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187-053
4110 4110 Kg-Ct. Regg, James B (DOA) From: Regg,James B (DOA) Sent: Monday,July 18, 2016 9:55 AM To: NSK Problem Well Supv Cc: Brooks, Phoebe L(DOA); Wallace, Chris D (DOA); DOA AOGCC Prudhoe Bay Subject: RE:Test forms for MIT KRU 3M- PAD and MIT KRU 3M- PAD non witnessed 07-14-16 Test result for initial attempt on KRU 3M-16 (PTD 1870530) should be "F" Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 C��ad8 JAN l A 907-793-1236 �4® CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, July 16, 2016 10:52 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Wallace, Chris D (DOA); DOA AOGCC Prudhoe Bay Subject: Test forms for MIT KRU 3M- PAD and MIT KRU 3M- PAD non witnessed 07-14-16 All- Attached are the witnessed and non-witnessed MIT forms for the tests that we performed on the 14th of July. Please let me know if you have any questions or concerns. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 V,/ LS TEAM conocips 1 • . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(cD.alaska.aov AOGCC.InspectorsAalaska.00v phoebe.brooksCrDalaska.gov chris.wallaceAalaska.gov OPERATOR: ConocoPhillips Alaska,Inc. FIELD/UNIT/PAD: Kuparuk/KRU/3M PAD �eI I 7(t�1I DATE: 07/14/16 OPERATOR REP: Miller/Riley AOGCC REP: Non-Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-07 Type Inj. N TVD 6,125 Tubing 1,800 1,800 1,800 1,800 Interval 4 P.T.D. 1870270 Type test P Test psi 1531.25 Casing 830 2,600 2,500 2,470 P/F P Notes: OA 25 25 25 25 Well 3M-15 Type Inj. N ND 6,149' Tubing 1,850 1,850 1,850 1,850 Interval 4 P.T.D. 1870520 Type test P Test psi 1537.25 Casing 1,025 2,610 2,500 2,490 P/F P Notes: OA 100 130 130 130 Well 3M-16 _ Type Inj. N ND 6,123' Tubing 25 200 250 Interval 4 (2P.T.D. 1870530 Type test P Test psi 1530.75 Casing 35 1,800 1,715 P/F --e......"Notes: 1st test-repressure due to almost 5%loss OA 0 0 0 Well 3M-16 Type Inj. N TVD -6,123'. Tubing 250 255 255 255- Interval 4 P.T.D. 1870530 Type test P - Test psi 1530.75 Casing 1,715• 1,810' -1,770 1,760 - P/F P Ir/v Notes: 2nd test repressure with 0.01 bbl diesel OA 0 0 0 0 Well 3M-20 Type Inj. N TVD _ 6,110' Tubing 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1870650 Type test_ P Test psi 1527.5 Casing 550 2,510 2,410 2,390 P/F P Notes: OA 310 410 400 400 Well 3M-21 _ Type Inj. N _ ND 6,118' Tubing 1,300 1,300 1,300 1,300 Interval 4 P.T.D. 1870660 Type test P Test psi 1529.5 Casing 740 2,000 1,930 1,910 P/F P Notes: OA 115 140 140 140 Well Type Inj. ND TubingInterval_ P.T.D. Type test Test psi ,Casing. P/F Notes: OA Well Type IN. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 3M-PAD non witnessed 07-14-16.xls • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, February 27, 2016 7:35 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: 3M-16 (PTD #187-053) Slow IA pressure build up report Attachments: 3M-16.pdf; 3M-16 365 Day TIO plot 27 Feb 2016.JPG Chris- Kuparuk injector 3M-16 (PTD#187-053) was originally reported in Jan of 2014 for a slow and intermittent IA pressure increase. Following the original reporting,the well was monitor for a 60 day period in which the IA pressure remained stable. The well returned to normal status and continued water injection with no IA pressure increase until early March 2015 at which time it was shut in for reservoir pressure management. Since the shut in date the IA has displayed an extremely slow increase in pressure, initially about—6 psi per day but down to—1 psi per day currently. It is CPAI's intentions to conduct a series of diagnostics to determine the cause of the IA pressure increase. The initial diagnostics will include tubing and inner casing pack off tests, an MIT-IA and an extended IA-DDT. Depending on the results of the initial testing a tubing plug may be set to allow for tubing pressure manipulation. Because the nature of the IA pressure increase is so small and requires an extended period of time to observe the leak the diagnostics may extend over a substantial amount of time. The well will remain shut in for the duration of the diagnostics and if at any point in time the diagnostic plan changes CPAI will notify the AOGCC with the proposed changes. Please let me know if you have any questions or disagree with the plan. Attached is a one year TIO plot and wellbore schematic. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 WELLS TEAM ConocoPhillips SCANNED MAR 1 1 2016 •ii @ ƒ $ _ 6 a73 ri) % $ coVIiz ( a 8 2 , /°°� . — co IP , , 1 � I { _ \ to-3 { CP e _$ -$ U 1/ ...1 �\ \ � » $ _ a - 5 A C . \ 0\k m _ C ) k o % -/ al ± 3 -\ -/ E ` E ; J J U RS \ lii .......,.. ? ir, „. \) m k E« . }\ j1.11 CD \\ {\ r §\ � / , : v. IN a. a.e F.SA - it- ! 5 . | ( Fel j k ` § § 2 ; § § ° k c w ° aa.Wa / k3j ^ ` ^ d 1VIEl~®RANDiJ1dI • State ®f Alaska • Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Tuesday, July 08, 2008 P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-16 FROM: Bob Noble KUPARUK RIV UNIT 3M-16 Petroleum Inspector Src: Inspector Reviewed. By: P.I. Suprv _ NON-CONFIDENTIAL Comm Well Name• KUPARUK RN UNIT 3M-lb IriSp Num: mitRCN080708054t39 Rel Insp Num: API Well Number: 50-029-21728-00-00 Permit Number: 187-053-0 Inspector Name: Bob Noble Inspection Date: 7/6/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-16 ' Type Inj. ' w i TVD ! 6123 ~ Iq j I Iao ~ z96o zaso zszo p T ~ Is7os3o TypeTest ' SPT ,Test psi 2960 /I pA ;. sIO 700 ~ ~o0 700 Interval 4YRTST p~F P ~ Tubing I zalo zalo zato zalo Notes: ~~ AUG ~ ~ 2D~8 Tuesday, July 08, 2008 Page l of 1 . ConocóP'hiiii ps . Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 18, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3M-16 (APD # 187-053) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3M-16. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, !,{ II!~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells " J MM/skad . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 187-0531 . 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21728-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 64' 3M-16 8. Property Designation: 10. Field/Pool(s): ADL 25512,' ALK 2553 Kuparuk River Field 1 Kuparuk Oil Pool . 11. Present Well Condition Summary: Total Depth measured 7955' . feet true vertical 6540' . feet Plugs (measured) Effective Depth measured 7837' feet Junk (measured) true vertical 6434' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SUR. CASING 4043' 9-5/8" 4080' 3430' PROD. CASING 7906' 7" 7941' 6526' Perforation depth: Measured depth: 7603'-7620', 7626'-7660' true vertical depth: 6224'-6239',6244'-6275' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7520' MD. RBDMS 8Ft MAY 3 ¡i 7006 Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7489' Cameo'TRDP-1A-SSA' SSSV= 1759' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: refer to attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation na na 690 Subsequent to operation na na 700 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead Sl22/ð~ Signature JA t JJ/ æ)(ß.v.. Phone Date Prenared bv Shamn AI/sun-Drake 263-4612 ----J Form 10-404 Revised 04/2004 k\.'b~ ~ Ç·Z,7'O&. S~ñ~ DATE 04/22/06 . . 3M-16 Well Events Summary Summary Pumped high pressure breakdown - 720 bbls 55 deg seawater at max rate of 6.25 bpm @ 4000 psi. ARCO Alaska, Inc.A . 3M-16 API: 500292172800 SSSV TVDe: Cameo'TRDP-1A-SSA' Annular Fluid: Last Taa: 7837 Rev Reason: New Sehem Elevations Grd 121 ft Casino Strino - CONDUCTOR Item 16.000 in CONDUCTOR Casino Strin~ - SURFACE Item 9.625 in SUR. CASING Casino Strino - PRODUCTION Item 7.000 in PROD. CASING Tubino Strino - TUBING Item I 2.875 in TUBING I Peñorations Interval Zone 7,612 - 7 612 A-2 7614 - 7,614 A-2 7616 - 7,616 A-2 7618-7618 A-2 7,626 - 7 660 A-1 7,603 - 7,620 A-2 Gas Lift MandrelsNalves Stn MD TVD Man Mfr Man Type 1 2515 2297 McMurray 27/8 X 1 FMHO 2 4466 3711 McMurrav 27/8 X 1 FMHO 3 5,414 4,414 MeMurrav 27/8 X 1 FMHO 4 5,842 4,738 MeMurrav 27/8 X 1 FMHO 5 6,269 5,079 McMurray 27/8 X 1 FMHO 6 6,665 5,402 MeMurrav 27/8 X 1 FMHO 7 7,061 5,743 MeMurrav 27/8 X 1 FMHO 8 7,424 6,065 Otis 27/8 X 1 1/2 LB Other (Dluas. eouiD., etc. - JEWELRY DeDth Tvpe 1,759 SSSV 7472 SBR 7 489 PKR 7 507 NO GO 7,519 SHEAR OUT 7,520 TUBING TAIL Top I 331 Kuparuk Well Tvpe: INJ Oria Completion: 6/14/87 LastW/O: Last TaQ Date: 7/4/97 Last Update: 3/18/98 I I I I I I Btm Btm Btm I Oriainal Ria RKB Jnts 115 Jnts 4,080 I Jnts 7,941 Len I Jnts I wt I 7 4871 I 6.50 I Status Feet Description Cameo'TRDP-1A-SSA' Cameo 'OEJ' Cameo 'HRP-1-SP' Cameo 'D' Nipple Cameo 34 17 SPF Date 1 8/15/87 1 8/15/87 1 8/15/87 1 8/15/87 4 8/15/87 4 7/5/97 Mfr Merla . PBTD: 7 955 ftKB TD: 7 955 ftKB Max Hole Anale: 45 dea @ 3600 Anale@TS: 27deQ~7590 Anale@TD: 26dea@7955 Grd I J-55 I TVDe 4" Csa Gun 4" Csa Gun 4" Csa Gun 4" Csa Gun 4" Csa Gun 2 1/8" EnerJet TVDe DV DV DV DV DV DV DV DV wt I 62.501 wt I 36.001 wt I 26.001 Latch BK-2 BK-2 BK-2 BK-2 BK-2 BK-2 BK-2 T-2 133ft Grd I Thd H-40 I Grd I J-55 I Grd I J-55 I Thd EUE 8RD AB MOD Comment SINGLE SHOT SINGLE SHOT SINGLE SHOT SINGLE SHOT Port 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 180 dea. DhasinQ TRO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Thd Thd Run 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 9/7/87 ID 2.310 2.347 2.347 2.250 2.441 2.441 3M-16 :~ SSSV TUBING PROD. CASING - Gas Lift- SUR. CASING - Gas Lift-' MandreVDummy VaW£¡ 2 Gas lift- MandreVDummy VaW£¡ 3 Gas lift - MandreVDummy VaW£¡ 4 Gas Lift- MandreVDummy VaW£¡ 5 Gas Lift- MandreVDummy VaW£¡ 6 Gas Lift MandreVDummy VaW£¡ 7 GasLift-a MandreVDummy VaW£¡ I 8 I \ SBR-\ PKR . NO GO SHEAR OUT TUBING TAil Perf Perf Perf r- µ "~~ t+ ~~ i Perf Perf ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 23, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 2.004 Subject: Report of Sundry Well Operations for 3M-16 (APD # 187-053) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3M-16. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )t{.)Ij~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NOV 2 9 2004 OR\G\NAL ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon D RepairWell D Alter Casing D Pull Tubing D Change Approved Program D Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 64' 1. Operations Performed: 8. Property Designation: ADL 25512, ALK 2553 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 7955' feet true vertical 6540' feet measured 7837' feet true vertical 6434' feet Length Size MD 80' 16" 115' 4043' 9-5/8" 4080' 7906' 7" 7941' Measured depth: 7603'-7620',7626'-7660' true vertical depth: 6224'-6239', 6244'-6275' 2004 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Stimulate [2] Other IJ Waiver D Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 187-0531 6. API Number: 50-029-21728-00 Exploratory D Service [2] 9. Well Name and Number: 3M-16 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3430' 6526' RBDMs 8Ft NOV J 9 2004 Tubing (size, grade, and measured depth) 2-7/8", J-55, 7520' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7489' Cameo 'TRDP-1 A-SSA' 1759' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7603'-7620., 7626'-7660' 13. Treatment descriptions including volumes used and final pressure: 716 bbls of slick seawater Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 1321 1321 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: oilD GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl n/a Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney ~'11~ Form 10-404 Revised 04/2004 Casinq Pressure Tubinq Pressure WDSPLD Title Kuparuk W ells Team Leader Phone ." Date II! 21)01 (- r', t,," \ ~ 1 1\ L Prepared bv Sharon Allsup-Drake 263-4612 j \¡.-( \ lJ\ \\~r\ ".,.,~ ~I Submit Original Only ) ARca Alaska, Inc.A ¡ 3M-16 Kuparuk Well Type: INJ Orig Completion: 6/14/87 Last W/O: Last Tag Date: 7/4/97 Last Update: 3/18/98 API: 500292172800 SSSV Type: Cameo'TRDP-1A-SSA' Annular Fluid: Last Tag: 7837 Rev Reason: New Sehem Elevations Grd 121ft Casing String - CONDUCTOR Item 16.000 in CONDUCTOR Casing String - SURFACE Item 9.625 in SUR. CASING Casing String - PRODUCTION Item 7.000 in PROD. CASING Tubing String - TUBING Item I Top I 2.875 in TUBING 33 Perforations Interval Zone 7,612 -7,612 A-2 7,614 - 7,614 A-2 7,616 -7,616 A-2 7,618 -7,618 A-2 7,626 - 7,660 A-1 7,603 - 7,620 A-2 Gas Lift MandrelsNalves Stn MD TVD Man Mfr Man Type 1 2,515 2,297 McMurray 27/8 X 1 FMHO 2 4,466 3,711 McMurray 2 7/8 X 1 FMHO 3 5,414 4.414 McMurray 27/8 X 1 FMHO 4 5,842 4,738 McMurray 27/8 X 1 FMHO 5 6,269 5,079 McMurray 2 7/8 X 1 FMHO 6 6,665 5,402 McMurray 2 7/8 X 1 FMHO 7 7,061 5,743 McMurray 27/8 X 1 FMHO 8 7.424 6,065 Otis 2 7/8 X 1 1/2 LB Other (plugs, equip., etc.) - JEWELRY Depth Type 1,759 SSSV 7.472 SBR 7,489 PKR 7.507 NO GO 7.519 SHEAR OUT 7,520 TUBING TAIL I Original Rig RKB 1151 Jnts Btm I Jnts 4,080 Btm Btm I Jnts 7,941 Len I Jnts I Wt I Grd I 7.487 6.50 J-55 Status Feet SPF Date 1 8/15/87 1 8/15/87 1 8/15/87 1 8/15/87 4 8/15/87 4 7/5/97 34 17 Mfr Merla Description Cameo'TRDP-1A-SSA' Cameo 'OEJ' Cameo 'HRP-1-SP' Cameo 'D' Nipple Cameo ) PBTD: 7,955 ftKB TD: 7,955 ftKB Max Hole Angle: 45 deg (ã>. 3600 Angle @ TS: 27 deg @ 7590 Angle @ TD: 26 deg @ 7955 133 ft Wt I Grd Thd 62.50 H-40 Wt I Grd Thd 36.00 J-55 Wt I Grd Thd 26.00 J-55 Thd EUE 8RD AB MOD Type 4" Csg Gun 4" Csg Gun 4" Csg Gun 4" Csg Gun 4" Csg Gun 2 1/8" EnerJet Type DV DV DV DV DV DV DV DV Latch BK-2 BK-2 BK-2 BK-2 BK-2 BK-2 BK-2 T-2 Comment SINGLE SHOT SINGLE SHOT SINGLE SHOT SINGLE SHOT 180 deg. phasing Port 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 TRO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Run 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 8/15/87 9/7/87 ID 2.310 2.347 2.347 2.250 2.441 2.441 SSSV TUBING PROD. CASING Gas Lift Mandrel/Dummy Valve 1 SUR. CASING Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Dummy Valve 3 G as Lift Mandrel/Dummy Valve 4 G as Lift Mandrel/Dummy Valve 5 G as Lift Mandrel/Dummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 G as Lift Mandrel/Dummy Valve 8 NO GO SHEAR OUT TUBING TAIL 3M-16 SBR PKR Perf Perf Perf Perf Perf ) 3M-16 Well Events Summary ) Date Summary 11/05/04 POOR BOY HPBD COMPLETED PUMPED 716 BBlS OF 55 DEGREE SLICK SEAWATER. MAX WHTP 4000 PSI AND MAX RATE 6 BPM. RETURNED WELL TO SW INJECTION POST BREAKDOWN. [HPBD] (;11 ) ) (t67... os'?' {~'7-oz9' / <¡¡(o-((p~ l'lf? -olf( (~"I- [(2 Page 1 of 2 Conoc~hillips Transluittal #383 Detail Date: 9/29/2004 To (External }Jarty): Email: Howard_Okland@admin.state.ak.us Fronl (1' AI Contact): Email: Sandra.D.Lemkc@conocophillips.com First Sandra Name: Last Lemke Name: First Namc: Howard Last Name: Oakland Phone Number: Company: Addrcss: Cily: ' Slalc: Zip Code: 11' Phone 265-6947 Number: Company: ConocoPhillips Alaska Address: 700 G Street, AT01486 City: Anchorage State: Ak Zip Code: 9951%CANNED JAN 0 6 2005 Sent Via: hand delivery TrallsluiUal Info: Tracking It: Justification: per 9/26/2004 request from Helen Warman, AOGCC Librarian Quantity 1 1 1 1 . Data Detail: Descl"ipUol1 Core Analysis report-KRU 30-12; Core Labs CL BP-3-1281; 8/9/1988 Core Analysis KRU 3M-09; 7/2111987; Core Labs Core Analysis Report; KR U 31-1-09; 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 Core Analysis Report- KRU 21'-09; Core Labs; 9/30/1988 Type paper / paper / paper / paper j paper ¡ paper / http://www.ak.ppco.com/transmiual/pri n Lasp ?transno=3 83 9/29/2004 ) Attachnlents: Filename: None Received By~~ h j} Î Sign~/f?~. ./tIM~ Approver: Signature: http://www.ak.ppco.com/transmi tta]/pIÌ ntasp ?transno=3 83 Filcsize: N/ A ). Date: 9J~ cf Date: Page 2 of2 Q/?Q/?OO4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-16 KUPARUK RIV UNIT 3M-16 TO: Jim Regg 'í7 r¿1/1 (04 P.I. Supervisor 1'\1r Src: Inspector Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIY UNIT 3M-16 API Well Number: 50-029-21728-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40803202347 Permit Number: 187-053-0 Inspection Date: 8/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-16 Type Inj. S TVD 6539 IA 600 2290 2150 2150 P.T. 1870530 TypeTest SPT Test psi 1537.25 OA 500 700 700 700 Interval 4YRTST P/F P Tubing 3150 3150 3150 3150 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL Wednesday, August 04, 2004 Page 1 of I MICROFILMED 9/218/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other ~ 2. Name of Operator ARCO .Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 904' FNL, 1578' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1256' FSL, 1737' FWL, Sec. 19, T13N, R9E, UM At effective depth 1319' FSL, 1838' FWL, Sec. 19, T13N, R9E, UM At total depth 1342' FSL, 1876' FWL, Sec. 19, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7955 feet 6539 feet 6. Datum elevation (DF or KB) RKB 64 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-16 9. Permit number/approval number 87-53 10. APl number so-029-21728-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7855 true vertical 6450 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 200 Sx CS II 1 15' 1 15' 1450 Sx AS Ill & 4080' 3430' 400 Sx Class G 300 Sx Class G & 7 9 41 ' 6 5 2 6' 175 Sx CS I 80' 16" 4043' 9-5/8" 7906' 7" measured 7603'-7620',7626'-7660' true vertical 6224'-6239',6244'-6275' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 7520' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 7489'; SSSV: Camco TRDP-1A-SSA @ 1759' 13. Stimulation or cement squeeze summary 14. Perforate 'A2' sand on 7/5/97. Intervals treated (measured) ORIGINAL Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ guns w/ DP charges at 4 SPF, fp was 2600 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1471 1200 2824 Subsequent to operation 0 0 1471 1200 2799 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service X 17. Si~lned./ ~ "~ ''~'' Form 10.40 /88 I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~.~_. ~-~(UPARUK RIVER UNIT ~ WELL SERVICE REPORT K1(3M-16(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-16 PERFORATE, PERF SUPPORT 0524972013.19 DATE DAILY WORK UNIT NUMBER 07/05/97'~ PERFORATE 2 1/8" ENERJET, 4 SPF, 180 DES PHASE 8293 DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~) Yes O No SWS-ELMORE ~ FIELD AFC# CC_.4f DAILY COST ACCUM COST ig ' ESTIMATE KAWWRK 230DS36ML $8,974 $24,696 Initial Tb.a Press Final Tbcl Press Initial Inner Ann Final Inner Ann ~ Initial Out I Outer Ann 2600 PSI 2600 PSI, 1300 PSI 1300 PSII 200 PSII 200 PSI DAILY SUMMARY PERFORATED F/7603- 7620' ELM W/2-1/8" EJ DP PHASED 180 DEG (4SPF TOTAL/. TIME 08:30 10:00 12:45 14:45 15:15 16:30 LOG ENTRY MIRU SWS (ELMORE & CREW). SI WELL @ WING. TGSM - PERFORATING SAFETY & JOB OVERVIEW. MU GUN ASSEMBLY #1 (17'- 2-1/8" EJ DP ORIENTED 90 DEG RIGHT/MPD/CCL/WT/ TL-30'. PT TO 3000 PSI. RIH & TIE IN TO 8/4/87 GEARHART CBT. PERFORATE F/7603 - 7620' ELM W/2-1/8" EJ DP @ 2 SPF ORIENTED 90 DEG RIGHT. LOG UP TO 7400' ELM. POOH. AT SUPS-.~1.,- ~ t' ' c .i,~Tq FIRED. MU GUN ASSEMBLY #2 (SAME AS BEFOR~' ""' '' TM ¢': o,~ -~, ~ .... -: ~ ,!~ ,~..~ 90 DEG LEFT). PT & RIH. TIE IN & PERFORATE F/7603 - 7620' ELM W/SAME GUNS AS BEFORE ORIENTED 90 DEG LEFT. LOG UP TO 7450' ELM. POOH. AT SURFACE. ALL SHOTS FIRED. BEGIN RD. OFF LOCATION. TURN OVER TO PRODUCTION FOR INJECTION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $186.00 APO $350.00 $5,850.00 DOWELL $0.00 $6,018.00 HALLIBURTON $0.00 $1,904.00 LITTLE RED $0.00 $2,115.00 SCHLUMBERGER $8,624.00 $8,624.00 TOTAL FIELD ESTIMATE $8,974.00 $24,697.00 '1'. Type of Request: ' ...-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate m Plugging Perforate Pull tubing .. Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address 5. Type of Well: P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic Service 4. Location of well at surface 904' FNL, 1578' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1256' FSL, 1737' FWL, Sec. 19, T13N, R9E, UM At effective depth 1278' FSL, 1772' FWL, Sec. 19, T13N, R9E, UM At total depth 1342' FSL, 1876' FWL, Sec. 19, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7955' feet 6 5 3 9' feet Plugs (measured) 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-16 9. Permit number/approval number 8-98 10. APl number 5o-029-21 728 11, Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7855' true vertical 6450' feet Junk (measured) feet Casing Length Structural Conductor 1 1 5' Surface 4 0 8 0' Intermediate Production 7 9 41 ' Liner Perforation depth: measured 7612', 7614', true vertical 6232', 6234', Size Cemented Measured depth True vertical depth 1 6" 200 Sx CS II 1 1 5' 1 1 5' 9 5/8" 1450 Sx AS III & 4080' 3429' 400 Sx Class "G" 7" 300 Sx Class "G" 7 9 41 ' 6 5 2 8' 175 Sx CS I 7616', 7618', 7626'-7660' MD 6235', 6237', 6244'-6275' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ib/ft, EUE, IPC 7520' MD Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA 1759', Packer: Camco HRP-1-SP 7489' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (producing) ,. Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 1200 1400 - 0 - 1600 1 90 - 0 - - 0 - 3000 1000 1780 16. Status of well classification as: Water Injector .. X Oil __ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Signed Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, In, Subsidiary of Atlantic Richfield Compa~,,...~. V WELL SERVICE REPORT WELL qONTRACTOR / REMARKS IPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME IDAYS I DATE / ~-~1-~8 2/4) 2./0 2.,¢.~'o I-~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK i Signed knots ~ ~"". /~c~'~ ARCO Ala Inc. Date Time_ Drillsite Morning Report CPF 3 ! Siatus i Production Well Status ~ Gas Lift Status I Shut-In Well P.T. or TP Cl~oke Temp Last H2S .CSG PressUre Psi Gas [ Inj. Rate # SI Zone PSI Bean °F WC% PPM 7" 10" Temp i MeterTotalt MSCFD Hrs Reason I ~ A 19o )?6 l:Z ~TZ-' /~o 7 !~o ~. vao 't 17 /~ 7 ;oa Total Status . .Injection Well Status i Shut-In Well Gl, PW Inject. Pressure PSI Temp Choke CSG Pressure PSI Meter Injection Rate # I orSW Zone Allowable Actual °F Bean 7" 10" Total BBLS/Day MMSCFD Hrs. Reason Total SWI Total ~ PWI Total Drillsite Coil Temperature °F Coil Pressure PSI Bath Blanket Heater Prod Test prOd Test Temp, Gas PSI Run Time , out Chemicals Type Gal/Day / Headers Production Water Injection Gas Injection Gas Lift Drain Pressure .~ / ~/4'~ 0 l-e: Temperature. 9-16: , , [ Tank: Meoh/Diesel Level Temp. Comments Operater!s Signature/~_~x~4. ~ 3A.024(05/27/87) ARCO Alaska, Inc. August 8, 1988 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3M-16 Core Description Dear Mr. Chatterton' Enclosed is a copy of the 3M-16 Core Description to include with the Well Completion Report. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG'hf Enclosures cc' 3M-16 Well File GRU14/O20h ARCO ALASKA, INC. KRU 3M-16 CORE DESCRIPTION SEC. 25, T13N, R8E, UMIAT CORE #1 7580'-7586.2' 7586.2'-7598.5' 7598.5'-7614.5' CORE #2 7614.5'-7676.3' CORE#3 7676.3'-7688' 7688'-7691.2' Shale, dark grey to black, slightly silty, very hard. Sandstone, medium grey, fine to coarse, pebbly near top and base of interval. Bioturbated, glauconitic, locally siderite cemented, some vertical fractures. Interbedded very fine-grained sandstone, siltstone and shale. Sandstone oil stained. Siltstone and shale medium to dark grey. Lenticular to wavy bedding becoming hummocky near base. Sandstone quartzose with fair to good porosity; well indurated. Same as above, lenticular, wavy, flaser, and hummocky bedding. Lenticular to wavy bedded, very fine-grained sandstone; well indurated, sparse ankerite cement. Shale, dark grey, some siltstone lenses, very hard. ARCO Alaska, Inc. Post Office L~..~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 SAMPLE TRANSMITTAL · hand-carried SHIPPED TO' · State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr.'~ Anchorage, Ak. 99501 Attn: John Boyle DATE' 5-12- 88 OPERATOR: ARCO NAME- see below S~.%~fPLE TYPE' core chips, plug ends NUMBER OF BOXES· 63 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 KRU 2T-9; I box KRU 3J-9:12 boxes ,a~'.r'~P. 05- 2150.8 --~ 6320 - 6393 "(~'250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are available)6459.- 6503 6507 - 6545 KRU 3H-9:9 boxes 6868 - 6908 6911 - 6958 6971 - 7058 KRU 3H-11:2 boxes 3941 - 3954 3970 -"3974 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 4061 - 4081 6548 -6570 KRU 3K-9:16 boxes 3365.2 - 3501.3 6967 - 7009 7027 - 7060 7060 - 7099 7102 - 7174 7199 - 7243 · KRU 3M-9:5 boxes 6531 - 6577.0 6579 - 6618 6637 - 6650 -KRU 7580 - 7614 76.17 - 7690 SHIPPED BY' _ ..... , BayView Facility Coordinator UPON RECEIPT OF T~ESE SAMPLES, PLEASE-XNOTE ANY DISCREPANCIES AND ~iaIL A SIGNED. COPY 'OF THIS FORM TO' ARCO ALASKa, INC. BOX 100360 P.O. ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab - -. RECEIVED BY' DAT~.' ~/ff~~~~ ARCO Alaska, Inc. is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, Inc. ~ Post Office Bo~,..~J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 17, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Commi s s i on Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Well Action Anticipated Start Date 2G-9 Fracture February, 1988 2D-16 Perforate & Stimulate March 4, 1988 2F-10 Perforate & Stimulate March, 1988 3M-21 Perforate & Stimulate February, 1988 2E-11 Stimulate February, 1988 2H-15 Perforate February, 1988 2H-13 Perforate February, 1988 3M-1 Perforate & Stimulate February, 1988 3M-2 Conversion February, 1988 3M-10 Conversion February, 1988 3M-15 Conversion February, 1988 3M-16 Conversion February, 1988 3J-4 Perforate March, 1988 3J-9 Perforate March, 1988 3J-13 Perforate March, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:pg:0154 Attachments cc: File KOE1.4-9 ARCO Alaska, Inc, is a Subsidiary ol AllantlcRichfieldCompany STATE OF ALASKA ALASi~,.cOIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension FI Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 4. Location of well at surface 99510 904' FNL, 1578' FEL, Sec. 25 T13N R8E tiM At top of productive interval ' ' ' 1256' FSL, 1737' FWL, Sec. 19, T13N, RgE, UM At effective depth 1278' FSL, :[772' FWL, Sec. 19, T13N, RgE, UM At total depth 1342' FSL, 1876' FWL, Sec.19; T13N, R9E: tiM 11. Present well condition summary Total depth: measured 7955' ND feet true vertical6539, TVD feet 5. Datum elevation (DF or KB) RKB 63 6. Unit or Property name Ku~aruk RivPr Unit , 7. Well number 3M-16 8, Permit number Permit #87-53 9, APl number 50-- 029-2172800 10. Pool KIJparuk RivPr Ili l Pnnl Plugs (measuredNone feet Effective depth: measured 7855' MD feet true vertical feet 6450' TVD Casing Structural Conductor Surface X X X)tm:l;eX~Rcti~tte Production xxx~_~q~xxxx Perforation depth: Junk (measured) None Length Size Cemented Measured depth 115' 16" 200 SX CSII 115' MD 4080' 9-5/8" 1450 SX ASIII 4080' MD & 400 SX Class G 7941' 7" 300 SX Class G 7941' MD & 175 SX CSI measured 7612' 7614' 76t6' 7618' 7626'-7660' MD true vertical6232, 6234' 6235' 6237' 6244'-6275' TVD Tubing (size, grade and measured depth) 2-7/8", 6.5 lb/ft, EUE, IPC, 7520' MD S.~j~/k.ers and SSSV (type and measured dept Camco TRDP-1A-SSA, 1759'. h~acker: Camco HRP-1-SP, 7489' True Vertical depth 115' TVD 3429' TVB 6528' TVD 12.Attachments Description summary of proposal [] Convert well to water injection. 13. Estimated date for commencing operation Februar~v, 1988 Detailed operations program [] BOP sketch [] 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 //~~ /~ ...~,..~/~/_~~ Title Sr. 0peratiofls Erlgifleer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI t~! :,' ~'.,.;- -.: "' '~: "': '~ ' '~':::::' Approved Copy Date2./17/88 NO. O ~) Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Returned by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicatu ~// ..--~ STATEOFALASKA ,~ ALASKA 0IL AND GAS CONSERVATION COI~IMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LO ,. 1. Status of Well Classification of Service Well OIL [~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ....... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-5:3 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510-0:360 50- 029-21728 '~,. Location of well at surface 9. Unit or Lease Name 904' FNL, 1578' FEL, Sec.25, TI:3N, RaE, UM Kuparuk River Unit At Top Producing Interval 10'. Well Number 1256' FSL, 17:37' FWL, Sec.19, TI:3N, R9E, UM :3M-16 At Total Depth 11. Field and Pool 1:342' FSL, 1876' FWL, Sec.19, TI:3N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 64'I ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/05/87 06/1 2/87 10/06/87* N/A feet MSL 1 17. Total Depth (MD+TVD) 18'.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where sSSV set 21. Thickness of Permafrost 7955'MD, 65:39'TVD 7855'MD, 6450'TVD YES'ii NO []I 1759' feet MD 1600' (approx) 22. Type Electric or Other Logs Run " DIL/GR/FDC/CNL, DIL/SFL/SP, Cal, FMS, CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE'WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i. '16" 62'.5# H-40 Surf' 115, 24,, 200 sx CS II 9-5/8" :36.0# J-55 Surf 4080' 12-1/4" 1450 sx AS III & 400 s:~ Class G , 7" 26.0# J-55 Surf 7941' 8-1/2" :300 sx Class G & 175 s;( CS 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/1 spf, 120° phasing 2-7/8" 7520' 7489' 761 2 ' MD 62:32 ' TVD ,, 7614 'MD 62:34 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7616 'MD 62:35 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7618'MD 62:37'TVD See attached Addenlum~ dated 10/21/877 ... Perforated w/4 spf, 120° phasing for fracture da~a. 7626'-7660'MD 6244 '-6275'TVD 27. N/A PRODUCTION TEST , , Date First Production J Method of Operation (Flowing, gas lift, etc.) I ,, ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ .......... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core description to be submitted when received. NOV 1 6 t~l A~aska 0il & Gas Cons. C0mmissi0;~ Anchorag~ *Note: Drilled RR 6/14/87. Perforated well & ran tubing 8/15/87. Fractured well 10/6/87. , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDiLCC:3/100:DAN I /'Y/' h-~ 29., ~ 30. ',.~j'- .. - GEOLOGIC MARINERS FORMATION TESTS " .. · . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,, _ Top Kuparuk C 7589t 6212~ N/A Base Kuparuk C 7601~ 6222~ Top Kuparuk A 7601 ~ 6222~ Base Kuparuk A 7686~ 6298t 31. LIST OF ATTACHMENTS Addendum (dated 10/21/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , ,'~L~')L--' . _L~I~(_? Title Associ ate Engi neet Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6/26/87 8/05/87 10/06/87 3M-16 Arctic Pak well w/175 sx CS I & 60 bbls Arctic Pak. Rn JB to 7870'. Rn CBL/CCL/GR f/7800'-5600'. Rn gyro f/ 7800'-surf. , '~7618' & Frac Kuparuk A sand perfs 7612~:.7614' 7616, 7626'-7660' in nine stages per procedure dated 9/28/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 B?M, 4300 psi Stage 2: 450 bbls gelled diesel @ 20 BPM, 4300 psi Stage 3: 40 bbls gelled diesel 2 ppg 20/40 sand @ 20 BPM, 4400 psi Stage 4: 70 bbls gelled diesel 4 ppg 20/40 sand @ 20 BPM, 4700 psi Stage 5: 70 bbls gelled diesel 6 ppg 20/40 sand @ 20 BPM, 4875 psi Stage 6: 70 bbls gelled diesel 7 ppg 20/40 sand @ 20 BPM Stage 7: 40 bbls gelled diesel 8 ppg 20/40 sand @ 20 BPM, 4880 psi Stage 8: 25 bbls gelled diesel 10 ppg 20/40 sand @ 20 BPM, 5461 psi Stage 9: 40 bbls gelled diesel 12 ppg 20/40 sand @ 20 BPM, 6139 psi. Screened out 4 bbls short of total displacement, 8000 psi. Fluid to Recover: Sand in Zone: Sand in Casing: Avg Pressure: 790 bbls 60,097# 1730# 4900 psi · ~rilling ~upervl=-so~ I~ate' August 12, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70050 Well: 3M-16 Field: Kuparuk Survey Date: August 4, 1987~ Operator: T. McGuire 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. Ken Broussard District Manager Enclosure NL Sperry. Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARL. u ALASKA, INC. :-~M-! 6 KLIPARLIK FIELD · =,F ERF~¥-.-,,.IN WE!_I._ ~--;! IRVEYING C:OMF'ANY F'AGE :1 .... : :: ......... :<"ii"'<!?<':':~??~'~ ..:~. .~...'<. " ,2, ~.'- ~.~'~i~!~i~:~i~i:~:::~?:?:~:~::'!'il- ~:'- ......... :":i::~,~: . ~:. .' .. :. :.:::: ..~%s ' "'%::q~$~. '~:"- ~ ....... .:~'-~ ..... · ....... .,:.~....-.-~,.- · .~..x-.~,.-~.x.:.~..;.~.,~.:.x,.,,x~.-.: ..,~,..~<:~.>:~::. :>:<,.~... ~..>...x.<:. x~+:x.:~-..~.~.~ ...... .: AUGLP. ST 7, 1987 dOB NUMBER AK-BO-70050 ALASKA KELLY BUSHING ELEV. '= 64.(:)(_-) FT. OPERATOR-MCGLI I RE -. VERT I C AL SEC T I ,-iN CAL Ct_lg~:~:.~ii!~[ClNO CLOSURE ...... ':":'?: ':':?:~:~':"':'~:~ J~'~'::~'~:~:'~:: :~:~:~::~:~~:~:~?:~ .......... ~:~'~:~:~:'~'?'"~ ..................... ~'~'~:: ' ............. 100 100.00 :36.00 ~ '"' . :::::::::::::::::::::: ::.:.<<>::~>:>:<:<.::. - .:.. :::>m~>x<::>.<<<..<.>>:::>..:,<.......>............... ............ 200 2C)(') ...... 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'~:'~::; 6425 9F.: 26 13 N ~::;:::. F:c) E 0,02 223:::. 04 N :74:~:::. :::7 F 4F~'75. ¢;:,'7 ...... ~ .... " ,, T:., ~ ........ :~ -7, .......... :~ .............................................................................. ~ ......... ~ ...................................... ~ ......... ~"'~ ......... ~ ............... ~?' ..................................... zz,,~ ............................................... '-~' ¢~t I~' I;:7 .. --- -.. .. ~ ..... ~ .~ ......, /; ........... c, ,~ -':,, ,::) 2'?:' A4'Tt: ';'9 2A 12 N 58.80 E O. 04 2245.6:? N 345f~. ~_(;, ~ ..................~...~ ,~..:~{,..?.~. H()R I Z Or, t'!"?~L D i SF'LACEMENT = 4119.96 FEET AT NUR::;[H.: ~,~::~:.~,~~.~ ~:~:.~,~::~:,~::[:~::H~: ::~D:~ ~:'.~.~'~:7,:.:.~:~ .... : ::.:.~'.:.: ': ....... · ................... :~::.~?:~:¢~;;:~ ':?~:;t'~'t ?:: ?~:~ ~] ~': ~:~:.~:~?~ ~ ~:?~ ~,~~:~~~ ~*~*~. ~:: ~: ~'~: ~:~ ~:~: ~'. ~:~* ~:~: ~:::' ::~.~:' *:::~.: ~'~':':'-':'~:: .:. · SF'ERRY-SLIN WELL. SURVEYING C:OMPANY F'AGE 4~ .................... ~:- .'.--:--:.:- .:~.,::~:::,:::...:.::..: -:---.::-:,::-: .... ----: -:-:.: ......... " ..... :- -:--::--~: ::: .-::.~ 5:~..-x,:.::::~.., ~,,~:: ~ - :..: -. ": ..........: :::?:: ::'::::::::::::::::::::::::=:::::::::::::: ::': ::.':.~ ....... :':' ANF:_.NC;tRAt_~E ...... ~~' :: '::~::'' ''~' "' ::~:''' ' '~ .... ",'" "'i ........ ~ ..................................... ~.~ ,.,;., -0:,~ ~ ARCO ALASKA, I NC. ..: ~:~::~..~':??~i~::i!~ii~:: ~!~i!!i~!~i!ii~OT" ..... · ': ,:. :~.~s:~Kx?;: .-,- ...... ~:~ ' ,'*~". ........ ~'" ~e~'..'~. ~'" ....... ~"-~;,9::' KLIPARLIK FIELD ALIGUST 7, 1987 ,JOB NUMBER AK-BO-70050 ALASKA KELLY BUSHING EL~V. = ~ ..,:.~ ..... O~RATL]R~MCFiU I RE ~.~ :?.:~.:.~.~:~:~:~::?:.::. ,-.:.:~?~.~:~,3,~.: ..,.-.:~ .: : ... · ................ ~ ~. ~,~a ~. ,:..~:~ ~-,~ ~ ~ ~a~ ~ · -~ .............................. . :~.::.:?':~.~:::-% ~: :: ::~: :-:~c~;~::~:: , :. :: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....... ZNT~RP:OL~B::~LUES FOR EVEN ':""" ............ ":'~':~??:"?:'~ ................ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ~:~:~:~f~?~~:~?~'::::?'~:::::'?:::~'?" ' ' ~"~ ~'~ ...... ': ......................... . ........ ..::¥..:..:~:.:¥: ................ i 000-'FEE~:?.~:::B "9~ :~~~:~:~:~:~:~:-~.:A~~:~:'~':~::~?~ ................'::::? ............. -?::??~~ ~:~:~:::: ........................ TRL.IE SLIB-SE~ TOTAL ........................................................................DEF'TH PEP'I"H J"";~; ...................................................... DEF'TH J ............................................................................................................................................... NORTH/SOUTH EnST/WEST ~ .................................................................................................................................................. DIFFERENCE CORRECTION ... ::.:, :~:::~:~:~:~:~:~::::::::~:::~:::~:~::~:::~:;:~:::~:~:]:::``~:~:~::~::~:~:`:::~:~:~:::~:~:::~:~:s~:~:::~:~:::~:}:~:::~:~:~:~:~:::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:::~::::~:::~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:?~:~:~:~:~:~:~:~:~:::~:::~:~:~:~:~:~:~:~:~:~:~:~:~:~`~:~:~:~:~:~:~:::~:~:~:::~:~:~::~:`:~:::::::~:~: .:.,:::h:,::~,:::. :: - ....... . . ~.. 9 .............................................. ~ ............................................................... ~ .......... ~ .......... · ............................. ::::::::::::::::::::: ...... , ?' 2000 1'~;'08.5;3 1844.5:3 26:3.09 N :344.9:3 E 91.47 :~A. 21 .............. :30 C)0 '"" :" z._, 7 1 ..... ~ ~ ~ 40f')~3 :':',:':~'71 '?4 3::~()7 '~)~ ....................................... ;~';~']~"~'"~i'(fN ].4'?:3 80 E ~'-":' 06 279 '-'"" .............. , =,~. . ......... """'""' ~ ~:.=:o, y: N ,..~,_,.:,. ~ 7 e, :. 7.79 N '2Z-,22, 58: E ~:~: ~::~ :: .:::i:~t~:~::'t~:.O:'?:t~:::?~?~?::~:~:~:~.::~?:' .:t:,,~o ~ ~,. · ...... 7000 s/-,~:9 '~'~; ~$ "'"~= '::'~ '"'" c 29 ::'::::?:~?:':~:;::..::'.' :~::' ::.~"'~:~' '"~ ....... =,z....., ..... ~u.~ ....... N 3091'. I5 E .~::~::.: ~.!::~:.!:0.,::~.~::.:.:::::.:.:~.::~::.::::~:.~::.:::::. :. :.I7,~.,:~,~, ............... THEE f,".AL. CI...IL..AT ]: (}N F:'ROCEi:F..dJRE$ ARE=. BASED L")N ]"HE I...i.'-:;E OF THREE DIMEN:=:IONAL RADIUS OF C:LIRVATUF~E METHOD.,_ .......................... ::: ..:.:'. ~:: ,:::' ~:. :..::: :::::::::::::::::::::: ]..: ::::::' .:.. :: :.:,::~:~ ~- :::,:~ :]: ~: )~::::~::::: ~ ~?:~?:~?:?:~::::~?.~ :::: ~::~::~::~ ?: ~:? ~~~~ ~J~ ~ ~ ~ ~ ~ ~ ~5~ :,~:.~::~:: ~?:~:: ~ ?: ~:: ~?:~?: :?~::: ??: ~:::?: · :. , :::.. :, :: .. · .: ...,:.,:,:,.:.-.,. :,,-: :-:,:..,:.:,:.;,:-:.::..: :,~ ~:::::::~.:,:,.~:5::5,~:.:::::::~:::~ ss,~.-:., ,.,':~:. ::x:.'~. :,, :.x5 ....... ~,.~, ~x~., .: ..,...x.~:.~x ~.:..,~..:< ~:.:.:.:~.:.:.:.:.:.:.,:..~.:.x.:,:.:.z.:.:.:.:,:.~:,:.. :.~:.:.:.,~:,:,:,:,:.: ::::::::::::::::::::::: ::: :,::,,:...:.:-.:-.: :.,...:.:.: :., ::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::': ::~ ~'~:.':~.::...: AROq ALAF~KA~ INC. 3M- 16 i<LIF'ARUK FIELr'~ ,z*.,, ~-...'" A L ~'~-:,I'...R SF'ERRY-:"_-':UN WELL '.:;URVEYING COMPANY F'AGE ~IJGUST 7, t'~87 dOB NUMBER ~E-BO-70050 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR-MCGU I RE . ·; ' ~,~'q: · ~ - ~ ]"RLIE 'SLIB-SE~ TOTAL. MEASURED VER ]' I E:AL ' ...... '~"ER'Y"~"i]~'AE .................. ~'~ET~'~'~'~:~'i:iI:~:'A'F~ ........... i:~'OORD INA TES MD-TVD VERT I CAL O 0. OO -A4_ . OO. . ·. ':'. "::'' O. (")(').. O., :' :::::::::::::::::::::::::::::::::::::::::::::::: u ~ . . : . , ._1 ..... . ............ . ;,. ,, ;, ,, .: . . . ,, .~,......~. ..... ; .... : ,...:-: ...... .:¢.: -: ...... .:..,: · .,..., ..,....:: , .::..-:..:.....-: ::.::...: .....: ...... . , · :::.: :L':. 164 164 O0 ~00 O0 O.~c, S 0.46 W 0.00 0.00 .................................... :'::/-,4- .... ::: ~, 4'; C)'(i ................... :.~: Ch;~";"'~5'i;~ ............................................................. 2 :'"'":~'0._,'= .................................................. S 0 ; ................................................................................................................................................................ 5A 4 564.00 500. 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O0 ,:~9 ~: ,:, N I 15 '- '-' ( 149("). .. 1464.00 1400.0(). 114.72 N 14'-',:,.68 E '"' ~" ' ": ~. ~ :' :" "~:":' ':':'" .~ ~"'":~::';'::":~'~ '~"~ ::'F:;~:¥'"'"~:':'%~'¢~ ,' ' ~.~]~}~.~:~.~'~:~'~.~]:~.~.~.~.~'~;.::~,~':;':;~:~':~:~.:.:~:...':'::'~??.F~'~'::::~:??.::.~':':.~:::~.::~(~ ' ·: · : : ',: '. · :::. :.: '....: :':,.x':.,.: .:": .... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .?:.,: .:::'..,,:...::~:~:u,-:::::: :':::':., ...,: :: q: ::~.::: ?:,::::?~::.::::.]:~:::~....~ .'" .: ~:~,'~, _ . : - - · - :', ::: =================================== :;':::::~.. ;.':~ ..::u?:~.~:. ~.""~,i,;' i~.:: ::::::~.:~: : ... :. ~. :. '":;~?:'u?'u~¢~.~'"""~:":~¢"~ ~ , :'.:' : ~: :::: :::::::::::::::::::::::::::::::: .~.:~:~:¥:::~:u ~:'::uu.~:u ::::::: .. ::: 'h:: ': :.. .:n ~,?: ::::: ::~::~u~:~n~¢ ~¢~:~:u~.n~::~-~n~:u~::~:~: u:.:::::n::::~:::u: ~ ::~::~....:~: .::~':::~:~::~:,~4~ ..... ...... 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AUF.:Li::;T 7., 1'.-?A7 ,...lOB NUMBER AK-BO-70050 ALASKA KELLY BUSHING ELEV =_ 64.00_FT OPERATOR-MC(..~LI I RE TRUE L=;LIB-'.:;E A TOTAL .......... ~'"!--i ~'"";"~ ....................... , -' '~';'~'": ":! ~ .................. :"!~;;~'"'" ..... =~ ............................ :':"~'"'::-?::,' ........ ~: ............ ;iii ~; ........... =:~'"-'": .................................. 2<'~/-,'.-? 1'P64 O0 1900, OO: :: ;:': 287, 02 N ..¢/~., 21 '-?.._::: ';.'-' c} ,-':, 4 00 2000 ,, 00 :3:34- ':: 9 N 445 ...... :::'-? E 1._',4'=' 6'-:' ..'- :.~'-"- '~'=' ........ ~ I~ -... · ,,.. ,~1 ........................... ......................................... :~!:-~ /::,:' ';..,~:,4. ~ 'hc~ ......... :~:~i-i?i':]~i'i:'-i' ........................................ 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ARC:O ALASI<A I NC. : ........... ~:" '? ........ **'~ ............ ~*'::::'~:'*'::~*~':* ................ ' .................... x?:¢:.:'.-:'~' KI_iF'~RI_IK F ZELD At..IC4LIST 7, 1987 ,_lOB NLIH~ER ~K-BO-7c)050 ............. ====================== .:'. ': ============================================================================================================================== ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: OF'ERATOR-MCGU I RE ,: :.,. 6?. ~: ;~ ::: :':::~-:,..:,:~:u<::::~ :-~:::~:: ~;:::::::?;?.:::::.?:.':::?.:~:::::?~:::;;:. ';:~:~::'::~::T?:;~ ':i~:??:%~4~4%%~:.;~;?~:~ . .: , ~. :-: ........ :..~ ........ ~: ........ : ............ ::~?;~::~ ............ ..:.: :... ::.;..;:~.;:.l~ ,: :' x::::.:.x,:,.: · -;'...:::::l :::::::::::::::::::::::::::::::::::::::::::::::::: ,:%:::;::: .-x:.: :::::::::, :.:: ::..: ::::,::::.: ::.._, TRLIE SUB'SEA 'FnT~:~L_ ' MEASURED VERT i"' c-_.~,,._." ' "VER'Ti ~'~[~ ........ 'R'EC: Y';~NOULAR "C:OoR[, i'~A"y'~'~ ...................... '~iz'fV~ ................................ ~'~'~'Y~"i~:~L- ................................................................................................... ................. DEPTH NORTH/SOUTH EAST/WEST D I FFERENC:E CORRECT I ON ................... ............... ' ( ......... :"' ?:::~:-":' :'" :' :':::::',:' :':::?": :::" "'-" :'" ':" '" :; ':':' ':' ":::::?::s<E :?; :.? :::: :::,?; ::~:;.::'::: ::::{::3;::}~ .... '.:": ': ":' ........ ,:.: ~:':: :::;:;;:;::~.,.~?:;;:::;~:::;::?,::::.::". :.: :: :.:c. ::-::;::: ;:. ..: ; .... ;... ... 45:39 :3764.00 :3700. O0 1174.~:z N 18 ~ o ~ = ...... · ..:...:: .......... ' · ................ :~ .: ........ · .......... · - '- i c,. 7=:. E.;:;:' ; ~::.:: 7~:.,~.~!;~:~::~::~:~:~.'-.. o :~ ~,. ~= .E.:::~..:: ::..: '.::8 ~.!:.:,::~.~0.:::::; ===================== ':':. '.'.:; ::.',.a:$;,.,:::7,~. :::.========================================== :: :::::~...:::: · ~ o4o. 5 t ~'~ 4:E', 12 ................. ":¢,:>/~ a. OC, 3'?00 O0 ~ 270 72 N t 975 ._ 4 E '-' '-' 50:E:2 4164.0() 4100.C)0 ~366.34 N 2~29.90 E 9t:E:.65 :34.5:3 ................. ~i'::' ~"'6;'" 4;2/-,4 "i:~5' ' ' 42c)o 00 1414.04 N '?'='o4.20 ~::::::.:~:?X::: '::' .::::~5'~. .... ~.; ::':':; · .. ~ ..... ~ ....... ~ ~. ~ . . ~ . -:~.~ ~::: ~.:.~ .;:.. ;:::. ~:: ::~; ~.:;. ;. : y:.~:~ ~. ~*~ . ~]'=:4:=: 4364 or) 4300 O0 1462 07 N °27o.88 E 98~;'~ .:: .::.:.:.::. ~ ~"~ ~ ..... , .: . :,..,.:.> :...: <:..: .::. :.: .... : ... .... 4,=,1 4464 c)o 440o O0 t510./32 N 2348, ........ 10::I:~7.;'07: ':: :39 .................. ?":;T'::': .............. ;:~: d. 4-'-'?:Y;~" 450 () c> o 1.*'-', ~-.-,,'':~ :37 N 2420 90 E 1049. ~:=,._, ~ :32 ~':=' ............................... . ..._ ..=, ~,. ~: ,=, · ,,'-,/.', Z]- ';T d:, 4 . OC) z~'7()':), OC) - z. ,:~, ,:,.':, , '=,,~ c ' o '" '~= ...... 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L)L)='-= ........................................... 1,=,;;;;'~ ~'; ......... e,~,;'-~: .................................... N :=;';~':=;zdzT. ............. LI~= ....... z=--.~. ......... lz~.~'=-~-;~":30 ...................................... ........... ~ - ~ · ~ :....:: :..... ::~::.:~:y:~:: ':"'.:'~:.;~;';~.':.::~::~: .:.'::.,-:..:. :..-:::.:.7:: .:~::..-..:~:<..:-~:::.-~:~:~?:~. ":"::::.':: ".: 5464.00 : ::;:. :::..:::. %;.:.:::~:~;~;:..~:~ ':. ' ': :...: :': :..:...:...': .' .: ': :.: ·: · :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~' :~:' ~ ,,:..~ ~, ~. ' ">~ ',.~:><:>¥~::~:.:>¥::::::,>~¢ ........... _ .... . .... : :: ::::::::::::::::::::::::: '.:::. :; ::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ARCO ALASKA, INC. 3 M- 16 KUPARLIK FIELD ALA.'::KA .SF'ERRY-g:LIN WEL. L '._:;URVEYING COMPANY PAGE .. AN,.He RA_ E.:.:.:,~:~ ....... ~,~:~~A~:~~ ......... A~ :::~: :: : :: "~::~:~:~?~;.... .~ .:.~. '~ ' ~, - ~t.,;:~.~ ~}' ,~:~:F:'.~:~' .. .,.' e '~"~'~:~J: : ·. AUGUST 7, 1987 dOB NUMBER AK=BO.-7OQSO KELLY BUSHING ELEV. = 64. ~~_~ INTERRO~:~D :~ALL!ES FOR EVEN F'TFI I]EF'TH NORTI--I/SOLtTH .EA::;T / NEST D I FFERENCE CORRECT I ON 6 ? 71 ?;/-,/-, 4 0 0 .~/-. (') A 0 0 '~ ':,~'-') '-' '" ........... ,. :..~ ,:,. o ?.~ N :'-]079, 82 - ,-, :;' --,~ '~?. ~ : :~ :" ~'i (: '::'i:~ :' ~ ~ ::::::::::::::::::::::::::: i'!:: ::.:: :~:':: i:.i: ~'i ~i'? .:?':i:::. ::.~ ======================= ::::::::::::::::::::::: ,:.::. 7U,:,._, 5764.00 ::~70('.~. 00_ . _ ~'-"r~'~":~,.,.,.... 97 N :31~.4 4 E :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 71. '::~'::~ .... ::, ~, 4. 00 5 ::: (') O. ( ) (.) ..' 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'. .' i<LIP~RLII< FIEI_F~ ALIGUL--:T 7, 1987 ,...lOB NUMBER AI<-BO-70050 OPERATOR-MCGLI I RE "FR~ S Li B - S E A T 0 T A L DEF'TH DEPTH DEF'TH NORTH/SOIJTH EAST/WEST MARKER · -: '~ ~.: .:::.:::': :.'.:: :?: :':::~:-~:::~ :~:~:,~:~! ~'.::,::~ ::'? :?:.'~L:":~:~ ?:~:~:~:?~' ~:.::' :]:~:: ::~ ~'~:' ~%::?' :'. :::':,:,.:~:~ :':~:)~::~::::':~ ?"":' ': .:' ' ' ...... ' ....... ":" "': t~ ' .~,~ ~ ,~ :::,:::::::::::::::::::::::::::: ~:::~: .:,'~ t~.~: ']i.~ :'~ '~ . ~t ~::.. ~:-:: ::. :::~'<.'~:?.',:'i~::?~: ]:: :.:,:.' · ~]::~t ~:::: 7~:R'? 6211.60 6147 60 ~ ~&L). "~'-~ _ _. . ~._, N 7601 ~. 9.::,.:, 27 ~, ~ ~':' ~'~ ~' .... 760 ~ 6222.27 6 ~ .._~':',._,. 27 .:':' ~ 1-_, ._,':'. ................................ ?~'0 ..... 6~.00",'"~2}'Z~ .............. ~:'~:'~'~:":"'~'}~i .................................... ~'~"~"~;':"'~'~'""~ ........ :3:395, 58 E SURVEY DEPTH 7 ,:,'"'~ ._._ ~ 6~49 . ._ ~ 7 o~,,:,.J z .-,,:,~, ~ J.z ~.~ ':'"~':""' ~:~,_t,:, ~ , , _ _ , , ~ ~,_~ ~ ........ . ............. , ...... .................. . . ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,~¥~, ~; · ~. ,,:~,~. ~.~-.:.,,~.~:::.::::.:~:~:-~:~:..::: :::::::::::::::::::::::::::::::::::::::::::::::: :::...,:: ~:..: .... :.. ·. :.:,:: ::,.: :.: :~~~'K~::::: ::~:::::::::~ .:~: '~ ~ :~ :~ :~: ~: ~: ::: ~: $~: ~: ~: ~::~?~: $ :~:~:~:~:~$~.~:~:~:~:~:~:~:~:~:F ~;~:~s ~:~:~::..,: -....::.:,:-?: :. ,:.,: ,': ,: :',: x, >..- ::. , .:. :,: ::~:::d:$:w::~ .:~::;~: ~$ ,,: :.:: ,,,, · i,r ,, i r rnl,11,r ir i,i :.: :,:::.:.:.:,.:..:~. .:. ,, :..:. ,'..'x::.::~::.?.: :b,.. '.. · ':?::,~::~¥::::~:~.,. :`.?:~:~::~::]::¥:~¥:::~:::~:~:::~:::~::::::::y:::~:~:~:g~:~.::~:~b:::~:~ :::::::::::::::::::::::::::::::::::::::::::: ~;,::::,:::::::::::::::::::::::::::::::::::::::::::::::.' :: .' .::', ....... MARKER ....... : :..::..:: ................................................................................................ : .............. -. .......................................... ~ ................................. ~.Lz_-"_Cb 2~,, :: ~...L~.,...;ELi..~ BA::;E ~::'11PARI IK F': 7/-,C> t /- '="':"? '.-"7 1- 1 .-~8. '='7 '-:, i ~. ':, t .-=.?,l .:,.:, ~ ,.-~ ,:~/. ~ ....... TOP KI_tPF~Rt_IK A ~/- BA:--;F Ki_tF'AFd_tK A PLUG BACK TD 7,:,._.- TOTAl .... Kd}ZPTH DR.1: LL. ER 7t:./==' ~"-"-:, ~ = 224= --, ~-.- /-- ...... =, .-. .'=":'~ =,47._,. 2':'~ 6:=:N .=,4._,4..l 6E :~ :....? ~L~i : · ,. ~ .~ ~ ~ - : · ..... ::'" :":::::::~:'"":.'"::::':::'"":'">'"":'"'"::'""~?'"'":'"'":::': '"'::"::~" ":'"'"'":': .......... :::::::::::::::::::::::::::::::::::::::::::::: .:~:~::::~;<.'~:~:t~::::: ~!~;<.i~:~::.::?:=!:r::i:~r!~!~!~ .~ :L .:::..::: :? ....................... :.-.: ....~:.:..:: .:.L.:...:.:.:: :,.., .............. :.:: ::.:~ ......... ·-... :: .~.:::.....::: ====================================== ~..~,.~::~:::::::~:~:~::~:~ :::::::::::::::::::::::::::::::::::::::::::::::: ::.,:::: :::::::::::::::::::::: -SUN 5CRLE :- 1 INCH TO ~00.00 / 500.0 KUPRRUK FIELO ARCO RLRSKR, 3M-16 RUGUST ~. RK -80-70050 TRUE NORTH O0 500.00 INC. 1987 000.00 '00 I SO0. O0 -5 . ~ORIZONTRL I 1500. O0 PROJECTTON 200~.00 250~.00 300~.00 0.00 1500.00 SPERR T- SU'~''?~''~.~I~:-.~ 5CRLE :- 1 INCH TO 1500.00 / 1 KUPfl8UK FIELD 9M-16 RK-BO-?O050 INC. · 2000.00 4500.00 6599.29 ?955 ?500.00 t500. O0 I SO00. O0 4500. O0 VEF~T I CRL ?ROJ~CT I ON - 1 Littan Core Lab /?7-- 053 1 j L 8005 Schoon Street Anchorage. Ataska 99518-3045 (907) 349- 3541 j L 1 ~ CORE ANALYSIS REPORT L Areo Alaska, Inc. KRU #3M-16 Kuparuk Formation Kuparuk River Unit North Slope, Alaska 19-Aug-87 L .J 1. TABLE OF CONTENTS SECTION A - SUMMARY OF PROCEDURES 1.) Introduction 2. ) Methodology a. Core Gamma Surface Log b. Laboratory Sampling c. Laboratory Procedures 3.) Special Conditions II. SECTION B - CORE ANALYSIS RESULTS - TABULAR DATA , 1.) Conventional Analysis Results 2.) CMS-200 Overburden Pressure Analysis Results , "'- 3.) Full Diameter Analysis 4.) Detailed Lithological Descriptions III. SECTION C - CORE ANALYSIS RESULTS - GRAPHIC DATA 1.) Correlation Coregraph IV. SECTION D - APPENDICES 1.) 2. ) 3. ) 4. ) r- 5.) 6. ) Refractive Index vs. API Gravity Plot oil Correction Chart Technical Paper - Automated Core Measurement System for Enhanced Core Data at Overburden Conditions (Keelan) Wellsite Core Report Well Site Handling Procedure Shipping and Receiving Transmittals J- Lilian Core Lab 8005 Schoon Street Anchorage. Alaska 99518-3045 (907) 349-3541 1~ j ,- j SECTION A SUMMARY OF PROCEDURES L L Areo Alaska, Inc. KRU #3M-16 Kuparuk Formation Kuparuk River unit North Slope, Alaska L. L - - ]- ]- INTRODUCTION ~- j Core Lab personal at the drill site supervised the processing and preservation of the KRU #3M-16 core. Well site handling procedures are explained in the Appendix. Whole core samples from the KRU #3M-16 well were brought to the Core Laboratories Anchorage facility for core analysis. The following is an outline of the procedures used in analyzing the KRU #3M-16 samples. ~ I j METHODOLOGY L Core Gamma Surface Log L 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. ~ Laboratorv Sampling Plugged Samples A one and a half inch length by one inch diameter plug was drilled from a lithologically representative section of each foot for helium porosity and air permeability measurements. Plugs were taken from the center of each section and parallel to the bedding strike, with water used as the bit coolant. Approximately 150 gram sample was removed adjacent to the plug for fluid saturation and API gravity measurements. To minimize invasion effects the sample was taken from the center of the core. Full Diameter Samples Full diameter samples were removed from selected intervals for helium porosity and directional air permeability measurements. C02 was used as the saw coolant. Laboratorv Procedures 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. L Porosity L Grain volumes were determined by a Boyle's Law - Heise Gauge Helium Porosimeter. Bulk volumes were measured by mercury displacement. , .I- ~ -- Permeability Horizontal permeability to air was measured using a steady state permeameter with a 400 psig. boot pressure. porosity and Permeability - Overburden Conditions L 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, and estimated air permeability, and a helium porosity is reported for overburden pressures of 1000 and 3000 psig. , .i- 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 #3M-16 well, as they are more representative of porosity and permeability at formation depth. Porosity and Permeability - Full Diameter Analysis Samples were cleaned, dry weights were measured and grain volumes determined by Boyle's Law-Heise Gauge Helium Porosimeter. Bulk volumes were measured by Archimedes technique. vertical and Horizontal permeability parallel and perpendicular to bedding, and porosity were measured in a hydrostatic holder at 400,1500, and 2000 psi. net overburden. Horizontal measurements were made using opposing 45 degree screens. permeability to air was measured using a steady state permeameter. Core Laboratories is pleased to provide the overburden porosity and permeability data performed on these full diameter samples at no additional charge. These values should prove most helpful in the evaluation of the KRU #3M-16 well, as they are more representative of porosity and permeability at formation depth. Fluid Saturation Measurements Of the 150 gram sample, 100 grams was broken pieces for the retort process. The 100 gram in a conventional retort oven at 400 deg. f. when an initial water reading was measured. into "peanut" size sample were retorted for 40 minutes , The temperature of ,- j '-- j 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. L * Observed oil readings were corrected for coking using the oil correction chart in Section D. J L oil Gravity Analysis L L 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. L ..... Core Photography The core was photographed in white and ultraviolet light with approximately l5 ft. of core per 8x10 in. print. As requested, two sets of white light and one set of UV core photographs are submitted. Special Conditions Core 1 from 7580 to 7601 and Core 3 from 7676 to 7691 have been slabbed and photographed. The un-sampled portion of each foot in the rest of the well remains preserved and preserved sections were not slabbed or photographed. 1 j- Littan Core Lab J- 1- j ,- j ¡ 1- i ,-- SECTION B CORE ANALYSIS RESULTS - TABULAR DATA Areo Alaska, Inc. KRU #3M-16 Kuparuk Formation Kuparuk River Unit North Slope, Alaska 8005 Schoon Street Anchorage, Alaska 99518- 3045 (907) 349- 3541 L L L L 1 Conventional Analysis Results , ,-'- 1 "- - - - - ... I File No BP-3-1223 Laboratory : Anchorage Analysts: TLS,TDT,PLB API No : 87 Sec 25 11-AUG Kuparuk Bland Mud T13N-R8E on d on Date Format F Drtg Locat nc Unit Alaska Arco A KRU #3M- Kuparuk RIver North Slope aska 16 AP OIL Grain Den M Wtr% Pore Oil% Pore He Por Perm MD Horiz Ka Depth Feet Sample Number on pt Descri GYBLK,SLTY,WELL CONS,PYR FILLED FRAC GYBLK,SLTY,TR VFGR SD,WELL CONS,SL ~ GYBLK,SLTY,TR VFGR SD,WELL CONS,PYR I GYBLK,SLTY,SDY,F-MGR SD,WELL CONS (II MDST,GYBLK,VSDY,M-CGR SD,WELL CONS,PYR F I MDST,GYBLK,VSDY,M-CGR SD,WELL CONS,PYR I MDST,GYBLK,VSDY,M-CGR SD,WELL CONS,PYR SLTST,LT OLVGY,VSDY,M-VCGR SD,WELL CONS lADES SLTST,LTGY,VARG,TR-1% VF-FGR SD,WELL COI MDST,LT OLVGv,SLTY,Tn SO,S' CLAC,DNSE,PI ; SID·ANK CMT ~. 'P~T .... 'Pnv ann "N" S" S' CLAC,WELL COI ,TR PYR ** CLAC,WELL COI TR CARB FRAGS ** GR,DNSE,SL CI :,POSS SID-ANK,GLAUC SLTY,DNSE,SL ,LC,POSS SID·ANK,GLAUC SLTY,WELL COI SL CALC,POO SID-ANK,GLAUC SLTY,WELL COI SL CLAC,POSS SID-ANK,GLAUC,BURS ,SLTY,WELL C( ,SL CLAC,POSS SID-ANK,GLAUC,BURS ;LTY,WELL CO~ SL CLAC,POSS SID-ANK,GLAUC,BURS : ;LTY,WELL CON SL CLAC,POSS SID-ANK,GLAUC, TR PYR ~ rR SLT,W C S,SL CLAC,POSS SID-ANK,GLAUC,TR PYR I . SLTST ! ! ~ FLUIDS ANALYSIS) OF FLUIDS ANALYSIS) .ISSILE (DATA FROM SUM. OF FILLED BURS (DATA FROM SUM FROM RETORT ANALYSIS) FOS ** BURS ** BURS TO M-CGR SS SLTY )ATA [LLED FILLED FILLED MDST MDST MDST MDST , " .. ~~ ,.011 ,ITI L.I \,II,. .n.\:II,I·11 1'\ v, L, SLTST,M-LTGY.ARG.MNR SD,SL SS,LT OLVGY SS.GYGRN.VF <10 <10 25 25 1 ELL CA..C,30% YELGY,DNSE,POSS SID-ANK CMT NTBD MDST ** 15% CLAC,INTBD MOST RD,WELL CONS,10 POSS SID - ANK 22 2.62 2.62 2.64 2.63 2.63 2.63 2.70 2.71 2.73 3.22 2.71 2.71 2.98 3.00 2.99 3_12 2.90 2.92 3.08 2.69 3.01 2.69 2.66 3.06 87.8 85.1 85.4 84.5 86.2 87.2 89.2 85.9 89.6 55.2 88.9 92.0 81.1 49.6 51.2 43.6 40.6 44.3 33.8 46.3 22.8 45.7 31.4 53.2 3.7 3.7 4.4 5.7 6.2 3.9 4.1 0.0 0.0 0.0 0.0 0.0 9.2 29.8 31.2 32.9 31.7 34.2 36.0 25.0 39.9 31.0 34.2 27.0 7614.5 14.3 15.2 15.6 16.1 14.3 14.6 14.3 14.0 12.4 2.9 11.3 11.7 14.8 19.5 19.0 18.7 19.3 19.1 18.7 17.0 8.2 15.4 16.8 1.8 7580.0 0.31 ** ** ** 10.67 2.01 ** 0.04 0.02 <0.01 0.02 1.51 0.14 0.33 0.47 6.21 0.34 1.31 1.22 0.48 0.17 1.55 12.34 <0.01 Fractured Sampled Core #1 7580.3 7581.8 7582.6 7583.5 7584.5 7585.3 7586.4 7587.7 7588.2 7589.5 7590.5 7591.4 7592.4 7593.5 7594.5 7595.8 7596.5 7597.4 7598.3 7599.3 7600.5 7601.7 7602.2 7603.6 01 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 121 122 123 124 ** r Î r ï I i r ~r -r Arco Alaska, Inc. Date 11-AUG-87 F i l e No BP-3-1223 KRU #3M-16 Format1on Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld Bland Mud AnaLysts: TLS,TDT,PLB North Slope, Alaska Location T13N-R8E"Sec 25 API No : Sample Depth Perm MD He Oil% Wtr% Grain API NlJIIber Feet Horiz Ka Por Pore Pore Den M OIL Description - , - - .. ........ .. .. ........ .. -....... - -- - - - - -- .... .... .. --.... --.. _oo ........_ .._......... .........._......._ ... .. ...... .....---..........- 125 7604.5 19.93 13.0 30.1 55.4 2.65 MDST,GYBLK,SLTY,SL CALC,40-50% VF-FGR,SLTY,WElL CONS,INTBD SS ** 126 7605.4 6.26 14.8 31.2 50.8 2.67 SS,LTBRN,VFGR,VWELL SRTD,SBANG-RD,WELL CONS,25-30% SlTY, Sl CLAC,INTBD MOST 127 7606.7 38.24 15.9 43.7 31.6 2.67 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOD CONS,20-30% SLTY,SL CALC,INTBD MDST ** 128 7607.7 17.12 15.1 39.4 33.3 2.67 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOD-WELL CONS,20-30% SLTY,INTBD MOST 129 7608.7 12.21 19.2 36.5 30.8 2.67 22 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOD CONS 130 7609.7 79.13 23.6 42.7 24.8 2.66 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI ** 131 7610.5 83.26 25.9 29.3 33.2 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS-SL FRI 132 7611.2 120.86 24.4 27.9 32.1 2.73 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,MNR MDY LAMS 133 7612.7 80.99 25.1 32.7 27.9 2.66 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS-SL FRI,TR LAMS,(SCULPTURED SAMPLE) 134 7613.4 ** 27.8 28.9 42.1 2.70 22 SS,LTBRN,VFGR,SlTY,VWELL SRTD,SBANG-RD,SL FRI,MNR MDY LAMS,(SCULPTURED SAMPLE) 135 7614.3 ** 25.2 32.2 27.5 2.69 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,SL FRI,MNR MDY LAMS Core #2 7617.0 - 7676.3 201 7617.7 1.47 14.3 44.7 32.7 2.65 MDST,GYBLK,SLTY,SL CALC,MIC,30-50% VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD-WELL CONS,INTBD SS 202 7618.4 74.75 25.4 56.1 14.2 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS-SL FRI,TR MDY LAMS 203 7619.4 4.83 15.9 52.8 14.0 2.64 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-25% SL CALC,INTBD MDST 204 7620.6 20.03 23.2 43.7 14.9 2.66 23 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS,TR LAMS 205 7621.5 4.30 17.4 37.3 45.3 2.64 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WEll CONS,15-20% SLTY,LAM MDST 206 7622.8 1.03 16.5 48.5 35.0 2.65 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-25% SlTY,SL ClAC,INTBD MOST 207 7623.7 7.24 13.7 30.4 57.7 2.65 MDST,GYBLK,SL CALC,WELL CONS,30-40%SDY,WELL CONS,INTBD SLTST ** 208 7624.2 8.21 13.5 46.8 31.2 2.62 MDST,GYBLK,SDY,SL CALC,WELL CONS,20-30%VFGR,SLTY,SDY BURS,BIOTURB ** 209 7625.5 88.44 15.6 48.0 14.7 2.67 25 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,MOD-WELL CONS,15-20% SL CALC, INTBD MDST ** 210 7626.9 19.38 16.0 33.1 53.5 2.68 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD'RD,WELL CONS,20% SL CALC,INTBD MDST,PYR BLEB 211 7627.3 0.15 12.8 28.2 62.4 2.67 MDST,GYBLK,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,VWELL SRTD,SBANG-RD,INTBD SS 212 7628.5 0.26 15.0 41.1 25.2 2.65 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,15-20%INTBD MDST 213 7629.6 0.41 12.0 26.0 61.4 2.72 MDST,GYBLK,SDY,SL CALC,WELL CONS,10-15% VFGR,SDY BURS,PYR FOS ** ** Fractured Sampled _.... Arco Alaska, Inc. Date 11-AUG-87 Fi le No BP-3-1223 KRU #3M-16 FormatIon Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld Bland Mud Analysts: TLS,TDT,PLB North Slope, Alaska Location T13N-R8E-Sec 25 API No : Sample Depth Perm MD He Oil% Wtr% Grain API Number Feet Horiz Ka por Pore Pore Den M OIL Description -. -- ..-......- .........-- .... .. .. .... --- - -- -- - ..--.... .. --....... ..............-............... -.............-- - ....---............. - 214 7630.9 188.57 24.3 41.8 20.0 2.66 23 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRO-RO,Sl FRI,TR MOY lAMS 215 7631.6 109.43 18.1 41.4 23.5 2.65 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,15-20% LAM MOST 216 7632.6 324.58 26.8 42.0 18.0 2.66 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,5% MDST LAMS 217 7633.6 244.68 25.3 52.8 16.7 2.64 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,5% MDST LAMS,PYR BLEBS 218 7634.3 122.72 18.6 40.0 26.5 2.64 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,10% MDST LAMS 219 7635.4 104.03 22.8 47.9 11.0 2.68 22 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,Sl FRI,5-10%MDST LAMS 220 7636.8 324.22 29.0 46.6 15.1 2.65 SS,YELBRN,VFGR,MNR SLT,VWELL SRTO,SBRO-RD,FRI,TR lAMS 221 7637.4 278.96 28.1 51.3 11.5 2.66 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI,TR LAMS 222 7638.4 125.78 25.3 44.5 12.2 2.65 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,TR LAMS 223 7639.1 4.91 17.2 39.1 38.1 2.65 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,5-10% INTBD MDST,TR PYR 224 7640.2 150.74 26.7 37.0 19.7 2.67 25 SS,YELBRN,VFGR,MNR SLT,VWELl SRTD,SBRD-RD,SL FRI,TR LAMS 225 7641.8 93.49 24.8 56.2 28.1 2.65 SS,YELBRN,VFGR,MNR SLT,VWELl SRTD,SBRD-RD,Sl FRI,TR LAMS 226 7642.4 8.75 18.3 39.7 22.4 2.67 SS,YELBRN,VFGR,SLTY,WELL SRTD,SBRD-RO,MOD-WELL CONS,10% THNLY INTBD MDST 227 7643.6 333.88 28.8 52.1 9.2 2.66 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI 228 7644.2 213.42 29.3 60.8 7.2 2.67 SS,YELBRN,VFGR,MNR SLT,VWELL SRTO,SBRD-RD,FRI 229 7645.3 1.40 20.0 47.1 22.1 2.94 22 SLTST,OLVGY,VSDY,ARG,SL CALC,WELL CONS,POSS SID-ANK CMT,MNR INTBD SS ** 230 7646.4 85.69 23.6 48.5 28.4 2.64 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI-FRI,10-15% MOST LAMS 231 7647.1 248.00 27.9 41.4 38.4 2.65 SS,YELBRN,VFGR,MNR SLT,VWELl SRTD,SBRD-RD,FRI,MNR MDY LAMS 232 7648.7 16.50 15.8 54.2 15.0 2.64 SS,LTBRN,VFR,SLTY,VWELL SRTD,SBRD-RD,MOD WELL CONS,15-20% INTBO MDST ** 233 7649.1 4.46 18.4 45.0 41.8 2.69 SS,LT-MBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,10-15% BIOTURB MDST,PYR BLEB 234 7650.4 ** 29.6 63.9 11. 7 2.67 27 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI 235 7651.2 181.22 28.5 66.4 6.2 2.66 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD.SBRO-RD,FRI 236 7652.6 112.61 21.9 56.7 6.5 2.64 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI5% THNBDD MDST 237 7653.7 30.81 21.0 49.9 27.4 2.65 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,SL FRI 238 7654.3 14.15 20.8 56.4 10.2 2.68 SS,YELBRN,VFGR,MNR SLT,VWElL SRTD,SBANG-RD,MOD CONS 239 7655.4 38.61 22.0 59.8 7.7 2.75 26 SS,YELBRN,VFGR,MNR SLT,VWELL SRTO,SBANG-RD,MOD CONS 240 7656.7 66.27 23.6 54.3 11.5 2.69 SS.YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,MOD CONS,TR PYR ** Fractured Sampled I r r~ í r --î ......--- ! Arco Alaska, Inc. Date 11-AUG-87 Fi le No BP-3-1223 KRU #3M-16 Format 1 on Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld Bland Mud Analysts: TLS,TDT,PLB North Slope, Alaska Location T13N-R8E-See 25 API No : Sample Depth Perm MD He Oil% Wtr% Grain AP Number Feet Hori z Ka Por Pore Pore Den M OIL Description - -- ......--.. -..-..-- .. .... ... -- - --- n _ ..-.... ...... ..-- ---.... -- --.. .............. -- '- 241 7657.2 14.67 17.2 54.4 14.0 2.64 SS,LTBRN,VFGR,SlTY,VWELl SRTD,SBANG-RD,MOD-WELL CONS,TR PYR 242 7658.6 0.04 3.7 41.3 26.8 2.77 SS,LT OLVGY,VFGR,CALC,WELL CMTD,DNSE,POSS SID-ANK CMT,GRADES TO SLTST 243 7659.3 120.33 24.2 34.4 25.5 2.70 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,SL FRI,DISM PYR 244 7660.2 3.85 15.0 48.9 25.4 2.64 25 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,WELL CONS,20-25% THKLY LAM MDST,PYR BLEB 245 7661.5 6.75 14.7 45.5 31.9 2.62 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,WELL CONS,20-30% THKLY LAM MDST ** 246 7662.5 27.77 20.9 40.4 24.9 2.67 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD-WELL CONS,TR MDY LAMS 247 7663.4 21.41 17.9 43.3 38.2 2.64 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOO CONS,15-20% MOST LAMS 248 7664.4 5.46 17.6 36.3 50.0 2.74 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-25% THNLY INTBD MOST 249 7665.2 5.38 15.8 35.9 36.2 2.63 23 SS,LTBRN,VFGR,VSLTY,VWELL SRTD,SBANG-RD,WELL CONS,TR PYR 250 7666.6 1.70 13.3 36.9 43.6 2.63 MDST,GYBLK,SLTY,SDY,SL CALC,WELl CONS,40-50% VFGR,SLTY,BIOTURB SS,TR PYR 251 7667.7 0.58 13.2 39.2 41.9 2.62 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,BIOTURB SS 252 7668.4 7.77 14.1 36.9 54.0 2.64 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,BIOTURB SS,PYR BLEBS ** 253 7669.5 4.24 18.6 50.3 24.5 2.73 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,WELL CONS,TR LAMS 254 7670.6 0.16 13.2 39.1 44.7 2.66 22 SLTST,OLVBlK,VSDY,ARG,WELL CONS,20% SLTY LAM MDST,PYR BLEBS,BIOTURB 255 7671 .2 4.57 17.2 45.3 41.2 2.63 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD CONS,15-20% BIOTURB MDST,TR PYR 256 7672.5 2.14 17.1 51.8 19.2 2.71 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD-WELL CONS,10-15% BIOTURB MDST,TR PYR 257 7673.7 0.39 12.4 40.4 37.8 2.68 MDST,GYBLK,VSDY,SL CALC,WELL CONS,20-30% VFGR,SLTY,BIOTURB SS,1-3% PYR 258 7674.3 0.58 14.3 51.6 30.6 2.62 MDST,GYBLK,SDY,SL CALC,WELL CONS,20% VFGR,SLTY,BDD SS,ABNT BIOTURB 259 7675.7 0.21 13.5 38.4 48.0 2.62 17 MDST,GYBLK,SDY,SL CLAC,WELL CONS,20-30% VFGR,SLTY,BDD SS,TR PYR,ABNT BIOTURB Core #3 7676.3 - 7691.2 301 7676.6 5.66 13.8 30.2 62.4 2.68 MDST,GYBLK,SLTY,SL CALC,WELL CONS,5-10% BIOTURB SS ** 302 7677.8 1.27 13.8 38.0 48.3 2.68 MDST,GYBLK,SL CALC,30-40% VFGR,SLTY,WELL CONS,THNLY INTBD SS 303 7678.5 1.83 13.9 32.8 40.4 2.64 MDST,GYBLK,SLTY,SL CALC,WELL CONS,20-30% VFGR,SLTY,THKLY LAM SS,TR PYR ** 304 7679.6 1.02 12.1 37.2 45.5 2.64 MDST,GYBLK,SLTY,SL CALC,30-40% VFGR,SLTY,THKLY LAM SS,TR PYR ** 305 7680.7 2.49 13.4 29.5 62.6 2.68 18 MDST,GYBLK,SL CALC,WELL CONS,20-30% VFGR,VSLTY,BIOTURB SS,1-3% PYR ** ** Fractured Sampled r'" 14 Arco Alaska, Inc. Date 11-AUG-87 File No : BP-3-1223 KRU #3M-16 FormatIon Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld Bland Mud Analysts: TLS,TDT,PLB North Slope, Alaska Location T13N-R8E-Sec 25 API No : Sample Depth Perm MD He Oil% Wtr% Grain API Number Feet Horiz Ka Por Pore Pore Den M OIL Description - - ...... .... - - - .......... .. - -- .. - - -- .. .. .. .. .. ----.. --- ---...." -.............. . - ' 306 7681.8 1.21 12.1 37.9 52.8 2.63 MDST,GYBLK,SLTY,SL CALC,WELL CONS,TR PYR,SDY BURS ** 307 7682.3 0.38 12.9 41.2 41.5 2.65 MDST,GYBLK,SLTY.SL CALC,WELL CONS,20-25% VFGR,SLTY,LAM SS,TR PYR ** 308 7683.7 0.54 13.3 29.1 62.8 2.65 MDST,GYBLK,SLTY,SL CALC,WELL CONS,20-25% VFGR,SLTY,LAM SS,PYR FILLED BUR ** 309 7684.3 0.96 13.0 36.0 42.7 2.61 MDST,GYBLK,SLTY,SL CALC,40-50% VFGR,SLTY,BIOTURB SS ** 310 7685.5 0.72 12.9 30.0 60.6 2.80 18 MDST,GYBLK,SLTY,SL CALC,20-30% VFR.SLTY,BIOTURB SS,PYR MASS ** 311 7686.8 2.30 13.6 26.3 65.5 2.69 SLTST,LTBRN,VSDY,WELL CONS,GRADES TO VFGR SS,15-20% BOD MDST,PYR MASS ** 312 7687.4 0.31 13.4 29.9 58.8 2.69 SS,LTBRN,VFGR,VSLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-30% BDD MDST,TR PYR 313 7688.6 0.17 11.6 21.4 69.3 2.62 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,5-15% VFR SLTY LAM SS 314 7689.5 ** 12.4 19.9 74.2 2.65 MDST,GYBLK,SLTY,SL CALC,WELL CONS,1-3% PYR 315 7690.3 ** 12.6 20.3 73.5 2.68 10 MDST,GYBLK,MIC.SL CALC,WELL CONS,5% LAM SLTST,3-5% PYR 316 7691 .0 ** 11.8 37.3 48.6 2.63 MDST.GYBLK.MNR SLT,SL CALC,WELL CONS,TR PYR,TR SLTY LAMS ~ l- L L L CMS-200 Overburden Pressure Analysis Results L L l t~ ..... t-- 1-..0 I-~ í COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. .... .... .... ..........-- .. .... .. .. .. .. - .... .... .. .... .. ...... .. .. .. .. .. .. ... .. -..--.. --.. ---............ -- -... .. ...... ..... .. .. .. ... .. .. .. ........ .. .. .. 101 7580.3 atm(1) 14.3 0.31 MDST,GYBLK,SLTY,WELL CONS,PYR FILLED FRAC 1000 12.1 0.09 0.11 3000 11.2 0.01 0.01 115 7594.5 atm 19.0 0.47 SS,GYGRN,VF-CGR,PRED F-MGR,SLTY,WELL CONS,SL CALC,POO SID-ANK,GLAUC 1000 18.5 0.28 0.56 3000 18.0 0.16 0.36 116 7595.8 atm 18.7 6.21 SS,GYGRN,VF-CGR,PRED F-MGR,SLTY,WELL CONS,SL CLAC,POSS SID-ANK,GLAUC,BURS 1000 18.4 3.87 4.88 3000 18.0 2.96 3.80 117 7596.5 atm 19.3 0.34 SS,GYGRN,VF-CGR,PRED VF-MGR,SLTY,WELL CONS,SL CLAC,POSS SID-ANK,GLAUC,BURS 1000 19.2 0.18 0.38 3000 18.8 0.13 0.29 118 7597.4 atm 19.1 1.31 SS,GYGRN,VF-CGR,PRED F-MGR,SLTY,WELL CONS,SL CLAC,POSS SID-ANK,GLAUC,BURS 1000 19.0 0.83 1.30 3000 18.6 0.51 0.86 119 7598.3 atm 18.7 1.22 SS,GYGRN,VF-CGR,PRED F-MGR,SLTY,WELL CONS,SL CLAC,POSS SID-ANK,GLAUC,TR PYR 1000 18.6 0.83 1.43 3000 18.3 0.75 1.29 120 7599.3 atm 17.0 0.48 SS,GYGRN,VF-CGR,PRED F-MGR,TR SLT,WELL CONS.SL CLAC.POSS SID-ANK.GLAUC,TR PYR 1000 17.0 0_17 0_31 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample )-.... I I I COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11 - AUG - 87 File No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis . CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ........--.. --........... -..a....... .. .. .. .... .. .. .. .. .. .. .. -..........- ...... .... .. .. .. .. .... .. .. .. .. .. .. .. .. ......... ....... .. .. .. .. ... .... .. ~ .. .. .. .. .. .. .. .. .. 3000 16.3 0.07 0.14 122 7601 .7 atm 15.4 1.55 SLTST,LTBRN,SDY,WELL CONS,15-20% SL CLAC,INTBD MDST ** 1000 15.1 0.70 1.02 3000 14.6 0.35 0.56 123 7602.2 atm 16.8 12.34 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,10-15% INTBD MOST 1000 16.5 9.97 11. 81 3000 16.1 9.37 11.11 125 7604.5 atm 13.0 19.93 MDST,GYBLK,SLTY,SL CALC,40-50% VF-FGR,SLTY,WELL CONS,INTBD SS ** 1000 12.2 4.72 5.02 3000 11.8 0.42 0.53 126 7605.4 atm 14.8 6.26 SS,LTBRN,VFGR,VWELL SRTD,SBANG-RD,YELL CONS,25-30% SLTY, SL CLAC,INTBD MDST 1000 14.1 4.31 5.07 3000 13.7 3.61 4.24 127 7606.7 atm 15.9 38.24 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOD CONS,20-30% SLTY,SL CALC,INTBD MDST ** 1000 15.7 28.10 34.18 3000 15.1 26.10 31.53 128 7607.7 atm 15.1 17.12 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOD-YELL CONS,20-30% SLTY,INTBD MDST 1000 14.6 14.07 15.54 3000 14.2 12.11 13.31 atm - measured Ka and Por taken from conventional core analysis resuLts ** Fractured Sample I 1- r r r "-r I - - - ] ! 1 COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 11-AUG-87 Fi le No. : BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TOT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ........ .. .. .. .. ............. .....a..___ .... ...... ------.. .... .. ........ ................-..-.... -.. -------. .. -- ---.. -- ...... -. .............-.... 129 7608.7 atm 19.2 12.21 SS,LTBRN,VFGR,SLTY,WELL SRTD,SBANG-RD,MOO CONS 1000 18.5 7_89 9.69 3000 18.2 6.72 8.34 130 7609.7 atm 23.6 79.13 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI ** 1000 23.2 66.08 72.90 3000 22.8 60.50 66.90 131 7610.5 atm 25.9 83.26 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD~RD,MOO CONS-SL FRI 1000 25.6 71.95 79.82 3000 25.2 69.44 77.02 132 7611.2 atm 24.4 120.86 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,MNR MDY LAMS 1000 24.0 106.94 115.32 3000 23.7 102.77 111.07 201 7617.7 atm 14.3 1.47 MDST,GYBLK,SLTY,SL CALC,MIC,30-50% VFGR,SLTY,VWELL SRTD,SBANG-RD,MOO-WELL CONS.INTBD SS 1000 13.1 0.68 0.92 3000 12.7 0.38 0.56 202 7618.4 atm 25.4 74.75 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS-SL FRI,TR MDY LAMS 1000 25.4 63.85 70.89 3000 25.0 61.64 68.54 203 7619.4 atm 15.9 4.83 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS.20-25% SL CALC,INTBD MDST 1000 15.5 3.11 3.88 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample I- I I- I r r I r ~ r I - - - ] ] I COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCR I PTI ON .. .. .. .. ~ .. .. .. ....... .... .. .. .. a .. ...... ----.. .. .. .... .. .... .. .. .... .. .. .. .. ---.... --..- ---..-..-......-....-..-..........- -- -.. -- --............ --.... 3000 15.0 2.42 3.08 204 7620.6 atm 23.2 20.03 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS,TR LAMS 1000 22.8 15.97 19.04 3000 22.4 15.30 18.25 205 7621.5 atm 17.4 4.30 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,15-20% SLTY,LAH MDST 1000 17.1 2.72 3.56 3000 16.7 2.28 3.01 206 7622.8 atm 16.5 1.03 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-25% SLTY,SL CLAC,INTBD MOST 1000 16.2 0.71 1.01 3000 15.7 0.63 0.87 207 7623.7 atm 13.7 7.24 MDST,GYBLK,SL CALC,WELL CONS,30-40%SDY,YELL CONS,INTBD SLTST ** 1000 12.6 2.08 2.23 3000 12.3 0.27 0.32 208 7624.2 atm 13.5 8.21 MDST,GYBLK,SDY,SL CALC,WELL CONS,20-30%VFGR,SLTY,SDY BURS,BIOTURB ** 1000 12.7 2.15 2.37 3000 12.3 0.36 0.49 209 7625.5 atm 15.6 88.44 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD.MOD-WELL CONS,15-20% SL CALC, INTBD MOST ** 1000 15.3 22.18 28.91 3000 14.4 4.17 5.20 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample I J~ I;~ ,.... ,..- r r r --r J -¡ - ~._--' I. , I ! COR E LAB 0 RAT 0 R E S N C . Arco Alaska, Inc. Date : 11-AUG-87 Fi le No. BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ............ .. .... .... .... .. .. ..... .. .. .... ..... .. .. .. .. .. .. ........ ....----- ............... --..................................................................................... 210 7626.9 atm 16.0 19.38 SS,LTBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,WELL CONS,20% SL CALC,INTBD MDST,PYR BLEB 1000 15.6 10.75 12.34 3000 15.2 5.21 6.42 212 7628.5 atm 15.0 0.26 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,15-20%INTBD MOST 1000 15.0 0.17 0.31 3000 14.5 0.11 0.21 214 7630.9 atm 24.3 188.57 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,TR MDY LAMS 1000 24.2 168.68 179.56 3000 23.8 161.88 172.46 215 7631.6 atm 18.1 109.43 SS,YELBRN,VFGR,MNR SLT.VWELL SRTD,SBRD-RD,SL FRI,15-20% LAM MOST 1000 17.5 97.71 102.97 3000 17.2 92.81 97.88 216 7632.6 atm 26.8 324.58 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,5% MDST LAMS 1000 26.5 285.69 299.02 3000 26.1 275.67 288.55 217 7633.6 atm 25.3 244.68 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,5% MOST LAMS,PYR BLEBS 1000 24.9 220.45 232.54 3000 24.5 212.81 224.62 218 7634.3 atm 18.6 122.72 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,10% MDST LAMS 1000 18.1 110.76 115.76 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample Ii I I .- ~,. í t r r ---I --r - - I I COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .............. .. .. .... .. .... ..... . .. ...... -........ ................ .. .... .. ...... .......- ...... ..-.._.. ----...... ---. .. ...... .... ..... ..... .. .. .. .... .. .. .. .. .. 3000 17.7 105.10 109.84 219 7635.4 atm 22.8 104.03 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,5-10%MDST LAMS 1000 22.5 91.47 98.91 3000 22.1 88.18 95.44 220 7636.8 atm 29.0 324.22 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI,TR LAMS 1000 28.7 283.99 300.96 3000 28.4 271.86 288.38 221 7637.4 atm 28.1 278.96 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI,TR LAMS 1000 27.8 238.06 253.67 3000 27.5 228.73 244.15 222 7638.4 atm 25.3 125.78 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,TR LAMS 1000 25.1 105.91 114.89 3000 24.8 101.95 110.59 223 7639. 1 atm 17.2 4.91 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,5-10% INTBD MDST,TR PYR 1000 16.6 3.31 4.19 3000 16.2 2.60 3.35 224 7640.2 atm 26.7 150.74 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,TR LAMS 1000 26.5 130.92 141.81 3000 26.1 125.88 136.52 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample r r r ~! I t· J >~ t ,I I~ ,- i t- h~ ï J COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ............ .... .... .... .. .......... .... -........ .......... .. .. .. ............ .. .. ...... .... .. .. ........ .. .. .......... .. .... ...... .. .. .. .. ........ ~ .. .. .. .. .. .. .... .. 225 7641.8 atm 24.8 93.49 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI,TR LAMS 1000 24.4 80.51 88.55 3000 24.1 77.86 85.67 226 7642.4 atm 18.3 8.75 SS,YELBRN,VFGR,SLTY,WELL SRTD,SBRD-RD,MOD-WELL CONS,10% THNLY INTBD MOST 1000 18.4 6.61 8.04 3000 17.7 5.71 7.03 227 7643.6 atm 28.8 333.88 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI 1000 28.3 308.84 328.37 3000 28.0 294.65 313.47 228 7644.2 atm 29.3 213.42 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI 1000 28.8 177.17 192.46 3000 28.4 169.77 184.60 229 7645.3 atm 20.0 1.40 SLTST,OLVGY,VSDY,ARG,SL CALC,WELL CONS,POSS SID-ANK CMT,MNR INTBD SS ** 1000 19.6 0.28 0.36 3000 19.3 0.06 0.12 230 7646.4 atm 23.6 85.69 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,SL FRI-FRI,10-15% MDST LAMS 1000 22.9 72.83 79.64 3000 22.6 69.96 76.63 231 7647.1 atm 27.9 248.00 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI,MNR MDY LAMS 1000 27_4 203.69 220.93 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample r Ir--r -r r J 1--' t- i ,.... l'" r t' r' r COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 Fi le No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ....--...... .... .. .... .... ...... .. .. .... .......... ............. .... .. .. .. .. .. ..........- -....... --...... --- -......... .. .. .. .. .. .. .. .. .. .. ~ .. ..... .... .. .. .. .. .. 3000 27.1 195.62 212.29 233 7649.1 atm 18.4 4.46 SS,LT-MBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,10-15% BIOTURB MDST,PYR BLEB 1000 17.9 3.09 4.09 3000 17.5 2.82 3.75 235 7651.2 atm 28.5 181.22 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD.SBRD-RD,FRI 1000 28.1 149.84 163.66 3000 27.8 144.59 157.98 236 7652.6 atm 21.9 112.61 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBRD-RD,FRI5% THNBDD MOST 1000 21.5 96.92 104.81 3000 21.1 93.74 101.34 237 7653.7 atm 21.0 30.81 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,SL FRI 1000 20.4 25.02 28.48 3000 20.0 24.09 27.41 238 7654.3 atm 20.8 14.15 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,MOO CONS 1000 20.1 11. 23 13.47 3000 19.8 10.55 12.66 239 7655.4 atm 22.0 38.61 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,MOD CONS 1000 21.6 32.63 36.99 3000 21.3 31.51 35.72 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample I~ r -r r -\r -r a._.____ -r --- ~ } J~ , 1 J ~ COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .... .... ...... .... ..... .. .. .. .... . ...... .. .......... ............... .. .. .. ...... .. ....... .... ...... ........ ...... .. .. .. .. ...... .. .. .............. .... . .... .... ... .. .. .... .. 240 7656.7 atm 23.6 66.27 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,MOD CONS,TR PYR 1000 23.2 56.04 62.67 3000 22.9 54.18 60.60 241 7657.2 atm 17.2 14.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD-WELL CONS,TR PYR 1000 16.4 11.74 13.62 3000 16.0 10.99 12.73 243 7659.3 atm 24.2 120.33 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRÐ-RD,SL FRI,DISM PYR 1000 23.9 99.23 108.94 3000 23.6 96.60 106.06 244 7660.2 atm 15.0 3.85 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,WELL CONS,20·25% THKLY LAM MDST,PYR BLEB 1000 14.0 2.87 3.58 3000 13.7 2.59 3.22 245 7661.5 atm 14.7 6.75 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,WELL CONS,20-30% THKLY LAM MOST ** 1000 13.7 5.07 5.98 3000 13.3 4.30 5.08 246 7662.5 atm 20.9 27.77 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOO-WELL CONS,TR MDY LAMS 1000 20.5 21.65 25.02 3000 20.2 20.49 23.67 247 7663.4 atm 17.9 21.41 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOD CONS,15-20% MDST LAMS 1000 17.4 17.65 19.81 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample . . . )- . '1 r- } r r ) r ....,. .....,¡ I'--"~~--""" ~.----_... l J t COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11'AUG-87 Fi le No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. ............ .. .. .. .... .... .... ...... .... .... .... .. ..-......... .. .. .. .. .. .. .. .. ....-............-....................... .. .... .. .. .. .... .... ....--......--- 3000 17. , 16.49 18.48 248 7664.4 atm 17.6 5.46 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-25% THNLY INTBD MDST 1000 17.2 3.57 4.59 3000 16.9 3.01 3.89 249 7665.2 atm 15.8 5.38 SS,LTBRN,VFGR,VSLTY,VWELL SRTD,SBANG-RD,WELL CONS,TR PYR 1000 15.1 3.35 4.15 3000 14.6 2.87 3.55 250 7666.6 atm 13.3 1.70 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,BIOTURB SS,TR PYR 1000 12.7 0.49 0.64 3000 12.4 0.12 0.20 251 7667.7 atm 13.2 0.58 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,BIOTURB SS 1000 12.6 0.26 0.42 3000 12.3 0.15 0.25 252 7668.4 atm 14.1 7.77 MDST,GYBLK,SLTY,SDY,SL CALC,WELL CONS,40-50% VFGR,SLTY,BIOTURB SS,PYR BLEBS ** 1000 13.3 2.24 2.43 3000 12.9 0.48 0.60 253 7669.5 atm 18.6 4.24 SS,YELBRN,VFGR,MNR SLT,VWELL SRTD,SBANG-RD,WELL CONS,TR LAMS 1000 18.5 3.62 4.83 3000 18.2 3.48 4.63 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample T l-~ l ~, ) ~ , ) ~ ~ ~ } ) ) ) , COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 Fi le No. : BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ......--.... .. ..... .. .... .. ....-......- -........ .. .... ..... .. .. .. .. ...... .. ... .. .. .. .. ..... .. .. ..... .. ........ .. .. .. ..... .... ..... -............... --..-............. -.. --.. 254 7670.6 atm 13.2 0.16 SLTST,OLVBLK,VSDY,ARG,WELL CONS,20% SLTY LAM MDST,PYR BLEBS,BIOTURB 1000 12.7 0.07 0.13 3000 12.4 0.03 0.07 255 7671.2 atm 17.2 4.57 SS,YELBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD CONS,15-20% BIOTURB MDST,TR PYR 1000 16.6 2_98 3.91 3000 16.2 2.35 3.13 256 7672.5 atm 17.1 2.14 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBANG-RD,MOD-WELL CONS,10-15% BIOTURB MDST,TR PYR 1000 16.9 1.30 1.89 3000 16.5 0.97 1.45 257 7673.7 atm 12.4 0.39 MDST,GYBLK,VSDY,SL CALC,WELL CONS,20-30% VFGR,SLTY,BIOTURB SS,1-3% PYR 1000 11. 7 0.12 0.20 3000 11.4 0.03 0.06 258 7674.3 atm 14.3 0.58 MDST,GYBLK,SDY,SL CALC,WELL CONS,20% VFGR,SLTY,BDD SS,ABNT BIOTURB 1000 13.9 0.36 0.56 3000 13.5 0.30 0.46 259 7675.7 atm 13.5 0.21 MDST,GYBLK,SDY,SL CLAC,WELL CONS,20-30% VFGR,SLTY,BDD SS,TR PYR,ABNT BIOTURB 1000 13.0 0.08 0.15 3000 12.6 0.03 0.06 301 7676.6 atm 13.8 5.66 MDST,GYBLK,SLTY,SL CALC,WELL CONS,5-10% BIOTURB SS ** 1000 12.4 4.51 4.81 atm' measured Ka and por taken from conventional core analysis results ** - Fractured Sample t f" r r' ) } , ~ . ~ . I I . }-' l~ ) )-" COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 File No. BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .... .. .. ....... ...... .. .. .. .. ----...... .. ........ .. ....... ...... .. .. .. .. .. .... -........ ...... ..-..-- ..........-....- .. ...... .... .. ...... ...... ...... .... .. .. 3000 11.8 1.24 1.33 302 7677.8 atm 13.8 1.27 MDST,GYBLK,SL CALC,30-40% VFGR,SLTY,WELL CONS,THNLY INTBD SS 1000 13.1 0.52 0.75 3000 12.7 0.26 0.40 303 7678.5 atm 13.9 1.83 MDST,GYBLK,SLTY,SL CALC,WELL CONS,20-30% VFGR,SLTY,THKLY LAM SS,TR PYR ** 1000 13.0 0.30 0.43 3000 12.6 0.05 0.10 304 7679.6 atm 12.1 1.02 MDST,GYBLK,SLTY,SL CALC,30-40% VFGR,SLTY,THKLY LAM SS,TR PYR ** 1000 11.4 0.30 0.43 3000 10.9 0.06 0.11 305 7680.7 atm 13.4 2.49 MDST,GYBLK,SL CALC,WELL CONS,20-30% VFGR,VSLTY,BIOTURB SS,1-3% PYR ** 1000 12.1 0.61 0.76 3000 11.6 0.12 0.18 306 7681.8 atm 12.1 1.21 MDST,GYBLK,SLTY,SL CALC,WELL CONS,TR PYR,SDY BURS ** 1000 11.2 0.07 0.12 3000 10.8 0.01 0.03 307 7682.3 atm 12.9 0.38 MDST,GYBLK,SLTY,SL CALC,WELL CONS,20-25% VFGR,SLTY,LAM SS,TR PYR ** 1000 12.7 0.18 0.30 3000 12.0 0.08 0.15 atm - measured Ka and Por taken from conventional core analysis results ** Fractured Sample 1 t" ) r } t ì ~ . ) ì ) 1~ 1-' )~ COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 11-AUG-87 Fi le No. BP-3-1223 KRU #3M-16 Formation : Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T13N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. - .... .......... ......... ... .. .... .......... .. .. ...... .. .. ....... .... .. ... .... .......... ...... .... .... ......--....---- . ...... .. .. .. .. .... 308 7683.7 atm 13.3 0.54 MDST,GYBLK,SLTY,SL CALC,WELL CONS,20-25% VFGR,SLTY,LAM SS,PYR FILLED BUR ** 1000 12.6 0.27 0.37 3000 12.1 0.06 0.10 309 7684.3 atm 13.0 0.96 MDST,GYBLK,SLTY,SL CALC,40-50% VFGR,SLTY,BIOTURB SS ** 1000 12.3 0.29 0.40 3000 11.9 0.06 0.10 310 7685.5 atm 12.9 0.72 MDST,GYBLK,SLTY,SL CALC,20-30% VFR,SLTY,BIOTURB SS,PYR MASS ** 1000 12.1 0.31 0.44 3000 11.8 0.08 0.14 311 7686.8 atm 13.6 2.30 SLTST,LTBRN,VSDY,WELL CONS,GRADES TO VFGR SS,15-20% BOD MDST,PYR MASS ** 1000 13.3 0.53 0.72 3000 12.9 0.16 0.28 312 7687.4 atm 13.4 0.31 SS,LTBRN,VFGR,VSLTY,VWELL SRTD,SBANG-RD,WELL CONS,20-30% BDD MDST,TR PYR 1000 13.1 0.11 0.21 3000 12.7 0.05 0.11 313 7688.6 atm 11.6 0.17 MDST,GYBLK,SLTY,SDY,SL CALC.WELL CONS,5-15% VFR SLTY LAM SS 1000 10.9 0.03 0.06 3000 10.5 0.00 0.02 L L 1.. ~ 1 ~ Full Diameter Core Analysis J- L. 1 - - - ~ 1 .... - - - -- ~ r 1 1 1 . t t )~ r .. r t r r r --r t COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 19-AUG-87 File No : BP-3-1223 KRU #3M-16 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : Full Diameter Core Analysis SAMPLE DEPTH CONFINING HORIZ Ka - (MD) VERT He GRAIN NUMBER FEET PRESSURE MAX Ka 90 DEG Ka (MD) POR DEN M. DESCRIPTION -- - .. .. .... eo.. .. .. ...., ........ .. ...... .. .. ...... ... .. .. .. ..- .. .. .. , .. _....- -..... --.......... --........ ..--- .- 108 7587.2 400 1.598 0.878 0.489 13.0 2.69 MDST - M-DKGY,V SDY,5-7% CGR-GRNLS,P FISS,SL CALC,MOD-WELL CONS 1000 0.255 0.201 0.049 12.2 1500 0.096 0.050 0.013 11.8 2000 0.042 0.036 0.007 11.5 113 7592.6 400 0.375 0.395 0.127 13.0 2.88 SS - GYGRN,LTBRN,VF-CGR,PRE FGR,1% GRNLS,SLTY,SL CALC,WELL CMTD,POSS SID-ANK CMT, 1000 0.229 0.207 0.078 12.2 40-50% LTBRN CMT FILL BUR 1500 0.188 0.152 0.055 12.1 2000 0.143 0.136 0.046 12.0 115 7594.6 400 0.826 0.614 0.732 12.6 2.94 SS . GYRRN,LTBRN,VF-CGR,PRED FGR,SLTY,SL CALC,WELL CMTD,POSS SID-ANK CMT, 1000 0.600 0.456 0.624 12.5 50% LTBRN CMT FILL BUR 1500 0.562 0.429 0.593 12.3 Kmax - FRACTURE(S) INFLUENCES PERMEABILITY 2000 0.504 0.382 0.569 12.0 119 7598.4 400 0.896 0.597 0.536 15.0 2.88 SS - GYGRN,LTBRN,VF-CGR,PRED FGR,SLTY,1% GRNLS,SL CALC,WELL CMTD,POSS SID-ANK CMT, 1000 0.788 0.538 0.490 15.0 30-40% LTBRN CMT FILL BUR 1500 0.667 0.441 0.460 14.9 Kmax FRACTURE(S) INFLUENCES PREMEABILITY 2000 0.620 0.408 0.449 4.9 L }- -L L î- L Detailed Lithological Sample Descriptions . .- L . .;... .l... , ~ - --- 1 1- L Detailed Lithological Descriptions , I-> '-- Lithological descriptions were performed on plugs removed from KRU #3M-16 whole core samples submitted by Arco Alaska, Inc. These are conventional descriptions using a binocular microscope, hand lens, grain size scales, and a comparison chart for percentage estimation and roundness determination. The following format was used for describing these samples: , ~......., Sandstones , "- 1.) Color 2 .) Grain size 3 .) sorting 4.) Roundness 5.) Cementing and/or degree of consolidation 6.) Minerals present 7.) Percent (%) minor rock type B.} Sedimentary structures or features 9.} Fracture descriptions .,.... .-.. Mudstones/Shales/siltstones ~ --. 1.) Color 2.) Grain size modifiers 3.) Cementing and/or degree of consolidation 4.} Accessory minerals 5.} Percent (%) minor rock type 6.) Sedimentary structures or features 7.) Fractures descriptions r-- - '- L Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska ~ }...-, 101 7580.3 102 7581.8 L 103 7582.6 ~, 1... 104 7583.5 105 7584.5 , --- 106 7585.3 ,..- 107 7586.4 - 108 7587.7 109 7588.2 110 7589.5 111 7590.5 ,.- Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. crosky Detailed Lithological Description Mudstone gyblk, slty, well cons, pyr fos, horz pyr filled frac, approx .1mm in width. Mudstone gyblk, slty, tr vfgr sd, well cons, sl fis (desc. from near retort sample) Mudstone gyblk, slty, tr vfgr sd, well cons, pyr filled, bur (desc. from core near retort sample) Mudstone gyblk, slty, sdy, f-mgr sd, well cons (desc. from core near retort sample) Mudstone gyblk, v sdy, m-cgr sd, well cons, sd consists of well rd qtz, glauc, and carb material, abnt cgr qtz ovgths, pyr filled foss, bed parallel break. Mudstone gyblk, v sdy, m-cgr sd, well cons, sd consists of well rd, qtz, glauc, and carb material, abnt cgr qtz ovgths, pyr filled burrows and fos, bed parallel break Mudstone gyblk, v sdy, m-cgr sd, well cons, sd consists of well rd, qtz, glauc, and carb material, abnt cgr qtz ovgths, pyr filled burrows and fos, bed parallel break siltstone It olvgy, v sdy, m-vcgr sd, well cons, graiding to a m-cgr slty ss, sd consists pred of ang-rd, glauc and qtz with ovgths, some granule size qtz siltstone ltgy, v arg, tr-1% vf-fgr sd, well cons, thn bed of f-mgr glauc sd, mnr qtz ovgths present. Mudstone It ovlgy, slty, tr fgr sd, sl calc, well cmtd, dnse, poss sid-ank cmt, tr glauc, tr qtz with ovgths siltstone m-ltgy, arg, 1-2% vf-fgr sd, sl calc, well cons, mic, tr pyr fos L L Arco Alaska, Inc. KRU #3M-16 Kuparuk River Unit North Slope, Alaska L ,1-. 112 7591.4 ~ ...... 113 7592.4 L L 114 7593.5 1 ~ 1 - 115 7594.5 116 7595.8 ~ 117 7596.5 118 7597.4 r" - Date : ll-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description siltstone m-ltgy, arg, 3-5% vf-mgr sd, sl calc, well cons, v mic, tr glauc, tr-1% carb frags, bed parallel break Sandstone dusky gy, vf-cgr, pred m-cgr, well cmtd, v dnse in places, sl calc, mod srtd, sbang-rd, composed of 40-50% dense ye1 brn cmt, poss sid-ank, 30% glauc, 10-20% qtz, 5-10% sIt, qtz ovgths presents Sandstone It olvgy, gy grn, f-cgr, pred mgr, abnt sIt, well cmtd, poss sid-ank cmt, sl calc, mod srtd, sbang-rd, composed of 15-20% glauc, 10-15% qtz, 40-60% sIt mtrx Sandstone gygrn, It olvgy, vf-cgr, pred f-mgr, slty, well cons, poss sid-ank cmt, sl calc, mod srtd, sbang-rd, composed of 30-40% glauc, 20-25% qtz, 15-20% sIt, 10-20% dnse cmtd bur, qtz ovgrth presents Sandstone gygrn, It olvgy, vf-cgr, pred f-mgr, slty, well cons poss sid-ank cmt, sl calc, mod-well srtd, sbang-rd, composed of 20-30% glauc, 20-30% qtz, 10-20%slt, 20-25% dnse cmtd bur, vug, qtz ovgths presents Sandstone gygrn, vf-cgr, pred vf-mgr, slty, well cons, poss sid-ank cmt, sl calc, mod- well srtd, sbang-rd, composed of 20-30% glauc, 20-40% sIt, 10-20% qtz, 10-15% dnse cmtd bur, qtz ovgths present Sandstone gygrn, It olvgy, vf-cgr, pred f-mgr, slty, well cons, poss sid-ank cmt, sl calc, mod-well srtd, sbang-rd, composed of 20-20% glauc, 20-40% qtz, 20-30% sIt, 10-15% dnse cmtd bur, abnt qtz ovgths present 1 ¡-- Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska ..I, ~ '- ~ 119 7598.3 120 7599.3 , ..... 1 f-- 121 7600.5 ~ 122 7601.7 123 7602.2 - 124 7603.6 125 7604.5 126 7605.4 127 7606.7 ,- Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. crosky Detailed Lithological Description Sandstone gygrn, It olvgy, vf-cgr, pred vf-fgr, slty, well cons, poss sid-ank cmt, mod srtd, sbang-rd, composed of 30-50% glauc, 20-40% qtz, 1-5% sIt, tr-1% pyr bur, abnt qtz ovgths Sandstone gygrn, vf-cgr, pred f-mg, tr sIt, mod- well cons, poss sid-ank cmt, mod srtd, sbang-rd, composed of 30-50% glauc, 20- 40% qtz, 1-5% sIt, tr-1% pyr bur, abnt qtz ovgths Mudstone It olvgy, 30% yelgy dnse sltst, poss sid -ank cmted, mdst is well cons sl calc siltstone 1tbrn, 15-25% gyb1k, sl calc, thn1y intbd mdst, sltst is sdy, well cons, grades to a vfgr, slty ss, horz open to closed frac Sandstone ltbrn, 10-15% gybld thnly intbd mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 70-90% qtz, 10- 30% sIt, tr mica Mudstone ltolv-olvgy, slty, sl calc, v well cmtd, dnse, poss sid-ank cmtd, bdd Mudstone gyblk, 40-50% ltbrn vf-fgr, slty well cons intbd ss, composed pred of qtz, and sIt, mdst is slty, sdy in places, sl calc, 1-3% mica, bioturb present, sample broken Sandstone ltbrn, 25-30% gyblk, slty mic, sl calc, well cons, intbd mdst, ss is vfgr, v well srtd, sbang-rd, well cons, composed of 80-90% qtz, 10-20% sIt, bioturb present Sandstone ltbrn, 20-30% gyblk, slty, sl calc, thinly intb mdst, ss is vfgr, slty, well srtd, sbang-rd, mod cons composed 70-90% qtz, 10-30% sIt, horz open frac ~ L Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska ~ 128 7607.7 129 7608.7 130 7609.7 1 ..-0 131 7610.5 132 7611.2 133 7612.7 134 7613.4 135 7614.3 201 7617.7 Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone ltbrn, 20-30% grblk, slty, sl calc, thnly intbd mdst, ss is vfgr, slty, well srtd, sbang-rd, mod-well cons composed of 80-90% qtz, 10-20% sIt, tr mica Sandstone ltbrn, vfgr, slty, well srtd, sbrd-rd, mod cons, composed of 70-90% qtz,10-30% sIt, mnr bd mdst Sandstone ltbrn, vfgr, mnr sIt, v well srtd, sbrd- rd, mod cons-sl fri, composed of 90% qtz, 10% sIt, mnr indistinct mdy lams, horz open frac in sd Sandstone ltbrn, vfgr, slty v well srtd, sbrd-rd, mod cons-sl fri, composed of 80-90% qtz, 10-20% sl~, 1-3% mica Sandstone ltbrn, 5-7% gyblk carb, mdy lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, mod cons-sl fri, composed of 80-90% qtz, 10- 20% sIt, 2-5% mica Sandstone ltbrn, vfgr, slty, v well srtd, sbang- rd, mod cons-sl fri, composed of 60-80% qtz, 20-40% sIt, 3-5% mica, mnr indistinct mdy lams (sculptured sample) Sandstone ltbrn, vfgr, slty, v well srtd, sbang- rd, sl fri, composed of 70-90% qtz, 10- 30% mica, 3-5% mica, 7% mica in places, mnr mdy lam (sculptured sample) Sandstone ltbrn, vfgr, slty, v well srtd, sbang- rd, sl fri, composed of 70-90% qtz, 10- 30% sIt, 3-5% mica, 7% mica in places, mnr mdy lams Mudstone gyblk, 30-50% ltbrn, vfgr, slty, v well srtd, sbang-rd, mod-well cons, intbd ss, composed pred of qtz and sIt, mdst is slty, sl calc, and v mic in places , ¡>-- L Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska L ,L. 202 7618.4 , 203 7619.4 L L 204 7620.6 205 7621.5 206 7622.8 207 7623.7 208 7624.2 209 7625.5 - Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. crosky Detailed Lithological Description Sandstone ltbrn, vfgr, mnr sIt, v well srtd, sbrd- rd, mod cons-sl fri, composed of 80-90% qtz, 5-10% sIt, 3-5% mica, tr mdy lams Sandstone 1tbrn, 20-25% gyb1k, sl calc, thn1y intbd mdst, ss is vfgr, abnt sIt, v well srtd, sbang-rd, well cons, composed of 60-80% qtz, 20-40% sIt, 1-3% mica, thn bdds of vfgr ss with little silt present Sandstone ltbrn, vfgr, mnr sIt, v well srtd, sbrd- rd, mod cons, composed of 80-90% qtz, 10-20% silt, 3-5% mica in places, tr indistinct mdy lams Sandstone ltbrn, 15-20% gyblk, slty, sl calc, wvy lam mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 70-80% qtz, 20-30% sIt, 1-3% mica Sandstone ltbrn, 20-25% gyblk, pred arg, slty, sl calc, thnly intbd mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 70-80% qtz, 20-30% silt, 1- 3% mica Mudstone gyblk, 30-40% It gybrn, sdy, well cons interbd sltst, 5-10% ltbrn vfgr, slty, thnly intbd ss, mdst is sl calc, well cons, mnr bioturb, horz open frac Mudstone gyblk, 20-30% ltbrn, vfgr, slty, well cons, sdy bur, mdst is sdy in places, sl calc, well cons, hvy bioturb, horz open frac Sandstone ltbrn, 15-20% gyblk, sl calc, well cons, intbd mdst, ss is vfgr, mnr sIt, v well srtd, sbang-sbrd, mod-well cons, composed of 70-90% qtz, 10-30% sIt, tr- 1% mica, bed parallel break 1 1- L Arco Alaska, Inc. KRU #3M-16 Kuparuk River Unit North Slope, Alaska ~ ,1-.. 210 7626.9 L L 21i 7627.3 L 212 7628.5 ~ r'- 1 ,-'-, 213 7629.6 214 7630.9 1 ~ 215 7631.6 216 7632.6 217 7633.6 Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone ltbrn, 20% grblk, sl calc, well cons, intbd mdst, some mdy lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, well cons composed of 80-90% qtz, 10-20% sIt, 1-3% pyr blebs, 1-3% mica in places, bed parallel break Mudstone gyblk, 40-50% ltbrn, vfgr, slty, v well srtd, sbang-rd, well cons, intbd ss, composed pred of qtz and sIt, mdst is sdy in places, sl calc, well cons, 3-5% mica, bioturb Sandstone ltbrn, 15-20% gyblk, sl calc, thnly intbd mdst, ss is vfgr, slty, v well srtd sbang-rd, well cons, composed of 70-90% qtz, 10-30% sIt, 1-3% mica, some sdy burrows Mudstone gyblk, 10-15% ltbrn, vfgr, sdy bur, composed of qtz, mdst is sdy in places sl calc, well cons, pyr fos, horz frac Sandstone yelbrn, vfgr, mnr sIt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1-3% mica, mnr indistinct mdy lams Sandstone yelbrn, 15-20% gyblk, sl calc, lam mdst, ss is vfgr, mnr sIt, v well srtd, sbrd- rd, sl fri, composed of 80-90% qtz, 10- 20% silt, 1-3% mica Sandstone yelbrn, 5% gyblk mdst lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1- 3% mica Sandstone yelbrn, 5% gyblk mdst lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1- 3% mica, 1-2% pyr blebs ,.- , , Arco Alaska, Inc. KRU #3M-16 Kuparuk River Unit North Slope, Alaska 2~8 7634.3 2~9 7635.4 220 7636.8 ,...- 22~ 7637.4 222 7638.4 223 7639.~ 224 7640.2 225 764~.8 226 7642.4 227 7643.6 Date : 1~-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T~3N-R8E-Sec 25 File : BP-3-l223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone yelbrn, 10% gyblk mdst lams, ss is vfgr, mnr slt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1- 3% mica, mnr bioturb Sandstone yelbrn, 5-~0% gyblk mdst lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, ~0-20% silt, ~-3% mica, 3-5% mica in places Sandstone yelbrn, ss is vfgr, mnr slt, v well srtd, sbrd-rd, fri, composed of 90% qtz, 10% silt, 1-3% mica, tr lams Sandstone yelbrn, ss is vfgr, mnr slt, v well srtd, sbrd-rd, fri, composed of 90% qtz, ~O% silt, ~-3% mica, tr lams Sandstone yelbrn, ss is vfgr, mnr slt, v well srtd, sbrd-rd, sl fri, composed of 90% qtz, ~0-20% silt, ~-3% mica, tr lams Sandstone yelbrn-ltbrn, 5-10% gyblk, sl calc, thnly intbd mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 60-80% qtz, 20-40% slt, tr-~% mica, tr pyr Sandstone yelbrn, vfgr, mnr slt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, ~0-20% slt, ~% mica, tr mdy lams Sandstone yelbrn, vfgr, mnr slt, v well srtd, sbrd-rd, sl fri, composed of 80-90% qtz, ~0-20% slt, ~% mica, tr mdy lams Sandstone yelbrn, ~~% gyblk, sl calc, thnly intbd mdst, ss ~s vfgr, slty, v well srtd, sbrd-rd, mod-well cons, composed of 60- 80% qtz, 20-40% sIt, tr-~% mica Sandstone yelbrn, vfgr, mnr slt, v well srtd, sbrd-rd, fri, composed of 90% qtz, ~O% slt, tr-~% mica ~ , ~ Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska L 1 L 228 7644.2 1 ,j- 229 7645.3 L 230 7646.4 231 7647.1 -- 232 7648.7 233 7649.1 234 7650.4 235 7651.2 236 7652.6 Date : 11-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone yelbrn, vfgr, mnr sIt, v well srtd, sbrd-rd, fri, composed of 90% qtz, 10% sIt, tr-1% mica, 3-5% mica in places siltstone o1vgy, 5-10% ltbrn, vfgr, interbdd ss, sltst is v sdy, arg, sl calc, well cons, poss sid-ank cmtd, bed parallel break Sandstone yelbrn, 10-15% gyblk mdy lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, sl fri-fri, composed of 80-90% qtz, 10-20% sIt, 1-3% mica Sandstone yelbrn, 1-5% gyblk mdy lams, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, fri, composed of 90% qtz, 10% sIt, 1-3% mica Sandstone ltbrn, 15-20% gyblk, mic, sl calc, intbd mdst, ss is vfgr, slty, v well srtd, sbrd-rd, mod well cons, composed of 70- 90% qtz, 10-30% silt, tr-l% mica, bed parallel break Sandstone It-mbrn, 10-15% gyblk, mic, sl calc, bioturb mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 60-80% qtz, 20-40% sIt, 3-5% mica 3-5% pyr bleb Sandstone yelbrn, vfgr, mnr sIt, v well srtd, sbrd-rd, fri, conposed of 80-90% qtz, 10-20% sIt, 1-3% mica, broken sample Sandstone yelbrn, vfgr, mnr sIt, v well srtd, sbrd-rd, fri, composed of 80-90% qtz, 10-20% sIt, 1-3% mica Sandstone yelbrn, vfgr, 5% gyblk, sl fri, thn bdd mdst, ss is vfgr, mnr sIt, v well srtd, sbrd-rd, fri, composed of 80-90% qtz, 10-20% sIt, 1-3% mica 1 r- j Arco Alaska, Inc. KRU #3M-16 Kuparuk River Unit North Slope, Alaska }- , J L-- L 237 7653.7 1 i-- 238 7654.3 L 239 7655.4 L 240 7656.7 - 241 7657.2 242 7658.6 - 243 7659.3 244 7660.2 245 7661.5 Date : ll-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone yelbrn, 5% mdy lams, vfgr, mnr sIt, v well srtd, sbang-rd, sl fri, composed of 70-90% qtz, 10-30% sIt, 3-5% mica Sandstone yelbrn, 5% mdy lams, vfgr, mnr sIt, v well srtd, sbang-rd, mod cons, composed of 60-80% qtz, 20-40% sIt, 1-3% mica Sandstone yelbrn, 5% mdy lams, vfgr, mnr sIt, v well srtd, sbang-rd, mod cons, composed of 70-90% qtz, 10-30% sIt, 3-5% mica, lams Sandstone yelbrn, 5% mdy lams, vfgr, mnr sIt, v well srtd, sbang-rd, mod cons, composed of 70-90% qtz, 10-30% sIt, 3-5% mica, tr-1% pyr Sandstone 1tbrn, 20% gyblk lam mdst, ss is vfgr, slty, v well srtd, sbang-rd, mod-well cons, composed of 70-90% qtz, 10-30% sIt, 1-3% mica, tr pyr Sandstone It olvgy, vfgr, calc, well cmtd, dnse, poss sid-ank cmt, grades to a well cmtd sdy sltst Sandstone yelbrn, vfgr, slty, v well srtd, sbrd- rd, sl fri, composed of 70-90% qtz, 10- 30% silt, 1-3% mica, 1-2% vfxl dism pyr Sandstone yelbrn, 20-25% gyblk, sl calc, thkly lam mdst, ss is vfgr, slty, v well srtd, sbrd-rd, well cons, composed of 70-90% qtz, 10-30% sIt, 1-3% mica, 1-2% pyr bleb Sandstone yelbrn, 20-30% gyblk, sl calc, thkly lam mdst, ss is vfgr, slty, v well srtd, sbrd-rd, well cons, composed of 70-90% qtz, 10-30% sIt, 1-3% mica, horz hairline frac , --- l~ Arco Alaska, Inc. KRU #3M-16 Kuparuk River unit North Slope, Alaska 1 >--- 246 7662..'5 247 7663.4 248 7664.4 249 7665.2 250 7666.6 251 7667.7 252 7668.4 253 7669.5 Date : ll-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone ltbrn, yelbrn, vfgr, slty, v well srtd, sbrd-rd, mod well cons, composed of 70- 90% qtz, 10-30% sIt, 1-3% mica, 5% mica in places, tr mdy lam Sandstone ltbrn, 15-20% gyblk mdst lams, ss is vfgr, slty, v well srtd, sbrd-rd, mod cons, composed of 80-90% qtz, 10-20% sIt, tr-l% mica, sub vertical open fracs Sandstone ltbrn, 20-25% gyblk, v slty, sdy, sl calc, thnly intbd mdst, ss is vfgr, slty, v well srtd, sbang-rd, well cons, composed of 70-90% qtz, 10-30% sIt, tr- 1% mica Sandstone Itbrn, 20-25% gyblk, sl calc thnly intbd to lam mdst, ss is vfgr, v slty, v well srtd, sbang-rd, well cons, composed of 60-80% qtz, 20-40% sIt, 1-3% mica, tr pyr, grades to a ss with 10-20% sIt Mudstone gyblk, 40-50% ltbrn, vfgr, slty, v well srtd, sbang-rd, well cons, bioturb, ss composed pred of qtz, mdst is slty, sdy in places, sl calc, well cons, with 1-3% mica, tr pyr Mudstone gyblk, 40-50% ltbrn, vfgr, slty, v well srtd, sbang-rd, well cons, bioturb, ss composed pred of qtz, mdst is slty, sdy in places, sl calc, well cons, with 1-3% mica, 1-3% pyr blebs Mudstone gyblk, 40-50% ltbrn, vfgr, slty, v well srtd, sbang-rd, well cons, bioturb, ss composed pred of qtz, mdst is slty in places, sl calc, well cons, with 1-3% mica, 3-5% pyr blebs, horz open frac Sandstone ye1brn, ltbrn, vfgr, sl slty, v well srtd, sbang-rd, well cons, composed of 70-90% qtz, 10-30% sIt, tr-1% mica, tr indistinct lams 1 ~ L Arco Alaska, In(~. KRU #3M-~6 Kuparuk River Unit North Slope, Alaska J ~ 1 '----- 254 7670.6 255 7671.2 , 256 7672.5 , ~ 257 7673.7 258 7674.3 259 7675.7 301 7676.6 302 7677.8 Date : ~1-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-l223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description siltstone olvblk, 20% gyblk, slty, mic, sl calc, lam mdst, 10-15% ltbrn, vfgr, slty, lam ss, sltst is v sdy, arg, well cons, grades to a vfgr ss, 1-3% pyr blebs, bioturb Sandstone yelbrn, ltbrn, 15-20% gyblk, sdy in places, sl calc, bioturb mdst, ss is vfgr, slty, v well srtd sbang-rd, mod well cons, composed of 70-90% qtz, ~O- 30% sIt, tr-l% mica, tr pyr in mdst, mnr sdy bur Sandstone ltbrn, 15-20% gyblk, sdy in palces, sl calc, pyr, bioturb mdst, ss is vfgr, slty v well srtd sbang-rd, mod-well cons, composed of 70-90% qtz, 10-30% slt, tr-l% mica, tr pyr in mdst, mnr sdy bur Mudstone gyblk, 20-30% ltbrn, vfgr, slty, v well srtd, sbang-rd, bioturb ss, mdst is v sdy in places, sl calc, mic, well cons, 1-3% pyr Mudstone gyblk, 20% ltbrn, vfgr, slty, v well srtd, sbang-rd, bdd ss, mdst is sdy in places, sl calc, mic, well cons, with abnt bioturb Mudstone gyblk, 20-30% ltbrn, vfgr, slty, v well srtd, sbang-rd, bdd, bioturb ss, mdst is sdy in places, sl calc, mic, well cons, with abnt bioturb, tr-l% pyr fos Mudstone gyblk, 5-10% ltbrn, bioturb ss, mdst is slty, sl calc, well cons, tr mica Mudstone gyblk, 30-40% ltbrn, vfgr, slty, v well srtd, sbang-rd, well cons, thnly intbd ss, composed of 70-90% qtz, 10-30% sIt, 3-5% pyr, mdst is sl calc, with some bioturb L Arco Alaska, Inc. KRU #3M-16 Kuparuk River u~it North Slope, Alaska L L L 303 7678.5 304 7679.6 ~ ...... L 305 7680.7 1 .... 306 768~.8 307 7682.3 308 7683.3 309 7684..3 3~0 7685.5 3~~ 7686.75 Date : ~~-Aug-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T~3N-R8E-Sec 25 File : BP-3-~223 Lab : Anchorage Geologist : G. Crosky Detai~ed Litbo~ogica~ Description Mudstone gyblk, 20-30% ltbrn, vfgr, s~ty, v well srtd, sbang-rd, well cons, thkly lam ss, mdst is slty, sl calc, tr pyr, horz open frac Mudstone gyblk, 30-40% ltbrn, vfgr, slty, v we~l srtd, sbang-rd, we~~ cons, thkly ~am ss, mdst is slty, sl calc, tr pyr, horz open frac Mudstone gyblk, 20-30% It-mbr, vfgr, v slty, v well srtd, sbang-rd, well cons, bioturb ss, mdst is mic, sl calc, well cons, ~- 3% pyr in ss, horz open frac Mudstone gyblk, slty, mic, sl calc, we~l cons, tr pyr, 5% sdy bur, horz hair~ine frac Mudstone gyblk, 20-25% ltbrn, vfgr, slty, well srtd, sbang-rd, well cons, lam ss, mdst is slty, sl calc, well cons, tr-~% pyr, a little bioturb Mudstone gyblk, 20-25% ltbrn, vfgr, slty, well srtd, sbang-rd, well cons, lam ss, mdst is slty, sl calc, well cons, tr-~% pyr, ~-3% pyr filled bur Mudstone gyblk, 40-50% ltbrn, vfgr, slty, well srtd, sbang-rd, well cons, bioturb, lam ss, mdst is slty, sl calc,mic, borz open frac Mudstone gyblk, 20-30% ltbrn, vfgr, slty, well srtd, sbang-rd, well cons, bioturb, lam ss, mdst is slty, sl calc, mic, 19 pyr mass, horz open frac Siltstone ltbrn-olbgy, ~5-20% gyblk, slty, sl calc, bdd mdst, sltst is v sdy, well cons, grades to a vfgr, slty ss, 3-5% pyr mass L Arco Alaska, Inc. KRU #3M-16 Kuparuk River Unit North Slope, A1¿:tska L , "- 312 7687.4 1 - 313 7688.6 1. 314 7689.5 1 .... 315 7690.3 ~ 316 7691.0 Date : 11-Aug-87 Formation : Kuparuak Dr1g F1d : Bland Mud Location : T13N-R8E-Sec 25 File : BP-3-1223 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone 1tbrn, 20-30% gyb1k, sl calc, well cons, bdd mdst, ss is vfgr, v slty, v well srtd, sbang-rd, well cons, composed of 60-80% qtz, 20-40% slt, tr pyr Mudstone gyb1k, 5-10% 1t-mbr, vfgr, slty, lam ss, mdst is slty, sdy in places, sl calc, well cons, mnr sdy bur Mudstone gyb1k, slty, sl calc, well cons, 1-3% pyr foss, 1-3% sdy burs, bioturb, broken sample Mudstone gyb1k, 5% ye1gy, lam sltst, mdst is mnr slt, blocky, mic in places, sl calc, well cons, 3-5% pyr in sltst, broken sample Mudstone gyb1k, mnr slt, sl calc, well cons, tr pyr, tr slty lams, broken sample L Littan Core Lab L L L l. l. l.. 1 ,¡.., 1 ... - - 8005 Schoon Street Anchorage, Ataska 99518- 3045 (907) 349·3541 SECTION C Core Analysis Results - Graphic Data Areo Alaska, Inc. KRU #3M-16 Kuparuk Formation Kuparuk River unit North Slope, Alaska 1 j- Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518-3045 (907) 349-3541 L J \.... j 1 I .. j SECTION D APPENDICES L - Areo Alaska, Inc. KRU #3M-16 Kuparuk Formation Kuparuk River Unit North Slope, Alaska l ... - - - - - - r . F¡ ) I r r.... ' [;~ J ~'r Refractive Index vs. API Gravity Kuparuk Formation '" ~ I """ ~ " ~ ,- ~ ~ ~ "- "- '" ~ ~ "- ",- "'. ~ "",- "- ~ ~ 30 29 28 27 26 25 24- 23 22 21 20 19 18 17 16 15 14- 13 12 '" Ii. . " , Q c Q) '\J ~ ~ .-4 Þ- .. k C ÞOI ~ 1.ð3 1.4-9 l.ðl Refractive Index (Retorted au) 1.4-7 ;(..~; , - J' ]~ 1 ~- OIL CORRECTION CHART l,.o.... j Kuparuk oil Correction Table oil Based and Water Based Cores ,- ¡ , Observed Tr- Tr+ 0.10 0.20 0.30 0.40 0.50 0.60 0.70 0.80 0.90 1.00 >1. 00 Correction 0.05 0.10 0.25 0.35 0.45 0.60 0.70 0.80 0.90 1. 05 1.25 1.40 +0.40 ,~ j J l.... i ,- '- ~ ....... i- ~ ""'" -" - -, , ~',' " ~, ~.~,~ ¡. . .,~ 'it.. i .', ]... , .... SPE 15185 SPE SocIetu of PetroIelIn Engneers r- I Automated Core Measurement System for Enhanced Core Data at Overburden Conditions .. by O.K. Keelan, Core Laboratories Inc. SPE Member . Copy"ght 1986. Society ot Pelroleum Engineers This paper was prepared for presentalton at the Rocky MountaIn Regional Meeting of the SocIety of Pelroleum Engineers held 10 Billings. MT. May '9-21, '986 This paper was selected for presentation by an SPE Program Committee following review 01 informatIon contained in an abstract submitted by the autho,(s}. Contents of the paper, as presented. have nOI been revtewed by the Society of Pe1roleum 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. Of members. Papers presented at SPE meetings are subject to publication 'eview by Edrto,ial Comml1lees of the Society of Pefroleum Engineers, Permission to copy is restricted to an abstract of not more than 300 words, Illustrations may nof be cop¡ed, The abstract should contain conspiCuous acknowledgment of where and by whom the paper is presented, Write Publications Manager. SPE. P,O, BeK 833836, RIChardson. TX 75083-3836, TeleK, 730989, SPEDAL. .. . ABSTRACT lIt A new automated, computer-directed, core me;is- 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 ror 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 burial, and subsequent compression of the rock pore spaces. Core cutting and retrieval relieves tbe 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 in gas slippage and air permeability values that were higher than at reservoir pressures. Cor- rections for this slippage effect were often applied by using published correlations for uniform sand- stones, and ignored in more heterogeneous carbonates where correlations were not valid. Low permeability ~ ~ - References and ll~.tratlon. at end of paper. "" '", "..~' ," 'c' , " .',' ',' .' ',,: _ .: 'i'. .:. _;/~~;?~~:;.~,;'<:><;// '" formations have focused attention on the importance of both slippage correction and overburden effects.1,2 The new automated, core measurement system offers a first-time capability to routinely and economically measure porosity and permeability at simulated over- burden stress conditions, while simultaneously meas- uring the gas sl1.ppage corrected equivalent 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-diagnosis of valve leak problems if present. Core sequencing and movement into a hydrostatic core holder, application of up to eight selected sequential overburden pressure meas- urements, interim data display while testing, calcu- lations and final data presentation are performed automatically while under IBM PC control. Pore volume is directly measured by helium injection into the pore space, while permeability and turbulence factor are determined during unstead~-state flow utilizing principles described by Jones. REVIEW OF FACTORS LIMITING ROUTINE CORE DATA Gas Slippage Effects Gas slippage effects were documented by K1inken- berg4, and the effect he observed is illustrated on Fig. 1. Unlike non-reactive liquid flow, where permeability of a rock is a constant, gas perme- ability is seen to vary linearly with the reciprocal mean pressure in the core. Mean pressure is defined as the average of the up-stream and down-stream pressure of the rock sample during flow. It is analogous to tbe formation pressure. At increasing mean pressures the gas molecules are forced closer together such that the gas becomes more dense, behaves more like a liquid, and has a lower measu red perme- ability. At infinite mean pressure, the reciprocal of Pmeen equals zero and the gas is visualized GO hGVlnx ~ondçnøed and GO tlow~ng l~kc on c~viy.lcn' inert liquid. 155 , .. . ,... ;, )~ 4 AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN œmmONS ',,-. '., -..---'~ '.~ ',,1.' -¡~ . Sample Consolidation ,: 1. Host tests to date have been made on consolidated cores. Limited data indicate that unconsolidated rock mounted in shrinkable tubinglO can be run in the device. Investigation of applicability to these type cores as well as metal jacketed samples is yet to be completed. ,- j Core Saturation Condition '¡.. 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 O.O-Swir) reduction due to overburden will be invalid and masked if the volume seen by injected helium increases due to evaporation. l¡e. ".. '- 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 resul ts 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 (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 porosity point. 11 - - ; , .- , - 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 + 51 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. """ l - Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state air - permeability measurements. 'Ibe t1fference shown 1. expressed as a percentage of t~ steady-state value. Three measurelllents are presenteoi for each sa.ple to illustrate reproducibility. Thf.:.au indicate three salllples with a difference gr&::u than 5% of the standard value. Two are lower ?,,::.eability samples, of less than one millidarcy. ~ + 5% limit was set for higher permeability sample~, ãnd the tolerance is normally expanded in the l~:: range because of the small values measured an¿ $ensitivity to !llean pressures in the core as permea::::' i ty becomes lOlorer. For example, if the true air =~:-1Iea~il1ty value is 0.020 millidarcies and the t~>:=~ value found is 0.025, an error of 25% is h::~.!:¿d, although the magnitude of the difference "0 :"c"01sequential and the permeability in both caSE, :, çuite small. A much larger (100%) error resu::, : ~0~ the incorrect use of the air permeability "é:c-= ,Jf 0.02 to repre- sent reservoir permeability ra:-",~ :'13n the slippage corrected Klinkenberg value 0: determined for this plug. Figure 6 shows comparison~ zero stress meas- urements utilizing a small vol c¡::..: !>Orosimeter (SVP) versus core measurement sys teft :.: :Jsity data at 800 psi confining stress. Porosi:~:'-: the system has been calculated using various E:~~:ions that require different basic data. The zerc ,:~¿ss equation util- izes bulk volume determined ~¿rcury displace- ment (8VHg) and grain vOlumE 7~) ~easured in a U.S.B.M. modified Boyle's La~ E=:~ratus using helium as the gas. ø BV -GV Hg 1 : ')0 BVHg ............(1) The core œeasureœent system uses .;'~·,¡ations in decreas- ing order of preference as sho..-: ~elow. Pore volu.e (PV) is by direct injection, ~¿ bulk volume 15 determined by one of three tech~~es. ø E PV x - . - PV+GV ......... ...... (2) ø E PV x 1 n-. BVHg ................(3) ø - PV x 1(( LxA ._..............(4) In the Fig. 6 data set all poro£i:ies agree well witb mean porosity differences from ::~-= zero stress condi- tion of -0.2, -0.2 and -0.3 pc:~-;ity points respec- tively. Figure 7 presen ts i nd i Y: :cal sample porosi ty differences comparing values frc": ":qu<ltions 2, 3 and 4 with Equation 1. Equation 2 allows for a dec~ò',i"g bulk volume as confining stress increases. ::: ~:: ion 4 typically yields porosity values too 10\,,- _ ~.~ rounded corners or broken edges are often not ¡c,:::--=rly accounted for in length (L) and diameter meas:::~ents used to co.- pute area (A). This results ir ':-t~her bulk volu.es than true; bence, low porosities. Equations 3 and 4 can be mo~i=:ed 8S illustrated below to allow for decreasing b~:~ volume a8 confin- ing stress increases. 158 1.--- li .' i t~ '.:'~~.., 6 AUTOMATED CORE !œASUREKENT 'SYSTEM FOR' ENHANcED, CORE' DATA AT OVERBURDEN CONDITIONS :;,~<; , '. the jacketed sample. (i.e. system value of 7.4 x 10-6 versus 9.3 x 10-6 at 4000 psig and mucb better agreement at 2000 psi.) ]~ The system can furnish. large volumes of data rapidly which are likely to be much more representa- tive of a formation or its various rock types and lithologies than average correlations in the litera- ture. The data can and should be calibrated 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. ,- 1 1- ,. j Irreducible Water (Relative Permeability Effects) r 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 reservoir permeability in zones containing irreduci- ble water. ,- i ,.- , - The samples were then restored with oil and oil permeabil1ties were determined. 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 Swir equaled the dry core Klinkenberg value; conversely, 60% of the samples gave poor comparison. The cônc1u- 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. '-' :0.- ..... 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 co.pres- _ sibllity was approximately 62% of hydrostatic val- ues12. Anderson presented data cOIDpsringhydrostatic losding to unisxial, and equa tions to transform hydro- static pore volume compressibility to uniaxial strain conditionsl3. It follows that a hydrostatic pore voluae compression that is too high will result 1n ..- - a laboratory porosity reduction that .18 too high. Similat' results have beef! reported for permeability 14. If reservoir compression is only 62% of the laboratory value, tben tbe reduction in reservoir porosity should only be 62% of the lIIeasured hydrostatic laboratory válue. Nelson concluded perllleability could be derived from hydrostatic confining pressure tests by calcu- lating the lIIean stress in the reservoir and then reading tbe permeability value from the hydrostatic curve at the calculated lIIean subsurface stress1S. Both porosity and permeability data from the core measurement system can be normalized by dividing each overburden value by the initial value at 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 permea- 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 adjusted upward using Teeuw' 5 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 intersec tion is the equivalent mean stress on, the hydrostatic curve required to yield the reservoiruniax1al 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 de.ignating 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. 'f1." :~-'i-.\; ~:~,*-".',~. '. ' ". .' ~,'" ',t ".~.' '~ :.. ;1 'fj ~ i :: ~ 1 1 ! i j \ I ., ~ ~ 'I ~ ., , '_,'.... ,....- ~~'¡ 'I ~ ,. t " \ 'J J ~ J 1Ì ! i i 1 \ \ \ '. , ... - .. ~ - .{ . ~ ~. ~, 1-- I L .~ ". .",j~~r¥Š~~~~:·· ·,;~··~i.~f~. Keelan 7 '.::,-. ,SPÈ:l$lS'S 3. Klinkenbergslippage fa¿tora (b) -..-e essentially the same' or increased only slightl! in tbe .and- stones tested as overburden pre~ increased, and the presence of irreducible ~ter resulted in a decrease in (b) value. 4. The turbulence factor (Beta) increased .oderately in the sand stones tested as ove~en pressure increased and the presence of l~ible water had little, effect on its value. 5. A minimum confining stress of 800 p!:' 1s currently required for the system determine:: ¡:>orosity and permeability to equal (1) poros:':T values at zero stress ;md (2) air permeabE::~' \'alues at 400 psi confining stress now empl~~~ in routine core analysis. 6. Helium injection porosity measure:;."",:: :echniques routinely employed in Special Core ~c¿:~sis labo- ratories yield porosity values in ..'._ agreement with those measured on the system_ 7. Conformance of the rubber boot to :;...., core sur- face had little adverse effect or, ~::<ste:: poros- ity values at pressures above 80C :5i confining stress, and the jacketed and nor- ~.:,:keted core yielded similar values of poros:':! :hroughout the range of overburden pressures :'':lvestigated. 8. Pore volume compressibility of :,~ non-jack- eted core was extremely sensitive to boot con- formance at confining stress bel~ 2000 psi. Above this stress compressibilit:'~s approxi- mated true values. Compressibiliti.::.s determined on non-jacketed dry core should ::~ calibrated to best technique values by compantive _a sure- ments on jacketed, water saturated sa'Ples tested in a compressibility apparatus. 9. Hydrostatically confined porosity ua: permeabil- ity determined at selected net ov~-':1urdeo pres- sures and presented as a fractim: of original values allows approximation of b::t porosity and permeability at uniaxial strai3: conditions. Note: This is likely to be restric---ed to well- cemented cores whose behavior follows elastic theory. 10. The system can be used-,to measure 1Cl1nk.enberg gas permeablity with irreducible water 111 tbe core, and thereby verify whether dry c:=e slippage corrected permeability at confini~ stress is representative of gas flow with c~nate water present. 11. Applicability of the system Klinkenb~=~ gas perme- ability (with or without irreducib:~ water pre- sent) to represent oil penneabili:! (Ko) with irreducible water present must be verified by independent measurements of Ko. NOMENCLATURE It - permeability, ad .. KA - permeability to air, ad K... - Klinkenberg "Liquid" penleab il1t.y. wi b - Klinkenberg slippage factor, psi ,'...1... '<II:¡!'J.:.. -:::~;:;~:,"~~..:'>-,~, .: ;~~~::J~~~:.~:~ .: - . Pnean · arithaetié average~.~re..ure\t~fore~~p81a p - pressure t psia ' , '~_.r' '>~:'¡;<",J:~j;,"" ' .' L - length of flow path. ft ' , " V - velocity, ft/sec ß - Beta - turbulence factor, ft-1 U - gas viscosity, cp P - density of fluid, Ib mass/cu ft ACKNOWLEDGMENTS The author gratefully acknowledges the contri- bution of Brian Davis and Lisa Curry and those who developed and implemented the theory resulting in the automated core measurement system. REERENCES 1. Thomas. R. D. and Ward, D. C.: "Effect of Over- burden Pressure and Water on Cas 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, St.an A.: "Offshore Fracture Gradients," Soc. Pet. Eng. J. (Aug.. 1973) 910-914. 6. Breckels, J. H. and Van Eekelen, H. A. H.: "Rela- tionship Bet.ween Horizontal Stress and Depth 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., Coat.s, K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Cas Through Porous Reservoirs." J. Pet. Tech. (July, 1962) 799-806. 8. ~cLeod, 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. Eng. Chem., (1953) 10. Griffin, T. J. and Rush, D. C., "Core Analysis in Unconsolidated Reservoirs Using an Improved Consolidation Technique," 36th Annual Meeting of Petroleum Society of CHi, Edmonton, Alta., Paper So. 85-36-41, June 1985. 11. API-RP 40: Recommended Practice for Core Analysis Procedures. Aøerican PetroleUM Institute, Dallas. 12. Teeuw, D.: "Predictions of FOI'1ll&tlon Compaction fro.. Laboratory Compressibility Data," Soc. Pet. Eng. J. (1971) 11, 263-271~ 161 ,-. r':;' , t ,. ~, j 1 I- I I ; 1- 1 Q \.... '- .... - fl. - .-., .. - -- ,.c>~ ¡.- ..-... (.{!¡I~·~l;f,L' " AUTOMATED CORE MEASUREMENT SYSTEM FOR ENlÍAÑcED CORE xu,:::" :_ 8 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. M., 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 ~onograph 24, American Geophysical Union (1981) 311-321. 162'",<; .,.,,' :, ,~.'.'>;:1.';r~~"_ic-: .-, .~.:; ~"'~'~". . .'..; .....,'<..', :~;;~~~~~;j·~l~ti~f¡Jl~I~¡'Y;':' :rnœURDEHœøDIUœS SPE 15185 ~ ~ TMLE 1 A TYPICAL CXJRf: MEASURÐÐII' S'tS'nM CALIIlRATIaf NIl) REPEATABILITY ANALYSIS af STEEL fatE \IOLlI'Œ STAN1Wt1:6 Ia CDNI'INIIC S'mESS ~ ) J Con! inin¡¡ Stress PaiQ 1000 2000 3000 4000 5000 6000 STANIWUJ \OUX'!E . O. 195 cc Run 1 Run 2 Run 3 Run 4 RunS 0.207 (+.012) 0.193 (-.002) 0.188 (-.007) 0.184 (-.011) 0.180 (-.015) 0.175 (-.019) 0.230 (+.035) 0.222 (+.027) 0.217 (+.022) 0.213 (+.018) 0.210 (+.015) 0.207 (+.012) 0.223 (+.028) 0.215 (+.020) 0.210 (+.015) 0.206 (+.011) 0.203 (+.008) 0.201 (+.006) 0.224 (+.0:19) 0.215 (+.020) 0.211 (+.016) 0_207 (+.012) 0.204 (+.009) 0.202 (+.007) 0.222 (+.027) 0.213 (+.018) 0.209 (+.014) 0.206 (+.0111 0.203 (+.008) 0.200 (+.005) STANDARD IAJUJME . 1.021 cc þ 1000 1.017 (-.004) 1. 045 (+.024 ) 1.043 ( +.0221 J. 043 (+.0221 1.043 (+.022) 2000 1. 008 (-.013) 1. 035 (+.014) 1.034 (+.013) I. 034 (+.013) I. 034 (+.013) 3000 I. 002 (-.019) 1.031 (+.010) 1.03ú (+.009) I. 029 (+.0081 I. 029 (+.008) 4000 0.998 (-.0231 1.027 (+.006) I. 025 (+.004) 1. 025 (+.004 ) 1.025 (+.004) 5000 0.994 (-.027) 1. 023 (+.023) 1.022 (+.0011 1.023 (+.0021 1.022 (+.001) 6000 0.991 (-.030) I. 020 (+.020) 1.020 (-.001) 1. 020 (-.001) 1.019 (-.002) STAN[}\RIJ IAJUJ'IE = 3.099 cc 1000 3.101 (+.002) 3.123 (+.0341 3.131 (+.032) 3.128 (+.029) 3.129 (+.028) 2000 3.089 (-.010) 3.121 (+.022) 3_119 (+.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) 1-. l.. , ,..Þ. 1) 0tS ran overnight in aut.omatic JTOde in laboratory envi.rorment. ....ith variable tef1'{>erature. 2) Haxinum error of 0.035 cc W<>.Jld result in 0.27 por05ity perœnt point error in a """"Ie of 1 inch di......ter and 1 inch length (i.e. 10_0 to 10.27 por'Oßity percent). -- TABLE 2 '" ì STANDARt'6 OlEO< I~It«:; (X)RE I1EA'5URD1ENr SYSTEM PORE 1IŒ.I.JME N::OJf>N:{ AND CCflSISTENC\' B£l'WEEN LCCATIafS (AT 1000 PSIC CCflFINIt«:; S'mESS) - Standard Volumes ~ Aberdeen lnndon . Calqary* . IÆillas Denver ,I , ?f 0.195 0.545 1. 021 3.099 5_109 0.209 (+_014) 0.188 (-.007) 0.212 (+.017) 0.199 (+_004) 0.540 (-.005) 0.515 (-.030) 0.547 (+.002) 0.529 (-.016) 1.026 (+.005) 0.999 (-_022) 1.016 (-.005) 1.014 (-.007) 1.025 (+.004) 3.104 (+.005) 3.085 (-.014) 3.092 (-.007) 3.097 (-.002) 3.105 (+.006) 5.118 (+.009) 5.101 (-.008) 5.086 (-.023) 5.108 (+.001) 5_109 (0.000) !r. ... ~L ~ ~, -- ·After 1 year field trial in Aberdeen ·"Recalibration after field repair ~ :1 TABLE 3 <DRE MEASURÐ\Etl!' S'iSTÐI AIR PERMEABILITY ACOJAAC'i AND REPfATABILITY OIECK œ STE:EL STANDi'.RI:6 Steady Conti niog State Stress SantJle K Äver age Pslg Number Md Run 1 Run 2 Run 3 Error SOO A 1.09 1.05 1.05 1.05 -3.7\ 1000 A 1.04 1.05 1.04 -4.3\ SOO B 29.3 28.7 28.6 28.6 -2.3\ 1000 B 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\ SOO 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\ t I i ,--- , ;.-=-- I j po.. TABLE 4 TYPICAL Q)RE IV.5URDIÐll' SYSn)I (X]II£ Dt.TA AT <nIFINIIC S11IESS IUlJSTI1ATIIC cnlSISTmCY I!f:NfÐ INSTRLtIFm'S SAHPl£ A (w./ PERMEABILITY) Confininc;¡ Dallas (Run 1) Denver (~n 2)· Stre"" ! K Ka(est) b(lie) lleta ! K !(a (est ) b(lte) lleta Psig \ ....'!!L ~ ~ Fe1 ...L ....'!!L ~ ~ Fe1 500 10.7 .065 .141 ~.6 2.75x1013 10.7 _055 .130 66.6 1. 76x1013 800 10.6 .057 .132 63.2 2.96x1013 10.6 .052 .126 6J!.2 2.44xI013 1000 10.6 .054 .129 6ì.2 2. 74xlO 13 10.5 .052 .124 67.7 2.8lxlO13 2000 10.4 .053 .122 0.0 4.52x1013 10.4 _050 .118 65.7 3.68xl013 4000 10.2 .048 .114 ffj.8 4.05xl013 10.2 .047 .112 67.1 3.71 xl013 6000 10.1 .043 .109 -5.9 1. 51xlO13 10.0 .043 .109 74.0 1. 77x1013 SA'IPIL H ("'JDEMTE P£R"If:l\HII.ITY) 500 1" .6 33.9 37.3 .:. :;B 3.46xl08 19.3 33.4 36.7 4.BO 3.55xl0B HOD 19.3 32.8 36.2 ~. ~.; 3.65x108 19.1 32.4 35.6 4.B4 3.81xl0B 10UU 19.2 3;> .4 35.7 '. "5 J.80xl0B 19.0 32.0 3'>.1 4.110 3.93xl0B 2\)00 18.9 31.1 34 .2 ~. ~S 4.05xl08 18.6 30.7 33.7 4.~0 4.23x108 4000 18.S 29.6 32.6 S. J4 4.33x108 lB.3 29.2 32.1 4.88 4.54xl08 6000 l~. 3 28.5 31.5 ;.05 4.56x108 18.1 28.3 31.1 4.91 4.77xIOH ~ 1 -- , jA.. :-.. -Data set indicated ~re space at tin? 0: Run 2 had not fully rehounòed frcrn 6000 psi ~ressive force i"\~ several days earlier dJdng R:..:~ 1. ,.- H3L£ 5 IRR£!JJClBl£ WATER (RErAn'.,;: PER'lEA'JILITY £FF"OCT) 0>1 CüR£ MEASUR£!ID-IT SY~"Tf.11 KLlNKrnBERG PER"IF.AE::':TY i\.''D OIL P£RI1EABILITY AT CO-¡F"INIIC STRESS - a\S K Ii n~enberg Oil Permeabil i ty:md Pe~ability:m:t..· Sarrp1e !'oms i ty Swir Drv Core Core @ Sw'ir 1<0 @ Swir N\nber \ \PV 800' 4000' 800' ~ ~ 4000' 15.5 5.0 ~5 520 543 517 400 374 7.7 7.2 32.2 29.5 31.3 29.3 22.3 18.5 17.2 22.9 30.1 28.7 31.1 29.6 30.7 29.2 .- ·Conf ini ng Stress .. ·Steady-State Measurerænt TABLE 6 IRREWCIBU: WATER £ITOCI" 00 SUPPN:;E (bl fl\CI'OR AND 1URB\JLfNC£ (BcrA) FACTOR AT CO-¡FINIIC = - - Contini~ Dry Core Irreó.Jcible Sw z 22.9 \ PV Stress IJ b(fie) Betd b(lie) lleta Psig \ ~ ~ Psi ~ 500 17.4 4.90 2.84x108 4.11 2.81xl08 800 17.2 5.03 2.Blx10S 4.10 2.89xl08 1000 17.2 5.06 2.83x108 4.13 2.90x108 20UO 16.8 5.05 2.991<108 4.16 2.99xl08 4000 16.6 5.11 3.04xl08 4.27 3.06x108 6000 16.5 5_10 3.19xl08 4.30 3.15xl08 -- - t 1- ..l- i ~ ~ ~ ~ r ¡r j I ¡ ",,-_._~ ,~ ,6 ) 0 J . 6 1 CONfINING STRESS : T~$ANOS Of PSI fig. 3-POfOSlty and permeability va. confining Itress '(A.,- '\ J ...1 ~v·-~------ .... J 1 10 F~. .-permeeblllty .. a function of mean pre..ure. 00 .;' .;' /..... :::~... NON-REACTIVE LIQUID ,~:................................. . SLIPPAGE CORRECTED KLINK ENBERG PERMEABILITY >- t- -I CD <I: W ::E a::: w Cl. KA = Kcc SURFACE T OVERBURDEN PRESSURE 0.5 ~ I: ~ NET OVERBURDEN = \OVERBURDEN PRESSURE) - (RESERVOIR PRESSURE) NOB ~ DEPTH (1.off - 0.5 ~s~ ) ~ DE PTH \0.5 ~s: ) Fig, 2-Na' overburden preaaure VI. deplh. LOST FLOW RATE DUE TO TURBUL~_ ~j <I: a::: ~ 0 -J , U. ' 1- ~~ = V + + ß p V 2 J C PRESSURE DIFFERENTIAL .. Fig. 4-Effec11 ot turbulence on flow. l J , l 1 -L. P mean - ,.-. J ~ ')- .:50'" 20T. ... u lOT. z ... II: w .... .... ã 07- Z ... U II: -107- ... Q 1- j \- J.-- ).~ J- L 16.0 15.0 14.0 13.0 12.0 ... 11,0 w 10.0 u II: ... 9.0 Q 6.0 t 7.0 Vi 0 6.0 II: 0 Q 5.0 4.0 3.0 2.0 1.0 0.0 ...... - --- :::' :; i': Vi o ct o Q w u Z W Il: w ... l.. Õ CONFINING STRESS .800 pa/g) - . ----.--- --11111111. -207. -- jO~ ¡--.-- r-"1 - 336 262 290 I I -1 -~'l - .,.--;...... 156 0,020 073 - " .. u_ r-'-' I--'~ u,-_ - .- '~6 175 99ti 80.6 52.2 ". 177 157 90,5 71.1 22,0 ;'0._ SAMPLE PERMEABILITY' MILLlOARCIES _ RU~;:> _ qUI, 3 FIe; _ .._-....... ;' ,.v,.l~m pt'~rn~.bo"t..... .I'd "llIndardft CONFINING STRESS (800 PSi\ ) ----. SVP 2 10 " ~ '= '4 16 19 7 5 12 20 6 13 17 4 15 6 SAf\APLE NUMBER _ PIt /BVHg _ P\l, "". -:;.i _ PIt /(L~A) Fe¡: ....--:.. ~ .f...... ~ va. .tandards. I 0.9 0.6 0.7 0.6 0.5 0.4 0.3 0.2 0,1 o -0.1 -0.2 -0.3 -0.4 -0.5 -0.6 -0.7 -0.6 -0.9 -1 CONFINING STRESS (800 paig) Ifll~~ 10 Ie I. -of :£ 9 7 17 1 2 6 20 I 3 5 I 5 4 6 1 ¡ !;Af\APLE NUMBER _ Pv/BVHQ _ PV/(PI/+f;" _ PI//(LxA) .... ---.................... ~., " I-" ¡~ 22.1 n.6 22,4 L ªU,2 ~ ¡: ~2a 21.1 ~ , 1 216 21' o 1000 1000 3000 "t::-: CONflNtHG STRESS: PStG Fig. 8-Comparatlve porostties VS. conhn~ s:'~ ;;;~~l~;' us UCI HS ! HO ! ~ ~ 34S 340 3 3~ 330 0 o 1000 )000 4000 ~ooo "'£ T CONftN'k(; STC;¡[SS: PSaG Fig. 9-Compat"W'tive pore volumes V$. net confíning stress. 18 ~ . 2' - ? 10 <; - 16 ~ § 12 ~ !; - ¡ 0 50GC 0 4000 SOOO ® ~© -------ï ®_---~¡@ I I I I I I I I I® '::~ OVERBURDEN PRESSURE .. 130 1 ...... 128 12.6 - % Ö 22. t' ~ ~ 222 ~ ~ 21.8 ¡ ~ 216 o ... 1000 2000 3000 NET CONFMOG STR[SS : PSIG fig. 10-c0mp.r.th,. poroaltiea v.. net Continiolç _ ¡ 'j ~ 1.0 J -1 >- I- --I =<t: ~~1 W_ ;: Ea: a:O w a.. u... o <Oz >-2 1-1- -<J (J)<t: 0a: g:¡u... a.. . '- . j J °0 J fig. '2__ __ 'iI i .- ~:JUSTED ~T¡¡tl~ O £' CONFINIHG STllESS : PSICi fig. 11~tIve __ volume compr..-... .... .... confining .t..... POROSITY ADJUSTED TO UNIAXIAL STRAIN ¢ ~ 1""". ___ 10 _lat 101'-. L--. J.-- Top Depth Bottom Depth ., ,-- ,1- 11.) 7603.2 7605.5 12. ) 7605.5 7607.5 13.) 7607.5 7610.0 14. ) 7610.0 7612.5 15. ) 7612.5 7614.5 16. ) 17. ) 18. ) 19. ) 20. ) 21.) 22. ) 23. ) 24. ) 25. ) 26. ) 27. ) 28. ) 29. ) 30. ) 31.) 32. ) 33.) ,.1.... ,.L. - - - Remarks End Core #1 -- 1- L 1.- WELLSITE CORE REPORT . ,-- Company: Arco Alaska. Inc. Date: 6/11/87 Well: KRU #3M-16 Technicians: TDT , ;-. County, state: North Slope, Alaska Formation : Kuparuk .J- Core # ~ Top Bottom Total ( Ft. ) .l- Coring Interval (drillers depths) 7617.3 7676.3 59.0 Retrieved Core (measured depths) 7617.0 7676.3 59.3 Type Preservation - Core Seal/Plastic sleeve Core Barrel on drill floor - 14:08 End preservation - 17:03 -- Box No. Top Depth Bottom Depth Remarks 1.) 7617.0 7619.3 2. ) 7619.3 7621. 7 3.) 7621. 7 7623.5 4. ) 7623.5 7626.0 5. ) 7626.0 7627.7 6. ) 7627.7 7630.0 7. ) 7630.0 7632.5 8.) 7632.5 7634.4 9.) 7634.4 7636.6 10. ) 7636.6 7639.2 1 ......... ~- Top Depth Bottom Depth Remarks L 11. ) 7639.2 7641. 4 1 12. ) 7641.4 7643.5 13. ) 7643.5 7645.4 14. ) 7645.4 7647.2 15. ) 7647.2 7649.3 J- 16. ) 7649.3 7651. 5 17. ) 7651. 5 7653.6 -- 18. ) 7653.6 7655.6 19. ) 7655.6 7657.8 20. ) 7657.8 7659.2 - 21. ) 7659.2 7661. 4 22. ) 7661.4 7663.5 ~ 23. ) 7663.5 7665.6 24. ) 7665.6 7667.6 25. ) 7667.6 7669.6 26. ) 7669.6 7671. 4 27. ) 7671. 4 7673.6 ,.... 28.) 7673.6 7676.0 29. ) 7676.0 7676.3 30. ) End Core #2 31.) 32. ) 33. ) -- 1 >--- L L WELLSITE CORE REPORT L Company: Arco Alaska. Inc. Date: 6/11/87 Well: KRU #3M-16 Technicians: TDT J--- County, state: North Slope. Alaska Formation : Kuparuk 1.. ,L. Core # 1 Top Bottom Total ( Ft. ) coring Interval (drillers depths) 7580.0 7617.3 37.3 Retrieved Core (measured depths) 7580.0 7614.5 34.5 1 - ~ Type Preservation - Core Seal/Plastic sleeve Core Barrel on drill floor 03:00 End preservation - 04:45 Box No. Top Depth Bottom Depth Remarks 1.) 7580.0 7582.2 , 2.) 7582.2 7584.7 - 3. ) 7584.7 7586.9 4. ) 7586.9 7590.0 5. ) 7590.0 7591. 5 6.) 7591. 5 7594.2 7.) 7594.2 7596.9 8.) 7596.9 7599.1 9.) 7599.1 7601.2 10. ) 7601.2 7603.2 1--- L L WELLSITE CORE REPORT L Company: Arco Alaska. Inc. Well: KRU #3M-16 County, state: North Slope. Alaska Date: 6/11/87 Technicians: TDT Formation : Kuparuk L Core # ..l Top Bottom Total ( Ft. ) L Coring Interval (drillers depths) 7676.3 7692.0 15.7 Retrieved Core (measured depths) 7676.3 7691. 2 14.9 Type Preservation - Core Seal/Plastic sleeve Core Barrel on drill floor - 23:57 End preservation - 00:49 Box No. Top Depth Bottom Depth Remarks 1.) 7676.3 7678.7 2. ) 7678.7 7680.9 3. ) 7680.9 7683.5 4. ) 7683.5 7685.4 5.) 7685.4 7687.8 6. ) 7687.8 7690.5 7.) 7690.5 7691. 2 8. ) End Core #3 9. ) 10. ) L Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518· 3045 (907) 349· 3541 L L Recommended Well site Handling Procedure Fiberglass Sleeved Cores L 1.) Fiberglass liner or inner barrel is laid down in work area. L 2.) Clean exterior of fiberglass tube and mark orientation lines down the entire length with a waterproof/non-erasable ink. Markette brand markers seem to be best suited for this. Orientation lines shall be marked with black on the left and red on the right. We have found that taping the red and black markers together allows this to be done in a minimum amount of time. L L 3.) Cut plastic tubes into three foot sections with an electric skill saw. In some cases it may be required to use a pneumatic saw avai.lable by special order thru our Anchorage supplier. We use a masonry blade for cutting, available at most hardware stores. Generally it is the responsibility of the coring company to provide an appropriate saw with blades. 4.) Number each tube from top down in consecutive order or coded numbers. We prefer marking be by depth, confidentiality is required, mark each core section number and tube number, i.e. core 1-tube 1 marked 1-1, tube 2 marked 1-2, etc. by depth but if by core core 1- 5.) Chips may-be taken from the ends of the three foot sections for field descriptions. Core should not be removed from the fiberglass tubes unless examination is required for decisions regarding further coring. 6.) Both ends of the three foot sections are sealed with caps and hose clamps provided by the coring company. 7.) Load the three foot sections on crates or pallets measuring 38 x 38". It is recommended that crates be used and no more than 60 feet per crate. 8.) Freezing of the cores from unconsolidated formations is recommended for transportation. We do not recommend freezing of the more non-friable cores , either for transportation or while waiting at the staging area for shipment. L Lilian Core Lab 8005 Schoon Street Anchorage, Alaska 99518· 3045 (907) 349· 3541 L WELLSITE CORE PRESERVATION PROCEDURE 1 I-- L . The fOllowing procedures for preservation of core samples at the wellsite conform to the requirements established for Prudhoe Bay equity determination wells and have been tested on a majority of those wells cored. The preservation rate for these procedures should average 20 feet an hour, thus keeping the time for the preservation of 60 feet under 4 hours total. If the process does not average 20 feet per hour, it is recommended that the core be fully wrapped in Saran Wrap, placed in a brine if a water/bland mud core, or placed in oil base mUd/arctic diesel for oil base cores. These procedures recommend six personnel for routine preservation and seven personnel for special preservation (core plugging,wettability tests,etc), although it has been properly performed with five personnel. It would be possible to meet these established requirements with four personnel who are experienced in core preservation. Although the following procedures are well defined, they will not substitute for experienced personnel familiar with the proper handling and preservation of core samples at the wellsite. L L Recommended Personnel 1.) Core Lab Representative - Fitting core together, marking depths, sample selection, overall supervision of preservation process. 2.) Core Lab Representative - cutting of plugs or full diameter samples for laboratory analysis, special tests if required, assist in the preservation process where needed. 3.) Client Coring supervisor, Engineer, or Geologist - Records depths of each core piece or sample before preservation and assists in decisions that may be required by special conditions encountered. Also generally performs core descriptions or other tasks required by his organization. 4.) Client Rep., Mudlogger, or Rig Hand - Wraps core in Saran Wrap. 5.) Client Rep., Mudlogger, or Rig Hand - Wraps core in foil and marks each piece with depth and orientation lines. These duties may be performed by one of the above if there is insufficient personnel available. 6.) Client Rep., Mudlogger, or Rig Hand - Wraps core with wire and dips core in Core Seal. 1 .i.- Wellsite Core Preservation Page 2 L 1 .L-- 7.) Client Rep., Mudlogger, or Rig Hand - Removes dipped core from rack, places Core Seal where wire was trimmed, and boxes preserved pieces. May be performed by the person who dips the core if there is insufficient personnel available. The preservation operation can be divided into three main phases: L 1.) Material and site Preparation 2.) Core Handling and Preservation 3.) Final Boxing and Quality Control 1.) Material and site preDaration 1 , Upon arrival at the wellsite the required preservation materials should be set up in the core trailer as listed in the attached diagram. The melting pot should be filled with Core Seal and turned on. The temperature should be adjusted for the length of time before the core in recovered, place on low (180 F.) if more than 48 hours is anticipated. It is recommended that the melting pot be checked at regular intervals when turned on and never exceed the recommended dipping temperature for Core Seal(320-330 F. ) Personnel need to familiarize themselves with the areas on the wellsite that they will be working in while retrieving the core such as the rig floor, pipe shed, and core trailer location. Also all personnel should be aware of their areas of responsibility for the preservation operation. If a brine or diesel solution is to be used for submerging the core while awaiting preservation it is important to have the solution ready well in advance. Generally the service company responsible for the drilling fluid can provide the required solution. A trough for placing the core and solution in is usually supplied with each core trailer. Upon completing the above preparations, the core boxes should be put together and marked with Client, well name, core no., and box no. - 2.) Core Handling and preservation The Core Lab rep. should be present on the rig floor when the core barrel is being disconnected from the drill collars. He should have all materials that will be needed to prepare the core for movement to the core trailer at the rig floor or in the pipe shed. Also he should have a rock hammer, marker, and plastic sample bags with him on the rig floor for the pieces of core that are generally hanging out of the end of the core barrel or the inner liner. It is also important that he insures that the core is maintained in the proper orientation until fully marked. The type of core barrel and inner barrel used will determine the 1 :~ Wellsi tE~ Core Preservation Page 3 '- ;.-. type of handling required to prepare the core for movement to the core trailer. Generally most cores taken at present use the fiberglass inner barrel and the procedures used for preparing this type of core can be found in the Wellsite Handling Procedures for Fiberglass Sleeved Cores. Most other types of core barrels may vary somewhat but overall they will require core boxes or core trays on the rig floor to carry the core in once it is removed from the inner barrel (not necessary for fiberglass sleeved core). Once core is in the core trailer it should be placed in a solution or wrapped in plastic wrap to reduce fluid loss. The core should be laid out on the counter in five to ten foot intervals, the surface cleaned to allow marking, and marked with depths and orientation lines. Depths shall be marked below the corresponding foot line and orientation lines marked with white on the right and yellow on the left if using lumber crayons, or red on the right and black on the left if using waterproof markers. It is recommended that lumber crayons be used for marking core surface and markers for fiberglass barrels or foil wrapped core. After core is marked, chip samples and core descriptions may be performed providing the exposure of the core is kept to a minimum. The Core Lab representative shall preserve a minimum of four inches from each foot for laboratory analysis. A cut-off saw using an appropriate coolant should be used for cutting out these samples. This samples shall be marked with a CL on both the core surface and the foil wrapping. Once the laboratory samples are designated, the core is placed with the top facing "down the line" towards the dip tank. This will help insure that the proper core orientation is maintained. The core is then wrapped a minimum of 3 full wraps of Saran Wrap, then wrapped with a minimum of 3 full wraps of aluminum foil, and marked. Wrapped core should be marked with depth and orientation lines. Also laboratory samples should be marked with the CL designation. Once marked, the core is wrapped tightly around the center with wire to facilitate the dipping of the samples. The core should be completely submerged in the dip tank for 10 to 15 seconds and then hunq- on the cooling rack. After Core Seal has cooled (3 - 5 minutes) it should be redipped to insure a proper seal and to help protect the core from damage during shipment. After the second dip, the wire is cut at a point just above the preserved piece, and a small amount of Core Seal should be placed over the exposed wire to eliminate the wick effect. The preserved core is then placed in core boxes and the boxes left open for final quality control inspection. -- 1 J.- Wellsite Core Preservation Page 4 Final Boxing and Oualitv Control Once all the core has been preserved and placed in the open core boxes, it should be checked for proper preservation and markings. Occasionally the Core Seal will be too thick to read the markings and if possible a marker should be used to mark the appropriate designations on the outside of the sample. waterproof markers seem to be best suited for writing on Core Seal. The core depths are then placed on the core boxes and the boxes packed and sealed for shipment. A wellsite inventory shall be completed for each core, and the boxes then placed in shipping crates. The core trailer should be cleaned and prepared for the next core to be preserved. Recommended Tools and Materials - Core Seal Preservative (estimate one pound per foot of core) Melting Pot ( supplied with core trailer in PBU & KRU ) Saran Wrap or Handiwrap brand plastic wrap Aluminum Foil Plastic sample Bags Plastic ~rubing for nonpreserved sections Tape Measure Waterpro()f Markers (black and red) Lumber Crayons (yellow and white) Wire or Twine for dipping Core BoxE~s Strappin9 Tape Stapler Rock Hammer Large Chisel Screwdrivers and Nutdrivers WirecuttE~rs Rags for wiping down core Skill Saw for cutting fiberglass inner barrel ( usually supplied by Coring Co.) Cut-Off Saw with pump and fluid tank Drill PrE~SS (if special sampling required) Rubber Gloves Hardhat Safety boots and glasses Coveralls Cold Weat:her Clothing - - Doorway ,_ (/J ~ u en ~ tJI ç:: .,.., r-i o o u ~ ç:: en E-< 0.. .,.., o ç:: Q) 0.. 0 ~ en -,.., "- .,.., ~ .¡.J ~ ~ en .¡.J CJ) f1j Q) H ~ tJI 0.. ç:: en .,.., H tJI ç:: ~ 3: c: 0 ~ lð .,.., .,.., en r-i ~ .¡.J ::s -,.., H en 0 en .¡.J 'd µ.. ::s CJ) ç:: en .¡.J ::J 0 I >< f1j ,...:¡ Q) ~ c: 0 t: 0.. 0 U 1\1 CU -.-I H H .¡.J '1\1 3: en CJ) .¡.J CJ) Trough for holding cores drill press cut-off saw Core Preservation Trailer Diagram ARCO Alaska, In( Posl Office"~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #: 6062 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. 3C-1 3I-1 1R-4 1R-6 3C-14 3I-5 3M-16 3M-18 3M-19 .PBU Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pres'sure Survey Static BHP Bottomhole Pressure Survey 'A' Sand Static BHP Bottomhole Pressure Survey 'A' Sand PBU Bottomhole Pressure Survey. Kuparuk Well Pressure Report(Otis) 8-20-87 8-15-87 8-27-87 8-20-87 8-21-87 8-16-87 Kuparuk Well Pressure Report(Otis) Static 'C' Sand Kuparuk Well Pressure Report (Otis) Static Kuparuk Well Pressure Report (Otis) 50-029-21413 50-029-21407 50-029-21331 50-029-21425 9-7-87 9-14-87 9-14-87 Receipt Acknowledged: DISTRIBUTION: ~ Oil & Gas Cons. Ancho~ a~je Date: D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Is a Subsidiary of AllanllcRIchfleldCompany ARCO Alaska, Ir, Post Office~l'ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 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. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt'Acknowledged: DISTRIBUTION: NSK Dri~ State of Alaska(+sepia) ~ault(film) ARCO Alaska, Inc. Is a Subsidiary of AllantlcRichfleldCompany L( STATE OF ALASKA A _~r~A OIL AND GAS CONSERVATION CL . .SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate ~ Pull tubing Alter Casing [] Other ~ COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, I nc. RKB 64' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 904' FNL, 1578' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1256' FSL, 1737' FWL, Sec.19, T13N, RgE, UM 7. Well number 3M-16 8. Approval number 7-433 9. APl number 50-- 029-21728 At effective depth 1319' FSL, 1838' FWL, Sec.19, T13N, At total depth 1342' FSL~ 1876' FWL~ Sec.19~ T13N~ 11. Present well condition summary Total depth: measured 7955 true vertical 6539 R9E, UM R9E~ UM 10. Pool Kuparuk River Oil Pool 'MD feet Plugs (measured) None ' TVD feet Effective depth: measured 7855 'MD feet Junk (measured) None true vertical 6450'TVD feet Casing Length Size Cemented Measured depth Conductor 80' 16" 200 sx CS II 115'MD Surface 4043' 9-5/8" 1450 sx AS Ill & 4080'MD 400 sx Class G Production 7941' 7" 300 sx Class G & 7941 'MD 175 sx CS I True Vertical depth 115'TVD 3430'TVD 6527'TVD 12. Perforation depth: measured 7612'MD, 7614'MD, 7616'MD, 7618'MD, 7626'-7660'MD true vertical 6232'TVD, 6234'TVD, 6235'TVD, 62~7'TVD, 6244 '-6275 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 7520' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7489' & TRDP-1A-SSA SSSV @ 1759' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Iniection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Wel 1 Hi story w/Addendum, dated 7/21/87) Daily Report of Well Operations X2 Copies of Logs and Surveys Run [~ G.yro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associ ate Engineer (Dani) SW02/74 Date ¢]- 17-~!~7 Submi, t in Duplicate AR~,b Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned o~ well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of lime. On workovers when an official test is not required upon completion, reporlr completion and representative test data in b~ocks providec The "Final Reporl" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish Slate Alaska I North Slope Borough Alaska Kuparuk River ADL 25512 3M-16 Auth. or W.O. no. ~Title AFE AK1690 I Completion Nordic ~1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete API 50-029-21728 ]A.RCo. W.I. Fotal number of wells (active or inactive, on thisI 56.24% ~ost center prior to plugging and pbandonment of this well IOate · ~our 1 Prior status ,f a W.O. 8/14/87 / 1930 hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 8/17/87 7" @ 7941' Diesel Accept rig @ 1930 hrs, 8/14/87. ND tree, NU & tst BOPE. RU & perf 7626'-7660' @ 4 SPF & 7612', 7614', 7616' & 7618' @ 1 SPF. RU & rn 227 jts, 2-7/8", 6.5#, J-55 8RD AB Mod tbg w/SSSV @ 1759', HRP-i-SP Pkr @ 7489', TT @ 7520'. ND BOPE, NU & tst tree to 5000 psi. Displ well w/270 bbls diesel. RR @ 1915 hfs, 8/15/87. Old TD New TD Released rig Date 1915 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data I PB Deplh 8/15/87 IKind of rig Rotary tType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands '~ell no. Date Reservoir Producing Interval Oil or gas 'Tesi'ti'meProduction 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 · Date ITitle s,g~j~. ~...,j I ~.~/~ ;Z Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPag[ no. Division of AflanflcRIchfleldCompany ADDENDUM WELL: 3M-16 6/26/87 Arctic Pak well w/175 sx CS I & 60 bbls Arctic Pak. Drill~ Su~perviso~ Da/te ARCO Alaska, Inc. Post Offic ,,~. 100360 Anchorag~.'7,~laska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal # 6003 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~ransmitted herewith are the following items. Please acknowledge .receipt and returff one signed copy of this transmittal. 3M-15 OH Lis Tapes 6-19-87 #72365 3M-16 OH Lis Tapes 6-11-87 #72361 3M-13 OH Lis Tapes 5-28=87 #72348 3M-17 OH Lis Tapes 6-30-87 #72405 3M-18 OH Lis Tapes 6-24-87 #72375 3M-14 OH Lis Tapes 6-4-87 #72353 3M-12 OH Lis Tapes 5-21-87 #72329 Receipt Acknowledged: DISTRIBUTION: M. Stanford · ~"~?State 'of Alaska:~ ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office ~f00360 Anchorage,~'~aska 99510-0360 Telephone 907 276 1215 Date:July 22, 1987 Transmittal #6005 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. v- 3M-20 5" DIL 7-9-87 974-11068 ~3M-20 Cyberlook 7-9-87 10200-10670 "' 3M-20 2" DIL 7-9-87 974-10776 '-3M-20 2" Porosity FDC 7-9-87 10200-10750 '-3M-20 2" Raw Data FDC 7-9-87 10200-10750 '" 3M-20 5" Raw (+1.2") FDC 7-9-87 10200-110420 ~20 5" Porosity FDC 7-9-87 10200-11042 ~M-16 5" Porosity FDC 7-11-87 6000-7916 --3M-16 Cyberlook 7-11-87 7350-7870 .~ --3M-16 2" Raw Data FDC 7-11-87 6000-7916 ---3M-16 5" Raw Data FDC 7-11-87 6000-7916 __~--3M-16'''~ 5" Dual Dipmeter 7-11-87 7350-7936 --3M-16 High Resolution FDC 7-11-87 6000-7916 ---3M-16 5" DIL 7-11-87 1000-7942 ~3M-16 2" Porosity FDC 7-11-87 6000-7916 ~- 3M-16 2" DIL 7-11-87 1000-7942 ~ 2" DIL 6-24-87 1000-8510 --~3M-18 5" Raw Data FDC 6-24-87 4800-8484 -- 3M-18 2" Porosity FDC 6-24-87 4800-8484 -- 3M-18 Cyberlook 6-24-87 8000-8440 --3M-18 5" DIL 6-24-87 1000-8510 ---3M-18 5" Porosity FDC 6-24-87 4800-8484 -~ 3M-18 2" Raw Data FDC 6-24-87 4800-8484 ------~M- 17 Cyberlook 6-30-87 ~i~--3M-17 2" Raw Data FDC 6-30-87 8150-8666 --3M-17 2" Porosity FDC 6-30-87~~~_ ~~ ~ r~81.50-~666~ -'-3M-17 5" Raw Data FDC 6-30-87 / I~~~~-~ --3M-17 5" Porosity FDC 6-30-87~~~~~66~ Receipt Acknowledged: ' ' Date: //~~ 0it & Gas Cons. Commission DISTRIBUTION: Anchorage NSK Drilling Rathmell D & M State of Alaska(+sepia) Vault(film) ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRichfieldCompany ARCO Alaska, Inc. Post Offic~ .,-1'00360 Anchorage?~aska 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #6005 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '---3M-17 A 5" Dual Induction 6-30-87 4325-8692 ---3M-17 2" Dual Induction 6-30-87 4325-8692 ~.~M-l'5 2" Dual Induction 6-19-87 3488-7590 ---3M-15 2" Raw Data FDC 6-19-87 3488-7564 .~ --3M-15 5" Raw Data FDC 6-19-87 3488-7564 ---3M-15 5" Porosity FDC 6-19-87 3488-7564 -~-3M-15 2" Porosity FDC 6-19-87 3488-7564 ---3M-15 5" Dual Induction 6-19-87 3488-7590 --3M-15 Cyberlook 6-19-87 Receipt Acknowledged: DISTRIBUTION: NSK Drilling State of Alaska(+ sepia) . .~~l/n ~(n~/x / Date.~ UL~-~, .~.~u~ ~ Oil & Bas Cons. Commission Anc~r~el1 .D &M Vault (fi~) ARCO Alaska, Inc, Is a Subsidiary of AtlanllcRichfieldCompany' STATE OF ALASKA ALA~,,,.A~'OIL AND GAS CONSERVATION CON~,,w~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend © Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other 2. Na~rl0e of Oper.ator ~r<C0 AlasKa, Inc 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 904' FNL, 1579' FEL, 5ec.25, T13N, R8E, UM At top of productive interval 1290' FSL, 1801' FWL, Sec.19, T13N, R9E, UM (approx) At effective depth 1368' FSL, 1800' FWL, Sec.19, T13N, RgE, UM (approx) At total depth 1394' FSL, 1836' FWL, Sec..19, T13N, RgE, UM (approx) 11. Present well condition summary Total depth: measured true vertical 7955 ' MD feet Plugs (measured) 6539 ' TVD feet 5. Datum elevation (DF or KB) RKB 64 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3M-16 8. Permit number 87-53 9. APl number 50-- 029-21728 10. Pool Kuparuk River 0il Pool None Effective depth: measured 7855 'MD true vertical 6450 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 4043 ' 9-5/8" Production 7941 ' 7" feet Junk (measured) feet None Cemented 200 sx CS II 1450 sx AS III 400 sx Class G 300 sx Class G Measured depth 115'MD 4080'MD 7941 ' MD ~ue Verticaldepth 115'TVD 3428'TVD 6527'TVD Perforation depth: measured No n e true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August, 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 ,4// Signed /-~¢.¢ (~/) oj)L. -' ,S~¥~1_~J¢ ~A,~, TitleAssoci ate Enqipeer (~ Commission Use Only (Dani ~,,--. -- -- Conditions of approval Notify commission so representative may witness I APproval No. [] Plug'integrity [] BOP Test [] Location clearanceI Date '7-i-g? Approved by Form 10-403 Rev 12-1-85 Commissioner the commission Date 7 (z;' '~'d, ~ ~ ~~~~ Submit in tdplicato -. feet ARCO Oil and Gas Company Well History- Initial Report- Daily Inetruction,: Prepare and submit the "Initial Report" on the first Wednesday after .a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska County, parish or borough North Slope Borough .~.~Leaae or Unit ADL 25512 / fTitlo Drill State Alaska Kuparuk River Auth, or W,O, no. AFE AK2165 IWell no. 3M-16 Doyon #9 AP1 50-029-21728 Operator ARCO Alaska, Inc. IDate IHour 6/5/87 Complete record for each day reported Spudded or W.O. begun Spudded 6/06/87 thru 6/08/87 2030 hrs. Date and depth as of 8:00 a.m, 6/09/87 6/10/87 6/11/87 IARCO W.I. Pri.0r status if a W.O. 16" @ 115'/9-5/8" @ 4080' _ 4100', (3985'), NU BOPE Wt. 9.2, PV 19, YP 10, PH 9.0, WL 10.8, Sol 6 NU diverter sys. Accept rig @ 1700 hfs, 6/5/87. Spud well @ 2030 hfs, 6/5/87. Drl 12~' hole to 4100', short trip, C&C, POH. RU & rn 102 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 4080', FC @ 3998'. Cmt w/1450 sx AS III & 400 sx C1 "G" w/2% S-1 & .2% D-46. Displ & bump plug to 2000 psi. ND diverter sys. 521', .7°, S17.5W, 520.99TVD, -2.46,VS S 3.04, W 0.96 1071', 13.7°, N48.2E, 1066.33TVD, 52.35 VS, N32.59, E 41.25 1637', 25.5°, N52.6E, 1598.85TVD, 240.81VS, N143.65, E 193.86 2013', 35.9°, N55.SE, 1921.21TVD, 433.01VS, N257.59, E 349.03 2760', 43.1°, N58.3E, 2478.19TVD, 929.81VS, N533.30, E 762.25 3044', 42.2°, N58.4E, 2687.07TVD, 1122.17 VS, N634.27, E 926.15 4000', 44.5°, N60.2E, 3370.05TVD, 1790.84 VS, N991.38, E1491.53 9-5/8" @ 4080' 5863', (1753'), Drlg Wt. 9.0, PV 4, YP 2, PH 8.0, WL 8.8, Sol 5 NU & tst BOPE. TIH w/8½" BHA, tag FC @ 3998', tst csg to 2000 psi. DO flt equip, cmt & 10' new hole. Conduct formation tst to 12.5 ppg EMW; leaked to 11.6 ppg EMW. Drl to 5863'. 4490', 42.9°, N58.9E, 3724.29 TVD, 2129.02 VS, 1162.93N, 1783.35E 4961', 42.0°, N56.7E, 4071.82 TVD, 2446.87 VS, 1332.32N, 2052.34E 5434', 40.7°, N53.9E, 4426.89 TVD, 2759.18 VS, 1510.20N, 2309.22E 5685', 41.2~, N54.SE, 4616.47 TVD, 2923.51VS, 1606.07N, 2442.89E 9-5/8" @ 4080' 7580', (1717'), CBU Wt. 10.0, PV 14, YP 5, PH 8.0, WL 4.4, Sol 10 Drl 8½" hole to core point @ 7580'. 6028', 36.5°, N53.3E, 4883.52 TVD, 3138.31VS, 1732.35N, 2617.01E 6973', 29.3°, N54.5E, 5667.30 TVD, 3664.58 VS, 2036.07N, 3047.29E 9-5/8" @ 4080' 7617', (37'), RIH Wt. 10.0, PV 16, YP 7, PH 8, WL 4.8, Sol 12 Chg mud over to core fluid, POH. RIH, core #1 f/7580'-7617'; jammed, POH; rec'd 34.5'. RIH w/new bit. 7486', 26.6°, N54.3E, 6120.43 TVD, 3904.77 VS, 2176.01N, 3242.81E 56.24% see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate/ / I Vit,e Drilling Supervisor ARCO Oil and Gas com"~any ~ Daily W~istory-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District J.~ounty or Parish Alaska I North Slope Borough Field JLease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. JTitle AFE AK2165 I Drill Doyen #9 AP1 50-029-21728 Operator I A.R.Co. W.I. ARCO Alaska, Inc. ] 56.24% Spudded or W.O. begun ~Date Spudded I 6/5/87 Accounting cost center code State Alaska 6/12/87 6/13/87 Date and depth as of 8:00 a.m Complete record for each day reported Iotal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our ~ Prior status if a W.O. 2030 hrs. I mn 9-5/8" @ 4080' 7813', (196'), Drlg Wt. 10.0, PV 14, YP 6, PH 8; WL 4.0, Sol 11 Wsh 30' to btm. Rn Core #2 f/7617'-7676'. Rec'd 100%. Core #3 f/7676'-7692'. Rec'd 95%. RIH w/new BHA, rm 7615'-7692', drl to 7813'. 7" @ 7941' 7955' TD, 7855' PBTD, (142'),' RR Wt. 10.0, PV 16, YP 6, PH 8, WL 4.6, Sol 12 Drl to 7955' TD, short trip, C&C, POH. RU Schl, log 8½" hole w/DIL, Density, CNL, GR, FMS, RD Schl. Make wiper trip. RU & rn 184 its, 7", 26#, J-55 BTC csg w/FC @ 7851', FS @ 7941'. Cmt w/100 sx 50/50 w/4% D-20, .2% D-46 & .5% D-65 & 200 sx Cl "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/300 bbls brine, bump plug. ND BO?E, NU & tst wellhead to 3000 psi. RR @ 1200 hrs, 6/14/87. Old TD New TD Released rig Date 1200 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth 7955' TD Kndof rg 6/14/87 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk. Sands 7855' PBTD Rotary Well no. Date Reservoir !Producing Interval Oil 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska, Inc. ~' Post Office B~xx i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure '" "? ~ 4]. AJas~..',~ 0ii & Gas Cons. ARCO Alaska, Inc. is a Subsidiary ol AtlanticRichfieldCompany ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. £4 _VICINITY MAP SCALE I" m tM ILES' NOTES: I. ALL COORDINATES ARE A.S.P. t ZONE 4. 2.ALL DISTANCES SHOWN ARE TRUE. $.ELEVATIONS ARE B.P.M.$.L- 4.REF. FIELD BOOK LIT-5 t POi. 77-1I; LI77-1t R77; LST-$,PSI - 53; 5.0.G.ELEVATIONS FRO" F.". BELL & ASSOCIATES. ,os,m.s o. T! MONUMENTS PER LHD 8~ ASSOCIATES. ASPs 'X' LATITUDE LONGITUDE Dist. F.N.L. Dist. F.E.L. 6 202.17 S06,tZ6.t! ?'It i49°5 1296 1741 , 1732: 6,016,225.10 ,156.4! 6~16,248.Zl ~0(~6,145 6,016,271 .E4 506,155.5' 6,016,294.28 506,165.0 6,016,$17.42 506,174.6 506,184.1 $06,193.5 ?'20.0 i6' 121' 3 7'20.2 IESO 7' 1~0.459 12Z7 1' 1204 77'20.915 1181 I i6'58.316 I 158 ITEZ 1715 1705 1694 1~84 16775 1665 1636 16 2:6 6,016,340.48 I 135 6,016,363.49 I 112 6,016,$86.92 506,;Z03. I' IO42 ,,o,,,,,.,, 6,016,479.22 506,Z41.5 · 1617: ~,016,502.~6 5~,~51.07 70°~ 973 1607 ~l.t 6,016,525.tl 506,Z60.~ 7~21 1598: Il I' Z6.4~ 6,016,548.6Z 5~,ZTO.~O 70°27',Z~'lK 950' 6,016 ,571.45 S~,z-Tg.TT 70°27,2~-410 ~ZT' 1586, ~9' E6.4, 6 ,016 , 59 4.75 5~,289.40 7~Z7 23.639 904' 1578, 6,016,617~9 506,~99.05 70°27'23-868 881' 1569 6,016,~1.02 5~,308.76 7~Z7;24.094 4~56'54.647 858' 1559' ZO.8' 26.6' 5~k ~/7.~2 7P'Z7 ~. ~ /~'f4.~72" 635' l~f~' Z~. ~' Z5.q' , I~' ~P.~' z5.7' ~) o~b j &OZ~ 5DA, 3Z~ 70'27' Z~. /~?'Sa' 5~.~97" ~/Z ' · ~lb,/7~.~g 5~b, 117.~ 7~'z7'/~.55° /4¢'57'oP.~6/ i~' /7~/' zt.~' ZG.z ~;o/&, i~.77 5o~,107.~J 7~'ZT'/9.32J /~ST'OO.~z /~), 17~0' Z~.O' ZG.~' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 3/8/87 ., .........................................................tative · "~e ' /~ ...................................................... ~ermi. t ~ C~nera] ,o~s~e~g ~ ~{~es~Jre After C]o~r~~sig ~ese~e pit__/ P~p ~ -~.m~. cios. pres. 200 psig ' · -- - o~ t~~ " [.~' a. f <,': .: - ~ ~~ ""' ' '[T~t ~'es~ee~ Kelly ~d Flor ~fe~ V~v~s - ~t Re~]ts: Fai ~est T~~~' Bepair or R~]ac~nent of fai]~ ~.pr~ to ~ ~ade ~th~ ...... ~ys ~d ;p~pector/Ca.~nission office potified. · .~va rks: 'RECEIVED. Nas~"'",,,, & Gas Guns. CommiSsion CC June 3, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 · Re: Telecopy: (907) 276-7542 Kuparuk River Unit 3M- 16 ARCO Alaska, Inc. Permit N°. 87-53 Sur. Loc. 904'F~, 1579'FEL, Sec. 25, T13N, R8E, UM. Btmhole Loc'. I423'FSL, 2007'FWL, Sec. 19, T13N, R9E, UM. Dear Mr. Kewin.- Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ¥~ tru~~s ,~ ~ Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery '", STATE OF ALASKA ALASKA OIL..,4D GAS CONSERVATION CON,,.,.__,SION PERMIT TO DRILL 20 AAC 25.005 Re-Entry'~ Deepen[]1 Service [] Developement Gas [] Single Zone/J~ Multiple Zone E~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64', PAD 27' feet Kuparuk River Field Kuparuk River 0il Pool 3 Address 6ADPr_.oP2eCtsY D2esi~:ti P.'O.-Box 100360 Anchorage, AK 99510-0360 1 (~n553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 904'FNL, 1579'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit Statewide 1 29~I Ft~P/L ,of 10~%dlU,CF_t~ interval 8. Well nu ,mber Number , Sec.19, T13N, R9E, UM 3M-16 #8088-26-27 At total depth 9. Approximate spud date Amount 142_~'FSL, 2007'FWL, Sec.19, T13N, R9E, UM 06/07/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth(MD a,d TVD) property line 3M-1 5 8064 'MD 904'@ Surface feet 25' @ Surface feet 2560 (6492'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 1 0 0 0 feet Maximum hole angle 4 2 0 Maximum surface 2 0 2 0 psig At total depth (TVD) 3 I 7 2 psig 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' 115' +200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3891 ' 35' 35' 3926' 3413' 1325 sx AS I II & HF-EFW 400 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8030' 34' 34' 8064' 6492' 200 sx Class G(minimum HF-EFW TOC 5~)0' above 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: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ,'~',;:~ 1 9 Production Perforation depth: measured /~i;cJ'!~)~*;~ true vertical fee)~(]" plat [] BOP Sketch~. Diverter Sketch ~ Drilling program ~ 20. Attachments Fil~g . . - Property Drilling fluid program (~ T~me vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirement 21. I hereby ¢,,e'¢~ that the foregoing i,¢:~t?rue and correct to the best of my knowledge ;/''?// Signed{k -:/¢' ~'/"-Z'~'/~''' ~~z~"~;~¢'1~'¢'"¢~'' ¢-"~ ~'~'~ ..... T''I"I~Regional Drilling Engineer Date /x_~-~,--/ ' - Commission Use Only (HRE) PD2/27 Permit Nu'm/ber// I APl number I Approval date I See cover letter -~ I 50-- 0 ,~¢ - ~;-~[ ? .~ I 06/03/87I for other requirements Conditions of approval Samples required [] Yes '~.,.No Mud log required L-] Yes' Hydrogen sulfide measures [] Yes [] No Directional survey required .~Yes [] No ~' Required working~ for~O~~,~ ~.~M~,[] 5M; [] 10M; [] 15M °the. ,, , order of Approvedby ~...~'.~ ~ _¢~'~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Su 3ate -T I I J i I ! i~'," ~ ~---i ~ ~"" ', ii I ~ '~ ~,t ~.~jl i !~ ~ ~, j ~ 4-~.--~-~---~-~-.-~ ..... ~.~-.-~ ........ +-~--~---~ .... ~-~-* ~-~---F-~--~-4-.?~ ~ ~ : ~ ~ ~ ~ ~ ~ :,i ', ; ,,,; ....... : i ~ ~i; i~ ~--~+~ ~I~ fl' ~--.~.-L-~--~-.-~ ~:-.;-;-.:-~.~.:-: ........ ;-.;; ............. ~--~-.-;~ .... -'~: ~I~, ..... ~~'~-~,,~ ~,~+-'~ ~Tt- ' ....... ~i,~I' ' -~-~-" T .[~6~V : ' r'~T~ -~;~-..~1-~-1o., ~; , ; ~ ~ ~ ~ - ~ ,- ~ ;~ ' ~ ~ ~ : , ~ ~ ~ ' ' ~ ~ : ~ ! ~ ~ ; : ....... ~ - : ' I · ' : ~.-L..4--~_. ~k.~-~--i--.~4-J~-~---G-~-~-~ ...... ~ +?..~ ..... ~-.L--~ .... ~-~ ~- :-~-: ..... ~ ~ · i : - : - ~ - ~ ~ ~ ..... ..... ~-~--~-.--~-M~--~-,-~- ~ -~--~~-~-~---~ ~--~-~- ~-~----~--~ ...... ~--~ .... ~-~i~-~-.~- - ~ ~,~-; ~ --, ...... ~-~ .... ~i -~44~ 4~4-~.+-A~.--~4~; ..... ~A-.~=--~~--~--+-:-~ ..... :--' ~-~t · ~-r~- :~ ~ ~ ~ ~t : ~: ....... '..__:_ _:_ L, ~__~_L '~. :.L7 L~:~L-~_~j~.:-~.:._.: ......... '~..~_: ....... ~ ~.4--'- ..... ~J--.~ ~-.~ ~ .~N:~-~ :'"'7~.'~1:1 ~ .T~~ ~1'0~ . ! ~-----~?+ ~ f-~--~-~---+--~ .... ~---~--~-.,--~-~--: ....... ~ .~.. ....... ~ ...._ __~ .... -~--~--~-~t--: ~'~-' ~-?--~' -~ ....... ~--~ ..... ~' "~ ..... r r---:-~ t ......... , .... ) ......... - ' '~, '. ~ : ~ '; - ~ : F :-- 17] ~11~] ~' I I~i ~g: !11~--I q~ ~1.1' --~ I ~ T ' :"~---~'~'-rz-'r--r .......... --~ ..... ~-'ZONE:"~ ...... TV~32~--:~-~r43.-~;P-40t~O- ~,- ~: N ] ~v.,~l z. 7 ~ " '4t4t' aOli&, :::::~::.L.~..~.~::.:~::...[.:::::~:::;t:`:~:~:.~[:2:::~V:~i~=6.~:E:::T.~8~4: DE~=~275: :::::,:.: ~-: ~ T ' ~-~- ~ :t ~ r~ ~ ] :::::::::::::::::::::::::::: [ :;:.:::::::::::::::::::::::::::::::::::::::::::: :;': ~O~::J:::: ~000: I:: ' :4000 i: 5000: :---T ..... ~---,--.:-T ..... ~ ...... T-'-~ ,--~-~-~-~-~---T'-~ ...... --~ ..... ~ .... : ............... ~ ............... ~ .... i ' ~ ' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::;:.:::::~: :.;: :-: :: ::::; j--;'::::::. ~ ...... ~ ............... ~ , · I . . ......... ~ ...... ~ ......... ~ ................. - ~ ...... ~ ...... ~ ........... .... ~ ' ! ~ ................. . KUPARUK RIVER UNIT :20' DIVERTER SCHEMATIC J I_ DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP-ON ~VELD STARTING HEAD 3. FMC DIVER'I'ER ASSEMBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES ~//10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROH 20AAC25.035(b) 2 A MAINTENANCE ~,,OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 7 6 DIAGRAM #l 13-5/8" 5000 PSI RSRRA BOP STAQ( 1. 16" - 2JD(X) ~! TAt~CO ~TAR~rlNG FF. AD 2. II "'- ~CX30 P~I C./~I~ FF. AD ~. I1' - 3CX~O P~I X 1~--5/8' - ~ PSI SPAC~ ~ 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRILLING SPCX3L W/CHC~E AN3 KILL LI~.S 6. 13-5/8" - 5000 PSI ~ RAM W/PIPE RNaB ON TOP. 7. 1~'-5/8' - 5000 PS! A~ A~TOR CAPACITY TEST I. (3-ECl( ~ FILL ~TDR RESERVOIR TO ~ LEVEL WITH HYDRALI. IC FLUID. 2. ASSI. RE THAT ~TGR PRESSLRE I$ 3000 PSI WITH 3. CaSERVE TII~o ~ CLO~E NJ. UNIT8 SlMJLT~ClJS. Y ALL UN~TS ARE CLO6ED WITH ~ING ~ OFF. 4. RE(:I:R~ CN ~ REPCI~, TIE ACCEPTABLE LC~I~R LIMIT IS 45 SE~ CLOSII~3 T%I~[ ~ 12130 PSI REMAINING PRESSURE. 5 4 i ii i 13-5/~" BOP STACK .TEST I. FILL ~ STA(]( ~ CHOd~ MN~FOI. D W/TH AI~"TIC DIESEL. 2. tHE(3< THAT ALL LOCI< ~ SCRE3~ IN ~-1/~EAD ARE FLI_LY RETRACTED. SEAT TEST PLUG IN ~'11~) WITH ~ING Jr ~ ~ IN L~ SCREVIS. LI~E VALVES ADJACENT TO BOP STAQ(. ALL ~ 4, PRESSLRE UP TO 250 PSI ~ HCLD FCR I0 M/N. IN- CREASE PRESSURE TO 3000 PSI ~ H~LD FOR I0 MIN. BLEED PRESSLRE TO 0 PSI. LI~E VALVES. CL~ TOP PIPE RAMS ~ HCR VALVES ON K/LL A~D CHO<E LI~.S. 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. 7. CCNTI~ TESTING ALL VALVES. LIt~_S, ~ CHCKES WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST AS IN STEP 4. DO M3T PR~_~ TE~T ANY CI-E3KE THAT IS NOT A FULL CLOSING POSITIVE SEN_ CHO<E. CI~LY ~IEl~ TEST Q-E](E$ THAT DO NOT FLI. LY CLO~E. 8. OPEN TOP PIPE RNaS ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RNdS TO 250 PSI ~ 3000 PSI. 9. OPEN BOTTCM PIPE RAMS. BAQ( OUT RUNNING Jr A~D I0. CLOSE BLII~) RAMS ~ TEST TO 250 PSI ~ 3030 PSI. II. CPEN BLI~I:) RAMS ~ RETRIEVE TEST PLUG. MAKE SURE MANIFOLD ~ LI~ES ARE FULL CF NCt++-REE:ZING FLUID. SET ALL VALVES IN DRILLING POSITICI~ 12. TEST STAt~EPIPE VALVES, KELLY, KELLY COCXS. [:RILL PIPE SAFETY VALVE, ~ INSICE BCP TO 250 PSI AN3 3000 PSI. 13. RECCR9 TEST I~FCRMATION ON BLOWOUT PREVENTER TEST FORM, SIGN, A~D SE~D TO DRILLING SUPERVISDR. 14. PERFORM COVF~ BCPE TEST AFTER NIPPLING UP AI~D WEEKLY Tt~:J~:AFTER FUNCTICNALLY OPERATE BOPE DALLY. 510084001 REV. MAY 15o 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Wei§ht Up 9.6-9.8 8.7-9.2 Weight Up to TD 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 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators 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 GENERAL DRILLING PROCEDUR~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Dow~squeeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. 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 scandin$ tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. --~ DEOASSER '1 SHALE SHAKERS .~ ST _~EANER R ~..~ STIR ---w, STIR TYPICAL HUD SYSTEH SCHEMATIC LWK4 / ih CHECK LIST FOE NEW W~. PE~fLTS ~ APPROVE DATE (2) Loc ~ ~. ~ -~7 " (z tnmi 8) 13) 10. '~, ~i ~-~Z-~ 11. (10 and 13) 12. 13. (4) Casg .//~Z'..,,~',~ ' (14 thru 22) (23 thru 28) (6) OTHER (29 thru 31) Company 1. Is the permit fee attached .......................................... Lease & Well No. YES NO Is well to be deviated and is wellbore plat included ................ Is operator the only affected parry ................................. Can pen=it be approved before fifteen-day w~it ...................... 2. Is well to be located in a defined pool ............................. ~., Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. 7. 8. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease r~ber appropriate ..................................... ~ Does the well have a unique ~ and n~er .......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cememt used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ ~ Is old wellbore abandonnmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23 Is a diverter system required · e~eeeee®®e eeeee eeeee®eeeeeeeeeeeeeeeeee 24. IS the drilling fluid program sch~tic and list of equi~t adequate 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to 27. Does the choke m~n~*old comply w/API RP-53 ~May 84) .................. 28. Is the presence of ~S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ............ 31. If an offshore loc., are survey results of seabed conditions 32. Additional requirm~=nts ............................................. GeoloKy: rev: 01/28/87 6.01,!, INI'i/AL GEO. UNIT DN/OFF POOL CLASS STATUS AREA NO. SHORE 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. m~mmm il i i ,i, ~,i ~l~ ,,ii ~ii 4,45 f.<! 69 OF 3,89 O, 6~ OF 2,113 0 I~3 t) F 0 0 0 0 0 0 0 () ( 0 C T A h ) 68 OOO00OO0000000 O000OO00000000 O00OO000000UO0 OUUOOOOk~O00000 O00OO00OO00000 00000000000000 000o0000000000 O0000OO0000000 OOOOO000000000 OUOOOUOOOO0000 OOO00OOOOO000O 0000000o0o0000 OOO00OOOOOO000 O00UOUOOOUO000 O000000000OO00 ", 3 ':~:. '! 5 u 6 !{ 2,,6't98 13.719'1 CALl -999,2500 2.1035 ~0,b625 ~.4141 2002,0000 -999,2500 2,4700 72,6875 ~.'157~ 2,b7a4 102,5625 S,8437 209~,0000 -999,2500 2.~02b ~,8516 ? N I, .4, i. ',:~ 0 U 4: ~',~ ;,< b T !.~.2339 C;~bI -999,2500 o244,00U0 12,!6~6 CAb! 4. 1758 -S~99,2500 TENS 'I.'1295 '7~,5625 8.6250 2296,0000 -99'9 ~500 I 5469 9~ 8750 i, 3 0703 2238 0000 '99~ 2500 1,9742 107,8750 12,~53i 571,0000 1999,2500 2 ~937 -999 2500 -999 2500 -999 2500 -999'2500 3.143'1 -999 2500 -999 2500 -999 2500 -999 2500 3,~37 999,2500 999,2500 9919,25U0 -999.250U 3.~385 -999 ~SUO -99~,25U0 -~99,25U0 -999.25o0 -999.2500 -99~,25U0 3.5232 -999.2500 -99Y,25UO -999,2500 -99~.2bU0 p i:-!,:: I, - 99 ~-,~. 25 {) <" ;,~ !*', & L: -9g~9.250o CADI -999,250(} -999,2500 TEaS -999,250{) CA.u t. -999,2500 i'~C/';L -999,2500 CA~i. -999,2500 -999,2500 !6.54~3 ChbI -999. 2500 TEi'~5 3.0222 -999,2500 -99'9,2500 -999,2500 3 5552 99~.2500 -999.2500 -99~,2500 3,4699 999,2500 Z999,2500 '999,2500 '999,2500 2,9670 '999,25(t0 -99~,~5u0 ,. -999,2500 -99W,25~0 3,16~4 -~9~ 2500 -999,25uu .~,2596 111~,4375 9,9453 1830.00U0 -999,25U0 2.9207 i08,02b0 10.1328 i~2U,oOUO 10q.$125 ~41,0000 i999,25ti0 2.5481 -~9~,25U0 -999,25UU -999.2500 p H t P H I' ~P !PHI ~. p,~ .] :EFT ~PHI "C :~ L, 9,25 u C: 9,2 5 {,' 0 3.1225 8.00 (',) u -999,25o0 9.25 0 U -999,2SOu 9.250 '0 9.25 o :) 00 0 ,:) 3.7 2 3 :~ ~, , 9.2 b 0 <) -999. 2509 3,3 2 3 4 9.250 U -999,2bu() 3,44 ~ b 5,25 C, ~ 9,25 U U a · 2 b O 0 -Y79.250:i 9 9.25 (~ 0 <? 9.250 '3 3.3594 :uUg,2bO0 999.2500 '999.2500 -999.2500 ~,0928 -999,2500 -99~.2500 -999,2500 O0 ~,2838 999,2500 :s99,2soo '999,~0 -999,25()0 '999,2500 '99~2500 '999,~5U0 '999,2500 3,a422 -gq~. 25(?0 -999,2500 -999,2500 -999,2500 ~.3255 -999,2500 -999,25(i0 -999.2500 -999,2500 3.3287 -999°2500 999,25b0 ~99~ 2500 ' · · -999,~5U0 3,0580 -999.2500 -999,25U0 -999.2500 -9g~,2500 3.3150 -99~.2500 -ggg.2bO0 -999.25U0 -999,25U0 'C ,~ L - 999,2 5 u <., T 6 P, 5 3,714.~ 3700.000;) -999,2509 · ,, 9 9 9.2 50 9 3,3445 -999,2500 -999. 250(3 -999,25L)0 '999,2500 '~99.2500 '999.2500 '999.2500 '999,2500 '999,250Ci '~99.2500 '999,250{) -999,2500 3.2943 -999,2500 -99~,2500 -999.2500 -~99,2500 "999,2500 -999,2500 3,76~7 -999,Z5~0 -999,25~0 -999,25o9 -99~,2500 2.4071 -999,Z500 -g99,25uu -999,2500 -99~.25U0 2,~4'1t '~99.25U0 '999,2500 329U,UUO0 'P~! -999.250{} ' 9 9 q ' -999.2500 -999. 250i, -999. 250~ -9e9.2b(., ii - 99 %. ~ 5 v -F99,2500 .1 h -999.2500 56. 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