC 211A 6921.2 0.28 20.6 35.3 50.8 2.97 SS,OLVGY,VF-MGR,PRED VF-FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS SID-ANK,ABNT GLAUC 211B 6921. 7 0.33 12.5 2.67 SS,OLVGY,VF-VCGR,PRED F-MGR,PSRTD,ANG-SBANG,WCONS,GLAUC 212A 6922.2 0.50 11.4 8_9 87.4 2.65 SLTST,M-DKGY,VSDY,WCONS,VFGR BURS,MDST LAMS 212B 6922.7 0.10 14.4 2.76 SLTST,M-DKGY.ARG.WCONS.MDY LAMS.MNR PYR ** = Denotes fractured sample Page 5 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3'1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS ~ Ç"UMH AT \ON ÓF Fl-U \ \:) S <- SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .. ............. .. .. .. ......- .... .... .. ...... ........ .. .... .. ..... .. ...... .. .. .. .... ... .. .. .. ......- ..................... --.... -- ---- .............................. --.......... ---- 213 6923.6 0.04 12.2 37.2 43.9 25.7 2.65 MDST,DKGY,ARG,WCONS,SL CALC,SDY BURS,20% BDD SLTST 214 6924.7 ** 14.3 18.8 66.3 2.64 MDST,DKGY,ARG,~CONS,30% SDY LAM SLTST,SLICKS 215 6925.3 ** 13.0 12.0 81.7 18.3 2.66 MDSTMDST,ARG,~CONS,30-40% VF-FGR,~SRTD,LAM SS,MNR PYR,SLICKS,BIOTURB ** 216 6926.5 ** 15.9 27.6 33.6 2.62 SLTST,LT OLVGY,SDY,~CONS,VMIC,20-30% MDST BURS,SLICKS 217 6927.5 ** 12.9 14.4 79.1 2.68 MDST,DKGY,SLTY,MIC,~CONS,20-30%VSDY,INTBD SLTST 218 6928.7 0.86 12.2 26.5 57.4 2.68 MDST,DKGY,SLTY,MIC,WCONS,20-30%VSDY,INTBD SLTST 219 6929.2 ** 12.4 17.2 76.5 2.67 MDST,DKGY,SLTY,MIC,WCONS,20-30%VSDY,INTBD SLTST 220 6930.5 1.97 13.1 22.1 67.5 24.0 2.65 MDST,DKGY,SLTY,MIC,WCONS,20-30%VSDY,INTBD SLTST,TR PYR ** 221 6931.3 0.15 14.3 26.8 60.0 2.64 MDST,OLVGY,ARG,BIOTURB,~CONS,LAM,50% SLTY LAMS 222 6932.7 9.19 13.4 13.9 79.4 2.68 MDST,OLVGY,ARG,BIOTURB,WCONS,LAM,50% SLTY LAMS 223 6933.7 0.36 12.8 10.4 76.1 2.71 MDST,DKGY,ARG,WCONS,LAM,30% SLTY LAMS 224 6934.6 3.32 13.0 9.3 82.8 2.69 MDST,DKGY,ARG,WCONS,LAM,30-40% SLTY LAMS ** 225 6935.3 0.92 12.9 3.0 89.4 2.83 MDST,DKGY,ARG,~CONS,LAM,LAM,10-20% SLTY LAMS 226 6936.4 9.82 13.6 11.8 80.3 20.8 2.67 MDST,DKGY,ARG,BIOTURB,WCONS,LAM,30-40% SLTY LAMS ** 227 6937.5 104.81 14.4 25.4 56.5 2.64 MDST,DKGY,ARG,~CONS,BDD,30·40% THNLY BDD SLT ** 228 6938.5 0.07 13.1 23.9 61.9 2.65 MDST,DKGY,ARG,WCONS,LAM,30-40% SLTY LAMS 229 6939.7 12.09 13.1 26.3 53.2 2.62 MDST,DKGY,ARG,~CONS,LAM,40·50% SLTY LAMS ** 230 6940.7 0.03 11.9 19.2 71.6 20.8 2.65 MDST,DKGY,ARG,~CONS,LAM,MNR SLTY LAMS 231 6941. 7 0.40 14.8 2.5 92.3 2.81 SLTST,OLVGY,BDD,WCONS,MNR BIOTURB,MNR PYR ** 232 6942.5 36.18 12.9 11.8 78.8 2.69 MDST,DKGY,ARG,THNLY BDD,WCONS,15-20% SLTY LAMS 233 6943.6 3.10 13.2 10.6 78.4 2.66 MDST,GYBLK,ARG,THNLY BDD,~CONS ** 234 6944.5 ** 13.4 8.6 86.2 2.72 MDST,DKGY,ARG,THNLY BDD,~CONS.30-40% SLTY LAMS.MNR BIOTURB ** ** = Denotes fractured sample Page 6 r l- I- I t r r COR E LAB 0 RAT 0 R E S [ N C . Arco Alaska, Inc. Date : 26-Feb-88 Fi le No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .............. ------- .. .. . .. .. ... .... ...---.. .. ...... ... .. .. .. -...... .... .... .. .. .. .. ..... .. ..... ...... ....... ... .. .. .. .. .. .... ..... .. .. .. .. ..... .. 235 6945.7 0.32 13.2 4.4 87.2 15.5 2.68 MOST,GYBLK,ARG,WCONS,THNLY BDO 236 6946.5 0.16 14.1 10.4 82.0 2.81 MOST,OLVGY,SLTY,THNLY BDD,WCONS,MNR SLTY LAMS 237 6947.6 0.99 13.2 29.5 55.1 2.66 MDST,DKGY,ARG,BIOTURB,WCONS,LAMS,50% SLTY LAMS 238 6948.4 0.95 13.8 26.6 63.5 2.64 MDST,DKGY,ARG,WCONS,LAM,60% SLTY LAMS 239 6949.6 0.04 12.1 29.7 54.7 2.66 MDST,OKGY,ARG,WCONS,BIOTURB,LAM,50% SLTY LAMS 240 6950.5 6.04 15.8 20.1 73.6 15.9 2.65 SLTS,LT OLVGY,WCONS THNLY BDO,20-30% ARG LAMS 241 6951.3 0.09 11.1 25.1 68_6 2.67 MDST,DKGY,ARG,WCONS,LAM,10-20% SLTY LAMS 242 6952.7 1.39 15.1 23.6 60.6 2.65 SLTST,OLVGY,WCONS,THNLY BOO,10-20% ARG LAMS,ABNT BIOTURB 243 6953.6 2.95 14.7 26.9 50.6 2.66 SLTST,OLVGY,WCONS,THNLY BDD,20-30% ARG LAMS,BIOTURB 244 6954.2 0.24 13.8 38.1 49.1 2.66 SLTST,OLVGY,VSOY,WCONS,LAM,10-20% MOY LAMS 245 6955.7 5.35 14.9 40.4 47.2 25.7 2.67 SS,LT OLVGY,VFGR,WSRTO,SBANG-SBRD,WCONS,10-15% MDY LAMS ** 246 6956.5 122.05 23.1 52.9 13.2 2.66 SS,LT OLVGY,VF-FGR,PRED FGR,VWSRTD,SBANG-SBRD,MOD CONS 247 6957.6 217.19 24.8 38.0 27.6 25.3 2.66 SS,LT OLVGY,VF-FGR,PRED FGR,VWSRTD,SBANG-SBRD,SLFRI Core #3 6971.0 - 7030.8 301 6971.2 0.72 14.8 32.0 55.9 25.7 2.66 SS,OLVGY,VFGR,VWSRTD,SBRD,WCONS,30% OKGY,SLTY,MIC,MDST LAMS 302 6972.2 0.63 14.2 10.6 77.6 2.67 SS,OLVGY,VFGR,VWSRTD,SBRD,WCONS,30% DKGY,SLTY,MIC,MDST LAMS,TR PYR 303 6973.5 2.65 14.5 47.8 20.6 2.66 SS,OLVGY,VFGR,VWSRTD,SBRD,WCONS,20% DKGY,SLTY,MIC,MDST LAMS,TR PYR ** 304 6974.3 6.48 14.7 38.8 33.0 2.66 SS,OLVGY,VFGR,VWSRTD,SBANG-SBRD,WCONS,30% OKGY,SLTY,MDST LAMS,TR PYR ** 305 6975.3 149.82 24.6 44.5 19.6 25.3 2.65 SS,LT OLVGY,VFGR,VWSRTD,SBRO-RD,SLFRI,TR MOY LAMS 306 6976.4 122.84 24.9 54.1 14.3 2.65 SS,LT OLVGY,VFGR,VWSRTD,SBRD-RO,SLFRI,TR MDY LAMS ** = Denotes fractured sample Page 7 · I~ I- .. I~ ~ ~ ~ r r : r COR E LAB 0 RAT 0 R E S , I N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TlS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .. .................. ............... ..... . ...... ... - ...... ... .. ..... ... ... .. ... ..... ..... ....... ...... ...... ............ _...00................._.......... ................ -- ..-- ....---..-..................... 307 6977.6 2.65 15.8 43.8 31.5 2.66 SS,LT OLVGY,VFGR,VWSRT,SBANG-SBRD,WCONS,10% THNLY BOD MDST 308 6978.6 115.49 25.2 47.3 10.8 2.65 SS,OLVGY,VFGR,VWSRTD,SBANG-SBRD,SLFRI,TR MDY lAMS 309 6979.5 64.80 25.3 45.5 12.7 2.64 SS,OLVGY,VFGR,VWSRTD,SBANG-SBRD,SLFRI,TR MDY LAMS 310 6980.5 270.86 26.6 48.9 16.2 25.7 2.64 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,TR MDY lAMS 311 6981.4 124.24 26.6 52.0 12.0 2.65 SS,OLVGY,VFGR,VWSRTD,SBRD,SlFRI,TR MDY LAMS,TR PYR 312 6982.5 87.88 26.4 50.5 11.4 2.65 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,TR MDY LAMS 313 6983.2 9.26 18.9 22.8 60.1 2.68 SS,OLVGY,VFGR,VWSRTD,SBANG-SBRD,MOD CONS,20% SlTY,MIC,BDD MDST ** 314 6984.5 75.71 24.3 37.0 29.3 2.65 SS,lT OLVGY,VFGR,VWSRTD,SBRD,SlFRI,TR MDY lAMS 315 6985.2 26.39 21.1 48.7 23.5 25.7 2.64 SS,LT OLVGY,VFGR,VWSRTD,SBANG-SBRD,SLFRI,20% SLTY,MIC,BDD MDST ** 316 6986.5 53.99 24.9 54.3 10.2 2.64 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,TR MDY LAMS 317 6987.4 39.49 22.0 42.8 30.9 2.67 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,1% PYR 318 6988.4 172.13 26.0 54.0 10.1 2.64 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI 319 6989.3 34.88 22.0 55.9 14.3 2.65 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,SlFRI,MNR MDY LAMS,TR PYR 320 6990.6 7.32 14.6 14.2 76.5 10.1 2.64 MDST,DKGY,SLTY,MIC,40% OLVGY,VFGR,WSRTD,BDD SS,2-3% PYR ** 321 6991.5 23.07 23.7 53.2 12.4 2.63 SS,OLVGY,VFGR,WSRTD,SBRD,MOD CONS 322 6992.8 57.12 23.7 40.3 23.4 2.67 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,MOD CONS,TR MDY lAMS, 1-2% PYR 323 6993.8 16.93 16.9 46.1 33.8 2.66 SS,OlVGY,VFGR,WSRTD,SBRD,MOD CONS,30% DKGY,SlTY INTBD MDST ** 324 6994.2 0.89 15.8 36.2 31.0 2.66 MDST,SLTY,WCONS,MIC,30-40% OLVGY,VFGR,WSRTD,SBRD,BDD SS 325 6995.3 5.08 20.5 36.3 47.4 22.4 2.64 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,WCONS,5-10% MDY lAMS 326 6996.2 1.81 18.1 42.5 33.8 2.66 SLTST,OLVGY,VSDY,WCONS,10-20% DKGY,SlTY,VMIC,INTBD MDST 327 6997.3 0.85 13.6 50.2 21.3 2.67 MDST,DKGY,SLTY,VMIC,20% OLVGY,VSDY,BDD SlTST,1% PYR,SDY BURS ** 328 6998.5 13.35 19.3 44.0 20.2 2.64 SS,lT OLVGY,VFGR,VWSRTD,SBRD,W-MOD CONS,10% MDY lAMS,TR PYR ** ** = Denotes fractured sample Page 8 ! I 1 I I 1 '¡ ] I ~ ....... ~ ~.--' 10.-- ....-1 .......--.............. --... Iao..-..._ '. COR E LAB 0 RAT 0 R E S [ N C . Arco Alaska, Inc. Date : 26-Feb-88 FIle No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION ............ .. .... ...... .. .. --............ ------- ....... .. .. .. .... .... .. .. ..... .... ........... .. .... .. ........ .. .. .. .... .. -----......---... . .. .. ...... - - 329 6999.7 0.70 16.5 40.2 49.5 2.66 SLTST,OLVGY,VSDY,ARG,WCONS,30% DKGY,SLTY,MIC,LAM MDST,1% PYR ** 330 7000.3 0.97 19.1 39.8 24.9 23.6 2.70 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,TR MDY LAMS 331 7001.4 4.76 21.8 48.7 11.7 2.65 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,TR MDY LAMS,2-3% MDY LAMS 332 7002.4 3.01 12.5 37.3 40.3 2.64 MDST,DKGY,ARG,10-20% VFGR,SDY LAMS ** 333 7003.3 2.13 14.1 23.4 50.9 2.65 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,30-40% SDY,SLTY,LAM MDST 334 7004.3 0.49 12.3 31.0 42.3 2.67 MDST,DKGY,ARG,MIC,WCONS,15-20% VFGR SDY BURS 335 7005.5 8.01 13.9 29.6 57.1 19.1 2.64 SLTST,OLVGY,VSDY,WCONS,20% DKGY,LAM MDST 336 7006.4 4.61 14.3 29.3 59.8 2.67 MDST,DKGY,ARG,VSDY,MIC,40-50% VFGR,WSRTD,SBRD,INTBD SS 337 7007.3 15.75 13.1 35.0 58.5 2.65 MDST,DKGY,ARG,MIC,20% SDY,BDD SLTST,BIOTURB ** 338 7008.3 5.16 13.8 24.8 67.9 2.65 MDST,DKGY,SLTY,MIC,BIOTURB,15-20% VFGR,WSRTD,SBRD,WCONS ** 339 7009.4 1.02 13.0 24.5 64.2 2.66 MDST,DKGY,SLTY,WCONS,30% VFGR,WSRTD,SBRD,WCONS,INTBD SS,BIOTURB 340 7010.4 4.02 15.2 33.3 35.8 25.7 2.67 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,40-50% DKGY,SLTY,MIC,BIOTURB MDST,2% PYR 341 7011.4 6.94 16.5 41.4 39.0 2.72 SS,LT OLVGY,VFGR,VWSRTD,SBRD,WCONS,20-30% SLTY INTBD MDST,PYR FRAC 342 7012.8 8.99 18.6 51.9 16.5 2.66 SS,OLVGY,VFGR,WSRT,SBRD,MOD CONS,15% INTBD MDST 343 7013.7 3.06 14.6 23.1 57.6 2.68 MDST,SLTY,SDY,WCONS,30-40% SDY INTBD SLTST,TR PYR,SDY BURS ** 344 7014.5 3.50 14.8 48.9 20.5 2.66 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,WCONS,40% DKGY,ARG,LAM MDST 345 7015.4 8.76 13.9 44.3 23.8 24.4 2.71 MDST,DKGY,SLTY,SDY,WCONS,20% VFGR,BIOTURB ss ** 346 7016.5 1.68 15.3 39.2 34.9 2.67 MDST,DKGY,SLTY,SDY,WCONS,30-40% OLVGY,VFGR,WSRTD,SBRD,MOD CONS,INTBO SS 347 7017.3 1.48 14.8 43.7 27.8 2.66 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,WCONS,50% DKGY,HVY BIOTURB MDST,1-2% PYR 348 7018.8 2.03 13.0 41.0 31.1 2.66 SLTST,OLVGY,VSOY,WCONS,30-40% HVY BIOTURB MOST 349 7019.4 ** 11.0 35.3 34.5 2.65 MDST,DKGY,ARG,SLTY,WCONS,10-20% OLVGY,SDY MIC,BIOTURB SLTST ** 350 7020.5 4.26 15.0 27.7 46.1 2.65 SS,OLVGY,VFGR,WSRTD,SBRD.WCONS.40% OKGY,SLTY,MIC,BIOTURB MDST ** ** = Denotes fractured sample Page 9 t \ I ~ I ~ ) , ) I ) ....... ... ¡"...-,. -........ ---- .. ~ """'-- _. COR E LAB 0 RAT 0 R E S , I N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3·1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .. .. ~ .. .. .. .. .... .... ...... ............... .... .. .. .. .. ....... .. . .. .. .. .. ..... .. .. ....... .. .. ... ..... .. .. .. .. .. .... .. ......... ....... .. .. ..... .... .. .. - .. n 351 7021.2 0.13 23.3 45.6 22.2 26.9 2.96 SLTDT,OLVGY,VSDY,WCONS,20% SlTY,MIC,BIOTURB,LAM MOST 352 7022.5 3.08 15.1 40.6 37.2 2.63 SLTST,LT OLVGY,VSDY,WCONS,30·40% 8IOTURB,8DD MDST ** 353 7023.8 89.08 23.3 42.8 20.5 2.65 SS,LT OLVGY,VFGR,VWSRTD,SBRD,MOD CONS,MNR MDY LAMS,TR PYR 354 7024.7 1.55 15.1 40.1 27.9 2.71 MDST,OLVBLK,ARG,SDY,~CONS,30% VFGR,WSRTD,SBRD,INTBD SS 355 7025.5 4.68 15.9 34.3 36.9 23.2 2.63 SS,LT OLVGY,VFGR,WSRTD,SBRD,20-30% ARG,SDY,BIOTUR8 MDST ** 356 7026.6 4.29 17.7 50.1 13.7 2.64 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,15-20% 8IOTURB,LAM MOST 357 7027.5 4.07 15.6 31.4 44.9 2.67 MDST,DKGY,SLTY,SDY,~CONS,40·50% VFGR,~SRTD,SBRD,BIOTURB SS 358 7028.7 5.93 14.4 52.3 14.1 2.63 MDST,DKGY,SLTY,SDY,WCONS,30·40% VFGR,WSRTD,SBRD,MOD CONS ** 359 7029.6 9.25 16.5 32.4 53.3 2.66 SS,LT OLVGY,VFGR,~SRTO,SBRO,~CONS,30% DKGY,SOY,MIC,INTBO MOST 360 7030.6 1.21 17.6 51.7 12.9 25.7 2.66 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20% ARG,LAM MDST Core #4 7031.0 - 7058.6 401 7031.8 2.36 17.2 26.8 52.3 22.0 2.66 SS,LT OLVGY,VFGR,~SRTD,SBRD,~CONS,15·20% ARG,MIC,LAM MOST,TR PYR 402 7032.5 8.73 20.4 54.3 13.7 2.65 SS,LT OLVGY,VFGR,WSRTD,SBRD,~CONS,MNR MDY LAMS,TR PYR 403 7033.5 2.59 13.4 29.7 51.4 2.65 MDST,DKGY,VSDY,MIC,~CONS,20·35% VFGR,WSRTD,SBRD,BIOTUR8 SS ** 404 7034.5 8.46 14.6 42.7 36.1 2.65 MDST,DKGY,SDY,MIC,WCONS,30% VFGR,~SRTD,SBRD,MOD CONS SS ** 405 7035.7 5.51 13.6 25.8 66.7 15.4 2.66 MDST,DKGY,SLTY,SDY,WCOHS,20% VFGR,SDY lAMS ** 406 7036.5 4.80 15.6 28.6 51.5 21.6 2.67 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20-30% SDY MIC,BIOTUR8 MDST 407 7037.6 0.30 12.4 26.2 51.6 2.65 MDST,DKGY,SLTY,MIC,WCONS, 10·15% VFGR SDY BURS,1% PYR 408 7038.4 0.81 16.0 43.7 31.8 2.64 SS,lT OlVGY,VFGR,WSRTD,SBRD,WCONS,20% BIOTURB MDST 409 7039.5 5.12 13.9 28.7 42.7 2.65 MOST.OKGY.ARG.SDY.WCONS,20·30% VFGR,WSRTD,S8RD,BIOTURB SS ** ** = Denotes fractured sample Page 10 ~ ~ 1 ~ t I· 1· I·· ~ ¡... ~ I- r r ~ COR E LAB 0 RAT 0 R E S , I N C . Arco Alaska, Inc. Date : 26-Feb-88 Fi le No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % WTR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION ..........-- .. .... .... .... ........ .. ...... ....... .. ...... .. .. .. .. .... .... ...... .. ........ .. ..............._......oo.. __...... .... ............... ...... .. 410 7040.3 10.20 14.2 25.1 64.0 16.3 2.67 MDST,DKGY,SDY,WCONS,30% VFGR,WSRTD,SBRD,LAM SS TR PYR ** 411 7041. 2 0.20 12.7 34.4 52.8 17.5 2.63 MDST,SLTY,SDY,WCONS,10-15% VFGR,HVY BIOTURB SS 412 7042.5 4.16 11.8 38.0 42.7 2.62 MDST,DKGY,SLTY,SDY,WCONS,5-10% VFGR,SDT BURS ** 413 7043.5 ** 12.5 35.7 52.4 2.62 MDST,DKGY,SLTY,VSDY,WCONS,20-30% VFGR,BIOTURB SS ** 414 7044.2 1.34 12.7 26.7 60.1 2.64 MDST,DKGY,SLTY,SDY,WCONS,20-30% VFGR,HVY BIOTURB SS ** 415 7045.6 2.67 12.0 27.7 61.1 17.1 2.63 MDST,DKGY,SLTY,SDY,WCONS,15-20% VFGR,BIOTURB SS ** 416 7046.5 7.92 13.0 29.5 61.0 2.64 MDST,DKGY,SLTY,SDY,WCONS,15-20% VFGR,BIOTURB SS ** 417 7047.6 11.34 18.6 35.3 32.7 2.66 SLTST,OLVGY,VSDY,WCONS,10-15% BIOTURB AND LAM MDST 418 7048.5 1.64 16.7 37.7 47.3 2.65 SLTST,OLVGY,VSDY,WCONS,10-15% BIOTURB AND LAM MDST 419 7049.6 0.59 12.2 31.0 59.0 2.65 MDST,DKGY,SLTY,SDY,WCONS,10-20% HVY BIOTURB VFGR SS ** 420 7050.5 0.25 12.2 27.7 65.2 15.4 2.64 MDST,DKGY,SLTY,WCONS,5-10% BIOTURB SLTST 421 7051.3 0_28 13.3 34.4 39.8 18.7 2.65 MDST,DKGY,VSDT,SLTY,WCONS,20-30% VFGR,BIOTURB SS ** 422 7052.3 12.68 13.4 31.7 56.3 2.65 MDST,DKGY,SLTY,WCONS,20% VFGR,LAM SS ** 423 7053.2 1.54 14.7 26.8 66.9 2.64 SLTST,LT OLVGY,VSDY,BIOTURB,30% SLTY,MIC,WCONS MDST 424 7054.4 2.50 16.2 19.1 73.2 2.65 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20% DKGY,SDY BDD MDST 425 7055.3 2.13 13.9 24.3 59.9 12.6 2.65 MDST,DKGY,SLTY,MIC,WCONS,10-20% INTBD SLTST,MNR SDY BURS ** 426 7056.6 1.76 12.4 14.8 79.2 2.75 MDST,DKGY,ARG,WCONS,MNR SDY BURS,3% PYR ** 427 7057.5 ** 12.1 15.2 79.2 2.64 MDST,DKGY,ARG,SLTY,WCONS,MNR SDY BURS ** 428 7058.3 4.44 12.3 11.6 81.0 10 2.67 MDST,DKGY.ARG.SLTY,WCONS.TR SDY BURS ** ** ~ Denotes fractured sample Page 11 ---- . ~ CMS-200 Overburden Pressure Analysis Results .... } 1 I } 1 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCR I PT ION .. ~ .. .. .. .. .. ------.. .. .. .. .. .. ... .... .............. .... .. .. ...... .... .... .. .. .. ..----............ .. .... .. .. .. .. .. .. .. .. .. .. ...... .. .. .. 104B 6871.7 atm 22.6 0.78 SS,OLVGY,Vf-CGR,PRED fGR,MOD SRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 1000 22.6 0.60 0.81 3000 22.2 0.48 0.64 105A 6872.2 atm 21.3 0.49 SS,OLVGY,VF-CGR,PRED f-MGR,MOD-WSRTD,SBANG-SBRD,W-MOD CONS,POSS SID-ANK,VUGS 1000 21.3 0.32 0.46 3000 20.8 0.20 0.30 106A 6873.2 atm 27.9 5.02 SS,OLVGY,Vf-CGR,PRED F-MGR,MOD-WSRTD,SBANG-SBRD,MOD CONS,POSS SID-ANK.MNR VUGS 1000 27.6 4.04 4.54 3000 27.1 3.60 4.06 106B 6873.7 atm 27.4 27.27 SS,OLVGY,Vf-CGR,PRED F-MGR,MOD SRTD,SBANG-RD,SL FRI,POSS SID-ANK 1000 27.2 23.88 25.81 3000 26.8 22.10 23.94 107A 6874.2 atm 30.0 51.88 SS,OLVGY,Vf-CGR,PRED f-MGR,MOD SRTD,SBRD-RD,SLFRI-FRI,POSS SID-ANK 1000 29.8 46.44 49.02 3000 29.1 39.97 42.29 atm = measured porosity and Ka from conventional core analysis results Page t J L I 1 J ). \. ~ ~ ~ ~ ~ l- I- t COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 FIle No BP- 3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANAL YSI S .- CMS- 200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR KaCest) NUMBER FEET OVBD % Cmd) PORE DESCRIPTION ........---- .. .... ........ -------- --........... ............ .. ...... .. .. .... .. .. .... .. .. .. .. .. ..... - - . .. ........ .... .. .. .. .. .. .. .. .. .. .. .. .. 107B 6874.7 atm 22.0 1.73 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SLFRI-YCMTD,POSS SID-ANK 1000 21.2 1.36 1.62 3000 20.6 1.03 1.23 108A 6875.2 atm 21.9 0.93 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 21.9 0.76 0.97 3000 21.4 0.63 0.79 108B 6875 . 7 atm 18.2 0.09 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 18.1 0.09 0.15 3000 17.8 0.02 0.04 109A 6876.2 atm 22.9 1.48 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 22.9 1.24 1.64 3000 22.4 0.96 1.29 109B 6876.7 atm 22.5 12.66 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,MOD CONS,POSS SID-ANK 1000 22.4 10.99 12.27 3000 22.1 9..70 10.82 110A 6877 .2 atm 23.5 12.11 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,MOD CONS,POSS SID-ANK 1000 23.4 10.85 12.04 atm = measured porosity and Ka from conventional core analysis results Page 2 1 l J. 1. ~ ~ } ¡. r r ~ 1 COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ~---_.... .. .... ..... .. .. ---..-..-- .......--.... .... ...... .... .. .. ........ .. ........------- - .. ..... .. .. ........ .... .. ........ .. .. ...... 3000 22.9 9.56 10.60 110B 6877.7 atm 25.3 43.60 SS,OLVGY,VF'CGR,PRED F'MGR,MOD SRTD,SBRD-RD,MOD CONS,POSS SID'ANK 1000 25.3 40.46 42.77 3000 24.8 36.75 38.90 111A 6878.2 atm 24.1 62.18 SS,OLVGY,VF'CGR,PRED F'MGR,MOD SRTD,SBRD-RD,MOD-WCONS,POSS SID-ANK 1000 23.9 59.30 61.05 3000 23.5 55.73 57.43 111B 6878.7 atm 21.8 44.99 SS,OLVGY,VF'CGR,PRED F-MGR,WELL SRTD,SBRD-RD,MOD-WCONS,POSS SID-ANK 1000 21.8 42.44 43.84 3000 21.4 40.28 41.63 112A 6879.2 atm 27.0 123.94 SS,OLVGY,VF'CGR,PRED F'MGR,WELL SRTD,SBRD'RD,MOD CONS,POSS SID-ANK 1000 26.5 119.59 121.83 3000 26.1 112.95 115.18 112B 6879.8 atm 25.9 117.91 SS,OLVGY,VF-CGR.PRED F-MGR,MOD SRTD,SBRD·RD.WCONS·SLFRI,POSS SID-ANK 1000 25.9 112.45 115.04 3000 25.4 105.26 107.88 atm = measured porosity and Ka from conventional core analysis results Page 3 ¡ 1" 1 L 1- ).. ¡~ 1- r 1- ¡- Ì' ,. COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR KaCest) NUMBER FEET OVBD % Cmd) PORE DESCRIPTION ........ .. .. .. ....... ...... .. ---.........- --.......... ............ .. --.......... .... ..... .. .... .. .... .. ...... .. .................. ......-....-..- .............--..... --.. 113A 6880.2 atm 28.1 218.63 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SB~D-RD,SLFRI-FRI,POSS SID-ANK 1000 28.0 210_23 215.10 3000 27.4 198.25 202.38 113B 6880.7 atm 25.1 134.20 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,SLFRI-WCONS,POSS SID-ANK 1000 25.1 129.30 132.96 3000 24.5 121.40 124.99 114A 6881. 2 atm 22.5 66.72 SS,OLVGY,VF-CGR,PRED F-MGR,MOD-WSRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 22.5 63.66 65.63 3000 22.0 61.21 63.11 114B 6881. 7 atm 21.6 21.36 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK 1000 21.4 19.81 20.87 3000 21.0 18.77 19.80 115A 6882.2 atm 16.1 8.57 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK,VUGS 1000 16.0 7.50 8.24 3000 15.6 7.02 7.72 115B 6882.6 atm 29.7 200.40 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,FRI,POSS SID-ANK 1000 29.7 218.30 222.26 atm = measured porosity and Ka from conventional core analysis results Page 4 l' t 1 1 ¡ I" 1 ~ , ~ ~ 1- r r COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR KL HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .. ~ .. .. .. .. ... .... ...... .... -------- ..........-- ... .. ....... .. .. ...... .. .. .... ....--------- - - ....... .... ........ ...... .. .. .. ............ 3000 29.1 195.27 199.19 116A 6883.2 atm 26.8 69.46 SS,LT OLVGY,VF-CGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 1000 26.7 63.89 67.49 3000 26.1 59.06 62.55 116B 6883.8 atm 28.0 183.01 SS,OLVGY,VF-MGR,PRED F-MGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 1000 27.9 171.36 174.80 3000 27.6 157.74 160.98 117A 6884.2 atm 21.4 17.49 SS,LT OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,WCONS,POSS SID·ANK 1000 21.3 14.98 16.45 3000 20.9 13.86 15.23 117B 6884.7 atm 18.5 4.64 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,VWCONS,POSS SID-ANK 1000 18.4 3.68 4.37 3000 18.1 3.44 4.03 118A 6885.2 atm 21.6 10.92 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,VWCONS.POSS SID-ANK 1000 21.5 9.98 10.95 3000 21.2 9.14 10.03 atm = measured porosity and Ka from conventionaL core analysis results Page 5 I ~ 1 \~ I 1 , }- ¡.. ¡- t' r .~ COR E LAB 0 R A TO R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 FiLe No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ...... .. ...... ... ..... .. .. .... ..--....--- ....----- .... .... ....... ..----"- ....---............--..--.. ........ ...--- ..--....--.. ------- ----..-.... 118B 6885.7 atm 24.2 16.86 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 24.0 15.56 16.76 3000 23.5 13.91 14.99 119A 6886.2 atm 27.4 124.83 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 1000 26.9 118.48 121.69 3000 26.5 107.67 110.83 119B 6886.8 atm 22.1 123.66 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,SLFRI-WCONS,POSS SID-ANK 1000 22.0 121.61 123.44 3000 21.7 116.53 118.34 120A 6887.2 atm 21.1 51.40 SS,LT OLVGY,VF-MGR,PRED F-MGR,WSRTD,SBRD-RD,WCONS,POSS SID-ANK 1000 21.0 46.85 48_99 3000 20.5 44.52 46.54 120B 6887.7 atm 27.6 346.25 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 1000 27.1 311.95 322.56 3000 26.8 294.73 304.78 121A 6888.2 atm 33.2 1875.69 SS,OLVGY.VF-CGR,PRED F-MGR,PSRTD,RD-WRD,FRI,POSS SID-ANK 1000 33_2 1716.68 1721.33 atm = measured porosity and Ka from conventional core analysis results Page 6 T J. 1 ¡ t t J 1 1 COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb·88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, ALaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCR I PTI ON .......... .. .. -----..- ...___wOO__ _______ ......... .. .... ... .. ..... .. .. ... ........ ................. ......... .. .. .. ... .. .. ... .... .. .......... ... 3000 32.3 1574.57 1580.10 121B 6888.7 atm 30.4 879.54 SS,OLVGY,VF-CGR,PRED F-MGR¡MOD SRTD,RD-WRD,FRI,POSS SID-ANK 1000 29.7 829.33 835.50 3000 29.3 779.05 784.69 122A 6889.2 atm 18.5 18.46 SS,OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,RD-WRD,FRI,POSS SID-ANK 1000 18.2 16.46 17.66 3000 18.0 15.94 17.11 123B 6890.8 atm 27.9 582.57 SS,OLVGY,VF-CGR,PRED F-MGR,MOD-PSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 27.5 505. 15 515_82 3000 26.7 447.92 458.23 124A 6891.3 atm 27.9 625.92 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 27.6 455.29 469.03 3000 27.0 410.22 421.97 124B 6891 .7 atm 27.8 344.54 SS,LT OlVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FR' ** 1000 27.4 277.77 293.59 3000 26.7 250.47 265.41 atm = measured porosity and Ka from conventional core analysis results Page 7 1- ¡. 1 ¡ . ]. ¡. ).. ). ~ } COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS.- CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .............. .. .. .... .. .. .. .. .. .. .. .. ...... ............... .... .. .... .... .. .. .. .. ...... .... .... ..... .... ... .. ... - - ...... .. ...... .... .. .... .. .... .. ...... .. 125A 6892.2 atm 29.3 874.57 SS,LT OLVGY,VF-CGR,PRED F-MGR,MOD SRTD,SBRD-RD,FRI,POSS SID-ANK 1000 28.9 750.86 761.93 3000 28.2 689.00 699.66 125B 6892.7 atm 26.7 243.57 SS,LT OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS MNR SID-ANK 1000 26.1 221.43 230.29 3000 25.7 209.94 218.43 126A 6893.2 atm 11.7 37.77 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBANG-SBRD,WCMTD,POSS SID-ANK ** 1000 11.6 34.19 36.70 3000 11.2 31.83 34.33 126B 6893.7 atm 23.2 94.27 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 1000 23.0 81_37 87_39 3000 22.6 76.56 82.49 127A 6894.2 atm 26.2 302.56 SS,OLVGY,VF-CGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 26.1 261.40 279.37 3000 25.5 221.49 232.32 127B 6894.8 atm 26.0 232.34 SS.OLVGY.VF-MGR.PRED FGR.WSRTD,SBRD-RD,FRI,POSS SID-ANK ** 1000 25.7 167.93 168.31 atm = measured porosity and Ka from conventional core analysis results Page 8 '~ t t' t~ I- ~ 1- l- I- I" ~ COR E LAB 0 RAT 0 R I E S N C Arco Alaska, nc. Date : 26-Feb-88 F i l e No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR KaCest) NUMBER FEET OVBD % Cmd) PORE DESCRIPTION -_.......-- .. .. .... .. ..... .. .... .... ...... ............... .. .. .. .... .. .. .......... .... .... .. .. .. .... .. .. .. .. -- - ---..--....-- .. .......... .. .. .... 3000 24.7 124.88 125.60 128A 6895.2 atm 24.0 223.39 SS,OLVGY,FGR,VWSRTD,SBRD-RD,FRI 1000 23.9 206.30 214.94 3000 23.1 188.31 198.14 128B 6895.7 atm 25.5 135.32 SS,OLVGY,FGR,VWSRTD,SBRD-RD,FRI,POSS SID-ANK 1000 25.5 116.24 119.28 3000 24.9 94.96 95.92 129A 6896.2 atm 23.5 55.30 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,SLFRI,POSS SID-ANK 1000 23.5 47.63 52.38 3000 23.2 45.18 49.74 129B 6896.7 atm 25.2 69.35 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK 1000 25.2 58.98 64.61 3000 24.9 55.33 60.75 BOA 6897. 1 atm 27.5 223.71 SS,LT OLVGY,VF-MGR.PRED FGR,VWSRTD,RD-WRD,FRI,POSS MNR SID-ANK 1000 27.3 201.18 210.56 3000 27.0 187.49 196.71 atm = measured porosity and Ka from conventional core analysis results Page 9 , L t I ~ ~ } } COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION -_...--- .... .... ...... .. .. .. .. ... .. ..... ............... .... .... ...... .. .. .. .. .... .. .. .. .. ..... .. .. ...... .. - .. .......... .. .. .. .. .. ... .. ...... .. .... - BOB 6897.8 atm 22.2 0.05 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD-WCMTD,POSS SID-ANK,GLAUC 1000 15.1 0.04 0.07 3000 14.8 0.03 0.06 131A 6898.3 atm 10.4 0.05 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK ** 1000 10.2 0.05 0.09 3000 9.9 0.03 0.06 131B 6898.7 atm 19.7 0.01 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK ** 1000 12.2 0.02 0.04 3000 11.8 0.01 0.03 132A 6899.3 atm 25.7 88.35 SS,OLVGY,VF-MGR,PRED VFGR,VWSRTD,RD-WRD,FRI-MOD CONS 1000 25.7 98.84 116.30 3000 25.2 87.76 102.23 132B 6899 . 6 atm 30.3 213.87 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK.ABNT GLAUC ** 1000 30.0 397.21 514.21 3000 28.5 263.72 353.69 133A 6900.2 atm 28.3 116.23 SS,DK GRNGY,VF-MGR.PRED FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 28.0 123.41 144.52 atm = measured porosity and Ka from conventional core analysis results Page 10 1 1- ~ ~ I. \... ¡.. .. ... ... ¡.. I- COR E LAB 0 RAT 0 R I E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ------- .. ... .. .... .... ...... .... ...... ............... .. .. .. .. .. .... ........ .... .. --..---....--..---- - .. ....... .. ........... .. ...... .... .. .... .. 3000 27.1 107.59 125.51 133B 6900.9 atm 27.4 131.60 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK,VUGGY FRAC ** 1000 27.3 111.03 127.51 3000 26.8 88.67 100.88 134A 6901.2 atm 30.7 251.74 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI 1000 30.6 236.15 246.15 3000 29.7 207.28 215.99 134B 6901.7 atm 29.6 152.65 SS,DK GRNGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI ** 1000 29.6 153.46 161.37 3000 28.8 132.11 138.99 135A 6902.2 atm 11.4 4.15 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,VWCMTD,POSS SID-ANK 1000 11.3 3.89 4.12 3000 11.0 3.57 3.80 136A 6903.1 atm 20.5 13.88 SS.OLVGY.VF-MGR,PRED FGR,WSRTD,SBANG-SBRD.WCONS.POSS SID-ANK 1000 20.5 13.22 14.03 3000 20.1 12.39 13.08 atm = measured porosity and Ka from conventional core analysis results Page 11 1 I ~ ~ ~ .~ .. } r } COR E LAB 0 RAT 0 R I E S N C . Arco Alaska, Inc. Date : 26'Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .. .... .. .... .. .... ...... .. - ___oo__.._ _______ .......... .... ------- ....- --...... -..---..- ---...... ....--..--..---........ ..-__00----- 136B 6903.7 atm 27.8 120.45 SS,OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI 1000 27.6 125 .58 149.11 3000 27.0 114.80 135.82 137A 6904.2 atm 27.1 197.53 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI ** 1000 27.1 150.74 163.96 3000 26.6 137.87 149.46 137B 6904.7 atm 29.1 164.90 SS,DK GRNGY,VF-MGR,PRED F-MGR,WSRTD,SBRD-RD,FRI 1000 28.5 139.85 146.61 3000 27.9 125.60 132.08 138A 6905.3 atm 24.3 19.81 SS,OLVGY,VF-MGR,PRED FGR,VWSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 24.3 15.35 17.63 3000 23.8 13.58 15.63 139A 6906.4 atm 26.1 38.23 SS,OLVGY,VF-MGR,PRED, FGR,WSRTD,SBRD-RD,FRI,POSS MNR SID-ANK 1000 26.0 32.69 35.96 3000 25.6 29.89 32.97 140A 6907.3 atm 23.0 18.07 SS,LT OLVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,WCONS-SLFRI,POSS SID-ANK.ABNT GLAUC 1000 22.8 14.70 16.62 atm = measured porosity and Ka from conventional core analysis results Page 12 · .. ~ ]... ).. 1- ~ ¡. ~ COR E LAB 0 RAT 0 R I E S N C Arco Alaska, nc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR KaCest) NUMBER FEET OVBD % Cmd) PORE DESCR I PTI ON .......... .... --_.....-- ----_....- ------- ------- .. ...... .... .. .... .. .. .. .. .. .. .. .. .. '. .. .. .... .. .. .... .... ... ................. .. 3000 22.5 13.40 15.20 140B 6907.7 atm 25.5 12.22 SS,OlVGY,VF-MGR,PRED FGR,WSRTD,SBRD-RD,FRI,POSS SID-ANK,ABNT GlAUC 1000 25.4 9.74 11.59 3000 25.0 8.55 10.23 141B 6908.5 atm 18.5 1.91 SS,OlVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,SLFRI-WCONS,POSS SID-ANK,ABNT GLAUC 1000 18.4 1.84 2.20 3000 17.8 1.69 2.04 201C 6911.8 atm 21.1 3.43 SS,OLVGY,VF-FGR,WSRTD,SBANG,WCONS,POSS MNR SID-ANK,ABNT GlAUC 1000 21.1 2.65 3.51 3000 20.6 2.43 3.25 202A 6912.2 atm 19.5 1.98 SS,OLVGY,VF-FGR,PRED VFGR,VWSRTD,SBANG-WCONS,GlAUC 1000 19.4 1.31 1.83 3000 18.8 1.14 1.61 202B 6912.7 atm 21.9 8.41 SS.OLVGY.PRED VF-FGR,WSRTD,SBANG-SBRD.W-MOD CONS,GlAUC ** 1000 21.7 6.49 7.92 3000 21.2 5.53 6.77 atm = measured porosity and Ka from conventional core analysis results Page 13 1 r ) L 1· . ~ I.- ~ ¡.. 1"' t ~ r COR E LAB 0 RAT 0 R I E S N C . Arco Alaska, Inc. Date : 26-Feb-88 Fi le No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANAL YSI S ,- CMS- 200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (mcI) PORE DESCRIPTION .. ...... ...... .. .... .. ...... ..........--.. ....--..-- .... .... ...... ........ .. .. .. ...... .. .... .. ........ .. ...... .. .... .... .. .... .. .. .... .. .. .... .. .... .. 203A 6913.2 atm 19.9 1.69 SS,LT OLVGY,VF-FGR,PRED VFGR,WSRTD,SBANG-SBRD,W-MOD CONS,GLAUC 1000 19.6 1.20 1.73 3000 19.1 0.97 1.41 203B 6913.7 atm 20.3 1.77 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,W-MOD CONS,GLAUC 1000 20.1 1.31 1.88 3000 19.6 1.09 1.56 204A 6914.2 atm 20.1 2.09 SS,LT OLVGY,VF-FGR,PRED FGR,WSRTD,SBANG-SBRD,W-MOD CONS,GLAUC 1000 19.7 1.44 2.06 3000 19.1 1.14 1.65 204B 6914.8 atm 0.7 0.01 SLTST,LT OLVGY,VSDY,VWCMTD,POSS SID-ANK,ABNT GLAUC,CALCXL FRAC 1000 12.5 0.02 0.05 3000 12.2 0.01 0.02 205B 6915.8 atm 12.5 0.40 SS,LT OLVGY,PRED VFGR,VWSRTD,SBANG-SBRD,VWCONS,POSS MNR SID-ANK 1000 12.5 0.03 0.07 3000 11.9 0.02 0.05 206A 6916.2 atm 16.1 0.10 SS,LT OLVGY,VF-FGR,PRED VFGR,WSRTD,SBANG-SBRD,WCONS,SL CALC,GLAUC 1000 16.1 0.06 0.14 atm = measured porosity and Ka from conventional core analysis results Page 14 t II 1 1 " I I~ ¡.. It- l- t t \11 t COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .......... .... ........ .... .. .. .. .. .... .. .... ................ ...... .. .. .... .. .... .. .. .. .. ........ .. .... .. .... .. -- .... .. ...... .. ...... .... .. .. .. .. .. .. .. .. 3000 15.8 0.05 0.11 206B 6916.7 atm 18.1 4.82 SS,OLVGY,VF-FGR,PRED VFGR,W-MOD SRTD,SBANG-SBRD,WCONS,GLAUC ** 1000 18.1 3.43 4.11 3000 17.7 2.30 2.73 207A 6917.2 atm 17.6 0.36 SS,LT OLVGY,VF-CGR,PRED VFGR,WSRTD,SBANG-SBRD,WCONS,GLAUC 1000 17.5 0.19 0.36 3000 17.0 0.13 0.26 208A 6918.2 atm 17.3 0.34 SS,OLVGY,VF-MGR,PRED FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS MNR SID-ANK 1000 17.3 0.23 0.40 3000 17.0 0.19 0.34 208B 6918.7 atm 17.7 0.17 SS,OLVGY,VF-MGR,PRED FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS MNR SID-ANK 1000 17.7 0.12 0.23 3000 17.4 0.09 0.18 209A 6919.2 atm 7.4 0.05 SS,LT OLVGY,VF-MGR,PRED VF-FGR,MOD SRTD,SBANG,VWCMTD.POSS SID-ANK,GLAUC 1000 7.3 0.04 0.07 3000 7.1 0.02 0.04 atm = measured porosity and Ka from conventional core analysis results Page 15 1 1 I t 1- JJ. 1 J I~ ... )- ¡.. fi- t ~ t t COR E LAB 0 RAT 0 R E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ... M ........ .. .. ............... .. .. ...... .. .. ...... ............... .. .. ..... .. ... - ..... .. .. .... ... --...........--............... ,- .. .. ....... -.. ...... .. ....--..........-.. 209B 6919.6 atm 18.1 0.32 SS,OLVGY,VF-MGR,PRED VF-FGR,W SRTD,SBANG-SBRD,WCONS,POSS SID-ANK,GLAUC 1000 18.2 0.23 0.39 3000 17.8 0.19 0.32 210B 6920.7 atm 23.2 3.09 SS,OLVGY,VF-MGR,PRED VF-FGR,W-MOD SRTD,SBANG-SBRD,WCONS,POSS SID·ANK,GLAUC 1000 23.3 2.31 3.11 3000 22.8 1.94 2.62 211A 6921. 2 atm 20.6 0.28 SS,OLVGY,VF-MGR,PRED VF-FGR,MOD SRTD,SBANG-SBRD,WCONS,POSS SID-ANK.ABNT GLAUC 1000 20.3 0.19 0.36 3000 19.9 0.15 0.29 212A 6922.2 atm 11.4 0.50 SLTST,M-DKGY,VSDY,WCONS,VFGR BURS,MDST LAMS 1000 10.5 0.05 0.09 3000 10.3 0.01 0.02 213A 6923.6 atm 12.2 0.04 MDST,DKGY,ARG,WCONS,SL CALC,SDY BURS,20% BDD SlTST 1000 12.1 0.02 0.05 3000 11.8 0.00 0.01 220 6930.5 atm 13.1 1.97 MDST,DKGY,SLTY.MIC.WCONS,20-30%VSDY,INTBD SLTST,TR PYR ** 1000 13.1 0.64 0.75 atm = measured porosity and Ka from conventional core analysis results Page 16 I t t t ) ) I l- I rl- }. )y' ~ l- t- I COR E LAB 0 RAT 0 R I E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR KaCest) NUMBER FEET OVBD % Cmd) PORE DESCRIPTION -.............. ... ....... .. ...... .. .... .. ...... ..... .................... ......... .. ... ... ..------ ..... ..... .. ..... ... ... ... ... ... .... ...... .............-......-.....-....... .......... ..... ....... .. 3000 12.8 0.06 0.09 221 6931. 3 atm 14.3 0.15 MDST,OLVGY,ARG,BIOTURB,WCONS,LAM,50% SLTY LAMS 1000 14.3 0.07 0_14 3000 13.9 0.02 0.06 222 6932.7 atm 13.4 9.19 MDST,OLVGY,ARG,BIOTURB,WCONS,LAM,50% SLTY LAMS 1000 13.0 0.44 0.48 3000 12.6 0.14 0.17 225 6935.3 atm 12.9 0.92 MDST,DKGY,ARG,WCONS,LAM,LAM, 10-20% SLTY LAMS 1000 12.6 0.33 0.39 3000 12.2 0.05 0.07 228 6938.5 atm 13.1 0.07 MDST,DKGY,ARG,WCONS,LAM,30-40% SLTY LAMS 1000 13.0 0.02 0.04 3000 12.5 0.00 0.01 229 6939.7 atm 13.1 12.09 MDST,DKGY,ARG,WCONS,LAM,40-50% SLTY LAMS ** 1000 13.0 3.14 3.34 3000 12.1 0.34 0.39 atm = measured porosity and Ka from conventional core analysis results Page 17 I t r } ) ) J. ) J \. ... ~ r, .. ,t' COR E LAB 0 R A T.O R E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (met) PORE DESCRIPTION ....... .. .. ..... .. ........ .... .. ....... .. ...... .............. .. .. .. .. .... .. .... .......... .. .. ....... .... .. .... .. .. .. .. .. .............-..-.... ...... -_...- .. ............ .. .. .. 232 6942.5 atm 12.9 36.18 MDST,DKGY,ARG,THNLY BDD,WCONS,15-20% SLTY LAMS 1000 12.7 0.63 0.72 3000 12.2 0.04 0.06 237 6947.6 atm 13.2 0.99 MDST,DKGY,ARG,BIOTURB,WCONS,lAMS,50% SLTY LAMS 1000 12.6 0.16 0.24 3000 12.3 0.03 0.06 239 6949.6 atm 12.1 0.04 MDST,DKGY,ARG,WCONS,BIOTURB,LAM,50% SLTY LAMS 1000 11.8 0.02 0.04 3000 11.3 0.00 0.01 240 6950.5 atm 15.8 6.04 SLTS,LT OLVGY,WCONS THNLY BDD,20-30% ARG LAMS 1000 15.1 2.75 3.09 3000 15.0 0.70 0.93 242 6952.7 atm 15.1 1.39 SLTST,OlVGY,WCONS,THNLY BDD,10-20% ARG lAMS,ABNT BIOTURB 1000 14.7 0.74 1.06 3000 14.3 0.51 0.75 243 6953.6 atm 14.7 2.95 SlTST,OLVGY,WCONS,THNlY BDD,20-30% ARG LAMS.BIOTURB 1000 14_7 1.18 1.51 atm = measured porosity and Ka from conventional core analysis results Page 18 I 1 \ Þ I. .J l } } r COR E LAB 0 RAT 0 R I E S N C Area Alaska, Inc. Date : 26- Feb·88 File No BP·3-1251 KRU #3H·9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ...... .. .. .... ...... .. .. .... .... .. .......... .............. .. .. .. .... .. ... .. .. ..... .. .. .. .... .. .. .. .. .. ..... .. .. --------...- .. .. .. ..... .. .. .. .. 3000 14.1 0.39 0.58 244 6954.2 atm 13.8 0.24 SLTST,OLVGY,VSDY,WCONS,LAM,10-20% MDY LAMS 1000 13.4 0.05 0.10 3000 13.0 0.02 0.05 245 6955.7 atm 14.9 5.35 SS,LT OLVGY,VFGR,WSRTD,SBANG'SBRD,WCONS,10-15% MDY LAMS ** 1000 13.8 1.69 2.05 3000 13.3 0.48 0.68 246 6956.5 atm 23.1 122.05 SS,LT OLVGY,VF-FGR,PRED FGR,VWSRTD,SBANG'SBRD,MOD CONS 1000 22.9 108.94 117.44 3000 22.6 104.77 113.00 247 6957.6 atm 24.8 217.19 SS,LT OLVGY,VF'FGR,PRED FGR,VWSRTD,SBANG'SBRD,SLFRI 1000 24.5 184.19 195.08 3000 24.1 178.05 188.59 303 6973.5 atm 14.5 2.65 SS,OLVGY,VFGR,VWSRTD,SBRD,WCONS,20% DKGY,SLTY.MIC.MDST LAMS.TR PYR ** 1000 14.3 1.36 1. 71 3000 13.9 0.61 0.85 atm = measured porosity and Ka from conventional core analysis results Page 19 ~ r 1 . » L i- t '}.. }. .~ t.- \- ¡. ,. r COR E LAB 0 RAT 0 R I E S N C Area Alaska, Inc. Date : 26- Feb-88 Fi le No BP·3·1251 KRU #3H'9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS'200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ...... .... .... .. .... ... ... .. .. .......... ...... .............. .. .. .. .. .. .. .. ...... ...... .. ......------..... . . ----............. ...... .... .... ..... .. 304 6974.3 atm 14.7 6.48 SS,OLVGY,VFGR,VWSRTD,SBANG'SBRD,WCONS,30% DKGY,SLTY,MDST LAMS,TR PYR ** 1000 14.5 5.08 5.82 3000 14.1 4.65 5.32 305 6975 .3 atm 24.6 149.82 SS,LT OLVGY,VFGR,VWSRTD,SBRD-RD,SLFRI,TR MDY LAMS 1000 24.6 133.68 142.69 3000 24.2 128.94 137.65 306 6976.4 atm 24.9 122.84 SS,LT OLVGY,VFGR,VWSRTD,SBRD'RD,SLFRI,TR MOY LAMS 1000 24.7 109.49 118.12 3000 24.3 105.56 113.97 307 6977.6 atm 15.8 2.65 SS,LT OLVGY,VFGR,VWSRT,SBANG'SBRD,WCONS,10% THNLY BDO MOST 1000 15.6 1.39 1.87 3000 15.2 0.99 1.39 308 6978.6 atm 25.2 115.49 SS,OLVGY,VFGR,VWSRTO,SBANG-SBRD,SLFRI,TR MOY LAMS 1000 25.1 102.19 110.65 3000 24.7 98.59 106.90 309 6979.5 atm 25.3 64.80 SS,OLVGY,VFGR,VWSRTO,SBANG-SBRD,SLFRI,TR MOY LAMS 1000 25.2 54.81 60.98 atm = measured porosity and Ka from conventional core analysis results Page 20 .. r L ~ }. L . \. }. 1,. ~ ~ ~ r r r COR E LAB 0 RAT 0 R I E S N C Area Alaska, Inc. Date : 26-Feb-88 FIle No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .. ............ .. .. ...... .. - .. .... .... .. .... .............. .. .. .... .... .. .... .. .. .. .. .. .. .. .. .. .. .. .. ......... .. .. .... .. .. ....... .... .... .. .. .... .. .... 3000 24.7 52.65 58.56 310 6980.5 atm 26.6 270.86 SS,OLVGY,VFGR,VWSRTD,SBRO,SLFRI,TR MOY LAMS 1000 26.5 247.11 259.96 3000 26.1 238.63 251. 43 311 6981.4 atm 26.6 124.24 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,TR MDY LAMS,TR PYR 1000 26.4 109.30 118.20 3000 26.0 105.40 114.09 312 6982.5 atm 26.4 87.88 SS,OLVGY,VFGR,VWSRTO,SBRD,SLFRI,TR MOY LAMS 1000 26.3 75.73 83.22 3000 25.9 72.95 80.20 314 6984.5 atm 24.3 75.71 SS,LT OLVGY,VFGR,VWSRTO,SBRD,SLFRI,TR MOY LAMS 1000 24.2 62.70 68.61 3000 23.8 59.83 65.62 315 6985.2 atm 21.1 26.39 SS,LT OLVGY,VFGR,VWSRTO,SBANG-SBRD,SLFRI,20% SLTY.MIC,BDD MDST ** 1000 20.9 20.32 23.24 3000 20.5 18.62 21.33 atm = measured porosity and Ka from conventional core analysis results Page 21 f r r I l t J. \. ~ ~ ¡. ~ r r r r .\.. COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3·1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS' CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ...... .... ..... ---_....- ........ ........ .............. .. .... ........ .... .. .... .... .. .. .. ...... .......... . - . .. .. ... .. .. .. .. .. .... ......... .......... .. 316 6986.5 atm 24.9 53.99 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,TR MDY LAMS 1000 24.9 44.79 50.25 3000 24.5 43.16 48.48 317 6987.4 atm 22.0 39.49 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI,1% PYR 1000 21.7 32.30 36.19 3000 21.0 29.25 32.91 318 6988.4 atm 26.0 172.13 SS,OLVGY,VFGR,VWSRTD,SBRD,SLFRI 1000 25.6 153.70 164.69 3000 25.2 148.64 159.40 319 6989.3 atm 22.0 34.88 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,SLFRI,MNR MDY LAMS,TR PYR 1000 21.7 29.22 33.07 3000 21.3 27.76 31.45 320 6990.6 atm 14.6 7.32 MDST,DKGY,SLTY,MIC,40% OLVGY,VFGR,WSRTD,BDD SS.2-3% PYR ** 1000 13.9 1.73 2.03 3000 13.5 0.34 0.50 321 6991. 5 atm 23.7 23.07 SS,OLVGY,VFGR,WSRTD,SBRD,MOD CONS 1000 23.5 18.11 21.33 atm = measured porosity and Ka from conventional core analysis results Page 22 ~ } 1. \.. ¡,. ).. ~ .. ~ COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No : BP'3-1251 KRU #3H-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .............. .. .... .. ........ ---........... ............... .... .... .. -... .. - -........ -.. .. .. - - - - .. .... .. .. . ...-...... - -.......... ........--.... -.. --....- 3000 23.1 17.27 20.36 322 6992.8 atm 23.7 57.12 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,MOD CONS,TR MDY LAMS, 1-2% PYR 1000 23.4 48.97 54.61 3000 23.0 47.13 52.56 323 6993.8 atm 16.9 16.93 SS,OLVGY,VFGR,WSRTD,SBRD,MOD CONS,30% DKGY,SLTY INTBD MDST ** 1000 16.2 9.26 10.52 3000 15.7 6.08 7.12 325 6995.3 atm 20.5 5.08 SS,OLVGY,VFGR,WSRTD,SBANG'SBRD,WCONS,5'10% MDY LAMS 1000 20.1 3.78 4.94 3000 19.7 3.44 4.52 326 6996.2 atm 18.1 1.81 SLTST,OLVGY,VSDY,WCONS,10-20% DKGY,SLTY,VMIC,INTBD MOST 1000 17.6 0.82 1.17 3000 17.2 0.37 0.60 328 6998.5 atm 19.3 13.35 SS,LT OLVGY,VFGR,VWSRTD,SBRD,W·MOD CONS,10% MDY LAMS,TR PYR ** 1000 18.7 10.79 12.61 3000 18.3 9.90 11.58 atm = measured porosity and Ka from conventional core analysis results Page 23 I r .~ I . ¡ 1 ¡.. r ¡.. r r COR E LAB 0 R A TO R E S N C Arco Alaska, Inc. Date : 26-Feb-88 File No BP-3'1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS' eMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ...... .. .. .... ........ .. .... -------- ----...... .... .. .. .... .. ..-..---- .... ...... ............ .. - . ....---......-- ....----...... 330 7000.3 atm 19.1 0.97 SS,OLVGY,VFGR,WSRTD,SBRD,WeONS,TR MDY LAMS 1000 18.8 0.67 1.08 3000 18.3 0.62 0.96 331 7001.4 atm 21.8 4.76 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,TR MDY LAMS,2-3% MDY LAMS 1000 21.4 3.50 4.58 3000 21.0 3.15 4.26 332 7002.4 atm 12.5 3.01 MDST,DKGY,ARG,10-20% VFGR,SDY LAMS ** 1000 11.9 0.73 0.83 3000 11.4 0.07 0.10 333 7003.3 atm 14.1 2.13 SS,OLVGY,VFGR,WSRTD,SBRD,WeONS,30'40% SDY,SLTY,LAM MDST 1000 13.4 0.65 0.88 3000 13.0 0.17 0.27 335 7005.5 atm 13.9 8.01 SLTST,OLVGY,VSDY,WCONS,20% DKGY,LAM MDST 1000 13.0 57.69 60.61 3000 12.5 11. 50 11.83 336 7006.4 atm 14.3 4.61 MDST,DKGY,ARG,VSDY.MIC.40·50% VFGR,WSRTD,SBRD,INTBD SS 1000 14.0 1.93 2.15 atm = measured porosity and Ka from conventional core analysis results Page 24 I ) \ 1 J 1 _J J _--1 ___J .OJ COR E LAB 0 RAT 0 R E S N e Areo Alaska, nc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - eMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .. 4 ........ .. .. .... .. ....... _..__..-...- ......---- .. .. .. .. .. .... .......... .... .. .... .. .. .. .. .. .. .. .. ------....-.. .. ...... .. ....... .... 3000 13.6 0.32 0.44 339 7009.4 atm 13.0 1.02 MDST,DKGY,SLTY,WCONS,30% VFGR,WSRTD,SBRD,WeONS,INTBD SS,BIOTURB 1000 12.9 0.42 0.60 3000 12.6 0.21 0.33 340 7010.4 atm 15.2 4.02 SS,OLVGY,VFGR,WSRTD,SBRD,WCONS,40-50% DKGY,SLTY,MIC,BIOTURB MDST,2% PYR 1000 14.9 1.15 1.59 3000 14.5 0.37 0.60 341 7011.4 atm 16.5 6.94 SS,LT OLVGY,VFGR,VWSRTD,SBRD,WCONS,20-30% SLTY INTBD MDST,PYR FRAe 1000 16.4 4.66 5.55 3000 16.1 3.81 4.56 342 7012.8 atm 18.6 8.99 SS,OLVGY,VFGR,WSRT,SBRD,MOD CONS,15% INTBD MOST 1000 18.1 5.21 6.38 3000 17.8 3.41 4.35 343 7013.7 atm 14.6 3.06 MDST,SLTY,SDY,WCONS,30-40% SOY INTBD SLTST,TR PYR,SDY BURS ** 1000 14.2 1.23 1.56 3000 13.9 0.45 0.62 atm = measured porosity and Ka from conventional core analysis resuLts Page 25 1 r } \ ) \. ~ ~ r r COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb'88 Fi le No Bp·3·1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TlS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS.- CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ....-..--.. .... .......... ..........--.. ------- .. .. .. .. ... ..- .. .. .... .. ..- .. .. .... .. .. .. ........ - .. .... .. .. .... .. .. .. ..... .. .. .......... 344 7014.5 atm 14.8 3.50 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,WCONS,40% DKGY,ARG,LAM MDST 1000 14.9 1.44 1.86 3000 14.4 0.46 0.67 345 7015.4 atm 13.9 8.76 MDST,DKGY,SLTY,SDY,WCONS,20% VFGR,BIOTURB SS ** 1000 13.6 2.15 2.37 3000 13.2 0.19 0.27 346 7016.5 atm 15.3 1.68 MDST,DKGY,SLTY,SDY,WCONS,30-40% OLVGY,VFGR,WSRTD,SBRD,MOD CONS,INTBD SS 1000 15.0 0.72 1.00 3000 14.5 0.36 0.53 347 7017.3 atm 14.8 1.48 SS,OLVGY,VFGR,WSRTD,SBANG-SBRD,WCONS,50% DKGY,HVY BIOTURB MDST,1-2% PYR 1000 14.3 0.70 0.97 3000 13.9 0.35 0.54 348 7018.8 atm 13.0 2.03 SLTST,OLVGY,VSDY,WCONS,30'40% HVY BIOTURB MOST 1000 13.3 0.54 0.69 3000 12.8 0.08 0.13 352 7022.5 atm 15.1 3.08 SLTST,LT OLVGY,VSDY,WCONS,30-40% BIOTURB.BDD MDST ** 1000 14.5 1.25 1.70 atm = measured porosity and Ka from conventional core analysis results Page 26 l ~ r J \.. l,. ~ \. ~ ~ COR E LAB 0 RAT 0 R E S N C Areo Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ... ...... .. .. .. .------ .... .. .......... ............... ... .. ........ .. ........... .... ...... .. .. .. ........ .. .- -. .. .. .. .... ...... ..... .... .... .... ... ... .. 3000 14.0 0.55 0.84 353 7023.8 atm 23.3 89.08 SS,LT OLVGY,VFGR,VWSRTD,SBRD,MOD CONS,MNR MDY LAMS,TR PYR 1000 23.1 81.25 88.05 3000 22.7 77.84 84.46 354 7024.7 atm 15.1 1.55 MDST,OLVBLK,ARG,SDY,WCONS,30% VFGR,WSRTD,SBRD,INTBD SS 1000 14.8 0.66 0.86 3000 14.9 0.20 0.30 355 7025.5 atm 15.9 4.68 SS,LT OLVGY,VFGR,WSRTD,SBRD,20'30% ARG,SDY,BIOTURB MDST ** 1000 15.7 2.87 3.54 3000 15.0 2.03 2.54 356 7026.6 atm 17.7 4.29 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,15-20% BIOTURB,LAM MDST 1000 17.8 2.73 3.37 3000 17.4 1.84 2.38 357 7027.5 atm 15.6 4.07 MDST,DKGY.SLTY.SDY.WCONS.40-50% VFGR,WSRTD,SBRD,BIOTURB SS 1000 15.6 2.62 3.01 3000 15.2 1.98 2.27 atm = measured porosity and Ka from conventional core analysis results Page 27 l \ 1 ] 1 ___1 __....1. -.J. .-.-L .... -...... "- -.. ...........~ COR E LAB 0 RAT 0 R I E S N C . Arco Alaska, Inc. Date : 26-Feb-88 File No : Bp·3·1251 KRU #3H'9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION . - .. .. .... .. .......... .... --............ ..---..-- ............ .. .. .. ...... .. .. .... .. .. ..... .. ........ ...... .. . -- .......... _.....-- ......-..... ---......... 358 7028.7 atm 14.4 5.93 MDST,DKGY,SLTY,SDY,WCONS,30'40% VFGR,WSRTD,SBRD,MOD CONS ** 1000 13.7 1. 71 2.05 3000 13.2 0.51 0.71 359 7029.6 atm 16.5 9.25 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,30% DKGY,SDY,MIC,INTBD MDST 1000 16.2 5.15 6.04 3000 15.7 3.86 4.56 360 7030.6 atm 17.6 1.21 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20% ARG,LAM MDST 1000 17.5 0.81 1.20 3000 17.1 0.60 0.93 401 7031. 8 atm 17.2 2.36 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,15-20% ARG,MIC,LAM MDST,TR PYR 1000 16.9 1.05 1.56 3000 16.5 0.57 0.88 402 7032.5 atm 20.4 8.73 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,MNR MDY LAMS,TR PYR 1000 20.3 7.02 8.67 3000 19.8 6.65 8.21 403 7033.5 atm 13.4 2.59 MDST,DKGY,VSDY.MIC.WCONS,20-35% VFGR,WSRTD,SBRD,BIOTURB SS ** 1000 13.1 0.93 1.19 atm = measured porosity and Ka from conventionaL core analysis results Page 28 1 I, J ¡ L 1 ~ 1 ~ COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 FIle No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .. ~ .. .. .. .. .. .. .... ...... .. .. .. .. .... .. .... ............... ........... .. .. .... ...... .... ..........--......... .. .. .. .... .. .... .... ....--.. ....-..-.. --....-...........- 3000 12.6 0.15 0.22 404 7034.5 atm 14.6 8.46 MDST,DKGY,SDY,MIC,WCONS,30% VFGR,WSRTD,SBRD,MOD CONS SS ** 1000 14.3 3.73 4.36 3000 13.7 1.83 2.24 405 7035.7 atm 13.6 5.51 MDST,DKGY,SLTY,SDY,WCONS,20% VFGR,SDY LAMS ** 1000 12.7 2.43 2.45 3000 12.2 0.27 0.32 406 7036.5 atm 15.6 4.80 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20-30% SDY MIC,BIOTURB MOST 1000 15.1 1.93 2.28 3000 14.7 0.77 1.03 407 7037.6 atm 12.4 0.30 MDST,DKGY,SLTY,MIC,WCONS,10-15% VFGR SDY BURS,1% PYR 1000 11.6 0.13 0.22 3000 11.1 0.03 0.05 408 7038.4 atm 16.0 0.81 SS,LT OLVGY,VFGR,WSRTD.SBRD.WCONS,20% BIOTURB MDST 1000 16.0 0.50 0.69 3000 15.5 0.27 0.42 atm = measured porosity and Ka from conventional core analysis results Page 29 1 ) 1 I ] 1 J. _..1 _,_--1 ~ ._- .~ .--- COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26-Feb-88 FIle No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ............- .. .. ... .......... ---.......... ------... .. .. .. .. .... .. .. ....... ...... .. .. .. .. ...... ...... .. - .. .... .... .... ...... .. ...... .... .... ..", .. 409 7039.5 atm 13.9 5.12 MDST,DKGY,ARG,SDY,WCONS,20-30% VFGR,WSRTD,SBRD,BIOTURB SS ** 1000 13.6 1.54 1.85 3000 13.0 0.37 0.50 410 7040.3 atm 14.2 10.20 MDST,DKGY,SDY,WCONS,30% VFGR,WSRTD,SBRD,LAM SS TR PYR ** 1000 13.7 1.67 1.78 3000 13.3 0.24 0.33 411 7041. 2 atm 12.7 0.20 MDST,SLTY,SDY,WCONS,10-15% VFGR,HVY BIOTURB SS 1000 12.6 0.08 0.15 3000 12.1 0.02 0.05 412 7042.5 atm 11.8 4.16 MDST,DKGY,SLTY,SDY,WCONS,5-10% VFGR,SDT BURS ** 1000 11.3 1.14 1.22 3000 10.8 0.11 0.14 414 7044.2 atm 12.7 1.34 MDST,DKGY,SLTY,SDY,WCONS,20-30% VFGR,HVY BIOTURB SS ** 1000 12.5 0.37 0.51 3000 11.9 0.06 0.11 415 7045.6 atm 12.0 2.67 MDST.DKGY.SLTY.SDY.WCONS,15-20% VFGR.BIOTURB SS ** 1000 11.7 0.71 0.78 atm = measured porosity and Ka from conventional core analysis results Page 30 I COR E LAB 0 RAT 0 R I E S N C Arco Alaska, Inc. Date : 26- Feb-88 File No BP-3-1251 KRU #3H-9 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION ......--.... .. ...... ...... .. .. .. .. .. ...... .............. ........ .. .. .. ....----.. ......... .... ... .. .... .. .. .... .... ...... .... ...... .... ........ 3000 11.3 0.04 0.08 417 7047.6 atm 18.6 11.34 SLTST,OLVGY,VSDY,WCONS,10-15% BIOTURB AND LAM MDST 1000 18.2 4.08 5.00 3000 17.7 1.22 1.63 418 7048.5 atm 16.7 1.64 SLTST,OLVGY,VSDY,WCONS,10-15% BIOTURB AND LAM MDST 1000 16.6 0.76 1.10 3000 16.2 0.42 0.67 419 7049.6 atm 12.2 0.59 MDST,DKGY,SLTY,SDY,WCONS,10-20% HVY BIOTURB VFGR SS ** 1000 12.0 0.15 0.22 3000 11.6 0.02 0.04 420 7050.5 atm 12.2 0.25 MDST,DKGY,SLTY,WCONS,5-10% BIOTURB SLTST 1000 11.9 0.12 0.22 3000 11.5 0.02 0.05 422 7052.3 atm 13.4 12.68 MDST.DKGY.SLTY,WCONS,20% VFGR,LAM SS ** 1000 13.6 4.17 4.36 3000 12.5 0.29 0.35 atm = measured porosity and Ka from conventional core analysis results Page 31 " 1 I ~ 1 ~ ~ ~ } } COR E LAB 0 RAT 0 R I E S N C Area Alaska, Inc. Date : 26-Feb-88 File No BP-3-1251 KRU #3H-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : API No : OVERBURDEN PRESSURE ANALYSIS- CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER FEET OVBD % (md) PORE DESCRIPTION .._----.. .... .... .... - ..--....--- ....----- .. .. .. .. .. .. .. .. .. .. ...... .. --..-------.. .. .... .... ... .. .. .. .. .. .. .... .. .. .. .. .. .. 424 7054.4 atm 16.2 2.50 SS,LT OLVGY,VFGR,WSRTD,SBRD,WCONS,20% DKGY,SDY BOD MOST 1000 16.1 0.67 0.95 3000 15.6 0.17 0.30 425 7055.3 atm 13.9 2.13 MDST,DKGY,SLTY,MIC,WCONS,10-20% INTBD SLTST,MNR SDY BURS ** 1000 13.6 0.63 0.81 3000 13.9 0.11 0.17 atm = measured porosity and Ka from conventional core analysis results Page 32 o (1) rt PJ 1-'- I-' (1) p., t-t 1-" rt ::r o I-' o ~ 1-'- () PJ I-' en PJ S "Ö I-' (1) o (1) fJ) () Ii 1-" "Ö rt 1-" o ::! fJ) 1 "--- t:I <D M- ¡:¡, 1-0. I-t <D 0.. 1:-1 1-0. Ci- :::r o I-t o 1-0. 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""-J \.Q()tnt/) .....Oo-s:» s:»!3'1:::J ~ '"0 Q., Q., o 0 I tn , tn'1ti- t1> Q., 0 '"0 a.' :::J o t1> {f¡ 0 tn {f¡1;¡....1 {f¡'¡:"1--¡¡0 -.I. c '1 ..... a. I -.I. <:: IO\I\Q s:»O~~ :::J 0\0 t1> ' ~ ..... ~ ..... <:: -.I. ("'f- I--¡¡ :::J tIiI () 1 , !3 () {f¡ ti- \.Q '"0 w Q., t; ..... C' , , 1 ,¡:,. Q., '"0 ~Ct1>'1 ("'f- 0\0 \.Q t1> tIiI t; Q., a.t1> 0~t1>1--¡¡ <:: 1 \.QrnO!3 ~ ..... I--¡¡ \.Q ("'f-rt t; ::r'~ () , {f¡ 0 . !3:::J!3 ("'f-tnO >.; Q., , <:: s:» {f¡ VI '1 '1 0\0 -.I. ti- mQ., (f¡' , Oa.tnt/) <:: ~ 0' s:» \Q '1:::J ~tna.a. ti-.....lrn ::r'("'f-'1("'f- tn~a.o , ':::J !3 t1> () ("'f- ~ s:» >.; t1> 1 .....' ..... o ..... 0 ..... ..... I;¡I()<:: -.I. w 0 \.Q ..... 0\0 :::J '"<: ..... rn ' t1>\.Q' a...... <:: S:»()I;¡ I;¡~O 1 '1 () !3 () s:»''"O\.Q () 0'1 '"0 rn ' "ö0t1> t; tn a. '"0 t1> {f¡ '1 {f¡ 0 t1> t1>tnN¡a. :::J -.I. ti-a.VlI;¡ . I C 1 s:» 1 !3 :::J O\\Q ~c'1 0\0 , -.I. :::J ~ !3 ("'f-O tntlila. '"0' ..... (f¡ , ,¡:,. '1 O("'f- ~Ia. rt lr1' tIiIO 0\0 ~OQ.,tnt/) -.I. <:: ~ 0' s:» a. \.Q '1:::J ("'f-~tna.Q., ::r'("'f-.....I{f¡ · ::r' rt '1 ti- tn~Q.,O , ':::J !3 t1> <::("'f-~ m>';t1> 1 '1' ..... rt .....0 ..... ..... () 1 () <:: s:»wO\.Q ..... 0\0 :::J ~ () tn' \.Q' I;¡..... <:: -.I. s:» () I;¡ .....~ 0 1 .....()!3() m''"O\Q a. 0'1 '"0 tn' 1;¡0t1> '1 {f¡ a. "ö s:» tn t; () 0 t1> tnl;¡a. '"0 -.I. '1Q.,'¡:"1--¡¡ t1> I C I {f¡S:» 1!3 t1> :::J VI\.Q :::J~ct; ("'f- 0\0' , -.I. :::J ~ !3 . ti- 0 I\.>{f¡tlila. !3'"O' !3..... {f¡ , ,¡:,. '1 -.I. Crt :::J1oQ 1 a. ("'f- 0\' tIiIO 0\0 -..' Î I ~ Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska -, j -, 109A 6876.2 ''I j 109B 6876.7 -1 ~1 110A 6877.2 -.1 110B 6877.2 -, .,-... IlIA 6878.2 111B 6878.7 -, 112A 6879.2 ~ 112B 6879.8 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l25l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, well cons, composed of 50-70% qtz, 30-50% dk slty mtx, 1-3% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, mod cons, composed of 40-50% qtz, 40-60% dk slty mtx, 5-7% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, mod cons, composed of 40-50% qtz, 40-60% dk slty mtx, 1-3% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, mod cons, composed of 50-60% qtz, 40-50% dk slty mtx, 1% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, mod-well cons, degree of cons varies, spl is composed of 50-60% qtz, 40-50% dk slty mtx, 1- 3% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, well srtd, sbrd-rd, mod-well cons, degree of cons varies, spl is composed of 50-70% qtz, 30-40% dk slty mtx, 3- 5% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, well srtd, sbrd-rd, mod cons, spl is composed of 50-60% qtz, 40-50% dk slty mtx, 2-3% glauc, poss sid-ank in spl. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, well cons-sl fri, degree of cons varies, spl is composed of 60-70% qtz, 30-40% dk slty mtx, 3-5% glauc, poss sid-ank in spl, qtz ovgwths. ~ ,..... ....... Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Alaska 113A 6880.2 -.....::. l13B 6880.7 114A 6881.2 l14B 6881.7 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l25l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sl fri-fri, well cons-sl fri, spl is composed of 50-60% qtz, 30-40% dk slty mtx, 5-10% glauc, poss sid-ank in spl, qtz ovgwths, mnr vugs. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, sl fri-well cons, degree of cons varies, composed of 60-70% qtz, 30-40% dk slty mtx, 3-5% glauc, poss sid-ank in spi, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, well srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% dk slty mtx, 1% glauc, poss sid-ank in spi, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod-well srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% dk slty mtx, 1-3% glauc, poss sid-ank in spi, qtz ovgwths. l15A 6882.2 Sandstone - olvgy, wht, vf-cgr, pred fgr, well srtd, sbrd-rd, v well cons, composed of 70% qtz, 20% dk slty mtx, 10% glauc, poss sid-ank in spi, abnt qtz ovgwths, vuggy. .-,- :......... l15B 6882.6 Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, fri, composed of 60-80% qtz, 20-30% dk slty mtx, 5-10% glauc, poss sid-ank in spl. ....... l16A 6883.2 Sandstone - It olvgy, vf-mgr, pred fgr, vwell srtd, sbrd-rd, fri, composed of 80% qtz, 20% dk slty mtx, tr-l% glauc, poss sid-ank in spl. l16B 6883.8 Sandstone - olvgy, vf-mgr, pred f-mgr, well srtd, sbrd-rd, sl fri, composed of 70-80% qtz, 20-30% dk slty mtx, 3-5% glauc, poss sid-ank in spl, qtz ovgwths. ...-........; 117A 6884.2 Sandstone - It olvgy, vf-cgr, pred fgr, well srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% dk slty mtx, tr-1% glauc, poss sid-ank in spl, qtz ovgwths. -. ~ Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Alaska .-.; -I 117B 6884.7 t t 118A 6885.2 -1 -:--, 118B 6885.7 ...., l19A 6885.2 -, ~""""', 119B 6885.8 120A 6887.2 (-.. , -' 120B 6887.7 "" 121A 6888.2 121B 6888.7 --. -- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - It olvgy, wht, vf-mgr, pred fgr, well srtd, sbrd-rd, v well cons, composed of 70-80% qtz, 20-30% dk slty mtx, 1-3% glauc, poss sid-ank in spl, qtz ovgwths, mnr vugs. Sandstone - It olvgy, wht, vf-mgr, pred fgr, well srtd, sbrd-rd, v well cons, composed of 70-80% qtz, 20-30% dk slty mtx, 1-3% glauc, poss sid-ank in spl, qtz ovgwths, mnr vugs. Sandstone - olvgy, vf-cgr, pred fgr, well srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20- 30% dk slty mtx, tr-1% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - It olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, sl fri, composed of 60-70% qtz, 30-40% dk slty mtx, tr glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-mgr, pred fgr, v well srtd, sbrd-rd, sl fri-well cons, degree of cons varies, composed of 60-75% qtz, 20-30% dk slty mtx, 3-5% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - It olvgy, vf-mgr, pred f-mgr, well srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% sIt, tr glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, sl fri, composed of 60-70% qtz, 30-40% dk slty mtx, tr glauc, poss sid-ank in spl. Sandstone - olvgy, vf-cgr, pred f-mgr, p srtd, sbrd-rd, fri, composed of 75% qtz, 20-25% glauc, 5% sIt, poss sid-ank in spl. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, rd-wrd, fri, composed of 60-70% qtz, 20-30% dk slty mtx, 10% glauc, poss sid-ank in spl, qtz ovgwths. ----' .-6. Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska ~ 122A 6889.2 ""'" 122B 6889.6 - .....,. 123A 6890.2 123B 6890.8 124A 6891.3 ^¡ 124B 6891.7 - 125A 6892.2 ".... --' 125B 6892.7 ~- 126A 6893.2 126B 6893.7 ~ Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, rd-wrd, fri, composed of 80% qtz, 5-10% dk slty mtx, 10-20% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-mgr, pred fgr, vwell srtd, sbrd-rd, vwell cons, composed of 70-80% qtz, 20- 30% dk slty mtx, 5% glauc, poss sid-ank in spl, qtz ovgwths. Sandstone - olvgy, vf-cgr, pred f-mgr, mod srtd, rd-wrd, fri, composed of 80% qtz, 10-15% gauc, 5% sIt. Sandstone - olvgy, vf-cgr, pred f-mgr, mod-p srtd, sbrd-rd, fri, composed of 70% qtz, 20% glauc, 5- 10% sIt, poss mnr sid-ank cmt. Sandstone - It olvgy, vf-cgr, pred fgr, well srtd, sbrd-rd, fri, composed of 70% qtz, 20% glauc, 5- 10% sIt, poss mnr sid-ank cmt. Sandstone - It olvgy, vf-cgr, pred fgr, well srtd, sbrd-rd, fri, composed of 70% qtz, 20% glauc, 5- 10% sIt, poss mnr sid-ank cmt, open frac present. Sandstone - It olvgy, vf-cgr, pred f-mgr, mod srtd, sbrd-rd, fri, composed of 80% qtz, 15-20% glauc, 5% sIt, poss mnr sid-ank cmt. Sandstone - It olvgy, vf-cgr, pred fgr, well srtd, sbrd-rd, sl fri, composed of 60-70% qtz, 15-20% glauc, 15-20% sIt, poss mnr sid-ank cmt. Sandstone - It olvgy, wht, vf-mgr, pred fgr, well srtd, sbang-sbrd, well cmtd, poss sid-ank cmt, composed of 60-80% qtz, 20-30% sIt and cmt, 5-10% glauc, vuggy, open to closed frac present. Sandstone - olvgy, vf-mgr, pred fgr, vwell srtd, sbrd-rd, fri, composed of 80% qtz, 15-20% sIt, 5- 7% glauc, poss sid-ank in spl. -! Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska -! -, l27A 6894.2 J(.....~ l27B 6894.8 --, l28A 6895.2 ....., l28B 6895.7 -, l29A 6896.2 .r-_ l29B 6896.7 - l30A 6897.1 t....." l l30B 6897.8 -' ,-. l3lA 6898.3 l31B 6898.7 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l25l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, grades to m-cgr, mod srtd ss, spl is fri, composed of 80% qtz, 15-20% sIt, 5-7% glauc, poss mnr sid-ank in spl. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 80% qtz, 10-15% glauc, 5% sIt, poss sid-ank in spl, open frac present. Sandstone - olvgy, fgr, 1-3% mgr sd, vwell srtd, sbrd-rd, fri, composed of 70% qtz, 15% glauc, 15% sIt. Sandstone - olvgy, f-mgr, pred fgr, vwell srtd, sbrd-rd, fri, composed of 70% qtz, 15% glauc, 15% sIt, poss sid-ank in spl. Sandstone - It olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, sl fri, composed of 70% qtz, 20% sIt, 10% glauc, poss sid-ank in spl. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 65% qtz, 20% sIt, 15% glauc, poss sid-ank in spl. Sandstone - It olvgy, vf-mgr, pred fgr, vwell srtd, rd-wrd, fri, composed of 70% qtz, 15% sIt, 15% glauc, poss mnr sid-ank in spl. Sandstone - It olvgy, vf-mgr, pred fgr, well srtd, sbang-sbrd, well cmt, dnse, poss sid-ank cmt, spl is composed of 60% qtz, 30% sIt and cmt, 10% glauc. Sandstone - It olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, vwell cmtd, dnse, poss sid-ank cmt, spl is composed of 50-60% qtz, 30-40% sIt and cmt, 10% glauc, open frac present. Sandstone - It olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, vwell cmtd, dnse, poss sid-ank cmt, spl is composed of 50-60% qtz, 30-40% sIt and cmt, 10% glauc, open frac present. - . ./ -^- r'\ Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Alaska ---¡ -, 132A 6899.3 ."-"~ l32B 6899.6 ,-, j ...,.., 133A 6900.2 'J ~, l33B 6900.9 -----, 134A 6901.2 - 134B 6901.7 - '"-" , 135A 6902.2 l35B 6902.7 ...... 136A 6903.1 '"'"'" ~ Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-125l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-mgr, pred vfgr, vwell srtd, rd-wrd, fri-mod cons, degree of cons varies, poss sid-ank cmt, spl is composed of 60% qtz, 20% glauc, 20% sIt and cmt. Sandstone - dk grngy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 70-80% qtz, 15-20% glauc, 5-10% sIt, poss mnr sid-ank in spl, open frac present. Sandstone - dk grngy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 75% qtz, 10-15% glauc, 10-15% sIt, poss mnr sid-ank in spl. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 70% qtz, 5-10% glauc, 15-20% sIt and cmt~ poss sid-ank in spl, closed vuggy frac present. Sandstone - dk grngy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 60-70% qtz, 25-30% glauc, 5-10% sIt. Sandstone - dk grngy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 60-70% qtz, 25-30% glauc, 5-10% sIt, open to closed frac present. Sandstone - It olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, vwell cmtd, poss sid-ank cmt, dnse, spl is composed of 30-50% qtz, 30-40% sIt and cmt, 10-15% glauc, carb plant foss present. Sandstone - olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, vwell cmtd, poss sid-ank cmt, spl grades to a f-mgr, mod srtd, sl fri ss, percent of qtz and cmt varies in spl, abnt glauco Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbang-sbrd, well cons, poss sid-ank cmt, spl is composed of 60-70% qtz, 20-30% cmt and sIt, 5-10% glauc. ,... Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska ,^" ~36B 6903.7 ,~~ ~37A 6904.2 - ~37B 6904.7 ~38A 6905.3 ,..;.,,;,... l38B 6905.8 ~ ~39A 6906..4 ,¡S o" ~39B 6906..7 .-. .£.~ ~40A 6907..3 ...,.¡., ~40B 6907.7 ...... ~ ~4~A 6908.0 ..-. --- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-~25~ Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, spl is composed of 70-80% qtz, ~5- 20% glauc, 5% sIt. Sandstone - It olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, spl is composed of 70-80% qtz, 15- 20% glauc, 5% sIt, open to closed frac present. Sandstone - dk grngy, vf-mgr, pred f-mgr, well srtd, sbrd-rd, fri, spl is composed of 60-70% qtz, 25-30% glauc, 5-7% sIt. Sandstone - olvgy, vf-mgr, pred fgr, vwell srtd, sbrd-rd, fri, composed of 60-70% qtz, 15-20% glauc, ~0-~5% sIt, poss mnr sid-ank in spl. siltstone - It olvgy, vsdy, 15-20% vf-fgr glauc, vwell cmtd, dnse, poss sid-ank cmtd. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 70% qtz, 20-30% sIt, 5- ~O% glauc, poss sid-ank cmt in spl. Sandstone - It olvgy, vf-fgr, vwell srtd, sbang- sbrd, vwell cmtd, dnse, poss sid-ank cmt, spl is composed of 40-50% qtz, 30-40% cmt, 20% glauco Sandstone - It olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, well cons-sl fri, degree of cons varies, spl is composed of 40-60% qtz, 20-40% cmt, ~0-20% glauc, spl grades to a dnse cmtd ss, poss sid-ank in spl. Sandstone - olvgy, vf-mgr, pred fgr, well srtd, sbrd-rd, fri, composed of 60% qtz, 20% glauc, 20% sIt and cmt, poss sid-ank in spl. Retort j Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska ,....., ";>, --, 141B 6908.5 "'->, 201A 6911.2 -1 , , 201B 691.1.7 ...;0., 201C 691.1.8 -. 202A 6912.2 "..-J-.... /""""". , 202B 691.2.7 ....----'. > 203A 6913.2 ,"-.. . 203B 6913.7 204A 6914.2 ...--. -- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, sl fri-well cons, spl grades to dnse, sid-ank cmtd ss, percent qtz and cmt varies, 15- 20% glauco Sandstone - olvgy, vfgr, vwell srtd, sbang, vwell cons, well cmtd, poss sid-ank cmt, tr calc, spl is composed of 30-50% qtz, 20-30% glauc, 15-25% mtx, horz calcxl filled frac present. Sandstone - olvgy, vfgr, vwell srtd, sbang, vwell cons, well cmtd, poss sid-ank cmt, tr calc, spl is composed of 30-50% qtz, 20-30% glauc, 15-25% mtx. Sandstone - olvgy, vf-fgr, well srtd, sbang, well cons, partially si-ank cmtd, spl is composed of 50-70% qtz, 10-20% glauc, 10-15% slty mtx, tr mica, mnr calcxl frac. Sandstone - olvgy, vf-fgr, pred fgr, vwell srtd, sbang, well cons, composed of 60-70% qtz, 10-20% glauc, 10% slty mtx, tr mica. Sandstone - olvgy, vf-fgr, pred fgr, vwell srtd, sbang, well-mod cons, composed of 70-80% qtz, 10- 15% glauc, 10% slty mtx, tr mica, closed horz frac present. Sandstone - It olvgy, vf-fgr, pred vfgr, well srtd, sbang-sbrd, well-mod cons, composed of 80% qtz, 10-15% slty mtx, 5-10% glauc, tr mica. Sandstone - It olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, well-mod cons, composed of 80% qtz, 10-15% slty mtx, 5-10% glauc, tr mica. Sandstone - It olvgy, vf-fgr, pred fgr, well srtd, sbang-sbrd, well-mod cons, composed of 80% qtz, 10-15% slty mtx, 5-10% glauc, tr mica. .- . Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Alaska ¡P- . ^ ". - I 204B 6914.7 ."..::::.. 1 J 205A 6915.2 -1 205B 6915.8 ~l .-0-, 206A 6916.2 -, 206B 6916.7 207A 6917.2 -, 207B 6917.7 -, - 208A 6918.2 208B 6918.7 -- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description siltstone - It olvgy, vsdy, vwell cmtd, poss sid- ank cmt, tr calc, abnt glauc, spl grades to a vf- fgr well cmtd ss, calcxl frac .1mm in width present. Sandstone - It olvgy, vf-fgr, pred vfgr, vwell srtd, sbang-sbrd, well cons, calc cmtd, composed of 60% qtz, 20-30% slty mtx, 5-10% glauc, tr mica. Sandstone - It olvgy, pred vfgr, vwell srtd, sbang-sbrd, vwell cons, partially sid-ank cmtd, sl calc, spl is composed of 50-60% qtz, 20-30% slty mtx and cmt, 5-10% glauco Sandstone - It olvgy, vf-fgr, pred vfgr, well srtd, sbang-sbrd, well cons, sl calc, composed of 60% qtz, 10-20% slty mtx, 10-20% glauc, 1-2% mica, tr dk lith frags, cgr qtz ovgwths present. Sandstone - olvgy, vf-fgr, pred vfgr, well-mod srtd, sbang-sbrd, well cons, composed of 60% qtz, 10-20% slty mtx, 15-20% glauc, tr mica, cgr qtz ovgwths, horz closed frac present. Sandstone - It olvgy, vf-mgr, pred vfgr, well srtd, sbang-sbrd, well cons, composed of 60-70% qtz, 10-15% slty mtx, 10-20% glauc, tr mica, tr dk lith frags, cgr qtz ovgwths present. Sandstone - olvgy, vf-mgr, pred fgr, 3-5% cgr qtz ovgwths, mod srtd, sbang-sbrd, well cons, poss sid-ank mnr cmt, spl composed of 50% qtz, 20-30% glauc, 15-25% slty mtx, 1-3% mica, broken spl. Sandstone - olvgy, vf-mgr, pred fgr, 3-5% cgr qtz ovgwths, mod srtd, sbang-sbrd, vwell cons, poss sid-ank mnr cmt, spl composed of 50% qtz, 20-30% glauc, 15-25% slty mtx, 1-3% mica. Sandstone - olvgy, vf-mgr, pred fgr, 3-5% cgr qtz ovgwths, mod srtd, sbang-sbrd, vwell cons, poss sid-ank mnr cmt, spl composed of 50% qtz, 20-30% glauc, 15-25% slty mtx, 1-3% mica. .... .-'- I Arco Alaska, ILIC. KRU #3H-9 Kuparuk River Unit North Slope, Alaska j ..-"-\ j ~.' 1 --, 209A 6919.2 ~-, ~~ 209B 6919.6 --'1 210A 6920.2 -"".., "'-.., 210B 6920.7 ~ 211A 6921.2 ~, 211B 6921.7 .-, , ...>.. 212A 6922.2 ~' 212B 6922.7 .-... Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - It olvgy, vf-mgr, pred vf-fgr, 3-5% cgr qtz ovgwths, mod srtd, sbang, vwell cmtd, dnse, poss sid-ank cmt, composed of 40-50% qtz, 30-40% cmt and mtx, 10-15% mgr glauc, mnr vugs, spl grades to dnse sltst, mnr sub horz calcxl frac present. Sandstone - olvgy, vf-mgr, pred vf-fgr, 5-7% cgr qtz ovgwths, pred well srtd, sbang-sbrd, well cons, poss sid-ank cmt, sp1 is composed of 50-70% qtz, 10-20% glauc, 10-15% slty mtx, tr mica. Sandstone - It olvgy, vf-mgr, pred fgr, 5% cgr qtz ovgwths, well-mod srtd, sbang-sbrd, vwell cmtd, dnse, poss sid-ank cmt, spl is composed of 40-50% qtz, 30-40% cmt and sIt, 10-15% mgr glauc, mnr vugs, spl grades to dnse sltst. Sandstone - olvgy, vf-mgr, pred vf-fgr, 3% cgr qtz ovgwths, well-mod srtd, sbang-sbrd, well cons, poss sid-ank cmt, composed of 50-60% qtz, 15-25% glauc, 10-20% slty mtx, tr mica. Sandstone - olvgy, vf-mgr, pred vf-fgr, 7% cgr qtz ovgwths, mod srtd, sbang-sbrd, well cons, poss sid-ank cmt, composed of 50-60% qtz, 20-25% glauc, 15-20% slty mtx, tr mica. Sandstone - olvgy, vf-vcgr, pred f-mgr, 1% grn1s, 10-15% cgr qtz ovgwths, spl is psrtd, ang-sbang, well cons, composed of 50-60% qtz, 15-20% glauc, 15-20% slty mtx, tr mica. siltstone - m-dkgy, 10-15% dkgy, arg, mdst lams, sltst is vsdy, well cons, tr mica, abnt vfgr sdy burs, 1% cgr qtz ovgwths. siltstone - m-dkgy, 10-15% dkgy, arg, mdst lams and burs, sltst is pred arg, well cons, 3-5% mica, horz sd filled frac present, mnr pyr bleb, slickensides present. - --' I Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, A1.aska .J "'"\ "'\ I .-, J 2l3A 6923.6 ,....., 2l4A 692-',1.7 --¡ 215A 6925.3 ~q, -'" 1 216A 6926.5 217A 692:7.5 ~...... ... 218A 6928.7 ~ 219A 6929.2 - 220A 6930.5 ~ ~ 221A 693.1. 3 -' 222A 693.2.7 223A 693.3.7 -'" 224A 6934.6 ..->-. - 225A 6935.3 -, .- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 20% olvgy, sdy, mic, bdd sltst, mdst is pred arg, well cons, sl calc, with sdy burs, tr mica, tr pyr. Mudstone - dkgy, 30% olvgy, sdy lam sltst, mdst is pred arg, well cons, tr mica, abnt slicken surfaces. Mudstone - dkgy, 30-40% It olvgy, vf-fgr, well srtd, intlam ss, mdst is sdy in places, pred arg, well cons, mnr pyr, slicken surfaces, open fracs present, bioturb. siltstone - It olvgy, 20-30% dkgy mdst burs, sltst is sdy, well cons, vmic, slicken surfaces present. Retort Mudstone - dkgy, 20-30% It olvgy, vsdy, thn intbd sltst, mdst is pred slty, mic, well cons. Retort Mudstone - dkgy, 20-30% It olvgy, vsdy, thn intbd sltst, mdst is pred slty, mic well cons, tr pyr, horz open frac present. Mudstone - olvgy, 45-50% olvgy bioturb, slty lams, mdst is pre arg, lam, 1-3% vfgr qtz sd, 1% mica. Mudstone - olvgy, 50-60% olvgy, slty lams, mdst is pred arg, lam, well cons, 1% mica, abnt bioturb. Mudstone - dk olvgy, 25-30% olvgy slty lams, mdst is pred arg, lam, well cons, 1% mica, tr bioturb. Mudstone - dkgy, 30-40% olvgy slty lams, mdst is pred arg, lam, well cons, 1% mica, tr bioturb, spl broken. Mudstone - dkgy, 10-20% olvgy, slty lams, mdst is pred arg, lam, well cons, 5% pyr, 1% mica, tr bioturb. -- i Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, AJaska ~ I ,(-'1 .-, 226A 6936.4 1 .~~ 227A 693?5 --, 228A 6938.5 -, 229A 6939.7 -" 230A 6940.7 >-"- ' 231A 6941.7 ,,-... 232A 6942.5 .... ........~ ) 233A 694.3.6 234A 6944.5 ...... 235A 6945.7 - 236A 6946.5 237A 6947.6 -- Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 30-40% olvgy, bioturb slty lams, mdst is pred arg, lam, well cons, 1-3% vfgr qtz sd, 1% mica, spl broken. Mudstone - dkgy, 30-40% olvgy, thnly bdd sltst, mdst is pred arg, thnly bdd, well cons, 1-3% vfgr qtz sd, 1% mica, spl broken. Mudstone - dkgy, 30-40% olvgy slty lams, mdst is pred arg, lam, well cons, 1-3% vfgr qtz sd, 1 % mica, mnr bioturb. Mudstone - dkgy, 40-50% olvgy slty lams, mdst is pred arg, lam, well cons, 1-3% vfgr qtz sd, 1 % mica, mnr bioturb, open frac present. Mudstone - 5-10% 1tgy, slty lams, mdst is pred arg, lam, well cons, 1% mica, tr bioturb. siltstone - olvgy, 95% olvgy, thnly bdd slt, well cons, 1% pyr blebs, mnr bioturb, open frac present. Mudstone - dkgy, 15-20% olvgy slty lams, mdst is pred arg, lam, well cons, 1% mica, mod bioturb, open frac present. Mudstone - gyblk, 95% thnly bd arg mdst, well cons, 1% mica, open frac present. Mudstone - dkgy, 30-40% olvgy slty lams, mdst is pred arg, lam, well cons, 1-3% vfgr qtz sd, 1 % mica, mnr bioturb, sp1 broken. Mudstone - gyblk, pred arg, thnly bdd well cons, tr mica, tr bioturb. Mudstone - olvgy, thn1y bdd slty mdst, 5% ltgy slty lams, well cons, tr mica, tr bioturb. Mudstone - olvgy, 50% olvgy bioturb, slty lams, mdst is pred arg, lam, well cons, 3-5% vfgr qtz sd, 1 % mica, abnt bioturb. - - ~ Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Ala!ska ~ 238A 6948.4 -'" 239A 6949.6 --- 240A 6950.5 241A 6951.3 242A 6952.,7 -",. 243A 6953.,6 ,.... 244A 6954..2 245A 6955..7 ..-, 246A 6956..5 - 247A 6957,.6 ..... 301A 6971.2 302A 6972.2 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 60-70% olvgy, slty lams, mdst is pred arg, lam, well cons, tr mica, tr bioturb. Mudstone - dkgy, 50% olvgy, slty lams, mdst is pred arg, lam, well cons, 1% mica, mod bioturb. Siltstone - It olvgy, 20-30% dkgy, arg lams, well cons, 1% mica, x-bdd, mnr bioturb. Mudstone - dkgy, 10-20% olvgy, slty lams, well cons, 1% mica, mod bioturb. siltstone - olvgy, 10-20% dkgy arg lams, 10-20% vfgr qtz ss, well cons, tr mica, abnt bioturb. siltstone - olvgy, 20-30% dkgy, arg lams, well cons, 1% mica, mod bioturb. siltstone - olvgy, 10-20% dkgy, mdst lams, sltst is vsdy, well cons, 1-3% mica, tr pyr, spl grades to vfgr ss. Sandstone - It olvgy, 10-15% dkgy, lam mdst, ss is vfgr, vwell srtd, sbang-sbrd, well cons, composed of 70-80% qtz, 10-20% sIt, horz open frac present. Sandstone - It olvgy, vf-fgr, vwell srtd, sbang- sbrd, mod cons, composed of 80-9C% qtz, 5-10% sIt, tr-1% mica. Sandstone - It olvgy, vf-fgr, vwell srtd, sbang- sbrd, sl fri, composed of 90% qt2, 5-10% sIt, tr mica. Sandstone - olvgy, 30% dkgy, sIt}', mic, lam mdst, ss is vfgr, vwell srtd, sbrd, well cons, composed of 60-70% qtz, 10-20% slty mtx, ':;-5% mica. Sandstone - olvgy, 30% dkgy, sIt}', mic, lam mdst, ss is vfgr, vwell srtd, sbrd, weJl cons, composed of 60-70% qtz, 10-20% slty mtx, ~.-3% mica, 1-2% pyr blebs. ...... i j Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, AIaska 7"- ~""- j . 1 303A 6973.5 304A 697,4.3 '~-1 305A 6975.3 306A 6976.4 ~ ) 307A 6977.6 ....... 308A 6978.6 ....-=-- 309A 6979.5 -- 310A 6980.5 311A 6981.4 3l2A 69612.5 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-l25l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Descripticn Sandstone - olvgy, 20% dkgy, slty, mic, lam mdst, ss is vfgr, vwell srtd, sbrd, WEll cons, composed of 60-70% qtz, 10-20% slty mtx, 1% mica, tr pyr blebs, mnr bioturb, open to cloE.ed frac present. Sandstone - olvgy, 30% dkgy, slty, lam mdst, ss is vfgr, vwell srtd, sbang-sbrd, WEill cons, composed of 70-80% qtz, 10-20% slty mtx, tr mica, tr pyr, mnr sdy burs, horz open frac prE!Sent. Sandstone - It olvgy, tr-1% mdy lams, ss is pred vfgr, vwell srtd, sbrd-rd, sl fl'i, composed of 90% qtz, 5-10% sIt, tr-1% mica. Sandstone - It olvgy, tr-l% mdy lams, ss is pred vfgr, vwell srtd, sbrd-rd, 51 fl'i, composed of 90% qtz, 5-10% sIt, tr-l% mica. Sandstone - It olvgy, 10% dkgy, pred arg, thnly bdd mdst, ss is vfgr, vwell srtd, sbang-sbrd, well cons, composed of 80% qtz-, 20% ulty mtx, tr mica. Sandstone - olvgy, tr mdy lams, ss is vfgr, vwell srtd, sbang-sbrd, 51 fri, compoued of 80-90% qtz, 5-10% slty mtx, tr-1% mica. Sandstone - olvgy, tr mdy lams, ss is vfgr, vwell srtd, sbang-sbrd, sl fri, compoHed of 80-90% qtz, 10% sIt, tr-1% mica. Sandstone - olvgy, tr mdy lams, vwell srtd, sbrd, fri, composed of 90% qtz, 10% s.[t, tr mica. Sandstone - olvgy, tr mdy lams, vfgr, vwell srtd, sbrd, 51 fri, composed of 80-90~ qtz, 10-15% sIt, tr-1% mica, tr pyr. Sandstone - olvgy, tr mdy lams, vfgr, vwell srtd, sbrd, sl fri, composed of 80-90~ qtz, 10-15% sIt, 1-2% mica. ~ - Arco Alaska, Inc. KRU #3H-9 Kuparuk River unit North Slope, Alaska _J 3l3A 6983.2 314A 6984.5 --- 315A 6985..2 ->'. 316A 6986..5 -- 317A 6987..4 .-'" 318A 6988..4 ---- 319A 6989..3 -'" 320A 6990..6 ,..:.... 321A 6991..5 322A 6992..8 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : .pile : BP-3-125l Lab : Anchorage Geolo¡ist : G. Crosky Detailed Lithological Description Sandstone - olvgy, 20% dkgy, slty, mic, bdd mdst, ss is vfgr, vwell srtd, sbang-sbrà, mod cons, composed of 80% qtz, 20% sIt, tr-l% mica, sdy burs, spl broken. Sandstone - It olvgy, tr mdy lams, ss is vfgr, vwell srtd, sbrd, sl fri, composed of 80% qtz, 20% sIt, tr mica, tr pyr. Sandstone - It olvgy, 20% dkgy, slty, mic, bdd mdst, ss is vfgr, vwell srtd, sbang-sbrd, sl fri, composed of 70-80% qtz, 20% sIt, 3-5% mica in places, horz open to closed frac present. Sandstone - olvgy, vfgr, well srtd, sbrd, sl fri, composed of 80-90% qtz, 10-20% sIt, tr-1% mica, tr mdy lams. Sandstone - olvgy, 5% mdst lams, ss is vfgr, well srtd, sbrd, sl fri, composed of 80-90% qtz, 10-20% sIt, 1-2% mica, 1% pyr. Sandstone - olvgy, vfgr, vwell sztd, sbrd, sl fri, composed of 90% qtz, 10% sIt, tr mica. Sandstone - olvgy, 5% mdst lams, ss is vfgr, well srtd, sbang-sbrd, sl fri, composed of 70-80% qtz, 20-25% sIt, tr-1% mica, tr pyr. Mudstone - dkgy, 40% olvgy, vfgr, well srtd, sbang-sbrd, bdd ss, mdst is pred slty, 5-7% mica, 2-3% pyr blebs, horz open frac pzesent. Sandstone - olvgy, vfgr, well srtd, sbrd, mod cons, composed of 70-80% qtz, 20% sIt, tr mica. Sandstone - olvgy, tr mdy lams, 5S is vfgr, well srtd, sbang-sbrd, mod cons, compcsed of 70-80% qtz, 20-25% sIt, 2% mica, 1-2% fn pyr. - - Arco Alaska, Inc. KRU #3H-9 Kuparuk River mait North Slope, Al.:iska ,- 323A 6993.8 324A 6994.2 .-" 325A 6995.3 326A 6996.2 ....... 327A 6997.3 ~ 328A 6998.5 ...... ~ 329A 6999.7 330A 7000.3 - 331A 7001.4 332A 7002.4 ~ Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological DescriptioI[ Sandstone - olvgy, 30% dkgy, slt}', intbd mdst, ss is vfgr, well srtd, sbrd, mod COIlS, composed of 70% qtz, 20-25% slt, tr-1% mica, tr-1% pyr, horz open frac present. Mudstone - dkgy, 30-40% olvgy, vj'gr, well srtd, sbrd, bdd ss, mdst is pred slty, well cons, 5-7% mica, vert open frac present. Sandstone - olvgy, 5-10% mdy lamH, ss is vfgr, well srtd, sbang-sbrd, well cons, composed of 70- 80% qtz, 20-30% slt, 1-2% mica, npl grades to vsdy sltst. Siltstone - olvgy, 10-20% dkgy, nlty vmic, intbd mdst, sltst is vsdy, well cons, ~~% mica, spl grades to slty vfgr ss. Mudstone - dkgy, 20% olvgy, vsdy, bdd sltst, mdst is pred slty, mic, 1% pyr, sdy burs, horz open frac present. Sandstone - lt olvgy, 10% dkgy, ndy lams, ss is vfgr, vwell srtd, sbrd, well-mod cons, composed of 80% qtz, 20% slt, tr mica, tr PYJ':', mnr bioturb, subhorz open to closed frac presEmt. Siltstone - olvgy, 30% dkgy, slty, mic, thkly lam mdst, sltst is vsdy, arg, well cons, 2-3% mica, 1% pyr, spl broken. Sandstone - olvgy, vfgr, well srl:d, sbrd, well cons, composed of 70-80% qtz, 20,,30% slt, 3-5% mica in places, tr mdy lams. Sandstone - olvgy, vfgr, well srl:d, sbrd, well cons, composed of 70-80% qtz, 20"30% slt, 3-5% mica in places, 2-3% mdy lams. Mudstone - dkgy, 10-20% olvgy, vfgr sdy lams and burs, mdst is pred arg, lam, grades to slty mdst, well cons, 3-5% mica, horz open t:o closed frac present. ~ Arco Alaska, InC'. KRU #3H-9 Kuparuk River unit North Slope, Alaska '-" - 333A 7003.3 334A 7004.3 335A 7005.5 336A 7006.4 337A 7007..3 338A 7008..3 339A 7009..4 340A 7010.,4 J'"""'- 341A 7011.4 342A 7012..8 ,...... Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : F'ile : BP-3-l251 Lab : Anchorage Geolo7ist : G. Crosky Detailed Lithological Description Sandstone - olvgy, 30-40% dkgy, s2y,slty, lam mdst, bioturb, ss is vfgr, well s~td, sbrd, well cons, composed pred of qtz and sIt, 1% mica. Mudstone - dkgy, 15-20% vfgr, sdy burs, mdst is pred arg, mic, well cons, tr pyr, closed frac present. Siltstone - olvgy, 20% dkgy, lam mdst, sltst is vsdy, well cons, 3-5% mica in places, grades to vfgr, slty ss, horz open frac present. Mudstone - dkgy, 40-50% It olvgy, vfgr, well srtd, sbrd, intbd ss, composed pred of qtz and sIt, mdst is pred arg becoming vsdy, 3-5% mica, horz open frac present. Mudstone - dkgy, 20% olvgy, sdy, bdd sltst, mdst is arg, becoming vsdy, 1-3% mica, mnr vfgr sdy burs, bioturb, horz open frac present. Mudstone - dkgy,15-20% olvgy, vfgr, well srtd, sbrd, well cons, intbd ss, mdst is pred slty, bioturb, 3-5% mica, horz open frac present. Mudstone - dkgy, 30% olvgy, vfgr, well srtd, sbrd, well cons, intbd ss, composed of qtz, mdst is pred slty, sdy in places, well cons, 1% mica, bioturb. Sandstone - olvgy, 40-50% dkgy, slty, mic, bioturb mdst, ss is vfgr, well srtd, sbré', well cons, composed of 80% qtz, 20% sIt, 1% mica, 2% pyr blebs. Sandstone - It olvgy, 20-30% dkg}', slty, intbd mdst, ss is vfgr, well srtd, sbré', well cons, composed of 80% qtz, 15-20% slt, 2-3% mica, pyr filled frac .4mm in width. Sandstone - olvgy, 15% dkgy, preé' arg, intbd mdst, ss is vfgr, well srtd, sbrd, mod cons, composed of 70% qtz, 30% sIt, tr-1% mica. , ~ Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alé!ska 343A 7013.7 344A 7014.5 345A 7015.4 346A 7016.5 - 347A 7017..3 348A 7018..8 349A 7019..4 ~ 350A 7020,.5 351A 7021.2 352A 7022.5 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : pile : BP-3-l251 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 30-40% sdy intbd bioturb sltst, mdst is pred slty, sdy, well cons, 1% mica, tr-1% pyr, vfgr sdy burs, subhorz open trac present. Sandstone - 40% dkgy, pred arg, lam mdst, ss is vfgr, well srtd, sbang-sbrd, well cons, composed of 70% qtz, 30% sIt, 1% mica, tr-1% pyr, subhorz open frac present. Mudstone - dkgy, 20% olvgy, vfgr bioturb ss, mdst is pred slty and sdy, well cons, 1-2% mica, horz open to closed frac present. Mudstone - dkgy, 30-40% olvgy, vfgr, well srtd, sbrd, mod cons, intbd ss, composed of 80% qtz, 20% slt, mdst is pred slty, sdy in places, 1-2% mica, abnt bioturb. Sandstone - olvgy, 50% dkgy, hvy bioturb mdst, ss is vfgr, well srtd, sbang-sbrd, well cons, composed of 80% qtz, 15-20% sIt, 1% mica, 1-2% pyr replaced burs. siltstone - olvgy, 30-40% hvy bicturb mdst, sltst is vsdy, well cons, 1-2% mica, mnr vfgr sdy burs. Mudstone - dkgy, 10-20% olvgy, vsdy, mic, bioturb sltst, mdst is pred arg, slty, well cons, 5-7% mica, spl broken. Sandstone - olvgy, 40% dkgy, preå slty, mic, bioturb lam mdst, ss is vfgr, well srtd, sbrd, well cons, composed of 80% qtz, 20% sIt, open to closed frac present. siltstone - olvgy, 20% dkgy, slty, mic bioturb lam mdst, sltst is vsdy, well cons, 1% mica, mnr vfgr sdy burs. Siltstone - It olvgy, 30-40% dkgy, bioturb bdd mdst, 10% vfgr, well srtd, sbrd, bdd ss, sltst is vsdy, 1% mica, well cons, open tc closed frac present. · I Arco Alaska, Inc. KRU #3H-9 Kuparuk River L~it North Slope, A1.aska ~. '-I 353A 7023.8 ~ , 354A 702,=1.7 1 355A 7025.5 356A 7026.6 -, 357A 7027.5 358A 70213.7 - 359A 7029.6 360A 7030.6 - 401A 703.1.8 - 402A 703.2.5 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-125l Lab : Anchorage GeolJgist : G. Crosky Detailed Lithological Description Sandstone - It olvgy, 5% dkgy,mdy lams, ss is vfgr, vwell srtd, sbrd, mod cons, composed of 80- 90% qtz, 10-20% sIt, 1% mica, tr pyr. Mudstone - olvblk, 30% It olvgy, vfgr, well srtd, sbrd, intbd ss, mdst is pred arg, sdy, well cons, vert open frac present. Sandstone - It olvgy, 20-30% dkgy, pred arg, sdy, bioturb, lam mdst, ss is vfgr, well srtd, sbrd, well cons, composed of 80% qtz, 20% sIt, open to closed frac present. Sandstone - It olvgy, 15-20% dkgy, bioturb, lam mdst, ss is vfgr, well srtd, SbId, well cons, composed of 80% qtz, 20% sIt, tI-l% mica. Mudstone - dkgy, 40-50% ltolvgy, vfgr, well srtd, sbrd, bioturb lam ss, mdst is pIed slty, spl is well cons. Mudstone - dkgy-blk, 30-40% olvgy, vfgr, well srtd, sbrd, mod cons, intbd ss, mdst is slty, sdy, well cons, tr-l% mica, open to closed frac present. Sandstone - It olvgy, 30% dkgy, sdy, mic, bioturb, intbd mdst, ss is vfgr, well srid, sbrd, well cons, composed of 80% qtz, 20% Æ'lt. Sandstone - It olvgy, 20% dkgy, pred arg, thkly lam mdst, ss is vfgr, well srtd, sbrd, well cons, composed of 70-80% qtz, 20-25% t,:lt, 2-3% mica. Sandstone - It olvgy, 15-20% dk~~, pred arg, mic, lam mdst, ss is vfgr, well srtd, sbrd, well cons, composed of 80% qtz, 20% sIt. Sandstone - It olvgy, 5% mdy laIls, ss is vfgr, well srtd, sbrd, well cons, composed of 80% qtz, 15-20% sIt, tr-l% mica, tr pyr. Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska 414A 7044.2 415A 7045.6 416A 7046.5 417A 7047.6 4l8A 7048.5 419A 7049.6 420A 7050.5 -'- 421A 7051.3 422A 7052.3 423A 7053.3 424A 7054.4 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : File : BP-3-1251 Lab : Anchorage Geoloqist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 20-30% It olvgy, vfgr, hvy bioturb ss, mdst is slty, sdy, well cons, 1% mica, tr pyr, horz open frac present. Mudstone - dkgy-blk, 15-20% It olvgy, vfgr, bioturb ss, mdst is slty, sdy, well cons, tr mica, horz open to closed frac present. Mudstone - dkgy-blk, 15-20% It olvgy, vfgr, bioturb ss, mdst is slty, sdy, well cons, tr mica, spl broken. siltstone - olvgy, 10-15% dkgy, mdy lams, 20% It olvgy vfgr, bdd ss, sltst is vsdy, 5-10% mica, spl is well cons. siltstone - olvgy, 10-15% dkgy, tioturb and lam mdst, sltst is vsdy, well cons, 1% mica. Mudstone - dkgy, 10-20% olvgy, hvy bioturb vfgr ss, mdst is slty, sdy,- well cons, 1-2% mica, horz open to closed frac present. Mudstone - dkgy, 5-10% It olvgy, lam and bioturb sltst, mdst is pred slty, well cons, 5% mica in places. Mudstone - dkgy, 20-30% It olvgy, vfgr, bioturb ss, mdst is vsdy, slty, well con~~, 1-2% mica, horz open frac present. Mudstone - dkgy, 20% It olvgy, vl'gr, lam ss, mdst is pred slty, well cons, 3-5% mica in places, x- lams, horz open frac present. siltstone - It olvgy, 30% dkgy-bJk, pred slty, mic, bdd mdst, sltst is vsdy, bioturb, spl is well cons. Sandstone - It olvgy, 20% dkgy, l)dd and lam, sdy mdst, ss is vfgr, well srtd, sbrd, well cons, composed of 80% qtz, 20% sIt, 1-3% mica. Arco Alaska, Inc. KRU #3H-9 Kuparuk River Unit North Slope, Alaska 425A 7055.3 426A 7056.6 427A 7057.5 428A 7058.3 Date : 22-Feb-88 Formation : Kuparuk Drlg Fld : Bland Mud Location : rile : BP-3-1251 Lab : Anchorage Geoloqist : G. Crosky Detailed Lithological Description Mudstone - dkgy-blk, 10-20% It ol1Tgy, intbd and lam sltst, mdst is pred slty, mic" well cons, mnr sdy burs, horz open frac present. Mudstone - dkgy-blk, pred arg, 3% pyr replaced burs, tr-1% mica, mnr sdy burs, horz open frac present. Mudstone - dkgy-blk, pred arg, slty, mnr sdy burs, broken spl. Mudstone - dkgy-blk, pred arg, slty, tr sdy burs, horz open frac present. -1 j Littan Core Lab -1 1 ----1 -1 ~l I j -1 -1 _1 _1 ~ 8005 Schoon Street Anchorage. Alaska 99518-3045 (907) 349- 3541 SECTION C Core Analysis Results - Graphic Data Arco Alaska, Inc. KRU #3H-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska Lilian Core Lab ~ SECTION D -, i I APPENDICES -1 Arco Alaska, Inc. KRU #3H-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska ~ -1 ---1 -, -1 -' 8005 Schoon Street Anchorage, Alaska 99518-3045 (907) 349- 3541 J SPE 15185 ." SPE Society of Petroleum E~1ireI~ Automated Core Measurement System for Enhanced Core Data at Overburden Conditions . . by OK Keelan, Core Laboratories Inc. SPE Member ! j Copyright 1986, Society 01 Petroleum Engineers This paper was prepared fOr presentation at the Rocky Mountain Regional Meeting of the Sociely of Petroleum Engineers held ,n Billings, MT. May 19-21,1986. , This paper was selected lor presentation by an SPE Program Committee lollowing review of information contained in an abstr~,ct submitted by the author(s). Contents of the paper. as presented, have not been reviewed by the Society of Petroleum EngIneers and are subject to correction by the author(s), The material, as presented, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Papers presented at SPE meetin\ $ are subject to pubtication review by Editorial Committees of the Society 01 Petroleum Engineers. P,~rmission to copy is restricted to an abstract of not more than 300 words, Illustrations may not be copied. The abstract should contain conspicuous acknowledgment 01 where and by whom the paper is presented, Write Publieations Manager. SPE, P,O. 80. 833836. Richardson, TX 75083-3836. Tele.. n0989. SPEOAL ABSTRACT ;. J A new automated, computer-directed. core meas- urement system furnishes porosity, air permeability, equivalent non-reactive liquid permeability (Klinken- berg), and Forcheimer (turbulence) factor at program- mable, sequential overburden pressures from 500 to 10,000 psi. The system is accurate, precise. and flexible and ·furnishes enhanced routine core data. Capabilities and limitations of the system are dis- cussed. Data are presented for selected rock types and a graphical technique is proposed to relate the system measured porosity and permeability values to uniaxial strain conditions. INTRODUCTION Formations deposited in ancient times were buried under successive layers of sediments, resulting in increasing depth of bu~al and. subsequent compression of the rock pore space.. Core cutting and' retrieval. relieves the reservoir formation pressure and removes' the weight of the overburden deposits, allowing expan- sion of the core. Consequently, routinely. measured porosity and permeability values are higher than those present in the reservoir. ~~. Adjustments to routine data have often been made by applying factors developed by simulating reservoir overburden stress conditions on representative but limited suites of cores from the formations of inter- est. Even then. air permeability data were often measured at low mean pressure in the core sample. resulting 1n gas sllppage and alr permeability values that were higher than at reservoir pressures. Cor- rections for this slippage effect were often applied by using published,çOrrelattons for 'uniform sand- stones, an~ ignore4. ~n more heterogeneous carbonates where . correlat1on.~rè.not 'valid. ,Lc*,permeabllity " . '. < ;".-: >"~i;:~~"-'~-')_";' c ':1.. ai'end Þf¡:;p~per;'i.¡- ..-. ;··'.';f·;··' ···,,,:¡··;~~_:rf;_J;-,;".}·'_ê:'.i; formations have focused attention on the importance of both slippage correction and overburden effects.1,2 The neW' automatE,d, core measurement system offers a first-time capabiLty to routinely and economically measure porosity and permeability at simulated over- burden stress conditions, while simultaneously meas- uring the gas sli¡>P:~ge corrected equivaleTtt liquid permeability as well as the Forcheimer turbulence factor required to predict flow in high-rate wells. When placed in the calibration mode, the system is self-calibrating with self-diagnos1s of valve leak problems if present. Core sequencing and movement into a hydrostatic core holder, appl~cation of up to .;eight selected sequEntial overburdelÌ,:pressure meaS- urements, interim data displaY while~est1ng, calcu- lations and final ètata presentation": are performed automatically while IInder IBM PC control'. . ,Pore volume is dIrectly measured bYhel1U811njecUon into the pore.space,while permeability and turbulence factor are determined during unstead~-statef1OW utilizing prlnc1plesdescribed by Jones. .' REVIEW OF FACTORS Ll'''IITING ROUTINE CORE DATA Gas Slippage Effects Gas slippage effects were documented by Klinken- berg4, and the effE,ct he observed is illustrated on Fig. 1. Unlike non-reactive liquid flow, where perllleabi lity of a rock is a constant, gas perme- ability is seen to "ary linearly with the reciprocal \lean pressure in thE' core. Mean pressure is defIned as the average of the \1p-stre_ and down-strea1D pressure of the ro,:k sample'dudngflow. It is analogous to the fo:rmationpre8.ure.~· At increasing aean pressures the gas molecule. are forced closer ,together such· that thegaSbeco_~'lIOre dense~ behaves ) 1I!ò.... "Ulte .al1quld. ·and.· ba"'jàX'1~el');1iéa8Ut'f!dpèt'lle..·· . ,,',.ti111tY. .At.inUni tell\ean ....pr...ure_)t:beteciProcal '~:,;þtq:::d;:~ede~~d ::d fi~~~tl~~~:~;t~:h~~::~ ~t~e,î;Ç' liquid. "";"'''''':: " -...'. ".-.,~.~. .' -. ... >;Jr:c. ".-. -{;,;, ~ '. 2 AUTOMATED CORE ~!EASUREMENT SYSTEM FOR EN!IAJI;CED CORi:: DATA AT OVERBURDEN CO:-'1)lTIO~S Reservoir TurbLlence (Kinet:lc) Effect:s SPE 15185 Routine permeability data are measured using air at low mean pressure in the core sample. In contrast, gas reservoirs described as "low pressure are at hi¡~h enough mean pressure whereby the reservoir gas perme..bility approaches the equivalent liquid perme- ability from laboratory tests. Results of steady- state flow measurements seen in Fig. I require deter- minations at several mean pressures and then extrapo- lation of the data to infinite mean pressure. These tests are time consuming and expensive and have not been routinely determined despite the more representa- tive reservoir permeability value resulting when the slip-corrected Klinkenberg value is used. Klinkenherg also found that different gasses have different permeahiJity at the same mean pressure but all extrapolate to the same equivalent liquid perme- ,.hi I itv. This results in diffèrent slopes of the gas permeability versus reciprocal of mean pressure 1 ines. This has importance in the automated core measurement system which utilizes helium as the flow- ing gas, and which determines both the slip-corrected permeability and a helium slippage factor (b) propor- tional to slope. The need exists to calculate an equivalent air permeability to serve as a common tie point to previously measured core data where nitrogen or air has been used as the flowing gas. This calcu- lation utilizes the helium determined (b) value, and adjusts it to arrive at a slippage factor of (b) for air. Air permeability at com:nonly used laboratory instrument mean pressure conditions is then calculated using the equation shown on Fi¡.:. \. Overburden Effects ..--' Increasing depth of burial results in increasing weight of overburden sediments tending to compress the formation rock. An overburden gradient of 1 psi per foot of depth is commonly assumed, although a bulk density log can be integrated to compute this overburden value.5,6 The difference between the over- burden pressure and the formation pressure increases with depth as i llust ra ted on Fig. 2, and the dif- ference is commonly referred to as the effective or net overburden pressure (NOB). When formation pres- sure is unknown, it is often calculated by multiplying an assumed salt water gradient of approximately 0.5 psi per foot times the formation depth. The differ- ence of these gradients times depth yields the NOB. It is this NOB that primarily controls formation compaction stress, and it is this NOB that is relieved during the coring process and that is re-applied and simulated in the core measurement system. --' Re-application of net overburden pressures on core samples allows adjustment of routine non-stressed core porosity and permeability data to initial reser- voir net overburden conditions. It also allows both porosity and permeability reduction to be monitored as reservoir pressure declines with a resultant in- crease in net overburden. Normalized data illus- trating these changes in porosity and per~eability were generated from measurements on the core measure- ment system and are illustrated on Fig. 3. Great diversity is observed, and different formations exhib- it widely differing sensitivity to overburden stress. Estimates of reservoir flow can' he made using Darcy equat ions and <ore permeabi 11 ties corrected for slippage, overhurden and relative permeability effects. 40wever, well test data and laboratory data sho\.1 that ahove a critical rate Darcy's equation does not describe fluid or gas flow, but predicts higher flo\.1 rates than the wells can deliver. The lower flo\.1 rate of the well has been attributed to an effect referred to as turbulence, inertial, or kinetic energy losses. This _effect has been studied by Forcheimer and others', and it can be quantified by core r.leasurements Hnd included as an additional term In thp Darcy equation, The turbulence factor has been used to describe pressure losses and to calculate maximum flow rate during non-Darcy turbulent flow into a well bore. It has been combined ,,,ith flowing well analysis to predict the economic effects of perforating conditions as well as the number and size of perforations re- quired to maximize procuction8. The effect of turhulence on flo\.1 is illustrated on Fig. 4 and the Darcy equation I!Iodif led for tubu- lence is sho\.1n. The zero turbulence condftion is illustrated by the straight line, where flow rate per unit cross-section.>! area increases in a linear fashion as the pressure drop per unit length in- creases. Above a critical rate the relationship is no longer linear, and an increase in pressure dif- ferential results in less flow than predicted by Darcy flow. The excess pressure drop is due to turbulent, non-laminar flow, and can be calculated by the product of the turbulence façtor (Beta) times the density Qf the flowing fluid and the square of the velocity. 9 Relative PerTlleability Effects Routine core analysis permeability data are gen- erated with a single non-reactive fluid (gas) in the pores of a cleaned and dried core. In the reser- voir both hydrocarbons and interstitial water are present. The water sometimes reacts with the rock, or occupies pore space such that it interferes wi th hydrocarbon flow, resulting in a lower reservoir permeability to the hydrocarbon than measured during routine core analysis :m the clean and dry core. In many reservoirs of moderate permeability with no rock-water reaction and sufficient height above water to be at a minimum irreducible water, the intersti- tial water does not mo~e and has a negligible effect on hydrocarbon permeability reduction. Routine core permeability data corr~cted for slippage will approxi- mate reservoir values in this case. In other situ- ations, water in the reservoir may reduce hydrocarbon permeability and dry eore Klinkenberg data will be optimistically high. THE CORE MEASUREMENT SYSTEM The core measuremE,nt system routinely and rapidly overcomes all of the factors limiting conventional core data except for the relative permeability effects due to the presence of i rreduci ble water. This can 156 SPE 15185 Dare K. Keelan 3 also be addressed in the system with additional effort and is discussed under Core Saturation Condition that follows. Equipment Description The system is packaged in a compact desk top. front loading chassis approximately 28'" wide by 30'" high and IS'" deep containing back plate connections for helium, nitrogen, vacuum, power and data communi- cations. Major components include (I) an eighteen- sample carousel core plug holder, (2) an automatic load and unlo,¡d system, (3) hydrostatic core holder and pressure application assembly, (4) helium volume reference cells and pressure sensing devices, and (5) computer hardware and software. Equipment Operation The system is self-calibrating when the calibra- tion mode is specified, and utilizes stainless steel center-bored cylindrical standards of known pore vol- ume. It is also self-diagnostic, checking for proper valve operation and system leaks if present. Samples are manually loaded into individually numbered posi- tions within the carousel, which is then positioned in the chassis. Sample identification, length and area, for example, are required input to the IBM PC, and grain volume, bulk volume and weight of the sample are optional. Up to eight overburden pres- sures can be designated, which may include both sequential increasing and then decreasing overburden values. f . At test initiation, Position 1 of the carousel is automatically rotated into position, a vacuum is pulled on the rubber boot wi thin the core holder, and a vertically upward moving hydraulic ram advances and lifts the sample into the rubber boot. After sample insertion, the vacuum is released and the minimum programmed hydrostatic confining stress is applied to the core. A quick permeability approxima- tion measurement is then made for selection of both the upstream volume and pressure to be used during subsequent permeability measurements. . j- ~ } ~ ! Pore volume is then determined by expansion of helium into the core sample from a known volume source at approximately 240 psi. At pressure equili- brium, Boyle I s Law is used to compute pore volume. The difference between the confining stress and the equilibrium pore pressure is the net confining stress. During this operation the overburden and internal pore pressures are monitored with digital readout on the chassis, and by a real t1me visual display of the plot of pore pressure versus time. ~-- J- f , I~ I I- f Permeability is then measured by flowing helium from the previously selected volume reference cell at the selected pressure through the core. The downstream end of the core is maintained at atmos- pheric pressure. The upstream pressure decline is monitored in real time, and is observed by digital readout and visually displayed in either graphical or tabular form. The difference between the confin- ing stress and the mean pore pressure during flow is the net confining stress. Unsteady-state equations developed by Jones are used to calculate the Klinkenberg slip corrected permeability, the helium slip factor, !Ind the For- cheimer turbulence factor.3 Air permeabilit~ is then ca lcula ted as a base to he compa red wi th other non- Klinkenberg measured core information from the field. The next pre-progr!lmmed overburden pressure is then !Ipplied to the sample and measurements are repeated. After the last permeahilit~ measurement is completed for Sample 01, the final selected overburden pressure is released, vacuum ig applied to the rubber hoot releasing the sample, and the core rides downward as the ram retrieves. Data are printed and stored on both hard Rnd floppy disks. The carousel then rotates into the next position and the sequence is repeated until all samples are tested. Data can then be transferred to a central computer for statistical manipulation, graphical dis- play, and core analysis final report generation. CAPABILITIES AND LIMITATIONS Sample Sizes The current carousel will hold a maximum of 18 one-inch diameter cylindrical plugs, 3/4 to 3 1/8 inches in length. Since pore volume is by direct helium injection, sample ends must be essentially parallel, and data indicate well maintained normally used preparation equipment can furnish adequate sam- ples. Core should have square, not rounded, corners and be free of surface vugs and chipped edges. By mid-year, sample-size capabilities will include 1 1/2 inch diameter cores, and a 100 sample holder for either diameter that can be substituted for the carousel. Stress Condi tions The confining stress is applied hydrostatically (equal on all sides) and can vary from 500 to 10,000 psi. A maximum of eight stresses can be programmed, and increasing as well as decreasing stress can be simulated. The miniml~ confining stress to yield porosi ty and permeab ility data comparab Ie to routine zero stress porosity and routine 400 psi stressed core for permeability measurements is apparently a function of the hardness of the rubber boot that surrounds the core. The boot should be soft enough to conform to sample sides at low confining stress, but hard enough so that it will not flow into pore space at high confining stress and fail to properly release the sample at test conclusion. The current boot material requires at least 800 psi confining stress to conform to the samples, but a new design currently under investigation appears promising in allowing the minimum stress to be reduced to 500 psi. Accuracy and Repeatability The system was designed to yield accurate and reproducible permeability values over a range of 0.01 millidarcies to 2 darcies. Test data indicate pore volumes can be determined for a range of 0.02 cc to 10 cc. Tables 1, 2 and 3 and Figures 5, 6 and 7 furnish control data on both one inch diameter steel standards and cor'e samples substantiating design specifications. Control data are commented on in Data and Discussion of Results. 157 4 AUTOMATED CORE ~1EASUREMENT SYSTH1 FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 15185 Sample Consolidation -L. Most tests to date have been made on consolidated cores. Limited data indicate that unconsol1.dated rock mounted in shrinka\¡ Ie tub ing 10 can be run in the device. Investigation of applicability to these type cores as well as metal jacketed samples [5 yet to be completed. -~ Core Saturation Condition _-L The system was designed to test clean, dry cores. Data indicate valid permeability at irreducible water (Swir) can be measured. Multiple cores should not be batch loaded as evaporation will occur while awaiting analysis, and immobile water is necessary to prevent water redistribution during gas flow and movement from the core. Total evaporation during analysis should be monitored by sample weights. Indicated hydrocarbon pore volume (l.O-Swir) reduction due to overburden will be invalid and masked if the volume seen by injected helium increases due to evaporation. -'- DATA AND DISCUSSION OF RESULTS ~~... Accuracy and Repeatability of Steel Standards - Each core measurement system is calibrated at 1500 psig confining stress utilizing stainless steel cylinders of known pore volume. Each is subsequently independently checked with a set of steel standards. - Typical resul ts of a pore volume accuracy and repeatability check are shown in Table I. These tests were run overnight in a laboratory with no special temperature control. Maximum pore volume difference observed in the sequence was 0.035 cc, which yields a maximum porosity error of 0.27 porosity points (Le. 10.0 to 10.27 percent) for a I-inch diameter plug 1 inch in length. This is well within the API RP 40 accepted accuracy of + 0.5 porosi ty point-II Table 2 illustrates pore volume accuracy and consistency between various systems checked with a set of common standards. These locations represent various elevations, barometric pressures and tempera- tures, and excellent agreement is seen in measured pore volumes. Permeability checks on steel standards are shown in Table 3. All fall within the + 5% industry stan- dard for plugs of moderate permeability and reproduci- bility is excellent. Accuracy and Repeatability of Core Plug Standards Suites of cores tested with steady-state perme- ability techniques were used as standards in this evaluation. Air permeability was selected for com- parison as most historical data are in this form and routinely used permeameters develop these data. Mul- tiple measurements were made on carefully calibrated equipment and cross-checked between various instru- ments to arrive at standard values. Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state air permeability measurements. The difference shown is expressed as a percentage of the steady-state value. Three measurements are presented for each sample to illustrate reproducibili.ty. The data indicate three samples with a difference greater than 5% of the standard value. Two are lower permeability samples, of less than one millidarcy. The! 5% limit was set for higher permeability samples, and the tolerance is normally expanded [n the lower range because of the small values measured and sensitivity to mean pressures in the core as permeability becomes lower. For example, If the true air permeability value is 0.020 millidarcies and the tested value found is 0.025, an error of 25% is indicated, although the magnitude of the difference is inconsequential and the permei1bility in both cases is quite small. A much larger (100%) error resul ts from the incorrect use of the air permeab il ity value of 0.02 to repre- sent reservoir permeability rather than the slippage corrected Klinkenberg value of 0.01 determined for this plug. Figure 6 shows comparisons of zero stress meas- urements utilizing a small volume porosimeter (SVP) versus core measuremen t sys tern porosi ty da ta at 800 psi confining stress. Porosity in the system has been calculated using various equations that require different basic data. The zero stress equation util- izes bulk volume determined by mercury displace- ment (BVllg) and grain volume (GV) measured in a D.S.B.M. modified Royle's Law apparatus using helium as the gas. ø BV IIg -GV BVlIg x 100 ............(1) The core measurement syste~ uses equations in decreas- ing order of preference as shown below. Pore volume (PV) is by direct injection, and bulk volume is determined by one of three techniques. ø = PV x 100 PV+GV .............. .(2) ø PV x 100 BVHg .............. ..(3) ø PV x 100 LxA ............... .(4) In the Fig. 6 data set all porosities agree well with mean porosity differences from the zero stress condi- tion of -0.2, -0.2 and -0.3 porosity points respec- tively. Figure 7 presents individual sample porosity differences comparing values from Equations 2, 3 and 4 with Equation I. Equation 2 allows for a decreasing bulk volume as confining stress increases. Equation 4 typically yields porosi ty values too low, as rounded corners or broken edges are often not properly accounted for 1n length (L) and diameter measurements used to com- pute area (A). This t'esults in higher bulk volumes than true; hence, low poros1ties. Equations 3 and 4 can be modified as illustrated below to allow for decreasing bulk volume as confin- ing stress increases. 158 · , , J , I j J 1 i j , .. i ' -{ .. ;. -~ f -I SPE 15185 Dare K. Keelan 5 ø PV BVHg-(PVj-PVn) ............(5) Where PY 1 Pore volume in cc al minimum confining stress (800 psig) I'\'n Pore volume 1n cc Rt Rny succeeding stress Overburden Effects Table 4 presents typical system d..ti.! ;It various confining stresses on a low ..nd moderate rermeability sample. Measurements were made at two locations to evaluate consistency bètween instruments. Once again, repeat..bility is good, although Run 2 data indicate samples have not fully rebounded from stres- ses imposed several days earlier during Run I. Po- rosity and permeability decrease as expected, and these data indicate values of (b) related to slip- page are essentially independent of confining stress whereas turbulence factors (Beta) tend to ~ increas~ as confining stress increases. The Sample A Beta factor at 6000 psig stress decreased remarkablv in Run 1, and this anomalous behavior was seen again in a second instrument in Run 2. Reasons for this are unknown. Figure 8 presents a typical porosity comparison between system measured porosity at various confining stresses with (I) a porosity generated at zero confin- ing stress and (2) with a helium injection technique commonly employed in Special Core Analysis laborator- ies. The zero confining stress measurement is des- cribed previously as Eq. 1. The "Pore Volume by Helium Injection" was determined with the core con- fined in a hydrostatic boot of lesser hardness than used in the system. Some initial porosity differ- ences between the three techniques is to be expected because some finite stress is required for the direct pore volume measurement techniques to conform the boot to the core exterior. The data indicate that 250 psig yields conform- ance in the softer rubber, while approximately 750 psig confining stress was required for the system to match the zero stress porosity. All measurements agree within an acceptable tolerance of 0.5 porosity points at the initial values reported, and the system and conunonly used helium injec tion technique agree within acceptable limits throughout the overburden stress range investigated. INVESTIGATIONS IN PROGRESS Pore Volume Compressibility Investigation is ongoing to evaluate core surface conformance effects as the rubber boot surrounding the core is subjected to increased confining stress. This has importance in evaluation of both porosity reduction observed in the system, and pore volume compressibility calculated from system measured pore vollDlles. Initially the boot is held away frora the core surface by tops of grains and/or any high points present. As confining stress increases, the boot conforms lIIore closely and flows into the indented spaces between adjacent sand grains. This translates into a differential pore volume reduction sensed by the system as subsequently injected heliu:n sees a smaller volwne. While the pore volume is smaller, the core may not have compressed at all, and the pore volume compressibility calculated from pore vol- ume reduction is erronèously high. When the boot material fills the surface indentions, subsequent increase in confining stress docs compress the t'ock and t'esult in actual pore volume compressibility. Samples prepared ror constant temperature, pt'e- cise compressibility measurements are normally jack- eted with a heat shrink;Ü>1e tubing that fills sur"face indentions so that no conformance problem exists, and early applied confining stresses see only sample compression. Figure 9 illustr..tes pore volume de- crease for a jacketed dnd non-jacketed core. The jacketed sample also contained water 'it the tir;¡e of test, which sometimes softens the rock and yields greater and more representative pore volume compres- sibility than a dry cort'. This sample was tested, while jacketed, in a hydrostatically stressed compres- sibility apparatus, and the jacket was removed prior to testing the sample in the system. Curve 1 is the first system compressive cycle, and greater pore volume reduction is seen at low net stress than observed on the jacketed core. This is believed due to the boot conformance previously discussed, even though this sample was relatively smooth. Curve 2 is the hysteresis curve, and at the minimum net confining stress of 400 psi obtained after the hysteresis loop, a lesser pore volume than initial is determined. This may gradually recover to initial value as a function of time, or may remain permanently reduced depending upon properties of the core and whether the elastic limit was exceeded. Examination of other data from this reservoir indi- cated an elastic limit of slightly greater than 4500 psi, and for this reason this test was not taken above 4000 psi confining stress. Curve 3 represents the second compressive cycle and Curve 4 is the final hysteresis curve. Note that the slope of the pore volume curve is essentially the same for the jacketed and non-jacketed tests above a net stress of approximately 2000 psig. Although Cycle 3 is below Cycle 1, pore volume compressibilities would be essentially the same at the higher pressures since the slope of the pore volwne versus net confin- ing stress is similar. Figure 10 presents porosity as a function of net confining stress. Agreement is well within accepted tolerance for both tests over the range of stresses applied. Note that a net confining stress of approxi- mately 800 psi was required on the Curve 1 compres- sive cycle to yield the pore volume measured on the jacketed core at 200 psi net stress. These data indi- cate boot conformance was occurring in this sample until at least 1500 psi net stress, yet the conform- ance effect on porosity was negligible. Figure 11 illustrates the sensitivity of calcu- lated pore volume compressibility to initial boot conformance. The early system values do not appear to represent true pore volume compressib ili ty, but conformance. While differences in compressibility at low confining stresses are significant, compressibil- ity is an instantaneous value calculated at a selec- ted net confining stress, and there is no cumulative error. Values at net stresses above 2000 psi repre- sent reservoir conditions at the reservoir depth of burial and values are in reasonable agreement with 15Q J Sample Consolidation AUTOHATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEt\ CONDITIONS SPE 15185 4 ~lost tests to date have been made on consolid,1ted cores. Limited data indicate that unconsolid~ted rock mounted in shrinkable tubinglO can be rlln in the device. Investigation of applicability to these type cores as well as metal jacketed samples is vet to be completed. Core Saturation Condition ì 1 The system was designed to test clean, dry cores. Data indicate valid permeability at irreducible water (Swir) can be measured. Multiple cores should not be batch loaded as evaporation will occur while awaiting analysis, and immobile water is necessary to prevent water redistribution during gas flow and movement from the core. Total evaporation during analysis shollld be monitored by sample weights. Indicated hydrocarbon pore volume (I.O-Swir) reduction due to overburden will be invalid and masked if the volume seen by injected helium increases due to evaporation. DATA ~~D DISCUSSION OF RESULTS , Accuracy and Repeatability of Steel Standards Each core measurement system is calibrated at 1500 psig confining stress utilizing stainless steel cylinders of known pore volume. Each is subsequently independently checked with a set of steel standards. Typical results of a pore volume accuracy and repeatability check are shown in Table 1. These tests were run overnight in a laboratory with no special temperature control. Maximum pore volume difference observed in the sequence was 0.035 cc, which yields a maximum porosity error of 0.27 porosity points (i.e. 10.0 to 10.27 percent) for a I-inch diameter plug 1 inch in length. This is well within the API RP 40 accepted accuracy of + 0.5 porosi ty point-II Table 2 illustrates pore volume accuracy and consistency between various systems checked with a set of common standards. These locations represent various elevations, Darometric pressures and tempera- tures, and excellent agreement is seen in measured pore volumes. Permeability checks on steel standards are shown in Table 3. All fall within the + 5% industry stan- dard for plugs of moderate permeability and reproduci- bility is excellent. Accuracy and Repeatability of Core Plug Standards Suites of cores tested with steady-state perme- ability techniques were used as standards in this evaluation. Air permeability was selected for com- parison as most historical data are in this form and routinely used permeameters develop these data. Mul- tiple measurements were made on carefully calibrated equipment and cross-checked between various instru- ments to arrive at standard values. Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state air perme;¡bility me;isurements. The difference sho",n is expressed as a percentage of the steady-state value. Three measurelJlents are presented for each S:imple to illustrate reproducibil ity. The d,1ta indic3te three samples with a difference greater th;¡J1 5% of the standard value. Two are lower permeability samples, of less than one mill idarcy. The 2: 5% limi t was set for higher permeability simples, and the toler'lnce is normally expanded i.n the lower range hecause of the small v'llues measured and sensitivity to mean pressures in the core as permeability becomes lower. For example, if the true 'lir permeability value is 0.020 millid'lrcies and the tested value found is 0.025, an error of 25~ is indicated, although the magni tude of the difference is i nconsequen t Î<1l and the permeability in both cases is quite small. A much larger (JOO%) error results from the incorrect use of the air permeability value of 0.02 to repre- sent reservoir permeability rather than the slippage corrected Kl1nkenberg value of 0.01 determined for this plug. Figure 6 shows comparisons of zero stress meas- urements utilizing a small volume por6simeter (SVP) versus core measurement systelJl porosity data at 800 psi confining stress. Porosity in the system has been calculated using various equations that require different basic data. The zero stress equation util- izes bulk volume determined by mercury displace- ment (I:IVHg) and grain volume (GV) measured in a ·U.S.B.M. modified, Boyle's Law app'lratus using helium as the gas. ø BV -GV Hg x 100 BVHg .. .. . . .. .. . . (I ) The core measurement system uses equations in decreas- ing order of preference as shown below. Pore volume (PV) is by direct injection, and bulk volume is determined by one of three techniques. ø = PV x 100 PV+{;V .............. .(2) ø PV x 100 BVHg . . . . . . . . . . . . . . . . (3) ø PV x 100 LxA .............. ..(4) In the Fig. 6 data set all porosities agree well with mean porosity differences from the zero stress condi- tion of -0.2, -0.2 and -0.3 porosity points respec- tively. Figure 7 presents individual sample porosity differences comparing values from Equations 2, 3 and 4 with Equation 1. Equation 2 allows for a decreasing bulk volume as confining stress increases. Equation 4 typically yie Ids porosity values too low, as rounded corners or broken edges are often not properly accounted for in length (L) and diameter measurements used to com- pute area (A). This results in higher bulk volumes than true; hence, low porosities. Equations 3 and 4 can be modified as illustrated below to allow for decreasing bulk volume as confin- ing stress increases. , ! J 1 1 1 -Î. t ,....- ' - ~ .. $ ~ -oct f -I r SP~ 15185 Dare K. Keelan 5 ø PV IWHg-(PVi-PVn) ............(5) \"here PVi Pore volume in cc at minimum confining stress (800 psig) PVn Pore volume in cc at any succeeding stress Overburden Effects Table 4 presents typical system data at various confining stresses on a low and moderate permeability sa:;¡ple. ~leasurements were made at two locations to evaluate consistency between instruments. Once a&ain, repeatability is good, although Run 2 data indicate samples have not fully rehounded from stres- ses imposed several days earlier during Run I. 'Po- rosity and permeability decrease as expected, and t':1ese data indicate values of (b) related to slip- PØ5e are essentially independent of confining stress, "'~ereas turbulence factors (Beta) tend to increase as confining stress increases. The Sample A Beta f ac tor at 6000 psig st ress dec reased rema rkab ly in Run l, and this anomalous behavior was Seen again in a second instrument in Run 2. Reasons for this are unknown. Figure 8 presents a typical porosity comparison between system measured porosity at various confining stresses with (I) a porosity generated at zero confin- ing stress and (2) with a helium injection technique cOwmonly employed in Special Core Analysis laborator- ies. The zero confining stress measurement is des- cribed previously as Eq. 1. The "Pore Volume by HelilU1l Injection" was determined with the core con- fined in a hydrostatic boot of lesser hardness than used in the system. Some initial porosity differ- ences between the three techniques is to be expected because some finite stress is required for the direct pore volume measurement techniques to conform the boot to the core exterior. The data indicate that 250 psig yields conform- ance in the softer rubber, while approximately 750 psig confining stress was required for the system to match the ;zero stress porosity. All measurements agree within an acceptable tolerance of 0.5 porosity points at the initial values reported, and the system and commonly used helium injection technique agree ...'i,thin acceptable limits throughout the overburden stress range investigated. I~~ESTIGATIONS IN PROGRESS Pore Volume Compressibility Investigation is ongoing to evaluate core surface conformance effects as the rubber boot surrounding the core is subjected to increased confining stress. This has importance in evaluation of both porosity reduction observed in the system, and pore volume compressibility calculated from system measured pore volUllles. Initially the boot is held away from the core surface by tops of grains and/or any high points present. As confining stress increases, the boot conforms more closely and flows into the indented spaces between adjacent sand grains. This translates 1!lto a differential pore volume reduction sensed by the system as subsequently injected helium sees a saaller volume. While the pore volume is 81IIaller, the core may not have compressed at all, and the pore volume compressibility calculated from pore vol- ume reduction is erroneously high. When the boot material fills the surface indentions, suhsequc'nt increase in confining stress does compress the rock and result in actual pore volume compressibility. Samples prèpared for constant temperature, pre- cise compressibLlity measurements are normall\' jack- eted with a heat shrinkahle tuhing that fills surface indentions so that no conformance problem exists, and early applied confining stresses see only sample compression. Figure 9 illustrates pOre volume de- crease for a jacketed and non-jacketed core. The jacketed sample also contained water at the time of test, which sometimes softens the rock and yields greater and more representative pore volume compres- sibility than a dry core. This sample was tested, while jacketed, in a hydrostatically stressed compres- sibility apparatus, and the jacket was removed prior to testing the sample in the system. Curve 1 is the first system compressive cycle, and greater pore volume reduction is seen at low net stress than observed on the jacketed core. This is believed due to the boot conformance previously discussed, even though this sample was relatively smooth. Curve 2 is the hysteresis curve, and at the minimum net confining stress of 400 psi obtained after the hysteresis loop, a lesser pore volume than initial is determined. This may gradually recover to initial value as a function of time, or may remain permanently reduced depending upon properties of the core and whether the elastic limit was exceeded. Examination of other data from this reservoir indi- cated an elastic limit of slightly greater than 4500 psi, and for this reason this test was not taken above 4000 psi confining stress. Curve 3 represents the second compressive cycle and Curve 4 is the final hysteresis curve. Note that the slope of the pore volume curve is essentially the same for the jacketed and non-jacketed tests above a net stress of approximately 2000 psig. Although Cycle 3 is below Cycle 1, pore volume compressib 11 i ties would be essentially the same at the higher pressures since the slope of the pore volume versus net confin- ing stress is similar. Figure 10 presents porosity as a function of net confining stress. Agreement is well within accepted tolerance for both tests over the range of stresses applied. Note that a net confining stress of approxi- mately 800 psi was required on the Curve 1 compres- sive cycle to yield the pore volume measured on the jacketed core at 200 psi net stress. These data indi- cate boot conformance was occurring in this sample until at least 1500 psi net stress, yet the conforœ- ance effect on porosity was negligible. Figure 11 illustrates the sensitivity of calcu- lated pore volume compressibility to initial boot conformance. The early system values do not appear to represent true pore volume compressib ili ty, but conformance. While differences in compressibility at low confining stresses are significant, compressibil- ity is an instantaneous value calculated at a selec- ted net confining stress, and there is no cumulative error. Values at net stresses above 2000 psi repre- sent reservoir conditions at the reservoir depth of burial and values are in reasonable agreement with 1 ......;:.;: j ] 6 AUTOMATED CORE ~IEASUREHENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDl TIOt>\S SPE 15185 the jacketed sample. 10-6 versus 9.3 x 10-6 agreement at 2000 psi.) (I.e. system value of 7.4 x at 4000 psig and much hetter The system can furnish large volumes of datô rapidly which are likely to be much more representa- tive of ;¡ formation or its various rock. types and lithologies than average correlations in the litera- ture. The data can and should be cal ibrated to more precise measurements by running a suite of water saturated jacketed cores in a compressibility appara- tus, and arriving at a confidence and adjustment factor to be applied to the system calculated pore volume compressibility values. Irreducible Water (Relative Permeabil~ffects) , i j Table 5 is a subset of data to illustrate the effect of irreducible water (Swir) on the Klinkenberg permeability. The data are somewhat erratic due to the unusual relationship of porosity and permeability indicated, and Swir appears quite low for two of the three samples. These cores were reported to contain kaolinite and perhaps slight changes in loose particle location in the dry core contributed to these results. In any event, irreducible water saturation of, up to 22.9 percent pore volume had a negligible effect on gas flow in all core tested. This indicates the dry core Klinkenberg permeability would represent gas reservolT permeability in zones containing iTTeduci- ~le watee , The samples weTe then restored with oil and oil permeabilities were deteTmined. Sample 3 yielded an oil permeability equal in value to the Klinkenberg values found both on the dry core and the core con- taining irreducible water. The total data set indi- cated that in 40% of the_ samples tested, Ko at $wir equaled the dry core Klinkenberg value; conversely, 60% of the samples gave poor comparison. The conclu- sion here is that validation of the Klinkenberg value at Swir as equal to the Ko at Swir must be done on an individual formation basis with independent oil permeability measurements. Table 6 illustrates the effects of irreducible water on slippage factor and turbulence for the core identified as Sample 3 in Table 5. The b value decreased in this and other cores tested in the presence of Swir, while turbulence factor (Beta) remained essentially constant. Conversion of Hydrostatic to Uniaxial Strain Data The core measurement system employs a hydrostatic load to simulate stresses of the rock at net overbur- den conditions. However, numerous authors have indi- cated that reservoir stresses are not hydrostatic, and the reservoir is free to compact in a vertical direction only, with no deformation laterally. This is referred to as uniaxial strain. Teeuw showed that uniaxial pore volume coapres- sibility was approximately 62% of hydrostatic val- ues12. Anderson presented data co~paring hydrostatic loading to uniaxial, and equations to transform hydro- static pore volume compressibility to uniaxial strain conditions13. It follows that a hydrostatic pore volume compression that is too high will result in a laboratory porosity reduction that is too high. Similar results have been reported for permeability'J4 If reservoir compression' is only 62% of the laboratory value, then the reduction in reservoir porosity should only be 62% of the measured hydrostatic laboratory value. Nelson concluded permeability could be dèrlved from hydrostatic confining pressure tests by calcu- latinp, the mean stress in the reservoir and thcn read ing the permeab 11 i ty value from the hvd rosta t ic curve at th0 calculated mean subsurface'stressI5. 80th porosity and permeability data from the core measuremenl system can be normalized by dividing each overburden value by the initial value ;¡t the minimum confining pressure. This type of data is illustrated on Fig. 12, and the curves allow a quick approximation of uniaxial strain porosity and perme;!- bility. The approach illustrated employs the average correction factor of 0.62 proposed by Teeuw. The curves are entered at Point A, the calculated reservoir net overburden pressure computed as illus- trated in Fig. 2. The porosity "fraction of original" curve intercepted at Point B represents too great a reduction in porosity since porosity was measured under hydrostatic loading. This "fraction of origi- nal" value is adj\.Jstedupward using Teeuw's factor by multiplying 0.62 (1.0 - normalized porosity factor read at Point B) and subtracting this product from 1.0. This adjusted value is plotted as Point C, which is the porosity "fraction of original" more representative of reservoir conditions, and which approximates data that would have been measured had the core been tested in a uniaxial strain test. We then move from Point C horizontally to the left to intersect the hydrostatic curve. The net overburden pressure Point D corresponding to this intersection is the equivalent mean stress on the hydrostatic curve required to yield the reservoir uniaxial strain porosity. By moving vertically, we intersect the normalized permeability curve at Point E at the same mean stress. We can then move horizontally to the left to Point F which represents the factor for permeability adjustment. This factor times initial permeability yields the desired permeability value. Reliability of this approach for a particular formation would be improved by having uniaxial perme- ability and porosity measurements to compare with hydrostatic and to develop the actual correction factor for the formation. CONCLUSIONS 1. Klinkenberg corrected permeability, porosity, slippage factor (b) and turbulence factor (Beta) can be accurately and routinely determined in the core measurement system at overburden pres- sures. 2. Overburden pressure effects (including hystere- sis) can be easily studied by designating confin- ing stresses that are automatically applied from 500 to 10,000 psi, and differences in properties at overburden conditions from low stress measure- ments can be significant. ."'^ 1 j , j '., -f 1 -{ ~ ' .~ ~J ~~; ~}1' r ...... ·1 l' '} 1 t 1 i SPE 15185 Dare K. Keelan 7 3. K1inkenberg slippage factors (b) were essentially the same or increased on ly slight ly in the sand- stones tested as overburden pressure increased, and the presence' of irreducible water resulted in a decrease in (b) value. 4. The turbulence factor (Beta) increased moderately in the sand stones tested as overburden pressure increased and the presence of irreducible water had little effect on its value. 5. A minimum confining stress of 800 psi is currently required for the system determined porosity and permeability to equal (1) porosity values at zero stress and (2) air permeability values at 400 psi confining stress now employed in routine core analysis. 6. Helium injection porosity measurement techniques routinely employed in Special Core Analysis labo- ratories yield porosity values in good agreement with those measured on the system. 7. Conformance of the rubber boot to the core sur- face had little adverse effect on system poros- ity values at pressures above 800 psi confining stress, and the jacketed and non-jacketed core yielded similar values of porosity throughout the range of overburden pressures investigated. 8. Pore volume compressibility of the non-jack- eted core was extremely sensitive to boot con- formance at confining stress below 2000 psi. Above this stress compressibilities approxi- mated true values. Compress ib il ities determined on non-jacketed dry core should be calibrated to best technique values by comparative measure- ments on jacketed, water saturated samples tested in a compressibility apparatus. 9. Hydrostatically confined porosity and permeabil- ity determined at selected net overburden pres- sures and presented as a fraction of original values allows approximation of both porosity and permeability at uniaxial strain conditions. Note: This is likely to be restricted to well- cemented cores whose behavior follows elastic theory. 10. The system can be used to measure Klinkenberg gas permeablity with irreducible water in the core, and thereby verify whether dry core slippage corrected permeability at confining stress is representative of gas flow with connate water present. 11. Applicability of the system Klinkenberg gas perme- ability (with or without irreducible water pre- sent) to represent oil permeability (Ko) with irreducible water present must be verified by independent measurements of Ko. NOMENCLATURE k . permeability, md KA . permeability to air, md K.o . Klinkenberg "Liquid" permeability, md b . Klinkenberg slippage factor, psi Pmean p L V ß )J p arithmetic average pressure in core, psia pressure, psia length of flow path, ft velocity, ft/see Heta - turbulence factor, ft-1 gas viscosity, cp density of fluid, Ib mass/cu ft ACKNOWLEDGMENTS The author gra tefully acknowledges the cont r i- but ion of Brian Davis and Lisa Curry and those who developed and implemented the theory resulting in the alltomated core measurement system. REFERENCES 1. Thomas, R. D. and Ward, D. C.: "Effect of Over- burden Pressure and Water on Gas Permeability of Tight Sandstone Cores," J. Pet. Tech. (Feb. 1972) 120-124. 2. Jones, F. O. and Owens, W. W.: "A Laboratory Study of Low Permeability Gas Sands," AIME-SPE 7551 (May, 1979) Denver Low Permeability Gas Reservoir Symposium. 3. Jones, S. C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Eng. J. (Oct., 1972) 383-397. 4. Klinkenberg, L. J.: "The Permeability of Porous Media to Liquids and Gases," Drill. and Prod. Prac., API (1941) 200. 5. Christman, Stan A.: "Offshore Fracture Gradients," Soc. Pet. Eng. J. (Aug., 1973) 910-914. 6. Breckels, J. M. and Van Eekelen, H. A. M.: "Rela- tionship Between Horizontal Stress and Deptn in Sedimentary Basins," paper SPE 10336 presented at 56th Annual Fall Tech. Conf. and Exhibition, San Antonio, Texas, October 5-7, 1981. 7. Tek, M. R., Coats, K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Gas Through Porous Reservoirs," J. Pet. Tech. (July, 1962) 799-806. 8. McLeod, H. 0.: "The Effect of Perforating Condi- tions on Well Performance," J. Pet. Tech. (Jan., 1983) 31-39. 9. Cornell, D. and Katz, Through Porous Media," 45, 2145. D. L.: "Flow of Gases Ind. Eog. Chem., (1953) 10. Griffin, T. J. and Bush, D. C., "Core Analysis in Unconsolidated Reservoirs Using an Improved Consolidation Technique," 36th Annual Meeting of Petroleum Society of CIM, Edmonton, Alta., Paper No. 85-36-41, June 1985. 11. API-RP 40: Recommended Practice for Core Analysis Procedures, American Petroleum Institute, Dallas. 12. Teeuw, D.: "Predictions of Formation Compaction from Laboratory Compressibility Data," Soc. Pet. Eng. J. (1971) II, 263-271. - ..~.,. :::: 8 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 15185 13. Andersen, M. A.: "Predicting Reservoir Condition Pore-Volume Compressibility from Hydrostatic- Stress Laboratory Data" paper SPE 14213 presented at the 60th Annual Technical Conference and Exhi- bition, Las Vegas, September 22-25, 1985. 14. Gray, D. 1'1., Fatt, I. and Berganini. G.: "The Effect of Stress on Permeability of Sandstone Cores," Soc. Pet. Eng. J. (1963) 2, 203. 15. Nelson, R. A.: "A Discussion of the Approximation of Subsurface (Burial) Stress Conditions in Lab- oratory Experiments," Geophysical Monograph 24, American Geophysical Union (1981) 311-321. "- ~. .....;.. 162 j TABU: 1 A TYPICAL a:>R£ M£ASlJRÐoIV-T S~IÐ'I O\LlBRATlCW AND REPEATABILITY ANAL'iSIS CW S"I'œL roRE \IOUJ'1E ST"''lQl\Rœ AT <DIFINlr-I:; STRESS STAN!Y\RD \GLUM!:: . 0, 195 cc Cont ini,," St ress Psiq !<un 1 Run 2 ~3 Run 4 Run 5 1000 0.207 ( +.012) 0.230 (+.03S> 0.223 ( +,028) 0.224 (+.029) 0.222 (+.027) 2000 0.193 (-.002) 0.222 (+.0271 0.2J5 (+ ,020) 0.215 (+.020) 0.213 (+.OJ8) 3000 0.188 (-.007) 0.217 (+.022) 0.210 (+ .01 5) 0,211 (+.016) 0.209 (+.014) 4000 0.184 (-.011 ) 0.213 (+.018) 0.206 (+.01l) 0.207 (+.012) 0.206 (+.011 ) 5000 0,180 (-.015) 0.210 (+.015) 0.203 ( +.008) 0.204 (+.009) 0.203 (+.008) 6000 0.175 (-.019) 0.207 (+.012) 0.20~ ( +.006) 0.202 ( +.007) 0.200 ( +.005) STANQA..'W \GLl/Ii£ . 1. 021 CC 1000 1.017 (-.004 ) 1.045 (+.024) 1.00 ( +,O22) 1.043 ( +.022) 1. 04 3 (+ .022) 2000 1. 008 (-,013) 1.035 (+.014) 1. 034 (+.013) 1. 034 (+.013) 1. 034 (+.013) 3000 1. 002 (-.019) 1.0Jl (+.010) 1.03<J (+.009) 1.029 (+.008) 1.029 ( +.0081 4000 0.998 (-.023) 1.027 1>.006) 1. 025 (+,004) 1. 025 (+.004) 1.025 (+.004) 5000 0.994 (-.027) 1.023 (+.023) 1.022 (+ .00l) 1.023 (+.002) 1. 022 (+.00l) 6000 0.991 (-.030) 1.020 (+.020) 1.02J (-.00l) 1.020 (-.00l) 1. 019 (-.002) STANffiRD \Glil"£ . 3.099 cc 1000 3.101 (+.002) 3.123 (+.034) 3.131 (+_032) 3.128 (+.029) 3.129 (+.028) 2000 3.089 (-.010) 3.121 (+.022) 3_1B (+.020) 3.119 (+.020) 3.117 (+.013) 3000 3.083 (-.016) 3.114 (+.015) 3.113 (+.014) 3.113 (+.014) 3.113 (+.014) 4000 3.077 (-.022) 3.109 (+.010) 3.108 (+.009) 3.108 (+.009) 3.109 (+.010) 5000 3.073 (-.026) 3.105 (+.006) 3.105 (+.006) 3.103 (+.004) 3.105 (+.006) 6000 3.069 (-.030) 3.102 (+.003) 3.101 (+.002) 3.102 (+.003) 3.102 (+.003) j -ii J ¡ , 1) 01S ran overnight in autOfMtic node in laboratory envircnnent with variable tenperature. 2) Kaxi..nurn error of 0.035 cc WCJ.lld result. in 0..27 po["Q5ity percent point error in a sançle of 1 ind'\ diiWMter and 1 ind1 length (i.e. 10.0 to 10.27 P9rosity percent). TABLE 2 STANDARœ OIECK IILlJS'I'RATIN:; CDRE 11EASURÐ1ENI' SYSTEH PORE VOUJME N:.OJRACY NlD CDlSISTEN::¥ I!ETWErn LOCATlOOS (AT 1000 !'SIC <nIFINIr-I:; STRESS) ... Standard Volumes ~ Aberdeen london· Ca..lQary* . l:811a8 Denver 0.195 0.209 (+.014) 0.188 (-.007) 0.212 (+.017) 0.199 (+.004) 0.545 0.540 (-.005) 0.515 (-.030) 0.547 (+.002) 0.529 (-.016) 1.021 1.026 (+.005) 0.999 (-.022) 1.016 (-.005) 1.014 (-.007) 1.025 (+.004) 3.099 3.104 (+.005) 3.085 (-.0141 3.092 (-.007) 3.097 (-.0021 3.105 (+.006) 5.109 5.118 (+.009) 5.101 (-.008) 5.086 (-.023) 5.108 (+.001) 5.109 (0.0001 """' 1 ....... - ·After 1 year field trial in Aberòeen ·*Re<:alibration after field ApIIir -~. J' TABU!: 3 CIJRE MEASURE:MENl' SïSTDI AIR P£R1EABIUTY N::CIJPAi:'{ AND REPEATABILITY OifDC CtI STE:E:L STANDA1ID5 Steady Contini,," State Stress Sanp Ie K Aver age Psiq Number ~ ~ R.Jn 2 Run 3 Error SOD A 1.09 1.05 1.05 LOS -3.7\ 1000 A 1.04 1.05 1.04 -4.3\ 500 8 29.3 28.7 28.6 28.6 -2.3\ 1000 8 28.8 28.7 28.6 -2.0\ 500 C 48.5 46.5 46.5 46.4 -4.2' 1000 C 46.4 46.4 46.4 -4.1\ SOD D 73.7 70.7 70.5 70.4 -4.3' 1000 0 70.6 70.5 70.3 -4.3\ SOO £ 1430 1480 1480 1470 +3.3\ 1000 £ 1490 1490 1480 +4.2\ ..........." -JI -' ~ ---: t -~ ! , ;..:;.:.~. l I J TA!\U: . TYPICAL Q)RE Hf.A.<;URf.Mllir S~ïV1 OJH£ Do\TA AT Ü)Jf(N\N:; ~ïRf'.sS IUJJ~ïRATlN:; O"'SISTDlCY m:rwEf1~ INSTHllMf}/f$ SA.'1PLE A (w.., ¡>EI~:ABIU~ Confining []a lIas (Run I) Denver (Run 211t Stress ¡J K Ka(est) b(He) !\eta ø K Ka(est) b(He) !"'ta -~ % ..& ~ ~ ft-I % md ~ Psi _l~ 500 10.7 .065 .141 56.6 ~. 75xlO13 10.7 .055 .130 66.6 I. 76x 1013 800 10.6 .057 .132 63.2 ~.96xlO13 10.6 .052 .126 6ij.2 2.44xI013 1000 10,6 .05. .129 67.2 ~. 74xlO 13 10.5 .052 .124 67.7 2,81xl013 2000 10.4 .053 .122 63.0 4.52xI013 10.4 .050 .118 65.7 3.68xIOJ.J 4000 10,2 .048 .114 66.8 4.05x1013 10.2 .047 .112 67.1 3.71x1013 6000 10,1 .043 .109 75.9 I. 51 xlO 13 10.0 .043 .109 74.0 l.77x1013 SAMPLE: B ( t-GOCRATE P£RMEABI Un) 500 19.6 33.9 37.3 4.88 3.46x108 19.3 33.4 36.7 4.80 3.55x108 800 19.3 32.8 36.2 4.96 3.65xl08 19.1 32.4 35.6 4.84 3.81x108 1000 19.2 32_4 35.7 4.95 3.80x108 19.0 32.0 35.1 4.80 3.93x108 2000 18.9 31. 1 34.2 4.95 4.05x108 18.6 30.7 33.7 4.80 '.23x108 4000 18. S 29.6 32.6 5.04 4.33x108 18.3 29.2 32.1 4.88 4. 54x1 08 6000 18.3 28.5 31.5 5.05 4.56x108 18.1 28.3 31. 1 4.91 4.77xl08 1 l j 1 ] - , "Data set indicated pore space at tine of kJn 2 had not fully reboonded fran 6000 psi oonpressive force i~ several days earlier d.1ring Run 1. TABLE llU<£OOCIBL£ W1'JER (RELATIVE PERMEABILITY EffÐ:::T¡ av CüRE MEASURÐ1ENf SY"1Ð1 KLINKrnBEK> PERMEABILITY AND OIL PER.'ÌEABILlTY AT CUlflNIN:; STRESS OIS Klin<enœrg Oil Per:meabil ity:1OC! Permeability:nd** San\J Ie Porosity Swir Dry Core Core @ Swir Ko ~ Swir ~ % ~ ~ 4000' 800" 4000" 800" 4000' I 15.5 5.0 545 520 543 517 400 374 2 1.1 1.2 32.2 29.5 31.3 29.3 22.3 18.5 3 11.2 22.9 30.1 28.7 31.1 29.6 30.7 29.2 ii. - *Confining Stress * ·St.eady-State Measurenent -. TABLE 6 IRR£IXx:IBIE Wl'.TER EFP1C' CN SUPPIQ; (b) FAC'roR ANa 'lUI8JLЫ:E (Bt:rfol FACTOR AT o::NFININ:; STRESS ---. Coni ining [)[y Core IrreòJcible Sw . 22.9 \ PV Stress /I b(lte) Beta bOte) ~=! Psig --L ...f!L Ft-l ~ 500 17.4 4.90 2.84><108 4.11 2.8bl08 800 11.2 5.03 2.81xl08 4.10 2.89xl08 1000 11.2 5.06 2.83x108 4.13 2.90xl08 2000 16.8 5.05 2.99xl08 4.16 2.99x108 4000 16.6 5.11 3.04xl08 4.27 3.06xl08 6000 16.5 5.10 3.19.108 4.30 3.15x108 I I!s i i ¡ I 3 D .. .. .f .5 .5 .7 3 . 5 5 7 CONfINING STI!ESS : THau$AIIOS ( f PSI fig. 3-PO.....11y .nd penM.blltty .... conllnlng .t,.... 10 K.JI Kao - >- t: ~I " ,,~.. a:: ~~ '" NON-REACTIVE LIQUID LU Q.. ......................................... . Kao SlIPP AGE CORRECTE D KLINK ENBERG PERMEABILITY 00 --1- Pm.an - FIg. '-P........blllly .. . lunctlon of masn pr...ur., SURfAG E T OVERBURDEN PRESSURE 0.5 L At E V E URE··.·.¡; ...." .'," NET OVERBURDEN = IOVERBURDEN PRESSURE)- (RESERVOIR PRESSURE NOB ~ DEPTH (1.0 ~.: - 0.5 ~.: ) ~ DEPTH (0.5 ~.; ) Fig. 2-Net overburden pressure Y$, depth. ~' Wi r flOW /.,// ~ c:: ~ 0 ....J u.. 1- :~ = V + + ß p V z J PRESSURE DIFFERENTIAL . Fig. 4-Ettects 01 turbulence on flow. , . -==-t:- , 1 , 307- 201: w u 101: Z w It: W U. u. ëi O~ ~ w U It: -107- - w CL -207- -301: ~ 11.0 tJ 10.0 It: :r 9.0 ~ ¡¡:¡ o It: o a.. C/I .... Z ::> ~ ¡¡:¡ o no o a.. '" U Z '" '" t õ .----.-----.-------- ------ CONFINING STRESS (800 pot9) -~----.....,.- I --,----r-, -~r---'-r-._""--- r-r-",-.---r-;--r---l - -r-j-J 336 262 216 196 175 99.8 80.6 52.2 15.6 0.020 290 230 203 177 157 90.5 71.1 22.0 0.73 INDIVIDUAL SAMPLE PERMEABILITY: MllLIDARCIES _ RUN 1 _ RUN 2 _ RUN 3 F\g, S-OinoH.nc.. at .,.Iem ~(.,...blliti... and .'and.to.. 16.0 15.0 14.0 13.0 12.0 CONFINING STRESS (800 pal ) I I I I I I I I I I I I I I I I I I ...... I I I I I I I I I I I~ I I I I I I I I I I I I . I I I I I I I I I I I I I- I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 8.0 7.0 6.0 5.0 ".0 3.0 2.0 1.0 0.0 2 10 11 9 18 14 16 19 7 5 12 20 6 13 17 " 15 8 SAtoIPLE NUMBER SVP _ PV/(PV+CV) _ PV/BVHg _ PV/(LxA) Fig.o-<:oro__~..,_. 1 0.9 0,8 0.7 0.6 O.~ 0.4 0.3 0.2 0.1 o -0.1 -0.2 -0.3 -0.4 -O.!! -0.6 -0.7 -0.8 -O.g -1 COHFltllNG STRESS (800 pal ) 1 0 1 8 1 4 1 6 1 1 2 9 7 17 12 6 20 1 3 5 , 5 4 8 1 9 SAMPLE NUMBER _ PV/BVHg _ PV/(PV+CV) _ PV/(W<A) .....--..---- I I - I ~ ..~ J6~ i ¡ 360 i -1m ~!- B~ u 0 :> ~ Æ> ) .t~ J 40 --~-".~ "L 3:JO ~ (000 ~OOO ~ aoo 1000 3000 <000 iL.6 12. ~n] §no £ - 116 J 116 1000 2000 ~ftNING S¡I<:£SS P$IG fig. 8-Compar8'¡ve porosities ...:s. confining stress ))0 ':' " ~ " l' i[> ~ ~ 20 > :0 16 0 ª !If ~ : .~--- ---! £ 126 , I ---L----IJ~=-- 1- --- ~ ---1 I I I ! ST AHDARD POROSITY ¡ ,:' I£RO STTII£SS-11 I'. L ...... JJ.()o:.(TEO BRINE SATURATED COM ~ I (:1W:PRESStBILlTY APPARATuS . - 116 z ~ 124 110 118 116 o 1000 fig. 11~e pore volume compr_lItIes..., net -.fining al,... HET COHFI!OHG STRESS: f'SIG HE' COHftNoiG STR£SS : PSIG Fig, 1 D-Comperetive pomeJtlea .... net conllnlng attesa. -~ '-...,., N~ T CON' INI~G STRESS PSiG Fig. 9-Comparative pore volumes vs. net confining stres... .·...L~ --- 1000 2000 3000 <000 1?1OO 1,0 POROSITY ADJUSTED TO UNIAXIAL STRAIN I I I I I I I I I® NET OVERBURDEN PRESSURE ........ >- t- --I -1« ~~1 w_ :Ea:: a:: c> w 0.."- c> <t)z >-2 t- t- -u <1)« Ocr :S"- a.. ® ~I o o K Fig. 12-,,-"y end permeeblllty ecljuatmentto __lei llreln. .. Littan Core Lab WELLSITE CORE REPORT Company: Arco Alaska, Inc. Well: KRU #3H-9 ...L County, state: North Slope, Alaska ...L Core 4/: 1 .Jk Coring Interval (drillers depths) --'- Retrieved Core (measured depths) -1. Type Preservation - Core Seal Core Barrel on drill floor - 2:45 am - -'-. Box No. Top Depth 1.) 6868.0 2. ) 6870.0 3 . ) 6872.5 4 . ) 6875.0 5. ) 6877.3 6.) 6879.4 7 . ) 6881. 7 8. ) 6884.1 9. ) 6886.0 10. ) 6888.6 ~ - Top 6868.0 6868.0 Bottom 6911. 0 6909.0 8005 Schoon Street Anchorage. Alaska 99518- 3045 (907\ 349- 3541 Date:11/25/87 Technicians: TDT Formation : Kuparuk Total ( Ft. ) 43.0 41.0 End preservation - 6:05 am Bottom Depth 6870.0 6872.5 6875.0 6877.3 6879.4 6881. 7 6884.1 6886.0 6888.6 6890.4 Remarks Core No. 1 Box No. Top Depth Bottom Depth 11.) 6890.4 6892.4 12. ) 6892.4 6894.9 13.) 6894.9 6897.3 14. ) 6897.3 6899.7 15. ) 6899.7 6902.0 16. ) 6902.0 6904.0 17. ) 6904.0 6905.2 18. ) 6905.2 6907.3 19. ) 6907.3 6909.0 20. ) 21.) 22.) 23.) 24.) 25. ) 26. ) 27. ) 28.) 29. ) Remarks .-4 -' ~ -1 ---' -.:! - ~-1 Littan Core Lab 8005 Schoon Street Anchorage. Alaska 99518-3045 (907) 349- 3541 WELLSITE CORE REPORT Company: Arco Alaska, Inc. Date:11/26/87 Well: KRU #3H-9 Technicians: TDT County, state: North Slope, Alaska Formation: Kuparuk Core # 2 Top Bottom Total eFt.) Coring Interval (drillers depths) 6911. 0 6971. 0 60.0 Retrieved Core (measured depths) 6911. 0 6958.0 47.0 Type Preservation - Core Seal Core Barrel on drill floor - 6:00 am End preservation - 9:15 am Box No. Top Depth Bottom Depth Remarks 1.) 6911. 0 6913.4 2. ) 6913.4 6915.7 3. ) 6915.7 6917.3 4 . ) 6917.3 6920.3 5.) 6920.3 6922.3 6. ) 6922.3 6924.0 7 . ) 6924.0 6926.0 8. ) 6926.0 6927.7 9.) 6927.7 6929.9 10. ) 6929.9 6931.0 Core No. 2. Top Depth Bottom Depth 11.) 6931. 0 6933.6 12. ) 6933.6 6935.5 13. ) 6935.5 6937.4 14.) 6937.4 6939.5 15. ) 6939.5 6941. 9 16. ) 6941. 9 6943.4 17. ) 6943.4 6945.5 18. ) 6945.5 6947.7 19. ) 6947.7 6949.8 20. ) 6949.8 6952.0 21.) 6952.0 6954.1 22.) 6954.1 6956.3 23.) 6956.3 6957.7 24.) 6957.7 6958.0 25. ) 26. ) 27.) 28. ) 29. ) 30. ) 31.) 32.) 33. ) 34. ) 35. ) Remarks End Core 2 Littan Core Lab 8005 Schoon Street Anchorage. Alaska 99518- 3045 (907) 349-3541 WELLSITE CORE REPORT Company: Arco Alaska, Inc. Date:11/26/87 Well: KRU #3H-9 Technicians: TDT County, state: North Slope, Alaska Formation: Kuparuk Core # 3 Top Bottom Total ( Ft. ) 7031. 0 60.0 7030.8 59.8 coring Interval (drillers depths) 6971. 0 Retrieved Core (measured depths) 6971. 0 Type Preservation - Core Seal Core Barrel on drill floor - 6:45 pm End preservation - 9:20 pm ..-J. Box No. Top Depth Bottom Depth Remarks 1.) 6971. 0 6972.9 2 . ) 6972.9 6974.7 3. ) 6974.7 6976.8 4. ) 6976.8 6978.9 5.) 6978.9 6980.7 6. ) 6980.7 6982.7 7. ) 6982.7 6984.3 8. ) 6984.3 6986.7 9. ) 6986.7 6988.6 10.) 6988.6 6990.8 - Core No. 1 Top Depth Bottom Depth Remarks 11.) 6990.8 6993.1 12. ) 6993.1 6995.1 13. ) 6995.1 6997.0 14. ) 6997.0 6999.6 ~ 15. ) 6999.6 7001.6 16. ) 7001. 6 7004.3 17. ) 7004.3 7006.8 18. ) 7006.8 7008.4 19.) 7008.4 7010.1 - 20. ) 7010.1 7012.2 21.) 7012.2 7014.9 - 22. ) 7014.9 7016.7 23. ) 7016.7 7018.7 -- 24. ) 7018.7 7020.5 25. ) 7020.5 7021.8 _. 26. ) 7021. 8 7023.9 -- 27. ) 7023.9 7026.5 28. ) 7026.5 7028.6 29. ) 7028.6 7030.8 End Core 3 30. ) 31.) 32.) 33.) 34.) 35. ) - - Litton Core Lab 8005 Schoon Street Anchorage. Alaska 99518- 3045 (907) 349- 3541 - ~ WELLSITE CORE REPORT Company: Arco Alaska, Inc. Date:11/27/87 Well: KRU #3H-9 Technicians: TDT -4 County, state: North Slope, Alaska Formation: Kuparuk ~ Core # 4 --1 Top Bottom Total (Ft.) Coring Interval (drillers depths) 7031.0 7059.0 28.0 - Retrieved Core (measured depths) 7031. 0 7058.6 27.6 Type Preservation - Core Seal - Core Barrel on drill floor - 4:30 am End preservation - 5:50 am - Box No. Top Depth Bottom Depth Remarks -- 1.) 7031. 0 7032.7 2. ) 7032.7 7035.0 3 . ) 7035.0 7037.5 4. ) 7037.5 7039.0 5. ) 7039.0 7042.1 6.) 7042.1 7044.1 7. ) 7044.1 7045.8 8. ) 7045.8 7047.9 9. ) 7047.9 7050.4 10. ) 7050.4 7052.8 Core No. .1 11.) 12. ) 13. ) 14. ) 15. ) 16. ) 17. ) 18. ) 19. ) 20. ) 21.) 22.) 23.) 24. ) 25. ) 26. ) 27. ) 28. ) 29.) 30. ) 31.) 32. ) 33.) 34. ) 35. ) To? Depth 7052.8 7055.2 7057.4 Bottom Depth Remarks 7055.2 7057.4 7058.6 End Core 4 .......... >~J''''.:' "..~.( , 1. . .....:.--. '11:- .''':".... f .'," : ~-f.- .' -'- .-1-- -,. '-"-.. -' ---; ~ . _1 1 -' 1 I ~J : I ... ,'\ 6005SQ100N SI,. ANCHORAGE, Al.J-SKA \>'3".>C: ; . . _......,#{t:':;'7~~ ......... .......__.io,..."..·:.,·..·~~,··..."..'-~.-~~~~..' . '.... :..::=:*:'~'. ,::t..~~l;;,z::~~...{~~~.. CORE LA80RATORíEŠ:'ìNc. ~1l1 f~ ll~V1J~ ... '~~- -'-~'. _.~ TRANStHTTAL AND ACKNOi.JLEDGH1ENT OF RECEIPT TO: L¡;b ò cJ s e. 17 ../€ , kUf4(¿U~ cJ pit Ilef:5 v hi -h¿J¿f I :31-/- ~ rkese/2 v (' j V'·'eo¡¿e. ßO bys C'ðl2eS )-L/ ' Materials received via f See /?f)/lde.tß t.,O¡;,és -fotC, /lVveNk/!i(f PLEASE RETURN ONE COpy SIGNED IDa'., s/ 9 1ft {Date: ~-9- ~ for Core Lab Received by: for :;.,. '~~~"!'k~~~:~.~;i~."\;::<~"M·~:::~..;.:.~~;~.z:~~~·:·~,;Ø.1~·~rþ ,~. ,...;;'0.' :;.... ,.,.':........~;'~" ..( ..·r·.:~:?~:·~~:it,·:'·· 7 'r' '. '. '. .; . .... ._.~., ,;.:'.<:' ".~' :', -.,¡'.': ::'.:' ..... 'Y~T'·/. 'I 1/ t4 . I .' -, , II - ' . " " II I' ,I I' II I' " 'A' :1.- Þ' - ~ ____... ';.._...._..UI' ; ".' ..... ". ,'" . - . ~ ~~~~~¡;~~Å~~.~~~4.~it~~jti~~ï~1!;·;> . ..1;:::::': ·:;·:~:';·"·";·;~C·orê~·t:ab··:··':"'-· :.... '.....,. .." .' ,.. ...' INVENTORY '. .......J'.. .... C0t:1p3ny: ''':~e'l'r'N~~:'è'::" : .' .Cont:ent:s: ~ -1 C.O~E f.J BOX f' .3 '. (; _II 1-...,...-..... , <00 '.'. ....c!-'--7'...&':~ ". -r :... . ., ~~ t :' " , :. " . . . .. ~. . " .Þ, .~.;:·,·,..j~;~::.~;.t~·.I'.:f'H: ,,:. ..~- ..1:....·, .. ..: . . . 'tJ ~. :,...~;.::. ~ ....... :___~;.¡.;...~...#. . 's-" ;::...';-..:............ .'\>......,....;. ....,.¡.-... . . ;' -:.~' -'.. . ~ - .·:·:·,::,,~L0/~j~¡¡i!~t1l.i~~~L?~·'., . . ...... I ,\·1i._~~....~..':\1"- :J.' .... - ~ Jo(""...~~...~~--"...QP ~h'pe:·· '. . e ~:~::-.. ~-;'t~~~~:~~.:~~~~~~~;~:.:--:,'~~~\~,f¿1;;-;...~~~.~Aa!:rsk~ . .. . ··_···>95i~3Õ45 . "~~:¿~~;'".~~' ...:~:. ~ . -~:;.~:.r:~:_~~~~.:~~.e- :~54' : " UM ')~. ~~'....~Y:"::"":::-o..' ~ I....~.., \....~ ~ - .".<#.--. DEPTHS - .! ..' ~. ....,.. ..':";.,. . .- , . ""1' '. '. ,".....: . ..' " > .:.. ; ~..' ,,';:~'i;: :~..¡ ~':<ç.t(4.",,::),', . '~'·-14':¿.! '~'... ~)}~;:..4-~·;.¡::·.·,;~~t.··: ;: '. :r~:~->.,. . .,' , .------. o' ~' ;'. ....:. '. 1 ;,;':~·:f::·~~:::~;.~:<3t~\f:~': .:. '." :,.;":'~<~;'~;·,:?·,~?J/':,::~:~:i:tt~~::1~~:;F:: . . ',". . ,'.' ;j' ~.... :<_.·~:..--:-:.#.:"V...:I~~uQO>"';'7'.; "'-'-~"":";"''''''.:J;''-:--f.;.#.. d."'f~~"'''''':.. ". '.. ,"" _. ~~;~}fI.£~~~·~J~;?;~~1~.t~:è6i~~tt~~~~~~~~:Y~~f~j¿t~~{~r~;:::· 1 .' '," .' I NVE!~TO!\ Y -i -j Contcnts: . . -j COi\E ;.' GOX :L -J , , !: " 1-;," f 1/ 9 of II , '~;""-1D' .. .-. ...." .'~''''''''''''.':'~. ~ !--. ......,-::.... _ J ~ ~ . ' ~ .' .. \.... ....-... ~ .. ,.¡..' . .......::..,~ ~~~~~-> . ?" ,. .~ . ........¡. .." ..... '. ...' " " .>~'~:~~;~ ~..': .:....~...-!..;~.;,;.".~: :.~~: " ":-'.', l' ..''''~. ->" ..:..:..;.., " II II I ( I , " ,I II II Ii / , . ..-,. ,: .:,,:_,':,: ,:;~~:SÞ~~;~~%it~:dt¡~i~~g~;W:'·~ :::". .. .' ", :.. . ·4~·'·~'~W-~"4~~,-:".<'-;,,¡,:-;Ä!' .- ." : '?~:~~'~~~;;~3t;i:{;:~t~~~!~P~~1i~~~~t: . ..->........:.....:.. ... '.-.-. . '. --'-..~.. ..... ~'. . . - . . . .-:"~;::..:..::~~~~:-;; :{~.~'- :~ )~1 DEPTHS tf '''~.' .' .I:' I:·:-:~·~ ··.:,.~·~~~~~::~1·;"·, ~:~ '~.~._# ',- -~-~:..., ;'":~~. : . ~. ... , . ., . . ~'¥: ~·~~~~1~~~.f;;~r;·~~~~;·;;,~J3:f~/f;¡;~~~~~~~?~B~2~'~..' ~_1:~.~ ",:...:__~..; ""1"':~~""''''1-:''''''"~"",,,~,,,:~~:;,, " ;':~ ~~t;·:;~.~~~·;':ú~l~~ê6re-: táb :::~: 2(:'<~:''::: ';~':;:-:';!;:~ ~~::~~;~. ::' . , , ~ : .~ ~.",. '.~. ',' ~ . , \Ç: ¡ , ".: :~:', ;.::~:~~~~~~¿.:(Ì:i~:~~~~~~~~~~~~~~;.: ~..~ : ,. .. . .-.t:............. '" :t"'''-~''-<'''~~~J>~--'' '. .' .' :,.;.-,~;~~.-:;f·;~·-::~f';'-~""''''~ ';~~:;"'--' . -:~',.; '-';ô.1.....~::\:!.,_··.;·,:·~~·':i~.,~'·..··,··..·· . . .~. '_':'."'.';:.~ ·_~~·.::·t)o.! ~"":-; ;;" .::.:.. ~'..:. ~-~;'''''i;~._''l~:~¥'Itì.. 0tre(>t . . ~.... ;.('Y-/'_.,--:....~'\~..... :-:. : .-.... :'\~""~..~\t~1;i:;I~1J ·/\I: ~I\. . . ··-:,·...:~.~1:d)3· ~~(,.:.s .<~~~<:~;.....:. ':.' - . ··~~;:::.~:~~1~J;i:.;i~..;? :b,~': ':' . . .~ "'I'". . INVEKTORY COr.1pany: \-Jèli Name: Content:s: ¡....- , ~ J CORE " BOX DEPTHS I! . Dr cl <f I/? 95¡)i Cot56.3 .:¿ ~~ - ~3 of ';)(j to 95/'.3 -10 9S 7. 5 :ltJ 0/= ..2<; '9575 - ÞrSf: c;- . , '. ... ; -I , .' .. .. ¡"~' " 0 ....~~~...:.'..... .~ '- q '_....:~,.... , .:.-..-...... -- '0 :]>.-. !- .::,. -~'.:~' . .. .. '. : , . . ..--~ ..." .. .. .. ." , " .. .. ..... "', .' ".' ~ I.. N..t'::~:'J;~~!~/~'.~'\~ . , ,. ..; ·t~ ~~-::~.... .' . ¡ ,. , .. -. .,.;... '. '. . . . - , . .' '. :'. ..... '~..,; . .' " .,. -':'.';'~~. ;;,,-·-~i.·.. ~ < :~' , . '. ., .. .' , .: ... , -. . ..'!:.~ ' . .',.1>.'. .. '. ;. "", ;~'... ..:,.; " ...... - ~.'" ..... . ,.:-:.':. . .. . . - . . ,u '?:~k1;¡;~1~fiJÞ;~c":;~:.Jt';ib~§;~~~~,ß.~~~ " ..' ~'~-~~~:~~;~~~k~~~J,i~~~;;; h~' ,......... .' OCr '3 ..',' '....,.... , . ,.. . c . .~ .,'" .~.." ..'(..... . r v' ~".... .. . ....~ ..~:.:..~~I ..;\.::, . 1 '.- " ~ . ~ f _ . J-",.~". - -"'. . ¡ -', '. ." ' , . \i' :~ ; , . , . . ~'.'-.' ..;, fi " ." '.Ij . 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'·-·.::.:.~::.~~'~~~t:·:" c.~,~ ';',';' Co¡:¡p;¡ny: flR..c 0 \,1e 11 Ibmc: K'£l) 31/-1. Conlents: flzesefivecf 11'1J;~ to.·_ " ~ CO~E II BOX DEPTHS ¡ I. . 3 70~rtð ;/3 /)~ ;;5 - 7lJ~'7 ? cf<V of ~51 7o~fJ', 9'- TCb?<lr ~s ()¡: oP 5 'lo~ 9 ~ ? - '103o'¿ l I -_.-.- , ¡ -j ....... , h' .. .;.0:;..' .. '. .- ," .......... .' ." ." ...,:... .' . 0, -.~ ...... ..~~.. .........;:.. .;.. . , 01."- ~ .~ .. .~.~. . '. ~ .'. .' " " . .. ". ·1.· .....' ... ........:--........:. '. .. . ¡..:," .... .. .'. .: . ~~ ,. ' ,. .. . ...... " . . . . .' . .. , ", -~. . . . .'.:'-, - : "',,,-'.':--'...' . '::~."~~~ .~.-" ,'~-': " "'-.' ..t.. . ". ·./~":_".i·'~:~ l' ~. ., . .. '., ,I'. ....:"... , .' ~ c-,. ~-~~ . '.~ " .~ . '.. 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'Im~ TRANSH ITTi,L AND ACKNOi,1LEDGEt-íENT OF RECEIPT TO: /érrc.. kK Un ì ve.r~ i + 'j Re...s.~_G/"C.k P(U"~ ..360 Wo...'(CM"O- W~ Salt Lo..~ c'~-tlj 1 (lt~ BL{,o~ 7¥ /~ is i ra A~n r"få1.l Qn ¡/I IlfIl.nt-C>rJ .. /.5 t:l !.so -I -) A-t+n ~ ~e(('~ BE('qöS\.¡ A ì (' b 0(' "e.... Materials received via I c.fo....-t e.. Cöre. So..""'ple.s ( Se.ve.r) boJJe~) JCJ $o...C"'\e k~ -\-0-\-0...\ - KRu.. 3\.\~<i. whole. Core. ~pl~ ,',- ~, # .~.i.::w.. p(e~ervé'd ìi\ core'.seøJ ~t~- b86g,1.-~?<7.J 697/..6 -7:<.5.) 6B73.3-73,9~687"19-7" .6B7b.O-7~& 6ß79. 7- 8/'1).:7 6888.5-89.¿¡~ 689/..5-9:1,~ /,89J.fl- 9~'~,6899,3 - 9f, 7., ~9()tJ"l- IJ/.:l,:) 67/13.3- p¥,S:> 69t/6.3 -ð~3.tl9ð2:¡- tJð...~ J t9/tð -ItS, 6r¡/ii~-J~7~ 69fJI. 7 -1£6:1 67/5,6 -/6.::l ~ ~?Ib'.J! - Jf, f PLEASE RETURN ONE COpy SIGNED Shipped by: ~rL~ for Core Lab /Date: /~..A':J- 97 Received by: for /Date: . ~...." ",_. ~~ '. . '.". " ............. ........,..~-,~ .~..... ....': ..... , .. ." '.:,;~~ ~~':.~~" ....~~~...:~-.-.':.. . ;, ". ,. , ~. ._.. :; ~".c.: . . ... :. ,:.\..:. ....:;,:....:~~..;:...~~~~~:~;... '. ~, STATE OF ALASKA --, ALASKA L AND GAS CONSERVATION Ct.. .¡MISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work Dri II W Redrill 911b. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil )<[ Re-Entry 0 Deépen o Service 0 Developement Gas 0 Single Zone l¥ Multiple Zone [J 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO RKB 76' , PAD 39' feet Kuparuk River Field Alaska, Inc. 3. Address 6. Property Designation Kuparuk River Oil Poo 1 P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 ,/ ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25,025) 1347'FNL, 281'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nurpber Number 1341 'FSL, 1808'FWL, Sec.12, T12N, R8E, UM 3H-9 #8088-26-27 At total depth 9. Approximate spud date Amou nt 1265' FSL, 1852'FWL, Sec.12, T12N, R8E, UM 11/15/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3H-8 7309'MD 1 'HL1 '(â) Tn feet 1()' (¡¡) 1?ll.()'T\ln feet ?c;.~() ( ~ < ? ? , T \/ n \ feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1000 feet Maximum hole angle 42 0 Maximum surface psig At total depth (TVD) 3066 psig 1 815 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115 ' 11 5 ' ±200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3427' 35' 35' 3462' 3066' 1200 sx AS I I I & HF-E W 400 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 7275' 34' 34' 7309' 6322' 200 sx Class G(minimurr) HF-E W TOC 500' abo ve top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measu red feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural f) r' f' ~ Conductor I'';. ~ ij" ~ ~ "- !I_. ;, ~.V Surface Intermediate Production ,t\:n:3ka f}i; i) (}?S Liner Cr- '" ' :';11.' 'c' Perforation depth: measured true vertical .- 20. Attachments Filia[ fee ~ Property plat 0 BOP Sketch ~ Diverter Sketch ø Drilling program Xi Drilling fluid program Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ?( 21. I her~ï7fY that the foOrrue and cor.rect to the bes~ of my knOWle~ge . . . ~~ S i g n e /.4h ~¿f / .J<S L.../.I. /iI.t..A/'\.......' Ti tie Reg 1 0 n a 1 D r 1 1 1 1 n 9 E n 9 1 nee r Date/OÁ /7 ~} / 7- / f/ 1 /- '" .r Commission Use Only (HRE) PD2/54 / ,/ ;/' Permit Númber API number I APpr1vðl/tlåe/ 87 See cover letter Br~(t 'EL 50- iÍ 0 F¡ -~ L-:;cof1(~ for other requirements Conditions of approval Samples required DYes ŒrNo Mud log required DYes ~No Hydrogen sulfide measures DYes I!YN 0 Directional survey required [ZJ Yes o No Required working P2 BOPE ~pQ 3M; o 5M; o 10M; o 15M Other: ,p ~-;t/... by order of / /)- 2¿J-¡JJ') Approved by , /vŸ---'<.., 'AO. ~ Commissioner the commission Date /' ,,---r - - - (/ --' Submit in tri licate - Form 10401 Rev. 121 85 P .-.,. "i ¡ ~.... -- i 0 ...'n. .....SURFACE 1.000 2000. ... 0 - - ra30.00 .,. ... ra 0 ... .. ') ~ - ':J ra 0 ~ J: 4000 5000 6000 7000 .KDe-.rYn~, 1. O_OO,-THD~ lOO-ODEP-O 3 . BUILD 3 DEO 9 PER :100 FT 1~ al- PERMAFROST TVD-1 591 Tr1D-160 1 DEP-94 21, : 27 T Ii ueNU SNOS TVD-1876 Tt1D-1'910 DEP-213 '--~"'33'_o' .0 . . . 38 eoC TVD-2280 THD-240~ DEP-492 - , iTlW SAKSNDS TYD-2588 Tt1D-2188 D£P-7-5-i K-12 TVD-2866 TMD-3192 DEP-1021 . 9.5/88 CSG PT TVD-3068 Tt1D-3482 DEP-t202 COLVILLE TVD-3116 THD-3529 DEP-1247 AVERAGE ANGLE 42 DEG 5 MIN BEGIN ANGLE DROP TVD-4045 THD-4781 DEP-2086 K-5 TVD-4416 TMD-S255 DEP-2381 42 39 ' 36 . 33 30 27 2.4 21 18 1S ~ , . DROP 1 1/2 DEG PER 100 FT " '.", ::,'- Y-', " .'". 1. END ANGLE DROP TVD-5811 TMD-6786 DEP-2987 iTI ZONE D TVD-5911 TMD-6889 DEP-3009 ~TI ZONE C TVD-S919 TMD-6897 DEP-3010 TI ZONE A TVD-6010 TMD-6990 DEP-3030 TARGET CNTR TVD-6023 TMD-7003 DEP-3033 81 KUP SNDS TVD-6126 TMD-7109 DEP-3054 TD CLOG PT) TVD-6322 TMD-7309 DEP-3096 TARGET ANGLE 12 DEG , , . 0 1000 2000 VERTICAL SECTION "000 4000 ---.'0 'd 100.0 ,SURFACE LOCAt ION I 11347' FNL. 281' FWL :SEC. . 12-.T'2I. ME i-, 00;' z. lOOO 0 ::u .... % I en 0 c: ~ 2000 3000 4000 1 SC~l.£'I¡ IN.. . ARCO ALASKA- INC. Pad 3H. W.II No- 9 Propo..d Kuparuk Ftald. North Slop.. AI..k. 1000 SURf' AŒ TARGET LOCATIONc 1320' FSL. 1820' FWL SEC. 12. TI2N. R8E a WEST-EAST 1000 2000 TARGET CENTER TYD-6023 T tto- 7 003 DEP-3033 SOUTH 2613 EAST 1 538 S 30 DEG 30 MIN E 3033' (TO TARGET) -¥--- * ~ ,¡; -~ ~ 3000 , .,. , TO lOC^TION, 1265' FSl. 1852' FWL SEC. 12. TI2N. R8E ~, ',,",':,,':,' ,."",,:,',.,-~,-,:',".':",',""":,',','.",,"H,'..:,',",'":"',:,',"':,',",",','>~~'i"l;-C'r,'Wt'C"-'f:"~",r" 'f~F~-'wrF" '","""r~»F,' ,..,-~<9>~"l",>T>'~;"1, ' . "'HI»""'I,"-"'- - .- ¡~,-,,',--' ".-----"l,-"-'~r~ ""'1 . - "'-.'{':]:-fT'O!'f>':L::":.{"':"'. ¡'~i ::, "1-:"--- ':"'-':(""--------""'! -":' \:. \ : i --._-+'_.__._-~.~_..._-----._+.._._---_......_.--_..--.--...,,_.....i- ----;""""--""'---" ,.-........-'-- ...' . '_h--'-'T"'------"-"-""-'-"------~--" 1250, 1,300.. 135.0. 150 250 350 400 300 200 .-- -- -, - - - - - - - - - - - I I I I I 450 1250 I I 1300 500 400 .....-- "'3S(Jt) - -~70cr ~O- --;s 300 !.{ ,'1 f'~':' h~, e. ¡.~ . 00 \ 1100\1400 500l. \ '1500 \ \ i.. , 1 600 \ \ \ \1700 \ \ 00 \ \1800 0 " ¡..,. -~.-' 14.0.0. ,.. 1450. 1500 1550 1600 1650 , . I .; . I I I I I I I I I 1100 '500 1 20~00 . '800 \ SOO\. 1 300 \ 600 ,900 . '700 \ , ' 1 000 I Sap , , 600 \ 800 \ \ , 1 1 00 '700 , 900 \ I \ ' I , , 800 \ .,1 200 I '1000 \ I \ \ \ \ , 900 \ ' 1 300 - - 20038 - ~ - - \ \ \1900 \ \ \ \ \2000 I \ I \ \ G \ 0 0 c.I G - - - 150 200 250 300 350 400 1350 1400 1450 1500 1550 1600 1650 450 HRE/13 ih Move in rig. Install Tankco diverter system. Drill 12~" hole to 9-5/8" surface casing point according to directional plan. Run open hole logs. Run and cement 9-5/8" casing. Install and test blowout preventer. Test casing to 2000 psig. Drill out cement and 10' new hole. Perform leakoff test. Drill 8~" hole to Kuparuk core point according to directional plan. Core Kuparuk with water base polymer mud. Continue drilling 8~" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. Run and cement 7" casing. Pressure test to 3500 psig. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. Nipple down blowout preventer and install temporary Xmas tree. Secure well and release rig. Run cased hole logs. Move in workover rig. Nipple up blowout preventer. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. Perforate and run completion assembly, set and test packer. Nipple down blowout preventer and install Xmas tree. Change over to diesel. Flow well to tanks. Shut in. Secure well and release rig. Fracture stimulate. ,.-, - - .31/- 7 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. 2. 3. 4. 5. 6. 7 . 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. DEMSSER MUD CLEANER SHALE SHAKERS STIR MUD CLEANER -- ," " r-, (. ,- , (, -,- STIR STIR CENTRIFUGE TYP I CAL MUD SYSTEM SCHEMA TIC -~~ / DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Cas in~ to Weight Up Weight Up to TD Density 9.6-9.8 8.7-9.2 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel '5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 6 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10:t 4-7 9-12 Drilling Fluid System: Triple Tandem Shale 2 Mud Cleaners Centrifuge Degasser Pit'Level Indicator Trip Tank Fluid Flow Sensor Fluid Agitators Shaker (Visual & Audio Alarm) Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No.2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih . ,-, KUP ARUK RI VER UN I T 20. DIVERTER SCHEMA TIC ~ 4 ,. 16" CONDUCTOR 2. FMC SLIP-oN WELD STARTING HEAD 3. FMC OIVERTER ASSEM8L V WITH 1'\\10 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOa.. W/10. OOTLETS 5. 10. HCR 8Äl.L VALVES W/10. OIVEATEA LINES. Å SiNGlE VALVE OPENS AUTOMA T'CALL V UP~ CLOSURE Œ ANNULAR PR£V£NTER. VALVES CAN BE REMOTEL V CONTRa.LED TO ACHIEVE DOWNWIND DIVERSION. 6. 20.2000 PSI ANNlI..AR PREVENTER 6 ARca ALASKA. INC.. REQJESTS APPROVAL Of THIS OIVERTEA SYSTEM AS A VARIANCE FROM 20AAC25.03S{b) MA 3 1. UPON INITIAL INST ALLA TlON. CLOSE PREVENTER AND VERIFY THA T VALVE OPENS PROPERl V . 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERV 12 HOURS. 3. CLOSE ANNULAR PRE VENTER IN THE EVENT THA T AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIA TE VALVE TO ACHIEVE DOWNWIND DIVERSION . " 2 UN 1 JG 1 1-3-86 .- ;- . , / 0 7 6 5 4 3 DIA<RØM #1 I. 168 - 2000 PSI T ÞN<CO ST ARTIN1 ~ 2. 1 I 8 - 3CXX) PSI CASI~ ..øÐ 3. I I 8 - 3000 PSI X 13-5188 - 5CXX) PSI SPACER SPCX1. 4. 13-5188 - 5CXX) PSI PIPE fWe S. 13-5188 - 5CXX) PSI tRILlI~ SP<XL W/OO<E ÞK) KILL LIr€S 6. 13-5188 - 5CXX) PSI DO a.f RIM WlPIPE RÞMI ~ TtP" 8lIN:> RM8 CN BOTTeN. 7. 13-5188 - 5CXX) PSI ÞHU..M I. C)£Q( NÐ FILL þ('XJU. &Tœ ~OIR TO ~ LEVEL WITH HVDW I IC flUID. 2. ASSIÆ THAT N::!:JJÆ. & TCR M:SSI.. I S 3000 PS I WI TH I 5CX) PSI CCINmÐM a: 'n£ RE<1U Tœ. 3. æsEJM: TDE. T1Ð4 C1.CIE ALL 001'8 SIMLTNEalELV NÐ REaR) 'n£ TIlE NÐ fW:SS.. AElMINItG AfiER ALL OOTS M£ a.C&D WITH OMGINi FUø» ŒF. 4. REaR) eN ~ ~T. 'n£ ÞfJ:EPT I8.E LCIER LIMIT IS 4S SEaK8 a..csOO TIME NÐ 1200 PSI RE*INIM) PRESStÆ . . I I. FIll BCP ST AQ( NÐ OOCE t.W4f'CLD WITH N«:T I C DIESEl.. 2. O£ Q( THAT ALl L OQ( ~ SCÆ>I8 I N VEJ...LJ.£þD ÞÆ. FU.L V RETRACTED. SEAT TEST PlUG IN VEJ...LJ.£þD WITH R\ffiIMJ JT NÐ Rt.N IN LOC1CI:XIW SCfÐI8. 3. Q.œe: ÞHO..M PREVEN1'ER ÞHJ MW..W.. KILL NÐ OOŒ LIf'£ VAlVES ÞDJAŒNr TO BCP STAOC. ALL cm£R VAlVES PI{) OO<ES SIÐ1.D BE <PEN. 4. PRESStÆ LP TO 250 PSI NÐ .a.D FCR I 0 MINe I f'.r æEASE PRESStÆ TO 3ŒX) PSI ÞH) H1.D FCR 1 0 MI N. 61 f:m PRESSÆ TO 0 PSI. 5 . CPEN ÞHU..M PREVENTER ÞH) MANJAL. IQ LL NÐ QOŒ LIf'£ V AlVES. Q.œe: TCP PIPE RPM; NÐ HCR VAl.. YES CN K1 LL PH) O«J<E L I ~ . 6. TEST TO 2SO PSI NÐ 3CXX) PSI ÞS IN STEP 4. 1. CCM"IN.£ TESTIMJ ALL VAlVES. LIf'Ð. NÐ OOŒS WITH A 2SO PSI LO'f NÐ 3000 PSI HICK TEST AS IN STEP 4. Q. œ;e: . 8. <FEN TCP PIPE RNJS NÐ O-œe: BOTTCM PIPE RÞM5. TEST BOTTCM PIPE RPM; TO 250 PSI NÐ 3CXX) PSI. 9. <FEN BOTTCM PIPE RPM;" BAa: C1JT R\ffiItÐ JT Þn) PLU. C1JT a: HCLE . I o. a..œe: BLI~ RNJS PH) TEST TO 2SO PSI NÐ 3<XX) PSI. II. CÆN BLI~ RÞNS NÐ RETRIEVE TEST PLUG. PwW<E SLÆ MAN! F ClD PH) L I f\£S ARE FU.L a: r-m-FREEZ I ~ FLUID. SET ALL VALVES IN I:AILLIrÐ PœITICN. 12. TEST STAN:PIPE VALVES" KELLY.. KELLY COC<S.. æILL PIPE SAFETY VALVE.. PH) It\SIŒ 8<P TO 250 PSI AN:) 300:> PS I. I 3. RE CCR:> TEST I N=" CRAA T I CN CN BL ()OJT PREVENTER T EST FCR.4.. SIG'J.. At{) $EN) TO I:AILLIr-.13 SlPERVI5æ. 14. PERFCRA ~ B<FE TEST AFTER NIPPLI~ LP AN:) V£EKL y Tt£REAFTER FU\CT I CNAl.L Y CFERA TE BCPE CiA ¡ l Y . 2 ,",0_,; - 510084001 ~E"'.2 MAY 15.,985 I , 0 I - -----... cc... "---, .. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 5, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 COMM ccÖ~J1M ---- --- - -MM co 17'\ RES EN~_~- -SA ENG__- SR EN~- ENG SR GEÖ~ - - SFf GEOl ---- ENd l\SSî -.-..-.- . ,... fiNO AS. sfÁ:fTE I SfÃtj~E 1 F-ie E: SUBJECT: Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincere ly, Ck Ûiì1/J{¿ sffill ~ a. Gruber Associate Engineer JG/pk GRU1/31 RECEIVED Enclosure AU(j 1 1 l~ð I ~~ ~~ , , .-\ ,.t i ", ';"_: I If Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc- is a Subsidiary of AtlanticRichfieldCompimy ~ I.'" ,~ - . . 2 II :2 -+-- . ' I a. IO:!I II. ." M. M:" II:Ø ... I' )t S~S NOTES .. ALL CO OR D' N ATE S AI' E A.S. P., Z ONE 4. 2. AL L DISTANCES SHOWN ARE TRUE. 3. ELEVA TIONS ARE I. P.".S .L. 4. REFE". FIELD 800K L-87-19, 35-44, L-87-tt, 29-32. 8. O.G. ELEVATION 5 FROM CEO -II' IXX - 3~71 A 6. HORIZONTAL POSITION IASEOON 3H CONTROL MONUME~E&' LVtil),URY a Aaoc. ALL WELLS LOCATED IN SEC. 12, T.12 N., R.B E., UMIAT MERIDIAN. (, ell ASPs 'X' LATITUDE LONG! TUDE [)i sf F. .st . . I 7O02~'41.5:5'" 150° 00' 39.4'6" 15'4ti&ka Oil G2~ c'ons. Co ' 8 6,000,110.73 498,655.44 m~~&; 2 6,000,135.5' 498,655.43 70° 24' 41.775" 150°00' 39.417. 1522' Audrage 34.0' 3 6,000,160.57 498,655.39 70°24'42.022" 150°00'39.418" 1497' 28" 33.9' . 4 6,000,185.28 498,655.43 70" 24' 42 26~' '50° 00' 39.4'7" 1472' 281' 33.8' 5 6,000,210.66 498,655.47 70° 24' 42.514" 15r1' 00' 39.416" 1446' 28" 33.1' 70° 24' 42.758" 0' 9 " 1422: 281' , 6 6,000,235.50 498,655.40 '50 00,:5 .418" 33.7, 7 6,000,260.34 498,655.41 70° 24' 43.003" 850° 00 39.418 1397 ze,' 33.6 8 6,000,285.82 498,655.44 10° 24' 43.253" 850°00' 39.411' 1311' 281' 33.6' 9 6,000,310.30 498,655.45 70° 24' 43.494" 150° 00' 39.411' 1347'. 28" 33.6' 80 6,000,335.43 498,655.44 70°24'43.748" 150°00' 39.4' 8322 28" 33.6 ' 81 6,000,425.37 498,655.44 70"24'44.626" 150°00' 39.488 1232' 28" 33.7' 82 6,000,450.5' 498,655.38 70°24'44.873" 150°00'39.431 1207' 28" 33.8' '3 6,000,475.46 498,655.42 70024' 45.119" 150° 00'39.419 8182' 281' 33.8' 70024' 45.3~ 150° 00'39. 4I( " ~ 7: 281' , 14 6,000,500.4' 498,655.43 33.8, 15 6,000, 525.44 498,655.41 70°24' 45.610 150°00' 39.41' If 32 281' 33.8 86 6,OOO,~50.46 498,655.47 70°24'45.856" 150°00' 39.417" 8 K)7' 28" 33.8' 87 1,000,575.45 498,655.55 70°24' 46. '02" 150°00' 39.415" 1082' 282' 33.8' 18 ',000,600. 498,655.59 10024' 46:S4S" 150°00' 39.414' 1057' 282' 3 3.8' & 20 6,000,650.45 498,655.49 70~4'46.84d' '50°00'39.418" 1007' 282' 33.9' 21 6,000,615.«) 498,655.63 70°24 '41.085- 150°00'39.41-5' 982' 282' 33.9' 22 6,000.700.42 498,655.73 70°24'47.331" 150°00'39.410" 957' 282' 33.9' P d I v. 38.8' 38.8' 38.7' 38.7' 38.8' 38.8' 38.9' 38.7' 38.6' 38.6' 38.7' 38.8' 38.8' , 38.7, 38.7 38.7' 38.8' 38." '38.7' 38.6' 38.6' ~.... ARca Alaska Inc. I HEREBY CERTIFY Tt4AT , AN PROPERLY REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING 'N THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SUAvE Y MADE BY ME OR UNDER NY SUPERV' S 'ON, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. -""'- ~.. OF At. '-- ...~~~.... ..... 4f') 'A.. 'L'.' A -. \)L~ ", .. ~ "r¡ . I fJ..: 49TH t~ ..'e~ \ "...., "";;:;" ~..\...: 1..I:!f:-..... ¡... ~~., '~.. IOHN w. T A nOt ~: I t..¡ '. LS. 4(546 " . 't... e.. ,." .. ~"""'~." . "'V¡ess~\ \; .. ~,..'\.."", KU "UK "OJECT D.S. 3 H WELL CONDUCTOR AS-BUILT PREPARED BY LOUNSBURY a Associates ALASKA CHK BY; JWT ANCHORAGE OWN BY: PJW ^ - - - - Ccmc AF-- ~ ~ - any -,' -\L_Cj Le.ase & Well fu. 'YES }. "TQ G.-ECK u:s-;. FOR NEw W I" ~ :r, PE?l1ITS 1: ¡ :- M APEROVE MT ~ 1. Is the pp~t fee a~a~~ed .......................................... á5 r' ! /, ~ ,;-, 1)/)/1" /..... ,ì ,(';, ;~J,< /;::7",' .!4..-I-" ~, {. ,~~ '~- ..' ¡ ~ " (1) 1'E:e - (2) we - .' ~ ~ J ""'il' " , /.oJ " ,/ {; ¿,J/ð",{,/"- Ie)) ,ç,.~ f / {; 1 (2. cr1rù. 8) , 4tl.d ~ /0-:27-87 (B) . (3 ) Þr1riri 11/}; D/~, {/v ,~. (9 ~ a1IU ,(¿(~~ /0-.27-8.2.. (10 ana. 13) . (4) Casg ~~«r I~ -27"8 ., ( t:tIt'U 2.2 ) (5) roPE k Y. -lit /6.:7-8" (23 tnru 28) , (6) (J¡r.!:-~ ~~~~n~>11{~ ~ (6) Add: ,,4f.:/.~ /0-:11.87 Gealoq: ¿Zf~: :: w't MIH/ ~ ~ /{:":. «",1../' ,,'-"0,'" " :rev: Ol/'2ß/87 6.011 2. Is well to be located ~ a ñp~ned pool............................. :11 .3. Is well located proper à:is~;:mce LUll. prot)~'-f line .................. 1;: 4. Is well located proper distance ':"'CUl other wc=lls ...................', ,f? 5. Is S't,r:; C'~ er1t lmderli ca.ted acreage. a:vai1able in this pool ............ ,.'if 6. Is well to be deviated and .is ~ore plat i-n~l:uded ................ el? 7. Is opera-tor 'the only affected part:y ................................. (J") 8. Can ~1"mi t be. approved before A rU:e!l-day wëri..t ..................... .Çf? 9. Does ODe-~tor bave a bond in force .................................. ad 10. Is a cònserva~ order needed ...................................... ':~ 11. Is añmri"T1i~t=ative ~oroval'needed ................................... --- ,~ . ~ 12. Is the lease. ïn~er åDD~oo~~te ..................................... c1? 13 . toes the well bave a ùDiqÜe "T1~ and rn;mber ......................... .Jj /Û( - ~ ,.:Jß. d:I£ dJL d!:f.. '. 14. Is canåuctor s~~ provided ........................................ 15. Will surface casing protect: fresh water zones ....................... 16. Is enough c:erœnt used to ~..ll.ate on conåuè-=or and ~-aee ......... 17. Will CP!"rP!1t tie in surface and int~te or proåucdon st:""Ï-DgS ... 18. Will c~:t cover all kncrwn produc.~ve bor.:.zons ..................... 19. Will all c.asiDg give ade.qua.!:e safety in colJ.apse, tension and burst.. 20 Is this -- T"'I b ~-= _1 . - - ,.. .. --111- . ~ to e ~tŒa aD: UaIl an ex:l.S't:u.-,g ~ore ............-: 21. Is old W'el.IDore ab~d[ JUUJ:ut proceåure iJ1clucied on 10-403 ............ - 22. Is adequate wellhore separation ~se.d ............................ ~ 23. Is a d:i..'Ve...~e:r syste!D. ~ ......................................... ~ . 24. Is the dJ:i1ling fluid pro~l..aw. sc.h~t:i.c and list of eqtrl LJll~Qt: ade.qua.te~ 25. Are ne~~sary dia.grams and desc:i?t:ions of åiver-...er and BOPE a~~ched.-1:!L 26. Does BCJPE bave snf-fi ctem: Pressure rari-np; - Test to ~ psig .. ~ 27. ~ the choke rremi -fold CCIIply wi M!I Rl'- 53 (¥.ay 84).................. - 28. Is the presen~e of E2S, gas probable ................................. - For exploratory and St:::a.t:igraI)bic wells: 29. Are. åata presented on potential ave!;pressure zones? ................. - 30. Are sø.; ~ c analysis data present:ed on sbalJ.ow' gas zones .... ,'....... 3.1. If an. offsbcre lac., are 5'Ur7eY results of seabed c:cnditicms presen~/' 32. Addit:iorla.1 reqtD.J::e!"!~t:S ............. .'.. ............................. - Addi d cm~ t RemaJ:ks: J \:rm.T!Ãl. POOL 0 C!.áS S STATDS 4 ,," ~r /' <co -, '. \ ! ì í-=- I¡'~! C / L . - ~-' "-.'(-' ",.. \~ \ÜÑIT NO. \ 1 i I ~,(") PWõ'E: . 5EoRE \ (' t, . k'~ ßjd',J (:',.. -- t -::11' ~? REl'iAlOCS - ~ ~8 -- §~ ~§ n~ t::1t=1 ~ .::::/:!:! - -Æ/A Ki>P ~ I OO/? ' IYIA 11 bg "lA1t+l.; #oJ J 0 ' ð+ ~)-/ ...'j - , @ 12..40" = þAiANC/&' ~, d/I/¡£~ ~ d ~ ~r R~f~ uJ!:td-eri - No+ .<"UbM"#l!!:.d -;¡;¡ ¡. ,(:5- I' . I /- :t!L -- ;':)C)vo ,,) ,'--' STRA TIGRAPHIC HIGH RESOLUTION DIP METER LOCA TED IN THE APPENDIX Well History File APPENDIX Information of detailed nature that is not " particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information. of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically. . organize this category of information. " '\, i Off £d,J.}. J(k-~~J< 3H-C¡ &-e h ho(.e) ;Jfð3 S71 i~, ~~ ~ "'~tD ',',,',"" ,,'i',"', ',,', '.'.',,",'~,' " ':è ,; ~, '>" \: ' ';"" Ii:,; '~' :'".';,1 ,.. t:'¡ H:'i.. ~~ ~ ,,~, '."I'{ t't ",,'!",J,:~.~:.~ '~:~"':"Ii'I"~':;:t~;-.;Þ.'~~ *--.----------~_._---. lJO/~s. ' at!; , , l{qlùo") . v!J¡œ.., t. I'" ,.. A r,¡ t.' ' V S I.jv'~, '..' ,') i I: t'. . ',', 'I..1C ,lJv ,," F91,r."" '¡"'c'i\'r-'r'M",," ,'r.'s"..,",!,iI\fG:" 'JSÞt) V,'~',,".I.,l'<:...ì.J' f""""'A.,t,,, /')'~/I:" ~v ~ '!n r" ".~tl)í::A """'$; I; V: Y;IS!?~-# q~ C1 C Da(J " ,..,.í1I¡J~¡¡ , ~c1 " Lu... I ' Schlumbe~ger ( ( (" LyP 01P.HO2 VERIfICATION LISTING ** RfE:IHE:ADEH ** SERVICE ~AkC :~UJI DATE :87/12/1.3 i.JHJGJ¡., : REEL NAM£ :12528 C CJ N T I \' L! A T r [J Nit: \} 1 PR~:VIC¡{JS REEL: CJ~NE~TS :EDI1 LIS,ARCO ** 'rAPE HEADER S L' D '" }' (' L~ '\', AM"" ~ r;., f\, " (;. ! !':, ,,'! I::,; DA'1'E ':87/12/13 () RIG 1 t., : 7 25 2 1'APENA¡\11E : C (J i¡j T 1 t\ I ¡ A T I [1 J"; 1~ PH.EvtQUS TAPE (' 0 ~11t E ~< T S ; ED I 'I KUPARUK 3h-9, ,PlffS(¡-l 03-20086 ** :f:Ol'l' : 01 .. . LIS, AH C 0 1< U P A H ( j 1<., 3 !! .. 9 , A P I # 5 () .. 1. 0 :3 .. 2 0 0 a E ********** Eur ********** ** " }f t~KM -.... , Cf'/,' . ",\4!N" : ,[;, ".. ~, . "H Þ., NG l TO~; N : ,~~f'.:!','.,~ C Î"J IJ ¡\ ; ",B'J"'J.\'l' : CTRY: j'i i\j F:~\'j ",' ..... ..' PAGE 1 .-... 000 QUO " 000 000 (jOG 00.0 000 QUO 000" C;J ¡'~,:fE¡\ T :~; "',"" -... "" ... . " '" '"", " ,.',' " ." IJ:\! IT TYPE CATE "..""," ..""'" ".""" ."""....-..."".. --.... ..-..- 'l'ïP.E ""CATE 'SIZE -.-.. ( 017 ",Ot5 (¡OB ûQ2 GO) 002 Oil Q9b 004 SiZE ,...-.. .. , . CODE "."" 065 OtiS\,' 065 <tiS 065 065 065 065 065 CODE ..:-... PRF..:$l' ti:,.., ,', " ' (Jon, 000 QOl Oø5 * * r. 0 ~¡i ~j¡ E:ì\j 1. S * * "* *** *- ************* **11:* ** *' * * * *' * * *- * *** **** ******* * * ** tf***** *** * ******* *** ***'**** ** 1 ("I 2/ ,," 1" ** fILF dt:ÄIJE:P ** F' J L r' !' A r ~ .~,: : F: l" 1 r S r:~'" VIe f ;'; A,'v'! r: : V¿;RSlt,Jr.. if : ÐÄTE,:: ' " r..IAxr""l/i'i IIEf,iGTb : F'l t.lL TVPE::" PKEvJnus FII;£,: ; n (, ~( F C' i" ,CON 'tEN:TS "UN!l Ai"C"ì /\1 AS'i.'? I~,.., ":(,~L 1-..,"""';"¡-1" ,;"\..,. ",:3H.9f;Ct:H;tVI LL¡E)" KUPARuh ,aF.;. " ' " ], 2 Ie} ",12"'.,, , """'/:"11",..'1 t.;L'I\OL (\J:UI"I',.i,n ~. ;<-",-1::'[',. , fA C". j'/' !'l i~ ¡;J ~,...) n,f'1 U5J\ 000 ,,000, ooÖ ,99() ,) LJ 0 " Q(J (J OúÚ {J 00 " ,oOn 1., Schlumberger I, V POl () . H () 2 V ~ f< 1 F' 1 CAT 1 0 N t, 1ST. r N G P 1\(;£:; 2 :~ *** * SCttLlIMBERG€f< . * Aui\SKA CO"¡PI.!TING c¡.~rJl'ER * *************,,******..,,*********************************************************** C (J rt P rd\ Y = A ¡~ C () ¡HI ASK. A I i'J C WELL = 3H-9 (COL~I~LE) API # = 5D-l0)-20086 FIELD = KUPARUK CO!) ¡,~ l' J' = ~\f ,] ¡;( T H S L U P E B 0 H 0 UGH SrATE = ALASKA JO8 NU~BER AT AKCC: 72528 R u !\ ~ 1 f ,!) A T t- [J r; I'; GEe; :2 ., .. iHJ V .. B 7 LoP: R Cr\ K RUW Ea,¡l¡ CASING '1.'\lPE G't, !,t'r¡ 10 "I .r , l. , IJE;NSlrrt Vr~col(:)'TV . "'" .' \..,1 "I. 1 PH J::'lIJ!r\ '! 1'JC'!S (' I \ I.," ,\." = 9.625" @ 3500' ;. Be i\ !\i ì) 1< C [, :: 1 () [18/(; :: 5t3 S :: 8.5 - ,~ :; /"13 -, 't.., \., - 8.5" TO I ' Schlumberger ( ,,(, bVP. OJ (1.HO2 VERIFICATJO!\I bIS1\lNG PAGE 3 f.' I,';, I) I C" f '¡<i 5' , ."iM/'i1 t' "le..J , . ****' THIS UATA HAS ~UT B~EN DEPTH SHIFTED. OVERLAtS FIELD PRINTS *.*** *****.**~********************.****************~*****.************************** * * * . * . * * * * * * * * * * * * * * * * * * '* * * * * * * * * * * * * * * * * * SÇHI"UM.tiE:HGt..:R LOGS l~,!CI/UDf;.;i) ,~ITH THIS M/!tGNE'frC TAPE: DUAL INr I,)CTI(Jì~ SPHI:':RICA[../LY r'OCU5~,:¡) LOG (Dll,) DAIA AVAILABLE; 7306'10 1501' r (J F l.ì A 'f I Ü 1\1 DEN SIT Y: C (] M P E 1\: S ~\ '1' ~ () tlO G ( f j) C ) DATA AVAILABLE: 4000' TO 3700' C U ~¡ P f-~ N ;:; J~ 1 ¡~ C 1,~ t~ U T RUN Lit! G ( C N L ) DATA AVAILABLE: 4000' TO 3100' (; l\ ~,!~ 1": A RAY 'f 11 HUe AS)' I',: G ( C S G ) DATA AVAILABLE: 3561' Tg HECGH~) ** coj¿ 2 {~ ."'1 Z!< .:>. ,. 1 'I Hi~PR CLiVE Ób "66 ENTH¥ " ,0 1 ( ( , I ~ Schlun,"berg~r I ( LVP. 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" RE"EL~/lME 'r72530 " 'CJ~tI~UÂtrON. :01 NEXT.F{t~EhN'AME;",' " " '""""".',.,"",'"",",, ","','" """, C'OM~1€¡~)'rs :SCHIllJ¡'1BÊ~RG£R ;'~'£rJL SERVICES (~IJSTOMtR f~CtêtÄÞE" , ,..."..," " "'. ";,' " '" ""';', ";'" ," ";"" ,," , ,',' , , , ** ** ***;+; **t:Öf ** ** ***** *" ", '",,' ""'" "'.... " , , ',," , ," .. '.. " '* t * :+: * * * * * *:: G f' * *:r** * * ¥* * ( , [ schiu~¡'erg~~ I ( ..... RECEIVE~D. DEC 1 6 1987 A1aska 011 & Gas Cons. ComIIltsJJII AnchOrage /(Í{~KJ< 31i~? .""" t I', l~y!'€>h J; dI ..~) ,I' ,() 3,,§5{~ ..(, ( l._..., .. I ." Schlumberger ( . [JVP 'Ol().HO2 VER.lflC}~T10¡\¡ fJISTli\iG '* REEL HEADEa -* SEPVIC~ ~A~E :~DIT ()ATE; :87/12/ B 0 H I G l'J : REELNAME :12527 CONTINUATION # :01 PRE:VIOU5 REE:L : CùM~ENTS :EDIT LIS,ARCO KUPARUK 3H.9,API # 50-103-20086 ** TAPE HEADER ** SERVICE¡\¡AME :t:DI'l DATEt8711218 ORIGIN :7252 TAP£ NAME. . : CONTINUATION # :01 ~~EVIOtJ.s TAPE: CO¡~1MENTS :EDI:f IJlS,AHCO K~JPARUK 3H-9,API *' 50-103-200Bb **~******* €OF ********** ~If!~.lf.¡~ H ~ÂOER * * . F' I f..l E N A h t: ; E [) IT. 001 ~li;~I'I'I.I;" t .. . RSIQN# .. : DATE:'" MAXIMUM LENGTH: 1024 f'II,:ETYPE f.. PR~~VTQl1!" FILE. .' ' ," ". "..) .',' '.. . ** . PAGE 1 t'I rtECOROS ** UNIT"fY,PE'CATESIZE..' "CODE .... .... .... .... .... 000 . ,O~QO . úÙO ..OQ,O. 000 000. 000 ,000. 000 .. , '., . UNiT !t~t. 'CATE '.~~~ . ~*.-.. ._~~ .... ........ CN : ..IÞfrJ : F'N : ...~ANG~= 'fO¡'JN: "$SC'l': COUN! SitA tí '. (TRy: '¡It ;~tM ARca ALASKA, INC. 3H,.9... . ..' '.. KUPARUK 88.E '..'. '. 12N . . 2 . ~OR.THSLOPE ALA.SKA' '., USA' . . . . .' . .'" CO,,~T€,'i 1'8 . '.. ..... ..... ,..," -... 000 ..000 000 ..();(ìO 000 Q()c)... 000 000 000' 000 ....000 017 004.. aua" 0'02,'" 003 00..2'.. 011 Üt16. 004 SIZE ..".'.. O()l.. 065 ".0,65 065 '.0'61 065 ....065.. 065 '.065 065 CODE ........, 065 ( \. Schlumbe~ger I ( . LV? 'O10"HO2 Vf~Rlf'ICArtlON L¡JS'rING PAGE 2 **** * SCHLUM8ERGER . *Al,ASKA COj\t¡PLITING Cr~NTER * ***'*'***'*'*****..***********'***************************,*****,**.*********.*.".* COMPANY: ARca ALASKA INC WELL = 3H-9 ApI ~ z 50-103.20086 FIELD . KUPARUK COUNTy $ NORTH SLOPE BOROUGH STATE . ALASKA JOB NUMBER AT AICC: 72527 tg;I#Afc~A¡~U~~~~ED: 21-NOV-ij7 CASING.9.621" '3500' . TYPE FLUID * BLAND KCL DENSITY ## 10 LBIG VISCOSITY: 585 PH . . . 9,5 f[¡{J I D {., Us S = 4, 8 C 3 BIT SIZE. 8.1" TO 7310# RM : .l~3i@8~6ÐgF ~~è .'i87i18Q.gr RM AT BHT = :145 @ 133DF MATRIX SANDSTONr: . . , NOTE: 1.JFIL~: F,DIT.OO1CONtAIN$DArl'AÖFDUAL INt)UCTION (OIL), F'ORMATION DENSITY t~... .".~;r..I!e:.'i,BDIPŒN:Iì1xfml}Nl'~l1:i'J<4(eNf4) , .. AND GAMMA ..RA Y ..THRU .CASI NG (CSG). ( I Schiumb~~ger L ( . IVPOIO.HO2 VERIFICATION LISTING P AGf<: :) 5AMPLH:O tG .5' 2 .. ) F' I L r~ f'~ I) 1 f d () 1. CON' r A 1 ill S 0 A 'I' A 0 f H r. H E SOL UTI 0 N f 0 I< foil AT ION 0 to; N S I 'f ï ( f' D H ) , ANn HI REloLUTION COMPENSATgD NEUTRON (CNH) SAMPLED @ 1.2" ***** TriIS DATA HAS NOT 8EEÑ DEPTH SHIFTED - OVERIJAYS FIELD PRINTS '*'** ******************************************************************************. * * . * * * * * * * * . * * * * * TAPE: SCHLUMBgRGER LOGS INCLUDED wITH THIS MAGNET1C DUAL INDUCTION SPHERICALl,Y FOCUSE'.D IJOG CUlL) DATA AVAILABLE: 7306' TO 3101' FORMATION DENSITY COMPENSATED LOG (FOC) DAIA AVAILABLE: 7280' TO 6650' Cd MP~>~ SA T€D Ni'.:UTR UN LnG (CNL) DATI AVAILABLE; 7265' TO 6650' GAMMA HAY THRU CASING (CSG) DITI AVAILABLE: 3569' 10 914' FORMATION DENSITY COMPENSATED LOG HIRES . IISI AVII..BLE: 7280. TO 6749. COMPENSATED NEUTRON LOG HI RES (CNH) 1.'la'lllllbll 7265~ TO 6749~ ** * * * . * . .t., ( I SChlu";berg;~J { , I.! V P '010. H 0 2 V l~ H:r FIe A T ION L.U; rr IN G '* DATA FORMAT RECORD ** E,N'l'Rï BttOCKS 'TYPE-: 2 4 8 9 16 0 PATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API ID ORDER # LOG '1'1' 00 OIL crHMM 00 0 I 1) J Hili, i^':, 0 0 OIL OfU4 M 00 DIL MV 00 [¡If.,¡ ';AP;¡ Q P OIL LB 00 F r)C;I~1 øø fùC La 00 ~~DC I t\i 00 Foe G/C) on fOC G/C3 00 FOC PU 00 roc cpa 00 FOC CPS 00 CNt 00 C~L 00 CNLPU 00 ChL CPS 00 CNI~ ,CPS 00 CNL C~S 00 CN' "CPSOO C~L LB 00 CNL> GAPIOO ", CSG GAPI 00 CSG La 00 DE: P T S'Ltr ILD lbM Sp II ~l'ENS GR 'fENS ,,'ClLl HHOB 'DRAa i)PHI fà,c-,f'\C H'rv"" " f¡'~f)C , 'T'f.lRÄ RTNR NPHI k C 1\1 I]' RCFT. CfTC 'CNTC' 1'I:'tJ S' ,> - 1;'... ,~ GR,,""'" GR 1~Ef1iS ,,' , -, ** DATA ** , f)EÞT "sp ""'.,','," '7' r;;' N S" .,. r.. "'DPHI f<TNH 1'i22 oÓÖO Sf'LU ';"54;:',;106:3 ,,(;~ ,,'. , "~980.()D()O C:At~I' " ,,"'lS'. O:lij ONFDC '3.7021 ¡"PHI SlZ', ~"', ", 1'0 t 1 1 4 1 1 API. API TYPE CJ.;ASS 000 00 220 01 120 46 120 '*4 010 v1 ItO Q~ 635 21 Ji~f) , 0 1 635 21 280 01 350 02 356 01 a(}o 00 354 01 354 02 420 01 000 00 8(.)(1 "00 000 00 ono 00 0 ¡:) 0 00 Q(}Q 00 635 21 )10 01 310 01 635 21 RH>PR CODE 66 66 "l) 65 66 66 API ~'j'ILE: MOD NO. 0 0 0 0 0 0 0 0 0 0 0.0 0 0 0 0 () 0 00 0 0 0 Q 0 0 0 ,0 0 0 0 "0 ù 0 iO' ,0. 0 0 n 0 0 0 0 ,Q'"" 0 0 0' "',0 0' 0 ,(), ,() ENTRY () 1 60 .11N SIZE SPL 4 1 4 1 4 1 I 1 4 1 ,I 1 4 1 4 1 " 1 '* 1 4 1. 4 1" 4 1 4 '1 4 ì 4 t '* 1 41 " 1 41 .;} l' ,4 ,,"I 4 ' 1 4" ,,1 4 1 4.1 PAGE 4 1 () REPR PROCESS CODE (QCIIL1 6800000000000000 68,OQQQOOQIOQIOQO 6900000000000000 is 0 (,IOQO.OO<1QllllfJ 68 OOOOOOOO~OOOOO , II ,OD.;00"IIOIIII;I;8'0 6800000000000000 he 00000090000000 6800000000000000 68 OOOQOOOQQOOOOO 6800000000000000 68 00000000000800 6800000000000000 ~8 00000000000000 6S'OOOOÒOOOOOOOOO &9"" "0'000 00t) (.lOOOOO 0 6800000000000000 680000'OOQOQOOØOO 68 00000000000000 6.8 " OO(lOQ,Q.OUOOQ.,OOQ " 6800000000000000 is>OOOO'O.OOOQøotHlO,,, 69 OOOUOOOOOOOOOO 6.8 OOO,QO'OOtlQQOO 00" 68 00000000000000 68 0000000000'0000 ' " , , , ' , "'," , " , ' , ' "" , " ",;' ',',..,.'", ".""""",',"', ii", """"";;,..,",",' '.' 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I" Schlumberger ~.. * * * * * * * * * * * * * * * * * * UIP F'REíH)Í~;LCY BY A7.,I~OTH * * 0-90 DEGREE DIPS * * . . * * * * .* * * * * * * * * * PH ES F~, 'r 1\ T I U h ~O 60 E 1.20 150 5 210 240 ~'J 300 330 N 30 ..-.-.-..----. 37°,j- 3800 3 R 6 4 10 '2 3 3 6 3 1 3bOO- 39{)O .~ It) 16 B 1 2 .i 1 1 2 1 2 3900- 3997 .3 2.l 9 4 1 2 2 1 2 1 2 ( . L"". I / Schlumberger . ( ~:~~*~~=~~=**¡~~*************:~;¡*~i~=:~~~~,**************~~==:~~******** * DEPTH * DIP DIP * DEV DEV DIAM DIAM * QUAL * * * AZM * AZM 1-3 2-4 * * *****~******************************************************************' * * * TOP * * 3703.86 14.7 106, 41,9 15!, a,a 11.4 0 * * . * ßUTTtH'l * * 3997.79 4.9 96. 40.' 151. 8.3 9.6 A' * * **************.******************.*.************************"******'***' .,. ( L Schlu~berger f ( EtJ D II F' ¡,Sf - t.:. 1< S I U j\/ I) i,i '] " t (:' 5 1 n-pf\('-H7 ... 2n:O1:4i <' ( .(,
