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191-018
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-17 KUPARUK RIV UNIT 2M-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/06/2024 2M-17 50-103-20150-00-00 191-018-0 W SPT 6005 1910180 3000 2440 2442 2446 2450 140 140 140 140 REQVAR P Sully Sullivan 6/22/2024 Tested to 3000 psi (MAIP) per AIO2C.055 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 2M-17 Inspection Date: Tubing OA Packer Depth 800 3310 3160 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624180246 MITOP000010447 BBL Pumped:3.5 BBL Returned:3.1 Tuesday, August 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO2C.055 James B. Regg Digitally signed by James B. Regg Date: 2024.08.06 09:35:41 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-17 KUPARUK RIV UNIT 2M-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 2M-17 50-103-20150-00-00 191-018-0 W SPT 6005 1910180 3000 2070 2070 2070 2070 180 180 180 180 REQVAR P Lou Laubenstein 6/29/2022 MIT-IA to maximum anticipated injection pressure per AIO 2C.055 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 2M-17 Inspection Date: Tubing OA Packer Depth 715 3310 3200 3180IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220629131028 BBL Pumped:4.3 BBL Returned:4.2 Thursday, July 21, 2022 Page 1 of 1 5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) Q #FRQRFRSKLOOLSVFRP! 6HQW )ULGD\-XQH 30 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW &3$,0,7.580 6,7(676[OV[ $WWDFKPHQWV 0,7.580 6,7(676[OV[ ůůͲ WůĞĂƐĞƐĞĞƚŚĞĂƚƚĂĐŚĞĚϭϬͲϰϮϲĨŽƌŵĨŽƌƚŚĞŶŽŶͲǁŝƚŶĞƐƐĞĚƐŚƵƚŝŶƚĞƐƚƐƉĞƌĨŽƌŵĞĚŽŶϮDͲϭϳ;WdηϭϵϭͲϬϭϴͿĂŶĚϮDͲ Ϯϳ;WdηϭϵϮͲϬϳϭͿ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐŽƌĐŽŶĐĞƌŶƐ͘ 'XVW\)UHHERUQ :HOOV,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .580 37' Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1910180 Type Inj N Tubing 1900 1920 1920 1920 Type Test P Packer TVD 6004 BBL Pump 4.3 IA 10 3300 3150 3140 Interval V Test psi 3000 BBL Return 3.6 OA 120 120 120 120 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1920710 Type Inj N Tubing 550 3300 3210 3165 Type Test P Packer TVD 5967 BBL Pump 2.8 IA 550 3300 3210 3165 Interval V Test psi 3000 BBL Return 2.8 OA 230 250 250 250 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2M Pad N/A Arend / Weimer 06/02/22 Notes:MITIA to MAIP per AIO 2C.055 Notes: 2M-17 2M-27 Notes:MITIA to MAIP per AIO 2C.021 NOTE: Hex plug in tubing at 7400' RKB, open mandrel pocket at 7329' RKB. Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0602_MIT_KRU_2M-pad_2wells 9 9 9 9 9 9 - 5HJJ 2M-17 MEMORANDUM TO: Jim Regg ,rII' P.I. Supervisor `61 FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-17 KUPARUK RIV UNIT 2M-17 Sre: Inspector Reviewed By: P.I. Supry :J _T?JZ- Comm Well Name KUPARUK RIV UNIT 2M-17 API Well Number 50-103-20150-00-00 Inspector Name: Adam Earl Permit Number: 191-018-0 Inspection Date: 6/12/2020 - Insp Num: mitAGE200617104535 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 2M-17 IType Inj I N' TVD 600 ubing 2160 2160 2160 2160 PTD 1910180 Type Test SPT Test psi 3000 IA ' 3180 3160BBL Pumped: 8 BBL Returned: 3s OA q708300 30 30 130 ^ InRaQv.aR p/F P Nates: MIT IA Tested as per AIO 2C.055 to MAIP shut in for curtailment Wednesday, June 17, 2020 Page l of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg p�DATE: P.1. Supervisory—yQ 6 (t Z�(y Friday, May 31, 2019 SUBJECT: Mechanical Integrity Tests (f CONOCOPHILLIPS ALASKA, INC. 1010 2M-17 FROM: Jeff Jones KUPARUK RIV UNIT 2M-17 Petroleum Inspector 170 --- 170 Ste: Inspector Reviewed By: P.I. Supry JSZ-- NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-17 IInsp Num: mitJJ190531101307 Rel Insp Num: API Well Number 50-103-20150-00-00 Inspector Name: Jeff Jones Permit Number: 191-018-0 Inspection Date: 5/12/2019 Packer Depth Well 2M-17 ; Type Inj r W, TVD 6005 Tubing PTD 1910180 Type Testl SPT Test psi 3000 IA BBL Pumped L-3 !BBLReturned: 33 OA Interval) REQVAR [P/F Notes: AID 2C.055; 2 year MIT -IA. I well inspected, no exceptions noted. 'retest Initial 15 Min 30 Min JS Min 60 Min Friday, May 31, 2019 Page I of 1 'al' 2618 - 2588 2604 1010 3300 3170 - 7140 1-0 _-- 170 --- 170 —170 - Friday, May 31, 2019 Page I of 1 � Or 77 • G;wP�� /7 �s THE STATEAlaska Oil and Gas ���►-s-��4 of® T /� Conservation Commission sKA 333 West Seventh Avenue of ra P GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 to ALAS Fax: 907.276.7542 www.aogcc.alaska.gov December 13, 2017 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-050 Defeated Safety Valve System KRU 2M-17 (PTD 1910180) SCANNED � � Dear Mr. Wolfe: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed ConocoPhillips Alaska Inc (CPAI)'s December 4, 2017, explanation regarding the defeated safety valve system on Kuparuk River Unit 2M-17. CPAI presented the findings from its internal investigation and corrective actions that have been implemented to prevent recurrence of defeated well safety valve systems at CPAI-operated wells within Alaska. These actions address the concerns identified in the violation. The AOGCC does not intend to pursue any further enforcement action regarding the Kuparuk River Unit 2M-17 defeated safety valve system. Sincerely, 6032 Hollis S. French Chair, Commissioner cc: AOGCC Inspectors (via email) • Patrick Wolfe Manager ConocoPhillips North Slope Integrated Operations and Projects Post Office Box 100360 Anchorage,Alaska 99510 ATO-1226 Phone 907.265.6202 Patrick.J.Wolfe@conocophillips.com December 4, 2017 RECEIVED DEC U 4 2017 Hollis S. French AOGCC Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3572 Re: Docket Number: OTH 17-050 Defeated Safety Valve System KRU 2M-17 (PTD 1910180) Dear Commissioner French: On November 7, 2017, the wellhead safety valve system (SVS) was found to be defeated during an AOGCC witnessed performance test of the 2M-17 well in the Kuparuk River Unit (KRU). ConocoPhillips Alaska (COPA) started an investigation of the matter on the same day. In a letter received November 27, 2017, the AOGCC asked COPA to provide the Commission with a written summary of its internal investigation report, and to describe what has been or will be done in the future to prevent recurrence. This letter is COPA's response to that request. Description of Incident: The State witnessed SVS test followed a recent "WAG" of the well, in which the service of the well was changed from water injection to gas injection. During the inspection, the low-pressure pilot (LPP) on the hydraulic panel was found to be in the closed position, preventing discharge of the hydraulic pressure and holding the surface safety valve (SSV) open. When the valve was returned to the normal position (open), the hydraulic pressure released and allowed the SSV to close. Summary of Findings From Investigation: COPA completed an investigation into the defeated SVS on November 10, 2017, and found the following: • Hollis S. French • Chair, Commissioner, AOGCC Page 2 • The 2M-17 well has a single pressure switch functioning as the LPP for both water and gas injection services. In this configuration only one LPP is necessary on the hydraulic panel, whereas wells with hydraulic LPPs require separate valves for the water and gas pilots. • The investigation found that the pilot on this hydraulic panel was incorrectly labeled as being the LPP for water injection. It should have been labeled simply as the LPP. • When the well was removed from water injection service,the LPP was isolated, as would be the proper step for the panel as labeled. • This error was not recognized prior to start up or during the 1.5 days prior to the AOGCC witnessed performance test. Additional Discussion: Upon discovery of the isolated LPP, we immediately inspected the wellhead SVS and hydraulic panels on each well on the 2M pad. All other SVS systems were found to be properly aligned, but one additional panel was found to be mislabeled in the same manner. We corrected the label. The particular error that lead to this incident, a mislabeling of the LPP, was something we have not previously encountered, despite the steps we have taken over the last six years to improve our SVS equipment and human systems. We have discussed those steps annually with AOGCC staff, mostly recently on November 15, 2017. As described in those meetings,ConocoPhillips undertook an effort in 2011 to standardize the'r15 types of hydraulic panel systems in the KRU to the commonly known "skimpy panel". While the overall objective of standardization was achieved, there are still remaining variations that appear to have contributed to this incident, and also the defeated SVS that was found on the 2M-31 well in June, 2017. As a result of the incidents this year, we are focusing our continuous improvement efforts in three areas: • Identifying SVS systems that are more difficult for the operator to identify out of position valves due to their geometries or configurations that have hidden components. We have taken immediate steps to modify hydraulic panels, starting in the CPF2 area, to standardize the location of any valves to the front or side of the panel, so they cannot be hidden from view. We are also modifying any label that is misleading. The configuration and labelling improvements are nearly complete for the CPF2 area. When it is done, we will take similar actions in the CPF1 and CPF3 areas. These steps are the most useful things that we think can be done to address the human factors involved in operation of the SVS equipment. Hollis S. French • I Chair, Commissioner, AOGCC Page 3 The residual inconsistences in skimpy panels, such as the use of a single switch LPP in some cases and dual valve LPP in others, is also getting focused attention. At this point, we don't have a clear answer on how much additional standardization is necessary to ensure reliable operation, but we are working on it. • ConocoPhillips is also modifying our custody seal program in two ways. We are improving the connection locations for custody seals, and improving the training and directions for seal attachment methods and inspections. This involves revitalization of a program that was highly successful when it was originally rolled out over 6 years ago, but developed internal inconsistencies over time, impairing the effectiveness of the program. • In July, 2017, we established a field verification program by our Kuparuk Operations leadership. Already, these efforts have highlighted the need to improve the custody seal program, and those improvements are in progress, as described above. We will continue to mature this field verification effort to help evaluate deficiencies and trends for corrective action before they evolve into incidents such as this one. ConocoPhillips leadership is using this incident as an instructional example in communications with operators, taking the opportunity to clarify and emphasize the expectations for SVS inspections during the daily operator wellhouse and well checks. These inspections should have, but did not, identify the deficiencies experienced this year. Conclusion: ConocoPhillips has developed a robust SVS management program over the past six years that has improved overall performance. However,we have had three incidents this year where performance fell below standards despite our efforts. We recognize that violations of SVS requirements are unacceptable, and that we must improve our performance. With the efforts described above, we believe we are on the right path, and that our systematic efforts will achieve the right results. We will provide updates on the status of these efforts to the AOGCC during our annual face to face meetings. Yours truly, '''''2'..7f 4 Z. Patrick Wolfe • • T A R C � tilli Lessons LearnedZERO Impact Investigation No: Date of Incident: November 7, 2017 DS2M-17 Defeated SSV Business/Facility/Site: GKA, CPF2, DS2M Location: DS2M-17 Consequence: Regulatory Compliance Risk Rating (Actual): 2 Incident Description: When performing a State Witnessed SVS Performance test on 2M-17 the SSV was found non- functional due to a closed pilot defeat valve on the Skimpy panel. Key Findings: The pilot defeat valve on the skimpy panel was found to be miss-labeled. It indicated that the pilot was for water injection when in fact it was the electronic pilot for both water and gas injection services. It was closed when the well was WAG from water to gas injection. The design and installation of the hydraulic skimpy panels throughout the field is inconsistent and some locations may have misleading tag/labels or hidden valves, as seen in previous 2M-31 incident, pictured below. 2M-17 2M-31 gi ,k2M-1,7 PUP Front of 2M-31 Panel Incorrectly " labeled Pilot '4 4 O Block that was 1 n ....o.Iet clPhot„ ._ by ' •-z6- a IS, heat ° 2M -31 Hidden t pro.] • to,the AOG(( tI 'I-nnissioi , a - to >t f •ts„orrykusi; ( jN tot an\ Pilot Block the] ewse beoem`Th pet. t pchib ,d oit?io'itkhe e' r o tient 0 Valve that was ('on,,co hl 1p,Alaskaa-In left closed. rUt _ii ,. 6 4 * 4 r 7- _ Back of 2M-31 Panel .PIE ""d: .'] '.yy .eroco• t; 1 1,' •IIs h ... . mei ed n h .` raph is being pro ided I the AO(1 1 ,c 1I] .T# P «........ {ci n sslon i. • r-,.., so] 17 b t noeol'that, bt any othe '1' 41- s Ned. IIs „..211:,4, < Con coPhill oma:\Ia ka Ia e f- (C'tsIth pul copy ctStil tep 1 t Iii an oih r,J dn)/c/ oI\b led Ihui '- rr9enf `Ct50tt,tt I \laska I Lessons Learned from Incident: Identify and correct indicator labels and signs. Evaluate means to improve consistency and eliminate hidden traps on wellhead SVS equipment. For suggestions, comments or questions,please contact the Responsible Supervisor NSK Fieldwide Operations Supt., 659-7042 VOF Tx • I//7,-�A THE STATE Alaska Oil and Gas �, o T a cKA Conservation Commission 333 West Seventh Avenue Anchorage,GOVERNOR BILL WALKER ge, Alaska 99501-3572 OF aTh Main: 907.279.1433 ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov November 21, 2017 CERTIFIED MAIL- RETURN RECEIPT REQUESTED 7015 0640 0003 5185 6052 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH 17-050 Defeated Safety Valve System KRU 2M-17(PTD 1910180) Dear Mr. Wolfe: On November 5, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed a miscellaneous well safety valve system test on Kuparuk River Unit(KRU)2M-17 that was performed by a ConocoPhillips Alaska Inc (CPAI) representative. The safety valve system on KRU 2M-17 was found defeated. Investigation revealed that the safety valve system was defeated preventing closure of the surface safety valve. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. CPAI is reminded that a completed well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph(m)of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on KRU 2M-17 that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265 —will not be tolerated. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written summary of its internal investigation report, and describe what has or will be done in the future to prevent its recurrence at CPAI-operated fields in Alaska. Failure to comply with this request will be an additional violation. Notice of Violation Docket Number:OTH 17-050 November 21,2017 Page 2 of 2 CPAI has been issued three notices of violation for defeated safety valves at several KRU pads within the past five months. In each enforcement action, CPAI was instructed to describe what has or will be done in the future to "prevent its recurrence at CPAI-operated fields in Alaska". Corrective actions identified by CPAI included mechanical as well as administrative enhancements that should have prevented the recent violations. The AOGCC is reviewing this violation along with the past commitments made by CPAI to implement corrective actions in response to similar defeated safety valve systems. We reserve the right to pursue enforcement action in connection with the recent defeated safety valve systems in the KRU. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Hollis S. French Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • U.S. Postal Service"' CERTIFIED MAIL° RECEIPT ru▪ Domestic Mail Only For delivery information,visit our website at www.usps.comu. co Certified Mail Fee ra $ U1 Extra Services&Fees(check box,add fee as appropriate) 0 Return Receipt(hardcopy) $ I." 0 Return Receipt(electronic) $ Postmark Certified Mail Restricted Delivery $ Here ❑Adult Signature Required $ Li Adult Signature Restricted Delivery$ O Postage . $ o TotalPostac Mr. Patrick Wolfe is) Sent To North Slope Operations Manager ConocoPhillips Alaska, Inc. . . $treerand A, P. O. Box 100360 r` �rh -- Anchorage, AK 99510-0360 PS Form 3800,April 2015 PSN 7530-02-000-9047 See Reverse for Instructions SENDER: COMPLETE THIS SECTION COMPLETE TPI:;SECTION ON DELIVERY • Complete items 1,2,and 3. A. Signatu J 1pg■ Print your name and address on the reverse x gent so that we can return the card to you. _ is .. i 4—Addressee • Attach this card to the back of the mailpiece, B. -° eived by(P in ` = C. Date of Delivery or on the front if space permits. Co�� i 1. Article Addressed to: - ,�s� -i ' N �'�_�5 L7 D. Is delivery address different from item 1? 0 Yes If YES,enter delivery address below: 0 No Mr.oPh Wolfe I VEL North Slope Operations Manager E ConocoPhillips Alaska, Inc. P. O. Box 100360 '''10 V 2 8 2 Anchorage, AK 99510-0360 3. Service Type 0 Priority Mail Express® 111111111111111111111111 II I I 111111 II I I III ❑Adult Signature 0 Registered MaimTM 0 Adult Signature Restricted Delivery ❑Registered Mail Restricted ❑Certified Mail® Delivery 9590 9402 1823 6104 6486 72 0 Certified Mail Restricted Delivery ❑Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) ❑Collect on Delivery Restricted Delivery 0 Signature Confirmation10 d Mail 0 Signature Confirmation 7 015 0640 0003 5185 6052 d Mail Restricted Delivery Restricted Delivery ;500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, November 30, 2017 5:08 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of multiple IA bleeds KRU WAG injector 2M-17 (PTD 191-018) 11-30-17 Attachments: 2M-17 schematic.pdf;2M-17 90 day TIO 11-30-17.JPG Chris, KRU WAG injector 2M-17 (PTD 191-018) is experiencing a buildup in IA pressure which has resulted in a need for repeated bleeding over the last two days. The well has been on gas injection since November 5th,2017. There has been a fluctuation in temperature and injection rate so this may still only be a thermal response. Therefore,at this point,we will only put the well on a 30 day monitor while on gas injection and watch for more definitive evidence of communication. The well was reported in January 2016 for possible TxIA on gas injection; but communication was not confirmed at that time so the well was returned to'normal' status. Due to this history, if the well becomes more strongly suspected of displaying TxIA on gas injection,the well will be WAG'ed to water injection for a 30 day water monitor in anticipation of an AA submittal. After the well is WAG'ed,the standard suite of DHD diagnostics to include an MITIA and packoff testing will be obtained. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 SCANNED • • �rw .uo in cDoo v 2.0 ONw H q -1rm r — — — T o Crli kNi o ` N O 117 . v o o Lgm Y -p > O OE TU- U +' N @ tr ' 11 U O. 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Q o0 00 o yam, : • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Wednesday,September 14,2016 P.I.Supervisor I����r ci(-- 11, SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-17 FROM: Johnnie Hill KUPARUK RIV UNIT 2M-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-17 API Well Number 50-103-20150-00-00 Inspector Name: Johnnie Hill Permit Number: 191-018-0 Inspection Date: 9/11/2016 Insp Num: mitJWH160911200103 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-17 - Type Inj W 'TVD 6005 Tubing 2610 - 2610 - 2600 , 2600 PTD 1910180 - Type Test SPT Test psi 1501 IA 1260 1880 _ 1850 1850 Interval 4YRTST — P/F P ,/ OA 90 , 90 , 90 90 Notes: SCANNED JUN 2 0 2017, Wednesday,September 14,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg P.I.Supervisor I 131 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-17 FROM: Jeff Jones KUPARUK RIV UNIT 2M-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry „Age— NON-CONFIDENTIAL -NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-17API Well Number 50-103-20150-00-00 Inspector Name: Jeff Jones Permit Number: 191-018-0 Inspection Date: 6/5/2016 Insp Num: mitJJ 160608092017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well2M-17 T e In' yp J N-TVD 6005 • Tubing 2920 - 2920 • 2920 2930 PTD 1910180 iType Test SPT Test psi 1501 IA 200 1810 1700 1690 - Interval 4YRTST P/F P V OA 70 . 7o- 70 . 70 - Notes: 1 well inspected,no exceptions noted. S p4t4E® DEC 2 9 2016 Thursday,June 09,2016 Page 1 of 1 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, March 07, 2016 1:45 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: Report of unexplained IA pressurization while on gas injection 2M-17 (PTD 191-018) 12-2-15 update 1-28-16 Chris, The 30 day timeframe since the well was WAG'd to gas has ended. During the testing timeframe however, the well did not take any gas. The tubing just stacked out with the injection header pressure but the formation did not allow any injection rate to be established. After the extended bleed periods the IA was bled extremely low and did not show any signs of communication while the tubing sat stacked out with a column of gas. It is ConocoPhillips intention to return the well to normal injection status and monitor the wellhead pressures daily as per our standard operating procedures. If the anomaly repeats itself,the well will be reported at that time and further diagnostics will be performed. Attached for reference are 2 different 90 day TIO plots, one to show the rate of injection (basically no injection) and the other one includes the tubing pressure in the plot. Please let me know if you disagree with this plan. SCANNED APR 0 7 201Z Well Name 2M-17 Notes: • Start Date 121612015 Days 90 End Date 3/5/2016 2ECC WHP Annular Communication Surveillance - 1= 2C0C — 12 — 1211 1ECC r&N „/� f ... J 1../v J( 1C .U) 1CCC od1 \ EC SCC iC — 60 Nor.`1E Dec-1` Dec-1F Dec-1E Jan-16 Jan-16 Jan-16 Jan-16 Feb-16 Feb-16 Mar-16 Mar-16 2 :::_ Plipl ...._ Nor-1E Cec-1E Ceo-1S Deo-15 Jan-16 Jan-16 Jan-16 Jan-16 Feb-16 Feb-16 Mar-16 Mar-16 Date 2 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday,January 28, 2016 4:53 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of unexplained IA pressurization while on gas injection 2M-17 (PTD 191-018) 12-2-15 update 1-28-16 Attachments: MIT KRU 2M-17 diagnostic MITIA 1-26-16.xls Chris, There was a short delay in WAG'ing 2M-17 to water due to water header repair work. The well was shut in following the initial report to you on 12-2-15 and was returned to water injection on 12-27-15. Its 30 day monitor on water injection has come to an end and all looks fine. All of the diagnostic tests passed: MITIA and the tubing and inner casing packoff tests. The IA drawdown test also passed after an extended bleed of the annulus over several days at the tail end of the monitor period. The annulus showed good stabilization during the monitor prior to the gas bleeding. ConocoPhillips intends to return the well to gas injection and to monitor for 30 days to see if the IA repressurization will return when on gas. At the conclusion of the monitor period, an updated email will be sent with path forward based on the results. Please let me know if you disagree with the plan. Attached are the MIT data and latest 90 day TIO plot. • SCANNED JUL 2 7 2016 1 • • Well Name 2M-17 Notes: Start Date 10/3012015 Days 90 End Date 112812016 2ECC - _ — 1` WHP Annular Communication Surveillance 1r+ OAP — 1' INK 20CC — ( 1: \'\fiq\ - 1: 1500 � f� 1' 1000 Si Q — g.( ECC rt 7( Oct-1E Nc.-1E Nov-1E 11 c•;-1E Cea1E Cec-1E Deo-1E Jan-18 Jan-1E Jan-1S Jan-15 Fet-1. Oct-1E Novi-1E Nov-1E Nov-1E Dec-1E Dec-1E Dec-1E Jan-16 Jan-16 Jan-16 Jan-16 Feb-1E Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr 909 From: NSK Problem Well Supv 2 • • . Sent: Wednesday, December 02, 225 11:28 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of unexplained IA pressurization while on gas injection 2M-17 (PTD 191-018) 12-2-15 Chris, KRU WAG injector 2M-17 (PTD 191-018) is displaying a repeated IA pressurization while on gas injection. Several bleeds were performed recently which were believed to be thermally related. However,the temperature has been on a recent downward trend and sufficient time has passed to no longer believe hysteresis is affecting the wellbore. The well is currently on gas injection and CPAI plans to WAG the well to water injection as soon as possible and monitor for 30 days. Because of the current slow build up in pressure and historic test results on other wells displaying similar characteristics, we do not expect the well to fail the MIT. Therefore we plan to delay the MIT and other initial DHD tests which will include packoff testing and an extended IA pressure bleed (possibly to take several days),till towards the end of the 30 day monitor period. With any extended bleeding of the IA,gas on the backside is expected to come out of solution and possibly confuse the results while on water injection. So instead we will first confirm that no communication is apparent when on water injection by initially only monitoring. Following the 30 day monitor and diagnostic testing period, a request may be submitted for another test on gas injection or an AA application for continued water only injection will be submitted. Please let me know if you disagree. Attached are the 90 day TIO and schematic. « File: 2M-17 90 day TIO 12-2-15.JPG » « File: 2M-17 schematic.pdf>> Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907)659-7000 pgr 909 3 KUP INJ 410 2M-17 ConocoPhillips ; Well Attributes Max Angle&MD TD illi htih 1 1!t.: Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Min(ftKB) iy 501032015000 KUPARUK RIVER UNIT INJ 42.57 4,719.95 7,947.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(it) -Rig Release Date 25-17,5111/2015 9:42:23 Ann SSSV.TRDP Last WO: 46.00 7/12/1992 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 7,625.0 5/10/2015 Rev Reason'.TAG hipshkf 5/11/2015 HANGER.375 _- Casing Strings Casing Description 'OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1-1-+] CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... WtlLen(I...Grade Top Thread SURFACE 9 5/8 8.921 41.9 3,189.3 2,783.7 36.00 J-55 BTC Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(L..Grade Top Thread f...- awl..PRODUCTION 7 6.276 39.0 7,943.4 6,392.3 26.00 J-55 BTC-MOD Tubing Strings .A-ti'CONDUCTOR;42.0-127.0 1 S ' '" Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 37.6 7,467.4 6,026.3 9.30 J-55 ABM-EUE Completion Details Nominal ID SAFETY VLV,1,813 3Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 37.6 37.6 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 1,813.3 1,690.3 36.66 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 7,424.9 5,993.8 40.14 PBR BAKER PBR w/10'STROKE w/4"SEAL BORE 3.000 7,438.6 6,0042 40.11 PACKER BAKER HB RETRIEVABLE PACKER 2.890 7,454.9 6,016.7 40.09 NIPPLE CAMCO D NIPPLE 2.750 7,466.5 6,025.6 40.10 SOS BAKER SHEAR OUT SUB 3.015 SURFACE;41.94,189.3-J Perforations&Slots Shot (-7Dens GAS LIFT;3,287.9- t Top(TVD) Btm(TVD) (ahotslf p �° Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Data t) Type Com 7,558.0 7,565.0 6,095.7 6,101.0 C-4,2M-17 11/17/1995 4.0 APERF 180 deg ph;Orient 90 deg F/Lowside;2 1/8" Hyperdome 7,5720 7,578.0 6,106.4 6,111.0 A-5,2M-17 11/17/1995 4.0 APERF 180 deg ph;Orient 90 GAS LIFT;4,933.1 1 ! deg F/Lowside;2 1/8" Hyperdome 7,590.0 7,608.0 6,120.3 6,134.1 A-4,2M-17 11/17/1995 4.0 APERF 180 deg ph;Orient 90 GAS LIFT;5,492.8 lYy deg F/Lowside;2 1/8" Hyperdome 7,630.0 7,650.0 6,151.0 6,166.4 A-3,2M-17 9/4/1992 4.0 IPERF 180 deg ph;Orient 156.4 deg.CCW;SWS 4.5" GAS LIFT:5,9656 Csg Gun 7,650.0 7,660.0 6,166.4 6,174.1 A-3,2M-17 9/4/1992 4.0 IPERF 180 deg ph;Orient 155.5 deg.CCW;SWS 4.5" GAS LIFT;6,437.3 Csg Gun 7,660.0 7,662.0 6,174.1 6,175.7 A-3,2M-17 9/4/1992 4.0 IPERF 180 deg ph;Orient 152.3 deg.CCW;SWS 4.5" ir Csg Gun GAS LIFT;e,e12.3 Mandrel Inserts st ati on Top(ND) Valve Latch Port Sin TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT,7,369 1 \ 1 3,287.9 2,861.2 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 11/24/1995 C 2 4,933.1 4,100.4-CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 9/14/1992 --- 3 5,4928 4,524.5'CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 11/24/1995 4 5,965.6 4,881.2 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 9/4/1992 5 6,437.3 5,242.6 CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 11/24/1995 I 1 PBR,],4249 6 6,912.3 5,604.27CAMCO KBUG 1 GAS LIFT DMY BK5 0.000 0.0 9/4/1992 PASSER.7.4366 7 7,369.1 5,951.2"CAMCO MMG-2 1112 GAS LIFT DMY RK 0.000 0.0 11/24/1995 IgNotes:General&Safety NIPPLE,7.4549 Ig End Data Annotation 11/12/2010 NOTE:View Schematic w/Alaska Schmatic9.0 SOS.7456.5 APERF;7,558.0-7,545.n-----. ^ APERF;7,572.0-7,578.0 APERF;7,5509-7.608.0 IPERF;7,e30.0-7,850.0 (PERF;7,850.0-7,880.0- . (PERF;7,800.0-7,002.0 PRODUCTION;35.0-7,843.4 XHVZE Pages NOT Scanned in this Well History File 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. //~/,Z~,~ File Num ber of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [3 Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED Logs-of vadous kinds . Other COMMENTS: Scanned by: ~ever~ Oi~n Lowell TO RE-SCAN Notes:- Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ • 4 ConocoPhillips Alaska P.O. BOX 100360 x , ANCHORAGE, ALASKA 99510 - 0360 June 30, 2011 Commissioner Dan Seamount Alaska Oil and Gas Commission ti ¢� 4 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: 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 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 on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor ! • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 6/30/11 2F,2M,2N,2T,2X,2Z,3B,3O PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor! Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A 50103201770100 1960900 SF N/A _ 18" _ N/A 3.5 6/26/2011 2M -14 50103201730000 1920630 SF N/A 19" N/A 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" _ N/A 4 6/27/2011 2N -318A 50103203430100 2090220 I 10" N/A 27" N/A 7 6/27/2011 2T -40 50103205280000 2060400 2' N/A 2' N/A _ 6 6/26/2011 2T- 202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 _ 1831130 SF N/A 21" N/A 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A 21" N/A 2.5 6/25/2011 2Z -02 50029209600000 1830800 18" N/A 18" _ N/A 2.6 6/24/2011 3B -01 50029213180000 1850560 SF 1.50 17" 5/23/2011 6 6/22/2011 30 -12 50029218040000 1880410 SF N/A 22" i N/A 1.7 6/22/2011 TO: Jim Regg 1~~., / ~~/ 7 / ;cam P.I. Supervisor ~( !` , FROM: Jeff Jones Petroleum Inspector Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 11, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-t7 KUPARUK RIV UNIT ZM-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprs~~Pn ~'(7/(~ Comm Well Name: KUPARUK RN UNIT 2M-17 API Well Number: 50-103-20150-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ080610125153 Permit Number: 19t-018 -0 ~ Inspection Date: 6/2/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zM-n ~TYP '.e ri,I G ' 'I'mo 6005 / IA 1180 2720 `~~ 2660 2640 ' ~- p T ! 191o1so ITypeTest ~ sPT Test psi lsol ~s ~' OA i 600 06 0 0 0 60o Interval 4YRTST P/F P ~ TUhlrig ~ 3300 i 3300 i 3300 3300 i i _ - Notes' 4.3 BBLS diesel pumped; no exceptions noted. • _ ___ _____ __ ~{~~ ~~~ {~(~~r ~l ~ 2D08 State of Alaska Wednesday, June I I, 2008 Pale I of 1 07/23/07 Scblumbergep NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dUL 2 5 Z007 l\iæka Oii B, Cons. commí§W.ìJiNED JUL 2 7 2007 1~l1chora9ø Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: U .l-C- L~ 1-0 l~ Field: Kuparuk Well Color CD Job# Log Description Date BL \1;; 2M-20 11629044 PRODUCTION PROFILE 07/11/07 1 3M-20 11665456 INJECTION PROFILE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1 R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 LDL 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V-08A 11665459 UslT 07/16/07 1 2Z-16 11665458 sCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L-07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test 'Rt~t -1ft ~ù4 Emall to.Tom_Maunder@admin.state.akus;Bob_Fleckenstein@admlnstate.ak.us; and Jlm_Regg@admin.state.~ us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2M DATE: 06/28/04 OPERATOR REP: Sauvageau I Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2M-03 Type Inj S TV.D. 5939 Tubing 2400 2400 2400 2400 Interval 4 P.T.D.1911410 Type Test P Test psi 1500 Casing 1250 1800 1770 1760 P/F P Notes: Well 2M-14 Type Inj G TV.D. 6025 Tubing 3550 3550 3550 3550 Interval 4 P.T.D. 1920630 Type Test P Test psi 1506 Casing 550 1920 1910 1910 P/F P Notes: Well 2M-16 Type Inj S T.V.D. 5845 Tubing 2300 2300 2300 2300 Interval 4 P.T.D. 1910320 Type Test P Test psi 1500 Casing 900 2910 2850 2840 P/F P Notes: Well 2M-17 Type Inj G T.V.D. 6005 Tubing 3580 3580 3580 3580 Interval 4 P.T.D. 1910180 Type Test P Test psi 1501 Casing 2800 1600 1620 1620 P/F P Notes: Drawdown test due to high IA initial pressure Well 2M-19 Type Inj S T.V.D. 5856 Tubing 2000 2000 2000 2000 Interval 4 P.T.D. 1911320 Type Test P Test psi 1500 Casing 135 2600 2600 2600 P/F P Notes: Well 2M-23 Type Inj N T.V.D. 1551 Tubing 100 100 100 100 Interval 4 P.TD. 1910340 Type Test P Test psi 1500 Casing 0 1800 1750 1720 P/F P Notes: Class 2 disposal well. IA & OA common via circ string Well 2M-26 Type Inj G TV.D. 5971 Tubing 3100 3100 3100 3100 Interval 4 P.T.D. 1920550 Type Test P Test psi 1500 Casing 1550 2320 2300 2300 P/F P Notes: Well Type Inj TV.D. Tubing Interval P.TD. Type Test Test psi 1500 Casing P/F Notes: 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 0 = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 2004-0628_MIT _KRU_2M-26.xls 7/1 3/2004 ON OR BEFORE E E C:LO~LM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well 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 114' FSL, 379' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1277' FSL, 1501' FWL, SEC 34, T11N, R8E, UM At effective depth 1090' FSL, 1554' FWL, SEC 34, T11N, R8E UM At total depth 1045' FSL, 1570' FWL, SEC 34, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7947 6395 Plugging Perforate X Other 6. Datum elevation (DF or KB) RKB 147 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-17 9. Permit number approval number 91-18/95-208 10. APl number I__1_. Field/Pool Kuparuk River Field/Pool feet Plugs (measured) feet feet Effective depth: measured 7 8 5 7 true vertical 6326 feet Junk (measured) feet Casing Length Structural Conductor 8 0' Surface 31 4 6' Intermediate Production 7 9 0 2' Liner Perforation depth: measured 7558'-7565', true vertical 6096'-61 01 ', Size Cemented Measured depth True vertical depth 1 6" 225 SX ASI 1 21 ' 1 2 1 ' 9 5/8" 545 SX PF E 31 89' 2604' 507 SX CLASS G 7" 208 SX CLASS G 7 9 41 ' 6 2 4 4' 7572'-7578', 7590'-7608', 7630' 7662' 6106'-6111', 61 20'-6134', 6151' 61 76' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 7467' Packers and SSSV (type and measured depth) Baker PBR @ 7425', Baker HB RETR. PKR @ 7439'; Camco TRDP-4A-40 @ 1813' 13. Stimulation or cement squeeze summary RECEIVED MAY 0 ? 14. Perforated 'A' & 'C' sands on 11/17/95 Intervals treated (measured) 7558'-7565', 7572'-7578', 7590'-7608' Treatment description including volumes used and final pressure Shot using 2 1/8" Hyperdome w/ DP charges @ 4 spf, 180° phasing, 90° orientation f/ Iowside. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4 5 3 408 185 941 241 Subsequent to operation 0 0 5100 1500 450 15. Attachments Wellbore Schematic Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil Gas -- Suspended Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendant Date SU BM IT/I'N DOPLICATE .'riCO Alaska, Inc. ~.~ KUPARUK RIVER UNIT ,~ WELL SERVICE REPORT '~, K1(2M-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2M- 1 7 MISC RESERVOIR MANAGEMENT 1 1 13951830.4 DATE DAILY WORK UNIT NUMBER 1 1/1 7/9 5 ADD PERFORATIONS DAY OPERATION COMPLETE ISUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O No I (~) Yes C) No SWS-JOHNSON PAIGE RELD AFC# CC# DAILYOOST AOOUMCOST Sit, el (.. r~ ~ '~ ESTIMATE K84958 230DS28M L $1 0,91 6 $10,916 ~ . Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1 100 PSI 1100 PSI 400 PSI 400 PSII 0 PSII 0 PSI DAILY SUMMARY ICOMPLETEDADD PERF USING 2-1/8" HYPERDOME W/DP CHARGES, 4 SPF, 180 DEG PH, 90 DEG ORIENTATION F/LOWSlDE I I I TO SHOOT 7558'-7565', 7572'-7578', & 7590'-7608' (REF HLDT/CNTG DATED 8/13/92) TIME LOG ENTRY 1 0:00 MIRU SWS. HELD SAFETY MTG. 1 2:00 PT LUB TO 3000#; TEST OK. RIH W/GUN#l- CCL, MPD, 2-1/8" HYPERDOME W/DP CHARGES, 4 SPF, 180 DEG PH, 90 DEG ORIENTATION F/LOWSIDE TO PERF 7590'-7608' 1 2:45 ON BOTTOM TO TIE-IN TO HLDT/CNTG DATED 8/13/92; TAGGED BOTTOM @ 7710' ELM. 1 3: 0 0 FIRED GUN; POH. 1 3:30 AT SURF W/GUN#l; ALL SHOTS FIRED. 1 4:00 PT LUB TO 3000#; TEST OK. RIH W/GUN#2- CCL, MPD, 2-1/8" HYPERDOME W/DP CHARGES, 4 SPF, 180 DEG PH, 90 DEG ORIENTATION F/LOWSIDE TO PERF 7558'-7565' &7572'-7578' 14:30 ON BOTTOM TO TIE-IN TO HLDT/CNTG DATED 8/13/92 14: 4 5 FIRED GUN; POH. 15:30 AT SURF W/GUN#2; ALL SHOTS FIRED. 1 6:30 RDMO. RECEIVED MAY 0 7 1996 SERVICE COMPANY - SERVICE SCHLUMBERGER TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate Pull tubing Alter casing Repair well __ 2. Name of Operator I 5. Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic __ P. O. Box 100360, Anchorage, AK 99510 Service X 4. Location of well at surface 114' FSL, 379' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1277' FSL' 1501' FWL' SEC 34' T11N' R8E' UM 0 RAt effective depth 1090' FSL, 1554' FWL, SEC 34, T11N, R8E UM At total depth 1045' FSL, 1570' FWL, SEC 34, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7 9 4 7 feet true vertical 6395 feet Plugging Perforate .... Other X 6. Datum elevation (DF or KB) RKB 147 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-17 9. Permit number approval number ~ APl number 5o-1 03-20 1 50 Kuparuk River Field/Pool Plugs (measured) feet Effective depth: measured 7857 feet true vertical 6326 feet Junk (measured) Casing L e n g t h Size Structural Conductor 8 0' 1 6" Surface 3146' 9 5/8" Intermediate Production 7902' 7" Liner Perforation depth: measured 7558'-7565', true vertical 6096'-6101', Cemented 225 SX ASI 545 SX P F E 507 SX CLASS G 208 SX CLASS G Measured depth 121' 3189' 7941 ' 7572'-7578', 6106'-6111', 7590'-7608', 6120'-6134', 7630' - 7662' 6151' - 6176' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 7467' Packers and SSSV (type and measured depth) Baker PBR @ 7425', Baker HB RETR. PKR @ 7439'; Camco TRDP-4A-40 @ 1813' 13. Stimulation or cement squeeze summary Convert oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A True vertical depth 121' 2604' 6244' 14. Prior to well operation .... Subsequent to operation ,R,epresentative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4 5 3 408 185 941 0 0 5100 1500 Tubing Pressure 241 450 15. Attachments Wellbore Schematic Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 16. Status of well classification as: Oil Gas ~ Suspended ~ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendant Date 7/,'~//~' SUBMIT IN DUPLICATE WELL 2M-17 PRODUCER APl #50-103-20150 SURFACE LOCATION: 114' FSL, 379' FWL, SEC 27, T11N, R8E, UM TOP OF KUPARUK: 1363' FSL, 1501' FWL, SEC 34, T11N, R8E, UM TD LOCATION: 1120' FSL, 1570' FWL, SEC 34, T11N, R8E, UM DEPTHS: REFERENCED TO 146' RKB ALL DEPTHS MD-RKB TUBING HEAD FLANGE RKB=37.60' 16": 62.5# H-40 @ 121' WELL TYPE: Oil Producer 9.625": 36# J-55 @ 3189' Baker PBR: 3.00" ID @ 7425' Baker HB Retr. PKR: 2.89" ID @ 7439' CAMCO D NIPPLE: 2.75" ID @ 7455' Baker SHEAR OUT: 2.875"1D @ 7467' C 7552-7560 B A5 7564-7583 A4 7583-7627 A3 7627-7712 7": 26# J-55 @ 7941' VOLUME: 0.0383 BBL/FT PBTD: 7857' L SPUD:7/6/92 COMPLETION: 9/4/92 SSSV: CAMCO TRDP-4A-RO @ 1813' GLMI: GLM2: GLM3: GLM4: GLM5: GLM6: GLM7: 3288'/CAMCO 4933'/CAMCO 5493'/CAMCO 5966'/CAMCO 6437'/CAMCO KBUG/1.0"/DV KBUG/1.0"/DV KBUG/1.0"/DV KBUG/1.0"/DV KBUG/1.0"/DV 6912'/CAMCO KBUG/1.0"/DV 7369'/CAMCO MMG2/1.5"/DV 3.5" 9.3# J-55 EUE, @ 7467' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 40.0 DEGREES MAX. HOLE ANGLE = 42 DEGREES @ 4574' VOLUME TO TOP PERF = 71.2 BBLS 7558'-7565' 7572'-7578' 7590'-7608' 7630'-7650' 7650'-7660' 7660'-7662' (7'), 4 SPF, 180° @ 90° ORIENT (6'), 4 SPF, 180° @ 90° ORIENT (18'), 4 SPF, 180° @ 90° ORIENT (20'), 4 SPF, 180° @ 156° CCW (10'), 4 SPF, 180° @ 152° CCW ( 2'), 4 SPF, 180° @ 152° CCW LAST TAG DATE: 7716' RKB on 11/23/95 REVISION: EZ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 114' FSL, 379' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1363' FSL, 1501' FWL, SEC 34, T11N, RSE, UM At effective depth ORIGINAL At total depth 1120' FSL, 1570' FWL, SEC 34, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 7947' feet true vertical 6395' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 1 47 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-17 9. Permit number/approval number 91-18 10. APl number 50-103-20150 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7857' feet true vertical 6326' feet Junk (measured) Casing Length Size Structural Conductor 1 2 1 ' 1 6" Surface 3189' 9 5/8" Intermediate Production 7941 ' 7" Liner Perforation depth: measured 7630'- 7662' true vertical 6151'- 6176' Cemented 225 SX ASI 545 SX P F E 507 SX CLASS G 208 SX CLASS G Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 7467' Packers and SSSV (type and measured depth) BAKER PBR @ 7425', BAKER HB RETR. PKR @ 7439' Measured depth True vertical depth 13. Attachments Description summary of proposal ~ Detailed operation program _ Convert oil producer to water injector. 14. Estimated date for commencing operation November 1995 Date approved BOP sketch -- 15. Status of well classification as: Oil __ Gas _ Suspended 16. If proposal was verbally approved Name of approver ,-~./ : I n j e c t o r I_2,,~/.-- ,~-' ~ ~,:~' ¢~'/t Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~¢~'// ~--~ ~ Title Wells Superintendent 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 Original Signed By i0avid W. Johnston Approved by order of the Commission 1-~(~r~ ~'.,°',~ Copy c,:~,tu~ned- /~ -, ~ Commissioner Date Form 10-403 Rev 06/15/88 IApprova.I, No. q SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 2M-17 ARCO Alaska requests approval to convert Well 2M-17 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6151' and 6176' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 09/23/94 RUN DATE_RECVD 91-018 CDR L 3190-7947 1 12/14/92 1 08/24/92 1 08/24/92 10/20/92 10/20/92 09/29/92 ALL 08/24/92 ALL 12/07/92 91-018 CET L 6400-7859 91-018 HLDT L 6480-7881 91-018 407 91-018 DAILY WELL OP 91-018 SURVEY R COMP DATE: 09/04/92 R 07/07-09/04/92 R SUB-SURFACE DIREC. 91-018 5357 91-018 5464 T 6480-7881 HLDT T 3136-7946 OH/FINALS Are dry ditch samples required?\ ~eceived? yes Was the well cored? _ye~ ~/~~~sis_& description received? Are well tests re~~ye~o Received? yes no WellcoMMENTsiS in compl~an~~ no yes no ARCO Alaska, Inc. --" Post Office E. i'00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. · WELL ACTION WELL ACTION ~*"~'~'~ 2M-03 Stimulate ~':',-~,.: 2M-18 Stimulate '~-~..-t:!;~ 2M-10 Stimulate ~;:-i- ~;-~ 2M-19Stimulate ~ ~.-.. ,. ;~ -i- 2M- 11 Stimulate ,-;: ~ _., ~ ¢.' 2M-20 Stimulate ~%-wz~ 2M-13 Stimulate ~;,-~ 2M-21 Stimulate ~t¢ 5~ 2M-15 Stimulate ¢~qct 2M-22 Stimulate c~_ 5~ 2M-16 Stimulate c~.~_ dc 2M-24 Stimulate cli_.t;~ 2M-17 Stimulate o~,_~ 2M-25 Stimulate if you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 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 114' FSL, 379' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1363' FSL, 1501' FWL, SEC 34, T11N, RSE, UM At effective depth At total depth 1120' FSL, 1570' FWL, SEC 34, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7947' 6395' feet feet Effective depth: measured 785 7' true vertical 6326' feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 1 47' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-17 9. Permit number/approval number 9/-/g" 10, APl number 5o-103-20150 11. Field/Pool Kuparuk River Oil Pool feet Casing Length Size Structural Conductor 1 21 ' 1 6" Surface 3189' 9 5/8" Intermediate Production 7941 ' 7" Liner Perforation depth: measured 7630' 7662' true vertical 6151' 6176' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 EUE, @ 7467' Packers and SSSV (type and measured depth) Cemented 225 SX ASI 545 SX PF E 507 SX CLASS G 208 SX CLASS G Measured depth True vertical depth RECEIVED lvlAY 2 0 1994 Aiaska Oil & Gas Cons. Commission Anchorage CAMCO TRDP-4A-RO @ 1813', BAKER PBR @ 7425', BAKER HB RETR. PKR @ 7439' 13. Stimulation or cement squeeze summary Intervals treated (measured)7630' - 7662' Treatment description including volumes used and final pressure See Attached Summmary 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/13/92 0 . 0 Subsequent to operation 11/15/92 1 979 2226 0 1300 163 0 1600 490 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. Signed '~~~ ~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 2M-17 GSW DATAFRAC W/DS YF140D. PUMP XLGSW BREAKDOWN @ 25 BPM. ESTIMATED FG=.74 PSI/FT A.ND FLUID EFFICIENCY OF 30% PLUS. FOLLOWED WITH XLGSW FRAC W/DS YF140D. FRICTIONAL PRESSURES APPEARED LOWER THAN AAI CORRELATIONS WOULD INDICATE. PUMP 445 BBL PAD @ 25 BPM, LAST WHTP=4499 PSI. PUMPED 19.5 MLBS 16/20 LWP IN 2 & 4 PPA STAGE & 175 MLBS 12/18 LWP IN 4-12 PPA STAGES @ 25 BPM. JOB PUMPED AS DESIGNED THROUGH FLUSH. TOT PROP: DESIGN=199.7 MLBS, IN FORiM=193.5 MLBS W/12.2 PPA @ PERFS. ESTIMATE 1200 LBS LEFT IN WELLBORE. TOT FLUIDS: WATER=1683 BBL, DSL(FLA)=30 BBL, ADD'S=127 BBL. ALL FLUIDS LOOKED GOOD, SAMPLES BROKE OK. (LENZ/CRABTREE) RECEIVED MAY 2 0 1994 A!~ska Oil & &as Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 11, 1992 Transmittal #' 8619 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. Receipt Acknowledged' 2M-27"' CDR 09-19-92 3117-7855 2M 27j ~ 09-19-92 3117-7855 2 M- 26--" CDR 07-28-92 2859-6765 2M 26 ~' CISN 07-28-92 2859-6765 2M-09 ~" CDR 09-1 8-92 4359-1 2177 2M 09/' CDN 09-18-92 4326-12177 2M-30 j CDR 09- 1 9-92 3507-9350 2M 30/'' CDN 09-19-92 3507-9350 / 17~' C.Z:)R 11-18-92 3212-7947 06 ~ CDR 09-1 7-92 3790-5732 06 .-- CDN 09-1 7-92 3790-5732 DISTRIBUTION: Date' DEC '14-1992 Alaska Oil & Gas Cons. Commission Anchorage D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: December 4, 1992 Transmittal #: 8614 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and 'return one signed copy of this transmittal. 2M 1 7~ - LIS Tape and Listing o~' 1 1 - 1 9 - 9 2 9 2 4 0 9 2 M 0 1 ~ .5'~-"' LIS Tape and Listing ,~ ~ 1 1 - 2 5 - 9 2 9 2 6 4 0 2 M 0 8,~ .~'(/~' LIS Tape and Listing ,~ ~ 1 1 - 3 - 9 2 9 2 6 6 7 Receipt Acknowledged' ~-~ Date' i~-E-CE I V'E D DEC 0 7 1992 DISTRIBUTION: Alaska 0il & Gas Cons. Commission Anchorage Lynn Goettinger State of Alaska ~-'" STATE OF ALASKA ~' 0 ~ ~ ~ ~ ?~! ~ AL~oKA OIL AND GAS CONSERVATION C~,v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [] GAS I--"1 SUSPENDED r~ ABANDONED r~ SERVICE r-"i 2 Name of Operator 7 Permil Number ARCO Alaska, Inc 91-18 3 Address 8 APl Number P.O, Box 100360, Anchorao~e, AK 99510-0360 50-103-20150 4 Location o~ well at surface ~ ...... 9 Unit or Lease Name 114' FSL, 379' FWL, SEC 27, T11 N, R8E, UM ? , ~0~] ! ] ~TIOI'~i KUPARUK RIVER 1363'FSL, 1501'FWL, SEC34, TllN R8E U 10 Well Nu~r , , ~ "~;~I ~t~-~. ~ 2M-17 At Total Depth ~...:?:,,z~.~' 11 Field and Pool 1120' FSL, 1570' FWL SEC 34, T11 N, RSE,, UM '~"*~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) ] 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 147', PAD 106' GLI ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore J16 No. of Completions 07106192. 07/10/92. 09/04/92. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directiorml Survey 20 Depth where SSSV set 21 Thickness of permafrost 7947' MD, 6395' TVD 7857' MD, 6326' TVD YES X~J NO L.J 1813' feat MD 1400' APPROX 22 Type Electric or Other Logs Run CDR,CDN,GR,CET,CBT, HLDT,GYRO, 23 CASING, UNER AND CEMENTING RECORD I SET'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 121' 24' 225 SX ASl 9-5~8" 36# J-55 SURF 3189' 12-1/4' 545 SX PF E,507 SX CLASS 123 SX PFC TOP JOB 7' 26# J-55 SURF 7941' 8-1/2' 208 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET {MD) 3-1/2', 9.3#, J-58 7467" 7439' 7630' -7662' W/4-1/2' CSG GUN ~ 4 SPF MD 6151 '-6176' 'rVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method (d Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 · CORE DATA Brief description of I,hology, porosity, fractures, apparent dips and presence of o,. gas or water. Submit co. ch.. Alaska OJJ & Gas C,,'x~,s, CommJssioP Form 10-407 Submit in duplicate Rev. 7-1-80 ~NUEDON REVERSES[:)E GE-CLOC_..~3 ~ FORlvlA~ TESTS NNV~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARU K C TOP 7552' 6091' NA KUPARUK C BO'I-rOM 7560' 6097' KUPARUK A TOP 7560' 6097' KUPARUK A Bo'FrOM 7747' 6241' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONg PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-17 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-103-20150 ACCEPT: 07/07/92 12:07 SPUD: 07/07/92 06:07 RELEASE: 09/04/92 06:09 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 07/07/92 ( 1) TD: 2146' ( 0) 07/08/92 ( 2) TD: 2146' ( 0) 07/09/92 ( 3) TD: 4100' (1954) 07/10/92 ( 4) TD: 7790' (3690) DRILLING MW: 9.6 VIS: 68 RIG MOVED FROM 2M-26. ACCEPT RIG @ 7/6/92 12:00. NU DIVERTER. MIX SPUD MUD. TEST DIVERTER AND ADJUCT LAY DOWN MACHINE GUIDES. SAC DL. PU BHA. CIRC AND COND MUD. ORIENT TOOLS. SPUD AND DRILL F/ 121-2146. WASH 9-5/8 CASING 9-5/8"@ 3189' MW: 9.6 VIS: 40 DRILL F/ 2146-3210. CIRC AND COND MUD. POH. SWAB F/ 1630-1300. CHANGE BIT BECAUSE OF JET BLOW OUT. REAM BRIDGES F/ 1400-1458 AND 1480-1600. CIRC AND COND MUD. DROP SINGLE SHOT. PUMP DRY JOB. POH LD BHA. RU TO RUN CSG. HOLD SFTY MTG. RUN 9-5/8 CSG. LD 1 JT 'AND PU HANGER AND LANDING JT. DRILLING 9-5/8"@ 3189' MW: 8.9 VIS: 31 CIRC AND COND HOLE TO CMT. CMT W/ 191 BBL E CMT AND 104 BBL G CMT. BUMPED PLUG, FLOATS HELD. LD CMT HD AND LANDING JT. ND DIVERTER. DO TOP JOB. INSTALL PACKOFF AND SPEED HEAD. NU AND TEST BOP. MU AND ORIENT BHA. RIH. TEST CSG TO 2000 PSI. DRL PLUGS, FC, FS, AND 10' NEW FORMATION. TEST HOLE TO 12.5 EMW. DRIL F/3220-4100. DRILLING 9-5/8"@ 3189' MW: 8.9 VIS: 37 DRILL AND SURVEY F/4100'-7790' 07/11/92 ( 5) TD: 7947' ( 157) 07/12/92 ( 6) TD: 7947' ( 0) RUN 7 CASING 7"@ 7941' MW:10.3 VIS: 43 DRILL F/ 7790-7945. CIRC AND COND MUD. PUMP DRY JOB. '.SHORT TRIP. SAC DL, SERVICE RIG. REPAIR CROWN-A-MATIC RESET CONTROL. RIH, WASH 7860-7945. CIRC FOR 7" CSG RUN. POH AND LD BHA. HOLD SAFETY MTG. RUN 7" CASING. RELEASE RIG 7"@ 7941' MW:10.3 VIS: 33 RUN 7" CSG. RU CMT HEAD. RECIP PIPE. CMT CSG. MONITOR ANNULUS FLOW, OK. SET SLIPS. ND STACK. MAKE FINAL CUT. INSTALL.PACKOFF. TEST @ 3000 PSI FOR 30 MIN, OK. NU TREE. PUMP 50 BBL WATER AND 45 BBL DIESEL DOWN ANNULUS. REC L IVF 'D Afa$l¢a Oi~ & f~.,.; gons. gommissJo,~ WELL : 2M-17 OPERATION: RIG : NORDIC 1 PAGE: 2 09/04/92 ( 7) TD: 7947 PB: 7857 RIG RELEASED 7"@ 7941' MW:10.2 NaC1/Br MVE RIG F/2M-14 TO 2M-17. ACCEPT RIG @ 08:30 HRS 09/03/92. ND TREE. NU BOPE. TEST ALL TO 3000 PSI. TEST 7" CSG TO 3500 PSI-OK. RU SWS. MU PERF GUNS. PERF A SAND IN 2 GUN RUNS F/7662'-7630' ALL GUNS SWS 4-1/2" CSG GUN 2 4 SPF, 180 DEGREE PHASING, ALTERNATING 24 & 21 BH SHOTS. NU FLOW NIPPLE. RU FOSTER TONG. RUN 3-1/2" SINGLE COMPLETION STRING. TBG TAIL @ 7467', BAKER HB RETRV PKR @ 7439', & CAMCO TRDP-4A-RO SSSV @ 1813'. TEST ANN & TBG -OK. TEST SSSV-OK. ND BOPE. NU TREE. TEST TREE TO 250 & 5000 PSI. TEST PACKOFF-ALL OK. RU LINES & OPEN SSSV. DISPLACE WELL TO DIESEL W/ 12 BBLS DN ANN & 4 BBLS DN TBG. SECURE WELL. RELEASE RIG @ 06:00 HRS 09/04/92. SIGNATURE: ORIGINAL SUB - S URFA CE DIRECTIONAL r~ UIDANCE r~-I ONTINUOUS r~ OOL SURVEY · 4~ask., 0it r~.Gas Cons /lnOhorag-e' Company Well Name Field/Location ARCO ALASKA, INC. 2N-17 (114' FSL, 379' FE'L, SEC 27, T11N, R8E,IJM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 92494 Logged BV: PORTER Computed By: ~t~,..~.!/_on, / ~ KRU#ELL · SCHLLklBERGER * OCT DIRECTIONAL SURVEY CUSTOMER LISTINO FOR ARCO ALASKA, INC. KUPARUK RUVER UNIT NORTH SLOPE, ALASKA SURVEY DATE' 13-AUG-1992 ENGINEER' K. PORTER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 14 DEG 22 MIN EAST COMPUTATION DATE' 21-SEP-92 PAGE 1 ARCO ALASKA, INC. 2M-17 KUPARUK RUVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 13-AUG-1992 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER' K. PORTER INTERPOLATED VN..UES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUD-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMLrrH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 200.00 300.00 400.00 500.00 500.00 700.00 800.00 900.00 0 O0 -146.00 100 O0 200 O0 299 99 399 99 499 91 599 42 698 03 795 77 892 34 0 0 -46.00 0 26 54 O0 0 22 153 99 0 17 253 99 0 44 353 91 3 38 453 42 7 42 552 03 10 56 649 77 13 29 746 34 16 22 N 0 0 E S 53 16 E S 73 43 E S 56 40 E S 35 3 E S 23 25 E S 20 28 E S 21 38 E S 19 52 E S 18 31E 0 O0 0 23 0 65 0 98 I 61 5 21 14 74 31 19 52 14 77 97 0 O0 0 32 0 09 0 O0 I 27 2 73 4 46 2 36 2 93 2 33 000 N 0 18S 0455 0655 I 18S 449 S 13 42 S 28 85 S 48 55 S 73 04 S 0.00 E 020E 088E I 38E I 87 E 3 50 E 704E 13 06 E 20 58 E 29 07 E 0 O0 N 0 0 E 0 0 1 2 5 15 31 52 78 27 S 48 5 E 99 S 62 53 E 53 S 64 42 E 21 S 57 50 E 69 S 37 56 E 15 S 27 42 E 67 S 24 22 E 74 S 22 58 E 61 S 21 42 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 987 56 O0 1081 O0 1172 O0 1262 O0 1349 O0 1434 O0 1517 O0 1599 O0 1679 O0 1759 641.56 19 21 O0 935.00 22 9 56 1026.66 24 46 29 1116.29 28 9 30 1203.30 30 43 55 1288.55 32 25 98 1371.98 34 34 29 1453.29 36 22 62 1533,62 36 39 84 1613.84 36 43 S 1747 E S 17 49 E S 18 10 E S 1854 E S 19 18 E S 18 50 E S 1828 E S 17 19 E S 1642 E S 17 8 E 108 41 143 94 183 81 227 99 277 09 329 17 384 14 442 22 501 72 561 38 3 50 2 73 I 84 3 17 I 70 I 99 I 95 I 14 0 08 0 83 102 05 S 135 173 215 262 311 364 419 476 533 38 51 E 109 07 S 20 41 E 92 S 49 94 S 61 95 S 75 50 S 91 86 S 109 12 S 126 48 S 144 46 S 161 61S 179 43 E 144 69 E 184 73 E 228 90 E 278 04 E 330 56 E 385 52 E 443 84 E 503 13 E 562 63 S 19 59 E 56 S 19 32 E 84 S 19 20 E 12 S 19 18 E 37 S 19 16 E 49 S 19 10 E 68 S 19 I E 20 S 18 46 E 88 S 18 33 E 2000 O0 1839 75 1693 75 37 8 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1919 O0 1999 O0 2079 O0 2159 O0 2240 O0 2319 O0 2399 O0 2478 O0 2557 52 1773 41 1853 57 1933 87 2013 07 2094 84 2173 38 2253 64 2332 92 2411 S 19 52 E 621.34 52 37 2 S 20 49 E 681.31 41 36 52 S 21 21 E 741.05 57 36 35 S 21 37 E 800.37 87 36 33 S 21 59 E 859.46 07 36 53 S 22 9 E 918.65 84 37 10 S 21 58 E 978.42 38 37 33 S 21 20 E 1038.53 64 37 25 S 20 53 E 1099.09 92 37 52 S 19 37 E 1159.71 I 34 0 37 0 51 0 26 0 33 0 63 0 42 0.82 O. 56 I .21 590.65 S 198 09 E 622 99 S 18 32 E 647.16 S 219 703.29 S 240 758.91S 262 814.26 S 284 869.59 S 307 925.50 S 329 981.80 S 352 1038.72 S 374 1095.86 S 395 16 E 683 79 E 743 69 E 803 81E 862 30 E 922 92 E 982 37 E 1043 22 E 1104 42 E 1165 27 S 18 43 E 37 S 18 54 E 09 S 19 6 E 63 S 19 17 E 29 S 19 28 E 54 S 19 37 E 11 S 19 45 E 07 S 19 49 E 02 S 19 50 E 3000 O0 2636.44 2490 44 38 44 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2714 07 2568 O0 2792 07 2646 O0 2870 77 2724 O0 2949 15 2803 O0 3026 73 2880 O0 3103 88 2957 O0 3179.77 3033 O0 3255.13 3109 O0 3330.33 3184 07 39 8 07 38 10 77 38 11 15 38 47 73 39 19 88 39 58 77 41 2 13 41 9 33 41 18 S 17 56 E 1221 43 S 15 44 E 1284 S 15 35 E 1346 S 15 32 E 1408 S 15 22 E 1470 S 15 I E 1533 S 14 33 E 1597 S 13 39 E 1662 S 13 52 E 1728 S 13 54 E 1794 41 97 66 74 84 46 57 30 22 2 85 0 42 I 51 0 17 1 3O 0 09 2 07 0 23 0 18 0 18 1154 42 S 415 52 E 1226 93 S 19 48 E 1214 1275 1334 1394 1455 1516 1580 1643 1707 86 S 433 11S 450 56 S 466 39 S 483 32 S 499 80 S 516 O0 S 531 8.5 S 547 84 S 563 41E 1289 28 E 1352 81E 1413 44 E 1475 86 E 1538 22 E 1602 90 E 1667 52 E 1732 33 E 1798 86 S 19 38 E 28 S 19 27 E 85 S 19 17 E 82 S 19 7 E 77 S 18 57 E 24 S 18 48 E 12 S 18 36 E 63 S 18 25 E 35 S 18 15 E COMPUTATION DATE' 21-SEP-92 PAGE 2 ARCO ALASKA, INC. 2M-17 KUPARUK RUVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY* 13-AUG-1992 KELLY BUSHING ELEVATION* 146.00 FT ENGINEER' K. PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURE) DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION tZI~llrH DEPTH DEPTH DEPTH DEG WIN DEG WIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH E~T/WEST DIST. AZID~JTH FEET DEG/IOO FEET FEET FEET DEG MIN 4000 O0 3405.40 3259.40 41 21 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3480 38 3334.38 41 34 O0 3555 O0 3629 O0 3704 O0 3778 O0 3852 O0 3926 O0 4000 O0 4075 07 3409.07 41 46 62 3483.62 41 50 10 3558.10 41 53 44 3632.44 42 6 50 3706.50 42 18 34 3780.34 42 31 28 3854.28 41 39 50 3929.50 41 9 S 12 53 E i860 27 S ll 36 E 1926 S 11 39 E 1992 S li 42 E 2059 S ii SS E 2126 S 12 7 E 2192 S 12 19 E 2260 S 12 33 E 2327 S 12 13 E 2394 S 12 2 E 2460 37 79 37 03 86 O0 40 69 53 2 5O 0 25 0 16 0 14 0 3O 0 26 0 28 0 28 2 66 0 33 1772 04 S 578 92 E 1864 21 S 18 6 E i836 1901 i967 2032 2097 2i63 2229 2295 2359 77 S 592 90 S 605 19 S 619 51S 633 94 S 646 61S 661 46 S 675 19 S 690 64 S 703 59 E i929 96 E 1996 42 E 2062 03 E 2128 95 E 2195 15 E 2262 69 E 2329 27 E 2396 97 E 2462 99 S 17 53 E 10 S 17 40 E 40 S 17 29 E 81 S 17 18 E 42 S 17 8 E 37 S 17 0 E 60 S 16 52 E 74 S 16 44 E 41 S 16 37 E 5000 O0 4150 62 4004 62 41 27 5100 5200 5300 5400 S500 5600 S700 5800 5900 O0 4225 O0 4300 O0 4377 O0 4453 O0 4529 O0 4605 O0 4681 O0 4756 O0 4831 52 4079 90 4154 25 4231 64 4307 95 4383 76 4459 15 4535 27 4610 37 4686 52 41 31 90 40 24 25 40 10 64 40 12 95 40 25 76 40 58 15 41 9 27 41 27 37 40 46 S 12 20 E 2526 49 S 12 27 E 2592 S 12 6 E 2658 S 12 8 E 2722 S 12 16 E 2787 S 12 23 E 2851 S 12 40 E 2917 S 12 47 E 2982 S 12 54 E 3048 S 13 50 E 3114 70 36 90 39 97 15 82 81 82 0 24 0 28 i 11 0 11 0 02 0 71 0 47 0 31 0 32 2 26 2424.16 S 717 89 E 2528-.23 S 16 30 E 2488.87 S 732 2553.07 S 746 2616.22 S 759 2679.30 S 773 2742.43 S 787 2806.09 S 801 2870.18 S 815 2934.54 S 830 2998.81 S 845.44 E 3115 11 E 2594 32 S 16 23 E 12 E 2659 66 E 2724 29 E 2788 07 E 2853 22 E 2918 69 E 2983 34 E 3049 86 S 16 17 E 28 S 16 11E 66 S 16 6 E 14 S 16 1E 24 S 15 56 E 84 S 15 52 E 76 S 15 48 E 71 S 15 45 E 6000.00 4907 44 4761 44 40 31 6100.00 4983 6200.00 S060 6300.00 5137 6400.00 5214 6500.00 5290 6600.00 5366 6700.00 5442 6800.00 5519 6900.00 5594 60 4837 30 4914 25 4991 08 5068 68 5144 81 5220 89 5296 O0 S373 93 5448 60 40 9 30 39 45 25 39 37 08 39 S9 58 40 13 81 40 26 89 40 28 O0 40 29 93 40 42 S 14 12 E 3179 72 S 14 37 E 3244 53 S 14 53 E 3308 70 S 15 14 E 3372 56 S iS 26 E 3436 SS S 15 42 E 3500 94 S 1S 53 E 3565 65 S 14 29 E 3630 54 S 14 27 E 3695.40 S 14 30 E 3760.47 O. 25 0.65 O. 37 O. 44 O. 38 O. 25 0.21 O, 95 0,34 0.14 3061 77 S 861 25 E 3180.59 S 15 43 E 3124 3186 3248 3310 3372 3434 3496 3559 3622 54 S 877 61S 893 27 S 910 O0 S 927 03 S 944 32 S 962 91S 979 75 S 995 75 S 1011 34 E 3245.38 S 15 41 E 66 E 3309.54 S 15 40 E 28 E 3373.40 S 15 39 E 19 E 3437.41 S 15 39 E 48 E 3501.81 S 15 39 E 08 E 3566.54 S 15 39 E 26 E 3631.43 S 15 39 E 32 E 3696.28 S 15 37 E 60 E 3761.34 S 15 36 E 7000 O0 5670 71 5524 71 40 44 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 5746 O0 5822 O0 5898 O0 5974 O0 6051 O0 6127 O0 6204 O0 6281 61 5600 36 S676 44 5752 74 5828 21 5905 93 5981 95 6058 98 6135 O0 6358.89 6212 51 40 42 36 40 37 44 40 20 74 40 12 21 40 7 93 39 40 95 39 33 98 39 43 89 39 44 S 14 42 E 3825.71 S 15 1E 3890.95 S 15 8 E 3956.11 S 15 21 E 4021.00 S 15 26 E 4085 62 S 15 18 E 4150 06 S 15 39 E 4214 18 S 16 2 E 4277 94 S 15 58 E 4341 68 S 15 57 E 4405 55 0 04 0 19 0 26 0 46 0 30 0 22 0 02 0 30 0 08 0 O0 3685.89 S 1028 03 E 3826 57 S 15 35 E 3748.95 S 1044 3811.87 S 1061 3874.48 S 1078 3936.80 S 1095 3998.95 S 1112 4060.76 S 1130 4122.13 S 1147 4183.42 S 1165 4244.86 S 1182 73 E 3891 80 S 15 34 E 70 E 3956 97 S 15 34 E 77 E 4021 86 S 15 34 E 92 E 4086 50 S 15 33 E 96 E 4150 94 S 15 33 E 06 E 4215 07 S 15 33 E 44 E 4278 85 S 15 33 E 06 E 4342.62 S 15 34 E 61 E 4406.52 S 15 34 E COMPUTATION DATE: 21-SEP-92 PAGE 3 ARCO ALASKA, INC. 2M-17 KUPARUI( RUVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 13-AUG-1992 KELLY BUSHING FIEVATION: 146.00 FT ENGINEER: K. PORTER INTERPOLATED VALUE FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 7947.00 6395.03 6249.03 39 44 S 15 57 E 4435.59 0.00 4273.75 S 1190.86 E 4436.56 S 15 34 E COMPUTATION DATE: 21-SEP-92 PAGE 4 ARCO ALASKA, INC. I~-17 KUPARUK RUVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: 13-AUG-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: K. PORTER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEA.SUR8 VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG WIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 1000.00 987 2000.00 1839 3000.00 2636 4000.00 3405 5000.00 4150 6000.00 4907 7000.00 5670 7947.00 6395 0 O0 -146 O0 0 0 N 0 0 E 0 O0 56 841 41 75 1693 34 44 2490 43 40 3259 27 62 4004 49 44 4761 72 71 5524 71 03 6249 59 56 19 21 S 17 47 E 108 75 37 8 S 19 52 E 621 44 38 44 S 17 56 E 1221 40 41 21 S 12 53 E 1860 62 41 27 S 12 20 E 2526 44 40 31 S 14 12 E 3179 71 40 44 S 14 42 E 3825 03 39 44 S 15 57 E 4435 0.00 3.50 102 1.34 590 2.85 1154 2.50 1772 0.24 2424 0.25 3061 0.04 3685 0.00 4273 0 O0 N 05 S 38.51 E 109 65 S 198.09 E 622 42 S 415.52 E 1226 04 S 578.92 E 1864 16 S 717.89 E 2528 77 S 861.25 E 3180 89 S 1028.03 E 3826 75 S 1190.86 E 4436 0.00 E 0 O0 N 0 0 E 07 S 20 41E 99 S 18 32 E 93 S 19 48 E 21 S 18 6 E 23 S 16 30 E 59 S 15 43 E 57 S 15 35 E 56 S 15 34 E COMPUTATION DATE' 21-SEP-92 PAGE ARCO ALASKA, INC. 2M-17 KUPARUK RUVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY* 13-AUG-1992 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER* K. PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 146 O0 246 O0 346 01 446 02 546 23 647 12 748 97 851 86 9,56 14 0 O0 -146. O0 146 O0 246 O0 346 O0 446 O0 546 O0 646 O0 745 O0 846 O0 946 O0 0 0 N 0 OE 0.00 0 26 S 70 50 E 100.00 0 19 S 69 8 E 200.00 0 21 S 45 50 E 300.00 I ,55 S 27 34 E 400.00 ,5 16 S 22 14 E 500.00 9 36 S 21 25 E 600.00 12 8 S 21 7 E 700.00 15 8 S 19 6 E 800.00 17 S2 S 17 57 E 0 O0 0 45 0 80 i 17 2 54 8 71 21 80 40 91 64 96 94 43 0 O0 0 O0 0 15 0 25 4 52 4 67 3 81 2 22 2 98 3 22 O00N 033S 053S 081S 202S 7 74S 20 05 S 37 97 S 60 69 S 88 72 S 0.00 E 0.51 E 1.14 E 1,58 E 2.37 E 4.87 E 9.57 E 16.64 E 24.86 E 34,22 E 0.00 N 0 0 E 0.61 S 56 58 E I .26 S 65 5 E 1.77 S 62 52 E 3.11 S 49 39 E 9.14 S 32 9 E 22.22 S 25 32 E 41.46 S 23 40 E 65.59 S 22 17 E 95.09 S 21 6 E L062 33 1046 O0 L170 L281 L396 LS13 .634 .758 .882 :007 !133 900. O0 21 14 71 1146 56 1246 17 1346 60 1446 19 1546 10 1646 74 1746 83 1846 17 1946 O0 1000.00 24 10 O0 1100.00 27 29 O0 1200.00 30 39 O0 1300.00 32 41 O0 1400.00 35 19 O0 1500.00 36 36 O0 1600.00 36 41 O0 1700.00 37 10 O0 1800.00 37 I S 1756 E S 17 58 E S 1842 E S 19 18 E S 1843E S 18 17 E S 1648E S 1659 E S20 5E S21 OE 130 03 171 70 219 38 275 14 336 48 403 68 476 75 551 07 626 OS 701 15 2 18 2 33 4 56 I 91 i 98 2 48 0 33 0 57 I O3 0 48 122 66 S 162 207 260 318 382 452 523 595 665 45 15 E 130.71 S 20 12 E 41S 57 77 S 72 65 S 91 81S 111 71S 132 52 S 154 75 S 176 11S 199 82 S 226 93 E 172 43 S 19 38 E 95 E 220 25 E 276 39 E 337 73 E 405 64 E 478 11E 552 68 E 627 28 E 703 21 S 19 21E 16 S 19 18 E 71 S 19 16 E 08 S 19 8 E 22 S 18 52 E 57 S 18 35 E 71 S 18 33 E 23 S 18 46 E !258 17 2046 O0 1900.00 36 40 ~382 73 2146 ~507 41 2246 ~632 84 2346 ~758 85 2446 ~88,4 92 2546 1012.25 2646 1141.09 2746 ,268.50 2846 O0 2000.00 36 34 O0 2100.00 36 S6 O0 2200.00 37 12 O0 2300.00 37 36 O0 2400.00 37 45 O0 2500.00 38 54 O0 2600.00 38 53 O0 2700.00 38 8 395.97 2946.00 2800.00 38 44 S 21 31E 775.61 S 21 54 E 849.27 S 22 8 E 923.05 S 21 54 E 998.10 S 20 56 E 1074.19 S 19 52 E 1150.51 S 17 27 E 1229.08 S 15 39 E 1310.27 S 15 31 E 1389.21 S 1,5 24 E 1468.23 0 44 0 32 0 67 0 47 0 45 I 45 3 42 0 87 0 31 1 26 735 71 S 253 52 E 778 17 S 19 I E 804 873 943 1015 1087 1161 1239 1315 1391 71S 280 7O S 3O8 91S 337 30 S 365 16 S 392 71S 417 76 S 440 81S 461 96 S 482 97 E 852 97 E 926 33 E 1002 28 E 1079 30 E 1155 89 E 1234 40 E 1315 60 E 1394 77 E 1473 35 S 19 15 E 73 S 19 29 E 37 S 19 40 E O1 S 19 47 E 77 S 19 51E 59 S 19 47 E 66 S 19 33 E 43 S 19 20 E 30 S 19 8 E 524 92 3046.00 2900 O0 39 21 655 30 3146.00 3000 787 87 3246 O0 3100 920 87 3346 O0 3200 054 10 3446 O0 3300 187 84 3545 O0 3400 321 99 3646 O0 3500 456 32 3746 O0 3600 591.21 3846 O0 3700 726.68 3946 O0 3800 O0 40 49 O0 41 8 O0 41 20 O0 41 25 O0 41 45 O0 41 51 O0 41 59 O0 42 18 O0 42 34 S 15 2 E 1549 63 S 13 45 E 1633 S 13 51E 1720 S 13 54 E 1807 S 11 44 E 1896 S 11 38 E 1984 S 11 43 E 2O74 S 12 2 E 2163 S 12 17 E 2254 S 12 36 E 2345 28 32 99 01 70 02 63 09 42 0 07 I 01 0 12 0 23 0 76 0 16 0 08 0 24 0 26 0 31 1470 57 S 503 95 E 1554 52 S 18 55 E 1551 1636 1721 1806 1893 1981 2069 2157 2247 53 S 524 10 S 545 21S 566 99 S 586 97 S 6O4 55 S 622 33 S 64O 82 S 659 06 S 679 98 E 1637 61E 1724 64 E 1812 45 E 1899 33 E 1988 39 E 2076 84 E 2166 89 E 2256 62 E 2347 94 S 18 42 E 67 S 18 27 E 09 S 18 13 E 78 S 17 59 E 05 S 17 42 E 99 S 17 26 E 29 S 17 12 E 47 S 17 0 E 58 S 16 50 E COMPUTATION DATE: 21-SEP-92 PAGE 6 ~RCO ALASKA, INC. .N-17 ;UPARIJK RUVER UNIT JORTH SLOPE, ALASKA DATE OF SURVEY: 13-AUG-1992 KELLY BUSHING ELEVATION: 146. O0 FT ENGINEER: K. PORTER INTERPOLATED VALUE FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SI.~-SEA COURSE -]~SURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGUL~ COORDINATES HORIZ. DEPAR31JRE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 1860 84 4046 O0 3900 O0 41 6 t993 i127 ;259 ;390 ;521 ;653 ;786 i919 i050 84 4146 34 4246 10 4346 O0 4446 09 4546 35 4646 30 4746 30 4846 70 4946 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 41 26 O0 41 27 O0 40 11 O0 40 11 O0 40 33 O0 41 5 O0 41 24 O0 40 25 O0 40 27 S 11 55 E 2434 80 S 12 19 E 2522 S 12 26 E 2610 S 12 7 E 2696 S 12 16 E 2780 S 12 27 E 2865 S 12 44 E 2952 S 12 52 E 3039 S 14 7 E 3127 S 14 22 E 3212 41 80 53 94 65 16 74 40 65 0 18 0 25 0 62 0 20 0 01 0 54 0 19 0 25 1 16 0 57 2334 45 S 698 62 E 2436 75 S 16 40 E 2420 2506 2590 2672 2755 2840 2925 3011 3093 18 S 717 56 S 736 42 S 754 99 S 771 80 S 790 26 S 808 70 S 828 04 S 848 68 S 869 02 E 2524 01E 2612 12 E 2697 92 E 2782 01E 2866 91E 2953 32 E 3040 46 E 3128 36 E 3213 16 S 16 30 E 38 S 16 22 E 96 S 16 14 E 22 S 16 6 E 80 S 16 0 E 21 S 15 54 E 70 S 15 48 E 30 S 15 44 E 51 S 15 42 E 1181 40 5046 O0 4900 O0 39 47 i311 1441 ;572 i704 i835 i967 '099 '231 '362 36 5146 68 5246 67 5346 09 ,5446 S2 5546 38 5646 33 5746 13 5846 35 5946 O0 5000 O0 SIO0 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 39 38 O0 40 4 O0 40 24 O0 40 27 O0 40 34 O0 40 44 O0 40 42 O0 40 31 O0 40 15 S 14 47 E 3296.80 S 15 15 E 3379.81 S 15 34 E 3463.35 S 15 49 E 3547.94 S 14 27 E 3633.19 S 14 31E 3718.48 S 14 38 E 3804.43 S 15 1 E 3890.51 S 15 11E 3976.35 S 15 26 E 4061.31 0 39 0 41 0 28 0 26 0 78 0 28 0 14 0 19 0.36 0.21 3175 11 S 890 61 E 3297 65 S 15 40 E 3255 26 S 912 3335 83 S 934 3417 28 S 957 3499 48 S 979 3582 10 S 1001 3665 31S 1022 3748 53 S 1044 3831.41 S 1066 3913.36 S 1089 19 E 3380 35 E 3464 24 E 3548 92 E 3634 09 E 3719 64 E 3805 62 E 3891 99 E 3977 45 E 4062 66 S 15 39 E 21 S 15 39 E 82 S 15 39 E 09 S 15 39 E 35 S 15 37 E 29 S 15 35 E 37 S 15 34 E 21 S 15 34 E 18 S 15 33 E '493.19 6046.00 5900.00 40 7 '623.47 6146.00 6000.00 39 40 '753.27 6246.00 6100.00 39 39 '883.24 6346.00 6200.00 39 44 '947.00 6395.03 6249.03 39 44 S 15 18 E 4145.67 S 15 42 E 4229.16 S 16 4 E 4311.88 S 15 57 E 4394.85 S 15 57 E 4435.59 O. 22 0.25 0.15 0. O0 0. O0 3994.72 S 1111.80 E 4146.55 S 1S 33 E 4075.19 S 1134.11 E 4230.06 S 15 33 E 4154.76 S 1156.82 E 4312.81 S 15 34 E 4234.56 S 1179.67 E 4395.81 S 15 34 E 4273.75 S 1190.86 E 4436.56 S 15 34 E COMPUTATION DATE: 21-SEP-92 PAGE 7 RCO ALASKA, INC. ~-17 ~PARtJK RUVE~ UNIT DRTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARL.JK C TOP KUPARUK A BASE KUPARLJK A LAST READINQ QCT PBTD 7m CASING DATE OF SURVEY: 13-AUQ-1992 KELLY BUSHING ELEVATION: 146.00 FT ENQINEER: K. PORTER IN'~O~TED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL & 379' FWL, SEC27 TllN R8E UM MEASURED DEPTH BEI_O~/ KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3146.00 2749.82 7552.00 6091.04 7560.00 6097.18 7660.00 6097.18 7747.00 6241.17 7800.69 6282.51 7857.00 6325.82 7941.00 6390.42 7947.00 6395.03 2603 82 5945 04 5951 18 5951 18 6095 17 6136 51 6179 82 6244 42 6249 03 1242.73 S 4031.19 S 4036.13 S 4036.13 S 4150.92 S 4183.84 S 4218.43 S 4270.06 S 4273.75 S 441.24 E 1121 82 E 1123 19 E 1123 19 E 1155 72 E 1165 18 E 1175 O6 E 1189 81E 1190 86 E COMPUTATION DATE: 21-SEP-92 PAGE ~C0 ALASKA, INC. A-17 JPARUK RUVER UNIT )RTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING DATE OF SURVEY: 13-AUG-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: K. PORTER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 114' FSL & 379' FWL, SEC27 TllN R8E UM M~ED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3146.00 7552.00 7560.00 7560.00 7747.00 7800.69 7857.00 7941,00 7947.00 2749 82 6091 04 6097 18 6097 18 6241 17 6282 51 6325 82 6390 42 6395 03 2603 82 5945 04 5951 18 5951 18 6095 17 6136 51 6179 82 6244 42 6249 03 1242 73 S 4031 19 S 4036 13 S 4036 13 S 4150 92 S 4183 84 S 4218 43 S 4270 06 S 4273 75 S 441.24 E 1121.82 E 1123 19 E 1123 19 E 1155 72 E 1165 18 E 1175 06 E 1189 81E 1190 86 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MF_ASUR~ VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7947.00 6395.03 6249.03 4436.56 S 15 34 E DIRECTIONAL SURVEY CC~m,Am' ARCO ALASKA, INC. mm.D KUI=ARUK Rt. NER UNIT w~.l. ~d.-17 CO~INT~Y U~A =Am -c~=m~ 15 - AU~ - m mmu~mSmmm~ ~ m m v~mm m ~mnmmm m m m m ~m~ ~m~m~ ~m~m m WELL' ~17 (114' FSL. 379' F~L. SEC 27, Tll)1, RSE, Urn) NOR IZONTAL PROJECTICN i/ELL: 2g-17 (114' FSL, 379' Fb'L, SEC 27, TllN, R8E, UI'*I) VERTZCAL PROJECTZON o o 1000 .I PERMIT a ,,, ?./ - COMPLETION DATE AOGCC GEOLOGICAL MATERIALS ]N~/ENTORY LIST /<~ WELL NAME /(-//~' ~/t,/..- CO. CONTACT /IKco I .... Check off or list dat'~'a~" it is received.*list'received date for 407, if not requir, ed !ist as NR 41~'. J../o/~"~,~.~.. /.._: ~ J drill'ine, histow, ,1~1 ~,~.v I'. . , . / 'j. 'well. tests "J corc..descriptio~ .... Cored ~ntcwalS core analysis J , d~ ditch intc~als digital data ............ ~s~F c ~) " ........ · ~ ~ 0~2 ...... ,,,,, ,I, ,,I ..... , LOG TYPE ' I RUN ' INTERVALS SCALE NO. ,,[to the nearest,foot.I , [inchl100"] ~/~ / 317 ~-- ?f~7 .~ ~ iiiii jllll i ii i i ....... 4~ i iii. i ii ii ,,,,, ', c ~ ......... ,, ~, , 111 ' i ~1 ....... , ARCO Alaska, Inc. Date: September 25, 1992 Transmittal #: 8559 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items., Please acknowledge receipt and return one signed copy of this transmittal. 2M-14 j Sub-Surface Directional 9-14-92 92497 / Survey 2 M - 2 8 Sub-Surface Directional 9 - 1 7 - 9 2 9 2 5 0 6 Survey 2M-1 7 / Sub-Surface Directional 9- 1 3-92 92494. Survey Receipt Acknowledged: ~ --~'~---- Date: ........... DISTRIBUTION: D&M State of Alaska (2 copies) / CEIVED S£P 2 9 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: August 21, 1992 Transmittal #: 8525 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1~2 M - 1 7 ~"~ LIS Tape and Listing 8 - 1 3 - 9 2 9 2 4 9 5 2 M 1 4 ~ 5 I~LiS Tape and Listing 8- 1 3- 9 2 9 2 4 96 Receipt Acknowledged''"~~/~~-/~--~-~"~'~'--~ate' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED AU(; 2 4 199£ A/aska.0il &eas Cons. Commission Anchorage ARCO Alaska, Inc. Date: August 21, 1992 Transmittal #: 8526 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt .~nd return one signed copy of this transmittal. ~,-'~22M-14 ~-'"' HLDT 8-15-92 8295-9723 ~,~~- 17 Receipt Acknowledged ate' - ......... DISTRIBUTION: D&M NSK Drilling Vendor Package(Johnston) R£CtlVtD Stale of Aiaska(+$epia) AUG 2 · ARCO Alaska, Inc. Date: August 21, 1992 Transmittal #: 8521 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~?""~'33R'2°R 20 /_/,~_.~.3 2M-1 4 q/-l¥ 2M-17 Receipt Drilling Cement Evaluation Log 8 - 8 - 9 2 Cement Bond Log 8 - 8 - 9 2 Cement Evaluation Log 8 - 1 4 - 9 2 Cement Evaluation Log ~/' . / 8- 1 3- 9 2 Acknowledge: ~~'~~~DaIo: State 6f Alaska(+sepia) 9950-10654 9950-10635 8300-9700 6400-7859 NSK RECEIVED AUG 2 4 1992 Qil & Gas Cons. Commission ~chorage · ARCO Alaska, Inc, .. Date: July 17, 1992 Transmittal #: 8479 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. Please acknowledge receipt 2M-20 C[3q 6/23-25/92 2M 20 CDR 6/23-25/92 2M-26 ~ 7/3-5/92 ~2M 26 ~ 7/3-5/92 2M-1 7 CDR 7/8-1 0/92 Receipt Acknowledged: 3398-9070 3398-9070 2839-6765 2839-6765 3190-7947 Date: .......... DISTRIBUTION: D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR ... 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 10, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-17 Rev. ARCO Alaska, Inc. Permit No. 91-18 Sur Loc ll4'FSL, 379'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc 1069'FSL, 1487'FWL, Sec. 34, TllN, R8E, UM Dear McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated February 9.2, 19 91 are in effect for this revision. Sincerely, Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental COnservation w/o encl ,.,,_--~-~")(A STATE OF N_ASKA OIL AND- .~' GAS cONSERVATION COMMI~_, PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory r'~ Stratigraphic r'~ Development Oil X Test Re-Entry r'~ Deepen D Service D Development Gas ~-~ Single Zone X Multiple Zone D 2_ Name of Operator ' 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 147'~ Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchorage~ AK 99510-0360 ADL 25586~ ALK 2672 4. Location of well at surface 7. unit or property Name 11. Type Bond (~ee 20 AAC 25.025) 114' FSL, 379' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1330' FsL, 1420' FWL, Sec. 34, T11N, R8E, UM 2M-17 #UG630610 At total depth 9. Approximate spud date Amount 1069' FSL, 1487' FWL, Sec. 34, T11N, R8E, UM 7/1/92 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number ot acres In property 15. Proposed ¢lepth (MD and lYD) property line 2M- 16 8,009' MD 1069 @ TD feet 21.,8' @ 550' M.D feet 2560 6,417' TVD feet 16. T° be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole angle 41 o Maximum surface 1647 D$1a At total de,th (TVD) 31 50 Dele 18. Casing program Settin Depth size Specifications Top Bottom Quanti~ of cement HOle Casing Weight Grade Coupling Length MD TVD MD TVD llnclude 8ta~le data~ 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' :!:200 CF i 12.25" 9.625" 36.0# J-55 BTC 3181' 41' 41' 3,222' 2,782' 313 Sx Permafrost E & HF-ERW 507 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 3830' 41' 41' 3871' 3275' , HF-ERW 8.5" 7" 26.0# J-55 BTC 4138' 3871' 3275' 8,0'09' 6~417' 165SxClassG HF-ERW Top 500' above Kuparuk 19. To be complete( for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Ceme~d~.~ .L~ ~ured depth True Vertical depth Structural~,E~EIV EL/ Conductor Surface Intermediate Production Liner JUN -- ;) 1992 Perforation depth: measured Alaska 0ii & Gas Cons, C0mm[s$~0tl true vertical Anchorage 20. Attachments Filing fee X property plat D BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'~ Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~l~J ~,~ ~'~~~ Title Area Drillin~ Engineer Date Y""2-'~'~-' APl/mber, nu Cpm ,misSion Use Only .Permi m_ 50- ,'/0 ~- ~ C:~/~Q ~ .~. ~ __~/ ) See cover letter for _ .-- other requirements Conditions of approval Samples required D Yes ~ No 'IVl~ld Io~ r~quired r'"! Yes ~' No Hydrogen sulfide D Yes '~ No Directional survey required ,~ Yes D No measures Required working pressure for BOPE r'~ 2u [~ 3u D SM r'~ 1OM D 1sa Other: Original Signed By by order of Approved by David W. Johnston Commissioner the commission Date ......... ~rm 10-401 Rev. 7-24-89 cate DRILLING FLUID PROGRAM Well 2M-17 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-35 15-35 50-100' 5-15 15-40 10-12 9-10 10% + Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1647 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-17 is 2M-16. As designed, the minimum distance between the two wells would be 21.8' @ 550' MD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. RECEIVED J UN - 3 1992 Alaska 0ii & (~as Cons. Commission Anchorage ARCO ALASKA, Inc. Structure : Pod 2M Well : 17 CREATEO aY : aO~ES For: B M&THEW$ DATE PLOTTED 22-blAY-92 JPkOT REFERENCE tS 17 VERSION #3. JCOORDINATE$ ARE IN FEET REFERENCE SLOT fit. TRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. l I/Ifil ,t ~ Hughe~ comp.any Field : Kuparuk River Unit Location : North Slope, Alaska S 14-.37 DEG. E 4tg§' (TO TARG.ET) ..... East --> 0 2~0 SO0";50 I ! I I ! I I I I JSURFACE LOCATION: ] 114.' FSL, 379' FWL SEC. 27, TI IN, RSE 3O0 · 6OD. - ~O0_ - 12OO_ · 15OO. · ~ 2100_ _ 240O_ . 270(3. _ 3000_ ~ 33O0. . 3600. 390(. 4.1100. 5100 . f,400. - 5700. . 6300.. RK8 ELEVATION: 147' KOP TVD=500 TMD=500 DEP=O 3.00 g.o0 1.5.00 BUILD 3 DEG / 100' 21.00 ~ 27.00 B/ PERMAFROST TVD=1397 TMD=1434- DEP=224- T/ UGNU SNDS TVD=1447 TMD=14-91 DEP=251 3300 9.00 EOC TVD=174-3 TMD=1853 OEP=460 W SAK SNDS TVD=2017 TMD=2214- DEP=695 B/ W SAK SNDS TVD=2582 TMD=2958 DEP=l179 ' X I,~,o, ~s~, ,,~o, ~w~I ~ I s~c. ~., T~., .e~ I ~~MD=529~EP=2700 TARGET TVD=6102 TMD=7594 0EP=4195 ~ SOUTH 4064 TD / LOGGING PT ~D=e417 THO=a009 DEP=4465 300 O '1OO 600 90,O 12OO I 1 SCALE 1 : 1 .~O.OO Vertical section on 155.63 azimuth with reference 0.00 N, 0.00 E from slot ~17 JTD LOCATION: J 1069' FSL, t487' FWL J SEC. 34, TllN, R8E J RECEIVED JUN - 3 1992 Alaska Oil & Gas Cons. Commission Anchorage SCALE 1 : 50.00 Eas ARCO 300 350 400 450 500 550 600 650 700 ALASKA, Inc. Structure : P.d 2M Fleld: Kuparuk River Unit r-I,1 Well: 17 / 26 Leceflon: NOrth SlOl~, Alaaka 900 0 t100 NOTE-. ~500 O0 )0 9O0 ~00 900 1300 1 O0 1100 100 00 500 1300 Plot includes Proposed Well #s 20/22/24 300 900 900 1500 1 O0 1100 750 t 300 800 30O 250 200 150 1 O0 5O 50 1 O0 150 A I GENERAL DRILMNG PROCEDURE KUPARUK RIVER RELD 2M-17 I · · 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (3,222')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,009') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion aSsembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. 'Clean location and release rig. RECEIVED JUN - 3 3992 Alaska 0ii & Gas Cons. C0mrnissi0~ Anchorage i, 7 3 .13 5/8" 5000 I-, 1 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PI:lC)PER LEVEL WITH HYDRAUUC FLUID. 2 ASSURE THAT ACCUMULATOR PRESSURE IS ~ ~ WITH 1500 PSI DOWNSTREAM OF THE REGULATOFL 3 OBSERVE TIME, THEN CLOSE AIL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. < RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER MMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2 CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE UNE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSi HIGH. TEST A~ IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PiPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. OPEN PiPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSi ~ 10 MINUTES. BLEED TO ZERO PSi. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. 1. 16"- 2000 PSI STARTING HEAD 2 11" - 3000 PSI CASING HEAD 3. 11" - 3(X)0 PSII X 13-5/8'- 5000 PSI SPACER SPOOL 4. 1D5/8' - 5000 PSI PIPE RAMS & 1.9-.~/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES 8. 13-5/8"- 5(XX) PSI DOUBLE RAM WI PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR RECEIVED JUN - 3 1992 Alaska Oil & Gas Cons. Commission Anchorage ,~UPARUK RIVER UNI,:, 20" DIVERTER SCHEMATIC 5 6 4 3 ,1 l--I --- · 2 1 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20' - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS 5. 10' HCR BALL VALVES WITH 10" DNERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OFANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TOACHIEVE DOWNWIND DIVERSION RECEIVED EDF~O~ JUN - ;~ 1992 Alaska 0il & 6as Cons. Commission Anchoraoe 4%1 I ~, 94~; 9~8. ~ 4 OX, Z54.$1 ?0e i0' IO.~X6" ~ ~,940,90~.93 4~7, ?79.~8 ?Oet~' 18.~??" ~ ~,9~0;9~.~ t 4~Y; 004.5~ YO~l~' 10,~?~" No. y X 5 ~,9~0~ $05.~ ~0~, 0~. ~1' ?0~1~' 8 5, 940,90~.~ 40?; S85.31 ?0~1~'I0.517 S 5, 940, $0~. ~Z qO? ) 984.~? ?Oe16' 10.3?~" 1I 5) 940, $~5. 95 400,004.39 ?OOlO'lO,~l " /~ ~,94~ 905.05 488, 0~9.48 /3 ~, 94~, ~$. 74 4 08, 119.27 /~ ~,94~,9~9~ 4~,/6~.02 /e ~;~4~ 9~4 4~, /94.04 ~0~1~' /~ ~, 94~, ~.06 4~, ~/~. I~ ~0~/~' /~ ~4~~ 4~, 244.~/ ~0~t~' /~.~# 19 5; 940, $ ~0~ 400, ~9. I0 ~0 ~, 948~ 9 8~04 4 08, ~9~.0~ ?O°tO' I0,$06" ~1 ~,~40,~80.00 488, $t~lO ~ ~, ~8~ O O~XX 4 OO~ ~44.40 ~ 0~1~' 18,~0~" ~3 ~, 948~ OO~.O3 488, ~08~1 LONW. , F.~.L, F..E.L. 0¢~. PAD I'EO°O$'$X.,E~?'' //4 ' 111 ' 101.0' 104.9 / ~0~ O~ ' ~, ~ ' I t 4 ' ~ ' I01.0' 104,9 I~0~0~'~. 809" 114 ' 6t ' I01.0' 104.~ 150°08'8~.0~ " / / 4' 3~' ;OO.O' tO~.O /~00 05' $~3&8 " 1t4' If' I01.0' 105.C /~0e0~'~.630 , //4' /~' I~.~' I0~.1 /~OeO~'~. /78" //4 ' $~' I00.8' 105.3 /$0*00'$1.~$0" //4' OO' IO~e' 105.~ /$OeO~'$O.~aO " //~' //4' ~0.?' I0~.~ /~0e0~'4~.~4'' //4 ' /~' I00.~' ~0~.~ t ~ 0e 0 ~' 4~.~ 4 " //4 ' / ~ 4 ' I00.~' 105.5 /~0e OS'caEn4" //4 ' /E~' 1~.5' I0~.~ i ~000~'44. 4?0" I 1 4 ' $~$' ~0.~' I~0°0~'43.?~2" I t 4 ' 304' I~.1' 105.6 I$0°05'4~.eZ~" tl4 ' 404' /~0~0~'4/.~4'' //4' ~' 9~,9' 105.6 /~0e~'3~9//' //~' ~' 99.5' ;04.9 ~ OF Az ,',.,~ .. ', '.: '. REGISTERED AND LICENSED TO PRACTICE Es ee.e ...... . L AND 8URVEYIN~ tN THE STATE OF ALASKA AND THAT THI$ PLAT REPRESENTS A SURVEY 'MADE BY ME OR UNDER MY DIRECT SURERVIglON~ f'"O'~'.;' .. ~53~.: ,..'... ,. ~ (.,'.*< .. ., ~,.,,, AND THAT ALL DIMENSIONS AND OTHER' "~ ~..: :'~'.'* · De ~ ct~pt~On ARCO ALASKA, INC. NSDK. ZMOO.CEA.ORMx. Oo~e, '~e. 11-9I NO..' NfK $ ~'3 47 ARCO Alaska, Inc./''''~-''~ Post Office B°x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Applications for Permit to Drill KRU Field Well 2M Pad Addendum to Previously Approved Permits to Drill The attached correspondence is the Alaska Oil and Gas Commission's ruling which approves isolation of Colville Sands at 2M pad by down squeezing cement into the annular space between surface and production casing. This will occur after the pdmary cement job on the production casing is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. There have been four drilling permits which have already been approved prior to the ruling mentioned above. ARCO Alaska, Inc. requests that these four previously approved drilling permits also be included in the ruling. The four wells are' We!!. Permit NO. APl NO.. Approval Date 2M-15 91-33 50-103-20154 03/05/91 2M-16 91-32 50-103-20153 03/05/91 2M-17 91-18 50-103-20150 02/22/91 2M-18 91-19 50-103-20151 02/22/91 If there are any questions, please contact Tim Billingsley at 265-6575. Thank you for your assistance in this matter. Sincerely, A.W. Area Drilling Engineer RECEIVED MAR 2 9 1991 Alaska 0JJ & Gas ConS, Anchora~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · AR3B-6003-C ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 21, 1991 A Wayne McBride Area Drlg Engineer ARCO Alaska, Inc P O Box 100360 Anchorage AK 99510-0360 Re: Alternative cementing procedure for some Kuparuk River Field wells on Drill Site 2M. Dear Mr McBride: This is in reply to the meeting with the Commission on March 8, and your letter of request dated March 11, 1991. The Commission has reviewed the conditions expected to exist on Drill site 2M, and approves isolation of Colville Sands by down squeezing cement into the annular space between surface, and production casing. This will occur after the primary cement job is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. If you have any questions, please feel free to call me. sincerely, fi Lonnie C Smith Commis s ioner LCS/jo RECEIVED ~,~P: 2 9 ]991 Oil& Gas Cons. ~0Jil. ~.SSJ~i3 Anchorage ...... ' ...... ALASKA OIL AND GAS CONSERVATION COMMISSION February 22, 1991 WALTER J. HICKEL, GOVERNOFI 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501..3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk~River Unit 2M-17 ARCO Alaska, Inc. Permit No. 91-18 Sur. Loc. ll4'FSL, 379'FWL, Sec. 27, TllN, RSE, UM Btmhole Loc.1399'FNL, 1840'FWL, Sec. 34, TllN, RSE, UM Dear Mr. McBride: 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 governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Si~cerel¥,~--...~-'Q Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA A~KA OIL AND GAS CONSERVATION COMMI,%'.'.SION PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill ~ ~ lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service Development Gas Single Zone ~ Multiple Zone P_. "Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 141'. Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 379' FWL, Sec. 27, T11N, R8E, UM Kuoaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1295' FNL, 1740' FWL, Sec. 34, T11N, R8E, UM 2M-17 #U630610 At total depth 9. Approximate spud date Amount 1399' FNL, 1840' FWL, Sec 34, T11N, R8E, UM 10-Mar-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-18 ~'p,e_oPO.'S~'~) 6864' MD 3440' @ TD feet 25' at surface feet 2560 6409' TVD feet , , 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 1 500' feet Maximum hole angle 25° Maximum surface 1650 pslg At total depth (TVD) 3440psi~1 @ 6409' 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement "Hole caSing Weight Grade Coupling Length IVD TVD IVD TVD (include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 2822' 35' 35' 2857' 2781 960 Cu. Ft. AS III & HF-ERW 530 Cu. Ft. Class G , 8.5 7" 26'0# J-55 BTC 6829' 35' 35' 6864' 6409' 190 Cu. Ft. Class G Top 500' above Kuparuk 19. 'I-° be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. Surface Cu. Ft.D Intermediate Production Liner Perforation depth: measuredFEB - 8 1991 true verticalAlaska 011 &.6a~.~ns- 20. Attachments Filing fee ~ Property plat ~ BOP Sketch X Diverter Sketch ;X Drilling rog~ram ..~ Drilling fluid program .~. Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements ,21. I herebY certify that the foregoing is true and correct to the best of my knowledge Si~l Title Area Drillin9 Engineer Date Commission Use Only . Perm i~me.~ (:~, I APl number I~(~/~. / ~ C) ISee c°ver letter f°r b/,,,~ 50-,/(~',~,~'--- .~(:~) [/,,.~"(~ Appr--I------1 other rec~uirements Condi{ions of approval Samples required mY e s ~ N o Mud Icg require, d ~ Y e s ~' N o Hydrogen sulfide measures~ Yes ~ N o Directional survey required ~XYes ~ N o Required working pressure for DOPE 2M; X 3 M; ~ 5 M; ~ I 0 M; ~ I 5 M Approved b~, Commissioner the commission Date '2_ ~ -~. Form 10-401 Rev. 7-24-89 Submit in triplicate [ARCO ALASKA, Inc. i'--~'ru--~ur--'~: Po~"~'---- .... ~e-~l: 1-~ ..... [ Field : Kuparuk River Unit Location : North Slope, Alaska 0 - - 800 1200 - Created by : jones FOR.' T BILUNGSLEY IDote plotted : 5-Feb-91 IPIot Reference is 17 version t2. ~Coordinotes ore in feet reference slot Frue Verticol Depths ore reference wellheod, J I-~IEASTMAN J IZflJtlCHRISTENSEN ISurface Locotion.' I 114' FSL. 579' PNL Sec. 27, T11N, R8E S 44 DEG E 1959' (TO TARGET) RK8 ELEVATION 14-1 * B/ PERMAFROST 3VD=1391 T/ UGNU SNB$WD=1451 KOP TVD,=1500 TMD=1500 3.00 9.00 BUILD 3 D£G/IO0 FT 15.00T/ W .SAt( SNDSWD=2016 TMD=2022DEP=71 21.00 EOC W0=,2311 TMD==2338 OEP--lB1 I~/' W SAK SNDS TVD==2581 TMD=2636 OEP=507 9 5/8" CSG PT TVD==2' 781 TM0=2857 DEP~401 K-lO 'rvo==2851 TMD==2934 D£P=454 K-5 '1~D=4551 TMD==4591 OEP= ! 138 AVERAGE ANGLE 25 DEG 8 MIN Easf --> 0 200 400 800 800 1000 1200 1400 1600 I I II II II II II II II I 0 ~00~ 1295' mL. 174~~LI / / % s,~. ~,~N, R~ I 1{ X h~'~ TMD=6524 , ~ / ~ 16~ ~ 1361 ITDLocation: I 1399' FN~ 1840' F~VL Sec. 34, T11N, R8E TARGET - T/ ZONE C TVO=6101 TMD=6524 DEP=1959 6000- \ T/ ZONE A'P,/O=6108 TM0=6532 DEP=.1962 - B/ KUP SNDS WD=6228 Tt,10=6664 0£P=2018 6400- TD / LOGGING PT 'rvD=6409 TM0=~6864 OEP=2103 i i i i i i i i i i i i i 0 400 800 1200 1600 2000 2400 s~, t: ~ Vertical Section on 135.99 azimuth with reference 0.00 N, 0.00 E from slot ~17 DRILLING FLUID PROGRAM (2M-17) Spud to 9-5/8" Drill out to Weight up ~Llrfa, ce casing weight uo toTD Density 8.6-1 0.0 8.6-9.6 1 0.3 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 1 5-4 0 4 - 8 4 - 8 APl Filtrate 1 0-1 2 8-1 0 4- 5 pH 9-1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4- 7 1 0-1 2 Drilling 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 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1650 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2M-17 will be 2M-18 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. 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. * Spud mud should be adjusted to a funnel viscosity drill gravel beds. FEB - 8 1991 Alaska 011 & '... GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2M PAD · . e 10. 11. 12. 13. 14 15 16 17 18 19 Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. kdPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 5 HCR I 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 10" HCR BALL VALVES WITH 1(7' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 , 6 5 13 5/8" 5000 Poi BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST Boq-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE F e e //:7(.~. [2 ~hru 8] (3) Admin~)/ ~ ' [ 9 t~hru [10 & 13] [14 thru 22] (5) BOPE ~.~,~,,~-~-~ [23 thru 28] / (6) Other 2/9///'thru [ 31] (7) Contact /V/~~ [32] (8) Add1 Company 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance fr~m property 1 in, ................... 4, Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool .............. 6. Is well to be devlated & is wellbore plat included ................... 7. Is operator the only affected party ................................... 8. Can permit be approved before 15-day walt ............................ Lease & Well &, . 10. 11. 12. 13. 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 1 ease n~nber appropriate .......................................... Does wel 1 have a unique name & mrnber ................................ Is conductor string provided ......................................... Wi l 1 surface casing protect al 1 zones reasonably expected ,p to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface ~ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing glve adequate safety in collapse, tension, and burst. Is 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 drilling fluid program schematic & 1 ist of equipment adequate .... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to .~o~, psig ..... Does choke ~nifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... // J 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpr~ssure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. //' / / g geology' eng i neer i ng DWJ MTM~_~ LCS ]/~q~ RPC~_~ BEW ~ RAD_~5 rev 04/92 jo/6.011 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , Add i t i ona 1 remarks' CHECK LIST FOE NEW WELL PEP, MITS ITEM APPROVE DATE (2) Loc 2 thru 2. 3.. 4. 5. 6. ~Z-II -~ t 8. (8) (3) Ad, in m~/~ ~/~/ 9. (.9 thru £3)' ' 10. (10 a~d 13) 12. i3. (14 th~ 22) Company. Xr~o . /~//~~ _~ Lease&YES WellNoNO . /~ L.~_CO"~~F~. Is the pe~t fee attached ~ -- 14. 15. (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) (29 thru 31) Geology: Eng~ ~n.esring: DWJ LCS ~. t~ BEW .-" rev: 01/30/89 6.011 For 29. 30. 31. 32. Is well to' be located in a defined pool ........... .................. Is well located proper distance from property line .................. Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ ly ty Is operator the on affected par ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .............. .................... _ Is a conservation order needed Is administrative approval needed iii Is the lease number appropriate ..................................... --~ Does the well have a unique name and number ......................... Is conductor string provided ' ''eeeeeeeeleeeeeee..®ee®ee.ee®m®eee,e~®e ,,, 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 .............. me.®em. 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 ,,~ · e®e®®ee.eee®®®.®e..eeeeeee. · ,, Is a diverter system required ....................................... ,~ . Is the drilling fluid program schematic and list of equipment adequate z~ Are necessary diagrams-and descriptions of diverter and BOPE attached. ~ . Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ' ''eeee®eeeeeeeeee®ee..eeeeee®...® exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? .... INiTIAL GEO. UNIT ON/OFF POOL II CLASS STATUS AREA NO. SNORE , Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented . Additional requirements ................................... dltlonal Remarks: 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. COMPANY NA.~E WELL NA~E FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO : ~RCO ~LASKA, INC, : KUPARUK RIVER UNI~ : 50-~0~-~0150 : 9~495 ,IS Tape Verification Listin~ ~chlumberger Alaska Co~put~na Center 17-AUG-1992 ]g:54 0~I~I~ : FLIC ~EL ~A~E : g24~5 CONT!NUATIDM ~ : P~E¥1OUS REEL : COE~ENT ~ ARCO ALASKA, INC,,KUPARUK RIYER UNIT,2~-17,50-103-20150 **** TAPE MEADER **** SL:RV!CE NAME : EDIT DATE : ~2/08/!7 O~I~IN : FLIC TAPE NA~E : 92495 CONTInUATiON # : P~EVIOU$ TAPE CO~E~T PAGEI SERVICE : FLIC YFRSION : O0~A07 DA, TK : 92108/17 ~AX REC SIZE : ~.o24 FILE TYPE : LO LAST FILE : ** SCHLUMBERGER WELL SERVICES ** CO~P~NY MAME~ ARCO AI~ASKA, INC, WFLL: 2M-17 FXELO: KUPARUK RIVER UNIT BOROUGH: MORT}{ SLOPE STATE: ALASKA APl NUMBER: 50-103-201§0 LOCATION: 114' FSb & 379' FWL SECTION: 27 TOWNSHIP: lin P~MANENT DATUM~ NS!, ELEVATION: O' LOG ~EASURED FROM KB 1,46' ABOVE PERMANENT DATUM ,IS %ape Yerlficatlon L, istl, ng ;cblumberaer Alaska Computing Center 17-AUG-lEg2 19:54 ELEVATIONS KH: 146' Dr: 146' GL: 105' TD DRILLER: 13-AUG'1992 ONE 7857' CASING 1: CASING 2: 9 5/a" 36 LB 0 DRILLER DEPTH OF O' TB 3~90' 7" 26 LB a DEILLER DEPTH OF O' TO 7941' BIT SIZE 1: ~2 1/4" BIT SIZE 2: O i/2" 0 7947' TYPE FLUID IN HOLE: BRINE WATER DENSITY: 10 LB/GAL MAXIM!IM TE~P RECORDED: 163 DEGF hOGGING DISTRICT: LOGGING ENGINEER: WlTNE$S~ PRUDHOE BAY K, PORTER B, BERRY TOOL NUMBERS: CAL-YA !,592 SGT-L 593 HbDC-AA 20 G$~-Z 872 NSR-FA 226 TCC-B 276 CNT-G 65 HLDV-AA TC~-AB 107 NSR-GB 4164 FIELD REMARKS: TIED INTO CET OF 13-AUG-1992 DATE JOB STARTED: 17-AUG-92 JOB REFERENCE NO: 92495 LDP/ANA: R,, KRUWELL FILE ' EDIT,O01 ARCO ALASKA, !NC, KUPARUK RIVE~"U~:~IT 2t~. 17 "CORRECTE[) CASED HOLE DENSITY ~ATERAbI, Y ........ AVE..~A¢,EDa" FRON 3 PAI3SES, G.A~MA RAY AND CASING COLLAR b CATOR FROI~ PASS #I" DATA SAMPLED EVERY -.5000 FEET ~IS Tape verlf.ication [,j, stlnq ichlumberger AlasKa Computing Center 17-aUG-19g~ 19:54 PAGE{ * DATA /r!CLUDEO - * TOOL EXTENSION TOOL * TYPE USED NAME * HbDT ,DEN H(~STILE ENVIRONME~T bDT ****************************************************************************** TABLE TYPE : CONS TUN! VALU DEFI '~'' .... "'' .................. '''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''ARCO ALASKA, INC, Compam¥ Name FN KUPARUK RIVER UNIT WN 2M-17 APiN 50-~03-20150 FL 114' ESL & 379' FWL SECT 27 COUN N~RTH SLOPE STAT ALASKA ~ATI USA PDAT MSL EPD FT 0 APO FT 1~6, KKB FT 146. EDF FT 146, EGL FT 105 TDD FT 785~. DFT BRINE WATER DFD G/C3 10 Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation witness Name Service Order Number Permanent datum Elevation of Permanent Log Measured From. Above Permanent Datum Elevation of Kelly Elevation of Derri~M Elevation of Groun~ bevel, Tot Depth al ,Driller Drifting Fluid Dr u ln~ F1 id Deh$tty DEGF Bottom Mole Temperatu. re. , TYPE : CUR¥ DEFI v ....... '"'"' ....... '"'" SS~H snort Spacing ~ulk Dens~ RHOB BUlk' Density DPHO Delta RHD GR Gamma CCL CCL Amplitude ,!S Tape Verification 1,1stinq ;chlUmberqer AlasKa ComDutin~ Center 17-AUG-1992 !9:5~ PAG~I ** DATA FOR~qAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** YPE REPR CODE, ~ VALUE 1 66 0 2 66 0 3 73 28 4 66 7 65 8 6~ 0,5 9 65 ET 11 66 36 1~ 6~ 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~ SERV T SERVICE API P APl AP1 ' B NUMB E REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) '''''DEPT .... '''' .............. FT 413497 ''''''''''';''''''''~'''''''''''''00 000 0 I I ........ 4 '''''''';'''''';'''68 000000 O0 bSRH DEN G/C3 413497 O0 000 O0 0 1 1 1 4 68 0000000000 SSR~ DEN G/C3 413497 O0 000 O0 0 I I 1 4 68 0000000000 R~OB D~N G/C3 413497 O0 00.0 O0 0 I 1 1 4 68 0000000000 D~HO DEN G/C3 413497 O0 000 O0 0 1 I I 4 68 0000000000 G~ PS1 GAPI 413497 O0 000 O0 0 1 1 I 4 68 0000000000 CCL PSI ~ 413497 oo 000 O0 0 I I 1 ~ 68 0000000000 m..m mmmmmmm ..m..mmm mmmmm.mmmm mmmmmMmmmm.mmmmmmm.mM....~mm ~M..~.mm ~mM...~N.... ** DATA DEPT. 7877.500 LSRH.DEN DR~{O, DEN -999,250 GR, PS 1 DEPT, .3 D~PT 7700,000 DSRH.DE~ -o. 99 .PSl -999,~50 SSRH'C. EN 56,906 CCL'P$1 2,662 SSRH,DEN 60.031 CCL:,P$! 2,79'8 $SRH'DEN 56,688 CCL,PS1 -g9g.250 RHOB,DEN -0,~053 3.485 RHOB.DEN 0.:004 3,623 RHOB,DEN -0,:057 '999'~$0 2,346 '2. :4 9 9 Tame Verificatlon Listino ~ChlUmber¢ler ~laska Computinq Center' DEPT. 7600. 000 DRHO.DEN -0. 354 LS~H.DEM GR.PS1 GR,PS1 LSRH.DE~ GR.PSI LS~H.DEN GR.PSI LSRH.DEN GR.PSI LSRM.DE~ GR.PS1 LSRH.DEN GR,PS! LSRH.DEN GR,PS! LSRH,DEN GR,PS1 LSRH,DEN GR,PS1 GR, PS I LSRM,DEN GR.PSI DEPT 7500.000 DP.HO:DEN -0.379 DEPT. 7400.000 DRUfi. DEM -0,411 D~PT 7,~00,000 DRHO:DEN ' -0,345 DEPT. 7200,000 DPHO.DEE '0,358 DEPT. 7100.000 DRHO.DEN '0,418 DEPT. 7000.000 DPHO,DE~ -0.392 D~PT. 6900.000 DRHO.DEN -0.338 DEPT. 6800,000 DRHO.DE~ -0,3~6 DEPT, 6700,000 DPHO,DEN '0,274 DEPT. 6600,000 DRHD.DEN -0.295 DEPT. 65~0,000 DREO,DEN 0,279 EPT, 64~0,500 ~MO"DEN -999,25() END OF DATA ** i7-AUG-lg92 1.9:54 2 681 SSRH,DEN 28~422 CCh. PS1 2.642 $SRH.DEN 62.125 CCL.P$1 2.~65 SSRH.DEN 74.438 CCL.P$! 859 8BRH.DEN ~3:625 CCh,PS! 2.785 SSRH.DEN 162,000 CCh,PS1 877 SSRM,DEN 9 '688 CCh PSi · · 2,912 SSRH,DEN 72,188 CCL,PS1 2 821 SSRH,DEN 66:250 CCh,PSI 2 672 $SRH.DEN ~7:188 cch,Psi 2,638 SSRH.DEN 78,000 CCh. PS1 2.6~4 SSR~'DE~ 87,563 CCh,PS! 2,~14 SSRH,'DEN 98. 13 CCh,PS! -999,250 8SRH.DEN 88.563 CCh,PS1 3.583 -0.055 3.64! -o.057 3.948 -0.102 3.767 0.029 3.726 0.016 3.977 '0.063 3.943 0,098 3.710 -0,043 3,504 -0,064 3,359 -0.055 3,429 '0,055 3.349 0,074 -999,~50 -0.:008 RHOB.DEN RHOB,DEN RHOB.DEN RHOB.DEN RHOB,DEN RHOB.DEN RHOB.DEN RHOB.DEN RHOB,DEN RHOB,DEN RHOB.DEN RHOB,DEN RHOB,DEN PAGE~ 2.329 2,264 2,459 2.513 2.427 2,459 2.521 2,356 2,364 2,359 2,335 -999.250 **** FILE TRglLER **** FILE NA~E : EDIT ,00I SERVICE : FLIC VERSION : O01A07 D~TE : 92/08/17 gAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ,IS Ta~e verification Listing icblumberger Alaska Computing Center **** FILE HEADER **** FIbF NAME : EDIT ,002 SERVICE : FbIC VERSION : O01A07 DATE : 92/08/17 ~AX REC SIZE : 1024 F'IL~ TYPE : LO LAST FILE : 17-AUG-1992 19:54 PAGE: ****************************************************************************** FILE - EDIT,O02 ARCO ALASKA INC. KUPARUK RIVER UNIT 2M-17 50-!03-20~50 "RAW FIELD DATA PASS #t" -DATA SA~!PLEI) EVERY -,5000 FEET DATA INCLUDED - ToOL EXTENSION TOOL TYPE USED NAME HLDT ,PSi CNT-G ,PS1 HOSTI. bE .EN'IR~NMENT bDT CO. PENSATED NS. UTRON THERMAL/EPITHERMAL ****************************************************************************** T~BLE TYPE : CONS TUNI VALU DEFI · CN ARCO AbASK INC, Company Name ~UPARUK RI~.P, uNIT Field Name FN WN 2. M- 17 Well Name AP!~i 50-103-20150 AP1 Serial Number FL !14' FSL & 379' FWL Field Location SECT 27 Section T~ W N 1 ! N T o~nshlp R A. NG 8E .Range COUN NORTH SLOPE Couhty STAT ALASKA Sta~e or Province NATI USA Nation ,IS wade Yerification Listlnq ;chlumDerqer Alaska Computing Center 17-AUG-I992 19:54 PAGE: 7 SON 3497 PDA? MSb EPD rT 0 APD FT 146 Elam FT 146: EDF FT 146, E~ ~ ~05. TDD FT 7857, DFT BRINE WATER DFD G/C3 10 BMr DECK 16~, witness Name Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Above Permanent Datum Elevation o~ Kelly Bush~q Elevation of Derrick Floor Elevation of Ground ~evel Total Depth ? Driller Drilling Fluid Type Drilling Fluid Density Bottom ~ole Temperature TAB[.,E TYPE : CURV DKPT DePth bSRH Lon~ S~acj. na ~ulk :Denstt SSRH Short Spacln~ Bulk DenSity PEFL PEFL PEFS PEFS PEF PhotoElectric Factor LSw~ LSWi LSW~ LSW2 LSW~ LSW4 LSW5 bSW5 SSwl SSWl SSW2 SSW2 SSw4 SSW4 SSW5 SSW5 R~OB Bulk Density DRHO Delta RHO CS Cable Speed TENS Ten ion GR Cam. ma Ra, · PlYt, ude CCL CCh Am , ENPH EpithermaI ~eutron Poroslt¥ ~..~ EPithermal Neutron Ratio C librated CFEC Corrected Far Epitberma! Counts CNEC Corrected Meat Epitbermal Counts REEF Raw Corrected Epitbermal Far Counts RCEM Raw Corrected EPitner~al Near Cot~nts NPHI Neutron Porosityp ., ~' m TNR~ Thermal Netltro~ Ratio Calibrated ,IS 'rave verification List!nO ;chlumberger Alaska Con, Put!DO Center 17-AUG-lg92 1.9:54 PAGE: DEFI .... ............ .--;. ....... ;-. ....... ;;[--- ...... ;........ NVOR Neutron Pot sity fro an Appli ion Progr m RCNT gCNT RCFT ~CFT C~TC CNTC CFTC CFTC ** DATA FORMAT SPECIFICATION RECO~D SE2' ~mm ~mm ~m T¥ mm~ ~mm ~mmm~ TYPE - 64EB ** ;~ ..... ~.'E;~''''''CODE ..... VAbUE''''' 66 0 66 0 73 152 66 66 73 65 68 0 5 66 6 68 66 65 FT 66 68 66 I 66 ** SET TY AME SER UNIT S ID OR DEPT FT 41 LSR~ PS1 G/C3 41 SSR~ PSI G/C3 41 FEFL PSl 41 P~F~ PS! 41 PEF PS~ 41 LSW1, PSI CPS 41 LSW~ PS! CPS 41 LSw3 PSt CPS 41 LSwa PS1 CPS 41 LSw5 PSi CP~ 41 SSWl PSi CPS 41 SSw2 PS1 CPS 4I PE - C~AN ** .... .... ................................-. RViCE API AP API FILE NUMB NUMB SIZE REPR pROCESS DER # LOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) mmm~mmmmmmmm~mmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmMm~mmm~~m~, 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 000 O0 0 2 I ~ 4 68 0000000000 3497 O0 000 O0 0 2 I 1 4 68 0000000000 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 000 O0 0 2 1 I 4 68 0000000000 3407 O0 000 O0 0 2 1 I 4 68 0000000000 3497 O0 000 O0 0 2 I 1 4 68 0000000000 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 000 O0 0 2 1 1 4 68 0000000000 3497 O0 OOO O0 O 2 I I 4 68 0000000000 3407 O0 000 O0 0 2 1 ! 4 68 0000000000 ~4g7 O0 000 O0 0 2 I I 4 68 0000000000 ..IS Tape Verification Listlnq ;chl~J.m~.~erqer Alaska C. omput~n~ Center 17-'AUg-J, 99~ !9:54 PAGE{ NA~E S~RV UN!R' S.R ICE A API AP FILE {]MB SIZE RE R PROCESS ID ORDER # LOG TYPE CLASS ~OD NUmB SA~P ELEM CODE ........ ......... .......... ' ....... .... """'" ....... "'"'"' SSW~ PS CPS 3497 O0 000 O0 2 I 4 68 0000000000 SSw5 PS! CPS 413497 O0 000 O0 0 2 · I I 4 68 0000000000 R}~OB PSi G/C3 413497 O0 000 O0 0 2 1 1 4 68 0000000000 D~HO PS1 G/C3 413497 O0 000 O0 0 2 1 1 4 68 0000000000 CS PS1 F/HR 413497 O0 000 O0 0 2 1 1 4 68 0000000000 T~NS PS1 LB 413497 O0 000 O0 0 2 i 1 4 68 0000000000 C~LI PS1 IN 4134~7 O0 000 O0 0 2 1 1 4 68 0000000000 G~ PSI GAPI 413497 O0 000 O0 0 2 I 1 4 68 0000000~00 CCL PS1 V 413497 O0 000 O0 O 2 1 I 4 68 O000000uO0 ENPN PS1 PU 413497 O0 000 O0 0 2 I 1 4 68 0000000000 ENR~ PSi 413497 O0 000 O0 0 2 ~ 1 4 68 0000000000 CFtC PS1 CPS 413497 On OOO O0 0 2 1 1 4 68 0000000000 CNEC PS1 CPS 413497 O0 000 O0 0 2 1 1 4 68 0000000000 RCEF PSI CPS 413497 O0 000 O0 0 2 ! 1 4 68 0000000000 ~CF~ PS1 CPS 413497 O0 000 O0 0 2 1 1 4 68 0000000000 NP[{I PS1 PU 413497 O0 000 O0 0 2 1 1 4 68 0000000000 T~P~ PS1 PU 413497 O0 000 O0 0 2 ! 1 4 68 0000000000 TNRA PS1 413497 O0 000 O0 0 2 1 1 4 68 0000000000 RTN~ PS1 413497 O0 000 O0 0 2 1 I 4 68 0000000000 NPOP PS! PU 413497 O0 000 O0 0 2 I 1 4 68 0000000000 RCNT PS1 CPS 413497 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT PS1 CPS 41.~497 oO 000 O0 0 2 1 1 4 68 0000000000 CNTC PS1 CPS 413497 O0 000 O0 0 2 I ! 4 68 0000000000 CFTC P$1 CPS 413497 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT 7877.500 ~SRH.PSI ~.686 HSRH,PSI ~ 404 PEFh-PSI P~F$'P8!, 20,703 PEF.PSI. 3 ,063 LSWI,PSI 14 ~:875 LSW~.PS1 890.500 LSW4.PS1 450 000 LSWS:,PS! 407,500 SSW .PS~ 1.9o6.000 SS~'3.PSI 4860~000 SSW4,PSI 1970~000 sSW5'P$1 RHOB.PS1 2.t60 OPHO,PS1 -0,506 C$*P.S1 243,250 TENS,PS1 C.~.hI,PSI ~ 500 GR,P$1 56,906 CCh?PS1 -~0.053 ENPH.P$1 Ek!~"P$1 4:904 CFEC.PS1 529.601 CNEC.PSi 2597.157 RCEF.PSI RCEE,P$1 2404'.658 NP~I,PS! 36.266 TNP~ H,PS! 35,~08 TNRA*P$1 RTN~.PSI 3,567 NPOR.PS1 35:,½08 RCNT,P$! 1078,222 RCFT*P$! CNTC'PSI !068,094 CFTC,PSi 323, 84 ~EPT, 780C).000 [iSR~.PS1 2,,~8 SSRH.PS! 3.346 PEFh,PS! LSW3'PS!. 647.000 I, SW'~,PS1 455,25 5$W~.PS1 424 O0 8SWI.PS! SSW2.PS! 1916,000 SSW3,PS1 50~4,000 SSW4,PSI 2156 ~()0 SSW5.PS1 C~LI PS! 6 242 GR P~' O0 TENS,PS~ · · ~04 ENPH,PSl ENRA.PS1 5.854 CFEC*:P$1 44318 1. CNEC,P$! 2598~ 66 RCEF,PSl RCE~N.PS~ 241!.975 NPHI.P$i 44,554 TNPH'PS1 39.603 TNRA,:P$1 RTNPiPS1 3.868 NPOR.PS! 40.007 RCNT"PS! 1045,646 RCFTiP$1 CNTC,PS1 1045 002 ~TC'~S1 292 078 2 2:5 1860:000 53~,392 299,65'2 23 ,094 28:0 o 125 3~ 0o0 4 703 44{ ,554 3 ,847 2748.30 ,IS Tame Verification Llsttmo. ;ch]umberger AlasKa ComPuting Center 17-AUG-19g2 lq:54 PAGE: !0 DEPT. 7700.000 LSRH,PS1 ¢FFS.PS! 22,469 PEP.PS1 LS~3.PSI ~6!,250 LSw4.PS1 SSW2,PS1 1~79,000 SSW3.PSI R~OB,PS1 2.368 DRHO.PS~ CaL~.PS1 6.191 Ga,Ps1 E~A,PS1 4.729 CFEC,PS1 RCEN.PS1 2724.971 NPHi. P$1 RTNR PSI 3.396 NPC)R.PS1 CNTC:PS1 1258.634: CFTC.PSI DEPT. 7600.000 LS~H.PSI PEPS PSi 20,344 PEP.PS1 LSW]~PS1 620,000 LSW4.PS1 SSW~.PS1 1809.000 SSW3.PS! RHO~,PSI 2,183 DRHO,PS! CALI.PS1 6.191 GR.PS1 ENR~.PS1 4.493 CFEC.PS1 RCEN,PS1 2754.72i NPH!,PS1 RTNR,PS1 2,920 NPOR,PSI CUTC.PSl ~567.717 CFTC.PS1 DEPT 750o.000 bSR~,PSI PEFS~PS1 36,438 P~F.PS1 LSW3,PS! 673.500 LSW4.PS1 S$~2,PS1 t~91.00© SSw3'Ps! ~OB.PSI ~,0@1 DRHO.PS1 CALl,PS! 6,188 GR:'PSi EN'RA.PSI 6.83~ CFEC.PS! RCEN'PSI 2161.320 NPHI.'PS! RTN~,PSI 4,036 NPOR.PS! C~TC,PS1 897.280 CFTC,PS! DEPT. 7400,000 LSR!i,PS1 PEFS.PSI. 40.000 PEF,PSI LS~3,PS1 348,000 hSW4,PSI SSW2.PS1 !035,000 SSW3'PSI RHO~,PS1 2'263 DPMO,PS! C~LI.PS! 6,203 GR.PS! E~,:PS1 5,8~3 CFEC,PS1 RCEM,PSt 2339.464 NP~.I.PSI CFTC,PSI !,02 069 CFTC.PS! DEPT, 7300 000 LSat.{ PSI PEPS PS1 25' · ,922 PEP,PS1 LS~'3.PSI 367,750 LSW4,PSt SSW~.PSI 1370.000 SSW3.'PSi R~O8 PS1 2,345 DRHO c Li' .PSI 6.'t6~ Ga,PSi ENRA PSI 5.651 CFEC,PS1 RCE~PS1 2474,579 NP~I.PSI RTNR.PS! 3,792 NPOR,PSl CNTC.PS! 1070,229 CFTC,PSI ] 813 SSRH,PS1 2 ~219 LSW!.PS1 3 2 000 LSwS,PS1 4816.000 SSW4.PS1 -0 444 CS,PS1 636,.':143 CNEC.P$1 33 123 TNPH,PS1 33'8~2. RCNT,PS1 405.7 8 2 705 SSRH.PS1 18i594 LSWI .PS1 45! 000 LSW5,PS1 4672.000 SSW4,PS1 -0.524 CS,PSi 28,4822 CCb. PSl 679.4 5 CNEC,PS1 24'397 TNPH,PS! 27'126 RCNT.PS1 577.121. SSR~I,DS1 520, 00 W 4396,05 I~S .:PS 1 00 SSW~ -o.569 cs.psl 62,125 CCL,PS1 345. 576 CNEC,PSi ' 49..002 TNPH.PS1 44. 81 RCNT,PSI 231, ,~16 2,883 SSR.H,PS1 312.2'50 LSWI.PS1 31 ,250 [.SWS,:PSi 3342,000 SS~4,PS1 - 0, 622 C $. P S I 74'438 CCh,PSI 435,3!2 CNEC,PS! ~.,:258 TNPH.PSI .788 <CN~,.P$1 299,997 2~,881 SSRH,PS1 ~ 094 b S w !, P $1 298.500 LSWS,PSI 4014' 000 SSW4,PS1 ]j0,537 CS,PSI 1 .,625 CCh. PSI 482,89~ C.IEC,PSI~." .. 3 8 .:9 6 2 T N P H · :P S 1 37'~7l RC~NT.PS! 308.336 445 326 250 2090~000 8~9..500 0.057 3009 1212.993 3.451 146.500 410.250 1~35000 00~000 -OO55 3053!179 26 t47 1538.913 3 457 155 50O 484 250 2002 000 903.000 0057 904,395 3,768 85,813 303,500 1828;000 900,500 '0.102 2560, 21 36,~34 1032~865 3.646 82,750 296'000 1846'000 oo :SOOo2o 272~,094 37'866 1082.709 PEFL.PS1 LSW2.PS1 SSWl.PS1 SSW5.PS1 TENS,PS1 ENPH.PS1 RCEF,PS1 TNRA.PS1 RCFT.PS1 PEFL.PS1 DSW2*PS1 SSWl*PS1 SSW5.PS1 TENS,PS! ENPH,PS! RCEF,PS! TNRA'PS1 RCFT,PS! PEFL PS! ssw2:psl $$WI.PS! SSw5'PS1 TENS.PSI ENPH.PS1 RCEF,P$1 TNRA,PS1 RCFT.PSi PEFL,PS1 5SW2-PS1 SSWt;PSl SSWS,PS1 TENS,PSi ENPH,PS1 RCEF.PSl TNRA.PS1 RCFT,PS1 bS~2*P$! SSWI,PS1 SSW5.PS1 TENS.~PS1 ENPH,PSI RCEF,P$! TNRA,PS1 RCFT'PSl 198 555 500 234 000 3225 O00 30 666 634 914 3 220 372 656 18 594 292i-000 535 000 215,500 000 651.1 2,,741 518.618 27641 287 500 496~500 205 .500 3035 ~000 55 .126 58 341 211.728 .32'25o 15i.~875 421~,250 249,250 3075,000 264~812 2g:~94 166: 214,750 3090 0 472 020 ~ 540 285,656 ~IS Tape verification histinO ;chlumberger AlasKa Computlnq Center 17-AUG-!992 1.9:54 PAGE~ li DEPT. 7200.000 LSRN.P$1 PETS.PS1 25,93S PET.PS1 LSW3.PS1 435 000 LSw4.PSI ssw~.Ps1 13o!~000 ssw3.PSl RNOB,PS1 2,249 DRHO,PS1 CALl.PS1 6,168 eR.PS1 ENRA.PSI 5.775 CFEC,PS1 PCF~,PS1 2550.4~B NPHI,PSI RTNR.PS! 3.942 NPOR.P$1 CNTC.PS1 1029.162 CFTC.PS1 DEPT, 7100.000 LSRH.P61 P~F$.PS! 40.000 PET.PS1 LSW3,PSI 357.750 BSW4,PS1 $SW~ PS1 9~6.000 SSw3.PS! RMOB:PS1 2,227 DRMO.PS1 CALl PS!. 6,176 GR'PS1 ENR~:PS1 5'446 CFEC.P$1 RCEN,PS1 2526.765 ~PNI.PSI RTNR,pS~ 3,896 NPOR,P$1 CNTC,P$~ 1111.542 CFTC'PSi DEPT, 7000.000 bSRH.PS1 P~FS,PS1 40"000 'PET,PS1 LS~3.PS! 327.000 LSW4,PS1 SSw2.PS! 1001.500 SSW3.PSI RHOR,PS~ 2,3~0 DRHO,PS! CALI,PS~ 6,.164 GR.PSI ENRA PS1 5:121 CFEC,PS! RC~N'' ' ,PS1 2624.663 NPHI,PS1 RTN~,PS! 3.6~7 NPOR.PS1 CNTC.PS1 1159.856 CFTC,PSi DEPT. 6900.000 LSRH,PSI PEFS.P$! 40.000 PET.PSi LSW~,PS1 388,250 LSw4,PSI SSW~.PS1 1308.000 SSW3,PSI RHO~.~PS1 2.3~2 DRHO,PS1 CALl.PS1 6,172 GR,PS1 ENR~,PS~ 4,827 CFEC,PS1 RCEM.P$1 2699,646 NPHI,PS1 CNTC,PSI 1245'935 CFTC,PS! DEPT. 6800,000 LSRH,PSI PETS.PS1 26.328 PET.PSi LSW3,PS1 593.000 bSW4,P$1 SSw~,PS1 1776.000 CAI]~.PS1 6,21i GR'PSI E~RA,PS1 5.974 CFEC.PS1 RCE~!,PSI 236]'946 NPHI,PSI RT~PS1 .4.000 NPOR.PS! C~!TC.PSI 1002.827 CFTC.PSi ?.797 SSR~.PS1 25.203 bSWl.PS1 364,000 LSW5,PS1 4!~8.000 SSW4.PS! '0.549 CS,PS1 16~,000 CCL,PS1 478 710 CNEC,PS1 40~758 TNPH.PS1 40.200 RCNT.PSl 2~3,240 2.904 SSRH.PS1 25.766 5SWl,PS1 287,500 5SW5.PSI 3t26.000 SSW4,PS1 -0.677 CS,PS1 95 688 CCh. PSI 510~088 CNEC,PSI 4!,351 TNPH.PS1 39,042 ~CNT.PSI 316,073 939 SSRH.PS1 2 :ooo 257.750 LSWS.PSI 3316.000 SSW4,PSl -0,629 CS,PSi 72,188 CCL,PSI 550,3~8 CNEC,PS1 39,2 5 TNPH,PS1 40.026 RCNT.PS1 330.020 2.848 SSRH.PS1 28.625 LSW1,PS1 32 50 0 0 SSW4.PS1 0 5 6 CS.PS! 66,~50 CCL,PS1 600..38 CNEC,PS1 3 ~ TNPH . RCNT.PSI 395,868 22.697 SSRH,PS1 7.156 LSW!.PSI 451,250 LSW5.PS1 4760,000 SSW4,PS! 0 ~l, CS.PS1 439,517 CN~C,PS1 43.9i9 TNPH,PSI 45.637 .~CNT.PSI ~62.51~ 3.578 100.938 374.000 1890.000 920.5OO 0.016 2764 708 40!516 1046 038 3.865 89.313 283.500 6:soo 0 063 27~7:871 38 607 3 832 91:813 283,000 1673,000 917,500 0 098 38 71 1133,9~7 3,609 33 . 0 1963.000 913.500 -0 043 2899 77~ 32 723 !242 609 124, 429,750 2029.000 912,000 -0.064 2625 729 43~614 072.008 PEFL.PS1 bS~2.PSl SSw5.PS1 TENS.PS1 ENPH.PSI RCEF.PSI TNRA.PS1 RCFT.PS1 PEFL.PS1 LSW2.P$1 SSWI-.PS1 SSWS.PSl TENS.PS1 ENPH.PS1 RCEF.PS! TNRA.P$1 RCFT.PS! PEFL.PS1 bSW2,PSl SSW1,PS1 SSWS'PS1 TEN'S,PS1 ENPH,PS1 RCEF,PS1 TNRA,PSI RCFT,PSI PEFL.PS1 SSWS,PS1 TENS,PSI ENPH,PS1 RCEF.PS1 TNRA.PSi RCFT.P$1 PEFb bSw2:PS! SSWI.PS1 SSWS.PS1 TE.NS,PS1 ENPM.PS1 RCEF.PS1 RCF PS1 25,203 176,750 49t.750 230.000 15,000 3041.790 479.829 3.638 263,857 25.766 374 50 38,087 521,646 3.~71 289. 30 25O 387 250 ooo ooo 037 28 625 167..000 460 500 6 5 209 0~0 3040 367 27 156 253 6 5 27~0 000 44 437 g84 251 8.12 923 ,IS TaDe Verification !..istin~ ;chlumberqer AlasKa Computimq Center 17-AUG-1992 19:54 PAGEI 12 DEPT. 6700,0o0 bSRH.PSI PFFS.PSI 31.156 PEF.PS! L~w3.PS! 628.500 LSW4.PS1 $$w2,PS1 1881.000 SSW3.PS! RHOP.PS1 2,237 DRHO,PS! CAL!,PS! 6,164 GR.PS1 ENRA.PS1 5,245 CFEC,PS1 RCfiM.PS! 2476.484 NPH!,PS! RTN~.PS1 3.345 NP[iR.PS! CNTC,PS1 1084'752 CFTC.PSI DEPT. 6600,000 I, SRH.PS1 PEFS.PS1 ~8.031 PEF,PS! LSw3,PS! 618.500 LSW4.PS! $SW2.PS1 ~754,000 $SW3,PS1 RHOB.PS! 2.21.7 DRHO.PS~ CALI.PS1 6,~0 GR.PS1 ENRA,PS1 5.375 CFEC,PS1 RCFN,PS1 24~8,5~5 NPHI,PSI RTNR.PS! 3.910 NPOR,PS1 CNTC,PS! 1077,~47 CFTC.PS1 O0 LSRH.PSi DEPT. 6500'~44 PEF'PS1 PEFS,PS! 30, LSW3.PSI 696,000 LSW4,PSI SSW~,PS1 l~zS.000 SSW3,PS! RHOB,PS! 2,204 DR~O'P$1 CALl,PSI 6,~76 GR,PS! ~N~A PS~ 5.601 CFtC'PS1 RTN~ PS1 3,820 MPOR PS1 · TC,PS! 9~9,449 CFTC,PSi D~PT. 6480.500 LSRH,PS1 PEFS,PSI 25,250 PEF.PS1 LS~3,PS! 6!~1,500 LSW4,~SI $Sw~,PsI 1944.0010 RHOB.PSI 2.~235 ORH~'PSI ~PSl CAD[,P$! 6,:164 EN~A,PS~. 5,702 CFEC,PSI RCEN.PS! ~50~,310 ~PHI,PS1 pTNR,PS1 3~7~5 NPOR,PS1 CNTC,PS! !052,722 CFTC.PSi ** END OF DATA 2,~4 $SRH,P$1 32. 5 LSW1.PS1 4a3 Psi 5240:000 SSW4:~SI '0.428 CS.PS1 78.000 CCh.PS1 506,062 CNEC.PS1 32.1!3 TNPH.PSi 30.662 RCNT.PSI 354.210 6 80 SSRH.PSl 2 922 LSW!,PS1 486.500 LSW5,PS! 500~ 000 SSW4.PS1 -0:464 CS,PSI 87 3 CCL,PS1 494:~5 CNEC,PS1 ~ 567 TNPH,PS1 ] '758 RCNT.PS1 312,333 22 16 bSWl,P$1 500 LSWS:.PS~ -0.437 CS,PS1 98,813 CCS,PS1 4~,390 CNEC,PSI ,855 TMPH,PS1 36,029 RCNT,PS! 292.944 2 795 19 172 468 250 4948 O0 8~,563 478,618 38,397 371486 299'121 SSRH,P$1 bSWl,PSl bSW5,PSl SSW4'PS1 CS,PS1 ccs~iPS~ CNEC,PS1 TNPH,PSI RCNT;PSI 3.277 137.750 487.500 2422,000 9~8.500 0.055 2654.045 31.403 1116.259 3,342 134.500 440.500 2204 000 . 940..500 '0.055 2657,862 37 543 1107:.820 3 264 160 ~375 487 500 2344 000 939'000 0.074 2584.077 36.'364 1006'67'9 3379 150500 406 250 2082 ~00 934 O0 2729 75 38.651 1090947 PEFL.PS! LSW2,PS1 SSWI.PS1 SSW5.PS1 TENS.PS1 ENPH.PS1 RCEF,PS1 TNRA.PSI RCFT.PS1 PEFL.PS1 LSW2.PS1 SSWl.P$1 SSW5.PS1 TENS.PSi ENPH PSi RCEF:PS1 TNRA,PS! RCFT.PS! PEFL PSi bSw2 PSi SSWl PSi SSW5 PSi TENS PSI ENPH.PS1 RCEF*PS1 TNRA.PS1 RCFT,PS1 PEFL,P$1 bSW2.PS.! $SWI,'PSl ~SwS.PS! 2ENS,P$1 ENPH.PS1 RCEF,P'S1 TNRA,PSI RCFT,PS1 32 125 297 250 608 50O 240 250 532 431 3 164 334 416 24,922 290,500 566,500 25 125 280~ 000 37 3 7 501 ~1~6 3 516 297 424 22'016 320,000 592,,0~0 255,0 0 2695~000 2~4~54~ 307'OOO 545,500 247~;375 2675'000 40,~948 479'778 ~.'509 282.~015 Tape verification List]no ~chlU~berger AlasKa Compt]tino Center 17-AUG-1992 19:54 PAGE~ **** FI!~M TRA!LS~R **** F'~LE ~E : EDIT .002 SERVICE : FLIC YERSIO~.~ : 001A07 OATF : 02/0B/~.7 ~× REC SIZE : 1024 FILF TY~E : LO LAST FILE : **** FILE HEAOER **** FILE NA~E : EDIT .003 SEPVICE : FLIC VERSION : O01A07 DATE ~ 92108/!7 MAX REC SIZE : 1024 FILE TYPE : [.,0 LAST FILE : ****************************************************************************** FILM - ARCO A!~ASKA INC 2~17 "RhW FIELD DATA PASS #2" Da. TA SAMPLED EVERY -,5000 FEET D~TA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME HLDT .PS2 !,{[]STILE ENVIRONMENT bDT * CMT-G iPS2 CO~,PENSATED NEUTROM THER~Ab/EPITMERMAL , ****************************************************************************** ,IS Tape verification LlstJna ichlumberqer AlasKa Computing Center 17-AUG-1992 19:54 PAGEI 14 ARCO AbASKA, I~C, Company Name CN FN KUPARUK RIVER UNIT AFI~ 50-103-20150 Fi, 114' FSL & 379' FWL SECT 27 TOWM COU~ NORTH ST~T ALASKA N~TI USA WIT~ B BERRY SON 4{3497 APD FT 146, EgB FT 146' E~F FT 146, EGL FT 105, TDD FT 7857. DFT BRINE WATE.. DF[) Field Name Well Name APl Serial Number Field bocation Section Township Range Count~ State or Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datu~ Dog. Measured From Above Permanent Datum Elevation of Kelly Bushing Elevation of Derric~ Ftoo~ ElevatiOn of Ground bevel Total~Depth ? Driller Drilling Fluid Type. Drillino Fluid Density BHT DEGF 16., Bot*tom Hole Temperature . TABLE TYPE : CURV DEPT Depth 5SRH bong Spacln~ Bulk Densit~ 85~ Short Spaclflg Bulk DenS!_y PEFL PEFL PEF$ PEFS pEF PhotoElectric Factor bSW! bSWl LSW3 LSw3 bS~4 t,$w4 bSW5 bSw5 SSW~ SSWI SSw~ SSw2 SS~ SSw3 S$~4 SSW4 SSW5 SSw5 RHOB BUI~ Density DR~{O Delta R~O CS Cable Speed TENS Tens~om ~IS Tame Verification bistino ;chlumberoer AlasKa Computing Center 17-AUG-X992 19:54 DEFI ChblCalimer · . CCL CCL Am ENP~ Mp~thermal Neutrom Porosit~ EMR~ E~xtbermal Neutron Ratio C~llbrated CFEC Corrected Far EPithermal Counts C~EC Corrected Near Eulthermal Counts ~CEF Raw Corrected Eplthermal Far Counts RCEN Raw Corrected EDlthermal Near Counts NPNI Neutron Porosity TNPM T~erma! Neutron Porosity TNRA Thermal ~4eutrom Ratio Calibrated ~TN~ Raw Thermal Neutron Ratio NPOR Neutron Porosity from an A~Dlication Prooram RCNT RCNT RCFT RCFT CNTC' CNTC CFTC CFTC PAGE: DATA FORe, AT SPECIFICATION RECORD SET TYPE - 64EB $$ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 152 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT ~ 66 6 !2 68 13 66 0 14 65 FT ~5 66 68 16 66 1 0 66 1 ,IS Tape Verification Listlnq ;chlumberqer AlasKa Comoutlno Center 17-AUG-1992 19:54 PAGE** ** SET TYPE - CHAN ** '~;~'. · ......... SERV U~i ~'~i~'"'"'"iAPI AP ............. APl API FI '''''''''''''''''''''''''''''''''''''''E NUMB NUMB SIZE OCESS ID ~RDER # bOG TYPE CLASS ~OD NUMB SAMP ELEM CODE (HEX) DKP FT 41~497 O0 000 O0 0 ] 1 ! 4 68 0000000000 bSRH PS2 SSR;~ PS2 PEFL PS2 PEFS PS2 PEF PS2 LSW1 PS2 LSd2 PS2 LSW3 PS2 LSW4 PS2 LSW5 PS2 SSWl PS2 SSw? PS2 SSW3 PS2 SSW4 PS2 S$W5 PS2 RMOB PS2 DRHO PS2 CS PS2 TENS PS2 CAbI PS2 OR PS2 COb PS2 ENP~ ENRA PS2 CFEC PS2 CNEC RCEF PS2 RCEN NPMI PS2 TNPN ~N~ PS2 RTNR PS2 NPOR PS2 RCNT P82 RCFT PS2 G/C3 413497 O0 000 O0 G/C3 413497 O0 000 O0 413497 O0 000 O0 413497 O0 000 O0 413497 O0 000 O0 CPS 41~497 00 000 O0 CPS 413497 O0 000 O0 CPS 413497 O0 000 O0 CPS 413497 O0 000 00 CPS 413497 O0 000 O0 CPS 413497 ~0 000 O0 CPS 413497 O0 000 00 CPS 413497 O0 000 O0 CPS 4!.3497 O0 000 O0 CPS 413497 O0 000 00 G/C3 413497 00 000 O0 G/C3 413497 O0 000 O0 F/~R 413497 O0 000 O0 LB 413497 O0 000 O0 IN 413497 O0 000 O0 GAPI 413497 O0 000 O0 V 413497 O0 PU 413497 O0 413497 O0 CPS 413497 O0 CPS 413497 O0 CPS 413497 O0 CPS 413497 OD PU 413497 OD PU 4134~7 413497 O0 4.13497 O0 pu 413497 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 CPS 413497 O0 000 O0 CPS 413497 O0 000 O0 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 o 3 o 3 o 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 ! I 4 68 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 ! 1 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000000000 I i 4 68 0000000000 I 1 4 68 0000000000 1 i 4 68 0000000000 I 1 4 68 0000000000 1 ! 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 ! I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 ~. 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 C~TC PS2 CPS 4i 3497 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC P. S2 CP~ 413497 0,0,?, 00.0 O0 0 ~ 1. 1 4 68 00.0000000 ** DATA ** DEPT, 7881.500 bSRH,PS~ 2 PEFS.PS2 'tl,891 PEF P$2 ~ 1.,$~3,P$2 1060.000 LSWa:.PS2 8 SS~?,PS2 3760,0o0 SSW3.PS2 8272 RMOB,PS2 2,333 D~HO.pS2 -0 CALl',PS2. 8.500. GR P~.o2 68 ENPA,PS~ 5.318 CFEC:PS2 478 65 SSRH,P$2 36 LSW1,PS2 000 LSW5.PS2 000 SSw4.P$2 133 CS..PS2 250 CCh,PS2 226 CNEC,PS2 2.664 PEFb. PS2 762.:500 SW .PS2 4066,000 SSW5.,PS2 86,500 TENS*PS2 -0,055 ENPH,PS2 2543,096 RCEF.PS2 14'836 553;000 ~293'000 897~000 2360'000 36.;699 479;442 16 .IS Tape Yerifi. cation I.,tst. inC~ :ch].umberqer Alaska ComDutino Center DEPT. 7800.000 LSRH.PS2 PEFS P$2 20.8!3 PEF.PS2 LSW3~PS2 617.000 [~Sw4,PS2 SSW~ PS2 1788.000 $Sw3.PS2 RHOB~PS2 2.171 D~HO,PS2 C~LI.PS2 6.219 GR.P$2 ENRA.PS2 5.664 CFEC.P$2 RCEN.PS~ ~322,9~7 NPHI.PS2 ~TND.PS2 4,O77 NPOR,P$2 CNTC.PS2 1050.692 CFTC.PS2 DEPT 7700 000 bSRH.PS2 P~F$:P$2 25:375 PEF,P$2 LSW] P$2 469.500 LSW4.PS2 SSW~:PS2 1755,000 SSW3.P$2 RHOB P$2 2.325 DRHO.P$2 CaLI:PS~ 6.219 GR.,PS2 [:NRa.PS2 4,936 CFEC P$2 RCEN,PS2 2746'240 NPHi:PS2 RTNR.PS2 3.362 NPOR.PS2 CNTC.P$2 ~267.450 CFTC,PS2 DEPT.: 7600,000 LSRH,P$2 PEF..q, PS2 22.813 PEF. P$2 LSW3,P~2 608,000 LSW4,PS~ SSW~.PS~ 1668.000 SSW3,PS2 RHOB,PS2 2,156 DRHO,PS2 CAL!....- $2 6.219 G~, PS2 E ~ ~ ~. P S 2 4.51 i C~ ~ C · PS 2 RCEN.,PS2 2771.703 NPHI,PS2 RTNRiPS~ 2.800 NPORiP$2 CNTC,PS2 ~573.3~5 CFTC,PS2 D~PT, 7500.000 ~ PS2 603,500 SSW2:PS2 1199,000 SSW3,P$2 RH[]B,PS2 2.026 DRHO.,.P$2 CALI,P$2 6,2~9 GR'P$2 ENRa,PS2 6 567 C. ~C,PS2 RCEN,PS2 2144.564 NPNI,P$2 RTN~'PS~ 4.q58 NPOR,PS2 CNTC,PS~ 894'~29 CFTC~Ps2 DEP'P, 7400.000 LSRH*PS2 PS~ 40 000 PEF~PS2 P~S. .. LSW3,PS~ 341.250 bSW4,P$2 SSW2.P$2 965,000 SSW3'PS2 ~OB,PS2 2.24! DRHO-PS2 C~LI,PS2 6,203 GR.Ps2 ENRA,PS2 5.924 CFEC,PS~ i7-AUG-1992 t9:54 4'2.583 TNPH.PS2 40.564 RCNT.P52 ~88.1]1 2.695 $SRH.PS2 25.109 LSW!.PS2 467.750 LSWS,P$2 4692.000 SSW4.PS2 -0 525 CS,PS2 63i156 CCL,P$2 451 974 CNEC.PS2 41,486 TNPH.P$2 41.400 RCNT.P$2 281.493 2.818 20. 1 4492'000 '0 495 34 214 408 899 2 715 20~688 431,500 4416,000 '0.56! 31'~88 668, 82 24, 602.461 3~ -686 ,031 477~750 3774'000 ~0.660 63.8!3 3~5,177 1.5:20 51.174 2! .062 2 898 25 859 285 000 3242 O00 -0 658 6 438 42~ 540 $S~H,PS2 bSWI,PS2 LS~5,PS2 SSW4,P$2 CS,PS2 CCD.PS2 CN£C,P$2 TNPH.PS2 RCNT,PS2 LSW1,P$2 bSwS,PS2 $SW4.P$2 CS'PS2 CCL!,PS2 CNEC,P$2 TNPH,P$2 RCNT,PS2 SSR~,PS2 SWS,P$2 $W4,PS2 CS,P$2 CCL,PS2 CNEC.P$2 TNPM.PS2 RCNT,PS2 SSRM.PS2 LS 5'P$2 SSW4,PS2 CS-PS2 cc 'v$2 CNEC.PS2 40.564 1057.712 3.443 413 .00 1937.000 880.000 -0.057 2559,867 42,153 1077.627 3 23 308 500 '1944[~000 895. g00 .o: 30~7.172 I ~80 1210~ 83 3'514 135.375 397.250 834,000 1898.000 '0.05i 3017'.09 24,593 1569.60'8 3,621 !25,750 436.000 1761,000 902'.000 0,':031 2332'394 50,163 886't00 3.832 79.000 298-.000 1670.000 897..000 '0-029 2538.86! TNRA.PS2 RCFT.PS2 PEFL.PS2 LSW2.PS2 SSWI.PS2 $SwS.PS2 TENS.PS2 ENPH.P$2 RCEF.P$2 TNRA.P$2 RCFT.P$2 PEFL.PS2 LSW2,PS2 SSWl.PS2 SSwS.PS2 TENS.PS2 ENPH.PS2 RCEF.P$2 TNRA,P$2 RCFT.PS2 PEFL,PS2 bSW2'PS2 $SW!.PS2 SSWS'PS2 TENS,PS2 ENPH.PS2 RCEF.PS2 TNRA.PS2 RCFT.P$2 PEFL.PS2 LSW2,.P$2 SSW!.PS2 SSWS.P$2 TENS,PS2 ENPH.P$2 RCEF,PS2 TNRA:,P$2 RCFT PS2 EF'b. PS2 LSW2'PS2 SSWl,PS2 SSWS,PS2 TENS,PS2 ENPH, PS2 RCEF'P$2 PAGEI 3.~39 266, 57 25109 293 500 533 000 213 625 3600 000 40,514 460.409 3,678 259.436 504 750 204 250 0 0 58~ 713 246 37 !. 540 20 688 283 500 494 750 3480 28 557 64~ 0.17· · 699 565 822 264 i84 3,525000 5I' 5:53 327.646 4 229 :215 841 25,859 145:,~ 0 !:95'~50 3570;000 4~5 420;3~ 17 ,IS Tape Verification Llstinq ;chlumberger Alaska Computlnq Center RCE~.P$2 2337.652 ~PHI.PS2 RTNP.PS2 4.O16 NPOR.P$2 CNTC.PS2 1029.366, CFTC.PS2 DrPT 7]00.000 LSRH,PS~ PEF$iPS2 31.078 PEF.PS2 5Sw~ PS2 369.75(3 LSW4.PS2 SSW2.PS2 1421 0GO $Sw3.PS2 RHOB.PS2 2~331 DRHO.PS2 CaLI.PS2 6.188 GR.PS2 ENR~.P$2 5,625 CFEC.P$2 RCE~.P$2 2517.282 EPRI.P$2 RT~]P,P$~ 3.812 NPOR.P$2 C~TC.PS2 10~3.644 CFTC.PS2 DEPT. 7200.000 LSRH.PS2 PEFS.PS~ 29.266 PEF.PS2 LSW3,PS2 467 250 bSW4.P$2 SSW2.PS2 1555:000 SSW3.PS2 RHOB.PS2 2,23g DRHO.PS~ C~L~,P$~ 6.207 GR,PS2 E~iRA PS2 5.672 CFEC,PS2 RCEN~P$2 2678.674 NPHI,PS2 RTNP,PS2 4.061 NPOR.PS2 CNTC,PS2 1062.7~1 CFTC.PS2 DEPT. 7191.500 5SR~{,PS2 PEFS.PS2 40,000 PEF:.PS2 L$~3,PS2 418,000 LSWg":.PS2 SSW~.P$2 I!65.000 ~SW3.PS2 RHOB,PS2 2,181 DRHO,PS2 CALI,PS~ 6.188 GR,PS2 EN~.PS2 5.7~.0 CFEC,PS2 ~CEN.P$2 2588.288 NPHI,P$2 RTN~,PS2 3,894 NPOR,P$2 CNTC.PS2 1081.931 CFTC.PS2 END OF DATA 17-AUG-1992 19:54 42.654 T~PH.PS2 39 856 RCNT.PS2 286~937 2.869 SSRH,PS2 28 609 bSW1,PS2 317~250 hSW5,PS2 4048.000 SSW4..PS2 -0.539 CS,P$2 135,500 CCL.PS2 487,798 CNEC,PS2 42.~1 T~!PH.PS2 37. 9 RCNT.PS2 310.458 ~:7~7 SSRH.P$2 2 8 5 LSWI,PS2 3681500 [.,SWL,PS2 4192'000 SSW4.PS2 -0.549 CS,PS2 156.250 CCL.PS2 491. 43.~ CNEC.PS2 TNPH.PS2 40.446 RCNT°P$2 295.566 2.822 $SRH.PS2 3 ~406 bSWl.,PS2 000 LSWL.PS2 3570.000 SSW'4,P$2 '0.643 CS~.PS2 18~,125 CCL,PS2 48 .764 CNEC,P$2 4~ ~I T~PH'.PS2 298,007 39.760 1036.949 3.635 81.813 300.000 1832.000 9O0.0OO 0.055 2744.015 38 182 1113:229 3.568 97'375 356 000 1910 33 8 00 8'975 27~9-892 1059.977 3.734 84.000 340.~500 1~66.000 21'500 -:0,.006 2785"243 40'~67 1089~527 TNRA.PS2 RCFT.PS2 PEFL.PS2 LSW2.PS2 SSWI.PS2 SSW5 P$2 TENS:PS2 ENPH PS2 RCEF:P$2 TNRA PS2 RCFT:P$2 PEFL,PS2 5SW2,PS2 SSWl.PS~ 8Sw5.P$ TENS.PS2 ENPH°PS2 RCEF P$2 TNRA:P$2 RCFT,P$2 PEFL.P$2 ~sw~.Ps~ SSw ,PS2 SSW ~PS2 TENS,PS2 ENPH.PS2 RCEF.PS2 TNRA,P$2 RCFT..PS2 PAGE: 18 3,742 260,661 28,609 177 250 457 000 204 375 3490 O00 40 079 472 729 3,~22 283.896 2?.875 208.000 479,750 207.375 3480,000 40,603 504' 36 406 66 00.375 000 196 ~ **** FILE TRAILER **** FILE NA~E : EDIT ,003 SERVICE : FLIC VERSIOC~t i O01A07 DAT~ : 02/08/17 ~AX REC $IZ~ : 1024 LAS], FILE : ,IS Tape Verification bistin~ ;chlt]mberger AlasKa Ccmputin~ Center **** FILE HEADEk **** FILE NA~E : EDIT ,004 SERVICE : ~!~!C VERSION : O01A07 DATE : o2/08!~7 ~AX PFC SIZE : 1024 FILM TYPE : l.,O LAST FILE 17-AUG-].g92 19:54 PAGEI 19 ****************************************************************************** FILE - EDIT.004 ARCO ALASKA, INC. KUPARUK RIVER U~IT 2~-1.7 "RAW FIELD DATA PASS #3" DATA SA~PI, ED EVERY -.5000 FEET DATA INCb~DED - TOOL EXTENSION TOOL TYPE USED NAME EN,I T HLDT ,F'.S3 HOSTILE "V RONM~NT bD CNT.'''G ,PS3 COMPENSATED ........ N~UTRON TMER~AL/EPITHERMAL ****************************************************************************** TABLE TYPE : CONS TUNI VALU OFF! CN ARCO ALASKA, IN'C. Company Name~ FN KU~ARUK RIVER UNIT FieldN. ame WN 2M !7 'Well Name APlN ..... 50!1~,103-201508 , APl Serial Number F b & 379' ~Wb Field Location FL SECT 27 ~ectlon RAN~ BE Ranoe COUN NORT~ SLOPE CoQfi:ty STAT AI,,ASKA State or Province N~TI USA Nation ,IS Ta~e_ verff~.catlor, Listlnq ~chlumberger AlasKa Comput.~..mg Center !7-AUG-I992 t9:54 PAGE{ 2O TUNI VALU DEFI ........ " ................ " ...... '"'"" .............. ---------------------------------------- ~ . B BERRY witness Name SON 4{3497 Service Order Number pDAT MSL Permanent datum ~pn FT 0 L~ K~ Elevation of Permanent Datum Log ~easured From APD FT 146 ADore Per~anent Datum EK~ FT 146: .... Elevation o~ Kelly Bushing EDF FT 146 Elevation of Derric~ Floor EGL FT 105i Elevation of Ground Level TOD FT 785 . Total Depth - Driller D~T BRINE ~'~TE~ ~ ~ § Driltlng Fluid Type~ DF. ~/C3 10 Dril in~ FlUid Density BNi DEGF 16 , Bottom Hole Te perature TABLE TYPE : CURV DEFI DM T..,p Depth LSRH Lono, $~acinq Bulk Oensit Short. SPacing Bull( Densl~¥ PEFL PEFS LSW~ LSW5 SSWl SSw2 $$w3 SSW4 SSW5 CS C~LI CCL ENpH Cr~C CNEC RCEF RCEN NPM! TNP~ TNRA RTN~ PEFb PEFS photoelectric Factor LSW 1 LSw2 LSW3 LSW4 bSw5 SSWl SSW2 SSW3 SSW4 SSW5 Bulk Density Delta Cable Speed ~ .n$lon Caliper Gam~a Ra CCL Amplitude Epltber~a], Neutron Porosi~V Bpi, thermal ~ieutron Ratio C~llbrated Corrected Far E~ithermal Counts Corrected Near EPlt, her~al Counts P~aw Corrected EDithermal Far CoUnts Raw Corrected Epitlbermal Near Counts Neutron Porositv Thermal. Neutron Poros~.~y Thermal Neutron Ratio Lalibrated Raw Thermal Neutron Ratio .,IS Tame verification Listinu · (.e ~ter ;cblu,~berqer Alaska Com[~t]tin~ ' r .. 17-AUG-lq92 1. q:54 DEFI NPO~ sit¥ fro an ~ppllca Pro~ra RCNT ~CNT RCFT RCFT CNTC CNTC CFTC CFTC PAGE~ 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TY REP .,~DE UE 1 6(-, . 2 66 0 3 73 152 4 66 5 66 6 73 7 65 8 6~. 0,5 g 65 ET 11. 66 6 12 68 13 66 0 14 65 FT 15 6~ 68 16 66 0 66 I ~,III~III~I~I~I ~I~I~I~I ~I~I~I~ ~ ~IIII~I~t~II~IlII~II~~ AME V [INIT $~RVICE A . API A API FIL NUmB N MB SIZE REPR PROCE~ ID ORDER # bOG TYPE CLASS NOD NUmB SAMP ELEM CODE (HEX) ......... ........... ;-; .................... ; ........ ............ ;;................. DEPT FT 41 4 7 O0 000O0 4 I 4 0000.000000 LSRM PS3 G/C3 4:13497 O0 000 O0 0 4 1 ! 4 68 0000000000 SSRW PS3 PEFL PS3 PFFS PS3 PEF PS3 LSW~ PS3 LSW2 PS3 LSWI PS3 LSW. PS3 LSW5 PS3 SS~1 PS3 SSW~ PS] $SW3 PS G/C3 413497 O0 000 O0 0 4 1 1 4 68 ~134o7 O0 000 O0 0 4 1 1 4 68 413497 O0 000 O0 0 4 1 1 4 68 4134g7 O0 000 O0 0 4 I I 4 68 CPS 413497 O0 000 O0 0 4 1 i 4 68 CPS 413497 O0 000 O0 0 4 1 1 4 68 CPS 413497 O0 000 O0 0 4 1 I 4 68 CPS 413497 O0 000 O0 0 4 I I 4 68 CPS 413497 O0 000 O0 0 4 1 I 4 68 CPS 413497 O0 000 O0 0 4 I ! 4 68 CPS 413497 O0 OOO O0 0 4 1 I 4 68 CPS 413497 O0 000 O0 0 4 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS TaDe Yeriftcatlon LlsttDq ;ch!umberger A].as~a ComputlD~ Center 17-AUG-1992 19:54 PAGE{ 22 i '"' ..... N3 3 ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) """"2"'''$SW P$3 ......... CPS 4'T'3497 ......... 00 '000 00 '~''''4 ........ ! ' ..... ! ' ..... 4 ''''''''''''''''3'''68 00000000 0 CPS 413497 O0 000 00 0 4 1 1 4 68 0000000000 RHOB PS3 G/C3 413497 00 000 O0 0 4 ! I 4 68 0000000000 DRHO PS3 G/C3 413497 00 000 00 0 4 1 i 4 68 0000000000 CS P$3 F/HR 413497 O0 ~00 00 0 4 1 I 4 68 0000000000 T£NS PS3 LB 413497 O0 000 00 0 4 1 I 4 b8 0000000000 CAL! PS3 IN 413497 00 000 00 0 4 1 1 4 68 0000000000 G~ PS3 GAPI 413497 00 CO0 O0 0 4 I 1 4 68 0000000000 CCL PS3 V 413497 00 000 O0 0 4 I 1 4 68 0000000000 ENP~ PS3 Pt! 413497 O0 000 00 0 4 1 ! 4 6'8 0000000000 ENRA P$3 413497 00 000 O0 0 4 1 ! 4 68 0000000000 CFEC PS3 CPS 413497 00 000 00 0 4 1 1 4 68 0000000000 CNEC P$3 CPS 413497 00 000 O0 0 4 1 I 4 68 0000000000 RCEF P$3 CPS 413497 O0 000 00 0 4 1 I 4 68 0000000000 RCEN P$3 CPS 413497 00 000 O0 0 4 ~ 1 4 68 0000000000 NPHI PS3 PU 413497 00 000 OO 0 4 1 1 4 68 0000000000 TNP~ PS3 PU 413497 O0 000 O0 0 4 ! 1 4 68 0000000000 T~RA PS3 413497 00 000 O0 0 ~ 1 1 4 68 0000000000 RTNR PS3 413497 O0 000 O0 O 4 1 1 4 68 0000000000 NPO~ PS3 PU ~13497 O0 000 O0 0 4 I 1 4 68 0000000000 RCNT PS3 CPS 413497 O0 000 OO 0 4 1 1 4 68 0000000000 RCFT P$3 CPS 413497 O0 000 00 0 4 1 1 4 68 0000000000 CNTC PS3 CPS 413497 00 000 O0 0 4 ~. 1 4 68 0000000000 CFTC PS3 CPS 41.3497 00 000 00 0 4 i I 4 68 0000000000 PEFS'PS3 ' 20 563 PEr,PS3 3 65 5$Wi.PS3 22 :' ' · · 5SW2.P$3 4 7 I~SW3*PS3 854,000 LSW4.PS3 ~62,500 LSW5.PS3 7~..~00 $SWl.PS3 933 $SW~,P$3 3038.000 SSW3.P$3 7 80,000 SSW4.PS3 34 '000 $Sw5.PS3 6~ RHOB;PS3 2.316 DRHO.P$3 -0.217 CS.P$3 300.000 TENS.PS3 13 CA. LI.PS3 8.500 GR,PS3 65,688 CCL,PS3 -0.055 ENPH.=PS3 ~NRA.PS3 5,353 CFtC.PS3 489.=380 CHiC,PS3 2619-.893 RCEF.PS3 4~0 ..... .,NPH :PS3 41,144 TNRA.P$3 3 R7>N~.PS3 ~.966 NPOR.PS3 4~4 RCNT,PS3 1159.941 RCFT,PS3 CNTC~p$3 !149..045 CFTC.PS3 31, , DEPT.- 7800,000 bSRH,P83 PEFS, PS3 23. 250 PEF* PS3 LSW3.PS3 635,500 LSW4,PS3 SSR2 PS3 1835,000 SSW3.PS3 RHOB PS3 21191 DRHO,PS3 CaLI PS3 ~ 223 GR.PS3 ENR~ Ps3 ~898 CFEC,DS3 R-.E~ PS3 2422.363 NPHI,.PS3 RTNR.PS3 4.091 D,~POR..E~3 CS}TC '. PS3 1040.431 CFTC,PS3 ,094 [,$Wl~PS3 465'500 LSW5'P$3 4864,000 $SW4.P$3 -0.498 CS,PS3 436,7 9 CNEC,P$~ 42.~2 TNPH.PS3 4!. 4 RC~'T,PS3 284.521 3.396 PEFL.PS3 134"750 LS~ ,PS3 420.250 S$.~.PS3 2022,~000 SSW'5.P$ 875.500 TENS.PS 0.004 ENPH.PS~ 2576.393 RCEF,PS3 40,899 TNRA.PS3 103!,824 RCFT.PS3 ¸2 6 :296 541 224 3495, 43,i ,,656 75O 000 000 6~4 :771 627 094 750 500 000 000 1226 :295 735 170 ..IS Tape Vertfi. catJon I. istl. nq ;chlUmberaer Alaska [om[utin~" '~ _ Center 17-AliG-1992 lg:54 PAGE: 23 DEPq: 7700.000 LSRH.PS] PEFS~PS3 20,453 PEF.PS3 LSW3.PS~ 523.500 bSw4.PS3 SSw~.PS3 !933.000 $SW3.PS3 R~O~.PS3 2.319 DRHOoP$3 CALI.PS3 6.2~5 G~*PS3 ENRA.PS3 5.0~2 CFEC.P$3 RCEN.PS3 2633.491 ~tPHI,P$3 RTNR.PS3 3.295 ~POR.PS3 CNTC.P$3 1268.714 CFTC.PS3 DEPT. 7600.000 LSRH.PS3 PEFS.PS3 28,438 PEF.PS3 LSW3.PS3 600.500 hSW4.PS3 $$W~.PS3 1654,000 SSW3 PS3 RHOB'PS3 2.167 DRHo:PS3 CaLI.PS] 6.1.99 GR.PS3 ENR~.PS3 4,446 CFEC,PS3 RC~.PS3 28~4,10! N~HI.PS3 RTNR,PS3 2,911 NPOR.P$3 CNTC.P$3 1.566.391 CFTC.PS3 DFPT 7500,000 LSRH,PS3 PEFS:PS3 37.531 PEF,PS3 LSW3,PS3 607.500 LSW4.PS3 $$W~,P$3 1305.000 SSW3,.PS3 RROB,P$3 2,053 DRHO.PS3 CAL!,PS3 6;223 GR.PS3 ENRg,PS3 6.575 CFEC.PS3 RCEN.PS3 2158,257 NPHI.PS3 RTNR.P$3 4.333 NPOR,PS3 C~TC.PS3 877,!73 CFTC.PS3 D~PT. 7400.000 LSRH,P$3 PEFS PS3 40.00() PEF.PS3 LSW3:PS3 346,750 bSW4.PS3 SSW~.PS] 956,000 SSW3,PS3 RHOB,P$3 2"208 DRHO,PS3 C~bl. PS3 6.21 ! GR, PS3 [~iR~.PS3 5;660 C~~Ec..ps3 RCE~PS3 2367.047 NP~I.P$3 RTNR.PS3 4-133 ~POR'P$3 CNTC,PS3 1028.747 CFTC'PS3 DEpT, 7300,000 LSRH,PS3 PEFS.P$3 29.859 PEF,P83 LS~i3 PS3 365,500 l'~ ~ · ' * . .uoW4.PS3 SSW2.P$3 137i.000 $SW3,PS3 EN~I,PS3 5.495 CFEC,PS3 RCE'~,PS3 ~474,992 ~PHI.~I] RTNP PS3 3.789 NPOR, CNTC' ' ..' . .... .PS3 10~5.463 CFTC,PS3 2.777 SSRH.PS3 24.625 LSWI.PS3 354.500 LSWS,PS3 4840.000 SSW4.P$3 -0 460 CS.P$3 62:750 CCh,PS3 599 104 CNEC,PS3 33:445 TNPH,P$3 35,~3 RCNT.P$3 393. 6 " 2,721 SSRH,P$3 22.484 BSWI.PS3 422.500 LSWS,PS3 4400.000 SSW4.P$3 -0,555 CS,PS3 34 1 CC5,PS3 686:1~7 CNEC.PS] 24.931 TNPH PS3 25.567 RCNTiPS3 596.0~9 · LSWI.PS3 464 0 LSWS,PS3 0,639 CS,PS3 ~4.250 CC[~,P$3 352,335 CNEC,PS3 49,016 TNPI~,PS3 48,853 RCNT,PS3 215.333 8 5SWl.,PS3 314,000 5$W5,:PS3 3276'000 SSW4,PS3 ;0,667 CS,PS3 3,563 CCh,PS3 448,963 CNEC,PS3 44.692 TNPH,PS3 43.47l RCNT,PS3 261,026 3~.885 '93g 307~250 3998,000 -0 544 135 625 499 376 40 953 38 566 3!0,459 SSR}i,PS3 LSWl,PS3 5$ws'Ps3 $SW4:,PS3 C$,PS3 CCh,PS3 CNEC,PS3 TNPH,PS3 RCNT'P$3 3.434 10!.250 344.5O0 2084.000 898.000 '0'055 3002.816 33..935 1231.938 3.510 123,625 383.500 1831,000 885.500 -0.06! 3051.460 24,835 1547.389 3.598 141,000 448,250 1792,000 892 000 0 020 2316 648 · 47 917 869 95! 820 3!2.2750 t640,000 8~8..000 ,.0.057 2541.~162 45,:655 1085.148 781 6o 179 O0 2744.012 38,276 1088.672 PEFL PS3 55W2:PS3 SSwl.PS3 SSW5.PS3 TENS.PS3 ENPH.PS3 RCEF.PS3 TNRA,PS3 RCFT.PS3 PEFL,PS3 LSW2,PS3 SSWI.PS3 SSW'5.PS3 TENS,PS3 ENPH,PS3 RCEF*P$3 TNRA'PS3 RCFT,PS3 PEFL.PS3 LSW2.PS3 SSWl.PS3 TENS,PS3 ENPH*PS3 RCEF'PS3 TNR.~.P$3 RCFT,P$3 PEFL.PS3 LSW2.PS3 SSWl.P$3 $$WS.PS3 TENS'PS3 ENPH'P$3 RCEF,PS3 TNRA,PS3 RCFT,:PS3 24.625 237,625 568.500 224.750 3530,000 33,499 626,546 34~ ® ,938 22.484 287,750 471,250 220.625 3390,000 27'948 689'590 , 770 55 ,865 279,750 4~3;250 1 1;1:25 3135,000 5t;663 326,595 4.09! 203'986 33,688 750 I O= 80 O0 40~ 472 467 295 155 45 !9 319.000 38 626 51,I 649 288 834 ,IS Tape Verification I..,lstino ;chlumberqer AlasKa ComPutlnq Center 17-AUG-1992 19:54 PAGE: 24 DEPT. 7' 200.000 LSRH PS3 P~FS.P$3 39.680 PEF:P83 LSw3.PS3 421,500 LSW4.PS3 SSw2.PS3 !244.000 SSW3,PS3 RMOB PS3 2.23i) DRHO.PS3 CALI~P$3 6.215 GR.PS3 ENRn.PS3 5 625 CFEC.P$3 RCEN.Ps3 RTN~.PS3 4,014 NPOR.PS3 CNTC'PS3 1049.542 CFTC'PS3 DEPT, 7!87.000 LSRH.PS3 PFFS.PS3 31~375 PEF.PS3 LSW3.PS3 464.750 LSW4,PS3 SSw2.PS3 1380,000 SSW3.PS3 RHOB'PS3 2,212 DRHO.PS3 C~LI,PS3 6.223 G~.PS3 EMma.PS3 5.7~8 CFEC,PS3 RCEN PS3 2535.499 ~PHI.P$3 R. TN~PS3 3'75.3 NPOR.PS3 CNTC,PS3 ~.042.760 CFTC.PS3 END OF DATA ~.~4 SSRH,PS] 3.672 2 , ~2 LSW!,PS3 102.875 335.500 LSWS.PS3 354.250 3838.000 SSW4.P$, 1744.000 -0 596 CS,PS~ 905.000 164~625 CCL.PS3 -0.066 487 778 CNEC,PS3 2743.989 ~41856 TNPH'PS3 40.194 41.087 ~CNT'PS3 1039.352 290,416 2. 789 SSRH,PS3 3.611 35'031 DSW1,PS3 96 563 370.000 LSWS,PS3 350~250 4032,000 SSW4,PS3 1807 000 -0.578 C$,PS3 899~500 40 975 RCNT.PS3 1060~ 9 283'228 PEFL,PS3 bSW2.P$3 $SWl.P$3 TENS.PS3 ENPH.P$3 RCEF.P$] TNRA.PS3 RCFT.P$3 PEFL.PS3 LSW2 P$3 SSW5.P$3 TENS.PS3 ENPH.P$3 RCEF,PS3 TNRA.P$3 RCFT.PS3 24,172 168'250 421.000 187,000 3025,000 40,081 40 489'~63 35,031 205 ~00 454:O0 o :§oo 3065 O0 4 46½,247 ':123 3,697 262,524 **** FILE TRAILER **** FILE NA~E : EDIT ,004 SERVICE : FbIC VERSIC)M : 001A07 DAT~ : 92/08/!7 ~AX REC SIZE : 1024: FILE TYPE : LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 92108/17 ORIGIN : FLIC TAP~ NA~E : 92495 CONTINUATION # : P~EViOUS TAPE : CO~ENT : ARCO AbASK&, INC,,KUPARUK RIVER UNIT,2M-!7,50-103-201§0 .IS ~a~e veriilcatio, histln~ chlumher~er Alaska Comput~nq Center 17-AUG-1992 19:54 25 **** REEL TRAILER **** SERVICE ~AM~ ~ EDIT ORI~!N : FLIC ~EEI, NA~IE : 92495 CONTINUATION PREVIOUS REEL. CO~EM~ : ARCO ALASKA. I~C..Kt!PA~UK RIVER UNIT.2~-I7,50-103-20150 o§moqou¥ uo!ss!u~moo 'suoO se~) 2 I!0 mlserf ~66~ L 0 33(] 3AI333 1 ~mmmmmmmm~mmmmmmmmmmmmmmmmmmm~ ~--' .... ~D~f'~qH~ ....... , ~mmmm~mmm~mmmmmmmm~mmmmmmmmmm~ IS Ta~e vertNicatlon l~i. stlno chlumber~er Alaska ComputinO Center 07:00 SERVICE NA~E : E~I'~' DATE : 02!11/19 O~IGIN : FLIC REEL ~A~E : 92409 CONTI~UATIO~ # : PREVIOUS ~EEL : COMmEnT : ARC~3 ~LASKA, INC.,KUP~RUF PlVE~ U~,iIT,2~-~7,50-103-20~50-O0 **** TAPE HEADER SERVICE NAHUM : EDIT DATE : 92/1~/~9 O~IG!N : FblC TAP~ NAME : 92409 PREVIOUS TAPE : COM~ENT : A~CO ALASKA, I~tC.,~[;PA~UK ~IVER U~.!IT,~-17,50-~03-20~50-00 TAPE HEADER KUPARUK RIVER UNIT MWD/~AD bOGS # API OPERATOR: LOC~ING COmPAnY: TAPE CREATION DATE: jOB DATA JOB MUMMER: OPERATOR SURFACE bOCATION SECTIOn: TOWNSHIP: RANGE: FSL: FEL: F~L: ~LEVATION(FT FR~..i ~i'S]5 0) KELLY BUS~IMG: DERRICK FbOOb?: GROUND LEVEL: PERRY ANGLE~ STRING STRING 2~-17 501O32015000 SC~bUi,:IBERGE~ }i!Ebb SERVICES 19-?~OV-92 BiT RUN ~ 27 114 379 146.00 146.0u 105.00 OPEN }{Oi,E CASING SIT SIZE (1!~) SIZE (!a) DEPTg (FT) 9,625 PAGE: ,IS ~a~e Ver~ficatlor, !,istin~ ;chlumberoer AlasKa Co~-I~utiDq Cer~t.~,? STRING RF~aRKS: FIEL[) [:~GI !qEER 'S 5WD Rich 001 3212' 'rD 7947' CD~ ~7~P 7'0 BIT 68.9'. HOLE CO~ECrlO~':~- ~,iT SIZ~ ]~-,~[.iV-~lg9~ 07:0o PAGE: **** FILE HEADE5 **** FILF UA~E : E~iT SERVICE : ~b!C VERSIO~ : O0~A07 D~TF : 92/11/19 MAX ~EC SIZ~ : 10~4 FILF TYPE : I~0 b~ST FILE : FILE HEADER FIL~ NUMBER: EDITED MERGED MwD Depth s~Ifted and clipped Curves: all, bit runs merged. DEPTH INCREMENT 0.5000 FILE SUMMARY PBO TOOL CODE START DEPTH STOP DEPTM ' ~WD''''''''''''', . ''~~''''~ ''''''''''7~47.0 BAS~LINE CURVE FOR SHIP'TS: GR CURVE S~IFT DATA (~EASORED DEPTH) BASELINE DEPTH 7770.0 7771.5 7735,5 7737.0 7722.0 7723.5 7712,0 7715,0 7707.5 7710. 0 7699,0 7702,0 7675,5 7677.0 7657 0 7659.5 7646:5 7649,0 7634.0 76)7,0 7606"5 7609.5 7595.0 759'9.0 7559.5 7563.5 7556"5 7560.0 IS Ta~e Verl~Jcstlom ~,istin~ cbl,3mber~er Alaska Com[~utin~ Cemter 7541.0 7545.5 7507.5 7512.0 7501.5 7506.0 748] 0 7486.5 7453:0 74.57.0 7414,5 7419,5 7368.0 7377.0 7346.0 7350.5 7131.5 7336.0 7307 5 73~.!.5 7 81:5 72 4.5 7 52.0 725s.5 7190.0 7J94.5 7147.5 7~52.5 7126,0 713!,5 7093.5 7097.5 7022,0 7025.0 6976 5 6980,0 6914:5 69J7.0 6857.0 6858.5 6835.0 6836.5 6789.5 6790.5 6754.5 6757.0 6619'5 6624.0 6539 0 6541.5 6506i5 6509.5 100 0 103.0 ~R~D DATA SOURCE PB[I TOOL COD~ RUN NO. ~E~GE TOP · MERGE BASE RM~AR~'S: THE ~:EF'TH S~!IFTS ABOVE REFLECT m%'~D GR TO cAS~,,D~ m MOLE GR ALb OT~,!~,i~ CURVES ~ERE C RRI. E WITH THE GR SHIFT, LIS FORMAT DATA PAGEI ** DATA FORe'AT SPECIFICATION ~ECi,)RD ** ** SET TYPE - 64EB ** I 66 2 6b 0 3 73 20 5 66 6 73 6~S'tS£ OsL'gs£ 800'SL~ ~t69°[6 q~'dO~ lOg'[ d~'d~ L6t '£ CI~' V~ 000'0009 . [ 8L'EOI ''''''''''''''''''''''''''''''''''''''''''''''''00 0000000 89 [ T ....... O0 000 ''''''''''''~;o0 0000000000 89 ~ '[ I T 0 OO 000 O0 0000000000 89 ~ ; '[ ; 0 O0 000 O0 8~68~g 0000000000 89 ~ ; ~ T 0 O0 000 O0 0000000000 89 ~ t T I 0 O0 000 O0 ** NYHD - ~dX& Id~D ~w 89 dN/A OM~ dOM ~WHO ~g~ Ol ~9 ** mmmmmmmmmmmmmmImmmmmmmmmmmmmm 0 99 0 I 99 9~ o mmmmmmmmm~mm##m :~ Fi q ~ .A :'il ~i F2 D 99 ~9 99 89 99 ~9 89 99 ~/'[ L mmmlmImmmmmmm l~D~d 0 (;: L (:) ~ 661: - A ri ~,: - 61: ,IS Tape Verification bisti~q ,chlumberger Alaska Computinq Center 07:00 PAGE: DEPT. 4000.000 RA.~O G~.MwD 83,282 DEPT. 3500.000 GP.MwD 74.205 DEPT. 3190 O00 RA,~t%.~O GP.~wD 46~103 3.355 4.114 3.195 3.754 -099.250 RP.~!~i) -999.~50 ROP,MWD ROP.~WD ROP.MWD 264,816 264.153 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT SERVICE : FLIC VERSION : OOlAO7 DAT~ : 92/11/19 MAX REC SIZE : !024 ~AST FIL~ FIL~ NAME : EDIT ,002 SERVICE : VERSION : O01A07 DATE : 92/11/19 ~AX REC SIZE : FIL~ TYPE : LAST FILE FILE HEADER FILE NUMBER RAW Curves and loq ~eader data ior eac~ bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCRE~E!~T: 0,5000 # VENDOR TOOL CODE START DEPTH 3712'0 $ LOG HEADE~ DATA DATE LOGGED: SOFTWARE SURFACE SOFT~APE VERSION: DOWNHOLE SOFTWARE VERSIOn: STOP DEPTH 7947.0 lO-JUb-g~ FAST 2,30 V4,0 IS Tape VerifJ~cation Listinq Chlt~mberqer Alaska Com!:)utip~q Center PAGE: DATA TYPE (~E~Y DP TD DRILLER TD LOGGER(FT): TOP bOG !I~TE~V~L (FT): RO~TO~ LOG INT~RV4L (FT): BIT ROTATIO~Ab SDEE~ HOLE I~CbI~ATIO~ (PEG) MAXI,,~U~ A~GLE: TOOL STRING (TOP TO VENODR TO{Lb CODE TOOL TY~E IVITY $ BOREHDLE AND CAST:lO DATA OPEN HOLE BIT S!%E (IN): DRILLERS CASIMG DEPTH BOREHOI, E C©NDITIOi~$ ~UD TYPE: ~UD DENSITY MUD VISCOSITY ~P PH: MUD C~LORIDES FLUID LOSS !4AXIMU~ ~ECORDED TEMPERATURE RESISTIVITY(OHMS) AT TEmPErATURE (DECF): ~UD AT ~EISU~ED TEMPERaTUrE MUD AT ~LX CIPCUL~IN~ MUD FILTRATE AT ~UD CAKL~ AT ~EUTRON TOOL MATRIX~ MATRIX DENSITY: ~OLE CO~RECT!O~t (IN): TOOL STAMDOFF~ (IN): ~WR FREQUENCY (HZ): PM~LRKS: LWD ~[,i~ 001 3~1~' TO 7947' CDR RO~ TO BIT 68.9'. ~ES TO ~IT 65o~' G R T{] BIT 76.~- ' H~bE CORRECTIO~'~:,'~ BIT SIZE LIS FORMAT DATA 7947.0 7947.0 3212.a 7947. o TnOL qU~BER 5o0 10,30 ~40.0 2.820 ~,~60 2.65 8.500 76.0 76.0 EgL'ggi~ ~0g'99i t69'g6 O'~q'3dOH 0~'666- Oi~'i'Sgd L99'C 4i~q'8~¥ vO0°O00£ 0~°666' ** ~%¥~ ** ~ ~ t 0 O0 O0 8~ Id 9 O~q ~D 0000000000 89 ~ t I g 0 O0 000 O0 ~68~S ~/~ O~q ~dO~ 0000000000 89 ~ ~ I g 0 O0 000 O0 8~68~ ~HO ~i~q 8Sd 0000000000 89 ~ I ~ g 0 O0 000 O0 8~68~S WNHO O~q ~V 0000000000 89 ~ I ~ ~ 0 O0 000 O0 B568~S ~ £d2~ m~mmmmmmmmmmmmmmmmmmmmmmmm#mmm '[ 99 0 [ 99 9I 89 99 0 99 &d 99 6 5'0 89 8 [£ 9 99 ; 99 o~ EL 0 99 0 99 mimmmmmmmmmmmmmmmmmmmmmmmmmmmI ** 8MP9 - 3dA£ £1~S ** 00: LO DIq~ : NIDISO }gOi : 2ZlS 33a X~ /O~IO0 : NOI~M3A 0fg'666- Ogq'gdO~ 0~g'666' daq'Mgd LO~'6gg L60'6t[ B6B'~ SLO'LL Oia"l'a£~ OOO'O00~ LOL'[b a~q'~iv 000'oo~ ~90'6I! 6~£'~iI d~q'dD Oo:L('~ 866I-Ai]i:i-61
