Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-077
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-07 KUPARUK RIV UNIT 3B-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3B-07 50-029-21337-00-00 185-077-0 W SPT 5913 1850770 3000 2503 2503 2503 2503 340 365 365 365 REQVAR P Bob Noble 6/7/2025 MIT-IA to max injection pressure per AIO 2C.028 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3B-07 Inspection Date: Tubing OA Packer Depth 790 3310 3150 3140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250617140421 BBL Pumped:2.7 BBL Returned:2.7 Thursday, July 24, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-07 KUPARUK RIV UNIT 3B-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 3B-07 50-029-21337-00-00 185-077-0 W SPT 5913 1850770 3000 2885 2885 2885 2885 520 590 590 590 REQVAR P Austin McLeod 6/14/2023 Two year to MAIP. AIO 2C.028. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3B-07 Inspection Date: Tubing OA Packer Depth 940 3500 3340 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230614193716 BBL Pumped:2.5 BBL Returned:2.8 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Two year to MAIP. James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 11:05:51 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Braden head repair ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7,270' feet N/A feet true vertical 6,513'feet N/A feet Effective Depth measured 6,948' feet 6,484' feet true vertical feet 5,913' feet Perforation depth Measured depth 6,625' - 6,982'feet True Vertical depth 6,022' -6,293'feet Tubing (size, grade, measured and true vertical depth)3.5 J-55 6,834' 6,181' Baker BHL Packer 6,484' MD, 5,913' TVD.Baker FB-1 Packer 6,803' MD , 6,154' TVD. Packers and SSSV (type, measured and true vertical depth) Camco TRDP-1A-SSA SSSV 1,915' MD, 1,915' 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Roger Mouser / Brenne Green Contact Email:N1927@ConocoPhillips.com Authorized Title: Well Integrity Field Supervisor Contact Phone: 1-907-659-7506 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A Water-BblOil-Bbl N/A N/AN/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A N/A N/AN/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-077 50-029-21337-00-00 P.O. Box 100360 Anchorage , Alaska 995103. Address: N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025633 Kuparuk River / Kuparuk River Oil 3B-07 Plugs Junk measured Length 71' 3,269' 103'Conductor Surface 16" 9.625 Size 103' 7"Production 7,217 Casing 6,492'7,241' measured TVD 3,300' 3,300' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 12:57 pm, Jun 27, 2023 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927 @conocophilllips.com Reason: I am the author of this document Location: Date: 2023.06.27 12:25:48-08'00' Foxit PDF Editor Version: 12.1.2 Roger Mouser Date Event Summary Executive Summary 3B-07 Repair braidenhead by seal welding 05/23/23 (BH REPAIR) PREP FOR NDE (COMPLETE) 05/25/23 (BH REPAIR) NDE BH WELD AREA (COMPLETE) 06/14/23 (SW/WC) 3B-07 State witnessed Austin Mcleod MITIA Passed to 3500 psi. 06/14/23 (BH Repair) IA and OA DDT to 0 psi In progress. 06/15/23 (BH REPAIR) DDT-IA & DDT-OA (IN PROGRESS) 06/16/23 (BH REPAIR) DDT-IA & DDT-OA (COMPLETE), INSTALLED PURGE JEWERLY / PURGED OA WITH N2 (IN 06/17/23 (BH REPAIR) PURGE OA WITH N2, (CRITERIA MET FOR WELDING BH), FLOOR KIT REMOVED, NEXT STEP REMOVE FLOOR CLAMP & INSTALL' WOOD CELLAR. 06/23/23 (BH REPAIR) PURGED OA WITH 50 PSI OF N2 THREE TIMES. READY FOR MILLER PROHEAT SET UP. 06/24/23 (BH REPAIR) PURGED OA WITH 50 PSI OF N2 THREE TIMES. READY FOR MILLER PROHEAT SET UP. 06/25/23 (BH REPAIR) BRADEN HEAD WELD (IN PROGRESS) 06/26/23 (BH REPAIR) MISTRAS MT INSPECTION, DEMOB (COMPLETE), MITOA (PASS) @ 1800 PSI P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 27, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for the Bradenhead repair on KRU 3B-07 (PTD 185-077). If you have any questions, please feel free to contact me or my alternate, Brennen Green, at 659- 7506 Sincerely, Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Roger Mouser DN: O=Conocophillips, CN= Roger Mouser, E=N1927@ conocophilllips.com Reason: I am the author of this document Location: Date: 2023.06.27 12:24:58-08'00' Foxit PDF Editor Version: 12.1.2 Roger Mouser MEMORANDUM To: Jim Regg ' ��� I r p}' Z�JZ P.I. Supervisor 66 FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3B-07 KUPARUK RIV UNIT 313-07 Src: Inspector Reviewed By: r— P.I. Supry �J Comm Well Name KUPARUK RN UNIT 313-07 API Well Number 50-029-21337-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-077-0 Inspection Date: 6/15/2021 r Insp Num: mitLOL210616085329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 36-07 - a In J W TVD 5913 ubin 2860 g 2860 2860 2860 L PTD 1850770 1 0 ,f YP 5 (Test SI' 3000 IA T e Test p ----- - _--- -----_._-... 3500 � 3340 3310 , BBL Pumped_ 1 2.5 ' BBL Returned: z_5 ' OA 630 — 720 , -- — 720. 720 - - - Interval ! REQvAR -_LP/F P- „ — Notes: MIT -IA to the Maximum Anticipated Injection pressure per AIO 2C.028. Thursday, June 17, 2021 Page I of 1 MEMORANDUM Depth State of Alaska Well M01 Type Inj w TVD 5911 Alaska Oil and Gas Conservation Commission TO: Jim Regg1 P.I. Supervisor h �l r( �j DATE: Monday, July 8, 2019 SUBJECT: Mechanical Integrity Tests l IA 850 OA 530 } ConocoPhillips Alaska, Inc. 3B-07 FROM: Guy Cook -- KUPARUK RIV UNIT 3B-07 Petroleum Inspector 1 ✓ y Notes: MIT -IA every 2 years to maximum anticipated injection pressure per AIO 2C.028. Job completed with a Little Red Services pump truck and calif ated analog gauges. Sre: Inspector Reviewed B P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-07 API Well Number 50-029-21337-00-00 Inspector Name: Guy Cook Permit Number: 185-077-0 Inspection Date: 6/28/2019 Insp Num: mi[GDCI90628174206 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M01 Type Inj w TVD 5911 Tubing 2480 2481 - '480 also Test, SPT Test p51 PTD 18507A1 ". =BBL BBL Pumped: 2.5 BL Returned: 3000 2.5 IA 850 OA 530 } 1 3320 3191 - 3160 - 640 eao -- Interval . -- RBQVAR P/F -�_ 1 ✓ y Notes: MIT -IA every 2 years to maximum anticipated injection pressure per AIO 2C.028. Job completed with a Little Red Services pump truck and calif ated analog gauges. Monday, July 8, 2019 Page I of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,June 16,2017 Jim Regg J P.I.Supervisor t1 ('I Tol t ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B-07 FROM: Matt Herrera KUPARUK RIV UNIT 3B-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J g2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-07 API Well Number 50-029-21337-00-00 Inspector Name: Matt Herrera Permit Number: 185-077-0 Inspection Date: 6/7/2017 ✓ Insp Num: mitMFH170609142421 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-07 - LType Inj W"TVD 5913 Tubing 2764 2763 2763 • 2764 • PTD 1850770 Type Test SPT Test psi 3000 IA 890 3480 3370 3350 BBL Pumped: 2.8 BBL Returned: 2.6 OA 795 " 920 ' 925 925 Interval REQVAR P/F P '' Notes: 3480 IA test Pressure per operator.AJO 2C.028 SCANNED AUG 3 D :o17, Friday,June 16,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday, May 30, 2017 4:00 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 3B-07 (PTD# 185-077) Chris, Diagnostics have been completed on 3B-07 (PTD#185-077). The tubing and inner casing packoffs passed both positive and negative pressure tests. An MITIA passed to 3300 psi and an MITOA passed to 1800 psi. We are continuing the well on water-only injection service per AIO 2C.028 and will place the well on a 30-day monitoring period to determine if there is any further anomalies seen in the IA or OA pressures. If anomalies are seen,we will notify you of a path forward. Please let me know if you have any questions or disagree with the plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Sunday, May 28, 2017 4:54 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: 3B-07 (PTD# 185-077) SCANNED ,'UN 0 2 21:f1.-/ Chris, Kuparuk injector 3B-07(PTD# 185-077)was reported as having IA and OA pressures elevated after it had been used for freshwater pit dewatering pumping. We intend to leave the well in a stabilized injection state to conduct diagnostics, which will begin as soon as possible. We will inform you of the results of these diagnostics,and propose a plan forward if a problem is found with the well. A wellbore schematic and 90-day TIO plot are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, May 28, 2017 4:54 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 3B-07 (PTD# 185-077) Attachments: 3B-07.pdf; 3B-07 90-day TIO plot jpg Chris, Kuparuk injector 3B-07 (PTD#185-077)was reported as having IA and OA pressures elevated after it had been used for freshwater pit dewatering pumping. We intend to leave the well in a stabilized injection state to conduct diagnostics, which will begin as soon as possible. We will inform you of the results of these diagnostics,and propose a plan forward if a problem is found with the well. A wellbore schematic and 90-day TIO plot are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 I- r IP 0 6 C P °I ,„ > a) a) bo p ' 0 Q X co 0. L 0as c:i SZ N a Q -r.< 1v N YO WV W 6. Ln t -CC 000 C r r r r r r r r r rn 1- T C7 N z O .i ns - f0 O m a u v) ai } o Y D_ C D O 'D Q�= 0 f0 Y N >• 0. Q SO 0• J W LO LO LO c, LO l0 O t9 O co O d 0 (� -C U y,, J (7 Y Ln J 6) & 6 (A 6) N O ate-+ Q L31 LA O) 7 7 7 7 3 ', _C C C co .�. J Q Q Q Q Q Q Q Q Q E co L. a) C W • Z' Q Ln O r r N M f` C N T > Z O 0 .a E O >. Q) v u +, 2 .> .c1:276 Y 0 0 0 0 0 0 0 0 0 cco "o v L 6 w J J J J J J J J J C L_ y� L } W W W W W W W W W pp C m O F•- LL LL LL LL LL LL L.L. LL LL N E - N O S < J J J J J J J J J Ln > - < < < < < 4 < < Qom . ° _ 0 () ozzzzzz zzz (0 vo ILL LL LL LL L.L. LL LL LL LL N t U L_ W Y El) �j E CI)1z Y .� V co O C o _0 v a) N 0 a LL 0 ro a) > C 0:1 -o V m W J Q v _C oo > Q is S. O o O O r a a_ a_ a_ j a CD Q� .Ci CO O �' W O Ce J J J J W ,� N CO -; m a a E O O O O a a 41 PI N m t! ;1 i, j -Wi 7C tai U > 00 a 1 o �s b N - .12 03 E Id as co �jy, h L„ O OS .COCCO - 2 J J J J J> > > > > J J J _I 2F-i 1 5 yy M om in in W 41111 02,--Vilif ... w W W W W W W W L° W > > > > > > > > N reCeC Cer4C4C - Z Y Y YCCY Y Y Y Y E ya v u Li a a a Y a a a a a in > > > > > > > 0 @ 0 ® Y Y Y Y Y Y Y YAll T ton of x n a o p W O _ O U O v •v r v v v v v v 0 0 0 0 0 0 0 0 0 co o O o 0 0 0 0 0 0 co ® -` V LL L1 LL c0 LL LL LL Li LL E (vim1-- I-- O NI-- I- I- F I- ...° a) > , 0 0 0 Y a a a a a is 0 0 0 0 0 0 0 0 0 c U w X tor Lu rro� `f < a SO O O O O O O O O U LD O O O O O O O O O roc CC N. r 6 L() V CO o V V C `t M c0 N M CO N Ln M N pp M M M N- t0 N N Cr) N 0 N O NN 0 r N NNNNNNNNN L_ U n O) O) C) M O) O) G) O) O O .o C NNNONINNNN u. vn 000s- 00000 _ ...+ O O O O O O O O O )' in Ln Ln Ln Lf) an In in Ln c a) GJ• ct 76 0. O c 0) E N > U Q .� CLI w Y Q V ,_ = i 'C L ,,,;.Q-. N- 0 N- M in 0 0 N ate+ U a+ V) 6L yt z O Ncr, O N O Y Ly a+ = CLn e n J m m Q ch O a' a' m R d Q O N W M M L,.) M M M N V) z a) ICI C▪ m I '--1 L C (0 vi j y~ I--1 UG n 14 .c N 'O a C/o a L� Q it a a < Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, July 10, 2015 3:06 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Kuparuk injector 3B-07 (PTD# 185-077) signs of IA pressurization follow up. Attachments: image001.png; 3B-07 90 Day TIO plot.JPG Chris- Kuparuk injector 3B-07 (PTD# 185-077) is nearing the end of the 30 day water injection period. The IA passed an AOGCC witnessed MIT-IA on the 18th of June 2015, however the IA increased in pressure since the test was completed. The buildup rate in which the IA experienced during the water injection period has decreased and has begun to show signs of stabilization. Because the IA showed build up while on gas injection it is thought that the current IA build up is potentially caused from the gas breaking out of the fluid from the TxIA gas leak. It is CPAI's intentions to conduct a series of IA bleeds in an attempt to remove the gas/gas entrained fluid from the IA. At the completion of the IA bleeds, a 30 day water injection monitor period will be conducted to watch for continued IA pressure build up. If the pressure buildup continues the well will be shut in and diagnostics will be conducted in attempts to identify the leak source. If integrity is proven an AA for water injection only for TxIA communication while on gas will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a 90 day T/I/O plot. Dusty Freeborn I Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907) 943-0450 WELLS TEAM ConocoPhillips From: NSK Well Supv Sent: Monday, May 1 , e 12:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Kuparuk injector 3B-07 (PTD# 185-0 - 'ens of IA pressurization Chris- Kuparuk injector 3B-07 (PTD# 185-077) has shown signs of IA pressikisation. The increase in IA pressure was initially thought to be caused from the steady increase in injection rate, but the IA hontinued to increase after the injection rate and temperature leveled out. CPAI intends to leave the well on gas injection 1dra30 day monitor period to perform initial diagnostic testing. If IA re-pressurization is confirmed the well will be WAbecito water and monitored for 30 additional days to verify integrity with intent to AA for water injection only. Please let melZitoak if you have any questions or disagree with this plan. Attached are a well bore schematic and 90 day T/I/O plot. Dusty Freeborn I Jan Byrne w U L'') a C = CC Cr CrCecCY IU W LU LU LU p W Q U 0 Ln 0 0 0 0 0 0 0 WI C') Ln Ch ,r) kr) kr, In CC 1'-_ Or t Cn ( CO o w o0 LnOOoo N w O O N O O 0 O • o a) y m w ooLn000 W M Ln 41 Ln 40 Ln Ln lY ti 0 r .-j .? ro M or r r r N N N CC Ln n Ln Ln Ln Ln Lr, Ln 0 0 0 0 0 0 0 w N N N N N N CD N F-- l•"i L(j r r N r N .D (D LD Ly j L[j K J1 r• N- N- r- N- N- P- J O O O O O O O co000mmmm CO C7 co M co co co 36ap O oU U U CJ L, •1 V I i I I 1 1 03 r17 vJ y u, u1 y V o D 0 .40.1111111. 1- 03 07 ° cz t Lr) r r r.- O O • Q] r Cn *- .. ri r r x y E= .3) )o U U U U.1 I § § U U U U U U U U U U C, U, U 2 CV ^ U) ad la'won C T isd cn � w MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,June 24,2015 P.I.Supervisor ' \ (°(Z é(�S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B-07 FROM: Chuck Scheve KUPARUK RIV UNIT 3B-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-07 API Well Number 50-029-21337-00-00 Inspector Name: Chuck Scheve Permit Number: 185-077-0 Inspection Date: 6/18/2015 Insp Num: mitCS150621102925 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well! 38-07 Type Inj W'TVD 5913 - Tubing 2166 2166 Jr 2166 - 2166 - PTD I 1850770 iT a Test SPT Test psi 1500 IA 1730 2890 2830 - 2820 - YP Interval 4YRTST P/F P OA iso 400 - 400 400 Notes: SCANNED 0 3 2.u1,,-) Wednesday,June 24,2015 Page 1 of 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, May 11, 2015 12:10 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Kuparuk injector 3B-07 (PTD# 185-077) signs of IA pressurization Attachments: image001.png; 3B-07 90 Day TIO plot.JPG; 3B-07.pdf Chris- Kuparuk injector 3B-07 (PTD# 185-077) has shown signs of IA pressurization. The increase in IA pressure was initially thought to be caused from the steady increase in injection rate, but the IA has continued to increase after the injection rate and temperature leveled out. CPAI intends to leave the well on gas injection for a 30 day monitor period to perform initial diagnostic testing. If IA re-pressurization is confirmed the well will be WAGed to water and monitored for 30 additional days to verify integrity with intent to AA for water injection only. Please let me know if you have any questions or disagree with this plan. Attached are a well bore schematic and 90 day T/I/O plot. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 iftWELLS TEAM SCANNED MAY 1 1 2015 ConocoPhiliips 1 KUP 3B-07 • ConocoPhillips Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore APW WI Field Name Well Status Incl r) MD(ftKB) Act Ben gam) 500292133700 KUPARUK RIVER UNIT INJ 41.85 5,700.00 7,270.0 Comment H2S(ppm) Dab Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:TRDP Last WO: 36.00 5/27/1985 Well Conf.:-36-07.10/18/2012 8:30 47 AM Schemavc-Actual Annotation Depth)ftKB) End Date Annotation Last Mod...End Date Last Tag: 7,093.0 9/3/1997 Rev Reason:DRILL DATES osborl 10/16/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String String Top Thrd HANGER.24 CONDUCTOR 16 15.062 32.0 103.0 103.0 62.50 H-40 WELDED -.1 Cuing Description String 0... String ID...Top(RCB) Set Depth(0...Set Depth(TVD)...String WE..String...String Top Thrd SURFACE 9 5/8 8.921 31.0 3,300.4 3,300.1 36.00 J-55 BTC Casing Description String 0... String ID...Top)ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd v„9 PRODUCTION 7 6.276 24.0 7,240.9 6,492.2 26.00 J-55 BTC Tubing Strings Tubing Description (String 0... (String ID...(Top(ftKB) (Set Depth(f...(Set Depth(TVD)...(String Wt...(String•••(String Top Thrd coNDucrGR, TUBING 3 1/2 2.992 23.7 6,833.5 6,180.9 9.30 J-55 EUE 8RD 32-703 Com letion Details SAFETY VLV, 1,915 I o I Top Depth (TVD) Topinel Noml... Top(NKS) (ftKB) r) Item Description Comment ID(in) GAS LIFT y 23.7 23.7 0.59 HANGER FMC#5000 TUBING HANGER 3.500 1,950 yyy 1,914.6 1,914.6 1.31 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2,810 6,470.2 5,902.7 39.19 PBR BAKER PBR 3.000 6,483.9 5,913.4 39.23 PACKER BAKER FHL PACKER 3.000 6,633.8 6,029.1 40.22 BLAST JTS BROWN STEEL BLAST JOINTS(2) 2.867 SURFACE, .A l 6,701.5 6,080.8 40.51 BLAST RING BLAST RING(1) 2.867 31-3,300 6,757.7 6,123.4 40.75 BLAST JT BROWN STEEL BLAST JOINT(1) 2.867 GAS a 55 - 6,800.9 6,156.5 41.28 LOCATOR BAKER LOCATOR SUB 3.000 6,802.7 6,157.9 41.27 PACKER BAKER FB-1 PACKER 4.000 GAS 44 -- 6,820.9 6,171.5 41.19 NIPPLE CAMCO D NIPPLE NO GO 2.750 1E11 6,832.7 6,180.3 41.14 SOS CAMCO SHEAR OUT SUB 3.000 GAS LIFT, 5.072 Perforations&Slots Shot GAS LIFT. Top(TVD) Ben(TVD( One. 5.058 Top(ftKB)Ben(ftKB) (ftKB) (ftKB) Zone Dab lob Type Comment 6,625.0 6,631.0 6,022.3 6,026.9 C-4,36-07 6/22/1985 12.0 IPERF 4"Dresser Atlas;120 deg.ph GAS LIFT. 6,650.0 6,655.0 6,041.5 6,045.3 C-4,38-07 6/22/1985 12.0 IPERF 4"Dresser Atlas;120 deg.ph 0.044 C 6,672.0 6,676.0 6,058.3 6,061.4 C-3,38-07 6/22/1985 12.0 IPERF 4"Dresser Atlas;120 deg.ph GAS LIFT, f 6,703.0 6,715.0 6,081.9 6,091.0 C-1,38-07 6/22/1985 12.0 IPERF 4"Dresser Atlas;120 deg.ph 0,430 6,750.0 6,760.0 6,117.5 6,125.1 UNIT B,3B-07 6/22/1985 12.0 IPERF 4"Dresser Atlas;120 deg.ph PIR,0,470 6,883.0 6,921.0 6,218.2 6,247.4 A-3,3B-07 6/21/1985 4.0 IPERF 4"Dresser Atlas;120 deg.ph PACKER.0,484 6,942.0 6,982.0 6,263.1 6,293.2 A-2,3B-07 6/21/1985 4.0 IPERF 4"Dresser Atlas;120 deg.ph Notes:General&Safety INJECTION. t End Date Annotation 0,523 11/10/2010 NOTE:View Schematic w/Alaska Schematic-9.0 INJECTION. 0,594 (1,025-0.03 (PERF1, IPERF. 0,050-8.055 IPERF, 0,872-8,070 PERF, 8,703-0,715 PERF, 1 8,]50-0,700 I 71 INJECTION, 0.783 LOCATOR. 8,001 PACKER.0,803 NIPPLE.0.821 Mandrel Details Top Depth Top Port (TVD) Ind OD Valve Latch Sin TRO Run SOS.6,839 Stn Top(ftKB) (ftKB) r) Mal. Model (In) Sery Type Type (in) (p.1) m Run Date Co ... 1 1,955.7 1,955.7 1.47 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 622/1985 2 3,354.6 3,354.3 0.55 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/1985 II. 3 4,420.1 4,351.0 38.05 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/1985 IPERF. 6,889-8,921III 4 5,071.9 4,847.3 41.05 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/1985 5 5,657.8 5,287.5 41.96 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/1985 0,947-8802- ■ 6 6,043.8 5,577.7 40.18 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 6/22/1985 7 6,430.5 5,871.8 39.08 CAMCO MMG-II 1 12 GAS LIFT DMY RK 0.000 0.0 6/27/1985 8 6,522.7 5,943.4 39.35 CAMCO MMG-II 1 12 INJ DMY RK 0.000 0.0 12/1/1997 9 6,594.1 5,998.6 39.55 CAMCO MMG-II 1 12 INJ DMY RK 0.000 0.0 12/9/1994 PRODUCTION. T24-77:.;(1- D,7,,410"� & 10 6,782.6 6,142.3 40.86 CAMCO MMG-II 1 12 INJ DMY RK 0.000 0.0 12/9/1994 27 W U C7 CL = W Q U III o Wu7 K ca CI. IL Z' G p to o 7:1U.1 ,=, z a c ai z y W m N O W 41 d' M CL N Ci F- ul Li-) 0 w_ C_ Ln 1 N ---t Gi N- J O J , th M d6ap 0 0 0 0 0 0 0 0 U co r- 0 U, V M (N 0 V2 I I I I I I I I c u in , U C�- R .4u N C O "n i7 r ✓ .Y-$ G C J.C.c,O U A h 13 7 Q u, in ' GO b 1 r r- t• O O O N O N V m O an ---,_ - rl r- '' A r O: Ul ul G7 ,` Z vv., 19 0 0 0 0 0 0 0 0 0 � i N o a1 0 (N 0 U) 0 w Ud le bdcs t ui v v N N 'S inCw is Im:~ Project Well History File Covelage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier / Organizing(do.e) I~Two-Sided IIIIIIIIIIIIllllll D RescanNeeded IIIIIIIIIlllllllll RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes. No. [3 Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor O.~lih/c~r;~,-,.--~.. "~ OVERSIZED (Non-Scannable) [] Othe I (~) (j iD Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE; /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation C'~ x 30 = BY: BEVERLY (/~N VINCENT SHERYL MARIA LOWELL DATE:{~)/.~)/O~.. /S/ ~ Production Scanning Stage l BY: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN ~DIVlOUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~/ YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScan ned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, June 22, 2011 P.I. Supervisor Kee 6(& f/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B -07 FROM: Lou Grimaldi KUPARUK RIV UNIT 3B -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 2-- NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3B - 07 API Well Number: 50 029 - 21337 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110620152626 Permit Number: 185 - 077 - Inspection Date: 6/16/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3B-07 Type Inj. W TVD 5913 - IA 850 1717 1670 1657 P.T.D 1850770 TypeTest SPT Test psi 1717 OA 840 890 _ 890 895 Interval 4YRTST P/F P Tubing 2825 2830 2830 2830 Notes: 1 Bbl pumped and returned, good stable test. TIO shows climbing IA pressures and bleeds, could not mention to WIE as he was not on slope. Mentioned to his step -up fill -in Ian Ives. ! eck 4-5 I- (joops; :NNE JON 4 !U1„ Wednesday, June 22, 2011 Page 1 of 1 . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED AUG 1 3 200í Alaska Oil & Gas Cons Com . . . . mISSIon Anchorage August 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 sCANNED AUG 1 42007 \l{¡5~D1~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 20". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on July 27,2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner August 5, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ;¡;dJ~ M~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/7/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na !:Ial 3B-02 185-057 32" .4bbls 20" 7/27/2007 4.2 8/5/2007 3B-03 185-060 29' 5.2 bbls 20" 7/2712007 4.2 8/5/2007 3B-04 185-061 14' 2.5 bbls 20" 7/27/2007 4.2 8/512007 3B-05 185-075 SF N/A SF 7/27/2007 1.7 8/5/2007 3B-07 185-077 45' 6.1 bbls 20" 7/27/2007 6.8 8/512007 3B-08 185-087 14' .5 bbls 20" 7/27/2007 2.5 8/5/2007 3B-09 185-113 SF N/A SF 7/27/2007 1.7 8/5/2007 3B-11 185-115 20' 2.9 bbls 20" 7/27/2007 5.1 8/5/2007 3B-12 185-116 43' 7 bbls 20" 7/2712007 3.4 8/5/2007 3B-13 185-023 43' 5.9 bbls 20" 7/27/2007 11.9 8/5/2007 3B-14 185-024 11 ' 8.9 bbls 20" 7/27/2007 5.1 8/5/2007 3B-15 185-025 57' 9 bbls 20" 7/27/2007 7.6 8/5/2007 3B-16 185-026 43' 6.8 bbls 20" 7/27/2007 7.6 8/5/2007 iVIEJVIORANDUM . State of Alaska . \Iaska Oil and Gas Conscnation Commission TO: Jim Reg;::. P.I. Supcnisor DATE: TUCid.l\ !,:ne 1.2 ¡,C -: SlB./F:CT: \1c~'1:u1!:'a! ¡:e[C;::t'. :,,:òti FROM: John Crisp Petroleum Inspector KUPARLiK Rrv U'iIT 38-07 ~tð5'~o17 Src: Inspector Rey¡ewed By: ;....·,î n P.I. Suprv'.JiS·' _ Comm NON-CONFIDENTfAL Permit Number: 18S-0n -0 Inspector Name: John CrISp Inspection Date: 6/8/2007 Well Name: KUPARUK RIV UNIT 3B-07 Insp Num: mitJCr0706121321 IS Rei Insp Num: API Well Number: SO-029-21337-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wcli~-3B-07¡Typ-;i~.:GI- TVD-- ~-59¡:;-~-~--~ ~-~- ~ ------19;o~--~-~----- __~_~1_-__~_~L-_____ ___\ - -- -- _~TY:_ 1~07~01Typ.:.T~t-!S~ '_:r~tJ>s! ]500_ _ _ _ _ 220 ___ ~__ _ __ Interval-=)~T.s.:¡-__r.IF_ __ ~ _~ __ _ _!u~ing ,__~5~_~__3569_ __..!.5~~ 35()9__~_____~___ __ Notes: .4 bbl pumped tòr test. SCANNED JUN·.2 1 2007 Tuesday, June 12,2007 Page I of 1 . Conoc6Phillips . Mike Mooney Wells Group Team Lead Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 12, 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 38-07 (APD # 185-077) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 38-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ){,~ M. Mooney Wells Group Team Lead CPAI Drilling and Wells ( r· - ~ 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 185-077 1 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21337 -00 7. KB Elevation (ft): 9. Well Name and Number: RKB 84' 3B-07 . 8. Property Designation: 10. Field/Pool(s): ADL 25633, ALK 2566 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7270' feet true vertical 6515' feet Plugs (measured) Effective Depth measured 7093' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 103' 16" 103' 103' SUR. CASING 3216' 9-5/8" 3300' 3300' PROD. CASING 7157' 7" 7241' 6492' Perforation depth: Measured depth: 6625'-6631',6650'-6655',6672'-6676', 6703'-6715', 6750'-6760', 6883'-6921', 6942'-6982' true vertical depth: 6022'-6027',6041'-6045',6058'-6061', 6082'-6091',6118'-6125',6218'-6247',6263'-6293' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6833' MD. RBDMS BFl ;~ 0 7006 Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 6484'; 6803' Cameo'TRDP-1A-SSA' SSSV= 1915' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6883~6921~ 6942~6982' Treatment descriptions including volumes used and final pressure: refer to summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubino Pressure Prior to well operation na na 1790 -- Subsequent to operation 1840 -- 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 WAG 0 GINJD WINJD 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 Signature )-4. /i Phone Date 4.«.2/6r;.. ..... . . . Prenared bv dh"mn AI/sun-Drake 263-4612 ---' U K Ib , \\J A L ~ s·z.J·~ Form 10-404 Revised 04/2004 4'30 4 ;¡;:~: conOCO·PhiIliPAaSka, Inc. . KRU 38-07 OC",u>< ii ii API: 500292133700 Well Type: INJ Anole @ TS: 40 deo @ 6625 SSSV Type: TRDP Orig 5/27/1985 Angle @ TD: 40 deg @ 7270 Completion: Annular Fluid: Last W/O: Rev Reason: Delete SSSV note Reterenee LOQ: Ret LOQ Date: Last Update: 2/5/2003 Last Tag: 7093 TD: 7270 ftKB Last TaQ Date: 9/3/1997 Max Hole AnQle: 42 d~700 ;41 DescriDtion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 103 103 62.50 H-40 SUR. CASING 9.625 0 3300 3300 36.00 J-55 PROD. CASING 7.000 0 7241 6492 26.00 J-55 TlJbinâSfriRâ" fOBING xi Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 6833 I 6180 I 9.30 I J-55 I 8RD EUE iii:,»< > >x Interval TVD Zone Status Ft SPF Date Type Comment 6625 - 6631 6022 - 6027 C-4 6 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. loh 6650 - 6655 6041 - 6045 C-4 5 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. Iph 6672 - 6676 6058 - 6061 C-3 4 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. Iph 6703 - 6715 6082 - 6091 C-1 12 12 6/22/1985 ¡PERF 4" Dresser Atlas; 120 deg. loh 6750 - 6760 6118 - 6125 UNITB 10 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. loh 6883 - 6921 6218 - 6247 A-3 38 4 6/21/1985 IPERF 4" Dresser Atlas; 120 deg. Iph 6942 - 6982 6263 - 6293 A-2 40 4 6/21/1985 IPERF 4" Dresser Atlas; 120 deg. loh i> x> St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv PKR Mfr TYDe Run Cmnt 1 1956 1956 Camco KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 (6484-6485, 2 3355 3355 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 OD:6.151) 3 4420 4350 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 4 5072 4847 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 5 5658 5288 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 6 6044 5578 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 7 6430 5872 Cameo MMG-II DMY 1.5 RK 0.000 0 6/27/1985 X » St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 8 6523 5944 Cameo MMG-II DMY 1.5 RK 0.000 0 12/1/1997 - r-- Cameo DMY 12/9/1994 - r-- 9 6594 5998 MMG-II 1.5 RK 0.000 0 - - 10 6783 6143 Cameo MMG-II DMY 1.5 RK 0.000 0 12/9/1994 - - ......,;... IV >., ""/» - - DeDth TVD Tv De Description ID - - - - 1915 1915 SSSV Cameo'TRDP-1A-SSA' 2.810 == == 6470 5903 PBR Baker 3.000 - - 6484 5914 PKR Baker 'FHL' 3.000 = = 6803 6158 PKR Baker 'FB-1' 4.000 - - - - 6821 6171 NIP Cameo 'D' Nipple NO GO 2.750 - - 6833 6180 SOS Cameo 2.992 6833 6180 TTL 2.992 PKR (6Im6804, OD:6.151) 'i ~ "-----' - - - - = = - - ... . 3B-07 Well Events Summary . DATE Summary 04/20/06 Pumped 5 meth ahead followed by first stage (120 bbls) of 50 deg SWat 8.5 bpm, 4000 psi. Upon pump shut-down, discovered coolant leak on pump motor. Shut down for repairs. Once repaired, attempted to restart HPBD, pumping 5 meth follow by first stage (120 bbl SW) and 2nd stage (200 bbl) at 8.5 bpm, 4000 psi. Upon shut down between stages, discovered radiator on 2nd pump had cracked. Unable to continue job with only one pump; IA bled back to 500 psi, well brought back on injection. 04/21/06 Pumped 4 stage breakdown per program; 717 bbls 65 deg seawater at max rate of 8.7 BPM @ 4000 psi. Bled IA back to 100 psi, brought well back on injection. Operations notified to keep an eye on fA pressures as well warms back. ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 NOV '2 ~¿Ut14 Subject: Report of Sundry Well Operations for 38-07 (APD # 185-077) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 38-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, #t,JI/~ M. Mooriey 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 0 Alter Casing D Pull Tubing 0 Change Approved Program D Operat. ShutdownO 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 84' 1. Operations Performed: 8. Property Designation: AD L 25633, ALK 2566 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 7270' feet true vertical 6515' feet measured 7093' feet true vertical 6378' feet Length Size MD 103' 16" 103' 3216' 9-5/8" 3300' 7157' 7" 7241' Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 2004 .þ:::',;¿ Time Extensfon' 0 '0' Re-enter Suspended Well 0 5. Permit to Drill Number: 185-077 I 6. API Number: 50-029-21337 -00 Stimulate 0 Waiver 0 ." 'c 'édiher Exploratory 0 Service 0 9. Well Name and Number: 3B-07 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 103' 3300' 6492' Measured depth: 6625'-6631',6650'-6655',6672'-6676', 6703'-6715', 6750'-6760', 6883'-6921', 6942'-6982' Intervals treated (measured) true vertical depth: 6022'-6027',6041'-6045',6058'-6061', 6082'-6091', 6118'-6125', 6218'-6247', 6263'-6293' 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 Mike Mooney @ 263-4574 Mike Mooney øl /v1) Form 10-404 Revised 04/2004 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6833' MD. RBDMS 8FL NOV 2 9 2004 Packers & SSSV (type & measured depth) pkr= BAKER 'FHL'; BAKER 'FB-1' pkr= 6484'; 6803' Cameo'TRSP-1A-SSA' SSSV= 1915' 12. Stimulation or cement squeeze summary: 6883'-6921',6942'.6982' 13. Treatment descriptions including volumes used and final pressure: 708 bbls of slick seawater Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 1500 2250 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG0 GINJO 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: Contact Printed Name Signature CasinQ Pressure TubinQ Pressure WDSPLO Title Kuparuk Wells T earn Leader I Phone.. Date 1 ( z. 2/04- a RIG I N A L P-::::i:::~:::D::::~4612 PKR (6484-6485, 00:6.151) PKR (6803-6804, 00:6.151) ) ) ConocoPhillips Alaska, Inc. 111':= I 'I ~..\i : ::~,~,.J 1..11 I ~I~ .1- ..; 11: lit U. I.c IJ i I /111';" , IIJ: II Ir' 3~ ~t ---i~: ~.. ~.. =1: : .l1{~i ~ ~~ i~ ; ------ ~ .~ 0 -- ~.~ or- . r--- .... ;~ l ' ~, l ILJ!I Il =* 4- "'- KRU 38-07 3B.07 API: 500292133700 SSSV Type: TRDP Well Type: INJ Orig 5/27/1985 Completion: Last W/O: Ref Log Date: TO: 7270 ftKB Max Hole Angle: 42 deg @ 5700 Angle @ TS: 40 deg @ 6625 Angle @ TD: 40 deg @ 7270 Annular Fluid: Reference Log: Last Tag: 7093 Last Tag Date: 9/3/1997 Casing String. ALL STRINGS Description Size CONDUCTOR 16,000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String. TUBING Size I Top 3.500 0 Peñorations Summary Interval TVD 6625 - 6631 6022 - 6027 Rev Reason: Delete SSSV note Last Update: 2/5/2003 Top Bottom TVD Wt Grade Thread 0 103 103 62.50 H-40 0 3300 3300 36.00 J-55 0 7241 6492 26.00 J-55 TVD Wt I Grade I Thread 6180 9.30 J-55 8RD EUE Status Ft SPF Date Type Comment 6 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. ph 5 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. ph 4 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. ph 12 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. ph 10 12 6/22/1985 IPERF 4" Dresser Atlas; 120 deg. ph 38 4 6/21/1985 IPERF 4" Dresser Atlas; 120 deg. ph 40 4 6/21/1985 ¡PERF 4" Dresser Atlas; 120 deg. ph Bottom 6833 Zone C-4 6650 - 6655 6041 - 6045 C-4 6672 - 6676 6058 - 6061 C-3 6703 - 6715 6082 - 6091 C-1 6750 - 6760 6118-6125 UNITB 6883 - 6921 6218 - 6247 A-3 6942 - 6982 6263 - 6293 A-2 Gas Lift MandrelsNalves St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 1 1956 1956 Cameo KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 2 3355 3355 Camco KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 3 4420 4350 Camco KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 4 5072 4847 Cameo KBUG DMY 1,0 BK-2 0.000 0 6/22/1985 5 5658 5288 Cameo KBUG DMY 1,0 BK-2 0.000 0 6/22/1985 6 6044 5578 Camco KBUG DMY 1.0 BK-2 0.000 0 6/22/1985 7 6430 5872 Camco MMG-II DMY 1.5 RK 0.000 0 6/27/1985 Injection MandrelslValves St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 8 6523 5944 Camco MMG-II DMY 1.5 RK 0.000 0 12/1/1997 9 6594 5998 Cameo MMG-II DMY 1.5 RK 0.000 0 12/9/1994 10 6783 6143 Camco MMG-II DMY 1.5 RK 0.000 0 12/9/1994 Other l:)lugs, equip., etc.: . JEWELRY Depth TVD Type Description ID 1915 1915 SSSV Camco'TRDP-1A-SSA' 2.810 6470 5903 PBR Baker 3.000 6484 5914 PKR Baker 'FHL' 3.000 6803 6158 PKR Baker 'FB-1' 4.000 6821 6171 NIP Camco 'D' Nipple NO GO 2.750 6833 6180 SOS Camco 2.992 6833 6180 TTL 2.992 ') 3B-07 Well Events Surnrnary ) D~e Surnrnary 11/03/04 POOR BOY HPBD COMPLETED. PUMPED 708 BBLS OF 55 DEGREE SLICK SEAWATER. MAX WHTP 4000 PSI & MAX RATE 8.9 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN. [HPBD] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3B 06/05/03 Arend/Brake- APC Chuck Scheve Well 13B-01 P.T.D. 11850560 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj I pS I T.V.D. 15954 I Tubingl 23501 23501 23501 235011ntervall ~ Type Test Test psil 1500 I Casing I 12501 22501 22001 22001 P/F P.T.D. I1850750 TypeTest Test psiI 15oo I Casing I 13501 20751. 20501 20501 P/F Notes: P.T.D. I1850770 Type Test TestpsiI 1500 I Casing I 7501 22001 21501 21501 P/F Notes: Well 13B-12 P.T.D. I1851160 Notes: TypeTest Test psi] 1500 I Casing I 135Ol 20001 2000l 20001 P/F Well 13B-15 P.T.D. 11850250 Notes: Type Test Test psiI 15oo I Casing I 14001 25501 25001 25001 P/F Well 13B-16 P.T.D.[1850260 Notes: Type Test Test psiI 1500 I Casing I 13001 20251 20001 20001 P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0605_MIT_K RU_3B-16.xls 7/10/2003 KRU MIT's Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, tom_maunder~admin.state.ak.us, jim_regg@admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) ] Name: MIT KRU 3F 06-05-03.xls I [~MIT KRU 3F 06-05-03.xlsI Type: EXCEL File (application/msexcel) [ iEncoding: base64 ~t ........................................................ ] Name: MIT KRU 3B 06-05-03.xls MXT rd U 06_-05-03.x s] Type: EXCEL File (application/msexcel) ] ]Encoding: base64 I of 1 6/25/2003 4:37 PM MEMORANDUM 'l State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU' Jim Regg "~'Y/'/i P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3B Pad KRU NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 3B-01 TypetestI P I Testpsil 1489 I CasingI 1250I 2250I 2200I 2200 P.T.D.I 185-056 Type _ Notes: We,,I 3B-05 I Type,nj.I e I T.V.D.I ~ ITM I~°° I 3700 I 3700 137oo I lntervall 4 P.T.D.I 185-075 1Type testI P ITestpsil 1484 I CasingI 1350I 2075I 2050I 2050 Notes: WellI 3B-07 I Type Inj.I G I T.V.D.I~" ITM I37°° I 3700I~oo I~oo I,nterva, I 4 P.T.D.I 185-077 ITypetestl P ITestpsil 1479 ICasingI 750 I 22001 2150 I 21501 P/F I -PI Notes: WellI 3B-12 I Type,r,j.I G I T.V.D. I 5743 I Tubingl= 0 I I I I,nte v ,l 4 P.T.D.I 185-116 ITypetestl P ITestpsil 1436 I Casingl 1350I 2000I 2000I 2000I P/F I ~P Notes: Well P.T.D. Notes: Well P.T.D. 'Notes: 185-025ITypetestl P I Testpsil 1442 ICasingI 1400I 2550I 2500I 2500I P/F I --P 3B-16 185-026 ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= .Other (describe in notes) Test's Details I traveled to Conoco Phillips 3B Pad in the Kuparuk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: O Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0605_M IT_KRU_3 B- 16_cs.xls 6/24/2003 JUL O 8 2003 " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X WI to WAG Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4407' FNL, 497' FEL, Sec. 16, T12N, R9E, UM 5. Type of Well: Development __ Exploratory __ Stratigraph ic __ Service__X (asp's 518531, 5991990) 6. Datum elevation (DF or KB feet) RKB 84 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3B-07 At top of productive interval 1332' FSL, 1214' FwL, Sec. 15, T12N, RgE, UM At effective depth At total depth 3842' FNL, 3658' FEL, Sec. 15, T12N, R9E, UM (asp's 520646, 5992563) 9. Permit number / approval number 185-077 / 10. APl number 50-029-21337 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CON DUCTOR 103' SUR. CASING 3216' PROD. CASING 7157' 7270 feet Plugs (measured) 6515 feet feet Junk (measured) feet Size Cemented Measured Depth True vertical Depth 16" 227 sx Permafrost C 103' 103' 9-5/8" lo8o sxAS III & 340 sx Class G 3300' 3300' 7" 460 sx Class G 7241' 6492' Perforation depth: measured 6883-6921' 6942-6982; 6625-6631; 6650-6655; 6672-6676; 6703-6715; 6750-6760 ~ "+. J:=, -;._.: .,= :j .. ;..., ,. _., true vertical 6218-6247; 6263-6293; 6022-6027; 6042-6045; 6058-6061' 6082-6091; 6118-6125 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, J-55 Tbg @ 6833' MD. BAKER 'FHL' @ 6484' MD; BAKER 'FB-I' @ 6803' MD; CAMCO 'TRDP-1A-SSA' @ 1915' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Dailv Average Production or Injection Data Gas-Mcr Water-Bbl 1807 1799 Casing Pressure 10 Tubing Pressure 2544 10 3617 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S~gned ~ Engineering 'jeffA. p~en~. ~~/'/~~~ Title Production Supervisor Questions? Carl Jeff Spencer 659-7226 Date /~' Prepared by Robert Christensen 659-7535 Form 10-404 Rev 06/15/88 · RBDI S BFL ,. APR 2 9 20¢2 SUBMIT IN DUPLICATE 3B-07 DESCRIPTION OF WORK COMPLETED SUMMARY ARCO Alaska, Inc~'-''~ Post Oflic~ .~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys as or spinner logs listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me'at (907) 263-4978. Sincerely, ~1. H' Kraly Operations Engineer MHK/SPT'pg-0163 Attachments ARCO Alaska, Inc. Is a Subsidiary o! AtlanllcRIchlieldCompany . k u P~,e.,v 'C i STATE OF ALASKA ALA,. _-t OIL AND GAS CONSERVATION CON ..... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other I~' 2. Name of Operator ARCO ATaska, Inc 3. Address PO Box 100360, ^nchorage, AK 99510 4. Location of well at surface 869' FSL, 499' FEL, Sec. 16, T12N, RgE, UM At top_ of productive interval 1332' FSL, 1214' FWL, Sec. 15, T12N, R9E, UM ,9,, U, At~a~Je~_, 1619' FWL, Sec.15, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 84' Feet 6. Unit or Property name Kuparuk River Unit 7.3B_7Well number 8.~p_~roval nu mber ~P=I2~ ~e r In Pool ]<uparuk River 0il Pool 11. Present well condition summary 7270' MD Total depth: measured feet true vertical 6513' MD feet Effective depth: measured 7155' MD feet true vertical 6425' MD feet Plugs (measured) Junk (measured) None None Casing Length Size Structural Conductor 100 ' 16" Surface 3300' 9-5/8" Production 7241 ' 7" XX~R~,rxxxxxx Perforation depth: measured true vertical Cemented Measured depth 227 SX PF "C" 100' MD 1080 SX ASIII 3300' MD & 340 SX Class G 460 SX Class G 2417' MD True Vertical depth 100' TVD 3300' TVD 6493' TVD 6750'-6760', 6650'-6655', 6703'-6715', 6625'- 6631', 6672'-6676 6942'-6982', 6883'-6921' MD 6118'-,6125', 6041' -6045', 6082' -6091', 6022' -6027', 6058' -6062 6263' -6293', 6218' -6247' TVD Tubing (size, grade and measured depth) 3½", J-55, 9.4 lb/ft., Tail @ 6823' MD PI~cgers a~LS~SX~ ,an~ar~arSU~d-~e~th~792' Camco TRDP-1A @ 1904' aKer , 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure oii ,l 8as Cons. AnChorage C°m~'S$1oo 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 600 900 -0- 500 150 Tubing Pressure Subsequent to operation -0- -0- 2000 1700 1500 14. Attachments Converted 1'rom oil producer to water injector on 1/24/87 Daily Report of Well Operations j~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge r igned ,~, j~ ~,/I/I,..[ ~/~-,,.,/..~,~2T i t I e Sr. Operations Engineer Form 10-404 Rev. 12-1-8~ - Date J~,,~/ 3/16/88 Submit in Duplicate ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL r"~NTRACTOR _ REMARKS IPBDT -21.55/ IFIELD - DISTRICT- STATE ~~ot~. IDAYS I DATE I o I 0 Te's r L'o r~,~ l~7'~ I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. Chill Factor I Visibility I Wind Vel. °F °FI miles[ knots ., ATTACIIMENT 1 PAGE 3 KUPARUK RIVER FIELD CONSERVATION ORDER RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl NUMBER NUMBER 50-029 '""~3B-01 '"'"' 21318 '""~3B-07~/' 21337 "'""~3B-12~/'' 21370 3C-02 21414 "~3F-03~--'/ 21448 3J-04 21400 '"'~3J-05~''/ 21436 'x'~3J-08~ 21~39 3J-13 21495 3J-16 21498 DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY WELL COMPLETION 01/23/87 05/23/87 SPINNER INITIAL A&C SS 01/23/87 05/22/87 SPINNER INITIAL A&C SS 01/24/87 05/21/87 SPINNER INITIAL AEC SS 01/09/86 06/22/87 SURVEY FOLLOWUP AEC SS 05/24/87 SPINNER INITIAL AEC SS 04/01/87 SURVEY INITIAL A S 05/28/87 SPINNER INITIAL AEC SS 05/28/87 SPINNER INITIAL AEC SS 03/01/87 SURVEY INITIAL A S 03/31/87 SURVEY INITIAL A S 01/21/87 05/21/87 02/02/87 02/02/87 02/02/87 02/02/87 ZONES TAKING WATER AEC AEC AEC AEC AEC A AEC AEC A A INJECTION BWPD 2530 A SAND 1240 C SAND 1927 932 1072 ! / / RECEIVED STATE OF ALASKA ALASI. .... OIL AND GAS CONSERVATION COMN..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,,l~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage; AK 99510 4. Location of well at surface 869' .FSL. 4.99' FEL, Sec 16, T[2N, RgE UM At top or proaucuve interval ' ' 5. Datum elevation (DF or KB) RKB 84 6. Unit or Property name KuDaruk River Unit 7. Well number 3B-7 8. Permit number Permit #85-77 9. APl number 50-- 029-21337 1332' FSL, 1214' At effective depth 1418' FSL, 1546' At total depth 1437' FSL: 1619' 11. FWL, Sec.15, T12N, R9E, UM FWL, Sec. 15, T12N, R9E, UM FWL: Sec.]5.. T12N: RCIE; Present well condition summary Total depth: measured 7270' ND feet true vertical 6513' MD feet 10. Pool K~JnarlJk Rivpr Oil Pool ! Plugs (measured)None Effective depth: measured 7155' MD feet true vertical feet 6425' MD Junk (measured) None Casing Length Size Cemented Measured depth Structural 100' 16" 227 SX PF "C" 100' MD Conductor Surface 3300' 9-5/8" 1080 SX ASI II 3300' MD xxx:kr~RAqX~'~te & 340 SX Class G Production 7241' 7" 460 SX Class G 7241' MD xxx Jex xxxx Perforation depth: measured 6750'-6760' MD, 6650'-6655' MD, 6703'-6715' MD, 6625'-6631' MD 6672' -6676' MD, 6942' -6982' MD, 6883'-6921' MD feet true vertical6118'-6125' TVD, 6041'-6045' TVD, 6082' 6058' -6062' TVD, 6263' -6293' TVD, 6218' Tubing (size, grade and measured depth) 3½" J-55 9 4 lb/ft Tail @ 6823' Packers and SSSV (type and measured depth) ~ue Vertical depth 100' TVD 3300' TVD 6493' TVD -6091' TVD, 6022' -6027' T -6247' TVD ' ' ,) Li'. Bnk~Y- FHI 0 RI[gq' Rnl<'~Y. DR-1 0 Ig7Cl?'. ¢'nm,'-n TDI'ID_IA I'~ lan/i, 12.Attachments Description summary of proposal ~ Detailed operations program Convert well from oil producer tn Water injector 13. Estimated date for commencing operation January 10, 1987 14. If proposal was verbally approved Date approved Name of approver Dat$2/24/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge f.<~,(.f_../r.~/-~.,/ Title Sr. Operations Engineer Signed ~--,)"L-1 y ~ ,~-t ' ~ Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance '~'"' ¢ Conditions of approval Commissioner by order of oomm ss o. Submit in triplicate Form 10-403 Rev 124-85 'D, ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-29-86 TRANSMITTA~ ~ 5652 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes plus Listing: Schl: One copy of each 3B-7 05=25-85 Run #1 3N-11 04-12-86 Run #1 Receipt Acknowledged: Date: ARCO Alaska, inc..×'-'~ ' Post Office B,... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 ¢ TranSmitted herewith are the following items. return one signed copy of this transmittal. DATE 12-31-85 TRANSMITTAL # 5495 Please acknowledge receipt and Open Hole LIS Tapes Plus Listing/ schl/ One of each 2H-7 12-18-85 Run #1 2H-8 12-il-85 Run #1 --' 3A-15 12-17-85 Run #1 ~ 3B-7 05-25-85 Run #1 ~' 3F-12 12-11-85 Run #1 3J-11 12-20-85 Run #1 2875.o-8o87.5 0 F - 1770 0-7889 ~995 . 5- 768o . o~ 2 ~A~--3 - ( / Ataska Oil & Gas Cons. Commission ',---' Anchorage Receipt Acknowledged: STATE OF AK. Date: AR~ Ale,lira In¢ is a Subslcliar¥ o! &llantlcRicll~ielclCom=sn¥ ARCO Alaska, lm Post Offid ,ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-15-85 r'l~-~ -,~ ~' ~ "~ ~ r. RETURN TO: ARCO ALASKA, iNC. nU." 'PAaUm ......... OPEF~A, RECOP~S CLERK ATO-!I!5~ P.O. ~OX 100560 ~" ~ ' ~ AK 99510 ~.~CnO ~.GE, , =mD HERL'~;i~ ' ~ECE!FT ,%ND REq'U'-:-'_ ,~, O~;L SiGN CbL/CET FINALS/ SChL/ ONs * · - iQ-i4 ~ Cbb/VDL 06- ~!k-~ / CBL/VDL 06- 2V-!4 /CsL/VDL 06- ~3b-5~ CbL/VDL- ~3b-6 ~ C~L/VDL 0~- '~:~'/ .... '~ CbL / VD L U 6- 3~-!0v~ CET LOG 06- 15 FO~ ' "" 'TNG~,~v~,_ I"SRS.~ PLEASE ACKNO~iLEDGE L;D CC'.z OF ~n~5 mt':"~Si';l~-~..~,.. ~' *~L. 02-85 RUN %! 5900-~87i 0S-~5 :~UN %1 6i40-9146 ~ 85 ~UN ~! 5090-7056 0i-S5 HUN ~i 5500-7990 01-85 RUN ~I 5900-6656 05-S5 P;UN ~1 ~690-7120 30-85 RUN ~! 4840-7137 I-',ECEIr~':,= .~ &CKNOWLEDGED: L;PAE '~ CU .... ~ Ci~gVRON ARCO AJaska. Inc. is a SuDsid,ary of Allarl!lcRichlieldComoany ARCO Alaska, Inc. Post Office B 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-7 Dear Mr. Chatterton- Enclosed is a copy of the 3B-7 Well History (completion include with the Well Completion Report, dated 9/9/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L94 Enclosure cc' 3B-7 Well File details) to ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanficRichfiel(~-":,mpany v~ Dai;~Tell History-initial Report Daily wM'k prior tO I~ou(~ling ~',ould De m, mmll-,Zi4 irlClulive dAtAa only. Alaska : North Slope Borough Field ~halle er Unit Kuparuk River I ADL 25633 Aut~. or W.O. no. ITitle AFE 604372 I Completion Nordic I API 50-029-21337 Alaska IWlll no. 3B-7 Operator ARCO Alaska, Inc. Spudaed or W.O. I~eun IData IHour Complete 6/21/85 2400 hrs. Date and 6/2t/85 Complete recor~i for IlCh day rel)oned I^.R.Co', w.~. 56 · 24% Prior ItatUl if · W.O. 7" @ 7241' 7155' PBTD, Perforating 10.3 NaCl/Br Accept Rig @ 2400 hfs, 6-21-85. NU tree &tst BOPE. RIH & pert w/4" guns, 4 SPF f/~-6921' & 6942'-6982'. RU DA. The aoove i· correct For form Dreparetion anc~distrihufJon, see Procedure· Manual. 5Action 10, Drilling, PAge· 86 and 87. DAte / I Title Drilling Superintendent AR3B-459-1-B INumt~er all da~ly wall hi·tom/ form· consecutively as they are 13reDarecl for each well. iPa~e no. ARCO Oil and Gas Compaq., Daily-Well Hist--- Final Report Ifletructi~a: PrePare and suomit the "l:inll lief)off" On ~e fi~t Wednesday after allowable has b~n assigned or well is Plugff~. Ablnoonl~ . ~ld. o~zaho~ il space is available. Accou~ti~g COSt cente~ c~e Count~ or Pa~ish J S~e ' ~aska . . ~ Alaska Fiet~ North Slope Borough Lease Or Un,t well no. Kuparuk River ADL 25633 3B-7 Aura. or W.O. no. )Ti~te AFE I Completion Nordic 1 APi 50-029-21337 Operator } A.R.Co. W I. ARCO Alaska, lac. {Da,, 56.24% SpuOdec~ Or W.O_ begun I Complece I 6/21/85 Iotel number pt wells (active or machve) Oh DSt center priOr tO plugging and bendonment of th,s well our ' ' ' 2400 hrs. Date an~ depth · as of 8:00 a.m. Olo TD 6/22/85 thru 6/24/85 Clas$ilications Ioil. gas. etc. I 0il ProClucing method Flowing Potential test c2ata Complete record for each day reported 7" @ 7241' 7155' ?BTD, RR Crude/Diesel RIM w/4" csg gun, pert f/6901~-6883'. RIH w/5" csg gun, pert w/12 SPF @ 6760'-6750', 6715'-6705', 6705'-6703', 6676'-6672', 6755'-6650' & 6631'-6625'. RIB, set pkr @ 6792' WLM. RIH w/3~" compl rn 209 Jts of 3-%" 6.4~ J-55 EUE 8rd tbS. Drop ball set pkr, shear PBR, Cst ann to 2500 psi, tsc cbs to 2500 psi. Set BPV, displ to diesel/crude. SITP - 550 psi. Tst ann to 2000 psi, tst easY; OK. Tst Orifice Vlv to 2000 psi; OK. Shear out ball, set B?V. RR @ 0830 hfs, 6-22-85. , t ,,w ~o IPs OePlh 7155' PBTD O~'t; )Ki~d pt rig 0830 hrs. - 6/22/85 I Rotary j 'Type completion (stogie, ~oa;. etc.) ~ Single } Kupa~k Sands t ~ell no. 6a,e ........ 1Rese~eir ' ' ' PrOclucing Interval ' Oil or gasTest t,me 'i~.oouct,on C~ P~ ~est 'G'~s Der day ,., PumD size, SPM X length Cho~e'size T.~. ~:P. ; Water % GOR Gray,fy' ' Allowable Effec[ive da~a cortecte~ ................. ................... see Procedures IVlenu~l. Section 10. Drilling. Pages 86 anct 87. AR3B-459-3-C INumDer ell daily well history forms coflsecutively as they are prePa~e~ for each well. no. -- Ol~l~io¢~ oi Atl~t~c~ Khfi,~4~O4~P~nY ARCO Alaska, Inc. { Post Office B~^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-7 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L60 Enclosure If you RECEIVED Oi~ & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA .L ._ AND GAS CONSERVATION CO, ,dlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-77 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21337 4. Location of well at surface 9. Unit or Lease Name 869' FSL, 499' FEL, Sec.16, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1332' FSL, 1214' FWL, Sec.15, T12N, RgE, UM 3B-7 At Total Depth 11. Field and Pool 1437' FSL, 1619' FWL, Sec.15, T12N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 84' RKB ADL 25633 ALK 2566 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 05/21/85 05/25/85 05/27/85* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ] 20. Depth where SSSV set ] 21.Thickness of Permafrost 7270'MD,6513'TVD 7155'MD,G425'TVD YES i-~X NO [] 1915 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, Gyro (GCT), CBL . 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 100' 24" 227 sx Permafrost C 9-5/8" 36.0# J-55 Surf 3300' 12-1/4" 1080 sx AS III & 340 sx Class G 7" 26.0# J-55 Surf 7241' 8-1/2" 460 sx Class G 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) 6942' - 6982' w/4 spf, 120° phasing 3-1/2" 6833' 6484' & 6803' 6901' - 6921' 6883' - 6901' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6750'-6760' 6650'-6655' See attached Adde:~dum~ dated 7/26/85~ for frac data. 6703'-6715' 6625'-6631' w/12 spf, 120° phasing 6672'-6676' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 1.0-407 * NOTE: Rev. 7-1-80 41aska Tubing was run and the well perforated 6/22/85. G~I~./~(~lsl "Submitinduplicate CONTINUED ON REVERSE SIDE/['90h0h%,~' COfl$. Coth[~!~sior~ 29. W 30. · GEOLOGIC MARKERS ~ FORMATION TE~STs . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6624' 6021' N/A Base Upper Sand 6715' 6090' Top Lower Sand 6863' 6202' Base Lower Sand 7037' 6334' 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~?~jT;"~--~ ~-~LL)~L."L._.~ Title Associate Engineer Date . . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate productiOn from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none''. Form 10-407 ADDENDUM WELL: 6~7~85 7~02~85 7/17/85 3B-7 Rn CBL f/7130' - 4930'. Rn gyro f/7130' - surf. Frac well in 7 stages w/298 bbls of gelled diesel, 1000# of 100 mesh & 5124# of 20/40 mesh. Screened out 26 bbls short of displm't. Rn swage & tag fill @ 7147'. Btm perf @ 6983'. Secure well. Turn well over to Production. Drilling~ Superintendent RECEIVED ~,laska Oil & G~$ Cons. Commission Anchorage ARCO Alaska, Inc/ Post Office ,.~,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-2 1-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B ' P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS, PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA '"-'lC- 4 '- 07-23-85 '-' 1C-5~ 07-29-85 '~ 1C-5 f- 07-30-85 "-'lC- 6 ~ 07-25-85 ""-~iC- 6 ~ 07-24-85 ~iD~. 8 -- 07-30-85 ~lH-3~ ~ 07-30-85 -"--iR-5- 07-05-85 -"--1~,- 6' 07-06-85 -"- 1R- 8 - 07-Ui:{- 85 '~ 1Y-10- 07-27-85 ~iY-11- 07-28-85 ~ 2A-2 .--- 07-04-85 "" 2~-13" 07-30-85 "-2U-14' 06-30-85 "- 2U-14 .... 07-01-85 "' 2U-15- 07-08-85 ~ 2V-2 07-27-85 "' 2V-2- 07-28-85 ~ 2N- 7-- 07-26-85 STATIC BHP PBU PBU STATIC BHP STATIC-BHP STATIC BHP STATIC BHP DHP & MISC. BHP & MISC. STATIC BHP & t,~ISC. STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESSURE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU ~2W-7~ 07-27-85 'A' SAND PBU 2X-15~' 07-09-85 FLOWING BHP & FLUID I.D. 2X-15 ~ 07-U4-85 FLOWING BHP & TEMPEi{ATURE ' 2Z-l- 07-05-85 - BHP SURVEY & MISC. ~2Z-6- ~4-08-85 ~3B-7 ~ 06-27-85 ' 3B-8~ 06-28-85 ~ 3B-8~ 06-27-85 ~3B-9 J ~7-18-85 3B-11 07-20-85 ' 3B-12- 07-21-85 ' 3C-11~-07-29-85 STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & HISC. BHP SURVEY & MISC. STATIC B}~P & MISC. STATIC BHP ~ MISC. RECEIPT ACKNOWLk. DGED: BPAt.'* B. CURRIER CHEVRON* D & ~* DISTRIBUTION: DRILLING ~,~. PASHER L. JOHNSTON EXXON HOBIL* PHILLIPS OIL* N~K CLERK J. RATRMELL* · ARCO Alaska. Inc. is a S~bsJdiary of AllanticRichfieldCompa~y CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAPICO ....... ~:,~. l;or;~issJor~ STAT£ OF AL'A:SKA* SOHIO* UNION* K.TULIN/VAULT ARCO Alaska, Inc/~'~' Post Office ,.,~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO:5292 R.E%'URN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE kECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK %~ELL PRESSURE REPORT--ENVELOPE FACE DATA lB-1.-~ 05-30-~5 CAMCO ~3B-15 05-28-85 -"lB-2 ~ 05-30-85 CAMCO 3B-16---~ 05-28-85 "'lB-4- - 05-16-85 CAMCO ~ 3C-11~' 07-29-85 '- lC- 4 07- 2 4- 8 5 CAIn]CO -- 1C-6-~' 07-25-85 CAMCO "iD- 8 ---' U 7- 3 0- 85 CALICO --iH- 3 ' .07- 30--85 CAMCO ~lQ-13'~ 0~6-24-8 5 "' lQ- 14-~ 06-23-85 CAMCO '"lQ- 15-"" 06- 2 1- 85 cAMCo '-lQ-16/ 06-21-85 CAMCO '- iR- 5-~-- 07- 05- 85 CAHCO ' 1R-6 / 07-06-85 CAMCO ~" iR- 7/ 07- 06- 85 CAMCO ~- 1R-8 ~- 07-08-85 CAMCO "-2A- 2-'~ 07-04-85 OTIS "'2W- 7" 07-26-85 DRESSE~{ '-2V-3 07-11-85 OTIS '~2W- 15'~ 08-04-85 OTIS 3B-1-~ 06-14-85 ???? ' 3B-2.? 06-14-85 CAMCO 3B-3~ 06-28-~5 OTIS "3B-3' 06-15-85 CAMCO --3B-4~' 06-15-85 CA~]CO "3B-5 ? 06-26-85 CAMCO ., ' 3 B- 6 ~ 06- 2.6- 85 CA[~CO -~3B- 7'~ 06-28-85 CA~]CO < 3B-7--~ 06-27-85 CAHCO -' 3B- 8-'- 06-28-85 OTIS "-3B-9'~ 07-18-85 CA~]CO -~3$- 10-~ 07-20-85 CA/~]CO '-3B-11 -~ 07-20-85 CAMCO -3B-12-~ 07-21-85 CAHCO ' 3B-13' 05-29-85 OTIS -'3B-14 05-29-85 OTIS RECEIPT ACKNO~4LEDGED: DISTRIBUTION: BPAE* DRILLING W. PAShER B. CUSHIER L. JOHNSTON EXXON CHEVRON* ~,~3B I L* PHILLIPS OIL* D & H* NSK CLERK J. RATHMELL* OTIS OTIS CAMCO o commission STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. ~s a Subsidiary of AtlanticRichfieldCompany RETURN TO: TRANSMITTED RECEIPT AND OPEN HOLE (ONE * OF 3B-6 ~ 5" 2*' 2 5" 2 ARCO Alaska, Inc Post Office ,._~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE:07-16-85 TRANSMITTAL NO:5251 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B ~ P.O. BOX 100360 ~ ANCHORAGE, AK 99510 HEREWITH ARE THE FOLLOWING ITeM E ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/SCHL EACH)' DIL/SFL-GR DIL/SFL-GR DEN/NEU-GR PORO DEN/NEU-GR PORO DEN/NEU-GR RAW DEN/NEU-GR RAW CYBERLOOK 3B-7 5" DIL/SFL-GR 2" DIL/SFL-GR 5" DEN/NEU 2" DEN/NEU 5" DEN / NEU 2" DEN/NEU CYBERLOOK 3B-8 /5" DIL/SFL-GR 2" DIL/SFL-GR 5" DEN/NEU 2" DEN/NEU 5" DEN/NEU 2" DEN/NEU CYBERLOOK 05-19-85 RUN fl 4245-8767 05-19-85 RUN fl 4245-8767 05-19-85 RUN fl 4245-8741 05-19-85 RUN-fl 4245-8741 05-19-85 RUN #1 4245-8741 05-19-85 RUN fl 4245-8741 05-19-85 RUN fl 8049-8710 PORO PORO RAW RAW 05-23-85 RUN fl 3296-7252 05-23-85 RUN #1 3296-7252 05-23-85 RUN #1 5100-7230 05-23-85 RUN #1 5100-7230 05-23-85 RUN fl 5100-7230 05-23-85 RUN #1 5100-7230 05-26-85- RUN fl 6400-7230 PORO PORO RAW RAW 06-02-85 RUN fl 3941-8472 06-02-85 RUN fl 3941-8472 06-02-85 RUN fl 3941-8446 06-02-85 RUN #1 3941-8446 06-02-85 RUN #1 3941-8446 06-02-85 RUN fl 3941-8446 06-02-85 RUN fl 7500-8333 RECEIPT ACKNOWLEDGED -~_ BPAE DRILLING*BL B. CURRIER L. JOHNSTON CHEVRON MOBIL D & M*BL NSK CLERK*BL DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL*BL Ap.c,i~ut'og" STATE OF ALASKA*BL SOHIO /SE UNION K.TULIN/VAULT*FILMS ARCO Alaska. !nc. is a Subsidiary of AtianticRichf,eldComl~any ARCO Alaska, Inc. Post Office Bo~, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-7 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for 3B-7. I have not yet received a copy of the Well History (completion details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU10/L66 Enclosures J u L .t 1985 Alaska Ou & Oas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA :~----~.:, ALASKAL -AND GAS CONSERVATION CC IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. S~atus of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-77 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21337 4. Location of well at surface ~L©CA~IO~S 9. Unit or Lease Name 869' FSL, 499' FEL, Sec.16, T12N, RgE, UM ~ VE&iF,E~) ~ Kuparuk River Unit At Top Producing Interval~ Sur~. ~-~'~Sur~r-~_~ 10. Well Number 1332' FSL, 1214' FWL, Sec.15, T12N, RgE, UM ~H.~H 3B-7 At Total Depth~ 11. Field and Pool 1437' FSL, 1619' FWL, Sec.15, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 84' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 05/21/85 05/25/85 05/27/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7270'MD,6513'TVD 7155'MD,6425'TVD YES F~X NO []I 1915 feet MD 1600' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Ca'I, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 100' 24" 227 sx Permafrost C 9-5/8" 36.0# J-55 Surf 3300' 12-1/4" 1080 sx AS Ill & 340 sx Class G 7" 26.0# J-55 Surf 7241' 8-1/2" 460 sx Class G 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) 6942' - 6982' w/4 spf, 120° phasing 3-1/2" 6833' 6484' & 6803' 6901' - 6921' 6883' - 6901' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6750' -6760' 6650'- 6655' N/A 6703'-6715' 6625'-6631' w/12 spf, 120° phasing 6672' -6676' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR !OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA ' iVED NONE Alaska 0i! & Gas Cons. commission Anchorage Form 10407 * NOTE: Tubing was run and the well perforated 6/22/85. GRU10/WC14 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. _1~11~' - '30.. ~ · . GEOLOGIC MARKERS " FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6624' 6021' N/A Base Upper Sand 6715' 6090' Top Lower Sand 6863' 6202' Base Lower Sand 7037' 6334' ; 31. LIST OF ATTACHMENTS . 32. I hereby certify that ti~e ...... J .... ~ correct to foregoing is true and the best of my knowledge Signed ~.~ /~/7%/~ ,~/~L~L~/ Title Associate Engineer Date // - INSTRUCTIONS General' This form is designed for submitting a comPlete and correct well completion report and log on all types of lands and leases in AlaSka. Item 1" Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records'for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none''. ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel~rl" 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE 604372 ICounty. parish or borough North Slope Borough Lease or Unit Title ADL 25633 Drill Istate Alaska no, 3B-7 Parker 141 Operator ARCO Alaska, Inc. API 50-029-21337 JARCO W.I. Prior status if a W.O. Spudded or W.O. begun Spudded 5/21/85 IH°ur Date and depth as of 8:00 a.m. 5/21/85 5/22/85 5/23/85 5/24/85 Complete record for each day reported 56.24% 0130 hrs. 16" @ 100' 475', (375'), Drlg Wt. 9.4, PV 11, YP 20, PH 10.5, WL 14, Sol 7.9 Accept rig @ 2145 hrs, 5/20/85. NU diverter sys. Spud well @ 0130 hfs, 5/21/85. Drl 12¼" hole to 475'. 3320', (2845'), Rn'g 9-5/8" Wt. 9.4, PV 12, YP 22, PH 8.5, WL 18, Sol 8.0 Drl & surv 12¼" hole to 3320', 22 std short trip, CBU, POH. & rn 9-5/8", 36(/, J-55 BTC csg. 475', .4°, N48.SW, 475, -.75, .86N, .98W 1626', .3°, Nll.0E, 1625.88, 1.07, 2.98N, .55E 2374', 1.0°, N34.7E, 2373.76, 10.26, 9.93N, 9.42E 3295', .6°, N52E, 3294.60, 20.43, 18.40N, 17.33E 'RU. 9-5/8" @ 3300' 3792', (472'), Drlg Wt. 8.6, PV 6, YP 9, PH 10, WL 12, Sol 4.5 Fin rn'g 76 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3300', FC @ 3210'. Cmt w/1080 sx AS II & 340 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter & NU & tst BOPE. TIH w/BHA, DO to 3330'. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 3792'. 3408', .5°, N49E, 3407.68, 21.35 VS, 18.06N, 18.13E 3661', 13.4°, N78.4E, 3658.81, 46.96 VS, 23.30N, 43.26E 9-5/8" @ 3300' 5684', (1892'), Turbine drlg Wt. 9.1, PV 8, YP 8, PH 10, WL 8, Sol 6 Turbine drl 8½" hole to 5684'. 3910', 20.5°, N84.7E, 3896.84, 118.69, 33.96N, 114..99E 4158', 26.9°, N81.3E, 4125.03, 214.94, 45.84N, 211.04E 4407', 35.6°, N77.9E, 4338.18, 342.97,- 67.45N, 337.42E 4750', 40.7°,-N77.2E, 4604.56.,'558.72,-111.05N~. 548;89E 5281~ 41..!°, N%4.7E, 5005.92, 906.28, '195.44N, 886.13E Tho above is correct Signature For form preparation arid ~-I~ribul[on, see Procedures Manual, Sec~on 10, Drilling. Pages 86 and 87. IDate 6/10/85 JTitle DrillinK Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or weir 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. Accounting cost center code District i County or Parish State Alaska North Slope Borough Alaska Field Kuparuk River Auth. or W.O. no. AFE 604372 Lease or Unit J Well no. ADL 25633 3B-7 Title Drill Parker 141 Spudded or W.O. begun Operator A.R.Co. W.I. 'ARCO Alaska, Inc. Date API 50-029-21337 56.24% I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our l Prior status if a W.O. 0130 hrs. Spudded 5/21/85 Date and depth as of 8:00 a.m. - 5/27/85 Complete record for each day reported 7" @ 7241' 7270' TD, 7155' PBTD, RR 10.3 ppg NaC1/NaBr in csg to FC @ 7155' Drl & surv 8½" hole to 7270', 20 std short trip, circ hole cln, POH f/logs. RU & rn DIL/SFL/SP/GR/FDC/CNL/CAL f/3300' - 7264' WLM, RD Schl. TIH, wsh & rm to btm, TOH. RU & rn 178 jts, 7", 26#, J-55 HF-ERW BTC csg w/FS @ 7241', FC @ 7155'. Cmt w/460 Sx Cl."G" w/3% KC1, .8% D~60 & .2% D-46. Disp using rig pmps, bump plug. Good rtns thru out. CIP @ 2315 hrs, 5/26/85. ND BOPE, NU wellhead, tst pack-off to 3000 psi. RR @ 0330 hrs, 5/27/85. 5783', 41.6°, N70.8E, 5382.77, 1236.52 VS, 293.77N, 1202.80E 6289', 40.1°, N73.0E, 5765.75, 1557.62 VS, 387.84N, 1508.19E 6420', 40.8°, N72.0E, 5865.44, 1642.39 VS, 413.40N, 1589.24E 7205', 39¼°, N78¼E, 6466.54, 2146.87 VS, 542.93N, 2076.92E Old TD New TD ,I PB Depth Released rig Date Kind of rig 0330 hrs. 5/27/85 / Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil J Single Producing method - .' . ~ J Official reservoir name(s) - . -' Flowing J ' Kuparuk 'Sands Pote6ti-ai te~t data Well no. Dale 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 Signature JDate JTitle 6/10/85 Drilling Superintendent For form pr~pCration a~nd dis,~utio-~, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. SUB'SURFACE DIRECTIONAL SURVEY [~UIDANCE [~ONTINUOUS ~-~OOL Company ATLANTIC RICHFIE. LD COMPANy. Well Name 3B-7 (869' FSL,. 499' FEL., S16. T12N, R9E, UM Field/LOcation. ~:~~- ~OR~ SToOl'S. ALASKA Job ReferenCe No. 70551 LO~3(3ed By; KOZUSKA Dat_._.~e 19-JUNE- 1985 Computed By.' CUDNE¥ GCT DIRECTIDNAL~,~URVS E¥ CUSTOMER £,ISTIN~ FOR ARCO AI, ASKA, INC, 3B-7 KUPARUK ~)URTH SLOPE,ALASKA SURVEY DATE: 5 dUN 85 ENGINEER; D, KOZUSKA METHnDS OF CPMPUTATIDN TOOL LOCATION: TANG~NTIaIj- averaged deviation and azimuth ~NTE~POLATION: I.,INE~k VERTICAl, SECTION~ HORIZ. DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 76 DEG 5 MIN EAST ARCO /~I.,RSKA, TNC. K[IPJ~ iq I.I K NOR?H ,SI.,OPE, Al,ASK ~ TRUE SUB-SEA COURSF MEA$I1RFD VFR?ICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0,00 100,00 ~00 O0 ~00!00 400 O0 ~00 O0 600~00 700.00 800,00 000,00 0 O0 100 O0 2O000 3O0 O0 '399 99 409 90 5q9 90 609 99 799 90 899 98 COMPUTATION DATE: 1g-JUN-B5 PAGE DATE OF $URVEYI 5 JUN 8~ KELLY BUSHING EbEVRTXON. ENGINEEP: D,KOZU$KA INTERPOLATED VALUES FOR E~E~t 100 FEET OF MEASURED DEPTH VERTTCAL DOGLEG RECTANGULAR COORDiNATEs HORX~'= DEPARTURE S~CTION SEVERITY NORTH/SOUTH E~$T/WEST D{$T. AZ2M[JTN FEET DEG/IO0 FEET FEET FEE~ DE~ 1000 O0 1100 oo 10q9 120n 1300 1400 1500 1600 1700 18 O0 1,199 O0 1299 oO 13o9 O0 1499 O0 1599 O0 1699 O0 17o9 O0 1809 -84.00 '16 O0 11.6 O0 2i6 O0 ]15 99 415 99 ~15 ~9 615.09 715.99 ~15.g8 999 98 915,08 9~ 1015,08 9~ 1115 98 98 1~15!08 98 1] 5 98 99 1415,g~ 97 1~}5.97 97 15,07 96 1815,06 0 0 ~ 0 0 ~ 0.00 0 27 N 15 5~ E 0 18 0 16 N 1 47 W 0~42 0 14 ~ 1.0 56 W 0 49 0 15 ~l 33 21, W 0~41 0 7 N 30 11 W 0,21 0 30 N 25 6 W 0.33 0 15 , 40 3 W -0.10 0 21 N 62 47 W -0.15 0 23 , 10 17 ~ -0,32 0 13 N 67 3~ W -0.33 0 21 N 30 23 E -0,25 0 13 S 79 1] W -0,1.1 0 13 , 51 57 ~ -0,14 0 1~ S 79 6 W -0.~4 0 16 $ 8 34 E -0,45 0 24 S 73 22 W -0,73 0 20 S 66 42 W -1.43 0 3~ N 41 36 W -~,88 1 15 N 15 20 W '2.12 39 N 2 27 E -{ 83 50 ~ 14 4 ~ -0:52 i 53 N 20 36 ~ 1.~3 1 21 ~ 31 7 ~ 1 1~ N ]4 20 ~ 4.50 1 ] "45 55 E 6,09 0 58 ~' 47 5 F 7.59 0 54 N 49 I F 8 94 0 53 , 51 5~ E 10:27 0 50 N 59 38 E. I~,62 2000 O0 1999 93 1o15,03 2100 O0 2099 88 2015,88 2~00 O0 9199 82 2115.82 2300 O0 2299 77 2~15.77 2400 00 ¢399 75 23~5.75 2~00 00 ~499 73 2415.73 2600 O0 ~599 79 2515.72 2700 OD ~699 70 261~.70 2800:00 ~799 6q 271D 69 2900,00 2899 68 2815:68 N 65 5 E 12.95 N 67 27 E 14.~4 ~! 65 14 E 15.41 N 55 54 E 16.39 N 73 51 E 17.50 N 73 4 E 19.26 ~ 83 14 E 28.57 , 78 44 ~ 49.63 N 78 5~ E 74.17 g 82 56 E ~0~.]9 3000 O0 ~999.67 2015,67 0 47 3100:00 3099.66 3015,66 0 43 3200.00 3199,66 31.15.66 0 41 3300,00 3209,65 3215.65 0 28 3400.00 3399,64 3315.64 0 37 3500,00 3499,63 3415.63 2 0 3600.00 3599.11 3515.11 9 11 3700,00 3696 82 361~.82 13 50 3800.00 3793:75 3709.~5 14 56 3900.00 3889-.30 3~05,30 19 30 0,00 0,26, 0,04 0,12 0.14 0.99 0 61 0 21 0 28 I O6 1 03 0 O6 o 0 0 43 0 27 1 04 0 O7 0 43 0 78 0 40 0 .16 0 22 0 14 0 27 0 82 0 40 0 10 0 46 1 22 I 07 4,41 O1 0 O0 N 0 46 ~ 1 t0 N I 52 N 1 95 ~ 7 ~ ,2 3 12 ~ 3 83 ~ 4 11 N 4.76 N 44 N . 67 IV 5,23 N 4 96 N 4::6~ N 5 12 N 6 64 N 9 02 N 12 15 N 15 28 N 17 98 N 1.9 80 IV 23 64 ~ 24 71 N 25 62 N 26 32 IV 26 92 N 27 46 N 28 O5 N 28 5I N 29 13 IV 30 32 . 33 81N 38 7~ N 43 31N 0 O0 g 0 08 E 0 16 g 0 13 E 0 06 W 0 3~ W 0 U 1 10 ~ 1 34 w 84,00.FT 1.52 W 1,50 W 1 46 ~ I47 W 65 W 1 77 W ~ 99 W 2 61 w 3 2O W 3 83 W 5 O0 N 17 43 W 5 24 N 16 37 W 5 5 5 5 5 5 64 N 15 3 W 54 h 15 21 W 90 N 16 12 W N 18 38 W 35 N 21 48 W 31 N 29 30 W 03 N 32 I W 66 N 29 '58 W 2, w 4 ~.5 W 3 2 52 W 1 44'W 0 27 W 1 02 g 2 25 E 338£ 4 46 E 5 62 E 992 N 24 34 W 66 N 16 16 W 1 18 19 ~6 48 N 9 21W 04 N 4 33 W 81 N 0 46 W N 2 4r e? N 8 ~ 10 ~3 N 12 22. E ,8! ~,00 9.07 9 93 10 96 12 63 21 92 42 75 66 82 95 27 26 26 29 30 3 79 E 105 1.11 ~ ~ 11E 5 1,53 3~ W 1',98" X,82 3'99 3 W 4,32 ~ 16 18 6 W 3R-7 KUP~RUK NORTH SLOPE,ALASKA COMPUTATION DATE: lO-JUN-85 TRUE SUB-SEA COUPSE MEAS!IRFD VERTIOAL VERTIC&b DEVIA?ION A%IMUTH DEPTH DFPTH DEPTH DEG NIN D~(; MTN PAGE -2 4000.00 39~2 83 3898.83 21 3.~ 4100 O0 4074 7~ 3090.76 ~4 4~ 4900:00 4.164 15 4080,15 28 2n 4300,00 4250 87 4166,87 4400.00 4334 31 4~50,]! 35 18 4~00 O0 4413,59 4129,59 39 17 4600:00 44~9.72 4405,72 40 49 4700,00 4565,46 4481,46 40 45 4800,00 4641,10 4557,10 40 54 4900,00 47~6,'74 463~,74 40 55 DATE OF SURVEY1 5 JUN 85 KELLY BUSH{NG EhEVATION: 84.00 F ENGINEER: DeKOZUSKA INTERPOLATED VA[,UES f'nR ~VEN lO0 FEET OF MEASURED DEPTH YE~TICAL DO~LEG RECTANGULAR COORDINATES HORIZ' DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,' , aZIMUTH FEET DEC/lO0 FE~T FEET FEE~ DEO MIN N ~2 36 E 139.49 2.39 47 41 N 130 9] E 139'25 N 70 5 E N ~1 58 E 177.58 2 55 52 86 N 1.69 85 g 177,89 N 72 42 E N ~0 42 E 2~6! 59 53 ~ 214 12 F 222,24 N 74 27 E 4.2~ 67 93 N 263 '16 E 271,78 N 75 3! E 5000 00 47q2 2R 470R.78 40 54 5100;00 4867 74 4783,74 Og 4R59,09 41 8 35 4934,35 41 lO 9 5000,49 41 16 ~O 5084,58 41 25 44 5159,~4 41 34 10 5~3a,10 41 51 66 530R,66 41 35 45 538],45 ~1 18 5~()0 00 4943 5]o0~oo 501.8 5400 O0 5093 5500:00 5168 5600 O0 5243 5700i00 5318 5800 00 53~2 5900 oO 5467 6000.00 K543 50 5~59,50 40 ~ 6100 O0 56i9 8,] 5535,~3 aO 16 6~00:00 5695 97 5611,q7 ~0 26 5688, 5764,19 40 30 16 16 a0 24 79 5840.79 39 17 27' 591fl,27 39 34 86 5994,86 40 30 52 6070,52 40 56 07 6146,07 ~0 5! 222.15 N 79 42 E 27{.77 "78 23 E 326.78 N 78 49 F 387.64 N 79 26 F 45~,36 ~' 78 20 E 517,58 ~ 77 21 E 582.96 ~ 7U 30 E 648,36 5' 76 5 E 71],88 ~] 75 4~ ~ 770.49 N 75 17 E R45,~4 ~ 74 4] F 91],09 N 74 ]7 ~ 977,04 N 73 31 E 1043,03 N 72 38 E 1109,~4 N 71 57 E 1t. 75,62 N 71 2~ £ 1~47,06 N 71 4 ~ 130B,~0 ~ 72 35 E 137~,95 n! 72 41E 1437,43 ~ 72 39 E 1502,15 N 72 49 E 1566.81 73 1E 163i,66 , 73 30 E 1695,86 "75 15 F 1759,05 ~ 75 2 ~ 182to33 N 75 ~ ~ 1~88,72 N 75 7 F 1954,~2 ~ 74 43 E 2019 44 76 16 E 2083:93 ~ 76 16 E 2147,51 N 76 16 E 2192,09 6300 O0 5772 6400 no 5848 6500 O0 59~4 660O O0 6002 6700 O0 6078 6800,00. '6154 6900,00 6230 7100,O0 63{:{2,]7 7~00,00 645'9.46 6375,46 39 33 7270,00 6513,43 6429,43 39 4 90 78 50 N 317 2.~ E 326 78 N 76 6 E 3 19 90,77 N 376 87 E 387 64 N 76 f' E 0 70 102,60 N 440 61E 452 40 N 76t E 0 71 115.17 N 504 69 E 517 67 N 77 8 E 0 71 198,96 N 568 63 E 583 07 N77 13 E 0 54 143,.76 N 632 35 E 648 48 N 77 11E 0 31 159 32 M 696 00 E 714 O0 N 77 6 E 0 17 175 27 N 759 64 E 779 60 N 77 0 E 0 39 191 64 ~ 8~3 32 E 845 ~3 N 76 53 E 0 65 208 70 . 8'6 9, E 911 15 N 76 45 E 0 44 226 29 N 950 52 E 97708 N 76 )6 E 0 59 305 08 N ~204 03 F 1242 08 N 75 46 i 1 81 326 65 N 1266 82 E 1308 25 N 75 32 E 0,50 346:78 N 13~8 54 E 1373 05 N 7~ 22 E 0,42 366 04 N ~390 20 E 1437 58 N 75 i4 E 0,59 4~366 N 1576 03 E 163198 ~4757 E N 74, E 1,07 475 52 ~ 1760,65 ~ 18~ ?] 0,15 492 45 N 1823,8{ F 18B9 12 N 74 53 E 0,44 509 23 N 1,887,14 E 1954 64 N 74 $3 E 4,85 542,~1 N 2012,37 E 2084,27 N 74 54 E 0,00 557,82 N ~074,24 E 2147,9] N 74 56 E 0,00 568,39 N 2117,54 ~ 2{92,50 N 74 58 E ARCn Ab~$KA, THC, 3R'7 KUP~RIIK NORTli ,SLDPE,ALASKA COHPLJTATION DAT~: lq-JUN-fl5 DATE OF SURVE~I 5 JUN 85 KEI, LY BUSHING EbEVRTIONI ENGTNEER~ D,KOZ[!SKA INTERPOLATED VAI~UES P'OR EVEN 1000 FEET OF MEASURED DEPT TRU~ SUB-SEA COURS~ ~E~$IIRFD V~RTI~A[, VERTICAL DEVIATION AZIMUTH DEPTH D~PTH DEPTH DEG MTN DKG M~N 0,O0 0,00 '84,00 0 0 1000,00 999.9B q15,g8 0 2000,00 ~9q9,9~ lqlS,q~ 1 39 3000 O0 ~999.67 20~.67 0 47 4000:00 ]982.8] 3fl~-,83 91 5000.00 4792 28 470~,~8 40 54 6000 nO 5543:50 5459,90 40 7000~00 6305'86 6221,86 40 25 7~70.00 651.3: 4] 642g,~3 39 PAGE 84.00,F 0,00 0,61 1,04 0,40 2,39 0,31 0,50 1,40 0,00 0,00 N 0,00 E' 0, 4.76 N 1,52 W 5~ 9 02 N 4 12 W 9. 26 32 N 6 81 E 27. ,47 4{, ~ 130 93 E 119. 159 32 ~ 696 00 ~ 714 346 78 N 1328 54 E 1373 526 26 ~ 1950 11 E 201,9 568 39 N 2117 54 E 2192 O0 N 0 0 E N 2~ 34 W N 70 5 E O0 N 77{ E 05 N 75 ~ E 87 N 74 5~ E 50 N 74 58 E N 0 0 ~ 0.00 N 67 35 W -0.~3 N 2 27 E -1,83 ~ 65 5 r 12.95 N ~2 36 E t3R,49 N 76 5 F 713,98 g 72 35 E 117~,q5 ~! 74 43 E 2019,44 ~{ 76 16 ~ 219~,09 VERT{CAL DO~LEG RECTANGUbAR COORDINATES HORZZ, DEPARTURE SECTION SEVERITY N~RTH/SOUTH ERST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FE~T DEG MXN ARCO AbASKA, TNC, 3~-7 NnRTH SLOPE,ALASKA TRUE SUF-$E~ COURSF MEASURFD VERTICAl. YERTIC~L DEVIATION AZI,UTH DEPTH DEPTH DEPTH DUG MTN DEG ~TN 0.O0 84.00 184 O0 284 O0 384 ol 484 Ol 58~ 01 684,nl 784.01 884,02 0,00 84 00 184 00 2~4 00 384 00 484 00 584 00 684 00 784 00 8~4 00 COMPUTATION DATE: 19-JUN-85 PAGE 4 DATE OF SURVEY% 5 JUN 85 KELLY BUSHING EGEVA,T~ON: ENGINEER: D.KOZUSKA INTERPOLATED VA[,UES FOR EVEN ~00 FEET OF SUB-$ER DEPTH VERTICAL DOGLEG R~CTANGULAR CDO~DINATES HOR~Z'. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIS?, AZIMUTH FEET DE~/~O0 FEET FEE~ FEEX DEG NIH -84,00 0 0 N 0 0 E 0,00 0,00 0 25 N 18 49 E 0.12 1.00,00 0 16 N 0 R W 0,40 ~00,00 0 14 N 7 46 W 9,49 300,00 0 16 N 28 21 w 0,44 400.00 0 8 N 57 13 W 0,24 500.00 0 29 ~ 9 38 W 0,34 600 O0 0 16 ~ 65 44 w -0.05 70o:00 0 27 ~ 40 20 w -0.07 ~00,00 0 19 N 9 5~ E -0,36 084.02 .984 O0 QO0,O0 1084.02 1084 O0 1000,00 0 19 N 58 51 w -0.27 0 19 N 34 50 E -0,32 O0 1100,00 0 14 N 76 23 W -0 05 O0 1700.00 0 11 ~' 88 50 E -0~19 O0 1300,00 0 1'7 N 72 12 W -0.16 O0 1400.00 0 16 $ 7 44 E -0.45 O0 1~00,00 0 24 S 78 52 W -0.62 00 1600,00 0 24 S 64 49 W -1.32 O0 1700.00 0 3~ N 43 35 W -1 79 O0 1RO0,O0 1 12 N 16 4 W 1184 O2 ~184 02 1384 1484 02 1.4.84 158a"03 1584 1684:03 1684 188~.04 2184 228a 2384 2484 2584 2684 2784 2884 1984.071984 O0 lO00,00 2084 12 2084 O0 2000,00 2100.00 1 31 N 0 45 W -1,95 1 50 , 14 7 E -0.76 O0 1 54 N 22 13 E 0,93 00 2~00 00 1 20 N 27 4! E 2,66 O0 2300~00 1 13 ~ 35 20 E 4,25 00 2400.00 1 4 N 46 32 E ~.83 O0 2500.00 0 5q N 47 42.E 7.35 O0 2600 O0 0 54 N 47 59 E 8.72 O0 2700:00 0 ~O N 47 7 E 10.05 O0 2800,00 0. 47 N 52 1 E 11,41 17 2184 ~2 2284 24 2384 ~6 2484 ~8 2584 29 ~684 31 2784 32 ~884 0 45 0 42 34 3184 00 310o.00 0 36 35 3284 00 320o,00 0 27 36 3384 00 3300.00 0 33 37 3484 O0 3400,00 1 28 72 3584 O0 3500.00 7 59 79 3684 O0 3600,00 13 31 92 37~4 O0 3700.00 Ii 4~ 36 3884:00 3800,00 19 17 ~' 65 35 ~. N 66 3~ E ~' 57 59 E N 46 17 ~ N 60 7 E N 67 49 E ~.' e3 '59 E N 79 9 E N,78 44 E N 82 46 E 2084 33 2984 O0 2000.00 3084 33 3084 O0 3000.00 3184 3284 3384 3484 3584 3686 3789 3~94 12 74 14 05 15 94 16 28 1~ 35 ! 80 26 30 46 47 7~ 64 101,49 0,00 0.41 0 08 0 12 0 21 0 35 0 71 0 45 I 79 0 ?~ I 10 0 29 1 43 0 55 0 84 0 05 0 28 0,19. 0,33 0,40 0 86 0 09 0 44 I 2! 0 ~0 O04) 0 20 ! 35 0,28 0,45 1,63 0,10 1 74 2 66 8 O8 ! 0.00 N 0 34 N 1 02 N 1 46 N 1 88 N 2 15 N 2 66 ~1 30q N 3 77 N 4 00 N 4 94 N 5 45 N 5 33 N 5 66 N 5 31 N 4,99 N 4,67 N 4,99 N 6m31 N 8 58 N il 66 N 14 79 N 17 64 N 19 53 N 21 O0 N 22 29 N 23 47 N 2455 N 25 51N 0.00 E 0 04 E 0 16 E 0 14 E 0 02W 0 2q W 0 31W 0,82 W 1.0! W 1,36 W 1'45 W 1,55 W I: o w 5~ W 1,56 W 1,78 W 1,87 W 2,51 W 3,0~ W 3,73 W ,, 4 13 W 3 67 W 2 71, W 1 63 W 84,00 F~ O0 N 0 0 E 34 N 632 E 03 N g 51 E 46 N 528 E., 88 N 031W 20 N 1452 W 90 N'15 0 W 23 ~ 18 48 W 495 N 1"/ 3 W 17 N 1726 W 63 N 1,425 W 54 N 1553 W 87 N 1527 W 60 N 18 29 W 33 N 2035 W 30 N 28 19 W W 86 N 313741 W 33 N 30 46 W 81 E 44 E 26 9,52 N 25 42 W ~S;04 N. 10 22 W 179'1 :~i' NN 51 216 W 39 N 5 ! ' N 9 5 £ 08 ~ 1'2 ~ ii: 6,62 g 92 E 28 84 E 29 10,82 E 30 12,19 E 31 19,64 E 35 39,65 E 51 64033 E 74 93,88 g 103 0 E 27 96 N 1 E 79 N 18 2 E 65 N 19 22 E 45 N 20 48 E 43 N 22 48 E 9iN 33 9 E N 50 3 E 83 N 59 17 E 29 N 65 20 E K[IPARUK NORTH ,SLDPF.,ALASKA DATE OF SURVEY~ 5 JUN 85 KELLY BUSHING EbEVAT~ON= INTERPOLATED VAIoUES F~R EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUN-SEA COURSF "EA$IIRFD VERTICAL VERTICAL DEVIATION AZi~UTH DEPTH DEPTH DEPTH DEG MTN DEG ~iIN 3000,00 21 36 N ~2 35 E 4000,00 25 4 ~{ 81 55 ~ 4100,00 28 5~ ~ ~0 30 F 4200.00 33 5 ~ 79 4 ~ 4~00.00 38 ? N 78 24 ~ 4400,00 40 48 N 79 2q ~ 4500,00 40 47 N 78 5 ~ 4600.00 40 48 N 76 5~ F O0 4700,00 40 54 N 76 7 ~ O0 4800,00 41 5 N 75 43 ~ 4001.2b 39~4,00 4110 19 40~4 O0 4222:63 4184 4339.~9 4284 O0 4467.05 4384 O0 4592,43 4484 O0 4724.48 4584 O0 4856,71. 4684 O0 498q,05 4784 512{,57 4884 5254,32 4984 O0 4900,00 41 g 5..387 ..38 5084 O0 5000 O0 41 15 5520'56 5184 O0 5100~00 41 20 5654~7 5284 O0 5200.00 41 4.2. O0 5300,00 41 38 O0 5400,00 40 55 O0 5500,00 40 16 O0 5600,00 40 29 00 5700,00 40 26 O0 5800,00 40 ] 5788,43 5384 5921.97 5484. 6053 03 55~4 6184'27 5684 6315~54 57~4 6447,02 5884 5900,00 ]9 21 6000,00 40 34 6100,00 40 56 6?0O O0 40 38 6300:00 ..39 3~ 6400,00 39 33 642q,43 39 33 6576,34 5984,00 6706,78 6084,00 6839.05 6184,00 697~,~9 6284.00 7102.12 6384,00 7~31 ~2 6484,00 84,00 VERTTCAL DOGLEG RECTANGULAR COORDINATES HOR2Z' DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN ! 3n.05 181 232.08 292.85 3.63,91 447,41 533.55 620,04 706,72 793,67 N 74 57 ~ 880.98 ~ 74 2~ E 96~,72 N 73 23 ~ 1056.62 N 72 15 E 1~45,~3 "71 26 ~ 1234,41 N 71 24 ~ 1322,60 N 72 38 ~ 1407,12 N 72 ]g ~ 1491,87 ~ 72 51. E 1576,B6 N 73 6 E I662,09 O2 N 74 57 E 1744 N 75 ~ F '1827 75 N 75 8 ~ 1914 31 ~ 74 47 ~ 2000 67 , 76 16 ~ 2085 18 ~ 76 1~ E 2~67 78 ~ 76 16 ~ 2192,09 2,46 2.91 2,39 3 03 3:18 0 68 0 6P 0 6~ ~ 32 0 29 0 64 0 35 0 72 0 50 0 73 2 47 0 32 0 4O 0 5O 1,31 0,99 0,21 0,32 0,00 0.00 0,00 47 47 ~ 131,39 E 139'70 N 70 8 E 53 46 N 174.12 E 18i2,~4 N 72 55 g 61 233.04 N 74 44 E 31 N 224,83 E 71 82 N 283,91E 292 86 N 75 48 E 86 01 N 353,61 E 36'3 92 N 76 19 E O! 70 ~ 435,74 E 447 48 N 76 ~"' E 37 21 N 604.7q E 6~0 16 N 77 1~ E 18 43 N 520,34 E 533 65 N 77X E ~57 61 N 689,04 E 706 83 N 77 6 E 178 75 N 773,38 E 793 77 N 76 59 E 200 82 N 857 86 E 881 05 N 76 49 E 224 05 N 942 50 E 968 76 N 76 37 E 248 274 302 331 356 382 407 432 47 N 1027 65 N 11 31. N 1280 99 ~ 1361 31N 144~ 56 N 1523 5~ ~ 1605 01E 1056 78 E 1145 75 E 123 50 E 132~ 22 E 1407 36 E 1492 55 E 1577 18 ~ 1662 64 N 76 23 E 23 N 76 7 E 42 N 75 48 E 67 N 75 29 E 2 5 N 7.~ i8 E '16 N 75 9 E 13 N 75 1 E 43 N 74 55 E 455 476 499 521 543 562 568 37 , 16~3,93 E 1744,41. N 74 52 E 66 N 1764~91E 1828,15 N 74 53 E 31 N 1932'00 E 2001,10 N 74 53 E 62 ~ 2093 3 g ~t68,20 N 74 * 39 N 211.7 4 E 2192,50 N 74 , ARCO ALASKA, ]fNC, NORTH SI, OPE, AI',ASKA TOP UPPER SAND BASE {!PPER ~AND TOP bOWER SAND BASE LOWER ~AND PB~n COMPUTATION DATE~ PAGB 6 DATE OF SURV£¥t 5 dUN 85. gNG[N~ER: D.KOZUSKA INTERPOLATED VAI,UE8 FDR CHD~EN HORIZONS M~ASURED ~EPTH nRIGIN: 869' FSI.~499' TVD FROM KB SUB-SEA SURFACE LOCATION FEL,SEC 16,T12N,R9E,IJM RECTANGULAR COORDINATES NORTH/SOUTH EAST/WE~T 6694.00 6715,00 6863.00 7037,00 7155,00 7270.00 6020.74 6090.~4 6~07.10 6334.10 6424.77 6513.43 5936 74 6006 24 6118 10 6250 10 6340 77 6429 43 478,05 N 1 503.O5 N i 3 532,54 N 1973 551,02 N 2046 568,39 N 2117 9_8 g 09 E 71 £ 3R-7 KUPARIIK NORTH SLI)PE,ALASKA ~ARKER TnP UPPER SAND BASE IIPPER SAND T~P LOW~R SAND BAS? [.,UWER SAND PBTD TD COMPUTATION DATE: 19-JUN-B5 MEASURED DEPTH BELOW KB 6624,00 6715.00 6863.00 7037.00 7155,00 './270,00 DATE OF SURVEY: 5 JUN B5 KELLY BUSHING E~EV~TION: 84,00 .F' ENGINEER: D.KOZUSKA S[INNARY SURFACE LOCATION AT ORIGIN: 869' FSL,499' FEL.SEC ~6,TI~N.RgE,UM TVD RECTANGULAR COORDINATES FRD~ KB 6020.74 6090.24 6202,~0 6334.~0 6424.77 6513.43 SUB-SEA ~ORTH/$OUTH' EAST/WEST 5936.74 463.09 N 1713 6006.24 478.05 N !770 61~8.10 503.05 N 1863 6250,10 532.54 N 1973 6340.77 55~,0~ N 2046 64~9,43 568.39 N 2,~17 28 E 09 E ''/1 E 40( 54 E FINAL WELL 50CATION AT TRUE SUB-SEA MFASURED VERTICAl, VERTICAL DEPTH DEPTH DEPTH 7270,on b513,4] 6429,43 Hn~TZDNTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2192.50 N 74 58 E -SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3B-7 F I ELD KUPARUK COUNTRY USA RUN ONE ORTE LOOOEO S JUN 85 REFERENCE O000?OSS! WI~,1~1, L~L~t~-J.i~; ~D~ I SURFACE LOCATION: ~69' FSL, 499' FEL, S16, T12N, , UM ~'~ VERTICAL PROJECTION - ! 000 -SOO 0 0 ~00 1000 1SO0 2000 9000 --I II ??-'"?"~ .!...~. -~-...~..-~..-~--.!----~---i---i~-.i r °~! ! ..... ! i ~ ................. !---!.--~---~--~ ?~----i--- ~ PROJECTION ON VERTICAL PLANE ?G. - 2S~. ~EO IN VERTIC~ DEPTHS HORIZ SCALE = I/S00 IN/FT ~000 ISO0 WELL ~Al~: Jt~- / SURFACE LOCATION: "9' FSL, 499' FEL, S16, T12N, R UM · HORIZONTAL PROJECTION I000 SO0 SOUTH -1500 ~ -lO00 WEST -SOO 0 SO0 1000 1 SO0 2000 2500 3000 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations- WELL I~AME AND NIJi~IBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report 7 Well History Samples Mud Log Core Chips Core Description Registered Survey Plat / Inclination Survey ., - Directional Survey ~~ .~/ Production Test Reports Log Run Digitized Data ARCO Inc. Post Ot'fice Box 100360 Anchorage, Alaska 99510-0360 Te!ephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-!!iSB P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 06-27-85 TRANSMITTAL NO: 5235 ENG '~' '"' INEEI~_, N~ PLEASE ACKNOJ ~,-.-.D,~,. ECEiPT AC'/.NO:':rpDcz D7. STR IB UTiON: · · CUP. RiL'I~ L. JOIINSTON EXXON SO!!iO : v .',,.,~, ~..:,.j~., ~. :; Pr'ii, LIPS.. Of':--' U'.-I_O,,.~' r " ........ ~:~, J RATr:MELL ~, ~""r ~'~T TP, ANSMITTED I-IER.?,'~iTH ARE .,-,.,,-, FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANS~.L.=AL. OPEN [,.'OLE LIS TAPES PLUS LISTING (ONE COPY OF EACH) SCIILUMBERGER 3C-12,~ 06-16-85 RUN #1 3756.0-7598.0 REF ~70547 3B-8~ 06-02-85 RUN ~1 3925.5-8516.0 REF ~70495 3B-7~ 05-24-85 RUN #1 3268.0-7310.5 REF #70468 3B-9~ 06-10-85 RUN ~1 3988.0-8415.0 REF #70526 3B-5--..~ 05-12-85 RUN #1 3447.5-8148.0 REF ~.704i7 2Z-16--.1 06-08-85 RUN #! 4062.5-8163.5 REF #70525 2V-16-... 06-03-~5 RUN #! 2973.0-7168.0 REF ~70496 2V-15---- 05-24-$5 RUN #2 2873.0-6544.5 REF #70470 2V-14 ~ 05-16-85 RUN ,%1 3047.0-7086.5 REF %70426 2V-!3 ---- 05-07-85 RUN ~! 3536.5-8710.5 REF %70409 1R-8~ 06-14-85 RUN #1 4040· 5-8576.5 REF j~70546 IR-6----. 05-14-85 RUN ~! 4623.5-9332.5 REF #70422 ]Q-15~ 05-12-85 RUN #1 4390.5-8730.0 EEL; ~70415 iQ-14 ~ 05-2~-85 RUN" . . · - ~.1 4371 0-9027 5 REF #70447 iQ-13x,,.., 05-30-85 RUN #1 3679.0-7772.5 REF ,~70482 LQ-4....., 03-18-85 RUN ~.1 4570 0-9471 0 REP ~ · . ,~70506 *ILEVISED* ARCO Alaska, Inc. Post Office Bo~,._~.0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the May monthly reports for the following wells: 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L56 Enclosures RECEIVED JUN 1 4 ]~l/t§ A!aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~AND GAS CONSERVATION COr~qllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-77 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21337 869' 4. Location of Well at surface FSL, 499' FEL, Sec.16, T12N, R9E, UM (Approx) 6. LeaseDesignationandSerialNo. ADL 25633 ALK 2566 5. Elevationinfeet(indicateKB, DF, etc.) 85' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3B-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of Nay , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0130 hfs, 5/21/85. Drld 12-1//+" hole to 3320'. csg. Drld 8-1/2" hole to 7270'TD (5/25/85). Ran logs· Ran, = 7155'. Secured well & RR @ 0330 hfs, 5/27/85. Ran, cmtd, & tstd 9-5/8" cmtd, & tstd 7" csg. PBTD 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62 5#/ft, H-/+0, weld conductor set (~ 100' Cmtd w/227 sx PF' "C" 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3300'· Cmtd w/1080 sx AS I11 & 3/+0 sx Class "GI' · 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 72/+1'. Cmtd w/460 sx Class "G". 14. Coring resume and brief description NONE 15. Logs run and depth where run D I L/SFL/SP/GR/FDC/CNL/Cal f/7200' - 3300' 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEiVeD Alaska 0it & Gas Cons, Commission Anchorage ~/~~ J~4J~/L~ Associate Engineer ~_//_~,~- SIGNED TITLE DATE NOTE--Repo~ on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR51 Submit in duplicate MEMORANDUM St--ate of Alaska TO: THRU: ALASKA OIL AND GAS CONSERVATION COP~ISSION ,~~ DATE: C. V erton Chai~ FILENO: Lonnie C. Smith / CJ"~'~/- TELEPHONE NO: Commissioner May 29, 1985 D.~S.41 FROM: Edgar W. Sipple, Jr~-x_ ~ SUBJECT: Petroleum Inspector~- Witness BOPE Test on ARCO's Kuparuk 3B-7, Sec.16, T12N,R9E,UM, Pemit No. 85-77, Parker ~%g t41. Tuesday, May 21, 1985: I traveled this d~-te from Anchorage to Prudhoe Bay via Aias~a Airlines to ARCO's 3B-7, Parker Rig 141, to witness a BOPE test. The drilling contractor was in the process of running casing. Wednesday, 3~ay 22, 1985: The BOPE test commenced at 1:00 pm and Was Concluded-at -2 35 pm. There were no ~a_,ures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 3B-7, Parker Rig 141. Attachment 02-00IA(Rev. 10/79) .O&.G 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec /~ Drillin~ Contractor Location, General ~P£< Well Sign~_~ General Housekeeping. O ~ Rig ~ Reserve Pit ~f~_ Mud Svstems Visual Audio Date -.~"~ Z L - cY°,5'- Representative Permit ~/ ~,~°~7 7 ACCUMULATOR SYSTEM Full Charge Pressure ~/~.O psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig ~,.~/~Casing Set @ ~ ~0~ ft.-33:o ~ Representative ~. ~ ~ ~-~-~ ~"' min ~.~sec. Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack /onular Preventer Blind Rams. C~o~e/- ~ine Valves H.C.R. Valve, mill Line Valves Check Valve Test Pressure ~000 0o0 00o ~ o Test Results: Failures --~ ~ Full Charge Pressure Attained: _~- min~. sec. / Controls: Master ~/!~ ~_~O(/~f~ ~ · Remote $ Blinds switch cover O~ Kelly and Floor Safety ValVes Upper Kelly ~P~est Pressure.. Lower Kelly ~ ~est Pressure Ball Type ~/~ ~est Pressure Inside BOP ~ T~est Pressure Choke Manifold ~f~ Test Pressure No. flanges ~7 3C~oo 3ooo Adjustable Chokes / ~ ~-~ 0 Hvdrauically operated choke Test Time / hrs. 3 -~' /~/'~ Repair or Replacement of failed equipment to be made within ~/~ days and Inspector/ Commission office notified. Remarks: -.. ..,::: ~: :: Distribution orig. - A0&GCC cc - Operator cc - Supervisor April 29, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3B-7 ARCO Alaska, Inc. Permit No. 85-77 Sur. Loc. 869'FSL, 499'FEL, Sec. 16, T12N, RgE, UM. Btmhole Loc. 1395'FSL, 1624'FWL, Sec. 15, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are no~t required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended.~ Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. K~in Kuparuk River Unit 3B-7 -2- April 29, 1985 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. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatter~ofi Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COmmISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo"6~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 22, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3B-7 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 3B-7, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° Diagram and description of the surface hole diverter system o Diagram and description of the BOP equipment We estimate spudding this well on May 14, 1985. If you have any questions, please call me at 263-4970. Sincerely, Area'Drimiing Engineer JBK/TEM/tw PD/L73 Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION CO~rrMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC ~ MULTIPLE ZONE)~ /'i ~¢'" :~-'~, 2. Name of operator ARCO Alaska, Inc, 9. Unit or lease name Kuparuk River 3. Address P. 0, Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 869' FSL, 499' FEL, Sec.16, T12N, R9E, UN (Approx.) At top of proposed producing interval 1289' FSL, 1197' FWL, Sec.15, T12N, RgE, UN At total depth 1395' FSL, 1624' FWL, Sec.15, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 85', PAD 55' 6. Lease designation and serial no. ADL 25633 ALK 2566 10. Well number 3B-7 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 499' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7294' MD, 6503' TVD fec. t 2560 15. Distance to nearest drilling or completed 3B-6 Well 60' ~ surface feet 18. Approximate spud date 05/14/85 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 28_98 psig@ 80OF Surface KICK OFF POINT 3405 feet. MAXIMUM HOLE ANGLE b, 3 (see 20 AAC 25.035 (c) (2) 3237 psig@. 5~57 ft. TD (TVD) 21 r Hole SIZE Casing Weight 124" 16" 62.5# 112-1/4" 9-5/8" 36.0# '8-1/2" 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade H-40 J-55 HF-ERW J-55 HF-ERW Proposed Casing, Liner and Cementing Program SETTING DEPTH Coupling We1 d J BTC J BTC r Length MD TOP TVD 80' 29' I 29' 3237' 29' I 29' 7266' 28' I 28' MD BOTTOM TVD 109! 109' 3266' I 3266' I 7294'1 6503' I I QUANTITY OF CEMENT (include stage data} * 200 cf 920 sx AS II! & 275 sx Class G 270 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7294' MD (6503' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3266' MD(3266' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2828 psi. Pressure calculations are based on latest reservoir pressure, Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged, The well will be completed by the workover rig with 3-1/2", 9.2#, J-55,, 8rd tbg. Non-freeZing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) · 23. I hereby~that the foregoing is true and correct to the best of my knowledge /) SIGNED / /.~-~--d~.~J,d' TITLE Area Drilling Engineer Th e space..~ f~)r ~6~r~Xn ~e /,)-- DATE .~~~ // / Samples required []YES ~NO Permit number Form 10-401 ( TE"~"~'"PD/~D 73 CONDITIONS OF APPROVAL Mud Iogrequired I Directional Survey required I AP number E]YES ~NO I *J~YES I-]NO J 50- ~) ~,,¢~ ~ / ,~.~ ~ Approval date I SEE COVER LETTER FOR OTHER REQUIREMENTS OMMISSIONER DATE April 29. ]98.5 by order of the Commission Submit in triplicate PERMIT TO DRILL 3B-7 installed and tested upon completion of the job. 3B-7 will be 60' away from 3B-6 at the surface. There are no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed at 5649'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well will be fracture stimulated. i ,_i ...._~_~_, I ._ ....... i ] >'~-'_ i ' ~ { ~ ! ' ' i! l: il ~ ~J ~ i: i: i i i ['" ~ ~] ~ - : ~-~4~ 4_~ .... ~ ;4 '.-~ .~-~-i ; , ~ i ~ ~ i ! 4 ~---ff-~-~ ~-~~ ~ i~-~-~ ;~-~-~- 7-~ . ' ~ . . · ' ; , , : : ~ i : ~ : ~ : ; I ¢ ! ~: .... ~-i~; ~ ~ ~ ~ ~ .... 4 ~ ~4 ~ .~-!;:mno-ly%%,: ...... . .... ,r. .,,, ;.: , .... ~ ..... ~ ..... '- - '~'- i' , , '.' : i : ' r i : . ' ~ : : t : .... , ; ] :, , ~ ' i . ~ ~ :. : · : . : , ~ ' ' - : ' .... r ~ : ' : ~ ; : ; ~ ~'~ ~ ~ ~ ~ i~ " - :, : ~ : : ; : ' - , . . , , , , ~ . , , ~ .... ~ · . , . . ~ . ~ ~ ~.. ' ~',: r; i j i I ~ I ~ '; I i t i i !! ~ I.~ [ iii, ~ :~Mt&~~M~~~~~i - 4, .. , - -~ ~. ' i,-~:--~ ' ' i ~ ! I i I I : : ~ . , : , '. ~ : , ~ . : . ~ , ' ~ ............. : ; ; ~. ; i i.i ~..~.~ ,mr': ~ ~.~ '~ ~' ; .... , , , -~. i i . . Surface Diverter $Tstem . 16'~o200D psi Tankco starting head. Tankco quick connect assyo '16" X 20'~ 2000 psi double studded adapter. 20" 2000 ps( drilling spool w/lC" side outlets, 10" ball valves~ hydraulically actuated, '.~/lO" lines to reserve pit. Valves to open auto~t(¢ml.ly upon closure cf annular preventer, 20" 2000 psi annular preventer. 20" bell nipple. ~mintenance & Ooermtion '-.. 1. Upon initial'-installation close annular preventer and verif~ it, hat ball valves have opened properly. 2. Close annular preventer and blo~ air through d(verter lines every 12 ~urs. ). Close ~nnular preventer in ~e event ~mt gms °r (lu~ tlm to surfmce (s detected. If necessmry, ~nually override mhd close ball valve to u~ind d~verter l~,- Do not shut (n ~ll under mn7 ~(rc~stmnoes~ Conductor 7 6 ~-~c~f'-F~J~A BOP STACK I. 16' - 2CX30 PS~--~/~<CO 5q'ARTIh~ ~ ~ L~S ACCLIV~ATOE CAPACITY TEST !. O-ECX ~D FILL ~TC~"~IR IO,PECPE~ LEVEL W3TH HYDENJ_IC FLUIEL · ~' 2. ASSLRE THAT AC. C3Jd. LATCR ~ ~15 ~ PSI 1KITH 1500 PSI D3't~TREAM CF TIE REGLI~TC~. ~. __,'73~__EVE TILE., TI-EN CL__n~_ ALL LIMITS .$:IlgJLTN,,E:CI.I~Y N,,D EEQ3:~ TIE T:II~E: AhD PEE. SSL,I~ EEI~:INIF,,G AFTER ALL Lt~T$ ~ CLCSED t~J:TH O4A.I~ING ~ CFF. 4. EECCRD ON 19=DC ;;EPC]RT, TIE ACCEFTABL.E U3'ER L]:I~T IS 45 SE~ Q.CSlI~ TIIvE: AM~ 12CX~ PSI RE),I~NING l, '' ' 5 IL !. 7. 2 12. 14, i I :~-.5/8' BOP ' sTAck' TEST FILL BOP STACK AN:) ~ I~FO_D WTTH ARC'TIC D:[ESE3_, FU.L¥ 'rEST ]. tN31H EL.N~II~ J'r ~ ~ IN LCX::KD3V~ LINE VALVES ADJACENT .TO BET> STACX. ALL OTI-ER Pi:E~ UP TO 250 PS:[ AN3 'HCLD FIR I0 MIN. 3N- ~ PRE~ TO 30CO PS! -AhD H31_D _1~ __~'!3 ~ TO 0 PS[. LZhE VALVES. CL~ TC:P PIPE RAiVtS AND ~ VALVES .TEET TO Z50 PS! It,q:) 5CZ:X:) PS]: AS 3N 5"IEP 4. W3TH A 250 PS3; LCW Arid 3C:X:X:) PS! H3GH. TEST AS ~'N STEP 4. DO N3T I:~ES"S'tJ;E TEs'r Akh' hOT A FULL CLOSIKG I;>OS]T]VE SEAL C:HCX[. CN.Y FL,NC~I'I't;;N I-F_.5! G-.E~E$ THAI DO NO1 C:PEN TCP PIPE RAMS AN:) CLI:3EE Bo'n'0M P:IPE TEST BETrTCM P:ZPE RAIVB TO 250 PS] AhD 3000 PS]:. CL0SE BLIhD RAIVlS AhD TEST TO 250 PS]; AhD 3EX:X:) . P[PE SAFETY VALVE., AID II,~[EE ~ TO 250 PS! AhD ~:X3D FIiRt~ SIGN, il~ 5EhD ~0 DRILl. INS ¥1EEKLY ~' F~~Y C:F'fD~'rF. ~ I~]LY. 510O8400 ~.V I ARCO Alaska, Inc Post Office'~.~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- Conductor As-Built Location Plats - 3B Pad Wells 5-8, 9-12 Dear Elaine' Enclosed is an as-built location plat for the sUbject wells. you have any questions, please call me at 263-4944. Sincerely, If J. Gruber Associate Engineer JG/tw GRU5/L70 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ...... DRIE.~ SITE $.B CONDUCTORS AS BUILT LOCATIONS WELL 5 Y= 5,992,109.75 Lat. 70°23'22.6108'' 1 X: 5t8,519.96 Long. ~49° 50'57.665" ' 989' FSL 5t0' FEL WELL 6 Y=5,992,049.98 Lat. 70°~3'22.~28'' X= 5~8~525.7 ~ Long. ~49°50'5~50t'' 929' FSL 504' FEL [ X: 5t8,53t. 34 Long.149°50'57.341" ' ' 869' FSL 499' FEL WELL 8 Y: 5, 991,930.53 Let. 70°23'2~8476'' J X: 5 18,536.99 Long..149°50'5~179" 810' FSL 493' FEL WELL 9 Y=5,99~,383.04 Lat.70°23'~5.46~3'' X= 5t8~589.15 L~g. 149°50'55.6~'' 262' FSL 444' FEL WELLIO Y=5,99~ ,323.38 Lat. 70°23' t4.8744'' ~15 WELL 1t Y=5,991,263.67 Lat. 70023'~4.2870'' - , x= 51 8,600.6t Long,,149°50'~5'' 2~' ~22 142' FSL 433' FEL WELL 12 Y = 5, ~,204.02 Let. 70°23' ~3.7001" X = 5~ 8~606.24 Long. ~49°50'55.205'' 83' FSL 428' FEL LOCATED IN PROTRACTED SECTION 16, TOWNSHIP t2 N.~ ~"-'~ .... ~.- OF A~,' ~ RANGE 9 E UMIAT MERIDIAN. ~ ~ .,,. ,.,, COORDINATES ARE A.S.P, ZONE 4. SECTION LINE ~- :'~'' ~ .... :~'-~ ~" ~ -'~ HORIZON+AL POSITION PER LHD'S ON PAD PILING CONTROL PK'S ~~~ ~) N 26+ 45 & N 13+~ f. ~ ~ ....... ~- ~ E ~ +70 E ~{ +~ I,~,~. 6~4-S VERTICAL POSITION PER LHD~S ALCAP TBM'S 3~1t~3B-12. {'~ ~' '" 3 O.G. ELEVATIONS INTERPOLATED FROM S/C DWG ~ ~--' ...... ,~ CED-9800-300~ ~ ~t~'i~ :"~ C LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ARE CORRECT AS OF FEB. 17, 19~ FOR WELLS 5-t2. ,, ~,~ ~/,,~)~ ,. ARCO Alaske, inc. - P ~ . · - Kuporuk Project North Slope Dril THI : , '" DRILL SITE 3B ~ Defe:Feb. 22~1985 Scele: AS SHOWN _- / Ora~n By: D~W. D~g. N~ NSKg. 05.3~d~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc '(2 thru 8) (3) Admin . ,~-Z.3-g~// 9. i2> 10. (10 and 12) I2. (4) qa s~ ~~.~ d/-~//- (lJ' thru 21) (22 thru 26) Geology__: EngiM~ering HWK Lcs~BEw~ rev: 03/13/85 6.011 Company /~Cf') Lease & weii No. YES NO 1. Is the permit fee attached .................. 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~ . 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. 8. Is operator the only affected party ................................. ~%t' Can permit be approved before ten-day wait .......................... '~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ~}~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ ~;~4. ~5. !6. 17. 18. 19. 20. 21. 22° 123. 24. ~!5. 26. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface. ........ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all, casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off' from an existing wellbore . ........... Is old wellbore abandonment procedure included on 10-403 ..., ........ Is adequate wellbore separation proposed ............ ................ Is a diverter system required ....................................... ~ Are:necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have Sufficient pressure rating - Test to .~~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ................... Is the presence of H2S gas probable ..................... ........... REMARKS 27. Additional requirements ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE O 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. · ,.'?- '.-. SC:Ht, U:~B E:RG E R '~?"~ - ¥ E RI F ICI, T l ON.':. L l S TI NG . . RECEIVED MAY- 6 1986 Alaska 0ii & Gas Cons. Commission Anchora[le LVP OlO.H02 VERIFICAT'Ig~ LISTIN$ PAGE ~ REEL~HEADER SERVICE NAME :EDIT DATE ORIGIN : REEL NAME :149148 CONTINUATION # :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE ** TAPE HEADER SERVICE NAME :EDIT DATE :86/0~/21 ORI$IN :FSIA TAPE NAME : CONTINUATION' ~ :0! PREVIOUS TAPE COMMENTS :LIBRARY T~PE ~* FILE HEADER FILE NAME :EDIT .00! SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : FILE TYPE : PREVIOUS FILE : INFORMATION RECORDS'~ MNEM CONTENTS UNIT TYPE CATE SIZE CDOE CN : ARCO A.LA.SKA' I:NC, NN : 3B -7 FN : KUPARUK RANG: 9E TOWN: 12N S E C T: 16 COUN: NO'RTH SLOPE ~ T A T: A'L ~ $ K A MNEM' CONTENTS PRES: E ,~* COMMENTS' 000 000 000 000 000~ 000 000 000 000 000 000 O0,O 000 000 000 000 016 065 00~ 065 OOB 065 002 065 00~ 065 OOZ, 065 012 065, 006 065 UNIT TYP~ CATE ' SIZE CODE 0 0 0 0 0 0 0 01 0 6 S LVP 010.HOZ VERIFICATION LISTING PAGE Z ¢ SCMLUMBERGER ~ ALASKA COMPUTING CENTER ,,"' CBMPANY = ~TL~TIC RICHFIELD COMPANY WELL' = 36-7 FIELD = K.UP~ RUK C~UNTY = NORT~ SLOPE BOROUGH STATE = JOB NUMBER AT ACC:. ?1407 RUN ~ONE, DATE LOGGED: 25-MAY'85 LOP: HOWARD.BDL~M CASING TYPE FLUID DENSITY VISCOSITY PH FLUID LOSS MATRIX SANDSTONE 9.6Z5" ~ 36.00' - BIT'SIZE = 8..5" TO X' XC-P~C 10.2 LB/G RM. 38.0 S RMF 7.2 RMC 9.0 C3 RM AT' ~H!T = 5.300 @ 62.0 DF = 5.810 @ 51.0 DF = 4°200 @ ~6o0: DF = 2.522 @ 138.0 DF ~**¢*' THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIE.LD, PRINTS ~~ LVP OlO.H02 VERIFICATION LISTIN~ PAGE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL INDUCTION SPiERICALLY FOCUSED LOG (OIL) FORMATION DENSITY COMPENSATED LOG (FDN) ~ DATA FORMAT RECORD *~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~ ! 66 1 8 4 73 60 9 4 65, ..lin 15 1 66 1 O 1 65 0 SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 AP1 API FILE SIZE SPL REPR ID ORDER~ DEPT FT. O0 000 SFLU OIL OHMM O0 220 ILO OIL DigMM O0 120 ILM~ OIL OHMM O0 120 SP OIL~ M~" O0 0,10 GR OIL GAPI O0 310 SR FDN G~PI O0 310 CALI FDN' IN' O0 280 RHOB FDN G/C3 0'0 350 DRHO FDN G/C3 O0 356 ~RAT FDN O0 .420 RNRA FDN O0 000 YPHI FDN P'~ O0 890 ~CNL FDN CPS O0 ~CNL ~ FDN CPS O0 330 LOG TYPE CLASS MOD NO. PROCESS CODE (OCTAL) 0'0~ 0 O1 0 46 0 44 0 01 0 O1 0 O1 0 O1 0 02 0 O1 0 O1 0 00: 0 O0 0 31 0 30 0 0 4 0 4 0 ,4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4, 58 00000000000000 68 00000000000000 00000000000000 58 00000000000000 58 00000000000000 58 00000000000000 00000000000000 .SB 00000000000000 58' 000000.0000000'0 58 00000000000000 00000000000'000 58 00000000000000 58 00000000000000 68 000000000001000 $8 00000000000000 3E PT 5P ~HOB qPHl 7310.5000 SFLU -40.7070 GR -999.2500 ORHO -999.2500 NCNL 2'6780 ILO 81-9548 GR -9'99'2500, NRAT -999.2500 FCNL 3.0842 ILM' -999.2:500' (ALI '-999.2500 RNRA -99'9.2500, 2.6174 -999,.2500 -999.250,0 LVP 010.H02 VERIFICATION LISTING PAGE OEPT SP RHOB NPHI DEPT SP RH.3B NPHI DEPT SP RHOB NPHI 2EPT SP RHOB NPHI DEPT SP 2HOB qPHI DEPT SP ~HgB 4PHI 3EPT ~P 2HOB ~PHI >EPT ~P ~P HI )EP T. ~P ~H O 8 ~PH I )EPT, ~P ~HOB ]PHI )EPT~ ~P ~HOB JPHI 7300.0000 SFLU -40.7070 GR 2.2542 DRHD 38.9548 NCNL 7200.0000 SFLU -18.9%82 GR 2.~551 DRH3 32.8125 NCNL 7100.0000 SFLU -19.6826 GR 2.3831 DRH2 43.2517 NCNL 7000.0000 SFL~ -22.9951 GR ,2.3811 DRHO 33.1055 NCNL 6900.0000 SFLU -60.7070 GR 2.1741 DRHD 30.9570 NCNL!i 6800.0000 SFL~ -29-7295 GR ,2.4026 DRH'3 3,2.9102 NCNL 6700.0000 SFLU -34.4883 G:R 2.4.5,34 DRHO 27.3838 NCNL 6600.0000 -35.2383 2.~551 31-6895 6500.0000 '-28.~951 2'3'010 44,4824 6400.0000 -32.2383 2.408~ 37.5000 6300.0000 -37.9883 -999.2500 -999.2500 SFLU GR- DRH g NCN L SFLU GR DRH.O NCNL S F L U~ GR DR NCN L SFLU GR DRHO~ NCNL. 2.6760 ILD 81.9548 GR 0.1536 NR~T 1971.6875 FCNL 4.3445 IL2 94.0273 GR 0.0596 NRAT 2087.5000 FCNL 2.9163 ILD 105.0273 GR 0.0649 NR~T, 1:836.6875 FCNL 5.9773 ILO ~1.4023 GR 0.0308 NRAT 2032.6875 FCNL: ~2. 9648 ILO 44.9492 GR 0.. 0122 NRAT 2441. 5000 FCNL 6.34&5 I:LD 86.0898 GR 0.0278 NR'AT' 2105.5000 FCN;L 3.6~48 ILD 85.3398 GR 0.0303 NR~T: 2287- 5000 F,CNL 3-0608 126. 5523 O. 0371 2020. 6875 1.7537 134.6875 0,0195 1595'6875 2.5745 111'0273 0.0181 1720'6875 2.7131 133.3125 -9~9.2500 -999'2500 I.LD GR 'NRAT: FCNL' ILD GR NRAT FC~L ILO GR NRA? FCNL: ILD GR NRAT :FCNL 2.7112 81.9548 3.1897 563.3125 4.1140 94.0273 2.9553 660.8125 2.7561 105.0273 3.5393 481.6~06 5.0125 91.~023 2.9885 590.3125 :57'5430. 44.9~92 2'81'86 767.3125 6,2742 86. 0898 2-9963 67:7.31 ,Z 5 4.481,2 8.5.3398 2.6370: 846.3125 3.0139~ 624,8125 1.6729 134.6875 3.6?Z1~ 402.8906 2.3694 111-0273 3':3¢40 471-6406 2.4~95 133.3125 -999.2500 -999.2500 I'LM CALl RNRA :ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA ILM CALi RNRA CALI RNRA ILM' CALi RNRA ILM' CA'LI RNRA CALI RNR~ CALI RNR~ ILM' CALI R'NRA 2.6174 7.4500 3.5002 4.2507 8.8223 3.1584 2.7795 8.9160 3.8127 5.1765 8.9863 3.4436 57.5117 8.6816 3'1799 6.1492 9.2676 3.1:077 4.4187 9 ' 3 g 26 2. 7014 3.1682 10.4551 3.2346 1.5973 9.7285 3.9592 2.3733 10'4004 3.64:67 2-4768 11.3145 -999.2500 LVP OlO.H02 VERIFICATION LISTIN~ PAGE 5 DEPT 6200.0000 SFLJ SP -40.2070 ER RHOB -999.2500 DRH2 qP~I -999.2500 NCNL OEp? 6100.0000 SFLD SP -41.4883 GR RHg8 -999.2500 DRMg NPHI -999.2500 NCNL DEPT 6000.0000 SFLg SP -16.2451 GR RHDB -999.2500 DRHD ~PHI -999.2500 NC~'L" DEPT 5900.0000 SF!LU SP -16.7607 GR RHOB -99'9.2500 DRH'D ~PHI -999.2500 NCNL DEPT 5800'0000 SP -22.0107 2MOB -999.2500 4P~I -999.2500 DEPT 5700'00'00 SP -15.4980 2HOB -999.2500 {PHI -999,2500 )EPT 5500.0000 ~P -16.7~51 {HOB -999.2500 ~PHI -999.2500 )EPT 5500'0000 ~P -13.5059 2HOB 2.3635 ~PHI 35. 2533 )E P T {H DB ) E P T ~P ~HOB ~P H I ~P 5¢00.0000 -19,5107 2.3127 33-3496 5300.0000 -18.2607 2.3440 41-9922 5200'0000 -21'5264 2,3928 SFLU GR DRHg NCNL SFL~ GR DRH'D NCNL GR. DRHO NC:N'L SFL GR NCNL SPL~ GR. D R H ,3 N C N L SFLU GR' DRHD NCNL SF!LU GR DRHD 2.9534 ILD 223.9375 GR' -999.2500 NRAT -999.2500 FCNL 3.7971' ILD 172.68?5 GR -999.2500 NRAT -999.25,00 FCNL 3.8596 ILD 156'0625 GR -999.2500 NRAT -999.2500 FCNL 2-4768 ILD 111.2~48 GR -999.2500 NR'AT -999.2500' FCNL , 4.2039 ILD 1D3.2773. GR -939.2500 NRAT -9~9.2500 FCNL 2.1545 ILD 116.9023 GR -999.2500: NRaT -999,.2500:' FCNL 2.1702' 107.15.23: GR -9~9.2500. NR&T -999,2500' FCNL 2.1409 ILD~ 97-'77731 GR 0,0298 N'R~T~ 201'9.6875 FCNL 2-4983 ILO: 111. 2148 GR 0-0059 'NRAT 1915.6875 FCNL:! 127'4023 GR 0'0181 NRAT 1808,687:5 FCN.L~ 2.0120 ILD 82.1523 GR 0'0371 NRAT 2,3967 223.9375 -999.2500 -999.2500 3.4417 172.6875 -999.2500 -999.2500 3.6331 156.0625 -999,2500 -999,2500 2.5061 111.2148 -999.2500 -999.2500 4.2859 103.2773 -999-2500 - 9 '99.2500 2.2991 116.9023 -999.2500 -999.2500 2.5100 107.1523 -999.2500 -999,2500 z.3 ,z 9'7.7773 3'I858 544'8125 2.7913 111.2148 3'1038 542.3125 1.774:5 127.¢023 3-5.862 486,1406 z.zo73 82.11523 3.2092 ILM CALI RNRA ILM CALI ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA CALI RNRA ILM: CALI RNR 4, I L M ~ CALl · RNR'A ILM R NRA; I :L'M CAiLI, RNR A, ILM,. CALI RNRA 2,3967 10.8379 -999,2500 3.4084 11.2441 -999,2500 3.6428 ll.$BO1 -999,2500 2.4924 11'3457 -999,2500 4.1257 11.2441 -999.2500 2.2952 10.4160 -999.2500 2,3928 10'3301 -999,2500 2,3362 9,9551 3-7073 2.6936 10.2129 3.5334 1-7618 10.3457 3.7190 2,1643 9,8848 3,1975 LVP OlO.H02 VERIFIC4TI'ON LISTING PAGE 6 NPHI DEPT SP NPHI DEPT SP ~HOB ~PHI 3E P'T SP ~HOB ~PHI DEPT SP 2HOB tPHI D E P T SP 2HOB qP H I DE PT SP ~HDB qPHI )EPT SP 2H 0 B 4PHI )EPT SP 4P~I )EPT ~P ~PHI )EPT SP ~H2B 4PHI )EPT SP 35.7910 NCNL 5100.0000 SFLU -25.0264 GR 2.3909 DRH3 37.1582 NC:~L 5000.0000 SFL~ -24.0264 GR -999.2500 DRHO -999.2500 NCNL 4900.0000 SFLJ -28.2764 GR -999.2500 DRH!2 -999.2500 NCNL 4800.0000 -31.5420 -999.2500 -999.2500 ¢700-0000 -32'5195 -999.2500 -999.2500 ~600.0000 -37.0X95 -999.2500 -999.25:00 4500.0000 -37-~883 -999.2500 -999.2500 4¢00':000'0 -35.269'5 -999.2500 -999.2500 4 oo.ooOo -37.3008 -999. 2500 -9'99.2500 4200.0000 -38.7595 -999.2500 -999.2500 4:100.0000 -38-?595 SFLU GR DRH9 NCNL SFLg GR. NCNL SFLU GR DRHD NCNL SFLJ GR NCNL SFLU GR DRHg NCNL S:FLU GR, DR HO NCN L SFLU GR DRHD NCNL SF'LU GR 2205, . 81. O. 20~9. . 79. -999. -999. 100. -999. -999. . 111. -999. -9~9- 93. - 999. -999. . -999. -999. . ~ g. -9 -999° 99- -9g9. -999 · . 103. -999, -999. . 93. -9g9. -999. 1104. 5000 2092 8398 0356 5000 2561 1523 2500 2500 0452 8398 2500 2500 0530 0273 2500 2500 6194 83,98 2500 250,0 3342 7148 250.0 2500 8870 9:648 2500 2500 8635 3398 2500 2500 9983 71¢8 2500 25O0 4202 0898 2500 2500 9124 0273 FCNL ILD GR NRAT FCNL ILD GR NRAT FCNL ILD GR NRAT: FCNL ILD GR NRAT FCNL ILD GR NRAT., FCNL I L;D GR. N R A 'T FCNL GR NR'AT FCN:L IL D GR NRAT F,C q C ILO GR, NRAT, FCNiL: ILD GR. N'R A T, FCNL ILD GR 689.3125 2.3518 81.8398 3.3010 606.8125 2.3889 -999.2500 -999.2500 -999.2500 2.3967. -999.2500 -999.2500 -999.2500 3.0940 -999,2500 -999.2500 -999.2500 2.8069 -999.250.0 -999,2500 -999'25'00 3,6917. -999.2500 -999.2500 -999.2500 3.28'74 -999.2500 -999.2500 -999.2500 3-1428 -999.2500 -999.2500 -999.2500 3.3~Z0 -999°2500 -999-2500 -999,2500 3.5081 -999,2500 -999,2500 -999.25:00 3,5979 -999.2500 ILM CALI RNR& ILM CALI RN'RA ILM CALI R'NR~ CALI RNRA ILM.: CALI RNRA ILM' CALI RNR& ILM CALI R'NRA IL.M CALI RNRA IL:M' CALI RNR~ ILM~ CALI RNRA CALI 2.2952 10.0801 3.3752 2.2874 -999.2500 -999.2500 2.3108 -999.2500 -999.2.500 3.0178 -999.2500 -999.2500 2.7092 -999.2500 -999.2:500 3.5061 -999.2500 -99'9.2500 3-1194 -99'9,2500 -999.Z500 2'99-53 -99'9.2500 -999.2500 3-1370 -999.2500 -999.2500 3.3733 -999°2500 -999.250:0 3.3499 -999.2500 LVP OlO.H02 VERIFICATION LISTINi~ PAGE ? RHDB -999.2500 DRHO NPHI -999.2500 NCNL -999,2500 NRAT -999,2500 FCNL DEPT 4000.0000 SFLU SP -43.0195 GR RHOB -999.2500 DRMO NPHI -999.2500 NCNL 3,5530 ILD 110.6523 GR -999,2500 NRAT -999.2500 FCNL DEPT 3900.0000 SFLJ SP -59,7695 GR RHOB -999.2500 DRHD qPHI -999.2500 NCNL 3.2424 ILO 107.3398 GR -999.2500 NRAT -999.2500 FCNL 3EPT 3800.0000 SFL,'J SP -55.7695 GR RHOB -999.2500 DRH2 4PHI -999.2500 NCNL 3,5510 ILO 107'7773 GR -999,2500 NRAT -999,2500 FCNL 3EPT 3700.0000 SP -53.2595 ~HDB -999.2500 4PHI ,-999.2500 SFLJ GR DRHD NCN'L 3.2952 ILD 85,5898 GR -999,2500 NRAT -999.2500 FCNL ]EPT SP ~HOB 4PHI 3600.0000 -58.¢883 -999.2500 -999.2500 SFLU GR DR H D NCNL 2,9963 ILD 127,4648 GR -999.2500 NR'AT -999.2500 FCNL )EPT SP ~HDB ~P~I 3500.0000 -46,5195 -999.2500 -999.2500 SFLU GR DRHD NCNL 2,3362 ILO 99,2148 GR -999,2500 NRAT '-9~9,2500 FCNL )E PT ~P ~HOB ~PHI 3400.0000 -50.9883 -999-2500 -999.2500 SFLU GR DRHD NCNL 3.3010 ILO 89-0898 GR -999.25001 NRAT, -999.2500 FCNL )EPT ~P {HOB qPHI 3300,0000 -50,8008 -999°2500 -9'99,2500 SFL~ GR. DRHO NC 3.7366 ILO 75.8398 GR -'999.2500 .NRAT: -999o2500 FCNL, )EPT ~P ~PHI 3268.0000 -82.2227 -999.2500 -999.2500 SFLU GR DRHD NCN.L 0,8306 ILO 53'5117 GR: -999,2500 NRAT -999.2500 FCNL PILE TRAILER ~ :ILE NAME :EDIT .DO1 ;ERVICE NAME : ?ERSION ~, : E : -999.2500 -999.2500 3.8167 -999.2500 -999.2500 -999.2500 3.5881 -999.2500 -999.2500 -999.2500 3.85~8 -999.2500 -999.2500 -999.2~00 3,6018 -999,2500 -999,2500 -999-2500 3.4846 -99'9.2500 -999.2500 -999.250'0 2.5940 -999.2500 -999.2500 -999.2500 3..6~28 -99'9.2500 -999.2500 -999.2500 3.2600 -999-2500 -999-2500 -999.2500 64.77?3 -999.2~00 -999.2500 -999.2500 RNRA CALI RNRA CALI RNRA ILM CALI RNRA ILM CALI RNRA CALl RNRA ILM. CA:LI RNRA ILM, CAiLt RNRA ILM CALI RNRA I LM i RNRA -999.2500 3.6428 -999.2500 -999.2500 3.3889 -999.2500 -999.2500 3.5510 -999.2500 -999.2500 3.3850 -999.2500 -999.2500 3-1799 -999.2500 -999.2500 2.4:045 -999.2500 -999,2500 3.1428 -999.2500 -999.2500 3.2776 -999:..2500 -999-2500 2000.6875 -999.2.500 -999.2500 LYF 010.H02 VERIFICATION LISTING PAGE 8 MAXIMUM LENGTH : 1024 PILE TYPE : ~EXT FILE NAME : ¢~ TAPE TRAILER ~ SERVICE NAME :EDIT ]ATE :85/04/21 ]RI~IN :FSIA TAPE NAME : SONTINU~TI,3N ~ :0! ~EXT TAPE NAME :. ;OMMENTS :LIBRARY T~PE ',.-~c REEL TRAILER X~ SERVICE NAME :EDIT ]ATE :85/0~/21 ]RI$IN : ]EEL NAME :149148 :ONTINU~TION # :01 ~EXT REEL NAME : :OMMENTS :LIBRARY TAPE LIS T~PE VERIFICATION LISTING RECEIVED JAN 0 8 t98,G Alaska 011 & l~as Omi[, GommwMo~ Anchor~9~ LVP Ol0.H02 VERZ~iCATiDN LISTINS 2AG5 1 ~. ~x .,. ,,- ~ .... ,~. ~;. ~: .4. ~.~ .,. ~,,.. ~,~ ~,: ;~,: ~,: ~ ~ ~ .~. NGTE ,,- WELL SiT~ DATA AND TABLES AR~ N~T INCLUDED ~N THIS L~STiN~ ~ 'WAVEFQRMS AND FAST CHANNEL D,~TA. ARE NOT iNCLUDED ZN THIS L,ZST.ING ~: RECEIVED JAN 0 8 ]98G Alaska Oil & Gas t~ Anchorage LVP O!O.HO2 VERIFICATION LISTiN3 PAGE ::-';:: R~EL HEADER ...... SERVICE NAME "EDIT 2.&TE :$5/12/17 ORIGIN : REEL N A ~'IE CSNTZNUATI2N .~ :01 PREVIOUS REEL COMMENTS :LIBRARY ,--,- TEP: H=~DER ....... SERVICE NAME :EDIT DATE :85/12/17 ORIGIN :0000 TAPE NAME :046'8 CO~TiNU6TI3N ~ :0t PREVIOUS TAPE : COMMENTS :LZ~BR&RY TEPE ~, FILE HEADER FILE NAME :EDIT SERVICE NAME VERSION ~ : DATE : MAXIMUM LENGTH : FILE TYPE : PREVIOUS'FILE : 1024 ALASKA COMPUTING ,CEN'TER COMPANY = .~TLANTIC RICHFIELD COMPANY WELL = ~'8-7 mIELD = KUP~RUK COUNTY = NORTH SE:OPE ~OROUGH kVO OlO.M02 VE~IFICaTIO~ L!STIN~ PAgE 3 ST&TE : .&LASKA JOB NUMBER AT ~CC: 71080 RUN ~ONE, DATE LOGGSD: 25-~lA'Y-85 LOP: C. WZLKIE CASING : 9 625" 9 m~ O0 BiT SIZE : $ 5" TO X TYPE FLUIO : XC-P~C DENSITY : 10.2 L..,g/G RM : ]5.300 :~ 6'Z.O DF VISCOSITY : 38.0 S RMF : 5.510 ~ 5!.0 'OF PH = 7.Z RHC = 4.200 ~ 46.0 DF FL Jig LOSS = 9.0 C3 RH ,AT BHT = 2.522 MATRIX S,ANDSTONE ~- ~,- .;: :,- -,. THIS u, ATA HAS NnT BE:N DEPTH S~I~T:;D - OVERLAYS FIELD PRINIS -,.~ .......... SCHLU,qSE~ER LOGS INCLUDED N'ITH TTH'IS M'~GN~:'TIC DUAL iNDUCTION SPqER!C~LLY FSCUSED LOG (DIL) ,,- FDRMATIO~ DENSITY CDMP:NSATED LOG (FDN) RECEIVED JAN 0 8 Alaska Oil & Gas Cons. Commisslor~ Anchorage LVP OlO.H02 VERZF.ZCATiSN LISTING P.~GE 4 ::~;:: DATA FORMAT ENTRY BLOCKS T Y ~ ,..'- 2 16 0 OATJM SPECIFI,CATION BLOCKS MNEM SERVICE SERVICE UNIT DEmT FT' SFLU OIL DHMM ILO OiL DH:MM ILM DIL OHMM SP OIL MV GR DIL GAPI CALl PON iN RHDB FDN GFC3 DRHO FDN G/C3 NR~T. FDN RNR~ FDN NPHI FON PJ NCNL FDN CPS FCNL FDN CP:S 9EPT SP NPHI 73t0,5000 SFLU -40,7188 GR -999,2500 ORHD -999,2500 NCNL 7300.0000 SFLU -~0,7158 GR 2,2539 ORHJ -999,2500 NCNL 7200,0000 SFLU -18.9531 GR 2.4545 ORHO -999,2500 NCNL DEPT SP RHOB NPHi SP 'NPHI SIZE t 1 4 4 i 1 66 66 73 AP.I API API API FiLE LOG TY~E CLASS MOD NO. O0 000 OD 0 0 O0 220 O1 0 0 O0 120 ,46 0 0 O0 120 44 0 0 O0 010 O1 0 0 O0 310 01 0 0 O0 310 O1 0 0 O0 280 O1 0 0 O0 350 02 0 0 O0 356 O1 0 0 O0 420 O! 0 0 O0 000 O0 0 0 O0 890 O0 0 0 O0 330 31 0 0 O0 330 30 0 0 2,5777 iLO 51.9375 GR -999.2500 NRAT -999,2500 FCNL 2.6758 ILO 81.9375 GR 0,1536 NRAT 1971.0000 FCNL 4,3438 ILO 94,0000 GR 0.0596 NRA'T 2036,0000 FCqL ENTRY 0 1 50 .liN 1 0 SIZE SPL REPR CODE 4 1 68 4 1 58 4 ! 68 ~ 1 68 4 1 58 4 1 58 4 1 68 4 I. 68 4 ! 68 4 I 58 ¢ 1 68 4 1 5:8 4 1 68 4 !. 58 3.0840 ILM -999,2500 CALl -999,2500 RNR~ -999.,2500 2,7109 ILM 81,9375 CALI 3,1895 RNR~ 4.1133 ILM 94.0000 CALi 2.9551 RNRA 660.5000 PRJC:ESS (OCTAL) OOO00000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O000000000OO00 00000000000000 O00000OO000000 00000000000000 2.6172 -9'99.2500 -999,2500 2.6172 7.4492 3,50O0 4,2500 8,8203 3,1582 ~ VO 010.H02 VERI:IC~TZON LISTIN~ PAGE 5 gEPT SP NPMi 2EPT SP RHO8 NPHI DEPT SP RHg8 NPqI DEPT SP RH2B NPHI DEPT SP RHOB, NPHi DEPT SP RHOB NPHI DEPT SP RHO8 NPHI DEPT SP NPHI D6PT SP RHgB NPHI DE PT SP RHDB NPHI DEPT SP RH05 7100.0000 SmLJ -19.5875 GR 2.3828 ORHS -999.2500 NCNL 7000.0000 SFLU -23.0000 GR 2,3809 DRH3 -9'99.2500 NCNL 6900.0000 SFLU -60.7188 GR 2.1738 DRH2 -999.2500 NCNL 6800.0000 SFLU -29.7344 GR 2.4023 DRHD -99'9.2500 NCNL 6700o0000 SFLU -34.5000 GR 2,4531 DRHD -999,2500 NCNL 8600.0000 SFLU -35.2500 GR 2.4548 DRHiD -999.2500 NCNL 5500.0000 SFLU -28.,5000 GR 2.3008 DRHD -999.2500 NCNL 6400'0000 SFLU -32.2500 GR 2.4082 DRH~ -999.2500 NCNL 6300.0000 SFLU -38.0000 GR -999,2500 ORHS -999.2500 NCNL 6200,0000 SFLU -40.2187 GR -999.2500 DRH3 -999.2500 NCNL 6100,0000 SFLU -41,5000 GR -9'99.2500 ORH~ 2.9160 ILO 1'05.0000 GR 0.0549 NRAT 1836.0000 FCNL 5.9756 IL~ 91.3750 GR 0.0308 NR~T 2032.0000 FCNL 92.9375 ILD 44.9375 GR 0.0122 NRAT 2440.0000 FCNL 8.3438 ILD ~6.0525 GR 0.0278 NR~T 2104,0000 FCNL 3.6~45 IL3 85.3125 GR 0,0303 NRAT 2286.0000 FCNL 3.0605 I:LD 126,6250 GR 0,0371 NRdT 2020.0000 FCNL 1.7537 IL~ 134..5250 GR 0.0195 NRAT 1595,.0000 FCqL 2,5742 ILD 111,0000 G.R 0.0181 NRAT 1720.0000 FCNL 2.7t29 IL~ 133,2500 GR -999,2500 NRAT -999.2500 FCN'L 2,9531 223,8750 G~ -999.2500 NRAT -999,2500 FCNL 3.7969 iLO 172.6250 GR' -999.2500 NRAT 105. 3. 481. 91. 2. 590. 57. 44. 2. 757. . 36, 2. 577. 8 4 6. 126. 3 · 624. 134. 3, 402, 2. 111. 3. 471 · . 133. -999. -999. 223. -999 · -999. ¸3 .. 17,2. -9 '99. 7559 0000 5391 5000 0117 3750 9883 0000 5313 9375 8184 0000 2734 05.25 9261 0000 4805 3125 6387 0000 1035 6250 0137 5000 6'729 6250 6719 7500 3591 00 O0 .3438 5000 4492 2500 2500 2500 3965 8750 2500 2500 4~14 6250 2500 ILM CALI RNRA ILM CALi RNRA ILM CALl RNRA !LM CALl 'RNRA ILM CALl RNR& ILM CALI RN,Rt I 'L ~ C A L I RNR A ILM CALl RNRA ILM CALl RNRA tLM CALI RNRA ILM C AL I RNRA 2.7793 8.9141 3.8125 5,1758 8.9844 3. 4434 57.5000 8.6797 3.1797 6.1484 9.2656 3.1074 4.4180 9.3906 2.701.2 3.1680 10.4531 3.2344 I. 69'73 9.72,56 3.9590 2.3730 10.3'984 3.8465 2.4766 11.31:25 -999,2500 2.3965 10.835'9 -999,2500 3.4082 I i. 2422 -'999.25 O0 RECEIVED J AN 0 8 1986 Naska OIi A Gas Co,s, (;ommWsion Anchorage LVP 010.HOZ V~R!FIC~TiON LISTIN$ PAGE 6 NPHI OEPT SP RH26 NPHI OEPT SP NP~I OEPT SP RHOB NPHI OEPT SP NPH! DEPT S? D~PT SP RH05 NPSI DEPT SP RHD5 NP~I DEPT SP RHOB NPHI DEPT SP NPHI DEPT SP RH3$ NPqI DEP'T SP -999.2500 NCNL 6000.0000 SFLO -16.2500 GR -999.2500 DRff2 -999.2500 NCNL 5900.0000 SFLU -16.7556 GR -999.2500 DRHD -99'9.2500 NCNL 5800.0000 SFLU -22.0156 GR -999.2500 DRHD -999.2500 NCNL 5700.0000 SFLU -15.5000 GR -999.2500 DRHO -999.2500 NCNL 5600.0000 S~LU -16.7500 GR -999.2500 ORH:O -99'9.2500 NCNL 5500.0000 SFLJ -13.5078 GR 2.3633 DRHD 35.2539 NCNL 5600.0000 SFLJ -19.5156 GR 2.3125 DRHS 33.3496 NCNL 5300.0000 SFLU -18.2655 GR 2.3435 ORHO 41.9922 NCNL 5200.0000 SFLJ -21.5313 GR ,2.3926 DRHJ 35.7910 NCNL, 5100.0000 SFLU -25.0313 GR 2.3905 ORHO 37.1582 NCNL 5000.0000 SFLU -24:.0313 GR -999.2500 FCNL 3.$594 156.0000 GR -9'~9.2500 NR~T -999.2~00 FCNL 2.4756 ILO 111.1875 SR -'999.2500 NR~T -999.2500 FCNL 4.2031 ILO 103.2500 SR -999.2500 NR4T -999.2500 FCNL 2.t543 ILD 116.8752 GR -999.2500 NRAT -999.2500 FCNL 2.1699 ILO 107.1250 GR -999.2500 N~dT -999.2:500 FCNL 2.1~05 ILO 97.7500 GR 0.0298 NRAT 2019.0000 ~CNL ,2.~980 ILO 111.1575 GR 0.0059 NRAT 1915.0000 FCNL 1.857,4 ILO 127.3750 GR 0.0181 NR~T 1808.0000 FCNL 2.0117 I'LO 82.1250 GR 0.0371 NR4T 220.4.0000 FCNL 2.2090 ZLD 81.8125 GR 0.0356 NRAT 20~8.0000 FCNL 2.2559 79.1250 -999.2500 3.6328 156.0000 -999.2500 -999.2500 2.5059 111.1875 -999.2300 -99'9.2500 4.2852 103.2500 -999.2500 -999.2500 2.2988 116.8750 -999.2500 -999.2500 2.5098 107.1250 -999.2500 -999.2500 2.3320 97.7500 3.1555 544.5000 2.7910 111.1875 3.1035 5:~2.0000 1.7744 127..3T50 3.5959 486.0000 2.2070 82.1250 3.2090 689.0000 2.3516 81.8125 3.3008 606.5000 -9'9'9.25,00 ILM C4LI RNRA ILM CALI RNR4 ILM CALl RNRA iLM CALl RNR~ ILM CALI RNR~ ILM C4LI RNR4 ILM CALl 'RNRA ILM CALl RNR~ ILM CALI RNRA ILM CALI RNR4 ILM CALl 3.6426 11.5781 -999.2500 2.4922 11.3438 -999.2500 4.1250 11.2422 -999,2500 2.2949 10.4141 -999.2500 2.3926 10.3281 -999.2500 2.3359 9.9531 3.'7070 2.6934 10.2109 3.5332 1.7617 10.3438 3.7188 2,.15,41 9.8528 3.1973 2.2949 10.0781 3.3750 .2.2~71 -999.2500 LVP OlO.H02 VERIFICaTiON LISTING P4GE T RM35 -999.2500 NPqI -999.2500 NCNL DEPT 4900.0000 SFLU SP -28.2813 GR RHSB -999.2500 DRH9 NPHi -999.2500 NCNL OEPT 4800.0000 SPLU SP -31.546'9 GR RHgB -999.2500 DRH3 NPHZ -999.2500 NCNL DEPT 4'700.0000 SFLU SP -32.5313 GR RHOS -999.2300 DRH3 NPHI -999.2500 NCNL DEPT 4600.0000 SFLJ SP -.37.0313 GR RHOB -999.2300 ORH~ NPHZ -999.2500 NCNL DEOT aSO0.O000 SFLO SP -37.5000 GR RHS6 -999.2500 ORHD NPHI -'999.2500 NCNL DEPT 4400,0000 SFLU SP -35.2813 GR RH3B -999.2500 DRHO NPHi -999.2500 NCNL DEPT .4300.0000 SFLU SP -37,.3125 GR RHDB -999.2500 ORHS NPHI -999.2500 NCNL DEPT 4200.0000 SFLU SP -38.T~13 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEP'T 4100.0000 SFLU SP -38.7813 GR RHOB -999.2500 DRH~ NPHI -999,2500 NCNL DEPT 4000.0000 S~LO SP -43.0313 GR RHD5 -999.2500 ORHO NP~i -999.2500 NCNL DEP'T 3900.0000 SFLU -999.2500 NR&T -9~9.2500 ~CNL 2.0~49 ILD 100.8125 GR -999.2500 NR~T -999.2500 PCNL 3.0327 ILD 111.0000 GR -999.2500 NRAT -999.2500 FCNL 2.6191 ILD 93.8125 GR -999.2500 NR~T -999.2500 FCNL 3.3340 ILO 97.68'73 GR -999.2500 NR~T -999.2500 FCqL 2.8867 ILD 99.9375 GR -999.2500 NRAT -999.2500 FCML 2 · 8633 ILO 99.3125 GR -9 ~9. ZSO0 NR AT -999.£500 FCNL 2.9980 ILD 103.6875 GR -999.2500 NR~'T -999.2500 :CNL 3.4199 ILD 93.0525 GR -999.2500 NRAT -999.2500 FCNL 2.912! ILO 104.0000 GR -999.2300 NRAT -999.2500 FCNL 3.51527 ILD 110.6250 GR -999.2500 NRdT -999.2500 FCNL 3.2422 ILD -'999.2500 -999.2500 Z. 3953 -999.2500 -999.2500 -999.2500 3.0938 -9~9.2500 -999.2500 -999.2500 2.8066 -999.2500 -999.2500 -999.2500 '3.891~ -999.2500 -999.2500 -999.2500 3.2871 -999.2500 -999.2500 -999.2500 3.1426 -999.2500 -999.2500 -999.2500 3.3418 -999.2500 -999.2300 -999.21500 3.5078 -999.2500 -999,.2500 -999.2500 3.59"?'? -999.2500 -999.2500 -999.2500 3.8164 -999,2500 -999.2300 .-999.2500 3.5879 RNR~ ILM CALI RNRA ILM CALl RNRA ILM CALI RNR4 ILM CALI RNR~ I L M CALI R N R ~ ILM C ~L'I RNRA ILM CALi ILM CALl RNRA ILM C & L I RNRA ILM CALI RNRA I LM -999.2500 2.3105 -99'9.2500 -999.2500 3.0176 -999.2500 -999.. 2500 2.7090 -999.2500 -999.2500 3.5059 -999.2500 -999.2500 3.1191 -999.2500 -999.2500 2.9961 -999.2500 ,-999.2500 3,1367 -999.2500 -999.2500 3.3730 -999.2500 -999.2~00 3.3496 -999.2500 -999.2500 3.8426 -9'99.2500 -'999.2500 3.3887 RECEIVED ,JAN 0 8 198G Alaska, Oil & Gas Cons. Commissior, Anchorage LVO OIO.HOZ VERiF!CATiSN LISTIN$ o.&GE 8 SP -39.7813 GR RH3B -999.2500 DRH3 NPHi -999.2500 NCNL OEPT 3800.0000 SFLD SP -55.7813 GR 9HDB -999.2~00 OR,D NPHI -999.2500 NCNL DEPT 3700.0000 SFLJ SP -53.2813 GR RHOB -999.2500 DRH3 NPHI -999.2500 NCNL OEPT 3500.0000 SFLU SP -58,5000 GR RHOB -999.2500 ORH3 NPqI -999.2500 NCNL DEPT 3500.0000 SFLd SP -fi6..'5313 GR RH3B -999.2500 DRH3 NPHI -999,.2500 NCNL DEPT SP NPHI DEPT SP RHOB NPHI DEPT :SP RHOB NPHI 3.400.0000 SFLU -Sl. O000 GR -999.2500 DRHS -999.2500 NCNL 3300.0000 SFLJ -50.8125 GR -999.2500 DRH3 -999.2500 NCNL 3268.0000 SFLU -82.2500 GR -'999,2500 DRHD -999.2500 NCNL 107.3125 GR -999.2500 NRAT -999.2500 FCNL 3.5508 iLO 137.7500 SR -999.2500 NRAT -999.2500 FCNL 3.2949 25,5525 GR -999.2500 NR~T. -999.2500 FCNL 2.9961 ILO 127.4375 -999.2500 NR&T -999.2500 FCNL 2.3359 ILD 9'9.1875 GR -999.2500 NRAT -999.2500 FCNL 3.3008 ILB B9.0525 GR -999.2500 NRAT -999.2500 FC~L 3.7363 IL2 '7S.B125 GR -999.2500 NRAT -999.2500 FCNL 0.8306 ILO 53,5000 GR -999.2500 NRAT -9')9.2500 FCNL ~: FILE T'RAILER '~ FILE NAME :EDIT .001 SERVICE NAME VERSION # DATE : ~AXIMUM L~NGTH ~ I024 FILE TYPE : NEXT FILE NAME : ~ TAPE TRAILER ~ SERVICE NAME :EDIT -999.2S00 -999.2500 -999.2500 3. B516 -9'99.2500 -999.2500 -999.2500 3.6016 -999.2500 -99'9.2500 -999.2500 3.4844 -999.2.500 -999.2500 -999.2~00 2.5938 -999.2500 -999.2500 -999.2500 3.6426 -999.21500 -9'99.2500 -999.250O 3.25,98 -999.2500 -999.2500 -999.2500 64.7500 -999.2500 -999.2500 -999.2500 CALl RNRA ILM CALI RNR4 iLM CALI RNRA ILM CALI RNR4 !LM C&Li RNRA ILM CALI RNR~ ILM CALi RNRA ILM CALI RNRA -999.2500 -999.2500 3.5508 -999.2500 -999.2500 3.3848 -999.2500 -999.2500 3.1797 -99'9.2500 -999.2500 2..40~3 -999.2500 -999.2500 3.1426 -999.2.500 -999.25 O0 3.27'73 -999.2500 -999.2500 2000.0000 -999.2500 -999.2500 LV° OIO.HOZ VERIFICATION LiSTiN$ PAGE 9 DATE :85/12/17 ORIGIN :0000 TAPE NAME :0468 CONTINUATION ~ :Gl NEXT TAPr- NAME : COMMENTS :LIBRARY TAPE ,,--,- REEL TRAILER SERVICE NAME :EDIT DATE :85/12/17 ORIGIN : REEL NAME : CONTINUATION ~ :01 NEXT REEL N.A,~E : COMMENTS :LIBRARY TAPE L¥~ OlO,H02 VERIF!¢~.ATIO~ L~iSTING PAGE LVP O:ln.H02 'vEP,I, FICA~Tr~N 6TS'rING PA6E 2 SEPVIC~ f',~ A M E DA'rE :~5/O&/ 1 ORTG~N ~ CO~TINf~ATI~N ~ :01 PREVTO~S R~E[, ** 'I',APF f'~EAD~'R ** SEP, V TCW ,~ A ~ g : ED~tT DATE :g5/06/ ORIGIN :0000 TAPE NAME :0~68 PREVIOUS TAPF C[)~MFNTS :f,IBR~RY TAPE ********** EOF ** FTLFi ~EAI)F,R FILE N~Mg :~DIT SERVIC~ MA~E : VERSION# : DATE : MAXI~U~ t.,E~(;TM : 1024 ~ILE TYPE PREVIOUS F~LE : ** If~IFOR~A~,ION R'~CORn, 8 WN : 3B-7 F N : Y U P A *~ U K ~A~!G: gE TOWN: SECT: ~, 6 COUN: N,SLOpE STET: ~,L,~ SKA PR~$: F UNIT TYPE CATE SIZE CODE 000 000 015 065 000 000 004 065 000 000 O07 O65 000 000 002 065 000 000 003 065 000 000 002 065 000 000 007 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SiZE CODE 000 000 001 065 * AbASKA CO.,MPUTI~TG CE!~'t~!]~ ~; COMPANY = AT~ANTIC RICHFIEbD CO~P~NY WELL = 3n-7 COUNTY = NORTR S~,[]o~.~ bO~UG~ ST~TW : ALASKA JOB NL,,~:~[::~FR AT /~,CC: 70468 LDP: C~_'i:~ CASING : 9,625" fa 36.00' - ~.IT SIZE = 8,5" TO TYPE [","'t, UID : XC-PAC VI'~COSI'I'Y : 3~,0 S R~F : 5,810 ~ 51.0 DF PH . 7.~ ~(,,. - 4.200 (a 46 DF FLUID [..USS = n.0 fi3 ~'~ AT BfIT : 2.5~2 (9 13~'0 DF ~ATRIX , O" .... O OVE~LA.¥S Fl[ELD PRINTS *,**** THTS I'.)~TA HAS ~I,, B,g~,~ D~PT~,~, SH'I~T~ .... - . ********************************************************************************** PAGE 4 , , , , , , , , , * , , , , * ~ , , , , , , , ~ , * , , , , , * · .~CFiblINP:E~Gw.~! bOGS TNCLI~D~D ~IT~ THTS MAGMETIC TAPE: * , , · DUah INDUCTIO~.I SPMERIC~LLY F'OCI. JSFD bOG (DIll) * · rO~M~TTON DE~.~SI'.FY CC~P~NSATED LOG (FDN) * , * DATU~ SPECIFIC,~TION ~bOC~iS M.NE~ SERVICE f,;ERVICF,. UNIT API API APl API Fi[bE SIZE SP[,, REP'R :ID OPOER ~ I,,t~G TYPF. CI~.,~SS MOD NO. DEPT FT O0 000 O0 0 0 4 SFLU 9IL OHMt4 00 220 01 0 0 4 I b ~ ~) I L 0 H ~ a 00 l; 20 46 0 0 ~ Ib~ nil OH~a O0 1,20 ~,4 0 0 4 SP ~)IL ~V O0 010 O1 0 0 4 G R D i !., O A P 'I 0 () 310 01 0 0 4 ~R ~DN ~API 00 310 01 0 0 4 RHOB ~P~ ~/C3 O0 350 02 0 0 ~, DRHO VDN ~/C3 00 356 01 0 0 4 N R ~ T W P ~ 00 420 01 0 0 4 ~N~A VD~ O0 000 O0 0 0 4 NPMI FDN DU ~0 890 00 0 0 4 CO[) ...... (OCTAL) 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 i 68 00000000000000 1 68 00000000000000 i 68 00000000000000 I 6~ 00000000000000 1 68 00000000000000 I 68 00000000000000 LYP 010.;.t02 VERiFICAWI~r,I I.,T~TING PAGE ~C~L F 1.3 ~,~ CPS O0 33n FCNL w!.) ~,I CPS O0 330 30 0 ** DATE ** DEPT 7310.5000 SP -40.71~8 RHOB -090.~5n0 ~P~l -090.2500 ~fCWb -'99e DEPT 7000 0000 SFT,U SP -2310000 RHO~ 2 3809 MPWI 99° p5oO ' , ,tCMb 5 9! 0 203~ ~£PT ~200iO0nO SFt,U SP 16 250o RHOB o90 2500 OR.O MpwI -990,P500 .6777 2500 2500 5200 0000 SFLU 24'031.3 GR -99o~25no PR}:~O 9q. 250() NCNb .a766 .375o nR 3 o 8 ~'.!R a T DEPT 4000.0000 SF!,,U SP -43 0313 dR RHOB -999'2500 ~RHO NPWi -~q°'7500 2559 Iht) 79:J250 OR -099'25~0 -999.~500 SERVTCE NAME; VERSIOW ~ : BATE : MAXiMLJu' ~,EMGTH : 1024 WILE TYPE : ~EXT FtbE uhuE; : 3.5527 110,6250 GR -099.7500 ~tRAT ** TAPE TRAil, ER SERVICE F!AME :EDTT DATE :~/0~/ ORIGTN :~000 TAPE NAME 0 53 -999 -999 EOF .8306 IhB .5000 ~R .2500 ~CNb o -090. -999, -090. 0 2, ~90, -999, -q9g, -099, o -999. -999, -099. i -999. -999, 64. 099, 990. -999, 084O ?500 ?50O 2500 011.7 3'750 9803 O000 6328 2500 2500 2500 38~7 2500 250O 2500 ~164 2500 2500 250O 7500 25OO 2500 :2500 t 68 00000000000000 68 00000000000000 Th~ 5.1.758 CALI 8,9844 RNRA 3,4434 Ib~ 3,6~26 CA[:,,I -99q,2500 RNRA -999.2500 IbM' P,~871 CAUI '999. 500 RNRA '099.2500 Ib~ 3,6426 C.hI.,I -999.2500 RN~A -~99.2500 :[I,,M 2000,0000 CALI -999,2500 ~:N~A ~099,750(.) ~L~ 2.6172 CA[,I -099,2500 RIqRA -990,2500 [,VP Ol.~.H()~ VIi]PlPICATIr~[~ I~TSTiNG P,AGE 6 CONTTN!~ATION ~ :~I COWNFNTS :~,I~R~RY TAPE aR!GIN :
