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Home My WebLink About189-082MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-06 50-103-20110-00-00 189-082-0 W SPT 6006 1890820 1800 2740 2740 2740 2740 320 2000 1900 1880 REQVAR P Guy Cook 6/11/2025 MIT-OA to 1800 psi per AIO 2C.054 amended. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 2K-06 Inspection Date: Tubing OA Packer Depth 1040 1110 1110 1110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612074627 BBL Pumped:1 BBL Returned:1 Tuesday, July 22, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-06 50-103-20110-00-00 189-082-0 W SPT 6006 1890820 3000 2740 2740 2740 2740 365 650 650 660 REQVAR P Guy Cook 6/11/2025 MIT-IA to maximum anticipated injection pressure per AIO 2C.054. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 2K-06 Inspection Date: Tubing OA Packer Depth 1050 3460 3340 3330IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612074332 BBL Pumped:3.7 BBL Returned:3.7 Tuesday, July 22, 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:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-06 50-103-20110-00-00 189-082-0 W SPT 6006 1890820 1800 2660 2675 2675 2675 130 2080 1990 1970 REQVAR P Kam StJohn 6/20/2023 MIT-OA to 1800 psi per amended AIO 2C.054 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 2K-06 Inspection Date: Tubing OA Packer Depth 600 630 630 630IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621141515 BBL Pumped:1.2 BBL Returned:1 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 MIT-OA to 1800 psi James B. Regg Digitally signed by James B. Regg Date: 2023.07.31 14:37:39 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-06 50-103-20110-00-00 189-082-0 W SPT 6006 1890820 3000 2675 2675 2675 2675 180 540 550 550 REQVAR P Kam StJohn 6/20/2023 MIT-IA to maximum anticipated injection pressure per AIO 2C.054 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 2K-06 Inspection Date: Tubing OA Packer Depth 550 3460 3300 3280IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621141116 BBL Pumped:3.6 BBL Returned:3.3 Thursday, July 27, 2023 Page 1 of 1            MEMORANDUM TO: Jim Regg ��11� 7/AI Zezl P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 2K-06 Insp Num: mitBDB210623075325 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Sre: Inspector Reviewed B P.I. Supry �JQ1�-- Comm API Well Number 50-103-20110-00-00 Inspector Name: Brian Bixby Permit Number: 189-082-0 Inspection Date: 6/20/2021 Wednesday, June 30, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-06 Type Inj W VD j 6006 - 'Tubing, 2490 - 2490 _ 2490 - 2490 PTD 1890820 'Type Test SPT Test psi - - -- 1800 T--1 IA 700 760 750 - 750 BBL Pumped 1.3 IBBL Returned: 1 12 OA 200 2000 1870 - 1840 Interval REQvAR P/17P Notes: MITOA as per AIO 2C.054 Wednesday, June 30, 2021 Page I of 1 MEMORANDUM TO: Jim Regg � � %l ��{122rZ I P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 2K-06 Insp Num: mitBDB210623075000 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-06 KUPARUK RIV UNIT 2K-06 Src: Inspector Reviewed By- P.I. Supry Comm API Well Number 50-103-20110-00-00 Inspector Name: Brian Bixby Permit Number: 189-082-0 Inspection Date: 6/20/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-06 ` LType Inj TVD 6006 Tubing 2490 - 2490- 2490 - 2490 - PTD 1890820 ]Type Test sPT-Test psi - - yp p 3000 IA 690 3300 3130. 3120 — BBL Pumped: 4 ' rBBL Returned: 3.8 OA 250 550 _ 560- 560 - Interval REQVAR P/F P ✓ Notes: MITIA as per AIO 2C.054 ,. Wednesday, June 30, 2021 Page I of I Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, January 22, 2021 4:30 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Specialist CPF2 Subject: RE: KRU 2K-06 (PTD# 189-082) Return to normal Waivered Status Attachments: 2K-06.pdf; 2K-06 90 Day TO plot.pdf Chris- KRU 2K-06 (PTD# 189-082) has been reported showing signs of suspected IAxOA communication again. The well completed a 30 -day IAxOA monitor period in early September with the IAxOA demonstrating stabilization while maintaining a differential pressure. Recently the IA and OA have shown a slow pressure convergence. The IA was charged to establish a differential pressure and the OA has since steadily increased. During the last set of diagnostics the IC pack -off failed testing and due to the nature of the intermittent communication the pack -off is suspected to be the source of IAx0A communication. At this point in time because the IAx0A communication appears to be intermittent, CPAI intends to leave the well on water injection and submit an amendment to AIO 2C.054 for continued water injection only with known TxIA on gas injection and intermittent IAx0A communication. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO trend and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM CmocoPNtlips From: Well Integrity Compliance Specialist CPF1 & 2 Sent: Wednesday, September 2, 2020 7:35 AM To: 'Wallace, Chris D (CED)' <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 2K-06 (PTD# 189-082) Return to normal Waivered Status Chris, KRU 2K-06 (PTD# 189-082) has completed the additional 30 day IAx0A monitor period. The IA & OA pressures have both stabilized & have not demonstrated the existence of IAxOA. CPAI intends to return the well to its normal waivered status. Attached is a copy of the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Matt Miller Filling in for Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, September 2, 2020 7:35 AM To: Wallace, Chris D (CED) Cc: CPA Wells -Supt Subject: KRU 2K-06 (PTD# 189-082) Return to normal Waivered Status Attachments: 2K-06 Schematic.pdf, 2K-06 90 day TIO plot.pdf Chris, KRU 2K-06 (PTD# 189-082) has completed the additional 30 day IAxOA monitor period. The IA & OA pressures have both stabilized & have not demonstrated the existence of IAxOA. CPAI intends to return the well to its normal waivered status. Attached is a copy of the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Matt Miller Filling in for Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 354-5520 WELLS TEAM ConocoP nips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, August 2, 2020 3:37 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 2K-06 (PTD- 189-082) Update to 30 day suspect IAxOA monitor Attachments: 2K-06 90 Day TIO plot.pd ; 2K-06.pdf Chris- KRU 2K-06 (PTD# 189-082) has completed the 30 day IAxOA monitor period. The OA continued to increase in pressure however, the IA did not demonstrate a pressure reduction as we would typically expect to see. To verify that the pressure source of the increasing OA is in fact the [A, CPA] intends to extend the monitor period by 30 days and reduce the IA pressure below the OA and monitor for continued OA pressure build up. Depending on the results of the extended monitor period, the proper paper work for continued injection or repair will be submitted. Attached is a copy of the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM conact"llips From: n tegrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, l 26'20:0 6:52 AM To: Wallace, Chris CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <rC @conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocoohillios.com Subject: RE: KRU 2K-06 (PTD- 1890 Report of suspect annular communication Chris- KRU 2K-06 initial diagnostics have been comp d. The well passed the diagnostic MIT -IA, MIT -OA, IA DDT and OA DDT, however failed the IC pack off tests. CPAI intends eturn the well to injection and conduct a 30 day monitor period for IAxOA communication while the well is on injectio If the well does in fact have IAxOA communication, an amendment to AID 2C. 054 will be submitted to include the IAxO mmunication. If at the end of the 30 days the well does not show indications of IAxOA communication the well will return normal injection status under the current NO 2C. 054. Please let me know if you have any questions or disagree with this Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, June 26, 2020 6:52 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: KRU 2K-06 (PTD- 189-082) Report of suspect annular communication Chris- KRU 2K-06 initial diagnostics have been completed. The well passed the diagnostic MIT -IA, MIT -OA, IA DDT and OA DDT, however failed the IC pack off tests. CPAI intends to return the well to injection and conduct a 30 day monitor period for IAxOA communication while the well is on injection. If the well does in fact have IAxOA communication, an amendment to AID 2C. 054 will be submitted to include the IAxOA communication. If at the end of the 30 days the well does not show indications of IAxOA communication the well will return to normal injection status under the current AID 2C. 054. Please let me know if you have any questions or disagree with this plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Cwwco`P1+191 ps From: Well Integrity Compliance Specialist CPF1 & 2 Sent: Monday, June 22, 2020 10:41 AM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 2K-06 (PTD- 189-082) Report of suspect annular communication Chris, KRU 2K-06 (PTD 189-082) (AID 2C.054) has been shut in since June 13, 2020. Operations reported the well today for suspect IAxDA communication. The OA pressure was bled down twice, but resumed increasing along with the IA pressure appearing to be decreasing. The plan is for DHD to perform initial diagnostics after which a diagnostic plan will be formulated. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM Cs�wca3'ld�lps MEMORANDUM State of Alaska Alaska Oil and Cas Conservation Commission TO: Jim Regg o �I�I DATE: Wednesday, June 26, 2019 P.I. Supervisor `(�`2 t1q SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-06 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-06 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-06 IInsp Num: mitL01-190610170551 Rel Insp Num: API Well Number 50-103-20110-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-082-0 Inspection Date: 6/8/2019 — Packer Depth Well zK-ob Type Inj w TVD 6006 Tubing -- — r -W PTD 1890820 _ Type Test SPT -Test psi 3001, IA BBL Pumped: 39 BBL Returned: 0 Interval KEQVAR P/F Notes: MIT -IA to Maximum anticipated injction pressure per AIO 2L054 Pretest Initial 15 Min 30 Min 45 Min 60 Min -- 30.0 2650 ' � 2655 0 650 GS 3300 3175 - 3150 _ 270 310_" L_ 310 Wednesday, June 26, 2019 Page I of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, November 3, 2017 3:59 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of OA pressure anomaly 2K-06 (PTD 189-082) update 11-3-17 Chris, Earlier this year, per the note below,we had begun a diagnostic monitor period while on water injection after TxIA communication on gas-only became suspected. Due to reservoir management issues for an offset drilling project, 2K-06 needed to be shut in prematurely. The well has been shut in since April 26, 2017. The drilling project is complete and we intend to restart the 30 day monitor on water injection, in anticipation of an AA submittal. Please let us know if you disagree with the path forward. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 ,,rr��11 r, Mobile Phone (757) 651-1622 SAN "` From: NSK Well Integrity Supv CPF1 and 2 S t: Friday;April 14, 2017 4:16 PM To:chr allace@alaska.gov Cc:Senden, . ler<R.Tyler.Senden@conocophillips.com> Subject: RE: Repo -of OA pressure anomaly 2K-06(PTD 189-082) update 4-14-17 Chris, Last month 2K-06 was reported possible IAxOA communication issue. The MITIA and MITOA both passed on 3/23/17,with the tubing packoff testsrising,and the negative drawdown inner casing packoff test failing. During the monitor since then,while the OA has not dbmonstrated any repressurization,the IA has now begun to become suspicious. There has been a repeated buildup i A pressure with an approximate buildup rate of^'120psi per day. The well has been on gas injection since 9-15-16. CPAI i nds to WAG the well to water injection for a 30 day monitor period to confirm the theory that this TxIA communicatio 's only present while on gas injection. There may be a several-day delay in WAG'ing due to anticipated phase weath expected to hit later today. Followup communication will be provided at the end of the monitor. Please let me know if ,u disagree with the plan forward. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent:Wednesday, March 22, 2017 10:27 AM To: 'chris.wallace@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Report of OA pressure anomaly 2K-06(PTD 189-082)3-22-17 N 1 410 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,April 14, 2017 4:16 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of OA pressure anomaly 2K-06 (PTD 189-082) update 4-14-17 Attachments: 2K-06 90 day TIO 4-14-17.emf; MIT KRU 2K-06 diagnostic 03-23-17.xlsx Chris, Last month 2K-06 was reported for a possible IAxOA communication issue. The MITIA and MITOA both passed on 3/23/17,with the tubing packoff tests passing,and the negative drawdown inner casing packoff test failing. During the monitor since then,while the OA has not demonstrated any repressurization,the IA has now begun to become suspicious. There has been a repeated buildup in IA pressure with an approximate buildup rate of^'120psi per day. The well has been on gas injection since 9-15-16. CPAI intends to WAG the well to water injection for a 30 day monitor period to confirm the theory that this TxIA communication is only present while on gas injection. There may be a several-day delay in WAG'ing due to anticipated phase weather expected to hit later today. Followup communication will be provided at the end of the monitor. Please let me know if you disagree with the plan forward. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Mobile Phone (907)943-0170 SCANNED APR 2 0201i, From: NSK Well Integrity Supv CPF1 and 2 Se -•Wednesday, March 22, 2017 10:27 AM To: 'chri . allace@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R. ler<R.Tyler.Senden@conocophillips.com> Subject: Report of • : •ressure anomaly 2K-06 (PTD 189-082)3-22-17 Chris, Kuparuk WAG injector 2K-06 (PTD 18•-e:2) is displaying an OA pressure anomaly while on gas injection. While there has been recent significant change in injecti.• emperature, causing a need for multiple OA bleeds, after a closer review of the TIO plot,there is some question whether th- • al effects are masking some other possible communication issue. Therefore we plan to begin troubleshooting with . .D later today to include MITIA/MITOA, packoff and drawdown testing. Following the diagnostics, pending passin: 4 ITs,the well will be put on a 30 day monitor period. A followup email will be provided at the conclusion of the monitor. • ;.se let us know if you disagree with the plan forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907)943-0170 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, March 22, 2017 10:27 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of OA pressure anomaly 2K-06 (PTD 189-082) 3-22-17 Attachments: 2K-06 90 day TIO 3-22-17.PNG; 2K-06 schematic.pdf Chris, Kuparuk WAG injector 2K-06 (PTD 189-082) is displaying an OA pressure anomaly while on gas injection. While there has been recent significant change in injection temperature, causing a need for multiple OA bleeds, after a closer review of the TIO plot,there is some question whether thermal effects are masking some other possible communication issue. Therefore we plan to begin troubleshooting with DHD later today to include MITIA/MITOA, packoff and drawdown testing. Following the diagnostics, pending passing MITs, the well will be put on a 30 day monitor period. A followup email will be provided at the conclusion of the monitor. Please let us know if you disagree with the plan forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED APR 2 4 2017 1 L.., r r ce (.) (.') (') (.) a w N Q j w w (� O O - - 1n w CZ U O 0 0 a o CO W N G t` . O V1 CC m a1 w m Cl) Lu C. [.> V U U Ce ,- '-1 O O I- N r r .r r . w o 0 0 0 I- rJ M N r C] �1 41 CD Cl.) fD 0 O V 0 J Y Y Y Y ? 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R - GJ 41-1CJU1 U Ui [J u, r, „ Z O Sr r7 r7 r J N r r Cd1E'0_005 �CD ''� ' w Isd cnO MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 14,2015 TO: Jim Regg �< (, Z,,1/S P.I.Supervisor I 1(l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-06 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-06 Petroleum Inspectort4 ) { ? 5 (cs)1r, SCAlSrc: Inspector Reviewed By: P.I.Supry Ter------ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-06 API Well Number 50-103-20110-00-00 Inspector Name: Chuck Scheve Permit Number: 189-082-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713094345 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 2K-06 . Type Inj G 'TVD 6006 Tubing 3825 - 3825 - 3825• 3825 , PTD 1890820 - ,Type Testi SPT'Test psi i 1502 - IA 350 1990 - 1960 - 1950 - 1 -T I Interval'4YRTST P/F P -- OA 230 - 240- 240 - 240 Notes: Tuesday,July 14,2015 Page 1 of 1 ! til el 59 WELL LOG TRANSMITTAL 6.1-3 To: Alaska Oil and Gas Conservation Comm. October 19, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2K-06 Run Date: 10/18/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-06 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20110-00 SCANNED MAR 1 3 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com 1 / Date: VZ- 12. 1k Signed: Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i ~q._ ~'~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: ~~~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 12, 2011 TO: Jim Regg Re�j *'1 ti SUBJECT: Mechanical Integrity Tests P.I. Supervisor (( ll CONOCOPHILLIPS ALASKA INC 2K -06 FROM: John Crisp KUPARUK RIV UNIT 2K -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry •` NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 06 API Well Number: 50 103 - 20110 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCrl10627160348 Permit Number: 189 - 082 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' 2K -06 ' Type Inj. N W - TVD 6006 IA 2100 2300 ' 2280 2280 - P.T.D 1890820 " TypeTest SPT Test psi 1501 QA 900 900 900 900 Interval 4YRTST p/F P - Tubing 2850 2850 2850 2850 Notes: CPAI stated the initial test did not meet their pass criteria. This is a retest for CPAI. .5 bbls pumped for test. oas Tuesday, July 12, 2011 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg w 7/Z-11 // P.I. Supervisor �(/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -06 FROM: John Crisp KUPARUK RIV UNIT 2K -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 06 API Well Number: 50 103 - 20110 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110628105803 Permit Number: 189 - 082 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 2K - -06 ' Type Inj. W ' TVD % 6006 1 IA ! 1030 2300 - 2100 2100 P.T.D1 1890820 TypeTest SPT Test psi L _ 1501 i O 815 900 900 900 Interval 4YRTST p/F P - Tubing i 2850 / 2850 2850 2850 Notes: 3.7 bbls pumped for test. CPAI called this test a fail. They were going to retest. I did not see the fail in the data taken. *1.. : 1,4;` i `; i 2 2 21 1 Tuesday, June 28, 2011 Page 1 of 1 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: AiJ ~ s ~- 2DD$ • Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4, and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, r ~~ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 1.88-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24!2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24!2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0/ . 1/ P.I. Supervisor 'I \&[1 &(h ò 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-06 KUPARUK RIV UNIT 2K-06 Src: Inspector ö CfJ~ \.~CJ( FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ß¡1-- Comm Well Name: KUPARUK RIV UNIT 2K-06 API Well Number: 50-103-20110-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS07060 1180856 Permit Number: 189-082-0 Inspection Date: 6/1/2007 -/ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -06 Type Inj. G TVD 6006 IA 920 2390 2320 I 2320 I P.T.D 1890820 TypeTest SPT Test psi 1501.5 OA 500 500 500 I 500 T Interval 4YRTST P/F P ./ Tubing 3750 3750 3750 T 3750 I Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ../ SCANNED JUN· 2 0 ZOO? Wednesday, June 06, 2007 Page 1 of 1 Sc~luIIIbepgeP ;) f} C'~~' '1> ,\t\",t:;~~, ., -::ÞW'J....~.... }\¡~,.....- '-' NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ItCJ -015d UI~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Date Log Description BL Color CD ,...,\.0 '':/ 1 E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-01 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1 D-1 0'1 N/A INJECTION PROFILE 06/27/06 1 2Z-1:t 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 . 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e MEMORANDUM TO: Randy Ruedrich )///?/0_~/'-- DATE: June 14, 2003 Commissioner THRU: Jim Regg "~?i ~':.i '~ I~i~''~, SUBJECT: Conoco/PhillipsMechanical Integrity Tests P.I. Supervisor ~ Kuparuk River Field 2K Pad FROM: John Crisp Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial 15 Min. 30 Min. Well] 2K-05 I Typelnj.I S I T.V.D. I 5945 I Tubingl~00 I~00 I~00 I~00 I,nterva, I 4 P.T.D.I 1881180ITypetestl P ITestpsil 3000 I Casingl 1380 I 2980 I 2940 I 2930 I P/F I P '-"'" Notes: dA 600 psi. pretest 680 psi. during test. 4.5 BBL. Pumped. WellI 2K-06 ITypelnj.I S I T.V.O. I~00~ I Tubingl 2340 12340 12340 I~0 Ilntervall' 4 P.T.D.I 1890820ITypetestl P ]TestpsiI 3000 I Casingl 1320 I 3040 I 2980 I 2975 I P/F Notes: dA 950 psi. during test. 2.6 BBL. Pumped. We,,I 2K.~0 I TYpe,~j.I ~ I T.V.P. I 59~7 I Tub~g13650 13~50 13SS0 13S50I,nterv ,l,,__4I P.T.D.I 1890590 ITypetestl P ITestpsil 3000 ICasingl 410 I 2960 I 29'10 I 2900 Notes: dA 200 psi. during test. 5.4 BBL. Pumped We,,I 2~-~ IType,~j.I S I T.V.D. I~ I Tubingl 24S0 124S0 12450 124S0 I,nterv~,l 4 P.T.D.I 18909S0 ITypetestl P ITestpsil 3000 I Casingl 1220I 2940I 2875I 2860I P/F I --P Notes: dA 850 psi. pretest '1020 during test. 4.5 BBL. Pumped. We,,I 2K-18 I Typelnj. I S I T.V.D. 15900 I Tubingl~0 I~0 I~,0 I~0 I,ntervall 4 P.T.D.I 1891080 ITypetestl P ITestpsil 3000 I Casingl 1320I 2980I 2925I 2900I P/F Notes: dA 300 psi. during test. 5 BBL. Pumped. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. cc: MIT report form 5/12/00 L.G. 2003-0614_M IT_KR U_2 K- 18_jc.xls 6/24/2003 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/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. I1881180 Type Test Test psiI 1500 I Casing I 13801 2980l 29401 29301 P/F Notes: Well 12K-06 P.T.D. It890820 Notes: Well [2K-10 P.T,D.I1890590 Notes: TypeTest Test psiI 1502 I Casing I 1320l 30101 29801 29751 P/F I Typelnj I Gp I T.V.D. 15987 I Tubing I 36501 36501 36501 365°llntervall ~ Type Test Test psiI 1500 I Casingl 4101 296OI 29101 29751 P/F Well 12K-13 P.T.D,'I t890950 Notes: Type Test Test psiI 1535 I Casing I 12201 29401 28751 286oI P/F Well 12K-t8 P.,T:Di.11891080 Notes: TypeTest Test psiI 1500 I Casing I 13201 29801 29201 29001 P/F P,T.D:.It891180 Type Test Test psiI 1536 I Casing I 4001 . 29001 28751 28501 P/F Notes: Well 12K-24 P,T, D.11891300 Notes: TypeTest Test psiI 1551 I Casing I 13001 28801 282oI 28001 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 2003-0614_MIT_KRU_2K-05 06 10 13 18 20 24.xls 6/2512003 ~(RU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) , ![ Name: MIT KRU 2T 06-14-03.xls ~_~ MIT KRU 2T 06-14-03.xls[ Type: EXCEL File (application/msexcel)] ~ --i[Encoding. base64 t MIT KRU 2K 06-14-03.xlst Type: EXCEL File (application/msexcel) 11 .IEncoding: base64 I of 1 6/25/2003 1:45 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory m Stratigraphic m Service X 4. Location of well at surface 171' FSL, 94' FEL, SEC 2, T10N, R8E, UM At top of productive interval 1574' FNL, 1424' FWL, SEC 2, T10N, R8E, UM At effective depth 1656' FNL, 1236' FWL, SEC 2, T10N, R8E, UM At total depth 1684' FNL, 1173'' FWL, SEC 2, T10N, R8E, UM 8 0 3 0 feet true vertical 6502 feet Present well condition summary Total Depth: measured 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-06 9. Permit number/approval number ~-82/94-31 9 10. APl number 50-1 03-2011 0 11. Field/Pool Kuparuk River Oil Field/Pool 12. Effective depth: measured 7 9 3 5 feet true vertical 6429 feet Plugs (measured) None Junk (measured) None feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3352' 9-5/8" Intermediate Production 798 1 ' 7" Liner Perforation depth: Cemented 1000 SX AS III & 400 SX CLASS G 385 SX Class G measured 7569' - 7587', 7630' - 7664' true vertical 61 31' - 6146', 6182' 6209', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7479' Packers and SSSV (type and measured depth) Measured depth 115' 3388' 8016' True vertical depth 115' 2750' 6327' RECEIVED DE(i: ,-. 7 0il & 6as Con~. C0mrdssion ~,nc~or: PKR: BROWN HB @ 7403'; SSSV: CAMCO TRDP-1A-SSA @ 1849' W/OTIS MCX IV 13, Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure INSTALL INJECTION VALVE 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 25O 1800 388O 250 1800 3880 16. Status of well classification as: Oil _ Gas Suspended ~ Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 /~,~', ~,1~ Title Wells Superintendent SUBMIT IN DUPLICATE ~ OIL AND GAS CONSERVATION COMMIS,'~ION 0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate X Repair well O t h e r 2. Name of Operator ARCO Alaska. In(;, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 171' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1574' FSL, 1424' FWL, Sec. 2, T10N, R8E, UM At effective depth 1659' FSL, 1221' FWL, Sec. 2, T10N, At total depth 1684' FSL, 1173' FWL~ Sec. 2, T10N, 12. Present well condition summary Total Depth: measured 8 true vertical 6 R8E, UM R8E~ UM 030' feet 492' feet 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-06 9. Permit numb_er/appro_val number 10. APl number 5o-103-20110 I11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 7940' feet true vertical 6423 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 3388' 9 5/8" 8016' 7" measured 7630'-7664" true vertical 6182'-6209' 4 SPF, Cemented 1000 Sx AS III & 400 SX Class G 385 Sx Class G 180° phasing Tubing (size, grade, and measured depth) 3.5" J-55, 9.3#, ABMOD, EUE @ 7418' Packers and SSSV (type and measured depth) Brown HB @ 7403', Camco TRDP-1A-SSA @ 1849' Measured depth 115' 3388' True vertical depth 115' 2750' 8016' 6327' RECEIVED [',3AR - 4 1392 Alaska Oil & Gas Cons. Cor~,rfti,~siot~ Anchorage 13. Stimulation or cement squeeze summary Perforate C Sand from 7569' to 7587' @ 6 SPF @ 0°deg phasing prior to conversion to water injection. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 390 631 -0- 1340 284 Subsequent to operation 390 631 - 0 - 875 257 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Form 10-404 Rev 09/12/90 Date ,SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY 2. TIME 07/5' oCI O f .~ oq~ / 105~ //2¢ IlqZ /20'7 1227 15:03 /3:5=_ Iq~3 !'~17 - DESCRIPTION OF WORK I CONTRACTOR I KEY PERSON OPERATION AT REPORT TIME [] COMPLETE J--J INCOMPLETE FIELD EST: AFC/CC ACCUMULATED COST $ LOG ENTRY flL//T//3/~ 5 ' '7-6'~ - ~'~/~-/~ //JIL,/&;")~ - 1~ ~,~'. ~7~'K' - ZEO pd~ PAGE 1 OF , . ~/~, ~ L 5 -Sk~~, ~ c l/ ! Oo/¢ ~/ z-5' R/F, /,1l-/ ¢//2.q5' ~¢.//¢~ £.¢0~ -~o ~c/¢ ouT' bTWPPCR *, II [~CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK AR3B-7031 Wind Vel. knots 298-3486 REMARKS CONTINUED: /~ 3o SERVICE OOM PANY SCA # DAILY ACCU M. TOTAL ~I£5 VOII~ 2tt.3o' o~ , DEC Z Y ~994 TOTAL FIELD ESTIMATE ~ ~ ~0 ARCO Alaska, Inc.~ Subsidiary of Atlantic Richfield ComDany TRACTOR REMARKS · WELL SERVICE REPORT ~,~ Cos'~': ~ ¢,5'o . °° iD30- Iloo- /~ ¢,s'-- /,-2 Io, - /09/5' - Alaska Oil & Gas Coi,s. ~,oinm~so,u~ Anchorace {""J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK wo.,~r I,o~,. lc~,,,~.~o~ ~v,.,~,,,,, Iw,.~v.,. Report t 'F *FI miles A~ OIL/~ID ~ OONSI::RVATION OOMMIf:~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development Exploratory Stratigraphic Service 4. Location of well at surface 171' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1574' FSL, 1424' FWL, Sec. 2, T10N, R8E, UM At effective depth 1659' FSL, 1221' FWL, Sec. 2, T10N, R8E, UM At total depth 1684' FSL, 1173' FWL, Sec. 2, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8030' 6492' feet Plugs (measured) feet None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-06 ~ 9. Permit number/approval_number 82. 10. APl number 5o-103-20110 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 94 0' true vertical 6423 feet Junk (measured) feet None Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3388' 9 5/8" Intermediate Production 801 6' 7" Liner Perforation depth: measured 7630'-7664" true vertical 6182'-6209' 4 SPF, Cemented 1000 Sx AS III & 400 SX Class G 385 Sx Class G 180° phasing Tubing (size, grade, and measured depth) 3.5" J-55, 9.3#, ABMOD, EUE @ 7418' Packers and SSSV (type and measured depth) Baker HB @ 7418', Camco TRDP-1A-SSA @ 1849' Measured depth 115' 3388' 8016' True vertical depth 115' 2750' 6327' RECEIVED J U N 11 4 t991 13. Stimulation or cement squeeze summary Intervals treated (measured) Alaska Oil & 6as Cons. Commissiot~ Anchorage Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 450 588 -0- 1000 295 Subsequent to operation 0 -0- 2500 1100 2100 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ~~ (~ ¢ (~~ Title ¢~"~t'~~ Form 10-404 Rev 09/12/90 Date ~-¢ "-/2.. -'-~ ~. SUBMIT IN DUPLICATE ARCO Alaska, Inc~ Sui3sidiary of Atlantic Richfield Cornish) WELL C~NTRACTOR ~IEMARKS IPBDT OTIS WELL SERVICE REPORT FIELD- DISTRICT- STATE IOPERATION AT REPOhT TII~IE DAyS 1 DATE / 3.3-?/ R/Y J =" 0~-I ! I ~WI',,- ~ 5'q.; _ 3;zo / '~03o RECEIVED [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK [ I 'I weather I Temp. Chill Fl~or Vl~lldllty STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Change approved program_ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ ARCO Alaska. Inc. Exploratory _ RKB 154' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 171' FSL, 94' FEL, Sec. 2, T10N, R8E, UM 2K-06 At top of productive interval 9. Permit number 1574' FSL, 1424' FWL, Sec. 2, T10N, R8E, UM ~ ~:)/ O ~j~-~ At effective depth 10. APl number 1659' FSL, 1221' FWL, Sec. 2, T10N, R8E, UM so-103-20110 At total depth 11. Field/Pool Kuparuk River Field 1684' FSL, 1173' FWL, Sec. 2, T10N, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8030' feet Plugs (measured) true vertical 6 4 9 2' feet None Effective depth' measured 7940' feet Junk (measured) true vertical 6 4 2 3' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 5' 1 6" 1 1 5' 1 1 5' Surface 3388' 9 5/8" 1000 Sx AS III & 3388' 2750' Intermediate 400 Sx Class G Production 8 01 6' 7" 385 Sx Class G 8 01 6' 6 3 2 7' Liner Perforation depth: measured 7630'-7664' 4 SPF, 180° phasing RFcEIV true vertical 61 82'-6209' r~,'~'~l !j Tubing (size, grade, and measured depth) ~'~..,, v 3 1/2" J-55, 9.3#, ABMOD, EUE @ 7418' 4~;~;~.~ji.& Gas Col~s~ Packers and SSSV (type and measured depth) , ; Baker HB ~ 7418'~ Camco TRDP-1A-SSA @ 1849' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch_ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: November 20. 1990 Oil ~ Gas __ Suspended _ 16. If proposal was verbally approved Name or~approver Date approved Service Water Injector 17. Iher~y) certi~ l~h'~t t~ is true and correct to the best of my knowledge. ~ Si~lned ~ ~'~ O, Title ~1~. ~~'~ Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval Plug integrity __ BOP Test Location clearance I ~,/) -, Mechanical Integrity Test~/'~. -- Subsequent form r--equire 10- ~o ~) Approve~ R~urnep Approved by order oft 0~\~\~k-'' S Commissioner Date Form 10-403 Rev 09/12/90 ~.~3~ SUBIV1T IN TRIPLICATE .,/ELL 2K-06 PRODUCER APl # 501032011000 SURFACE LOCATION: 171' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1586' FSL, 1391' FWL, SEC 2, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3388' TREE: FMC GEN IV 5000 PSI BAKER PBR: 3.000" ID @ 7405' BROWN HB PKR: 2.892" ID @ 7418' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 7457' SHEAR OUT: 3.000" ID @ 7491' L C A5 A4 A3 7": 26# J-55 @ 8016' PBTD: 7935' SPUD' 8/10/89 COMPLETION: 10/29/89 SSSV. CAMCO TRDP-1A-SSA ID 2.812" @ 1849' ~. GLMI' 2604' / 1.0' TMPD/DV GLM2: 5051' / 1.0" TMPD/DV GLM3: 6674' / 1.0" TMPD/DV GLM4: 7361' / 1.5" MMG-2 /DV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 7492' HOLE ANGLE ACROSS KUPARUK = 35 DEGREES MAX HOLE ANGLE = 46 DEGREES @ 3500' VOLUME TO TOP PERF = 70 BBLS 7630' 4 SPF ~. 90° PHASING ORIENTED 112° CCW 7664' FILL TAGGED AT 7884' (5/14/90) REVISION: 10/25/90 Messrs. Kralick and Sl,~ October 29, 1990 Page 2 Drill Site 2K Initial Water Injection Conversions CC: Downhole 899381 Surface 899399 10/29/90 1) 2) 3) 4) 6) 7) 8) 10) 11) This wireline work should be completed approximately one week prior to the completion of the water injection piping work at DS-2H. The spool piece work inside the manifold building should be completed at the same time. MIRU Slickline and diesel pump truck. RIH and set SV in "XN" or "D" nipple. Wells 2K-06, 18 and 20 are currently on gas lift. Well 2K-10 has not been gas lifted. RIH and pull the bottom DV and replace with a CV in Well 2K-10. Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2 K- 0 6 195 bbls 7361 feet 2 K- 1 0 166 bbls 6270 feet 2 K- 1 8 186 bbls 7035 feet 2 K-2 0 274 bbls 9056 feet 2-7/8" TBG RIH and pull all GLV's, OV's and CV's and replace with DV's. Ensure annulus is filled with diesel. Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure testing to prevent tubing buckling, RIH and pull SV. RDMO Slickline. Prior to initiating water injection, a diesel/xylene spear should proceed to clean up the perforations. Pump 50 bbls of diesel with 10% xylene at 2 BPM. Initiate water injection at approximately 500 BWPD and gradually ramp up the injection rate until the WHP reaches 1500 psi. Keep the injection rate constant until Operations Engineering can perform a step rate test. Once the step rate test is complete, open wells to maximum injection pressure. ADDENDUM WELL 2K-6 4/24/90 Frac Kuparuk "A" sand perfs 7630'-7664' @ 4 spf 90 deg phase, oriented 112 deg ccw in eight stages as follows. Stage 1: Pmp 100 bbls YF240 prepad @ 20 bpm 5920-4000 psi 45 bbls YF240 prepad @ 15 bpm 3370-3510 psi 30 bbls YF240 prepad @ 10 bpm 2940-3360 psi Stage 2:70 bbls slick diesel flush @ 20 bbm 4160-3945 psi Stage Stage Stage Stage Stage Stage screenout to 8240 psi Fluid to recover: Sand in zone: Sand in csg: Avg pressure: 3:250 bbls YF240 pad @ 20 bpm 4130-4150 psi 4:23 bbls YF240 w/2 ppg 16/20 Carbolite @ 20 bpm 4150-4100 psi 5:26 bbls YF240 w/4 ppg 16/20 Carbolite @ 20 bpm 4100-3960 psi 6:24 bbls YF240 w/6 ppg 16/20 Carbolite @ 20 bpm 3960-3830 psi 7:30 bbls YF240 w/8 ppg 16/20 Carbolite @ 20 bpm 3830-4120 psi 8:+-50 bbls YF240 w/l-18 ppg 12/18 Carbolite @ 20-16 bpm 4120-8240 psi 648 bbls 16,465 lbs 16,341 lbs 400O psi ~)~il~~p~rvisor -- Date STATE OFALASKA . ~ ~ ~ r' ~i~!1 ,~'~ , ALASKA ~J~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL Z' GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number (~f ~.~ ARCO A1 aska, I nc. GO-G2/5-8C~_- " 3. Addr~s 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 103-20110 4. Location of well at surface 171' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At Top Producing Interval 1574' FSL, 1/+24' FWL, Sec. 2, T10N, R8E, UM At Total Depth 1684' FSL, 1173' FWL, Sec. 2, T10N, R8E, UM 5. Elevation in feet (indicate KB, DF, etc.) 154' RKB 6. Lease Designation and Serial No. ADL:25589 ALK:2674 9. Unit or Lease Name Kuparuk River Unit. 10. Well Number 2K-6 11. Field and Pool Kuparuk River/ Kuparuk 0il Pool 12. Date SPudded 08/10/89 17. Total Depth (MD+TVD) 8,030 ' MD&6502 ' TVD 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 8/17/89 1~;7/,.~¢-~'/~ - i O/' ;' 9/' $ 9 ---feet MSLI 1 18. Plug Back Depth (M~D)I''' '----~19. D~tionalSurvey t 20. Depth where SSSV set I 21.Thickn,sofPermafros, 7935'MD&6429'TVD ~ YES ~ NO ~ ~ 1849' feet MD I --- 22. Type Electric or Other Logs Run DI L/GR/SP/SFL, FDC/CNL/CAL, CET, Gyro 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP HOLE SIZE CEMENTING RECORD AMOUNT PULLED ---- 16" 9-5/8" 7" 36# J -55 .I SETTING DEPTH MD BOTTOM Surf 115' Surf 3388' 5;urf . 8OIR' · 1 2-1/4" 8-½" 1000sx AS III & 400sx ~85~x £1a~ G 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 7,630'-7,664' MD 4" Super 0mnikone ~ 4 spf 6,182'-6,209' TVD lottom and 25. TUBING RECORD 27. SIZE DEPTH SET (MD) 3~2" ,9.3#,J-55 7,491 ' PACKER SET (MD) 7,Z~lB' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) PRODUCTION TEST tAMOUNT& KIND OF MATERIAL USED Date First Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. IMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR )OIL-BBL TEST PERIOD I~ CALCULATED i~ j OIL-BBL 24-HOUR RATE -r GAS-MCF GAS-MCF WATER-BBL WATER-BBL ICHOKE SIZE ]GAS-OILRATIO OIL GRAVITY-APl (cor~ CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev. 7-1-80 W C 1 / 2 8 CONTINUED ON REVERSE SIDE Submit in duplicate % , 29. 3O. NAME Kuparuk C Kupa ruk A GEoLoGIc MARKERS TOP.~ MEAS. DEPTH TRUE VERT. DEPTH 7,568' 7,593' 6,131 ' 6,151 ' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Gyro 32. I hereby certify that the 'foregoing is true and correct to the best of my knowledge Signed_ / ...... 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- lng 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 ARCO Oil and Gas Company Well History - Initial Report- Dait¥ Instructions: Prepare and submit the "Initial Rel)ort" on the first Wednesday after aweli is spudded or v, orkover operahons are ~la. rtcd. Daily work prior ,',o spudding should be summarized on the form giving inclusive dates only. District ARCO AT,AS~Z~ INC, Field State County. parish or borough NORTH SLOPE Lease or Unit ADL: 25588 ALK: 2674 Title COMPLETIONS 2K-6 IWell no. KUPARUK RIVER UNIT Auth. or W.O. no. AK3617 Operator ARco IARCO W.I. 55,8533 W.O. Prior status if a Spudded or W.O. begun IDate IH°ur SPUD I 08/10/89 I 18:30 Date and depth as of 8:00 a.m. 08/22/89 (12) TD: 8016 PB4 7935 SUPV: GB 08/23/89 ( 13) TD: 8016 PB: 7935 SUPV:GB Complete record for each day repo~ed NORDIC PERFORATING A SANDS 7"@ 8016' MW: 0.0 NaCl MOVE RIG FROM 2K-6, ACCEPT RIG AT 1930 10-27-89, ND DRYHOLE TREE, NU DOPE, TEST DOPE TO 3000 PSI, RU WA E-LINE, PERFORATE 7644-7664 @ 4SPF, DAILY:S12,417 CUM:$895,376 ETD:S894,376 EFC:$1,311,000 SETTING BPV 7"@ 8016' MW: 0.0 NaC1 PERF 7630-7644, RD WA E-LINE, RUN 3-1/2" COMPLETION ASSEMBLY, TEST CONTROL LINE, NOT HOLDING, DROP BALL, SET PKR W/2500 PSI, SHEAR PBR, CIRC. WELL TO 10.6 PPG BRINE, POH TO SSSV, CHANGE CONTROL LINE, TIH, TEST CONTROL LINE, LAND TBG, RILDS, TEST TBG TO 2500 PSI, TEST ANNULUS TO 2500 PSI, CLOSE SSSV, BLEED TBG PRESS, SSSV HOLDING, PRESS TBG AND SHEAR BALL, BLEED PRESS, CLOSE SSSV, SET BPV DAILY:S170,694 CUM:$1,066,070 ETD:S1,066,070 EFC:$1,310,000 The above is~t For form prel:)aratlon t6~dJdletrlbutlon, ~ see Procedures Manu~l~ectlon 10, Drilling, Pages 86 and 87. IDate / / AR3S-459-1-D INumber all daily well history forms consecutively a~ thay are prel3ared for each well. iPage no. ARCO '~.,,, and Gas Company Daily Well History-Final Report Instructions: Pre~are and submit the "Final Report" on the first Wednesday after allowable has been assigned or v. ell is Plugged. Abandoned. or Sold. "Final Report" s'hould be submftied also when operations are suspended for an indefimte or appreciable length of tin-lo. 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 State ARCO ALASKA INC. AK Field KUPARUK RIVER UNIT Auth. or W.O. no. AK3617 Operator ARCO County or Parish NORTH SLOPE JLease or Unit ADL: 25589 AKL: 2674 ITitle COMPLETIONS 2K-6 I Well no. Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/24/89 (14) TD: 8016 PB: 7935 SUPV:GB IA.R.Co. W.I. Date 55'8533 08/10/89 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our I Prior status If a W.O. I 18:30 Complete record for each day reported NORDIC 1 RIG RELEASED 7"@ 8016' MW: 0.0 NaCl ND BOPE, NU TREE, TEST TREE AND PACKOFF TO 5000 PSI, DISPLACE ANNULUS WITH 5 BBLS DIESEL,BULLHEAD 2 BBL DIESEL DOWN TBG, CIRC. VALVE NOT HOLDING, RELEASE RIG AT 1000 10/29/89 DAILY:S8,374 CUM:$1,074,444 ETD:S1,074,444 EFC:$1,310,000 Old TD Released rig INew TO IPe Depth Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production O'il'on lest Gas per day I:;~mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ,.. Signatur~~ ~ ~'-/~ I'~ Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvldofl of Atl~mtlcRIchfleldCompany 0 I=! I I__i__ I N Cl ORIGINAl. October 9, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90097 Well: 2K-6 Field: Kuparuk Survey Date: 9/17/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures 8537 Corbin Drive (99507) · PO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522.3432 A Baroid Company ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 9/22 /89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 -154 100 100.00 -54 200 200.00 46 300 300.00 146 400 400.00 246 500 499.99 345 600 599.99 445 700 699.99 545 750 749.98 595 800 799.95 645 850 849.79 695 900 899.44 745 950 948.95 794 1000 998.34 844 1050 1047.62 893 1100 1096.77 942 1150 1145.70 991 1200 1194.38 1040 1250 1242.75 1088 1300 1290.74 1136 · 00 0 0 · 00 0 13 · 00 0 2 · 00 0 14 · 00 0 28 PAGE .99 .99 .99 .98 .95 0 22 0 27 0 41 0 55 2 51 DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .79 6 1 .44 7 30 .95 8 34 .34 9 19 .62 10 6 N .00 E .00 .00 .00 N 84.50 W .23 .02N .20W N 82.90 W .19 .04N .43W N 79.20 W .20 .09N .67W N 73.50 W .24 .24N 1.28W .0£ .lC~ .42 .66 1.2.~ .77 11 0 .70 12 38 .38 13 45 .75 15 32 .74 17 2 1350 1338.42 1184.42 17 58 1400 1385.81 1231.81 19 12 1450 1432.65 1278.65 21 39 1500 1478.62 1324.62 24 37 1550 1523.65 1369.65 26 53 S 52.70 W .40 .16N 1.95W S 49.40 W .08 .30S 2.52W S 58.10 W .25 .88S 3.33W S 85.00 W .89 1.07S 3.99W N 76.10 W 4.01 .81S 5.61W 1.8~ 2.2-: 2.8] 3.3( 4.9( 1600 1567.72 1413 1650 1610.55 1456 1700 1651.86 1497 1750 1692.14 1538 1800 1732.16 1578 N 64.40 W 6.54 .62N 9.18W N 61.60 W 3.05 3.31N 14.42W N 60.10 W 2.16 6.72N 20.53W N 59.50 W 1.53 10.64N 27.25W N 59.10 W 1.55 14.94N 34.50W 8.8: 14.6( 21.51 29.2! 37.5~ 1850 1772.17 1618 1900 1811.82 1657 2000 1888.52 1734 2100 1962.88 1808 2200 2036.56 1882 N 59.40 W 1.80 19.62N 42.37W N 59.70 W 3.28 24.81N 51.20W N 59.90 W 2.22 30.55N 61.06W N 58.30 W 3.67 37.05N 71.90W N 57.30 W 3.07 44.53N 83.77W 46.5' 56.6, 67.9' 80.3 94.0 N 56.90 W 1.86 52.70N 96.40W N 56.00 W 2.55 61.52N 109.68W N 55.70 W 4.90 71.32N 124.12W N 56.10 W 5.93 82.33N 140.39W N 56.20 W 4.54 94.43N 158.43W 108.7 124.3 141.3 160.4 181.5 .72 .55 .86 .14 .16 29 28 32 37 35 55 36 43 36 54 N 57.00 W 5.23 107.42N 178.15W N 58.60 W 6.51 121.15N 199.98W N 60.00 W 6.79 135.51N 224.20W N 60.20 W 1.62 150.27N 249.88W N 60.00 W .43 165.21N 275.85W 204.5 229.8 257.5~ 286.8: 316.4C .17 .82 .52 .88 .56 36 47 38 15 41 33 42 20 42 43 N 59.80 W .34 180.25N 301.80W N 61.30 W 3.46 195.22N 328.32W N 62.90 W 3.46 225.20N 385.02W N 65.20 W 1.73 254.44N 445.12W N 66.80 W 1.15 281.94N 506.88W 345.9~ 376.0' 439.7 506.2 573.7 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DGMN 2300 2109.50 1955.50 43 36 2400 2182.86 2028.86 41 59 2500 2256.79 2102.79 42 39 2600 2329.89 2175.89 43 24 2700 2402.00 2248.00 44 18 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N 66.80 W .88 308.89N 569.77W N 67.40 W 1.67 335.33N 632.35W N 67.20 W .68 361.31N 694.46W N 67.30 W .74 387.70N 757.39W N 67.00 W .93 414.60N 821.23W VERT. SECT. 642.11 709.99 777.28 845.47 914.70 2800 2472.92 2318.92 2900 2545.85 2391.85 3000 2621.05 2467.05 3100 2695.32 2541.32 3200 2768.27 2614.27 45 20 40 58 41 30 42 34 43 43 N 66.50 W 1.09 442.43N 886.00W N 64.80 W 4.51 470.59N 948.32W N 64.60 W .54 498.76N 1007.91W N 64.30 W 1.09 527.64N 1068.32W N 63.80 W 1.21 557.57N 1129.81W 985.12 1053.37 1119.07 1185.78 1253.88 3300 2839.94 2685.94 3400 2910.44 2756.44 3500 2980.00 2826.00 3600 3049.27 2895.27 3700 3118.55 2964.55 44 42 45 37 46 13 46 4 46 12 N 63.50 W .99 588.52N 1192.30W N 63.60 W .93 620.11N 1255.79W N 64.50 W .88 651.54N 1320.39W N 65.00 W .39 682.31N 1385.62W N 65.20 W .19 712.67N 1451.03W 1323.27 1393.82 1465.36 1537.25 1609.16 3800 3187.76 3033.76 46 12 3900 3257.97 3103.97 44 35 4000 3329.84 3175.84 43 30 4100 3404.02 3250.02 40 43 4200 3479.83 3325.83 40 40 N 65.30 W .07 742.89N 1516.58W N 65.80 W 1.65 772.36N 1581.38W N 66.10 W 1.10 800.69N 1644.87W N 67.00 W 2.85 827.39N 1706.38W N 66.90 W .07 852.92N 1766.38W 1681.16 1752.1~ 1821.5~ 1888.55 1953.7~ 4300 3555.78 3401.78 40 28 4400 3631.83 3477.83 40 30 4500 3707.88 3553.88 40 28 4600 3784.03 3630.03 40 19 4700 3860.32 3706.32 40 14 N 67.20 W .28 878.29N 1826.29W N 67.00 W .14 903.56N 1886.10W N 67.00 W .04 928.93N 1945.87W N 67.10 W .15 954.20N 2005.56W N 69.70 W 1.68 978.00N 2065.66W 2018.7~ 2083.6] 2148.4~ 2213.2~ 2277.8~ 4800 3936.87 3782.87 4900 4013.93 3859.93 5000 4091.36 3937.36 5100 4168.90 4014.90 5200 4246.57 4092.57 39 52 39 19 39 11 39 8 38 56 N 73.90 W 2.73 998.09N 2126.76W N 75.20 W .99 1015.08N 2188.19W N 75.50 W .23 1031.08N 2249.41W N 75.60 W .08 1046.84N 2310.56W N 75.60 W .20 1062.50N 2371.57W 2342.1~ 2405.61 2468.54 2531.32 2593.93 5300 4324.23 4170.23 5400 4401.78 4247.78 5500 4479.34 4325.34 5600 4556.99 4402.99 5700 4634.91 4480.91 39 9 39 8 39 8 38 58 38 39 N 75.90 W .29 1078.01N 2432.63W N 75.90 W .02 1093.39N 2493.87W N 75.90 W .00 1108.77N 2555.09W N 75.90 W .17 1124.12N 2616.19W N 75.40 W .44 1139.65N 2676.92W 2656.54 2719.2{ 2781.9' 2844.5' 2906.8, SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5800 4712.97 4558.97 38 42 N 75.50 W .07 5900 4791.09 4637.09 38 33 N 75.40 W .15 6000 4869.38 4715.38 38 23 N 75.20 W .21 6100 4947.74 4793.74 38 25 N 75.30 W .07 6200 5025.93 4871.93 38 43 N 75.40 W .31 1155.35N 2737.41W 2969.00 1171.04N 2797.84W 3031.08 1186.82N 2858.02W 3092.96 1202.64N 2918.09W 3154.75 1218.41N 2978.41W 3216.76 6300 5104.04 4950.04 38 33 N 76.00 W .41 6400 5182.62 5028.62 37 50 N 76.60 W .81 6500 5261.88 5107.88 37 18 N 76.50 W .53 6600 5341.38 5187.38 37 22 N 76.50 W .06 6700 5420.68 5266.68 37 41 N 76.50 W .32 1233.83N 3038.92W 3278.81 1248.48N 3099.00W 3340.20 1262.66N 3158.31W 3400.69 1276.82N 3217.28W 3460.87 1291.04N 3276.52W 3521.32 6800 5499.97 5345.97 37 24 N 76.30 W .31 6900 5579.61 5425.61 37 0 N 77.10 W .63 7000 5660.08 5506.08 35 49 N 77.80 W 1.24 7100 5741.58 5587.58 35 0 N 78.20 W .86 7200 5823.90 5669.90 34 10 N 78.40 W .84 1305.37N 3335.75W 3581.8¢ 1319.29N 3394.60W 3641.77 1332.19N 3452.54W 3700.52 1344.24N 3509.22W 3757.8~ 1355.75N 3564.80W 3813.8~ 7250 5865.29 5711.29 34 4 N 78.40 W .18 7300 5906.88 5752.88 33 22 N 78.50 W 1.42 7400 5990.95 5836.95 32 11 N 77.60 W 1.28 7500 6074.71 5920.71 34 2 N 73.80 W 2.78 7600 6157.00 6003.00 35 13 N 69.20 W 2.87 1361.39N 3592.28W 3841.55 1366.95N 3619.47W 3869.0( 1378.15N 3672.44W 3922.52 1391.68N 3725.34W 3976.7~ 1409.74N 3779.19W 4033.5~ 7700 6238.78 6084.78 35 2 N 68.70 W .34 7800 6320.60 6166.60 35 9 N 67.90 W .48 7900 6401.09 6247.09 37 39 N 64.50 W 3.20 7950 6440.28 6286.28 39 5 N 62.10 W 4.14 8000 6479.09 6325.09 39 '5 N 62.10 W .04 1430.41N 3832.90W 4091.0~ 1451.67N 3886.33W 4148.5~ 1475.66N 3940.59W 4207.81 1489.61N 3968.30W 4238.6' 1504.36N 3996.16W 4269.9, 8030 6502.38 6348.38 39 5 N 62.10 W .07 1513.21N 4012.88W 4288.7' THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4288.71 FEET AT NORTH 69 DEG. 20 MIN. WEST AT MD = 8030 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 290.66 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 9-17-89 2K-6 KUPARUK JOB NUMBER: AK-BO-90097 ALASKA KELLY BUSHING ELEV. = 154.00 FT. COMPUTATION DATE: 9/22/89 OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 1000 998.34 844.34 2000 1888.52 1734.52 3000 2621.05 2467.05 4000 3329.84 3175.84 5000 4091.36 3937.36 6000 4869.38 4715.38 7000 5660.08 5506.08 8000 6479.09 6325.09 8030 6502.38 6348.38 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1031.08 N 2249.41 W 908.64 238.48 1186.82 N 2858.02 W 1130.62 221.98 1332.19 N 3452.54 W 1339.92 209.30 1504.36 N 3996.16 W 1520.91 180.99 1513.21 N 4012.88 W 1527.62 6.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. .00 .00 .00 10.64 N 27.25 W 1.66 1.66 225.20 N 385.02 W 111.48 109.82 498.76 N 1007.91 W 378.95 267.47 800.69 N 1644.87 W 670.16 291.20 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 54 54.00 -100.00 154 154.00 .00 254 254.00 100.00 354 354.00 200.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 .00 .00 N .03 W .04 N .39 W .05 N .50 W .14 N .92 W MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 · 00 .00 · 00 .00 · 00 .00 454 454.00 300. 554 554.00 400. 654 654.00 500. 754 754.00 600. 854 854.00 700. O0 O0 O0 O0 O0 .33 N 1.70 W .06 S 2.24 W .59 S 2.87 W .08 $ 4.06 W .83 N 9.60 W · 01 .00 · 01 .00 · 01 .00 · 02 .01 · 23 .21 955 954.00 800. 1056 1054.00 900. 1158 1154.00 1000. 1261 1254.00 1100. 1366 1354.00 1200. O0 O0 O0 O0 O0 7.10 N 21.19 W 15.53 N 35.48 W 25.75 N 52.80 W 38.70 N 74.57 W 55.49 N 100.66 W 1.11 .88 2.48 1.37 4.50 2.02 7.68 3.18 12.39 4.71 1473 1454.00 1300. 1584. 1554.00 1400. 1702 1654.00 1500. 1827 1754.00 1600. 1954 1854.00 1700. 00 00 00 00 00 76.27 N 131.42 W 103.27 N 171.80 W 136.29 N 225.55 W 173.42 N 290.04 W 211.47 N 358.60 W 19 3O 48 73 100 · 10 6.71 · 32 11.22 .65 18.33 · 30 24.66 · 41 27.11 2087 1954.00 1800. 2223 2054.00 1900. 2361 2154.00 2000. 2496 2254.00 2100. 2633 2354.00 2200. O0 O0 O0 O0 O0 251.05 N 437.77 W 288.28'N 521.69 W 325.34 N 608.36 W 360.31 N 692.09 W 396.50 N 778.42 W 133 169 207 242 279 .98 33.56 .74 35.76 .17 37.43 .20 35.03 .18 36.98 2773 2454.00 2300. 2910 2554.00 2400. 3044 2654.00 2500. 3180 2754.00 2600. 3319 2854.00 2700. 00 00 00 00 00 434.80 N 868.44 W 473.60 N 954.72 W 511.30 N 1034.29 W 551.54 N 1117.56 W 594.73 N 1204.75 W 319 356 390 426 465 .08 39.90 .79 37.71 .03 33.24 .25 36.22 .78 39.53 3462 2954.00 2800. 3606 3054.00 2900. 3751 3154.00 3000. 3894 3254.00 3100. 4033 3354.00 3200. O0 O0 O0 O0 O0 639.86 N 1295.90 W 684.38 N 1390.07 W 728.17 N 1484.60 W 770.75 N 1577.81 W 809.77 N 1665.50 W 508.42 552.82 597.22 640.42 679.03 42.64 44.40 44.40 43.20 38.62 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4165 3454.00 3300.00 844.21 N 1745.96 W 711.94 32.90 4297 3554.00 3400.00 877.70 N 1824.88 W 743.66 31.72 4429 3654.00 3500.00 910.96 N 1903.54 W 775.16 31.50 4560 3754.00 3600.00 944.28 N 1982.07 W 806.60 31.44 4691 3854.00 3700.00 976.14 N 2060.65 W 837.73 31.12 4822 3954.00 3800.00 1002.06 N 2140.50 W 868.31 30.59 4951 4054.00 3900.00 1023.44 N 2219.91 W 897.79 29.47 5080 4154.00 4000.00 1043.82 N 2298.82 W 926.79 29.01 5209 4254.00 4100.00 1064.00 N 377.39 W 955.56 28.76 5338 4354.00 4200.00 1083.92 N .456.15 W 984.40 28.84 5467 4454.00 4300.00 1103.74 N 2535.09 W 1013.33 28.94 5596 4554.00 4400.00 1123.53 N 2613.85 W 1042.15 28.82 5724 4654.00 4500.00 1143.50 N 2691.70 W 1070.45 28.30 5852 4754.00 4600.00 1163.58 N 2769.21 W 1098.56 28.11 5980 4854.00 4700.00 1183.71 N 2846.24 W 1126.38 27.82 6107 4954.00 4800.00 1203.90 N 2922.89 W 1153.98 27.61 6235 5054.00 4900.00 1224.08 N 3000.19 W 1181.98 27.99 6363 5154.00 5000.00 1243.33 N 3077.37 W 1209.76 27.78 6490 5254.00 5100.00 1261.26 N 3152.47 W 1236.10 26.34 6615 5354.00 5200.00 1279.07 N 3226.66 W 1261.88 25.78 6742 5454.00 5300.00 1297.05 N 3301.54 W 1288.10 26.22 6867 5554.00 5400.00 1314.98 N 3375.78 W 1313.93 25.83 6992 5654.00 5500.00 1331.26 N 3448.24 W 1338.50 24.57 7115 5754.00 5600.00 1346.02 N 3517.73 W 1361.17 22.67 7236 5854.00 5700.00 1359.85 N 3584.79 W 1382.36 21.20 7356 5954.00 5800.00 1373.16 N 3649.67 W 1402.31 19.95 7475 6054.00 5900.00 1387.94 N 3712.01 W 1421.08 18.77 7596 6154.00 6000.00 1409.00 N 3777.21 W 1442.33 21.25 7718 6254.00 6100.00 1434.28 N 3842.84 W 1464.58 22.26 7841 6354.00 6200.00 1460.97 N 3908.42 W 1487.11 22.53 7967 6454.00 6300.00 1494.82 N 3978.15 W 1513.67 26.56 8030 6502.38 6348.38 1513.21 N 4012.88 W 1527.62 13.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-6 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-17-89 JOB NUMBER: AK-BO-90097 K~LLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3388 2902.05 2748.05 616.29 N 7568 6130.80 5976.80 1403.43 N 7586 6145.56 5991.56 1406.92 N 7593 6151.28 5997.28 1408.32 N 7744 6274.81 6120.81 1439.58 N 1248.10 W 9 5/8" CSG 3761.94 W TOP KUPARUK C 3771.65 W BASE KUPARUK C 3775.42 W TOP KUPARUK A 3856.44 W BASE KUPARUK A 7935 6428.64 6274.64 1485.18 N 7950 6440.28 6286.28 1489.61 N 8016 6491.51 6337.51 1509.08 N 8030 6502.38 6348.38 1513.21 N 3959.94 W PBTD 3968.30 W SURVEY DEPTH 4005.08 W 7" CSG 4012.88 W TD ARCO ALASKA, INC. 2K-6 STRATIGRAPHIC SUMMARY -MEASURED ....... MARKER ....... DEPTH ........ TVD ........ BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 171FSL 94FEL SEC 02 T10N R08E 9 5/8" CSG 3388 2902.05 2748.05 616.29N 1248.10W TOP KUPARUK C 7568 6130.80 5976.80 1403.43N 3761.94W BASE KUPARUK C' 7586 6145.56 5991.56 1406.92N 3771.65W TOP KUPARUK A 7593 6151.28 5997.28 1408.32N 3775.42W BASE KUPARUK A 7744 6274.81 6120.81 1439.58N 3856.44W PBTD 7935 6428.64 6274.64 1485.18N 3959.94W 7" CSG 8016 6491.51 6337.51 1509.08N 4005.08W TD 8030 6502.38 6348.38 1513.21N 4012.88W emmmmmmmmmmmmmmmmmmmmmmemmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmm-- COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE DATE OF SURVEY: 9-17-89 COMPUTATION DATE: 9/22/89 JOB NUMBER: AK-BO-90097 KELLY BUSHING ELEV. = 154.00 FT. 2K-6 KUPARUK ALASKA 9-17-89 SPERm,Y-SUN DRLG. SVCS. HORIZONTAL PROJECTTON ~0:30 START TVD = 0 FINISH TVD = 6502.38 SCALE IS 1000 FEET/IN .eooo '- eobo ~obo 4oho ,oho =oho 1oho ~ DEPARTURE 'SO00 ,4000 ,0000 2000 lO00 2K--6 KUPARUK ALASKA 9-17--89 1000 20o0 r-'l 80o0 i-- 4o00 I..LJ n,,' sooo i--- 0000 - 7000 - SPERm,Y-SUN DRLG. SVCS. VERTICAL PROJECTION START TVD = 0 FINISH TVD = 6502.38 SCALE IS 1000 FEET/IN 8030 4.288.71 ~obo =oho soho .bo VERTICAL SECTION soho 8000 OIL AND GAS CONSERVATION COMr "N r~ APPLiL;ATION FOR SUNDRY APPROVALS' 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown ..X__ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other_ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development .X_.. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 171' FSL, 94' FEL, Sec. 2, T10N, RSE, UM At top of productive interval 1650' FSL, 2571' FWL, Sec. 2, T10N, R8E, UM At effective depth 1729' FSL, 2779' FWL, Sec.2, T10N, RSE, UM At total depth 1756' FSL, 2830' FWL, Sec. 2, T10N, R8E, UM (approx) (approx) (approx) 12. Present well condition summary Total Depth: measured true vertical 8030' feet Plugs (measured) 64 92' feet None RKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2k-6 9. Permit number ~8-82 10. APl number 50-103-20110 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7940' feet Junk (measured) 64 23' feet None Casing Length Structural 8 0' Conductor Surface 3 3 5 2' Intermediate Production 7 9 81 ' Liner Perforation depth: measured Size Cemented 16" 9 5/8" 1000 Sx AS III & 400 Sx Class G 7" 385 Sx Class G None true vertical Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Measureddepth True ve~icaldepth 115' 115' 3388' 2750' 8016' 6327' 13. Attachments Description summary of proposal _ Detailed operation program ~{ BOP sketch _ 15. 14. Estimated date for commencing operation November, 1989 16. If proposal was verbally approved Name of approver Date approved Status of well classification as: Oil X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~tned Fo.~I ~ -"~'. ~ Title Area Drillin[t En~lineer / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test~ Location clearance ~ Mechanical Integrity Test_ Subsequent form require JApproval No. d) ") Approved bi/the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY ! flNN,E C. SMITH Commissioner Date SUBMIT IN TRIPLICATE ARCO Oil and Gas Company ",~ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after s well is spudded or workover operations are started. Daily work prior to spudding.~lould be summarized on the form giving inclusive dates only. · District I County. parish or borough ARCO ALASKA INC. NORTH SLOPE Lea~ or Unit KUPARUK RIVER I ADL 25588 AKL 2674 ! Auth. or W,O. no. lTitle AK3617 I DRILLING IState AK no. Field 2K-6 Operator ARCO Spudded or W.O. begun SPUD IOate08/10/89 Hour 18:30 IARCO w,I. 55,8533 Prior status if a W.O. Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 08/11/89 (1) TD: 1771'( 1771 SUPV:CD 08/12/89 (2) TD: 3408'( 1637 SUPV:CD 08/13/89 ( 3) TD: 3408'( 0 SUPV:CD 08/14/89 ( 4) TD: 5580'( 2172 SUPV:CD 08/15/89 (5) TD: 7344'( 1764 SUPV:CD 08/16/89 (6) TD: 7594'( 250 SUPV:CD DRLG F/1771 MW: 9.1 VIS: 85 ACCEPT RIG AT 1500 8/10/89, NU DIVERTER SYSTEM, PU BHA, FUNCTION TEST DIVERTER DRLG F/115-1771 DAILY:S65,363 CUM:$65,363 ETD:S65,363 EFC:$1,310,000 RU TO POH W/9-5/8" CSG MW: 9.6 VIS: 60 DRLG F/1771-2119, CIRC, SHORT TRIP 10 STDS, DRLG F/2119-3408, CBU, SHORT TRIP TO HWDP (20 M LBS DRAP AT 1600'), CIRC, DROP SINGLE SHOT SURV, TOH LD BHA, RU & RUN 43 JTS 9-5/8" CSG, HIT BRIDGE AT 1638', CIRC ( UNABLE TO WASH THRU), RU TO POH W/ CSG DAILY:S54,829 CUM:$120,192 ETD:S120,192 EFC:$1,310,000 MU BRADENHEAD 9-5/8"@ 3388' MW: 9.7 VIS:104 TOH LD 9-5/8" CSG, PU 12-1/4" HOLE OPENER, TIH, WASH & REAM F/1635-2229, CIRC & INCR VIS, TIH, WASH & REAM F/3195-3408, CIRC, TOH LD BHA, RU & RUN 86 JTS 9-5/8" CSG TO 3388', RU DOWELL, CIRC, PUMP 80 BBL H20, 1000 SXS ASIII W/1/4 PPG CELLOFLAKES (12.1 PPG, 345 BBLS), 400 SXS CL G W/ADDITIVES (15.8 PPG 82 BBLS), DISPLACED W/255 BBLS H20, BUMPED PLUG TO 2000 PSI, FLOATS HELD, RD DOWELL, ND DIVERTER, DO TOP JOB, MU 11-3/4"X11" BRADENHEAD DAILY:S212,891 CUM:$333,083 ETD:S333,083 EFC:$1,310,000 DRLG F/5580 9-5/8"@ 3388' MW: 9.4 VIS: 39 NU BOPE, TEST BOPE TO 3000 PSI, MU BHA, TIH, TAG FC AT 3308, TEST CSG TO 2000 PSI (OK), DRLG FC, FS &10'NEW HOLE, TEST FORMATION TO 12.4 PPG EMW, DRLG F/3418-5580 DAILY:S48,252 CUM:$381,335 ETD:S381,335 EFC:$1,310,000 CIRC. & COND. MUD 9-5/8"@ 3388' MW: 9.4 VIS: 34 DRLG F/5580-6117, CBU, TOH TO CSG SHOE, PERFORM OH LOT (HELD TO 10.2 EMW), TIH (TIGHT F/5630-5725), DRLG F/6117-6653, TURBINE LOCKED UP, ROT. DRLG W/ LOCKED UP TURBINE F/6653-7433, CIRC & COND MUD BEFORE SHORT TRIP FOR OH LOT DAILY:S48,831 CUM:$430,166 ETD:S430,166 EFC:$1,310,000 DRLG F/7594 9-5/8"@ 3388' MW:10.3 VIS: 42 TOH TO CSG SHOE, CIRC, PERFORM OH LOT TO 10.8 EMW, CONT. TOH, LD TURBINE, PU ROT. BHA & SOS LWD TOOLS, TIH TO CSG SHOE, CIRC, PERFORM OH LOT TO 10.8 EMW CONT. TIH, PIPE STUCK AT 6869, JAR FREE, WASH & REAM F/6856-7344, DRLG F/ 7344-7594 DAILY:S56,822 CUM:$486,988 ETD:S486,988 EFC:$1,310,000 The above is correct For for~ propara~'n~an~t ~]stribu 't~, see Procedures I~a/ual, Section 10, Drilling, Pages 86"'and 87. Date RECeiVED AR3B-459-1-D Number all dally well history forms consecutively as they are prepared for each well. Page no, ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlnrlm" sheets until final completion. Report official or representative test on "Finnl" form. 1) Submit "lntnrim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strinG until completion. District Field ARCO ALASKA INC. IState AK Well no. J County or Parish NORTH SLOPE I Lease or Unit KUPARUK RIVER I ADL 25589 ALK 2674 2K-6 Date and depth as of 8:00 a.m. 08/17/89 ( TD: 8030'( SUPV:CD 08/18/89 ( TD: 8030'( SUPV:JR 08/19/89 ( TD: 8030'( SUPV:JR 08/20/89 (10) TD: 8030'( SUPV:JR 7) Complete record for each day while drilling or workover in progress DOYON 14 SPOT DIESEL PILL, TOH 9-5/8"@ 3388' MW:10.3 VIS: 44 DRLG F/7594-8030, CIRC & COND MUD, SHORT TRIP TO CSG SHOE, TIH, LOG W/SOS LWD F/7450-7750 AT 2 FT/MIN, CONT. TIH, CIRC, SPOT DIESEL PILL DAILY:S57,654 CUM:$544,642 ETD:S544,642 EFC:$1,310,000 PUMP DRY JOB/TOH 9-5/8"@ 3388' MW:10.4 VIS: 47 CONT. TOH, LD SOS LWD TOOLS, RU SOS E-LINE, WLIH, STACK OUT AT 7330, WLOE, ADD WEIGHT BARS TO TOOL STRING, WLIE, STACK OUT AT 7330, WLOH, RD SOS, MU BHA, TOH, STACKED OUT AT 7330', WASH & REAM F/7330-8030, CIRC & INCR MW TO 10.4, PUMP HIGH VIS SWEEP, MIX DRY JOB, PREP TO TOH DAILY:S48,537 CUM:$593,179 ETD:S593,179 EFC:$1,310,000 CIRC & COND MUD 9-5/8"@ 3388' MW:10.6 VIS: 50 10 STD SHORT TRIP, CIRC & RAISE MW TO 10.6+, 10 STD SHORT TRIP ( HOLE CLEAN), CIRC & COND MUD, DROP SS, SPOT DIESEL PILL, TOH, RU SOS, RUN TRIPLE COMBO, RD SOS, MU BEA, TIE, CIRC & COND MUD DAILY:S51,941 CUM:$645,120 ETD:S645,120 EFC:$1,310,000 RD DOWELL 7"@ 8016' MW: 0.0 VIS: 0 CONT. CIRC & COND MUD, SPOT DIESEL PILL, TOE 10 STDS, PUMP DRY JOB, TOH LDDP, TIH 10 STDS, TOH LD DP & BHA, PULL W/B, RU & RUN 210 JTS 7" CSG, CIRC 2-3/4 CSG VOLUMES, PUMP 10 BBL CW100, 20 BBL SPACER 3000, 79 BBL (385 SX) CL G W/ADDITIVES, DISPLACE W/306 BBL 10.3 PPG BRINE, BUMP PLUG, FLOATS HELD, RD DOWELL DAILY:$214,839 CUM:$859,959 ETD:S859,959 EFC:$1,310,000 The above is correct Signatu re/~ For form preparatil0'6 ~nd' distributio:~.- see Procedures Mk[~al Section Drilling, Pages 86 and 87 4, AR3B-459-2-B Number all daily well history forms consecutively as hey are prepared for each well. Page; no ARCO OiI and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Repo~t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final RapoIT' form may be used for reporting the entire operation if space is available. j Accounting cost center code District I State ~co ~As~ I~¢. I AK County or Parish NORTH SLOPE Field ILease or Unit I Well no. KUPARUK RIVER I ADL 25588 ALK 2674 2K-6 Auth. or W.O. no. ITitle AK3617 I DRILLING Operator A.R.Co. W.I. JTotal number of wells (active or inactive) on thisi ARCO 55,8533 Icost center prior to plugging and 1 [abandonment of this well Spudded or W.O. begun Date JHour I Prior status tf a W.O, SPUD 08/10/89 / 18:30 I Date and depth Complete record for each day reported as of 8:00 a.m. DOYON 14 08/21/89 (11) TD: 8016'( 0 SUPV:JR RIG RELEASED 7"@ 8016' MW: 0.0 VIS: 0 ND FLOWLINE, RISER, CHOKELINE, RAISE BOPE, SET SLIPS ON 7" CSG, BLOW DOWN 100' BRINE, CUT 7" CSG, LD LANDING JT, LOWER BOPE, LD KELLY, ND BOPE, INSTALL PACKOFF, INSTALL TUBING SPOOL, TEST TO 3000 PSI, RELEASE RIG 1530 8-20-89 DAILY:S23,000 CUM:$882,959 ETD:S882,959 EFC:$1,310,000 Old TD Released rig Classifications (oil, gas, etc.) INew TD Date PB Depth Kind of rig Type completion (single, dual, etc,) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing interval Oil or gasTest time Production OII 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 ~',gnature/~..,~ ~ ID~/~, ~~. For form preparati~ ~nd distribution. see Procedures M~n~al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively Pag~ no. as they are prepared for each well. I Division of AllanticRtchfieldCompany ARCO Alaska, Inc. Date: December 15, 1989 Transmittal #: 7624 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 6 PET Log 1 0-1 9-89 5900-791 8 Receipt Acknowledged: - Date' DISTRIBUTION: r~laska Oil & Gas Cons. Anchorage NSK Drilling State of Alaska(+sepia) ARCO Alaska, Inc. Date' December 6, 1989 Transmittal Ct: 7620 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 2 Acoustic Cement Bond Log 9 - 2 4; 8 9 4 5 8 8 - 6 9 0 6 2 K - 1 I Acoustic Cement Bond Log ,9 - 2 3- 8 9 4 9 9 8 - 6 7 7 0 2 K - 0 6 Acoustic Cement Bond Log 9 - 2 2 - 8 9 5 5 0 2 - 7 9 2 0 2 K - 0 5 Acoustic Cement Bond Log 9 - 2 6 - 8 9 5 3 5 6 - 7 8 0 3 2 K - 01 Acoustic Cement Bond Log 9 - 2 3 - 8 9 5 8 3 8 - 8 4 4 0 R[CEiVEi) Receipt Acknowledged- DISTRIBUTION: NSK Drilling State el. AlaSka( + SePia) ....... " ARCO Alaska, Inc. Date' August 25, 1989 Transmittal #: 7547 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 06 2" Dual Induction - SFL 8 - 1 8 - 8 9 1 000 - 8022 2K-06 5" Dual Induction - SFL 8-1 8-89 1 000-8022 2K-06 2" & 5" Raw FDC 8- 1 8-89 7300-7996 2K-06 2" & 5" Porosity FDC 8-1 8-89 7300-7996 2K-06 Cyberlook 8-1 8-89 7500-7950 Receipt Acknowledged' ........................... Date' ' ....... ~hora~te DISTRIBUTION: NSK State of Alaska(+sepia) Franzen Drilling D&M L. Johnston(vendor package) ARCO Alaska, Inc. Date: August 25, 1989 Transmittal #: 7544 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 6 LWD EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 3 4 2 K - 0 6 OH EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 3 5 2 K - 0 5 OH EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 2 8 Receipt Acknowledged: ........................... Date: DISTRIBUTION: Craig Suchland State of Alaska ALASKA OIL AI~D ~ ¢O~IS£RVATIC Trip tank A~ . Y~r Ko11~ I nm t de BOP ~k~ m~nt fold Nu~or valve~ N~ fl angel AdJua~obls eh, ~driu1(oi11~ IIIBi rkl % ertl - AOGCC · - OperltOr C.OO~ (rev 03/17/09) .... . : _ -;. :: Ti . 1= I i Inspnecor~ ~ )MM PA/ VALVESt . -- i L_ II '",' RECEIVED AUG 14 1989 Oil & Gas Cons. CommMlon August 3, 1989 Telecopy: (907)276-7542 Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 knchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2K-6 ARCO Alaska, Inc. Pexwnit No. 89-82 Sur. Loc. 171'FSL, 94'FEL, Sec. 2, T10N, RSE, UM. Btm_hole Loc. 1723'FSL, ll61'FWL, Sec. 2, T10N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other gover:unental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipmen~ so that a representative of the Commission may be present co 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 co~m~ei~cing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. V~ truly Cha i~n o f Alaska Oil and Gas Conservation Con~ission BY ORDER OF THE COMI~ISSiON dlf Enclosure cc: Department o£ Fish & Game, Habitat Section w/o eacl. Department of Environmental Conservation w/o encl. ..... ~-'" STATE OF ALASKA ...... ALA,_ .A ',..,- AND GAS CONSERVATIC C ISSION PERMIT TO DRILL Re-Entry - Deepen la. Type of work Drill 2. Name of Operator ARCO Alaska, Inc. 20 AAC 25.005 lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Service - Developement Gas ~_ Single Zone 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 171 ' FSL,94' FEL,Sec. 2,T10N,R8E,UM At top of productive interval 1 650 ' FSL, 1350 ' FWL,Sec. 2 ,T1 0N, R8E,UM At total depth 1723'FSL,1161 ' FWL,Sec. 2,T10N,R8E,UM 12. Distance to nearest I 13. Distance to nearest well property line ]2K-5 Conductor 1161' (~ TD feet 25' ~ surface feet 16. To be completed for deviated wells Kickoff depth 800 feet Maximum hole angle 41 0 18. Casing program size Hole Casing 24" 1 6" 12-1/4" 9-5/8" Development Oil Multiple Zone 5. Datum Elevation (DF or KB) KB 154, PAD 118'GL feet 6. Property Designation ADL 25588 ALK 2674 7. Unit or property Name Kuparuk River Unit 8. Well number 2K -6 9. Approximate spud date 08/14/89 14. Number of acres in property 10. Field and Poop uparuk River Field uparuk River 0il Pool 11. Type Bond (see 20 AAC 25.025) Statewi de Number #U630610 Amount $200,000 8-1/2" 7" 15. Proposed depth (MD and TVD) 8022'MD .... 6469' TVD f.e_e~:....~---" psig Specifications Weight I Grade ! Coupling I Length p- 0 I 6.0# -55 IE TC I3292' 2560 17. Anticipated pressure (see 20 AAC 25,035 (e)(2)) Maximum surface 1 6 5 7 psig At total depth (TVD) 3 0 9 8 Setting Depth Top Bottom I 35, j 115,j 34'1 24' 18092'1 I ! Quantity of cement TVD (include stage data) 115' ±200 # cf 2928' 650 sx AS II I & Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Oi)erations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Length Size Cemented Measured depth Casing Structural Conductor Surface Intermediate Production Liner True Vertical depth Perforation depth: measured · true vertical 20. Attachments Filing fee I~ Property plat [] BOP Sketch Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. ! hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~")~ ~'-~y TitleArea Drilling Engineer / Commission Use Only JWB/1 0 Number I APl number Approval date Permi Conditions of approval Samples req.uired [] Yes~No Mud Icg required [] Yes ~li~'No Hydrogen sulfide.measures [] Yes /~ No Di, rect'ional survey required ~t~'Yes [] N6 Required working pressure for BOP_~ FI.~VI; ~ 3M; [] SM; [] 10M; [] 15M by order of Approved by (~, --!--/. L __--' ,~"~-~-~,i~ Commissioner the commission Form 10-401 Rev.'f2:T¢85 Date ISee cover letter for other requirements ARCO ALASKA, ]:ne. Pad 2K, Well No, 6 Pr. opoeed Kupar'uk Field, Nor. th Slope. Aleeka 0 . RKB £LEVATI:ON~ 154' ! 000 _ 2000 _ m 3000 _ o 4000 _ 5000 - KOP TVD-800 THD-800 DEP'O BUILD 3 BEG 9 PER 100 FT B/ PERHAFROST TVD-1424 THD-1436 DEP-I05 I T/ UGNU SNDS TVD-1543 THD-1563 DEP-150 27 3e EOC TVD-2054 THD-2168 DEP-4?O T/ 14 SAK SNDS TVD-2159 THD-2307 DEP-561 B/ 14 SAK SNDS TVD-2728 THD-3062 DEP-1056 g 5/8" CSG PT TVD-2928 THD-3327 DEP-1 230 K-lO TVD-3260 THD-3Z6Z DEP-1520 K-5 TVD-4523 THD-5442 DEP-261g AVERAGE ANGLE 41 DEG $HIN 6000 _ T/ ZONE C ?VD-6154 THD-?605 DEP-4040 ,, T/ ZONE A TVD-6196 THD-7660 DEP-40?6 TARGET CNTR TVD-6236 THD-T?14 DEP-4111 Iii/ KUP SNDS TVD-6318 THD-7822 DEP-4183 7000 0 ! 000 2000 3000 4000 5000 VERTICAL SECTION HORI ZONT^L PROJECT I ON SCALE 1 IN. = 1000 FEET TD LOCAT ! ON, 17'23' FSL. ! ! 6! ' Fgl. ~E'C. 2. TI ON. RSE TARGET LOCATION' le~,O' I:~L. 13S0' FWL ~EC. 2. TION. RIlE 3000 ,,~ 2000 _ 1000 m 1000 _ ARCO ALASKA. ! no. Psd 2K. Well No, 6 Propo,ed Kuperuk Field. North SI ope, Al WEST-EAST $000 4000 3000 2000 I I I, 1 000 I TARGET CENTER TV~ T FEIm T T 14 DLq~-411 I NORTH 1 I/EST 3&~ N 68 DEQ 55 MI N W 4111' (TO TARGET) 1 000 I SURF~ LOCATION, I71' F~t.. 94' FEL ~EC. 2. TI ON. RIlE 400 550 300 250 200 ! 50 ! O0 50 0 I I I I _1 I I ,, I , I ............ _ __ 200 ~ ~ ~ lOO JJ I --- - ~. ~o~ -~,-~ ,'=,~oo 50 _ O ~ 2300 500 I · 500 J ! ! ,,,' ~.~O~o I I ---- "~ ...m --.-- J _ 300- 250 200 150 100 _ 50 400 3;50 3;00 250 200 1 50 1 O0 50 0 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and Cement 7" casing, Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. -~O'EGASSER'1 i CLEANER SHALE SHAKERS STIF STIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM (2K-6) Spud to 9-5/8" Drill out to surface casino weiaht UD Density 8.8-9.0 8.7-9.2 PV 1 5-30 5- 1 5 YP 20-40 8-1 2 Viscosity 70-80 35-40 Initial Gel 5-15 2-4 10 Minute Gel 15-30 4-8 APl Filtrate 1 0-1 5 1 0- 2 0 pH 9- 1 0 9.5-10.5 % Solids 10 +/- 4- 7 Weight up to TD 9.7 11-16 8-12 35-50 3-5 5-12 6 9.0-10.5 12-15 Drillina Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.0 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The closest well to 2K-6 is 2K-5. This well is 25' away at the surface which would be the closest point. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC J I. DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~:3N WELD STARTING HEAD 3. FMC D IVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10" HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEFL VALVES CAN BE REMOTELY CONTR~ ! ;n TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.~) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES = "~JG 4/26/88 -7 6 D]~ et 1~-5/B" ~ 1~3! ~ BCP STACK AOCUIvL~TC~ CAPACI~ I'EST I. C}.~C~ ~ FILL ACI3.MI. ATCI~ I~..~VOII~ TO ~ I. EV~L WITH ~IC FLUID. ~ T~T ~~ ~ I~ ~~I I~ ~l ~~ ~ T~ ~~T~. 3. ~ TI~ T~~ ~ ~ SIXThlY 4. ~~~~ ~. ~~~ L~ LI~T It 45 ~~ ~I~ lI~ ~ I~ ~1 ~I~ m 5 4 3 2 1:5-510' BOP STACK TEST I. FILL BCP STACK AI~ 04[~ blIN]FOLD WI:iH A~IC DIESEL. 2. O.~CK THAT ALL LOCX FLLLY RETRAC'T[~ SEAT TEST PLUG IN WI'IH RtJ~ING JT LII~: VALVF. S ADJ~ 4. PRE~ LIP TO 250 ~ AM) ~ FOR IO MI:N. I1~- ~ ~ TO :~)IZ) I~J:X AI~ HB.D I=l~ IO~N. BLEED PRESSt. RE TO 0 I~JI. LII~: VALES. Ct.08E TCP PIPE ~ AN) ~ VALVES CN Kill AI~ O4CKE LII~3. 7. O:NT~L~ TEs'r~ ll~l I~JT?~ ~I1~ RI~ ?0 ~ ~l ~ ~ ~I. ~I. ~ ~I. 006400 ARCO Alaska, Inc. Post Office Box 100360 Ancho[~ge, Alaska 99510-0360 Telephone 907 276 12'15 December 12, 1988 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat (Wells i - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for any questions, please call me at 263-4618. Sincerely, - 2K the Pad ~ subject wells. If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC 1 .1988 Alaska 0il & Gas Cons. C0mmissim] Anchorage GRU13/010 ARCO Alaska, Inc. is a S(~bsidiary of AtlanlicRichfieldCompany ~_~ i WELLS ~ -~2 ARE LOCATED ~N SECTION 2 T. ~O N., R. 8 E., z o. i UMIAT MERIDIAN. N.T.S. ! . ~ ' ' I UMIAT MERIDIAN. HIS ~URV~ s~cno~ z ~:~ ~ ..... .~ SECTION CORNER ' I t*~5 I. CO0~INATES ARE ASR ZONE 4. SECTION II 18:t9 SECTION lZ ~. ALL DISTANC~ SHOWN ARE TRUE. . ~:Zt 3. ELEVATIONS ARE B.P.M.S.L. ~ 5. HORIZONTAL POSITION BASED ON 2'K CONTROL MONUMENTS PER ~NSBURY ~ A~OClATE$. ' ) DEC 1 1988 s- 58REFERENCE, 59, 65 a 66.FIELD BOOK: L 88-40, p~. 55,56 , ~UI I Well ,y ASp's Ala¢ A UIt ~ t~;,.:~ C0,5. Dist I Dist. O.G. ~d ~. ' 'X' ~M~ ~l ~NGITUDE ES.L. IEEE Elev. Elev. I 5,938,600.18 f 498~310.17 i 70°14'36.519" : 150~00'49.]33'' ' 296' ~ 94' !!4.0 118.5 2 5~938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130" 271, 113.9 I ~1 II II 3 5,938,550.30 498,310.35 70° 14, 36.0~0 150 °00' 4~. ~,, ~4 113.8 4 5~038~5~5.4~ 408,310.0~ 70°1 35.784" ! 150°00'4~.1 ~ ~' ~3.8 5 5,~38,500.1~ 4~8,310.1~ 70° 14' 35.53~" ~50°00'4~.1S4'' I~ 113.8 6 5,938,475.14 498,310.33 70014' 35.289" 150°00'49.128" 17/' I 15.8 I 7 5,938,450.36 498,310.36 70°14'35.046'' 150°00'49.127'' 146' !13.8 : 8 5,938,425.30 498~310.18 70014'34.799'' 150°00' 49.13~'' 121' 113.8 9 5,938,400.30 498,309.98 70014. 34.553" 150°00'49.13T'' 96' I0 5,938,375.19 498~ 510.14 70014' 6"3" , I 113.8 34.30 150°00'49.13 71 I 113.9 t I i 5,938,350.22 498,310.14 70°14'34.061 " 150°00'49.133'' 46' ~' 113.9 :12 5,938,325.20 498,310.17 70°14'33.815" 150°00'49.131" 21' 94' 113.9 118.5 ~ FN.L 13 5,938,235.31 498,310.37 70 ° 14' 3Z.930'' 150°00'49.125" i 69, 94' 113.7 118.5 14 . 5,938,210.14 498,310.16 70o14'32.683" 150° 00' 49.131" ~ 94 113.7 15 5,938,185.12 498,310.16 70o14'32.437" 150°00'49.131" ~ 119' : 113.8 16 ~ 5,938,160.11 t 498 310 20 ; 70°14'32.191'' 150°00'49.130'' 144' 113.8 ' I · il7 ~ 5,938, 135.21 498,310.18 70o14' 31.946" ,~150°00'49.130'' 169' 113.9 18 5,938, 110.19 498,310.29 I 70014'31.700'' 150000'49.12T'' 194' 114.0 i 19 5,938,085.20 ; 498,310.27 i 70014'31.454'' 150000'49.127" 219' 114.0 I I I I ~0 5,938,060.14 498,310.22 70°14 31.207" 150o00 49.128" 244 114.1 21 5,938,035.16 498,310.16 70°14 30.962 150° 00'49. 130" 269' 114.0 22 5,938,010.40 ~ 498,310.19 70o14' 30.718" 150° 00'49. 129" Z94~ 94' 114.0 4' 23 5,937,985.32 498,310.1~ 70°14,30.471" 150°00'49.130'' 31 95'5, 114.0 9' [24 , 5~937,960.29 498,310.08 70°1 30.225" 150°00'49.132'' 344' 9 I 113.9 118.5 I HEREBY CERTIFY THAT I AM ~~..' ' PROPERLY REGISTERED AND LICENSED ~." ~ '".?+'e . , ,o .............. '" O i c0 AmSk STATE OF ALASKA AND 1HA/ /~ ~.....,. .......... .., ...... ~[ o~ u~o[~ MY O~EOT SU.E~- · DRILL 81TE VISIONAND OTHERAND DETAILsTHAT ALLAREDIMENSIONScoRRECTfl~j".. ~-s~ ....'~t~. CONDUCTOR AS-BUILTS .Alasl a VH & G:~.:s 13o,s. uon m;uu:'s;~ Dist Dist. O.G. ~d .I 'Y' 'X' ~~ ~NGITUDE ES.L. EEL. Elev. Elev. ASp's ' I 5,9~8,600.18 498,310.17 70°14'36.519" 150o00'49.]33'' 296' 94' !!4.0 118.5 2 5,9~8,575.14 498,310.28 70°14'36.273'' 150°00'49.130'' 271' 11~.9 3 5,938,550.30 498,310.35 70° 14' 36.029" 150 °00'49.128'' 246' I 1~.8 36" 4 5,938,525.46 498,310.06 70o14' 35.784" 150°00'49. I 22Z 113.8 5 5,938~500.19 498,310.1Z 70° 14' 35.536" 150°00'49.154'' 196' 113.8 6 5,938,475.14 498,310.33 70o14' 35.289" 150°00'49.128" 171' 115.8 7 5,938,450.36 498,310.36 70014' 35.046" 150°00'49.1~7'' 146' !13.8 8 5,938,425.30 498~310.18 70o14'34.799" 150°00' 49.13~'' 121' 113.8 9 5,938,400.30 498,309.98 70°14' 34.553" 150°00'49.13T'' 96' 113.8 I0 5,938,375.19 498~310.14 70° 14' 34.306'' 150°00'49. 133'' 71' 113.9 t I 5,938,350.22 498,310.14 70°14'34.061 " 150o00'49.133'' 46' ~. 113.9 12 5,938,325.20 498,310.17 70°14'33.815" 150 °00'49. 131'' 21' 94' 113.9 118.5 FN.L 13 5,938,235.31 498,310.37 70 ° 14' 3Z.930'' 150 °00' 49.1Z5'' 69, 94' 113.7 118.5 14 5,938,210.14 498,310.16 70o14'32.683" 150°00'49.131" 94 113.7 15 5,938,185.12 498,310.16 70o14'32.437" 150°00'49.131" 119' 113.8 16 5,938,160.11 t 498 310 20 70°14'32.191'' 150°00'49.130'' ~44' 113.8 ' I · 17 5,938, 135.21 498,310.18 70o14' 31.946" 150°00'49.130'' 169' 113.9 18 5,938, 110.19 498,310.29 70014'31,700'' 150°00'49.12T'' 194' 114.0 19 5,938,085.20 ; 498,310.27 70014' 31.454" 150o00'49.127" 219' 114.0 ~0 5,938,060.14 498,3;0.22 70°14' 31.207'' 150o00'49.128" 244' 114.1 ~1 5,938,035.16 498,310.16 70° 14' 30.962'' 150° 00'49. 130" 269' 114.0 22 5,938,010.40 ~ 498,5~0.19 70o14' 30.718" 150° 00'49. 129" 294' 94' 114.0 4' 23 5,937,985.32 498,310.1~ 70°14,30.471" 150°00'49.130'' 31 95'5, 114.0 9' ~4 , 5~937,960.29 498,310.08 70°1 30.225" 150°00'49.132'' 344' 9 I 113.9 118.5 CHECK LIST FOR NEW WELL PER, fITS ITEM APPROVE DATE /.Pc (~ thru 8) ' (8) (10 and 13) 12. 13. (4) Casg f/<~,~4 f-~--~ (14 thru 22) (5) ~OPE -f~:~.~f ~-~ ~= (23 thru 28) Company ./~-~ Lease & Well No. YES NO _ 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. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor String provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... 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 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 ....................................... Is the drilling fluid program schematic and list of equipment adequate~____ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~d~cpCp psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thru il)' rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ~';o/oo ,¢;'~ /-o. ??o ///~'o Additional Remarks: o ~ 0 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. · . · C"Ot~PAI~¥ NA'~'' ARCO ALASKA, WELL NAME FIELD NA~E J KUPARUK STATE , AI, ASK~ APi NtJm~g~ ~ 50-103-2011o REFER~]NCE~ N l'"' . . ~ , 734.3 4 NICI OFILNED [...IS Wave Verlflcation f,.istinq SchlUmberqer AlasKa ComputinO Center SERVICE i'4A~'a,E : EOIT D/~TE : 8q/08/20 OR ~[G I f'~ : FLIC TAp~ W~E : 73434 CONTIHUATI(]~ ~ : 1 CO~UEN'I; I ARCO ALASKA, INC,, KUPARUt'.. 2K-OU, APl #50-!03..20!.10 **** FILE !.t~ADER **** FIb.F. NA~E : EDIT ,001 5ERV.I C~; : WLIC V[~; RS I (.)N : 00~. AO2 i-~a TF : ~9/0~/20 MAX REC SIZE : 1024 FILF TYPE : f,l] KUPARUK 2K-06, AP1 $¢50-!03-20110 PAGE: CONPANY NAAE: ARCO ALASKA, wELL: 2K-06 FIELD: KUPARU~ STATE: ALASKA APl NUMGER: 50-103-20110 bOCa.~It]b~: !71. FSL .~..~0 94 FEb R A ,,N G E: LIS Taoe ¥orlfication Listino Schlumberger AlasKa Computing Center 20-AuG-] 999 F~EtfAT[ONS KB: t54.0 DF: 153.0 L) ~ '.I g LOGGED: TD DR[bi,ER; 8029 C~S!,]n: g 5/8 47 Lb ~¢ LOGGER DFPTH AF 3.38B BTT $~Z,E; 8 1/2 ¢ 8029 DE~SITY: 10.3 ~ ! ..' !') RESISTIVITY: 3.75 FILTRATE RESISTIVITY: 3,98 ,qAXIMUM TE~P RECORDED: 165 LOG~;I'4G DISTRICT; LOC 6.5 6b PRODHOE BAY TORBETT,PERRY,CA~![~ ND6002 DE~'~SITY FAILED AT 7774.0' ON 8IT 'TO DOMP PORT GS 1.4,56 ~.Do 37~01 SEi~SOR-BIT:. R ~ ... DEN ]8 61 MEU 4~34, t) ILhEO iMTERVAL: 734~' TO OATA FROM DO~NHOGE ~EM[)RY ~A~A SAMPLE RAIES = i)EN 10oEC, NE[ 3(,SEC, RES & (~R 20SLC DO~4N~IOL~ SOFTWARE: RGS ~3.0, ~[]ITO~ HOLE TEMP ESTIMATED DATE JO~ STARTED; 17-AUG-89 ,)OB REFERENCE Nh: 73434 bDP/ANA: J. KOHRING CENTER REI'~ARKS: 1) F,[,[,.~ EDIT.001 CONTAINS RESI6T~VITY, NbJI, JT[{[jN. DENS1Ty, AND GA~4A RAY OF MAIN PAS~ LWD .. ~.~ '~ ~ .... . 2) FIh~ f~]DIT.(.)02 CO~.:IA,INS ~,EASUR~ PO1NT UA~A OF RE~iSTIVITY, NE!J:IR(?N, DENSITY AND GAM~A RAY FOR U~[[~4 PASS LWD. 3) wll.,,g EDiT,O03 CO~i~.AINS' AE~" 5'ISq. IVIT~" ~ ' N~.;{t'fRON, DENSITY, AND GA[qi¥I.A RAY'OF WASHDO~N PASS LWD DATA. ' 4) F,IhCr~F:l.JTR[}NEDIT.O04DENSiTyCO~TA~M6~, MEASbR~ ~OINY bwO DATA OF RESISTI~IT~, W AOHD[]'~'N PASS FOTAB' Ol : 'fAB 5) DEW'"," ~ ~ .... .~.~IT~ONS: DATA, , ,.., DATA,~*AB, 02 = TAB [T~M~] AF'iE~ BIT) PROM. RG DATA,~WO = ~W[]B [6URFACE ~EiGHT ON BIT IN KhBS) D.ATA.'fiKL = HKLD (HOOK LOAO IN KLBS) PAGE: LiS ?ape verification [,istinq 8chlumberqer AlasKa ComputJnq Center 20-hUq-lggq t6:27 PAGE: .3 Cr, J ~N 2K-06 API~ 50-1u3-20110 FI, 171' PSI., ~,~g 94' SECT 2 RAN(~ STAT A[,ASNA N~TT USA ENGI 'I'ORBET'f, PERRY, CAc~i,L S~ 73434 E P i) ~' ~;' O, APD FT 15,i, EKB ~T 154. EDF ~'T i 53, EGb FT 1 18 Vh[,b DEFI ARC, el A~ASKA~ laC. Compa~v.Na em Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Engineer's ~ame Service Order Number Permanent datum .flOg ~easured From T~gLE TYPE : C.u D~.:PTN CHANNEL G a m m a R a Y _ NUME [DENT[FT}dD CHh~iNli:!,.. NA~4E TO PhOtO-E.Lectric Factor T~iERt4AL NEUTRON POROSITY SSt RHO DENSITY - bDT DeBSity PoroSity ~Ui~ Density Density Porosity Delta tho RGS aMC ~rTENUATIDN RESISTI{ITY RGS aMC PHASE SHIFT RESISTIVITY RATE JiF r)RIbLING pENETRATIO/~ Nf}UE IDENTIFIED ..... AooUR~,~ ~L)~,!E IOE?,iTIFI'ED CHAi'~NEb NAtaL TO NO'NE IDENTIFIED CHANNEL NAgE TO ASSUR~ THE ASSURE THE C[.}'!~PAT1BILITY wITH LOS SET "CgP~ - 64E~{ *~ ~ 0 2 66 0 3 73 64 5 66 6 73 ? 65 8 68 0,5 9 65 12 13 66 0 14 65 15 6~ 68 16 66 1 0 66 0 ** SET TYPE - C~ ** .... ~ .................. ; ..... ;l-' ' ID ORDER ~ bOG TYPE CLASS ND ...... ............... oo;;,, oo FF I,,,~D OO 000 00 0 ' ' N I, PE L~O P{] O0 OOO 00 ROSi h~S G/C3 O0 000 00 DPNI L~$ p~! 00 000 O0 u RROB LWD G/C3 OO 000 00 0 DP~I L~O pl_l O0 000 O0 u DR~O bwD G/CB GO 000 O0 O T' A R LWD OHMM OO 000 O0 0 PSR I,.,~D ('JH~ OO 000 O0 O ROPE L~D F/~R 00 O00 O0 0 D~T~ TA~ O0 000 O0 0 DAT~ SWO OO 000 00 O~T~ HKL O0 000 O0 '"' ................... I ~ ~ ~ °~°°°°°°°°°° ~ ~ ~ ~ ~ oooooooooo :~ ~ ~ 4 ~s ooooo~oooo ~ ~ ~,, 4 ~, oooooooooo ~ 1 I 4 68 0000000000 ~ I ~ 4 68 0000000000 i 1 1 4 68 0000000000 1 1 1 4 68 0000000000 1 t I 4 68 000000000 i ~ i 4 68 0600000000 I PAGE: -999.250 DATA.TaB -999,250 DPHI,LW;5 'q99.~50 ATR.LWD 'q99.2~0.~ DATA.S~O -999 -999 250 PEF.L~ 250 RHOB,L~D 250 PSR.Lt~D 250 DA;IA.t4KL -999 250 -999,250 -999,250 -999.250 I~iS Tare ver.iticat. Jon I.isti. n~ Schlumberqer AlasKa Compt]tinq Center 8000.000 GR.bwD -999,250 Rt)SioL~!5 -999,250 DRHO.L~ 34,443 DATA.TA~ DEPT. 7800,000 GR,LWD ~Npn.I:~D 36.071 ROS1,LW$ DPHI,L~D -510.735 DRHD.LWD R~P~.I~D 38.0!.1 DATA.TAS I)FP?'. 7700.000 GR.LWO T~PN,L~D 33.497 ROSI.LWS DD~T.L~D 10,892 DR}.{O LWD ROPE.LWD 49.329 DATA~TA~ 760o. O00 GR. LwD DEPT'LwD 29 525 Ri']S 1, LW8 TNp~, . DPH I, L~D ~. 629 DRI]O. LWD R~P~. I..,,~P 43. 543 DATA. TA.G DFPT. 7500.000 TNPH.I..,~D 45,3qu DDHT.T.,WD 1.4.1~8 DRHO~bWD ROPE.I.,,wO 65.798 DATA.'IA~ TI¸ END OF 92.01'! DATa.TAB -990,250 -999.25n 0.441 DATA.SWO 95.293 DATA.'£A~ 2.524 2.856 ATR.LwD 0,328 DATA.S~O 8~.280 DATA.TAa 2.490 DPHI.LWS 2.87] ATR.bWl) 0.319 DATA.SWO 78,554 DATA.TAB 2~49~ PPHI,SWS 0,003 ATR.LWD , ~; SWO 0 222 ~AT~, 74,317 DATA.TAB 2.496 DPHi.bWS 0,025 ATR,bWD 0.253 DATA.SWO 108.631 DATA.TAB 2,404 OPHI,bWS O.014 ATR,LWD O.2~5 DATA,SWO 229.7U4 DATA.'rAi,~ 2,107 DPHi,bW5 0,053 ATR.L~D - 2 999, ,bO DATA,SWO 999:2.50 PlgF.L~D !.957 PSR.L~D 57.372 bAll.Hr{L 1.224 PEF.L~D 7 600 RROB.L~D 2~042 PSR.L~D 54.826 DATA.HKL 1.089 PEF,L~D 9.713 RNOB.L~D 2 913 PSR,LWD ¢).859 PEF.L~U 9.610 RHOB,LWD 4.068 PSR,LWD 52,0.~5 DATA.HKL 0.838 PEF.LwD 14.933 RHOB,LWD , 376 PSR,LWD 4 .418 DAI~A.HKL 0,701 PEF,LND 12; 258 RHOB,L~I,, 2,424 PSR,LWD 52. 209 DATA -999.250 29 275 RHOB .009 PSR.L~D -999.250 DATA.M~L -999 250 -999~250 1.884 113,732 3.358 11,061 2.043 114,427 ~.226 11'078 2,940 112.573 3,164 2,470 4,177 113,517 3.382 2.541 4,104 115.257 3.436 2,116 i. 37 112,81b 333 436 4O8 4.185 ,295 ,754 -999~250 ' 999,250 '999,250 "999~,50 '999,250 I, i5 ~'ap..e fferiffcat~on L~,qtinq Schlumberger AlasNa Computinq Center FILE Na~E : EDIT .001 SFRViC~ : FL!C VERSZO:~ : O01. A02 MAX R~C 61Z~ : 10~4 FIL~ TYPE : LO L~ST FII,E FTL~.: NA~4E : EDIT ,002 VERSION : 00~.A02 D ~'1.'~' : 89/08/20 ~AX REC 5IZ~ : !024 FI"LF; TYPF, : I.,O L~ST FILE : 2 (),-,A 9c;- !. 9 R 9 .'t. 6: ;~ 7 PAGE: 6 TYPE : CONS T I.J ['.~ I v A I', {J D E F I' ~"N liU.PARI.!I% ~ ieid Name ~N 2K-Oo Well Natae PIN 50-t 0~-20110 ~PI Serial Number [~L 171' FSL AND 94' FE[j ~ield Location E 'CT 2 8ectloD n ;~ ~ 10~ Towns h I p ~.. ~ R,.~(, ~Ji): Range C~ tj ~! ~ ~ R T i..{ SLOPE C°t~ftY Ae STA~' Ah oKA State or Prov~nc, ~ 't'. U SA Ma t t On NGI I:O}iI4~TT ~PERRY~ CANIb En9i 0~:~ 7~434 ' ' ' ' sefv ~er PDAT gSk~ Per~nanent datum ~ hog ~easure~ ~'ro~ ' 15~, . T~itI,E TYPE : CORy DEF ! D Ir F.~T DEPTH t,,~ ~.~ A N N ~i'l~ TICK TI..K COUNTER TIC~ (' !,I$ ~a~e Verification l.,istinq Scblumberqer AlasKa Comput~nO Center !6:2'7 PAGE: TICK TICK crluN'I E, DATA ~;OR~,~Ai; SPECIF1CATII~N RECORD Sg~' TYP~ - 64CB ** TYPE REPR COD~ VALIJ~ ,i i, ,imm mm, em,mm,me mm me m m, m m,m m m tm mmm m e m mm m m mm 'l~ ,m 1 66 0 2 66 0 3 73 20 4 66 ,5 66 7 65 8 68 0.099 9 65 FT 1], 66 5i 12 68 13 66 0 14 65 I5 66 68 16 66 1. 0 66 ** SET TYPE - CHAN ** -'x ...... .... i .................... '"' ,ID ORDER ~ LOG TYPE CLA MOD MU~ SAMP RLR~4 CODE (HEX) OEPT FT O0 OUO O0 0 2 i t 4 68 0000000000 TICK N[)D 8 O0 000 O0 ~ 2 1 I 4 ~8 O00OO00000 TICK ND~ S O0 000 O0 0 2 1 I 4 68 0000000000 TICK RGR $ O0 000 00 0 2 I I 4 68 0000000000 TICK RGG S O0 000 O0 0 2 I I 4 b8 0000000000 , "C~ . . ¢'' ~ .... , -99 .~50 7254 0o0 TI..K,NDD -99q,2bO TI._K Ni)~4 TICK (;R '999.250 7299.899 TICK. NDD -99 }.250 TICK. {~DP~ -999.250 iIuK.RGR -999. 250 -999,250 -999.250 LIS fade Verification $chltl~ber!ter AlasKa Computing Center 20--~JG-1989 16:27 PAGE: DSPT. 7]00.100 TIC~.i~D!3 T~CI¢ . ~GG -909. 250 DFPT. 7399.80.9 TICK. L~DO DFpT, 7400,10o TIC~,~DU TICW 'PGG -999,250 OFPT. 7409.899 TICKol"~DD TICK,RGG i,OOO OEPT. 7500,100 TICK.NDO TICF.~GG -999,250 DFPT, 7599,899 TIC&.r~DD TIC[,RGG 1,000 DEPT. 7600,100 TICK, ~DD ']..C!',: RG~ 1 000 DF'PT, 7o99. 809 TICK. NDD TICK. RGG -999. 250 OKPT, ZIO0,100 TICK,~GG 999.250 DEPT. 7799. 809 TICK TIC[,R~/~, I, 000 DEPT 780¥, I00 T LCK. i,~DD TI'C~' R(;G OhO DKPT . 7899. 899 T.ICK, TICk .RGG I .000 ~EpT 7907, lO0 DFPT. , 7999,i399 '?"""~.NDD~.,,., TICR,RGG -999 250 [.EP'I aO00 O0 TiCK al)O T I C ~ ' ' ....... . RGG ~999 50 DEPT. 8017.700 TICK.ND?) TICK.RGG cg · -~.9 250 l.,.a ~ .... -999.2b0 TIC~.NDi~ -99q,250 TICK.:~Dq l.O00 TICK.ND?'I -99q,250 T1CK.~D~ -q99,250 TICK,NDN -ggq.2bO TIC~.~Da -090. 250 T'[CK , NDi,i -999,2D0' ;t.,.CK.i~DN -99g. 250 TICK -999,2b0 TICK.aD~ 1. , 00() TICK -999.250 TI .K,NDN -ggq.2bO TICK, ,~ D~.~ -999.250 TICK,RGR !,000 I'TCK.RGR 1.000 TICK,RGR -999,250 TICK,RGR 1. 000 TICK. RGR 1.000 TICK.RGR -g99,2bO TICK.RGR -999.250 TICK.RGR -999,250 TICK.RGR -999.250 TICK.RGR -999.250 IICK.R~, 1 , 000 TICK. RGR ' "'K 1.000 .tic ., GR '999.250 TICK.RGR -99q,250 TICK.RGR -999.250 TICK.RGR -999.250 '999,250 '999,250 1.000 '999,250 '999,250 1,000 -999,250 1,000 '999,250 '999,250 I .000 1,000 -999,250 -999,250 '999,250 LiS Ta~e veri+=i, cat. ion bistJ, nq Schlumberqer AlasKa Computing Center FILE NA~-~E : EDI'I~ .002 SERviCE : FblC ~AX REC SIZE : !024 FTI.~E TYPE : ~,0 h~ST FiL~ 2n-,~ uG- 19f!9 i6:27 P~GE~ **** f'IbE HEAi)ER FILE NAg£ :EDIT .003 SERVICE : FLIC VERSION : O01A02 1)~~r : ~9/o~f~0 M~X REC SIZE : ~024 ~'IL~ TYPE : bO b~ST FILE : r~BLE tYPE : T t~ ;,~ 17 V A L U D E F I F~ KUPA,RUK glei . a ~ 2K-06 ~ell API[~ 50-!03-20~ It~ _ API [ial Number FL 17i' FSL A r[)~ 94' FEL Fiel~eLOcat $ .,c~' 2 Section TOvit4 ION Townsh~ip CO U ~ ~ORTH SLOPE ~T~ ~r. AS~.~ or Province J BET ,[ ERRY,CANIb EnGine ,,r s ~ame s~a 73434 Servtce Order ~umber PI3A~ t~Sh Permanent datum EPD FT 0. L~F ~KD Lo~ ~easured From APD PT 15q, - EDF FT i 53. E G L ~' T 1 ! 8 TP¢ ~'.r a62~. . TABI E TYPE : CURV ~,,) 1/, If ,[ GP Gamma Ray PFF Pr~oto-Elect ric Factor IS Tar, e Yeri.£i..catio~, l, tstino cblumberqer AlasKa C. ompqtioa Center 20-hbG-1989 16:9.,7 PAGE: 1.0 DP~{] Dens J. tV Porosity ~0~ ~UlK OeDsity D~iiO [~ell;a tho ~OPE RATE OF DRILLING PENETRaTiON ** PATA FORNIAT SPECIFICATION REC[ORL) ** ** SET TYPE - 64EB ** TYPE REPR CODE VAL[I~ I 6 6 4 65 1 5 66 6 73 7 65 ~ 68 0,5 11 66 23 12 68 13 66 0 !~ 65 i. 66 68 66 66 ** SET TYPE - CHAN ID nRDEiR # t, OG TYPE CLASS ~0[)NU~{B SAI:~P ELEi~ CODE (HEX) DEp~ FT O0 000 O0 0 3 I 1 4 68 0000()0,.)000 IS ~ape Yerif.icat. ior~ !]istin<~ chlu,~berqer h!.agKa Computi~lg Center 16:21 PAGE: 1l 7795.500 G R. L%'~ ~,'~ -999,.250 PEF, bw~. -999,250 TNPH,L~W -959.250 DPHI, L~ -999,~50 RHO~,LWW -999,~50 DRHO.LW~ -9Q9.250 PSR, bW~' -999,250 ROP~,bW~ 2192,105 DEP'' q', 77o0. ,OhO GR.LW~ 83,196 PEF.I~Ww 3.070 TNPH.L~ ROS~,bi~,~ 2,~44 DPHI.LW~ 12.478 RHOB.L'~W 11.085 DRHO.LWW ATP.L~ 4.031 PSR.Lw~ 3.779 ROPE,L~ 251.658 D E [/.'T, '?6f~0. O0O GR bww 77 . ,. ,. . ,705 PEF LWw 3,184 'fNPH.LmW ROS1,LwW 2,511 DPRI.LWw 8,42o PHOB,LW~ 11.052 DRHO.L~W ATR,LwW 3,9~1 PSR.LW~ 4.2~7 ROP~,LW~ 151,910 DEPT, 7500,000 GR.LWW 1US,gu7 PEF.LW~ 3 1.93 TNPH.LWW R~$1,LWw 2.367 DP~I,LWW 17.13l RH~.]B.LW~ 11~124 DRHO,LW~ ATR.LWW 1.537 PSR.LW~ 1.519 ROPE,BW~ 120.817 I),,P1,E''~ 74(~4,000,, GR.LW~ -999,250 PEF . bWw - 999 .250 IiNPH.bmW R~S~.I.,~w -999.250 [')PH.[.L~W -999,250 RHOB.L~ 999,250 DRHO.LbW ATR.LWW -999,250 PSR.LWw -999.2b0 ROP~.LW~ 2999,250 END OF .OAmA ** -999.250 -999.250 33,78'7 2,880 29.~08 2,847 45,45] 2.919 2999 250 999:250 **** FILE TRAI'I, ER **** FILE NA~,iE : EDIT .003 S~RVICE : FLIC VERSION : 00!A02 DATE : 89/0~/~0 FILE .)'¥PE : LC) L~ST FiLE : **** FTLE HEADER FILE NA~ : EDIT .004 S..k¥~ E : FLiC qgR,,.iON : 001A02 DATE : MAX REC SIZE : !024 FILE TYPE : LO LASTFiLE [,,IS Ta~e Verification [,istinq Schlu~berger AlasKa Compt.]tin~ Center TA~T.~[. TYPF, : 16:27 PAGE: mmmmmmmmmmmmm~mm~mmmmmmmmmmmmmmmm~mmmmMMmm FN K!.IPARUK API~ 50-103-20110 FI, 171' FSL ANO 94' FEL TO ~ ~,,~ 10N H~NG 8E (]OU~~ ~ORTH SI, OPE STAT ALASKA N~TT USA ENGI I'O~BETT ~ PERRY, CAN ~i'~ SON 734~4 PDAT EPD FT 0, L~F RK~ APb FT 15g, Eg~8 WT 154. ~]DF FT 153. TDO FT ~0 , Field Name Well Name API Serzal Number Field Location Section Township Range County State or Province Nation Engineer's Name Service Order Number Permanent datum LOG Measured From T~BI~E TYPE ~ CURV D~FI DFPT DEPTH C~..~NEL NA~E ,. . ICK COUNTER I TICK T CK TTC~ TICK. LOU, .TER DATA FOrty, AT ,~PEC,,FICATION RE(.O~ D ** ** SET TYPE - 64EB ** TYP~i EPR CODE VALUE 1. 66 2 66 0 3 73 20 4 66 I 5 66 7 65 LIS Tau(? Yerification [,J. stIno Schlumberner AlasKa Computing Center 20-~U(;-19f{9 tf~:27 PAGE: 13 8 68 9 65 ll 66 12 68 13 66 14 65 15 66 16 66 0 6 ~, 0.09g FT 1 ** SET TYPE - C ..................... · SERV U~.~IT SERVICE A ID F}RDER ~ b DFPT FT 0 TICK N[)T~ S 0 TICK NDN S 0 TIC~ RGR 8 0 TIC~ RGG" ' S 0 ** OATA ** PT. 7403, ~00 .],CK. RG~ -~)99' 250 DEPT, 7499. 899 TICK.RGG -999.250 DFPT, 7500, i00 TICK.RGG -909'250 DEPT, 7599. 899 ~'ICK · RGG -999. 250 [)EPT. 7600,1 O0 TICK,RGG -999,250 OEP~, 7699,899 TICK,RGG -'~99.250 77 00 100 -999:250 D~:PT, 773~. 200 TIC~'. RG(:; -999,250 TICK,NOD -999,2b0 TICK.NON TICK.NOD -999.2b0 TICK.NON TICK.NDO 1.000 TICK.,NDN TICK,gDO 1.000 TiCK,NON TICK,NOD 1,000 TICK,NON TICK.NOD 1,000 TICK.NON TICK,NOD 1.000 %ICK.NDN TICK.NOD -999.250 TICK,MDg -999,250 TICK,RGR -999.250 TICK.RGB 1.000 TICK,RGR ~.000 TICK,RGR -999.250 'flCK,RGR 1..000 TICK.RGR ~,000 TICK.RGR -999.250 TICK.RGR -999,250 -999.250 1,000 -999.25:0 -999.250 1-000 -999.2 0 -999.250 LIS Tame '~'er[fi~cation Schlumberger AlasKa Compl]r..inq Center 20-~UG-!9tt9 16:~.7 PAGE: 14 **** TAP~ TRAIl, ER SERVICE; NAME : EDIf DaTV : ~9/0~/20 ORI(;i~ : FblC T~PF ~A~E : 73434 CfiNTi~UATIO~ ~ : ! P~EViO~S TAPE : CO~NE~T : ARCO ALASKA, INC., ~UPANUK 2K-06, API ~50-103-20110 **** REEL TRA I'[,ER **** SERVICE NAME : EDIT ORi~[~N : F6IC REEl'. t,:~A~g : 73434 ONTINOATION ~ : REV!OUS PEEL C()a~Et~IT : ARCO AhASKA, I~C., KUPARUK 2K-06, AP1 ~50-103-20110 * AbA*KA COMPUTING CENTER ****************************** *------- 6CHLU~BMRGER ....... LIS ~a~e Veriffcation I, istinq $cblumberqer AlasKa Computin~ Center 20-AuG-1989 13:2~ SERVICE NAME : EDIT D~TF : 89/08/20 OOIGIN : FLIC REEL NAME ! 73435 C~NTINU~TIO~ # P~EV1OUS ~EEL : COMMENT : ARCO, KUPARUK, 2K-6, AP1 ~5u-I03-201!0 **** TAPE HEADER **** SFR¥ICE NAME : EDIT DATE : O~I(;IN ~ FLIC TAPE NA~E : 73435 CONTINUATION ~ ~ ! P~EVIOUS TAPE : C~M~ENT : ARCO, RUPARU~, 2K-6, APl ~50-103-2Ol10 **** FILE HEADER **** FILE NAME : EDIT ,001 S~RU!CE : FLIC VERSION ~ 001A02 DATE t ~9/08/2o ~AX REC SIZE : FILE TYPE : LO LAST FILE : PAGE: ******************************************************************************* ** SCHLUMBERGER ~ELL SERVICES ** ** ** ********************************************************************************* ******************************************************************************** OMPANY NAME: ARCO ALASKA, INC. EL{]: ~K - 6 ~'~E!..,D: KUPARUK ~DROUGH: NURIH SLOPE STATE: ALASKA LDCATIDN. ~7 FSI, & 94 FEL SP]CTiON: ~ TOWNSHIP; iON P~]iNMANENT DATUM: ~!8L ELEVATION: MEASURED FRO~.~ RRB 154' ~OVE PERMANE~'JT RANGE: SE DATUM [,IS Ta~e Vertitcatj. on [,ist, inq SchlUmberger AlasKa C. omD~,~tinq Center 2o-AUG-19R9 ~3:23 PAGE: EI:EVATIONS KS: 154' 153' Tn DRIL~,E~: ~030' TO LOGGER: ~030' Cfi$ING 1: 9 5/8" DRILLER [)EPTM OF T~ 33~8' BIT SIZE 1: ~ 1/~" 8 8030' TYPE Fbi}ID IN HOLE: wEIGi, iTED DENSITY: 10.6 VISCOSITY PH: 9 FLUID LOS6 MU[) RESISTIVITY: 3,29 @ 72 F~LTRATE PESISTI¥ITY: 3.0~ g 72 MUD CAKE RESISTIVITY: 3,0~ M 69 TIME CIRCULATION ENDED: 13:30 8/18 TI~!!E LOGGER ON BOTTOM: 20:30 8/18 M~XIMU~ TEMP RECORDED: 132 LOGGING DISTRICT: PF~UDHf)E BAY WITNESS: ROBERTSON/BEAL T00t NUMBERS: DIS 1457 DfC 1308 PGS 508 CNC ~449 SGC 2626 IEM 1347 NLN 1378 Gb: ~13' FIELD REMARKS: I 1/2" STANDOFF & 2' HOLE FINDE[~ []SE 1, 0 G/C3 ~TR'X DENSITY : 2 65 G/C3 , ~6t~ C~L' ~ATRiX' = SAN[) ,HObE C~MPUTING CENTER RENAPKS: I.)FILE EDIT.O01 CONTAINS DUAL INDUCTION. FORMATION DENSITY, COMPENSATED NEUTRO AND GA~A wAY IN CASING SAN'PLED AT -.5' ' ' O' CONTA NS f'ORMATION DE.~JS!TY AND C MPENSATED NEUTRON SA~,~PLL[ AT .I' D ~E JOB, STARTED: 20-AUG-89 JOB REFERENCE NO: 73435 LDP/ANA: R. KRUWELL 8chlumberqer AlasKa ComputJ[no Cemter TIJN! VALU DEFI KUPAR[I~ FieId ~ame 2K - 6 Well Na~e USA Nation ALASKA State or Province NORTH SLOPE County 171' FSI, & 9~° FEL Field bocatlon 2 Section InN Township BE Range 1;INKHA~ ~ng~neer's Name 5~9~3! Service Order Number 5o-~03-2OllO APZ Serial Number TABLE TYPE : CURV DFPT' TENS ILD SFLb GR TENS DPHI DP'HO FFDC NFDC T~NS DEFI P P. EL NA~. Tension I[,-DeeD Resistlv~t¥ Ih-Medium Resistivity SF~, Unaveraged Spontaneous Potential G~mma ~av Tension Dens,tV Porosity Bulk Density Delta tho Far FDC Cou~t Rate Meat FDC COunt Rate Raw ear FDC Count Rate Raw Far FDC Cot~nt Rate aliper amh~a RATIU NE ],ROM POROSITY OUTPUT FROM AN RCNT RCFT RAW THERMAL NEUTRON CNTC CFTC Gamma Ray Tension Gam~a Ray NP~"~ THERMAL NEUTRON POROSITY NR~ CAL!BRATFD T~{ERMAL NEUTRON NPO~ CFT TNR RATIF] N' C ~C F~C C I~ G~ TFNM GR APPLICATT£}N PROGRAM LIS TaDe Veriiication bistinO Schlumberger AlasKa Comput!DO Center 20-AUC-IqR9 1~:73 PAGE: ** ~ATA FORMAT SPECIFICATION REC(J~D ** SET T~PE - 64EB ** TYPE HEPR CUDE I 66 0 2 60 0 ] 73 120 4 66 5 66 6 73 7 65 9 65 12 68 13 66 0 14 65 F'I' 15 66 68 16 66 0 66 0 N ~r EPT }L D FLU P G TENS DPHI ~rDC NFDC C aLI F'NS NPHI TNPM T~R~ N FOR RCNT RCFT ** SET TYPE - CHAN ** FT 549131 O0 DIL b~ ~4~131 OO DIL OHMN 549131 O0 D,~L OM~ 549131 O0 DIb ('3~ 549131 00 6. lb MY 549131 O0 OIb G~PI 549I~ O0 FDC L 549 ~, OO ~'DC PU 549131 O0 FDC G/C3 549131 0O FOC ~/C3 549131 O0 FDC CPS 549131 00 FDC CP6 549131 FDC CmS 549131 00 FDC CPS 549131 00 FDC JM 549131 O0 FDC G~PI 549131 00 CNL LB 549131 CNI, PU 549131 O0 CNL P!.! 549131 O0 CaL 549131 O0 CNL PU 549131 00 CNL CPS 549131 O0 CNL CPS 549131 O0 000 gO 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 o00 O0 000 O0 000 O0 000 O0 000 O0 000 00 000 OO 000 O0 000 On 000 O0 000 O0 000 O0 OOO OO 000 O0 000 O0 000 O0 000 O0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 4 68 0000000000 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tar, e Veriiicatl. o~ Listin(, umberger AlasKa Computind Center 20-AUG-1989 i3:23 ID CMTC CNL CF]'C CNL G~ CNL TFNS CSG ** DaTA DEPT, SFLU.DiL DPHI.FDC ~FOC.FDC G~.FDC RTNP CNL DFPT SFLU DPH7' NFDC G~ NRA .TN~ TFNS SFLU DP H I NFDC G~ TN~ DFPT D NFDC G~ TN~ TFNS DIL , FDC ,FDC , FDC , CN[., . CNL ,CSG IT SERVICE APl Apl AP1 F ILE . t:~ Sl REPR PROCESS ORDER ~ L~G TYPE CLASS ~OD ~UMb S~P ELE~ CODE (HEX) ..........549131''''''00 000 0,.~ .... ~'' ...... 1 ~ ......... l '4 ............. 68 0000000000''''='' CPS 549131 0o 000 O0 O 1 1 1 4 68 0000000000 CPS 549131 00 00o O0 O 1 1 1 4 68 0000000000 (;APl 549131 O0 000 O0 0 i 1 1 4 68 0000000000 L~ 549131 00 000 00 () 1 1 1 4 68 0000000000 8044,500 TENS,DII~ 3~U4 000 ILO,DIb 2,79~ ILM.DIL 2.734 SP.DIL 47:250 GR.DIL 88,750 TENS FDC 62,344 RtiOB,FDC 1,621 DRHO.FDC -0.025 FFDC:FDC 9)5.000 RNWD.FDC 176),0u0 RFFD,FDC 6672.000 CALI.FDC 88,250 TENS.CNb ~8U4.000 NPHI,CNL 42 718 TNPH,CNL 3.49] NPOR.CNL 4),403 RCHT,CNL 1614~769 RCFT,CNL 3.614 CNTC.CNL 1667,975 CFTC.CML 486.319 GR,CNL -999,250 GR,CSG =999,250 80(')0.000 TENS.DIb 2,421 SP, DIlL -44, (~44 GR, DIb 88 59.501 964,500 RNFD,FDC !838,000 RFFD,~"DC' 6296 ~8;250 TENS,CNL 5444'000 NPHi.CNb 42 3,531 NPOR,CNb ~4,2~ .~CNf,CNL 1757 3 614 CNTC,CNL 1778'764 '~T · C~ _.C. CML 483 -999. 250 GR. CSG -999. 250 7900,000 TENS,DIL 5384 DI5 2,748 SP.DIL -49 FDC~,.) 12,210 RHOB,FDC ~ ~C 654,500 ~NFD,FDC 125 ~D~. 92,188 TEhS,CNL 53~4 CML 3.572 NPGR,CNL 40 CNL 3,500 CNTC,CNb 1661 CSG -999,250 GR.CSG -999 DI.L . , FDC , FDC ,FDC ,CNL 7800,000 TENS,DTL 11,1.87 DHOB,FDC ~62;000 R~FD,FDC 97.500 TENS,CNb 3,467 MPOR;CNb 3,540 £,~TC C~L -909,250 GR,CSG 2.511 3804 000 3316:000 8.742 41,463 441,782 88,250 DFPT, 7700,000 TENS,DIL SFLU,DI[, 4,56@ SP...)~ .... DIb DPHI.FDC 12,732 ~HO~,.~C NFDC.FDC 587 000 RNFr) 175 ILM.DIL 250 TENS,FDC 004 FFDC,FDC 000 CAbI,FDC 764 TNPH.CNL 703 RCFT,C~[.I 056 GR~CN[. 2,309 5444,000 3108,000 7" 9t2 45 250 454 602 88 250 384 15M,DIL 188 TENS'FDC 071 FFDC,FDC 000 CALI,FDC 91~ TN~H.CNL 163 RCfT.CN~ 757 'R ' G..CNL 2,555 5384;000 547,500 10;250 42,400 422,247 92,188 5512.000 ILD.DIL 3 149 IbM -61.OOO GR,DIb 9~ ,466 DRHO,FDC 1338,000 RFFD,FDC 1077 000 CALl 5512.000 ~P~I'CNL 4.~ ~02 TMPH 3g,2~2 : RCNI, ~,[NB 1909,852 RCFT 1946,7 ~4 CFTC.CNL 579 ~92 GR -999.250 '' 3 55!2 541. 5 lO 97 323 500 820 00 5428,000 ILO,DIt~ ,440 DR[.,J, ~ DC 113 ,000 PFF'D, FDC 4,165 IL~,DIL 84; 625 TE~iiS · FDC 0,017 FFDC FDC 10121500 CALI 'FDC . 4,47~ 5428,000 250 49 ; 492 Tame Vertf, J, cation Listir~o Schlumberger AlasKa Computlno Center GP,FbC 84,625 TEN$.CNL TNRA,CNL 2,893 NPOR.C)Jb RTNP C~,t: 2,837 C~TC, ChL TF~S, CSG '999,250 GR, CSG DFPT 7600.000 TENS DIL SFLU' .DIL 5.331 SP,DIb PH!FDC 9,766 RHOB.f'DC ~[)C~F[>C 607 000 ' FDC ' GR, ~_ 85,000 TENS,CNb TER~,CqL 2,957 RTN~,CNL 2,976 C~TCoC~L TF~$,CSG -999,250 ¢;R,CSG 2o-~t~C-1989 13:23 5428.0Qr~ NPH[,CNL 33,210 RCNT.CMb 2108,a4~ CFTC,C~JL -999.260 31.084 199~.797 732.326 5~40,0u0 ILD.O[L 4,129 59.844.. GR,DIb 85.000 2,4~9 DRHO,FDC O,Oq8 1218,000 ~FFD,FDC 55~0,000 ~!PH1,CNL 32 I~7 31,~18 RCMT.CNL 2130!803 ~77898:750912 Cf'TC.CNb 767097 DFPT. 7500,000 TENS,DIL 5332, SFLI!, Dtl. 1 785 SP,DIL -58, DDHT.FDC 30:735 RHOB.FDC NFDC,FDC 565,500 GP.FDC O6.063 T...,NS,C~L 5332 TNR~,CNL 4,177 NPOR,CHb 54 RTN~ CNL 4.593 CNTC.C~L 1744 TFNS;CSG -999,250 GR.CSG -999 DF.PT, 7400,000 TENS,DIb SFI. I!, DII. 2,673 SP. DIL DPHI,FDC 14,510 NFDC FDC 649 500 RNF[) FDC G~ ' wnrTM ' "' '" TNR~' .... 11.3,625 TENS,CNL TENSiCS.:, -909, 50 CR CS 5304 -63 2 1223 5304 48 1691 -999 ~'= DI5 5188, 000 TgNo, 158 SP,DIb '63. 613 RHCB.FDC 2, 000 RNFD,FDC 1412, 2.0 TEN ~Cgb 5188. 771 NPOR,C~L 46, 946 CNTC,'C~L !80~, 250 GR'CSG 999, DEPT 72_ 0,000 SFLII' DIL 3,210 DPH] ' FDC -gqq, 9qn NFDC, FDC -999,250 GP,FDC -999,250 TNR~., CNL -999,250 RTN~, CNL ?99 ~ 250 TFNS,CSG :999'250 PAGE: 6 TENS,DIL sp R["iOB;FDC PNFD;FDC 'fENS. ~NL NPOR: ND CNTC.CN'L GR.CSG DEPT, 7100,000 FDC 'q99 250 NFDC'F ' -099' GP,...DC ,250 000 ILD.DIL 813 GR,DIb 143 DRHO,FDC 000 RFFD,FDC OOn ~IPHI,C~L ~ CNL RCN~, 3~9 CFTC.CNL 25O TEMS.DIL 8P.DID R~IOB.FDc RNFD;FDC 1.664 96,063 -0.052 1.580,000 53 ?98 1456i568 459 483 TNPH.Ci',~I., RCFT,CNL IL~,DiL %'ENS.FDC FFDC'FDC CALI,FDC TNPH CNL RCFT:CNL GR.CNL IL~,DIL TEN$.FDC FFDC FDC CALI FDC Th)PH CNL RCFT CmL GR CNL 32.223 660.517 84,625 4.352 5540,000 468,750 9,445 31.6~9 708,071 85,000 1.687 5332,000 858,000 10,039 46.538 415,618 96'063 000 iL[;,DIL 2 600 4il DRHO,~ C 0,053 ooo RF'FD,FDC i100,000 0~0 NP~I.CNb 47,642 123 PCNT,CNL 1602,512 77 C~ .. C,CNL 434.012 .50 ' IL~. DiL TENS. FDC FFOC .FDC CALI .FDC 1 ~P}t C~,~L RCFT C ~,;~ L GR,CNL 2 5304 576 !2 46 430 113 719 000 000 OO8 995 252 6~5 000 ILD. DIL 5.:~! G[~, D.I~ 244 BRBO,FDC 000 raFFl), F. C 000 ~.~PHI'CNL 505 .C~T, C~h 105 CF?C' CNL 250 2 03.4 IL~.DIL 268.250 TENS,FDC .030 FFDC,FDC 1833000 CAb .FDC 44 401 TNP~.CNL .1~4 764 RCFT,C~L 280 5~24. .71' -g99' -999, -999; -999' -999, -999. 000 ILD,OIL 2 000 .GR~DIL 1..19 ~50 DRHO'FDC 999 ~50 ~FFDiFDc :999 ~5i:) NP~I~NL -999 250 RCNT~CNb ~999 250 CFTC~Ch~L -999 25o DIL FDC 250 FFDC FD~ 250 C~bI FD 250 TNPH C~L 250 RCFT Ct~L 250 GR CNL 51~'8,000 -63,000 -999.250 -999,250 -999 ~ 250 516 IL~ 500 TENS 250 FFDC 750 CALl 250 TMPH 2 120 5188 000 82O 500 47I 430, . 3,045 2999;250 999~250 -999;250 -999,250 -999,250 -999)250 DIL i, 525 FDC -999,.2.50 FDC -999 ~ 250 FDC -999,250 CNL '999~250 [,IS Tame Yeriflcation Listinq Schlumberqor ^lasKa Computing Cer)ter TNR~.Ci.~[. -999.250 NPOR.CNL RTNP.CNL -999,250 CNTC,CNL I'FN$~CS~ -909.250 GR,CSG OEPT, 7000,000 TEN$.~)?L SFLU DI[, 5,009 SP,DIL DDH~FDC -9g9,250 ~HOB,?'DC NFDC,FDC -999.250 RNFD,FDC GR.FDC -999.250 TENS.C~3L TNR~.CNL -999.250 NPOR.C~L RTbF,CN[, -9~9.250 CNTC.CNL TFN$,CSG -999.250 GR,CSG -999 -999 -999 7O 999 -999 -999 -999 -999 -999 S;Lu*DFPT 6900 .000 TE~.!S,DIL 4~04 ,DI!. 5,2ol SP,DIL 60 DPHI,FDC -999,250 ~HO~,F'DC -g99 NFDC,FDC '999,250 RNFD,FBC ...... 'q9q GD.FDC -999,250 TENS,CNL -999 TNR~,CNL -999,250 NPOR.CNL -999 RTN~ CN! -999.250 CNTC,CNL -999 T~NS~CSG -999.250 GR.CSG -999 DEPT. 6800.000 TENS SFLII,DIL 3.962 SP vDC -999~250 ~gOS NFDC,FDC -999,250 PNFD GR.FDC TNR~.CNL :999,250 TENS 999.250 NPOR RTND~CNI~ -999.250 CNTC TFNS,CSG -999.250 GR 6700,000 TENS 2.289 SP -999,250 P80B -999'~50 RNFD -999,250 TENS -999~250 NPOR -99'9,250 CNTC -999~250 GR , DIL . D'] L FDC FDC CML CNb CML CSG SFL~DIL DPM~.FDC NFDC,FDC G.~ FDC TN'R~ CNI, RTNR CML T~NS. C~ DI L };'DC FDC C Nb , CNL ,CSt; DEPT. 6600,000 TENS SFLb DIL 3,175 S DPHT ' ~ ~C' -9 . ,FD.. 99,250 RHOB NFDC,~DC -999;250 RNFD GD,FbC '999,~50 TENS TNRA,CNL -999~250 NPOR RTNR,CNL '999~250 C~TC TFNS.CSG -999,250 GR ,DIL 'FDC ~NL ,(.Nb .C~G T ~ D1L P'. 650 ,000 TENS SFLU"D.IL . !85 SP ~5 DPHI,FI.)C -999,2.0 RHOB . 25C RNFD NFDC.~[)C -999 ' ' } ~,~,GR,FDC -999,250 TE;N~ ~. ~R~.CNI~ -999.250 NPOR 20-&UG-tgR9 13:23 PAGE: 7 , [)IL , D T L . FDC FDC ~ CML ,CML -999 -999 -999 -999 -q99 -999 4784 -64 -999 -999 -999 -999 -999 4720 -79 -999 -999 -999 4624 '37 ~999 ~99g -qgg .250 PC~!T,C~IL .2bO CFTC.CNU -999 250 -999~250 NCFT,CNL GR,CNL -999.250 -999,250 : 0()0 II..D. [)IL 813 GR.DIL .250 DRHQ,FDC 250 PFFO,FDC '250 ~'~ l:" H 1 C~L, .250 .~CNT.CNL ,250 CFTC.CML .250 ' 4.325 104 438 -999:250 -999 250 -999' ,250 -999.2b0 -999.250 TENS.FDC FFDC.FDC CALI.FDC RCFT,CNL GR.CNL 4.fl45 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 ,000 II, D,DIb .531 GR.DIb ,2bO DRHO,FDC ,250 RFFD,FDC ,250 NPH1.CNL ,?b0 RCNT,C~IL ,2bO CFTC,CNb ,~50 3 752 !I0 938 -999 250 -999 250 -999 250 -099 250 -999.250 ILM.DIL TFNS.FDC FFDC,FDC CALI,FDC "N~ CNI, RCFT.CNL GR.CNL 3,939 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 ,000 ,750 .250 .250 ,250 ,250 II.,D, DI b GR DRHO FDC FFD ,FDC PHI CNL CNI CML CFTC CML 3.341 126 813 -999 250 -999 250 -999 250 99 250 3 -999 -999 -999 -999 -999 -999 508 250 250 250 250 ,250 25O ()00 ILO,DIL 750 GR'DIb 10 50 ~RHO,FDC FFO.FDC 250 NPHI,CNL -999 250 ~CNT,CNL -999 250 CFTC,CML -999 250 ' DIL FDC FDC FDC 250 TNPH,CNL 250 R'CFT,C~L 250 GR.CNL 2 317 -999 250 - 9 9 9 ,250 "999 ~250 -999,250 000 ILD,DIb 2 250 GR,DIU 116 ;250 DRHO,FDC :999 ,2b0 PFFD,FDC 99:9 ;250 NPH!,cNL -999 ,250 RCNI~ ~NL -999 , ., ~f~ .250 CF~u. CNb -999 ,250 949 ILM.DIL 3 375 'S TEN~.,FDC 250 FFDC.FDC 250 CALI,FD ' 9 250 TNPHiCN[ ,99 · "999 250 RCFT,CNb -999 250 G~;CN£,, '999 026 250 250 ,00() ILl). DiL 3 ,2bO DRBO, ~]DC -999 ,~50 .~FFD'.~ DC -999 ,250 NPHi.CNL -999 250 RCNT CkL -999 946 ILE,DIL 4 000 TEN$~FDC '.999 ~50 FFDC,FDC -999 250 CALI.FDC '999. 250 TNPH,CNL -999 250 RCFT ' ,069 ,250 ,5o 250 250 LiS Tare 'Verification ListJno Schlumberger Alaska Comp~.ltlno Center RTNP, C.~..,[, -9~9,250 TEt~S,CSG -999,250 Ci~TC,C~L GR,CSG TENS DIL S P: [) I b rHOB. FDC RNFD,FDC TE:'JS,CNL PflR GR.CSG ~EMS, DIL SP,DIh ~fiO8, Fr)C R NFD, FDC TEN,S,CNL NPOR ,CNL CNTC, C~b GR,CSG SP,DIL RHO~, FDC R N~D, FDC TENS~ CNL ~lP OR, CML CNTC, CML GR.CSG TENS DIL RHDB,FrC TENS. Nh MPDR, CN5 C NTC ' CML GR, CSG DEPT, 6400, SF[ 11,DIt. 5.284 DPH!. FDC '999,250 N~'L'C. FDC 999,250 TN~.~'. CFJL -999,250 RT~;P.CNL -999,250 TF I'~ S, CSG -999,250 DEPT, 6300.000 SFLI! DIL 4,275 DPHI" NFDc,FDC -999,250 .FDC -999,250 G~.FDC -999,250 TNRA,CNL -999.250 RTN~,C~b -999.250 TENS.CSG '999,250 DFPT. 6200,000 SFI. U,DII. 2,8~7 DDDI wDC -999,250 NFDC'wDC -999.250 . G. FDC -999,250 25O T~R[,CIjlL '999,. ( RTNR C[,..L -999,25) T~S'CSG -999 250 DYPT, 6100 p!4I :~DC -999 NFDC.FDC -99 TE~S,CSG '999, 000 ]04 250 25O 250 250 250 250 DEPT, 6000 SFLU,DiL 3 DPH! FDC -999 NFDC: VDC -999 .FDC _NGR -999 T R.~'CNL -999 RTNP;CNL -999 TFNS.CSG -999 ,000 .411 .250 ,250 ,~5o .250 ,250 ,250 TENS SP RNFD TENS NPOR CNTC GR ,D!L , Dlb FDC FPC CNh ,000 .468 2uO '~50 '250 ,250 ,250 TENS SP TENS NPOR CNTC , , DIL , ["DC CN b .C b 20-.~0G-19~9 13:23 -99q. -999, 4564, -40. -q99, -999, 099, :999. .. -999, -999, 455~. 99,999, ~99, -999, -999. 72, 4~27, :999, 999. '999 -999, '999, -999~ 434~ '999 '999 '999 '999 -999 4628, -35, -999, -999, -99Q, -999, ~999, '999. 4?88 -25 -q99 -999 '999 -999 -999 ?50 CFTC.C~L 250 OOO ILO,OIL 250 DRHO,FDC 250 ~FF'D,FDC 250 NFHI,CNL 250 PCNT,C~L 2bO CFTC,CML ~50 000 ILD,DIL 7~1 GR,DI.L 250 DRHO,FDC 250 RFFO,FDC 250 NFHI,CNL 250 RCN'i'.CNL 250 CFTC,C~L 250 000 II,O.OIb 047 Gk,l)Ib 250 DRHO f'DC 250 RFFD'. FDC 250 NPH1.CNL 250 pCNT.C~L CFTC CNL 50 ' OOO II,D.O!I~ 250 D~O; ~c 250 RFF , ~ )C 250 000 ILD,DIL 250 ~FF'O 2b() NPHI,CNL 250 PCNT, 250 CFTC C~L ~50 PAGE: 8 -999.250 GR.CNL -999.250 3,194 ILM,DIL 84.250 TENS,FDC -999.250 PFDC,FDC , FDC -999 250 C~bI. 9o9,250 TNPH CNL 9~9. ?50 RCFT: CNL 999.250 GR,CNL 3,~BO -999,250 '999,250 '999,250 '999 250 '999:250 '999.250 3.376 ILU.DIL 81.250 TEN$,FDC -999,250 FFDC,FDC -999.250 CAbI,FDC -999.250 TNPH,CNI~ 999,250 RCFT,CNL :999.750 GR.CNL 3.551 '999,250 '999,250 '999,250 '999.250 '999,250 '999.250 3 84 -999 -999 -999 -999 -999 048 IbM DIL 313 TENS,FDC 250 FFDC,FDf 250 CALI'FDC 250 250 RCFT,CNL 250 GR,CNL 3 139 -999 250 =999 250 -999 250 2999,250 999;250 -999 250 3.46~ ILm .DIL 112 500 TENS" ' ~['3C -999 250 FFDC FDC -999 250 C. LI FDC -999 250 TNPH CNL -999 250 RCFT,CNL -g9c~ 250 3.435 ~999,250 2999'250 999,250 '999'250 '999,250 '999~250 3 125 -999 250 250 250 I L ' [) C FFDC FDC C../%L I FDC I {PM CNL RCFT CNL GR ~ .Ci~b . 3,387 9991250 '999,250 '999;250 '999,250 '999~250 '999;250 2 -999 -999 -999 -999 27'7 IL~.DIL 625 T~N$,FDC 250FFDC~FDC 250 C~LI,FOC 250 TgPH.CNL 250 RCFT,CNL 250 GR~CNL 2.410 -999,250 -999,250 -999;250 -999'250 -999;250 '999~250 LIS Tape verfficat~o, IistJnq $cblumberqer AlasKa CowputlDo Center TF~.~S.CSG -9o9.250 GR.CSG -999 DFPT. 5800.000 TENS.DIL 4112 SFLt! DiL 2.184 SP,DIb ~28 DD~{I'FDC. -999.250 .... DHQ~.F[JC -~99 NFDC.FDC -999,250 RNFD FDC -999 G~"FDC -999.~50 TENS~ C~.~L '999 T~R~,C)~L -999 250 NPOR CNb '999 RT~P,C~b -909~250 CNTC~CNL -99~ TFNS,CSG -999,250 GR,CSG '999 DEPT. 5700.000 TE~S.DIh SFLU.DiL 1,773 SP.DIL DPH! . FI)C -999. 250 RHOB. FDC - . FDC NFDC.FDC 909.250 nNFD, "N GR,FDC -999 250 TENS,L b TN~A.C~iL -909:250 ~]POR,CNL RTNP.CML -999,250 CNTC.CNb TFNS.CSC -999.250 GR.CSG 000 TENS.DIL 567 SP,DIL 250 RHOB.FDC 250 RI~FD.FDC 250 TENS,C~L 250 ~4POR,C~I, 250 CNTC.CMb 250 GR,CSG DFpT. 5600 SFbU,DIL 1 DPHI.FDC -999 NVD~,FDC -999 G ,FDC -999 TNR~ CNb -999 RT~'CN! -999 TFNS'CSG -999. 4128 -28 -999 -999 -999 -999 -999 -999 DFPT 5500, sFLU~DII, 2, DD[~I FDC -999, NFDC'FDC -999 GR,FDC -999, T~.A,CNL '999. RTN~ CNL "999, TE~S' .CSG -999' 4070 -23 -999 -999 -999 -999 -999 -999 000 TENS, D. IL 40.574, 679 SP.!7;'!L, 2 ~ . PDC 9, -99 250 ,, ~,~Fi~. [;'DC -qqg. ...... ,, ,,b '999, MPOR', kib -999, 250 CN_C,C~JL -999, 250 GR.CSG -999, DFPT, 5400,000 TE~IS,DIL SFbU,D.IL 3,314 SP,DIL [)P[~.T, FDC -999,250 RHOB.FDC NFDC,FDC -999.250 RNFD,FDC GR.FDC -999 250 TENS,CNL ~POR CNb TNR~,CNb '999~250 C RTNR~CNL -999,250 NTC.CNL TFNS.CSG -999,250 GR.CSG 13:73 DFPT. 5300, $ F L, U . D I {.~ 3 , DPH]' ,FDC -999, NFDC. Fi)C -999, 'P F~C '999, G R. TNR ;CNL -999, TFNS,CSG -9~9, 3944 -999 "999 -999 -999 -999 -999 000 T E N ~. L, I L 4010 250 RHOB,FDC ~g~) 250 R~'~FO F' . ~. DC -999 2.0 TENS,C gL ,,999 250 NpOR ~ C~,~L -99g 250 CNTC, C~' L -999 250 GR. CS(; -999 ,25O .250 .250 ,250 ,2bO .250 ,250 .000 ,2~1 ,250 ,250 :250 25O ,250 ,206 .250 250 250 50 ,250 000 03.1. 250 250 250 250 250 250 000 781 ~50 250 000 313 250 250 250 250 2 0 2_50 ILD,DIh GR,DIL DRHO,FDC ~f'FD,FDC NPHi,CWL PCNT.C~L CFTC,CML II.D,DIL GR,DIL DR~O.FDC PFF[>.FDC NPH1,CML ~CNI~,CML CFTC. ILO, GR DIG RFFt~ NPHi C,~ .[, ..CMl C~L CFTC PAGE: 9 1.985 152 750 -999:250 -999,250 -999,250 -999,250 -999.~50 ILM.DIL TENS,FDC FFDC,FDC C~LI.FDC T~]PH'CkL RCFT,C~L GR.CNL 1.984 -999.250 -999.250 -999 250 '999i250 '999250 -999 250 1,740 11.5 168 -999 250 -999 250 -999 250 -ggg 250 -999,250 Ibm.DIL TENS,FDC FFDC.FDC CAbI.FDC TNPH,CN[, RCFT,CNL GR.CNL I 751 -999:250 -999,250 -999.250 -999 250 -999:250 -999.250 1 110 -999 -999 -999 -999 -999 851. ILM.DIL 375 TENS FDC 250 FFDC:FDC 250 C.~LI FDC 250 TNPH,CNL 250 RC.. T, F C N I~ 250 GR.CNL 1,831 -9gg~250 -999,250 -999,250 -999;250 -999,250 -999'250 2 85 -999 -999 -999 -999 -999 620 ILM,DIL 81.3TENS~FDC 250 FFDC,FDC 250 CALI.FDC 250 TNPH,CNL 250 RCFT.CNL 250 GR,CNb 2,585 '999'250 999,250 999,250 "999,250 '999;250 '999'250 3 134 'gg9 -999 -999 414 I 'L m, D I L 500 TENS.FOC .250 FPDC~FDC ' FDC CALI, 250 TMPM. CML 250 RCFT,CNL 250 GR.CNL . 3,471 .999,250 2999,250 ~999,250 2999;250 999"250 -9992250 3 1.03 -999 -999 -999 ,652 ,500 ,250 FFDC ~50 CAL! 250 TNPH 25O RCFT 250 GR OIL 3,687 FDC -999. 250 FDC '999,250 POe '999,250 CML :9991250 250 C~.g 2999 ' '5' CNL 999:, 2 0 BIS Ta~e ver~ifIcotl, on I,istlmq $chlunberge~r AlasKa ComputlnO Center DEFT. 5200,000 TENS,OIL SFLI!. DiL 2. 567 SP, D1L DPH.T,FDC -999.250 RHOD,FDC NFDC,V[)C -999,250 ~NFD,FEC G~,FDC '999 250 TENS,CMO TNR~ ' C~,~L '999:250 ~JP~R.CUL RTNP,CNL '999.250 CNTC,CNL TFNS, CSG -999,250 GR, CSG DFPT. 5100.000 TEN$.D)L SFLU, DI [, 3. 006 SP, D!L DDHI',FDC -999,250 RHOB.FDC NFDC.F!)C -999.250 RNFD.FDC G~.FDC -999.250 TE~$,CNL TNR~,CNL -999 250 NPOR,CNL RT[qP.CNL -9o9i250 C~TC. C~;L TEI~S,CSG 999'250 GR,CSG DFPT 5o00,000 TENS,DIL SFi.:!~.' D1 b 2,789 SP, DI b DPHI,FDC 999,250 RHOB, f'DC NF[)C.FDC 2999.250 RNFD.FDC GR,FDC -999,250 TENS,CML TNRA.CNL -999.250 NPOR,CNL RTNP C~[, 999,250 CNTC,CNL ·-,,,>, CS(; :909,250 GR' CSG DEFT. z~900,O00 TEN'S.DIb SFLU. ~IL 2,512 SP,DIL DDHI.vDC -999,250 RHOB,FDC NFDC.FDC -999,250 RNFO,~IC GP,FDC -999.250 TENS,C~b TNR~,Cbtb '999,250 ' "' CSG -999,250 GR,CSG DEPT SFLU N~'= DC T.NRA RT NP TFNS ,DIL , F[.,C ,FDC .FDC C N L , C,.q. G 4800,?00 2, 63 '999 250 -999 250 -999 250 -999 25O -999 250 -999 250 4700 000 2 866 -999 250 -999 250 -999 250 -999,250 -999,250 -999,250 TENS SP R HOB RNFD TENS N p 0 R CNTC . DIL , D ! h , FPC ,FDC , Cr'~b , C~L .CSG 20-AOG-'I98g 13:23 PAGEt 10 3Zj[O 000 iLO.Olb 0~250 GR.DIL -999.2~0 DRHO,FDC 'g9g,?50 PFFD,F~C '999,2b0 NPHi,CNL -099.750. RCNT.Ct~L -999,250 CFTC.CML -ggg.2bO 3700. -4~ -999 -999 -g99 -999 -q99 -999, 36~4 -48 -999 -999 -999 -999 -999 -999 3684, -50 -999 -999 -999 'g99 -999 49 999 999 -999 -999 -999 -999 3314, '49, '999. -999, '99g, '999, -999. -999, 2,667 104.~13 99.250 999.250 999 ~50 IL~,D1L 'rE~s FDC FFDCiFDC CALI FDC TNPH.CNI~ RCFT.CNL GR,CNL 000 ILD,DII~ 2 53! GR,OIL 89 250 DRHO.FDC -999 250 RFFD,FDC -999 250 ~.}PHI,CNL -999 250 RCNT,CNL -999 250 CFTC.CNL -g9~ 25O 848 ILM.DIL 500 TEN$,FDC 250 FFDC,FDC 250 CAbI.FDC 250 TMPH.CNL 250 RCFT.CNL 250 GR.CNL 000 ILD,DIL 3 176 ILN,DIL 250 GR.DIL 99'.875 TENS,FDC 250 DRHO~FDC -999~ 250 FFDC,FDC 250 ~FFD,FDC -999.250 CALI,FDC 250 NPHA,CNL -999,250 "NJ PH,CNL 9.50 gCNT,C~L -099,9.50 RCFT.CNL 250 CFTC.CML -999.250 GR,CNL 25O 000 250 5O ,250 25O 25O ILD,O!L 2 ,606 II.,~ DIL GR,DIb !13 250 TEN~,, lOC DRHO. FDC -999 .250 FFDC, ~ DC FFO,FDC -.999 250 CALI FDC [~C.~'i,CNL -999: '25(.') RCFT,CNL CFTC. C%~b -999 250 GR,CNL 000 ILD OI~ :~,758 !LM,DIL 281 GR DI 9 .438 TENS'FDC 250 DRHO FDC -999,250 FFDC,FDC 250 RFFD MDC -999.250 CALI.FDC 250 NPHI,CNb -999,25( rNFu CML 990 2so -9 .2so 250 . 000 ILD. [}IL 250 GR DI L 250 DRN'O FOG 250 RFFD FDC 250 NPHI CNL 250 RCNT 'N 250 CFTC C~'M,b 250 3 04I ILM,DIL 999,250 F DC FDC 999 250 9992 . 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'999,250 TENS SP RNFD TENS CMTC TENS SP NPOR C N TC GR TENS SP TENS NPOR CNTC . DIL , D I I,, ~'"DC ~ ~ b .CSG iDIL D I L ,CNL ' C N L ,C~tL , CSG .DIL DIL FDC .FDC CNL cCN b N L CSG 20-At..!G-19~9 13:23 PAGE~ 11 3~90.000 ILO.DIL 55.281 GR.DIL -999,250 DRNO.FDC -999,250 RFFO.FDC -999.250 ~PHI CNL -99q.~50 RCNT:CNL C .' CNL -999.2b0· _.FTC, 3.439 91.000 -999 250 , -999,250 -999.250 -~99.250 -999.250 !LM.DIL TE~S,FDC FFDC.FDC CALI.FDC TNPH,CNL RCFT,CNL GR,CNL 3.390 -999,250 -999,250 -999.250 -999.250 -q99,250 -999,250 3280.000 !I,D,OIL 3,591 -53,2~1 G¢.OIh 109,375 -999,~50 DRNO,FDC -999.250 ~999,250 RFFD FDC 999.250 999,P50 ~PHI:CNL -999,~b0 RCNT.CN5 -999 250 .... CNL -ggg~50 '999,250 CFTC,. '999,250 IL~.DIL TENS.FDC FFDC.FDC CALI.FOC TNPH,CNL RCFT,CNL G~,CNL 3.540 '999 250 '999 250 '999 250 "999 250 '999 250 '999 250 80,OoO ILD,OIb 3 3!55,000 GR,i.)IL 89 -099,250 DRHO FDC -999 999,~50 ~FFD FDC -999 :999,2b0 NPHI CNb -999 -999, bO2 RCNT CNL -999 -999,~50 C' ' -999, 50 .~TC,CNL -999 053 I[,~ DiL 125 TFNS:FDC 250 FFDC,FDC 250 CALI,FDC 250 TNPH.CNL 250 RCFT.CNL 250 GR,CNL 2,863 '999,250 "99~,250 -99 .250 -999,250 '999.250 -999.250 i 70,000 ILD.OIb 3 · 53,750 ~R,DIL 106 999,250 DR O,FDC -999 -999,2b0 PFF ~CC 999 -999,250 ~PN :C~>L' -999 -99g 250 ~' ':" "'N' -~9~' CNI,C ~ 999 ,25o C TC : , 999 -999,2b0 056 II..,U.DIL 38 TEI~$,FDC 50 FFDC,FDC 250 CA. LI,FDC ~50 TNPH.CNL 2 936 '999 250 '999 250 "999 '999 '999 '999 UOI , '' " roc ~bO 250 RFF[:),FDC '999 250 CALI.FDC 250. ~r,,a~ur~,CNb -999 250 T~PI~)CNL '9~9, 250 ~C~T' C~,L -999 250 RCFT.C~L '999; 50 CFTC.CNL -999,250 GR,CNL -999,250 5O 3060 -57 -999 -999 -999 -999 -999 -999 0 0 0 I L [) . D ! L 3 ~50 D~HO'FDC 250 RFFO,FDC -999 250 NPMI . CML -099 250 '" ~u,~ z , ~..~ '999 250 CFTC.CNL -999 440 IL~,DIL 3.391 6~5 ~.RN~ ~ ~S,FDC ~999,250 250 FFDC,FDC ,.999;250 250 ~ALI.FDC -999,250 250 ~NPH,CNL -999~250 250 RCFT,CNL -999'~50 250 GR,CNL -999,250 IIS 1'ape Verification I, istJnq Schlumbcrner AlasKa Computlr~o Center 20-AbG-] 999 !3:23 P~GEI 12 DFPT. 4000,000 T~N$.OIb SFLU. DIL 3,056 SP, bi L DPHI' .FDC -999,250 RHOB,FDC NFDC.FDC -999.250 ~F~FD, FDC G~ FDC -'g~ 250 TEN6,C~b TNR~[CNL -999,250 hPOP, C~.~L RTNP.C[';L -999,250 CNTC,CNb TFNS. CSG -909. 250 GR, CSG DEFT, 3900.000 TENS.[>~b SFLi! DiL 3.009 SP.DIL DPHI'FDC. '999,250 ~HOB, FDC NFDC,FDC '999,250 RNFD FDC GP,FDC -999.250 TE~S~CNL TNR~.CNL -~99,250 NP~R.CNL RTNP.CNL -999.250 CNTC.C~L TENS.CSG -999,250 GR,CSG D~PT, 3800,000 TENb,DIb SFL!].D!L 3.083 SP.DIb 'DPHI,FI)C -999,250 RHOB,FDC NF'DC.PDC -999,250 RNFD,FDC GR,FDC ~999,250 TNR~ CNL '999,250 ~]POR,CNL RTN~' '~' CNL TFNs,CNL 999.250 C.4TC, ,CSG ~999.~50 GR.CSG DEPT. 3700.000 TENS,DI.L S~ L~, DIL 4, ogo SP, Ii)lb DvH! 'FDC -999,250 ~HOB;FDC N' ~';,DC,FDC" -999,250 ~NFD.FDC G~.FDC '999,250 .FENS ;C~L TNR~,CNL -999,250 NPOR,CNL ~TN~,CNL -9~9.250 C~TC. Ct3L ~FNS ~CSG -999,250 (;R, CSG DEPT 3600,000 TENS · . 2,784 SP SFL!!~DIL DPHI'.FDC 999,250 RBOB NF[>C.FDC -909.250 RNFD , G~ FDC 999,250 TENS ..., 9q9.250 NPOR RTNR CML -99 ,250 C~TC TF~S~CSC -99. ~2509 GR 3500.000 40!O -999250 -999250 -999 250 -999250 -999250 -999 250 TENS SP RHOB RNFD TEUS GR. o I b DI b FDC EDC CNb D IL D ! L FDC C N L CNL CSG 2~34,0u0 ILI?.OIt, 3 25.3 54,281 GR'OIL !i0]438 -999.2b0 DRhO.FBC -099,2b~ PFFD'FDC .90,250 '999.2b0 NPHi,CNL -999,2b0 -999.~b0 PCNT,C~gL -999.250 -999.250 CPTC.CN~ -999.250 -~9q'250 IL~.DIL TENS FDC FFDC FDC CALl FDC TNPH CNL RCFT CML GR.CNL 2854 000 ILD.DIL -bg:500 (;R,DIL -ggg.~bO DRHO.FDC -999,250 ~FFD.FDC -999.~50 NPHI.CNL '999.250 RCNT,CN~ -999,~50 CFTC.CML -099.~50 6 77 -999 -999 -999 -999 -999 541. ILN.DIL 438 TENS,FDC 250 FFDC.FDC 250 CALI.FDC 250 7~PH.CNL 250 RCFT.CNL 250 GR.CdL 2750 nO0 1LO,D'Ih -61~250 GR DIb -999,250 DRHO~FDC -999.~50 RFFD.FDC -999,260 NPHI,CNL -999,250 RCNT.C~L -999,~b0 CFTC.CNL -999. bO 3 643 IL~.DIL ~09,875 TENS.FDC -999,250 FFDC,FDC -999.250 CALI.FDC -999 ~50 TNPH,CNL -999~250 RCFT.CNL -999,250 GR,CNL 2620,000 IL~,DIL -999;250 RFFD[FDC 'CNL -g99*250 ~CNTC~D"N" -999,.o .... 4.620 !L~.DIL 98,250 ~E~S,~DC -999.~50 FFDC;[DC -9~9.250 CALI,~DC -999,~50 TNPH.CNL -999,250 RCFT,CNL -999,250 GR.CNL 2~5 999; -999, -999, '999, '999, 000 !LD DIL 3648 ,,IL~,DIL ' ' 3'15 'fENS ;FDC 503: GR,DI~ 99,250 ?~FDC, FDC 250 DR~D, ~TDC 999, 250 [~FFD, FDC '-999.250 CAL!,FDC 50 : RC~TiCNL -999~250 RCFTiCNL 2SO C~ TC,C,.~u -999,250 GR,CNL · D. 244:4,000 !1,~. DIL 4 -b4,Sb3 GR,DIL ,99q,250 NPHI~C,,.]L "999 2~0 B( .... T C~L -999 'q99,250 CF~C,CNb '999 ~ 0 '999.2b- 203 IEM, DIL 063 TENS FDC 250 FFDC FDC 50 RCFT CNL .~ 50 G~ CNL 3,017 '999.250 '999,250 '999,250 '999.250 2999,250 999,250 5119 -999250 -999250 -999250 -999250 -999250 -999250 35O5 -9991250 -999,250 -999.250 -999,250 -999'250 -999,250 . 4,426 999,250 -999'250 -999,250 '999.250 999,250 999,250 3 318 -999 250 ~ 5" · .99920 -999 250 ~5 2 0 250 -999,250 3984 '5 20 250 2so 9, 9,250 -999,250 -999,250 LIS Tame Verificat. Jon Listing Schlumberger AlaSKa Computing Center DEPT. 3400.000 TENS.DIL $~'LI!. DIL 3,904 SP, DIL DPHI ,FDC -999,250 RHF]B, FDC NFDC.FDC -999.250 N~FD,FDC GP,FDC -999.250 TENS.CN~, TNR~.C~JL -9Q9,250 NPOM.CNL RTNP,Ci~L -999,250 C{4TC.CNL TFNS. CSG 2344. 000 GR.CSG DEPT, 3300.000 TENS.I>IL SFLU,DIL. -999,250 SP. DIL DPHT.FDC -999.250 PHOB.FDC NFDC.FDC ,-999,250 RNFO,f. DC GF.FDC 999.250 TENS.CML TNRA.CNL -999.250 NPOR,CNL RTNR.CNL -9Q9.250 CNTC.CNL TFNS.CSG 2424.000 GR.CSG DEPT, 3200,000 TENS.DID SFLI). DI L -999,250 SP. DIL DPH!,FDC -999 250 RHOB FDC NFDC,FDC -999~250 ~NFD FBC GP.FDC -999,250 TENS CML TNR ~, (7~L -999.250 UPOR C~L TENS.CS~ z~30. 000 ~'.CSG. D.F. PT, SFLU * DIL PHT FDC FDC FDC GP FDC TNR~ CML TFN~,t 20-li]G-1. g89 13:23 2450,0U0 II,D. l).[L 4 968 -999,250 DRHO,FDC 999,250 -999,~b0 PFFD,FDC 2999.250 -999.~50 NPHI,CNL -999,~b0 -999.~50 PCNT.CNL -999,250 -999,250 CFTC,CNg -999.~50 77,~1~ -999.~50 ILD,DIL -999,2.50 GR,DIL -999.~50 DRHO.FDC -999,250 RFFD.FDC -999.250 NPHI,CNL -999,250 ~CNT.CNL -999,~b0 CFTC,CNg 49,531 2999,250 ILD,i3IL 999,250 GR.DIL -999,250 DRHO,FDC -999,~50 RFFD.FDC '999,250 NPHI,CNL -999.250 RCNT,CNL -999,~50 ~" 5~.813 3100,000 TENS,DIL -999 DIB -999 50 SP.,D '999 -999, 50 PHOB,~ .C -909, · 0 'F .... D" ~999,25. R~..D,~ C ~999 250 TEMS'CNL -990 '999,.5 -999,2.0 NPOR.,CNL -999 -999,250 CI'~TC,CMI.. -999 2310,0o0 GR,CSG 45 ~000 000 TENS,BIb 2999' ,250 SP.DIL ' 999,250 R}iOO,'~Dr -999,250 RNFD,~D~ 999,250 MPOR'CNL. -999,250 CNTC,CNL 2240,000 GR.CSG DEPT, I 7900,000 SFLU,D1 .~ -999,250 SP,DIL DPHT~FDC -999.250 RHOB,FDC FDC NFDC,FDC -999,250 RNFD, G~.FDC -999,250 TNR~,CN[~ -999 50 RTN~,CNL -909~~.50 CNTC,C~L TE''~t~$ ~CSG 2200,000 GR,CSG 250 ILD,DIL 250 GR,DIL ~50 P'" FDC 250 ..~FO, 250 NPHI C iiJ i] 250 ~CNT' " , CML 909 '999, 42, -999 -999 -999 -999 -999 -999 250 CFTC.CML 750 250 I LD GH, Dig ~0) DRHO FDC 250 [~ FFt), ~DC 250 RCNT,Cc~ 250 C F T 938 P A (; E: 13 IL~.DIL TENS.FDC FFDC.FDC CALI,FDC TNPH.CNL RCFT.CNL GR,CNL 4,b34 '999.250 '999,250 '999,250 '999.250 '999,250 '999,250 '999,250 '999 250 -999i250 -999 250 -999 250 999 250 29991250 IL~,DIL TENS,FDC FFDC,FDC CALI,FDC TMPH,CNL RCFT,CNL GR,CNL -999 -999 -999 -999 -999 -999 -999 250 250 250 250 250 250 250 -999 -99~ -999 -999 -999 -999 -999 250 IL~.DIL 250 TENS,FOC w" FDC 250 F..DC, 250 C~I,,I.~DC 250 TNPH,CNL 250 RCFT.CNL 250 GR,CNL -999 250 -999 250 '999 250 '999 250 '999 250 -999 250 -999,250 250 '999, . ''"'S -999,250 -999 .... 50 ~999, -:999, .,99~,250 '999,250 GR OIL FDC FDC FDC CML CML CML -999.250 2999,250 999.250 999,250 999,250 ~'999,250 '999.250 -999,250 I~M DIL -999i250 TENS~FDC -999,~50 FFDC.FDC -999,~50 C.ALI,FDC -999~ 999,250 GR,CNL -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 250 250 ~999 250 -999 250 -999 250 -999 250 IL~,DIL ~ENS,FDC ~'FDC.FDC ~ALI,FDC YNPH~CNL C~'....'.CNL G~.CNL -999 -999 -999 -999 -999 -999 -999 250 25O 25O 25O 25O 250 250 LIS Ta~e Veri[.icatlon Llstln(] Scblumherqer Alaska Computlna Center' 20-t~bG- 1. ~:9 13:23 14 5VLU ,D] L -9U9,250 DPHI.FDC ~999 250 ~OB, F[)C NFDC,FDC - 999:250 P'~FD. FDC G~.FDC -999,250 TENS,CML ~N~ .CML -999,250 R?NR C?~[, -999.250 CNTC.CNL TFb~S ' , CSG ~ 100,000 ~R,CSG DV[)T. 2700.000 SFLU DIL -999.250 SP,DIL NFDC.FDC 99.250 RNFD,FDC G~.FDC -999.250 TENS.CML T~RA CML -999.250 NPOR,C~iL RTNP~C~L -999.250 CNTC.CNL TFNS,CSG 2060.000 GR.CSG 2~00,000 -999,250 -999,250 -999.250 -999 250 -999 250 -999 250 7015 000 2500.000 -999,250 -999 250 "999 -999 50 9:~9 t965 000 2400,000 "999,250 "9q9 250 -999'250 '999,250 '999.250 '999,250 1935,000 2300,000 -999'250 -999~250 -999,250 '999,250 "999,250 -999.250 1900,000 TENS,DIL SP,gIb RHOB.FDC RNFD,FDC TENS,CML ~POR.CNL CNTC,CNL GR 's TENS.DIL RNFD,FDC TENS.CML MPOR,CML CNTC,CNL GR,CSG TENS, bi L RH. OB, FDC RNFD.FDC TEN$,CNb CNTC,C~b GR'CSG TENS,DIL SP.DIb RHDB,FDC RNF~,FDC TENG.CNL HPOR.CNL CNTC,CNL GR,CSG -999.~b0 IL~.DIL -99917b0 GR'91i, -999 250 DRHO FDC i~t ~ · _99,250 PFFi),FDC -999,290 NP~i,CNL -099,~50 PCNT.CNL -999,250 CFTC,CNb 44,563 -999,250 II, D.I)Ib -999,2b0 GR.DIb -999.250 DRWO,FDC -999 2bO RFFD,FDC -999'~50. MPHI,CML_ -999,~b0 RCNT,CN~ -999'~b0 CFTC,C~L 46,0~3 -999 -999 -999 -999 -999 -999 -999, 56, -999 999 -999 -999 45 -999 -999 -999 -999 -999 -999 -999 42 -99q -999 -999 -99~ -999 -999 5~ -999.2b0 -999 250 -999 250 -999 250 -999 250 -999 ~50 !bM DIL TEKSiFDC FFDC.FDC CALI,FDC TNPM.CNL RCFT'C~L GR,C~L -999 -999 -999 -999 -~99 -999 -999 250 250 25O 250 25O 250 250 ILM.DIL TENS,FDC FFDC.FDC CALI,FDC TMPH.CNI~ ~CFT,CNL GR.CNL 25(') ILD,DIb 250 GR,DIL 250 DRH[J,FDC 250 RFFD,FDC 250 NPHI,CNb 250 PC~IT, C~'L 250 CFTC.C 'b ~75 -999,250 -999.250 -999 250 -999 250 '999 250 -999 250 -999 IL~,DiL TENS,FDC FFDC FDC CALI~FDC ' 'H CML fNP., RCFT.CNL GR.CNL ,250 I~D,Plb ,250 GR ,FDC ,250 ~250 N~MI,CNL ,250 ~CNT,CNL ,250 CFTC.CML ,938 -999 250 ILM.DIL -999' ,990,250 TENS,FDC .250 FFDC~FDC -999 250 CALI.,FDC -999:250 TNPH~CNL ~999,250 RCFT,CNL -9~9.250 GRiCNL 250 ILD GR,DIL -999'250 TENS,FDC 50 ,DIL -999,250 IL~,DIL 50 'DRHO,['pC -99~,250 FFDC;FDC 250 NP~!,C~L ~999 250 ~PH.CNL 250 RC~.}T.CNL 999,~50 RC'FT'~CNL 250 CFTC,CNb -999.250 GR,CNL 719 250 ILD,DIL -999 250 ~(;R*DIL -999 250 DRMO'FDC '999 250 RFFD,FDC '999 250 MPH!,CNL -999 250 RCNT,CMb -,999 25o CFWC,C~L 750 250 RCFT,CNL 250 GR,CNL ~999,250 999,250 :999,250 999,250 -999,250 -999.250 -999,~50 -999 250 -999 250 -999 250 -999 250 -999 ~50 -999 250 -999 250 -99 250 '99~,250 "99 ,250 "999,250 '999,250 '999,250 -999 250 -999 250 -999 250 -999 250 -999 ~50 2999 250 999 250 -999,250 -999,250 -999,~50 -999"250 -999,250 -999,250 999,250 -999 250 "999.250 '999.250 ,250 .250 -999 250 -999 250 LIS Tame veriflc~tion Schlumberqer AlasKa Computind Center DEPT. 2200.000 TE;0S,DIL .SFI.U. [iii. -9q9,250 SP' [;1L DPhl .FDC '999,250 RHOB,FDC NFDC. F'[)C -999.250 ~NFD.FPC G~,FDC -999,250 TENS,C~L TNR~. C~[.. '999.250 NP RTNP.CI~b -999,250 CNTC,CNb TF['~S, CSG 1 840,000 GR.CSG DFP?, 2100,000 TENS,DYL SFLU DIL 2999,250 S ' DID DPH!'FDC, 999,250. RHOB,FDC NFDC.FDC -999.250 RNFD.FDC GP.FDC '999.250 TENS.CNL TNRA,CNL '999,250 NPO~,CNb RTs~.C~}L -999.250 CNTC,CNL TENS.CSG 1~15,000 GR,CSG DEPT, 2000.000 TENS,DIL SwbU.DI[, 9~9,250 SP.DIb DDHI.FDC :999,250 RHOB.FDC NFDC,FDC -9g9.250 PNFD.FDC - 250 TENS GR,FDC 999, TERA,C~L -9~g,250 NPOR,C~L RTNP,CNL 999,250 CNTC,CNh TFNS.CSG ~725i000 ~R.CSG 1.3:2.3 '099,250 ILD.DIL -099,~50 GR,D.!b '999'2b0 DRHO,FDC -~99,250 RFFD,FDC -999,250 NPMI,CNL -999~2b0 PCNT,CNL -999.2b0 CF~C,CNL q~i7bO -g99.250 ILD.t3!b :g99,250 GR.D!L 999.~50 DRHO.FDC '999,250 RFFO,FDC -999.250 NPHI.CNb -g99,250 RCNT.C~L -999.250 CFTC.CNL 39.53~ '99g, -q9g. '999 -999 '999 -999 "999 40 1900,000 TENS.DIL '999, ~999,250 SP,DIL '999, 999.250 EMOB;FDC -Qgg. -999 50 '~° ' '99 TEJo.CNL ~ 50 C,. T 1755,000 GR,CSG 45 PAGE: 15 ~PT, IBO0,~O0 TENS,DIL FLU2DIL -999. 50 SP,OlL NFDO,PDC -999, , GP,FDC -999 250 TENS, 9~NL TNR~'CNL -999 250 MPGR.CML RT~P,CNL -999 250 NTC.CNL TF~S. C~{G 1670 000 GR;CSG DEFT, .1700.000 TENS.DIb SFLI! ~ DI 1, :999,~ 250 SP. DIL DPt{T, FDC 999; 250 R}{OB. FDC NFD~,FDC '999,250 RNFD,FDC G .FDC -999,250 TENS. C~SL TNR~,CNL -999,250 NPOR ~ · C ~,; I,, -9~9 ', 250 CN-~'rC [ ' CNb TENS, CSG 1615,000 GR.CSG -99g, -999, -999' -999; -999, '999, -999 -999, -999, "999, -999. ~qgg, 999 250 :99o: so -999 250 -99g 250 -999 250 -999 -999 IL~.DIL ~ENS FDC FFDC,FDC CALI,FDC TNPH.CNL ~CFT,CNL GR.CNL -99g 250 -999 250 -999 ~50 -999 250 -999 25O ~999 250 999~250 IL~.DIL TENS,FDC FFDC.FDC CALI,FDC TNPH.CNL RCFT,CNL GR.CNL 250 ILD,DIb -999 250 GR.DIL -999 250 DRHU,FDC -999 ~50 RFFD.FDC -999 250 NPH.I.CNh -999 ~50 ~CNT.C~L -999. 250 CFTC.CNb -999. 250 IL~.DIL ~50 TENS.FDC 250 FFDC,FDC 250 CALI.FDC 250 TNPU,CNL 250 RCFT.CNL 250 GR,CNL 250 IL..,, ' P DIb 999,250 II~.DIL ~50 DR~IQ,FDC ~ 99, ~bO RFFD,FO~ -99g 250 ~ALI.FOC 50 M9HI.CN' -999:250 ~NPH.CNL 250 RCN'T,~L -999,250 RCFT,CNL ~50 CFTC. NL -g99.250 qb9 250 II, D, D!b -999. 250 IL~,DIL 250 GR'DiL -999,250 TENS,FDC 250 [)~HO ~DC -999,25 .. ~'FDC, FDC 250 ~FFD.FDC -999; 250 CAL1.FDC 250 ~PH1 ,gNl,, '999.250 TNPM,CNL 250 RCNT,C~t, -999;250 RCF~iCNL 250 CFTC,C~b -999.250 GR.Ch.L 000 250 ILD,DIL 25(} GR, DI.~ 250 DRHO'FDC '~'' .... FDC 250 ~FD,cNL 25O NP~[. 200 R C..,,~ ~, CNE 'o ' cui, 25 ,. CFTC, 7~ -999.250 -999,~50 TENS 'g99*250FFDC ~5 CALl '999.~ 0 -999.''0 ..... ~5. RC~'T '999.250 '999.250 '999.250 '999 250 '999~250 '999 250 '999:250 '999,250 '999.250 ~999,250 999,250 '999,250 '999.250 :999'250 999,250 '999 250 '999 250 -999 250 -999 250 2999 250 999 250 -999 250 '999,250 "999'250 "999.250 "999,2.50 '999,250 ,250 2 0 .-999 ' 5 999 250 250 250 -999 250 DIL '999,250 FDC -999,~50 FDC '999'250 FDC ~999,250 iCNL 999'250 CML -999,250 CNL -999,250 LIS Ta~e k. erif. ic. atior~ ~,istln9 8chlUm, berqer ~,lasKa Computfng Cea, Let D[PT, 1500,000 TENS,DIL 6FI,I! [)II., -999,250 SP,DIh DPHIiFDC -999.250 ~HOB,F[,C NFDC,FDC -909,250 RNFD,FDC GP.FDC -9~9,250 TFNS,C~Jb T~RA, CN[, -999,250 NPOR, CNh RTN~.CNL -999.250 CNTC. (]~.~L TENS .CSG 1505. 000 O~ .CSG DFPT, l. 400. 000 SFLU, DiI, -999,250 DPHI, ~DC -999. 250 NFDC, FDC -999,250 GR. FDC -999. 250 Tk~R~. CML -999,250 RTNR, CNL -999. 250 TFNS,CSG ~ 460,000 1300 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999~250 1400,000 -999 50 -999,250 -999~250 -999,250 -999,250 ~999,250 _330,000 1100,000 -999,250 -999,250 ~999~250 -9Q9.250 -999,250 '999,~50 1285.000 TENS.DIL SP,DIL RHOB FDC ~VD FDC NP~R CNTC CNL GR CSG TENS,DIL SP.DIL ~i~FD DC 2 E.. S, CNL NPOR.CNL CNTC,CNU GR'CSG TENS.DIL SP,DIL ~H:OB,FDC PNFD FDC # TEN$,CNL NPOR.C~L CNTC,C~L GR,CSG 20-~t..iC.-1.989 13:~:.'i -999,250 -999 2bO -q99 250 -999 25O -999 250 -999 250 -999,~50 27.438 II,O,DIL GR,Olb PR~O.FDC RFF'D.VOC NPHI,~L RCNT, , b CFTC,CNL -999,~b0 lLO,Olb -999.2b0 GR,DIb -999,250 DR~O,FDC '990,2b0 RFFD,FDC -999,260 NPHI,CNL -999,250 ~C~T,CUL -999,250 CFTC,CN~ 34,59,~ -09C~ 1250 ILD,DIL -999 2bO GR , '999 · ,,999 ~bO R~:F[,) ~D~' '999 250 NPHIiCN'L -g99250 ~C~T,CNL -999 5o 19,7~9 -999,250 -999,~50 GR DIb 2999,250 PFFD FDC 999,2b0 -999,~50 ~CNT .~,234 250 tLD DIb '999, ,.. -999.~50 GR '999...50 DRHO ~DC "999, RFFD .999~b0 FDC . ..50 NP}.!.I C~tL -999,250 RCt~'T CNL -999,~50 CFTC CNL 26~172 PAGE: 1,6 99,250 .. -999,250 -999~250 :099,~50 ~99,250 -999,250 I.L~'I,D1L TEb;S.FDC FFDC.FDC CALI.VDC THPH,CNL RCFT.CNL GR,CNL '999,250 '999.250 '999,250 '999.250 '999,250 '999.250 '999,250 -999,250 -999,250 -999,250 99~250 -999,250 999,250 IL~.DIL TENS FDC FFDC:FDC C~LI,FDC TNPH.CNL RCFT,CNL GR.CNL '999,250 '999 250 '999 250 '999 250 '999 250 '999 250 '999 250 -g99 250 -999 25O -999 250 -999 250 -999 250 -999 250 -999.250 IL~,DIL TENS.FDC FFDC,FDC CALI.FDC ~NPH.CNL RCFT.CNL GR,CNL -999 250 -999 250 -999 250 -ggg 250 -999 250 -999 250 -999~250 -999 250 ILM.DIL -999' ""' ... 250 "'~ ' I: , DC, 999 25~ CALI,FDC -999'250 TNPH'CNL -999 ~50 HCFT,fNL -999' 250 GR, CNL ~ · -999 1999 999 -999 -999 -999 -999 250 250 25O 250 250 50 -999,250 -999 250 TENS.~DC 250 FFDC,FOC 250 CAL!.FDC r 25D 1. PH,CNL 250 RCFT,CNL -999 ~50 GR,CNL -999 250 -999 250 ~999 250 999 250 -999 ~50 -999 50 -999 250 -o99,~S0 ~'FDC,~ DC '..50 CALl FDC -999,, ~ , -999,~50 T..~PH.CNL -999.250 ~CFT,C~L -999.250 G~.CNL "999 250 -999 250 -999 25O -999 2'50 :999 250 999 2'50 -999 250 [.,IS war>e veri,~ication I,ist. inq Schlumberqer Alaska Computinq Center 20-AOG-l. 989 ].3:2i PAGE: 17 DFPT, 10o0,000 TENS.Dlb SFL{~, blI, -999,250 SP. DI b DP~I FDC -999,250 RilOB. FDC NFDC ~'i)C -909,250 RNFD,FPC GP,FDC -999,250 TE~$,C~'b TNR~,CkL -999,250 NPOR,CNL RTNR. CNI., -999,250 CNTC.CNb TF~S, CSG 1240,000 GR. CSG END OF DATA ** ~999,2b0 iLb,DIL -999.250 99~,~b0 GR,DIL ~ 250 : 99 2~0 DRMO FDC .99:750 ~FFO:FgC -099.250 -999 250 NPHI,CNL -999,25. -999:250 RCNT.CNL -999,250 -999,250 CFTC.CNb -999,2b0 33,53!. '999,250 ILO.OIL '999.250 '999.250 GR,DIL -999 250 -.~99,250 DRH(].FDC -099' -g99,2bO PFFD.FDC -999,250 i 999,250 NPHI.C'NL -999.250 999,250 RCNT,CNL -999,25() .F~C.C~L -g99.~50 999,250 C ~ ~0.344 Ib~,DiL TENS,FDC FFDC,FDC CALI.FDC TNPH,CNL RCFT,CNL GR,CNL IL~.DIL TENS,FDC FFDC,FDC CAbI,FDC THPH,CNL RCFT,CNL GR,CNL '999,250 '999,250 '999.250 '999,250 '999,250 '999.250 '999,250 -999.250 ~999.250 999,250 -999,250 -999.250 -999,250 -999,250 **** F!I.,~ mRAII.,ER **** FILE NA~E : EDIT ,OOl SERVICE : FLIC VERSION : O01A. 02 D~TE : 89/0~/?0 ~AX. REC SIZE : 1.024 FILE TYPE : LO bAST FILE ~ ***~ FILE HEADER **** FIt.,~ NA~E : EDIT S~R¥!CE : FLIC V~RSI[,)N : OO A02 DATF : 89;08/20 MAX REC SIZE : 1024 F%LF TYPE ~ TABI E .IYP , : C0~45 TUNT VALU OEFI FN KUF A, kU~ WN 2~ - 6 well Name N,TI OSA Nat ion STAT ALASKA State or Province COtJN NO~TH oi.,.(), h, FI~ 17!' F6L g 94" FEL tis tape Verif!cat:lon [,istinq 2o-~Lic-lgRa 13:23 PAGE: 18 $chtumberaer AlasKa domputin~ Cen~er T~'! VA[,O DEFI ....................................... ....................... .... ................ .... SECT. t TO~N lOa Ta~nst~ip ENGI ~' I~ KH~t4 Enqineer's Name SP~ 549131 Service Order Number APlN 50-!03-20110 API Serial Number T~R!E TYPE : CURV DEFI DEPT DEPTH CHANNEL qh~E TENS Tension DPHI DensltV Porosity R}~OB P~llk Density D~}{fJ Delta rho FFDC ~ar FDC Count. Rate NFDC Near FDC Count Rate RNFP, Raw ~<lear FDC Count Rate RFFD Raw Far FDC Count Rate CaLT calir~er GR Camma Ray T~NS Temsfom NPHI NEUTRON POROSITY TNPN THERUAL NEUTRON PC~ROSITY I.,D THkR~ L NEUTRON RATIO ~POR NEUTRON POROSITY OUTPUT FROM AN AFPLICATIOM PROGRA~ RCNT RCN~ RC'F~ ~CF~ RTNR RAW THER~AL N~,[.TRUN RATIO CNTC CNTc Gamma RaY ** DA'_A FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** 1 66 0 2 66 0 3 73 88 4 6~ 1 5 ~6 6 73 7 65 [,IS war, e verification [.,istino Schlu~berqer AlasKa ComptltinQ Center PAGE: 19 9 65 !1 66 12 6~ 13 66 14 65 !5 66 t6 66 0 66 11 0 FT 6~ 1 mmmmmmmmmmmmmmmmm*mmmmm ** SET TYPE - CHAN NAiF SERV UMIT SKCVI P AP1 iD ORDER # LOG TYPE ~$ FDH LB 54q131 O0 000 DP"] FDH PU 549131 O0 000 D~Hfi FDH G/C3 549131 O0 RFFD FO!,! C~8 549131 O0 000 CAI~? FDH IM 549131 O0 000 GR FDH GAPI 549131 O0 000 T~NS CN~ Ln 549131 O0 000 ~PH! ~hiH PU 54913I O0 000 ~Np~ ci~p pll 549131 O0 O00 TNR~ CNH 549131 O0 NP~P CN~i PU 549131 O0 0 ~CNT CNH CPS 549131 O0 000 ~CFT Ci~I,i CPS 549131 O0 000 ~TNR 549131 O0 000 ~}TC . . N}4 CPS 549 31 O0 000 cps ooooo ...... APl. CLASS MOD NUMB SAMP E~EM CODE (HEX) 0 2 1 4 O0 000 O0 0 2 ! 1 4 6~ 0000000000 OO 0 2 1 1 4 68 O0 O 2 1 I 4 68 00 0 2 I I 4 6R O0 0 2 1 I 4 68 O0 0 2 1. ~ 4 6 ~ O0 0 2 1 I 4 O0 O 2 1 I 4 6R 00 0 2 1. 1 ~ 6~ 00 0 2 ! I ~ 68 00 0 2 ! O0 O 2 O0 0 ~ i b8 O0 0 oo o 1 00 0 2 1, O0 U 2 uo o ~ ~ 1 O0 0 2 ! 1 4 OoO00OO000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~000000000 0000000000 O0000000OO 0000000000 0000000000 b@ 0000000000 0000000000 08 0000000000 68 0000000000 . ** DATA ** DKPT. DRHO RFFD FDH P H I CN ~! CFT ~,. 8048 399 000B 4836 000 51 951 1749 152 464,109 3674 240~3 42 95 000 DF, Hi ,000 NF~C 606 R ,tN R 625 FDH F D H CN}t C~ ~ 52 427 RHOB.FDH 922 000 95 625 ;~ 958 NPOR.C~H 4 095 1,785 1775 000 3674 000 49 158 1806 786 WaDe Verifl. cation Listinq Schlumberger Alaska Computlnq Center DEFT. 8000,0~)0 TENS,FDH DPHP. FDH O. O~ 6 FFDC, FDH RFFD'WDH 4608.000 CALI.FI)~ ~P~ I. C~.~F~ 52.258 TNPH.C~4H CFTC, CNN 494,156 GR,CNM DFPT. 7800.000 mENS. FDt! DPHO FDH 0,023 FFDC FDH RFFD' FD~q 914 500 CAI..,I ~ FDH NPH. I CNH 42 160 TNPH CNH RrNa: CNH 1.740: 394 RCPT:CNH CFTC,CN~ 525 067 GR,CI'H DEPT. 7700,000 TENS,FDH D~HO,FDH 0,069 FFDC,FD}I RFFD,FDH 1087,000 CAL~,FDH NPHT.CNH 34,827 TNP .CNH RCNT,CNH 2119,979 RCFT.., CNH CFTC.CNN 699. 046 DEPT. 7600,000 TENS,FDH D~.ItO, FDH 0,051 FFDC,PDM RFF~iFD, I 014,00() CALI. F~!4 NP~I,CNg 34,599 TNPii,CNH RCNT;CNH ~039.~7 RCFT.CNH C. !'C,CN~ 77~,747 GR.CNH 20-gO(l-19;~9 13;23 5520,0U0 DPHI,FOH 535,000 NFDC,FDH 11.003 GR 46,6{~7 TNRA~CNH 412,2~2 RTN~.CN~ 99.375 5460,000 DPMI.FDM 440,000 NFDC.FDH 9.695 CR.FD~ 44,123 TNRA,CNM 464.959 RTh'!R.CN}t 9~.1~8 52~B, 540, 9 34 652 97 5532 532 9 32 67! ~9 DEPT 7500,000 TENS,FDH 5.360 D~HO~FDN -0,002 FFDC,FDH 1403 F RFFD .DF1 2746,000 CAI, I ~FDH FDH FDH F D H CNH CNH DEPT. 7400,000 TENS H O,FDH 0,008 FFDC FF~'FDW 121.5.000 CASI NPHI,CbtH 42,~7~ TNPH RCNT,Ct~g ~859,952 RCFT CFTC.C~M 476,339 GR DEPT '130~ 000 RFFD, FDI'{ 150U, 000 NP~{T ', ..m~ 45,374 RCNT '.C?~H 1636,567 CFTC i Ct,3~ 497.712 000 DPHI,FOH 500 ~!FDC.FDM 4~ GR,FDH 179 TNRA.CNH 303 RTNR,C~ 000 DPH1, FDH 500 . ~DC,FDH 414 GR'FDi~i ~4 TNRA C 08o 625 000 000 ~FDC,~Dii 234 936 TNRh,CNH 2 51 RTNR.CN~ ooo 5244.000 DP~I.FDH 640,500 NFDC, KOhl 12,602 GR, FDH [ .' 43,300 !'.iRA, 446.2(3)7 RTNR.CNH 125.50O 52i 000 DPHI ooo r,~Fr'~c, F DH Zi.4~l GR,FDH 41,564 TNRA,CN~ 463,52 ! R'INR,CNH 249;500 PAGEt 20 51.203 927,500 95.625 3.997 4.4'!6 RHOB. FDH RNFD. FDH TENS ,CNFi NPOR,CNH CL'TC.CNM 1,805 171.6.000 5440,000 46,220 1837.201 15,144 598.00n 99,375 3,703 4,113 RHOB.FDH RNFD'FDN TENS.CNH NPOR.CNH CNTC'CNM 2 400 1156:000 5520,000 44 436 1693~126 9.694 574 500 92.188 3,540 3.370 RH(']B.FDH RNf'D,FDH TENS.CNH NP£)R.CN~ CNTC.CNN 2 1099 5460 47 1908 490 000 000 155 773 12 o21 650,500 97,813 3,123 2,972 RHOB,FDM RNFD,FDW TENS,C.NE NPOR.CNH CNTC.CNM 2 1286 528.8 32 2100 452 000 000 490 392 12 633 89 700 RHOB,FDH 00 RNFD,FDE 25 TENS,CNH 104 NPOR CNH 029 CNTC' . .. .CNH 2,441 1239,000 5532'000 34,635 2234,863 39 817 767[500 RNFD.FDH 9~.ooo TEt~S.CN~ '738 · , ~ (~ · 4,8/5 CLT.~,CNH , 1542 5360 47 1670 993 000 000 246 .566 2 5~206 244 39 1760 322 000 000 ioo 78 21 688 249 3 3 503 RHOB,FDH 000 RNFD,FDH "0 " · CNH 50 tENS. 818 MPOR.CNH 565 CNTC.CN~ 2 1301 5212 43 1766 ,295 ,000 000 675 301 tis ~me Yerif~cat~om Listinq Schlumberger Alaska Computinc~ (,enter 2(')-AUG- PAGE: 21 DEPT, 7297.600 TEM$.FOH DPhO.FDU 0.033 RFF~.FD~ 1424.000 CAI,I.FDH NP~I.C~rt 49.873 ~PH.CNH RCb;~T.CN~ 1560.1~4 RCFT 5192,000 DPHI,FDH 692.000 ~3FDC.FDH 10 ~6 GR FOs 405.317 RTNR,CN~ ~97,250 20.269 6~6.500 297.250 4 015 3~792 MHOB.FOH TENS.CNM mPOR.CNH CNTC.CNH 2,31~ 1358.O00 5192,000 49.455 1663,197 ** E~iD UF DATA **** FILE TRAILER **** F!b~ ~iA~E : EDIT .002 SERVICE : FLIC VF~SIOt~ I 00lA02 DATF : 89/08/20 ~X R~C STZE : ~024 FIL~ TYPE ! LO LAST ~II~E : **** TAPE TRAILER SFRViCE NAME : EDIT DATE OPlgl~ : FLIC CnNTitcUA'I. ,ON ~ PPEVIOUS TAPE C~M~ENT : ARCO, KI.}PA~UK, 2K-6, APl ~50-,103-20110 REEL TR~IbE~; **** NAmE EDTT D r : ~9/08/20 ~P];~I~ : ~hIC PREVIOUS REEb ~ ~C~Eb!T : ~RCG, KUPARUK, K-6 APl ~50-103-20~.~0