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Home My WebLink About198-240MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-305 KUPARUK RIV U TARN 2L-305 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2L-305 50-103-20279-00-00 198-240-0 W SPT 5244 1982400 3900 1890 1900 1890 1890 200 350 350 350 REQVAR P Josh Hunt 8/6/2024 2-Year MIT- IA Required by AIO 16.002 Required test pressure to pass is the max anticipated injection pressure of 3900 psi 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 U TARN 2L-305 Inspection Date: Tubing OA Packer Depth 520 4210 4085 4080IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806164346 BBL Pumped:3.4 BBL Returned:3.1 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 À 9 999 9 9 99 9 9 9 2-Year MIT- IA AIO 16.002 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:22:18 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF2 Subject:2L-305 Surface casing leak detect 10-426 form from 8-13-24 Date:Sunday, August 18, 2024 11:40:03 AM Attachments:image001.png SCLD KRU 2L-305 08-13-24.xlsx Please see the attached 10-426 form from the surface casing leak detect from 8-13-24. If you have any questions or concerns, please let me know. Thanks, Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58/ 37' 0,75HSRUWLVWKHLQFRUUHFWIRUPIRUGRFXPHQWLQJDVXUIDFHFDVLQJOHDN GHWHFWWHVW-5HJJ Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982400 Type Inj W Tubing Type Test P Packer TVD 5244 BBL Pump IA Interval O Test psi 1200 BBL Return OA 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 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 / 2L Pad Waived Beck/Borge 08/13/24 Notes:Surface casing leak detect per AIO 16.022. Witness waived by Adam Earl. SCLD passed per the 1000' OA fluid level criteria. 2L-305 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)20245-0813_MIT_KRU_2L-305_SCLD &3$,DFFHSWDQFHFULWHULD-5HJJ MEU SCLD passed per the 1000' OA fluid level criteria &3$,DFFHSWDQFHFULWHULD-5HJJ 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Tuesday, August 30, 2022 11:12 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Earhart, Will C Subject:Emailing: SCLD KRU 2N-306 8-28-22.xlsx, SCLD KRU 2L-310 08-25-22.xlsx, SCLD KRU 2L-305 08-26-22.xlsx, SCLD KRU 2L-319 08-27-22.xlsx, SCLD KRU 2N-337C 08-29-22.xlsx Attachments:SCLD KRU 2N-306 8-28-22.xlsx; SCLD KRU 2L-310 08-25-22.xlsx; SCLD KRU 2L-305 08-26-22.xlsx; SCLD KRU 2L-319 08-27-22.xlsx; SCLD KRU 2N-337C 08-29-22.xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. All Attached are the 10 426 forms for the SCLD that are required for each wells associated administrative approval. Due to the fact that the surface casing leak detects are performed with a gas media there are no "bbls pumped" nor "bbls returned". CPAI's surface casing leak detects have two passing criteria; pass according to the MIT OA criteria to 1200 psi or if the OA fluid level depresses below 1000' without maintain MIT criteria. The wells that passed with MIT criteria will have the numbers input into the "Pressures" boxes as a UIC compliance MIT would. If the OA fluid level depressed below 1000' without meeting the MIT criteria the notation of a passing test is placed in the "Notes" portion of the 10 426. Since this is the first submittal of these types of tests if there is additional information in which you believe to be beneficial or you would rather have these test reported in a different manner please feel free to reach out to discuss. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265 6218 Cell phone: (907) 830 9777 Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982400 Type Inj N Tubing Type Test O Packer TVD 5244 BBL Pump IA Interval O Test psi 1200 BBL Return OA 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 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Surface casing leak detect per AIO 16.022. Witness waived by Lou Laubenstein. SCLD passed per the 1000' OA fluid level criteria. Notes: 2L-305 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2L Pad Waived Miller 08/26/22 Form 10-426 (Revised 01/2017)2022-0826_MIT_KRU_2L-305_OAFL AIO 16.022. passed per the 1000' OA fluid level criteria. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-305 KUPARUK RIV U TARN 2L-305 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-305 50-103-20279-00-00 198-240-0 G SPT 5244 1982400 3900 3500 3500 3500 3500 160 350 350 340 REQVAR P Austin McLeod 8/3/2022 Two year MITIA to MAIP. AIO 16.002 amended allowing GINJ with TxIA 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 U TARN 2L-305 Inspection Date: Tubing OA Packer Depth 1190 4200 4100 4070IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804183944 BBL Pumped:3.5 BBL Returned:3.5 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 Two year MITIA AIO 16.002 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:26:43 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214- 121) 30 day monitor period for diagnostic testing. Date:Wednesday, August 3, 2022 11:10:18 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-306.pdf AnnComm Surveillance TIO for 2L-319.pdf AnnComm Surveillance TIO for 2L-305.pdf AnnComm Surveillance TIO for 2N-337C.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, May 27, 2022 7:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) 30 day monitor period for diagnostic testing. Chris- CPAI has identified four Tarn injectors 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) that were previously waivered for water injection only due to known TxIA while on gas injection. During a recent reservoir evaluation, these 4 wells were identified to have a significant production benefit from the ability to inject MI. CPAI has developed criteria under which it believes a gas injection well may operate safely with TxIA communication. That criterion includes the well having casing rated high enough to support maximum anticipated injection pressure of gas injection should a barrier fail, passing a MITIA to maximum anticipated injection pressure of gas injection, passing a MITOA or SCLD, and passing an IA DDT on water or gas injection and during gas injection service the IA pressure must sustain below the “do not exceed” of 2400 psi. These wells meet the above criteria and CPAI has conducted diagnostic MIT-IAs and SCLDs all with passing results. The remaining criteria yet to be met is the ability to maintain IA pressure under DNE of 2400 psi while on gas injection. Therefore, CPAI intends to place 2L-305, 2L-319, 2N- 306 & 2N-337C into gas injection service for a 30 day monitor period. If the 30 day monitor period displays the ability of the IAs to sustain a pressure below the DNE, CPAI intends to apply for administrative approval for continued WAG injection with known TxIA communication while on gas injection. Attached are the current 90 day TIO plots and wellbore schematics. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.062 Top (ftKB)29.0 Set Depth (ftKB)108.0 Set Depth (TVD) …108.0 Wt/Len (l…62.58 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)7 5/8 ID (in)6.435 Top (ftKB)28.5 Set Depth (ftKB)2,667.2 Set Depth (TVD) …2,291.1 Wt/Len (l…45.50 GradeL-80 Top ThreadBTC-MODCasing DescriptionPRODUCTION 5.5"x3.5"OD (in)5 1/2 ID (in)4.950 Top (ftKB)25.3 Set Depth (ftKB)9,198.6 Set Depth (TVD) …5,656.1 Wt/Len (l…15.50 GradeL-80 Top ThreadLTC MODTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.992 Top (ftKB)23.4 Set Depth (ft…8,384.1 Set Depth (TVD) (…5,252.5 Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE8rdCompletion DetailsTop (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in)23.4 23.4 0.00 HANGER FMC GEN V TUBING HANGER 3.500 511.7 511.7 0.66 NIPPLE CAMCO 'DS' NIPPLE 2.875 8,257.0 5,186.5 58.53 SLEEVE BAKER CMU SLIDING SLEEVE w 2.813 CAMCO PROFILE (CLOSED 8/30/2000) 2.813 8,359.2 5,239.6 58.75 NIPPLE CAMCO 'D' NIPPLER 2.750 8,366.3 5,243.3 58.75 LOCATOR BAKER LOCATOR 2.985 8,367.1 5,243.7 58.75 SEAL ASSY BAKER SEAL ASSEMBLY w/15' SEALS 2.985 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 9,000.0 5,563.1 61.33 FISH FISH 1.85" ROLLER WHEEL LOST IN RATHOLE 6/4/2001 6/4/2001 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 8,526.0 8,534.0 5,326.0 5,330.1 S-8, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,548.0 8,556.0 5,337.3 5,341.4 S-7, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ, 60deg ph 8,586.0 8,604.0 5,356.7 5,365.8 S-5, S-3, 2L- 305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,648.0 8,688.0 5,388.2 5,408.4 T-2, 2L-305 12/22/1998 6.0 IPERF 2.5" HC, BH,60 DEG PH 8,690.0 8,700.0 5,409.4 5,414.5 T-2, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,712.0 8,722.0 5,420.5 5,425.5 T-1.5, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 5,283.5 3,535.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 12/6/1998 2 8,307.0 5,212.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 11/13/2004 Notes: General & Safety End Date Annotation 6/15/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/9/2012 NOTE: T x IA ON MI. WATER INJECTION ONLY. CommentSSSV: NIPPLE2L-305, 2/9/2015 10:51:29 AMVertical schematic (actual) PRODUCTION 5.5"x3.5"; 25.3- 9,198.6 FISH; 9,000.0 APERF; 8,712.0-8,722.0 APERF; 8,690.0-8,700.0 IPERF; 8,648.0-8,688.0 APERF; 8,586.0-8,604.0 APERF; 8,548.0-8,556.0 APERF; 8,526.0-8,534.0 SEAL ASSY; 8,367.1 LOCATOR; 8,366.3 NIPPLE; 8,359.2 GAS LIFT; 8,307.0 SLEEVE; 8,257.0 GAS LIFT; 5,283.5 SURFACE; 28.5-2,667.2 NIPPLE; 511.7 CONDUCTOR; 29.0-108.0HANGER; 23.4 AnnotationLast Tag: SLM Depth (ftKB)8,534.0 End Date8/30/2014 AnnotationRev Reason: ADD WAIVER NOTE Last Mod Byhipshkf End Date2/9/2015KUP INJ KB-Grd (ft)37.50 Rig Release Date12/6/1998AnnotationLast WO:End Date 2L-305H2S (ppm) Date...TDAct Btm (ftKB)9,210.0Well AttributesWellbore API/UWI501032027900 Field NameTARN PARTICIPATING AREA Wellbore StatusINJ Max Angle & MDIncl (°)65.77 MD (ftKB)4,469.95 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2L-305 (PTD #198-240)30 day monitor period for diagnostic testing. Date:Wednesday, July 6, 2022 8:23:10 AM Attachments:image001.png AnnComm Surveillance TIO for 2L-305.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, July 5, 2022 3:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240)30 day monitor period for diagnostic testing. Chris- Kuparuk Tarn injector 2L-305 (PTD #198-240) has completed the 30 day monitor period. The IA has shown stabilization below the DNE of 2400 psi while on gas injection and has now met all of the criteria in which CPAI requires to continue WAG injection with known tubing by inner annulus communication. It is CPAI’s intention to submit an application for continued WAG injection with known tubing by inner annulus communication. While the AA is in process the well will be left in gas injection service. Attached is the current 90 day TIO plot, bleed history and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Friday, May 27, 2022 7:50 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) 30 day monitor period for diagnostic testing. Chris- CPAI has identified four Tarn injectors 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) that were previously waivered for water injection only due to known TxIA while on gas injection. During a recent reservoir evaluation, these 4 wells were identified to have a significant production benefit from the ability to inject MI. CPAI has developed criteria under which it believes a gas injection well may operate safely with TxIA communication. That criterion includes the well having casing rated high enough to support maximum anticipated injection pressure of gas injection should a barrier fail, passing a MITIA to maximum anticipated injection pressure of gas injection, passing a MITOA or SCLD, and passing an IA DDT on water or gas injection and during gas injection service the IA pressure must sustain below the “do not exceed” of 2400 psi. These wells meet the above criteria and CPAI has conducted diagnostic MIT-IAs and SCLDs all with passing results. The remaining criteria yet to be met is the ability to maintain IA pressure under DNE of 2400 psi while on gas injection. Therefore, CPAI intends to place 2L-305, 2L-319, 2N- 306 & 2N-337C into gas injection service for a 30 day monitor period. If the 30 day monitor period displays the ability of the IAs to sustain a pressure below the DNE, CPAI intends to apply for administrative approval for continued WAG injection with known TxIA communication while on gas injection. Attached are the current 90 day TIO plots and wellbore schematics. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 2L-305 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-305 2022-04-28 76 911 835 OA 2L-305 2022-04-30 895 1 -894 OA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 8,534.0 8/30/2014 2L-305 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Welded a 9" Conductor extension 5/27/2022 2L-305 bsgreen Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.7 Set Depth (ftKB) 108.8 Set Depth (TVD) (ftK 108.7 Wt/Len (lb/ft) 62.58 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 75/8 ID (in) 6.44 Top (ftKB) 28.5 Set Depth (ftKB) 2,667.2 Set Depth (TVD) (ftK 2,291.1 Wt/Len (lb/ft) 45.50 Grade L-80 Top Connection BTC-MOD Casing Description PRODUCTION 5.5"x3.5" OD (in) 51/2 ID (in) 4.95 Top (ftKB) 25.3 Set Depth (ftKB) 9,198.6 Set Depth (TVD) (ftK 5,656.1 Wt/Len (lb/ft) 15.50 Grade L-80 Top Connection LTC MOD Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String Ma 31/2 ID (in) 2.99 Top (ftKB) 23.4 Set Depth (ftKB) 8,384.1 Set Depth (TVD) (ftK 5,252.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model 23.4 23.4 0.00 HANGER 3.500 8.000 511.7 511.7 0.66 NIPPLE 2.875 4.470 5,283.5 3,535.6 57.91 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 8,257.0 5,186.5 58.53 SLEEVE 2.813 4.500 8,307.0 5,212.6 58.70 GAS LIFT 2.900 4.725 CAMCO KBG-2-9 8,359.2 5,239.6 58.75 NIPPLE 2.750 4.470 8,366.3 5,243.3 58.75 LOCATOR 2.985 4.000 8,367.1 5,243.7 58.75 SEAL ASSY 2.985 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) Top Incl (°)Des Com Run Date ID (in) SN 9,000.0 5,563.1 61.33 FISH FISH 1.85" ROLLER WHEEL LOST IN RATHOLE 6/4/2001 6/4/2001 0.000 Mandrel Inserts : excludes pulled inserts St ati on N Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 5,283.5 3,535.6 57.91 1 GAS LIFT DMY INT 0.000 0.0 12/6/1998 2 8,307.0 5,212.6 58.70 1 GAS LIFT DMY INT 0.000 0.0 11/13/2004 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 8,526.0 8,534.0 5,326.0 5,330.1 S-8, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,548.0 8,556.0 5,337.3 5,341.4 S-7, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ, 60deg ph 8,586.0 8,604.0 5,356.7 5,365.8 S-5, S-3, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,648.0 8,688.0 5,388.2 5,408.4 T-2, 2L-305 12/22/1998 6.0 IPERF 2.5" HC, BH,60 DEG PH 8,690.0 8,700.0 5,409.4 5,414.5 T-2, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph 8,712.0 8,722.0 5,420.5 5,425.5 T-1.5, 2L-305 6/7/2005 6.0 APERF 2.5"HSD PJ/2506 PJ,60deg ph Notes: General & Safety End Date Annotation 5/22/2022 NOTE: Welded a 9" Conductor extesnion 1/9/2012 NOTE: TxIAONMI. WATER INJECTION ONLY. 6/15/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 2L-305, 5/27/2022 4:25:02 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5"; 25.3-9,198.6 CASING SHOE; 9,196.7-9,198.6 FLOAT COLLAR; 9,102.3-9,103.4 FISH; 9,000.0 APERF; 8,712.0-8,722.0 APERF; 8,690.0-8,700.0 IPERF; 8,648.0-8,688.0 APERF; 8,586.0-8,604.0 APERF; 8,548.0-8,556.0 APERF; 8,526.0-8,534.0 PROD CASING XO; 8,388.4-8,389.1 PROD CASING CSR; 8,369.1-8,388.4 SEAL ASSY; 8,367.1 LOCATOR; 8,366.3 NIPPLE; 8,359.2 GAS LIFT; 8,307.0 SLEEVE; 8,257.0 GAS LIFT; 5,283.5 SURFACE; 28.5-2,667.2 CASING SHOE; 2,665.7-2,667.2 FLOAT COLLAR; 2,581.2-2,582.6 NIPPLE; 511.7 CONDUCTOR; 29.7-108.7 CASING HANGER; 28.5-31.2 CASING HANGER; 25.3-28.3 HANGER; 23.4 KUP INJ KB-Grd (ft) 37.50 RR Date 12/6/1998 Other Elevatio 2L-305 ... TD Act Btm (ftKB) 9,210.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032027900 Wellbore Status INJ Max Angle & MD Incl (°) 65.77 MD (ftKB) 4,469.95 WELLNAME WELLBORE2L-305 Annotation Last WO: End DateH2S (ppm) DateComment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y Samantha Carlisle at 7:54 am, May 02, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ ; ; 97/ '65 3KRWR GRFXPHQW EHIRUH DQG DIWHU '/% GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.03 09:19:02 -08'00' RBDMS SJC 050422 32%2; $1&+25$*($/$6.$ 0D\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 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WATER INJECTION ONLY. &RPPHQW SSSV: NIPPLE/$0 9HUWLFDOVFKHPDWLFDFWXDO 352'8&7,21[ ),6+ $3(5) $3(5) ,3(5) $3(5) $3(5) $3(5) 6($/$66< /2&$725 1,33/( *$6/,)7 6/((9( *$6/,)7 685)$&( 1,33/( &21'8&725 +$1*(5 $QQRWDWLRQ Last Tag: SLM 'HSWKIW.% 8,534.0 (QG'DWH 8/30/2014 $QQRWDWLRQ Rev Reason: ADD WAIVER NOTE /DVW0RG%\ hipshkf (QG'DWH 2/9/2015 .83,1- .%*UGIW 37.50 5LJ5HOHDVH'DWH 12/6/1998 $QQRWDWLRQ Last WO: (QG'DWH / +6SSP 'DWH 7' $FW%WPIW.% 9,210.0 :HOO$WWULEXWHV :HOOERUH$3,8:, 501032027900 )LHOG1DPH TARN PARTICIPATING AREA :HOOERUH6WDWXV INJ 0D[$QJOH 0' ,QFO 65.77 0'IW.% 4,469.95 MEMORANDUM TO: Jim Regg-T P.I. Supervisor I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 12, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2L-305 KUPARUK RIV U TARN 2L-305 Src: Inspector Reviewed By: P.I. Supry T Comm Well Name KUPARUK RIV U TARN 2L-305 API Well Number 50-103-20279-00-00 Inspector Name: Lou Laubenstein Permit Number: 198-240-0 Inspection Date: 8/3/2020 Insp Num: mitLOL200804104316 Rel Insp Num: Wednesday, August 12, 2020 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 21-305 Type Inj W ' TVD 5244 Tubing 1900 1900 1900- 1900 1982400 PTDsl Type Test, SPT'iTest psi �� 3000 - - ]A 650 2 — - 33320 3240 3230 BBL Pumped: 23 BBL Returned: z.z 0A_t400 - 400 400 400 - Interval RF.QVAR P/F P Notes: MIT -IA to maximum anticipated injection pressure per ATO 16.002 Wednesday, August 12, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ij�4((-7DATE: Friday,April 21,2017 1 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-305 FROM: Lou Grimaldi KUPARUK RIV U TARN 2L-305 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name KUPARUK RIV U TARN 2L-305 API Well Number 50-103-20279-00-00 Inspector Name: Lou Grimaldi Permit Number: 198-240-0 Inspection Date: 2/14/2017 Insp Num: mitLG170214130851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2L-305 - !Type Inj W 'TVD 5244 Tubing 1900 1900 - 1900- 1900 - PTD 1982400 • Type Test SPT Test psi 1500 IA 660 3300 . 3210 3190 BBL Pumped: 2.1 BBL Returned: 2 - OA I 425 450 450 - 450 Interval Required by Variance P/F Pass Notes: Test required by A1016.002.All required paperwork supplied on location.Good test. SCANNED AUG 1 52017 Friday,April 21,2017 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg1 f J�r� DATE: Monday,January 25,2016 P.I.Supervisor "( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-305 FROM: Johnnie Hill KUPARUK RIV U TARN 2L-305 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.61(2--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-305 API Well Number 50-103-20279-00-00 Inspector Name: Johnnie Hill Permit Number: 198-240-0 Inspection Date: 1/19/2016 Insp Num: mitJWH160121151332 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2L-305 Type Inj W` TVD 5244 - Tubing 1975- 1980 . 1980 _ 1980 - PTD 1982400 - Type Test SPT Test psi 3000 - IA 650 3300 - 3210 - 3210 - Interval REQVAR P/F P ✓ OA 450 - 450 450 450 Notes• MITIA per AIO 16.002 to max anticipated inject psi 2.2 bbls diesel used SCANNED , :w; Monday,January 25,2016 Page 1 of 1 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. /?~/--2Li~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, NoFrype OVERSIZED Logs of various kinds Other COMMENTS: Scanned by~ildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • • ConocoPhillips RECEIVED Alaska U C 0 9 2012) P.O. BOX 100360 AOGCC ANCHORAGE, ALASKA 99510 -0360 October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue Suite 100 i° � (; - Anchorage, AK 99501 i — c Commissioner Dan Seamount: p2 1..,..`- 305- 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 in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.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, "rd 1/// Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,1F,2F,2L,2T,22,3G,31 & 3M 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 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 75" 1.30 18" 9/19/2012 19 9/27/2012 Z - ---.. 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 _ 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 13, 2012 TO: Jim Regg �� Z1 i / v P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L -305 FROM: John Crisp KUPARUK RIV U TARN 2L -305 Petroleum Inspector Src: Inspector Reviewed P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV U TARN 2L - 305 API Well Number: 50 103 - 20279 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr120124095227 Permit Number: 198 - 240 - Inspection Date: 1/21/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L-305 Type Inj. W ' TVD 5244 IA 1125 3330 - 3287 3282 - P.T.D 1982400 'TypeTest SPT Test psi 3000 OA 375 375 375 375 - Interval REQVAR P/F P Tubing 1700 1700 1700 1700 Notes: 2.1 bbls pumped for test. MITIA as per AIO 16.002 � & DFEB1C I Monday, February 13, 2012 Page 1 of 1 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 26, 2012 TO: Jim Regg K� II 1/ f v P.I. Supervisor SUBJECT: Mechanical Integrity Tests �� CONOCOPHILLIPS ALASKA INC 2L -305 FROM: John Crisp KUPARUK RIV U TARN 2L -305 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J5 . NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV U TARN 2L - 305 API Well Number: 50 103 - 20279 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr120124095227 Permit Number: 198 - 240 - Inspection Date: 1/21/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L -305 , Type Inj. W TVD 5244 - IA 1125 3330 3287 3282 P.T.D 1982400 ' TypeTest SPT Test psi 1500 ' OA 375 375 375 375 Interval REQVAR p/F P ' Tubing 1 1700 1700 1700 1700 Notes: 2.1 bbls pumped for test. MITIA as per AIO 16.002 . fliAINEPFEE 0 5 'LUIZ Thursday, January 26, 2012 Page 1 of 1 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, September 16, 2011 3:34 PM To: 'NSK Problem Well Supv' Cc: Brooks, Phoebe L (DOA) Subject: FW: 2L -305 (PTD 198 -240) Request to bring on water injection 09 -16 -11 Attachments: MIT KRU 2L -305 08- 16- 11.xls Kelly, The MIT looks good and is sufficient for you to bring the well back on for evaluation. It is correct to keep the well on the monthly report. It will be interesting to follow how the IA responds with the well back in service. I would hope that the pressure declines, but you are ready to apply for an AA if needed. Please keep us informed as the diagnostics proceed. Tom Maunder, PE f'3W C r 1 4. 20'1 AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Friday, September 16, 2011 3:12 PM To: Maunder, Thomas E (DOA) Subject: RE: 2L -305 (PTD 198 -240) Request to bring on water injection 09 -16 -11 Tom, Thanks for responding so quickly. No the MITIA was not submitted since it was not a witnessed event. I've used our witnessed form and attached it to this email to report the pressures during the test. As to gas being in the well, when DHD went out to test the well on 8 -16, the IA fluid level was at surface. Yes the drawdown spike occurred on the day of the test and it gradually built back up over the next couple of weeks. Kelly From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, September 16, 2011 2:12 PM To: NSK Problem Well Supv Subject: RE: 2L -305 (PTD 198 -240) Request to bring on water injection 09 -16 -11 Hi Kelly, Have you submitted the MITIA. Also, is there gas present in the IA? The pressure does decline through the period reported, however it is still near 2000 psi. I presume the drawdown spike was during the diagnostics. I look forward to your reply. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Friday, September 16, 2011 1:06 PM To: Maunder, Thomas E (DOA) Subject: 2L -305 (PTD 198 -240) Request to bring on water injection 09 -16 -11 Tom, ConocoPhillips requests permission to bring injector 2L -305 (PTD 198 -240) back on water only injection. We shut 9/16/2011 Page 2 of 2 • the well in on 6- 18 -11, after noticing TxIA while it was injecting MI and has been off -line since then. On 8- 16 -11, we performed diagnostics and all tests passed: MITIA to 3500 psi, IA DDT, tubing POTs (positive and negative). We would like to return the well to water injection and observe the well for an extended period of time to look for signs of the communication previously seen (while it was on gas) and depending on the results, perform more diagnostic work. It is our intention to apply for an administrative approval for water only service after the diagnostic period. 2L -305 will remain on the monthly failed report. Attached is a 90 day plot. Please call if there are any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 9/16/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg ©alaska.gov; phoebe.brooks@alaskagov; tom.maunder &alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2L DATE: 08/16/11 OPERATOR REP: Colee / Phillips AOGCC REP: No state representative present Packer Depth Pretest Initial 15 Min. 30 Min. Well 2L -305 Type Inj. I N TVD 5,244' Tubing 2,300 2,350 2,350 2,350 Interval 0 P.T.D. 1982400 Type test P Test psi 1500 Casing 1,925 3,500 3,440 3,440 P/F P Notes: Ann comm evaluation 125bbas diesel OA 250 300 300 300 P.T.O. I Type test 1 I Test Pte! Casing Interval P/F Notes: OA P.T.D._ Type test Interval I Test psi P/F Notes: OA P.T.D. Type t 1 Test psil Casing Interval P/F Notes: OA Well Type Inj.1 ( TVD Tubing Interval P.T.D. Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Cases D = Drilling Waste M = Annulus Monitoring 1= Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2L -305 08- 16- 11.xis Well Name 2L -305 Notes: TxIA while an MI Malt Date 6/18.2011 Days 90 End Date 9/16:2011 Annular Communication Surveillance 4000 - WHP ._.. - 180 IAP OAP it : a AMIIII IMMAIIL f — _ - 160 3500 - WHT V v V - 140 I L iri VA 3000 - 120 2500 vo e-- -�- ° .-�_ 2000 - 80 1500 - 60 1 aoo V------ - 40 Ill 500 - 20 0 0 Jun -11 Jul -11 Aug -11 Sep -11 Oct -11 Dial rv1 +a1 PWI SWI °° —BLPD d, i 000 200 100 0 + Jun -11 Jul -11 Aug -11 Sep -11 Oct -11 Date Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, July 26, 2011 5:13 PM To: Maunder, Thomas E (DOA) Subject: RE: 2L -305 (PTO # 198 -240) Suspect T x IA. Tom, There have been no developments thus far. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska. Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, July 26, 2011 11:02 AM To: NSK Problem Well Supv Subject: RE: 2L -305 (PTD # 198 -240) Suspect T x LA. Hi Kelly, Any news on this "problem child "? Tom From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Monday, June 20, 2011 12:28 PM o: Maunder, Thomas E (DOA) •i ect: RE: 2L -305 (PTD # 198 -240) Suspect T x IA. Tom, Diagnostics that • I follow will include T -POT's an MIT -IA and an IA -DDT. We will update you with results Ian Ives Problem Well Supervisor DHD Lead Technician AES Central Shops Phone (907) 659-7224 Pager 909 r. From: Maunder, Thomas E (DOA) [mailto:tom.maun. - walaska.gov] . a "' J 11 p 11 i Lk) 41 Sent: Monday, June 20, 2011 12:04 PM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: 2L -305 (PTD # 198 -240) Suspect T x IA. Ian, What sort of diagnostics are planned? Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, June 18, 2011 2:02 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: 2L -305 (PTD # 198 -240) Suspect T x IA. Tom, Jim, Guy, Kuparuk WAG injector 2L -305 (PTD # 198 -240) is suspected of having T x IA communication while on MI due to the need for = =nt frequent bleeds. The well had been SI on 02/13/2011 for rig operations and then returned to MI service on 04/26/2011. The well has been SI and added to the monthly report. Diagnostics follow. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Ian Ives Problem Well Supervisor DHD Lead Technician AES Central Shops Phone' (907)659 -7224 Pager: 909 7/27/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, July 25, 2011 9:07 AM To: Maunder, Thomas E (DOA); NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Tom, We have added 2L -305, 3F -04, and 3K -11. 3H -09 was removed because it was getting a RWO. I will be sending in a cancellation notice or 3H -09 in the coming days. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, July 25, 2011 8:46 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: RE: June 2011 monthly failed MIT report 07 -24 -11 Hi Kelly, I am just starting to review the document. Can you provide a list of any wells added or removed? That helps focusing my review. Thanks, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, July 24, 2011 8:33 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Subject: June 2011 monthly failed MIT report 07 -24 -11 All, Attached is the monthly failed MIT report for the month of June 2011. Please call if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 7/26/2011 • • ConocoPhillips Well 2L -305 Injection Data • Water Injection • Gas Injection 4000 3500 48..,4 ,,.• a• 3000 °' 2500 cii a a 2000 E 1500 1000 y O 500 0 I 0 500 1000 1500 2000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 30- Jun -11 0 0 2626 2190 273 29- Jun -11 0 0 2490 2195 274 28- Jun -11 0 0 2569 2157 274 27- Jun -11 0 0 2872 2079 274 26- Jun -11 0 0 2758 1985 274 25- Jun -11 0 0 2757 1878 273 24- Jun -11 0 0 2594 1758 274 23- Jun -11 0 0 2609 1 625 275 1 22- Jun -11 0 0 2657 1480 276 21- Jun -11 0 0 2654 1340 280 20- Jun -11 0 0 2617 1260 289 19- Jun -11 0 0 2967 1675 343 18- Jun -11 0 1404 3220 1719 369 17- Jun -11 0 1451 3237 1451 373 16- Jun -11 0 1408 3232 2121 368 15- Jun -11 0 1514 3234 1741 366 14- Jun -11 0 1641 3235 2009 365 13- Jun -11 0 1656 3218 1911 364 12- Jun -11 0 1581 3231 1921 367 11- Jun -11 0 1617 3217 1884 366 10- Jun -11 0 1615 3211 1838 364 9- Jun -11 0 1553 3203 1822 364 8- Jun -11 0 1625 3198 1666 349 7- Jun -11 0 1623 3183 1728 358 6- Jun -11 0 1447 3173 1813 368 5- Jun -11 0 1498 3170 1800 370 4- Jun -11 0 1520 3163 1780 371 • ConocoPhillips Well 2L -305 Injection Data • Tbg Psi IA Psi • OA Psi l 4000 3500 - 3000 ' • 000 y • 2500 - �~« •• 0- de a 2000 eiell • mr • ~ i 1500 - • • 1000 - • 500 - • ■ .2"M► 0 03/11 04/11 05/11 06/11 07/11 Date J PTD# 198 -240 TxIA communication while on MI Well shut in since 6/18/11 • • From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Monday, June 20, 2011 12:28 PM To: Maunder, Thomas E (DOA) Subject: RE: 2L -305 (PTD # 198 -240) Suspect T x IA. Tom, Diagnostics that will follow will include T -POT's an MIT -IA and an IA -DDT. We will update you with results. Ian Ives Problem Well Supervisor DHD Lead Technician AES Central Shops Phone: (907) 659 -7224 Pager: 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, June 20, 2011 12:04 PM To: NSK Problem Well Supv Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: 2L -305 (PTD # 198 -240) Suspect T x IA. Ian, What sort of diagnostics are planned? Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, June 18, 2011 2:02 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: 2L -305 (PTD # 198 -240) Suspect T x IA. Tom, Jim, Guy, Kuparuk WAG injector 2L -305 (PTD # 198 -240) is suspected of having T x IA communication while on MI due to the need for recent frequent bleeds. The well had been SI on 02/13/2011 for rig operations and then returned to MI service on 04/26/2011. The well has been SI and added to the monthly report. Diagnostics will follow. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Ian Ives Problem Well Supervisor DHD Lead Technician AES Central Shops • MEMORANDUM To: JimRegg ~~~. ~j13~~p P.I. Supervisor FROM: BOb NOble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-305 KUPARUK RIV U TARN 2L-305 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv .~ ~°-- Comm Well Name: KUPARUK RN U TARN 2L-305 API Well Number: 50-103-20279-00-00 Insp Num: mitRCN100809164306 Permit Number: 198-240-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L-305 (Type Inj. ~ TVD 5244 IA 2390 3230 3200 3200 ~ P.T.D ]982400 ~ TypeTest SPT Test psi 3230 QA 325 340 330 330 Interval4xRTST p~ P ~ Tubing 3740 3740 3740 3740 Notes: ~~1i ~ ~-~'~, 'cl ~'S}- i s~~s; ~.~:~ .~ ~ . ~~ ; I ; I_~~ Tuesday, August 10, 2010 Page 1 of 1 r~ ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 2L DATE: 08/08/10 OPERATOR REP: Colee /Coleman - AES AOGCC REP: Robert Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 2L-305 Type Inj. G TVD 5,244' Tubing 3,740 3,740 3,740 3,740 Interval 4 P.T.D. 1982400 Type test P Test psi 1500 Casing 2,390 3,230 3,200 3,200 P/F P Notes: OA 325 340 330 330 Well 2L-317A Type Inj. W TVD 5,350' Tubing 1,100 1,100 1,100 1,100 Interval 4 P.T.D. 2002100 Type test P Test psi 1500 Casing 850 1,830 1,780 1,770 P/F P Notes: OA 250 375 375 375 Well 2L-319 Type Inj. W TVD 5,225' Tubing 1,300 1,300 1,300 1,300 Interval 4 P.T.D. 2071120 Type test P Test psi 1500 Casing 230 2,150 2,080 2,060 P/F P Notes: OA 361 482 458 457 Well 2L-323 Type Inj. W TVD 5,237' Tubing 2,100 2,100 2,100 2,100 Interval 4 P.T.D. 1982510 Type test P Test psi 1500 Casing 800 2,800 2,750 2,740 P/F P Notes: OA 400 525 500 500 Well 2L-329A Type Inj. N TVD 4,899' Tubing 1,500 1,500 1,500 150 Interval 4 P.T.D. 1982250 Type test P Test psi 1500 Casing 520 2,270 2,200 2,200 P/F P Notes: OA 900 900 900 900 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing - Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes r~ I ~ - P`a ~ ~~ 1~7 ~ .dS ~ L~~~ac:..q ~'. .i ~:, - D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test ,~-~(~-~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2L Pad 08-08-10.x1s . . ~ ConocoPhillips Alaska RECEIVED AUG 2 9 2007 A/aska Oi/ & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 20,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tlt Avenue, Suite 100 Anchorage, AK 99501 5CANNED SEP \,\l?(~ () {1 2007 Dear Mr. Maunder: Enclosedplease 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 còÍÏductor. These voids were filled with a 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 corrosion inhibitor/sealant was pumped between August 12-13,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ft~~¿ M.J. oveland 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 8/13/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal 2L-305 198-240 SF N/A N/A N/A 1.7 8/13/2007 2L-307 198-256 10" N/A N/A N/A 8 8/13/2007 2L-311 203-155 15" N/A N/A N/A 9 8/13/2007 2L-313 198-219 15" N/A N/A N/A 5.9 8/12/2007 2L-315 198-218 23" N/A N/A N/A 5.9 8/12/2007 2L-317 200-210 SF N/A N/A N/A 4.2 8/12/2007 2L-323 198-251 9" N/A N/A N/A 3.4 8/12/2007 2l-325 198-209 24" N/A N/A N/A 9.3 8/12/2007 2L-327 207-008 20" N/A ..' . N/A N/A 6.8 8/12/2007 2L-329 198-225 24" N/A N/A N/A 6.8 8/12/2007 Œ 04/05/07 SlbliUßI~e1'18P RECEIVED NO. 4205 Schlumberger -DCS 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 ~ 011 & Gas Cons. Commission Anc~ Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 SCANNED APR 1 0 2007 UIC..- 1C\~-d% Field: Kuparuk Well Log Description BL CD Color Job# Date 2M,12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02' 11638845 GLS 03/21/07 1 2W-OS 11632686 SHUT IN BHP . 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-33t N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -:, V ,.., c'/ ''-"Ì ~[ ';--."'17 v, I Lr0,,,"' DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-305 KUPARUK RIV U TARN 2L-305 ~o \qli5-')) FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 37512- Comm NON-CONFIDENTIAL Permit Number: 198-240-0 Inspector Name: Chuck Scheve Inspection Date: 8/8/2006 Well Name: KUPARUK RIV U TARN 2L-305 Insp Num: mÎtCS060808193323 Rei Insp Num API Well Number 50-103-20279-00-00 Packer Depth ~Well I 2L-305 ¡Type Inj. I G i TVD i 5244 I 'I P.T. i 1982400 ITYP~Test! SPT ¡ Test psi '!J5oo Interval 4YRTST P/F P ;// Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ! IA i OA 1800 3020 I J 2990 2990 300 300 -~ 250 300 Tubing I 2950 '" I 2950 2950 2950 ---'-- -- Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity, SCANNeD AUG 2 4: 2006 Wednesday, August 09, 2006 Page 1 of I ) ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 June 21,2005 F~ r:: ("~ E f"~/r [-' ~") .... ¡!"....\,.,,'~ .". ~ '~: æ:: L. JUN 2 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Oii 8i Gems. Subject: Report of Sundry Well Operations for 2L-305 (APD # 198-240) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operation on the Kuparuk well 2L-305. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ;1. )4~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells SCANNEú ,JUL Ü ~1 2.Q05 MM/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2; Z005 REPORT OF SUNDRY WELL OPERA T!gN~~ .~~~. r"'-'T'-'~--f'~C'- Abandon D RepairWell D Plug Perforations D Stimulate D - .. ',- ~wl~r!!:'m]lr:W:; Ô"¡"·"""'·"~II<'I" Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extensio~ D Change Approved Program D Operat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 198-240/ 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-103-20279-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 146' 2L-305 1. Operations Performed: ) ) 8. Property Designation: ADL 380051, ALK 4599 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING PROD CASING Perforation depth: 10. Field/Pool(s): Kuparuk River Field / Tarn Oil Pool measured 9210' feet true vertical 5661' feet measured 8905' feet true vertical 5517' feet Length Size MD 108' 16" 108' 2521' 7-5/8" 2667' 8223' 5-1/2" 8369' 830' 3-1/2" 9199' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2290' 5245' 5656' Measured depth: 8526'-8534',8548'-8556',8586'-8604', 8648'-8688', 8690'-8700', 8712'·8722' true vertical depth: 5326'-5330',5337'-5341',5357'-5366', 5388'-5408', 5409'-5414', 5421'-5426' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8384' MD. Packers & SSSV (type & measured depth) no packer Cameo Nipple @ 511' 12. Stimulation or cement squeeze summary: RBDMS BFl JUN 2 2 2005 Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casinç¡ Pressure Tubinç¡ Pressure Prior to well operation n/a n/a 5200 Subsequent to operation n/a n/a 2200 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 P&A D Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney f{. !/æ~ Title Wells Group Team Leader / I Phone 907-263-4574 Date [Pll/lf) Ç" ¡i , . .' '. ' ': . ..JI '\ L Prepared bv Sharon Allsup-Drake 263-4612 U¡'\!'O¡¡\f\ Form 10-404 Revised 04/2004 Submit Original Only ) ) 2L-305 Well Events Summary Date Summary 06/02/05 CLEAN OUT TO 8904' CTMD THEN TAGGED UP HARD. CLEANED OUT USING GELLED DIESEL AND SLICK DIESEL. GOOD 1:1 RETURNS ALL DAY. BULLHEAD 15 BBLS OF DIESEL DOWN TUBING FOR FREEZE PROTECT AND LEAVE WELL SHUT- IN. [FCO] 06/06/05 TAGGED FILL & DRIFTED TBG W/12.25' OF 2.5" DUMMY GUN TO 8905' RKB [Tag] 06/07/05 RAN PERFORATING GUNS, 6 SPF/60 DEG, 2 1/2" HSD, PJ 2605. FOUR RUNS; 8712'- 8722', 8690'-8700', 8586'-8604', AND 8548'-8556' & 8526'-8534' (LAST TWO RAN TOGETHER). [Perf] NIP (511-512, 00:3,500) TUBING (0-8384, 00:3.500, 10:2,992) Gas Lift ldrel/Oummy Valve 1 (5283-5284, 00:4.725) PROO CASING (0-8369, 00:5,500, \I\Æ:23.00) SLEEVE-C (8257 -8258, 00:4,500) Gas Lift ldrellDummy Valve 2 (8307 -8308, 00:4.725) NIP (8359-8360, 00:4.470) SEAL (8367 -8368, 00:5,500) Perf (8648-8688) ') ConocoPhillips Ä.laska, Inc.. I I ~ 2L~05 ) KRU 2L-305 Well Type: INJ Angle ~ TS: deg ~ Orig Completion: 12/6/1998 Angle ~ TD: 62 deg ~ 9210 Last W/O: Rev Reason: Post FCO Tag, PERF Ref Log Date: Last Update: 6/14/2005 ID: 9210 ftKB Max Hole Angle: 66 deg ~ 4470 Size Top Bottom TVD Wt Grade Thread 16.000 0 108 108 62.58 H-40 WELDED 7.625 0 2667 2290 45.50 L-80 BTC-MOD 5.500 0 8369 5245 23.00 L-80 BTC-MOD 3.500 8369 9199 5656 9.30 L-80 EUE-8RD API: 501032027900 SSSV Type: NIPPLE Annular Fluid: DSUSW Reference Log: Last Tag: 8905 Last Tag Date: 6/6/2005 CasinQ String - ALL Description CONDUCTOR SURF CASING PROD CASING PROD CASING Tubing String - ALL Size I 3.500 Perforations Summary Interval TVD 8526 - 8534 5326 - 5330 Top o Bottom TVD 8384 5253 Zone Status Ft SPF Date Type Comment 8 6 6/7/2005 APERF 2.5"HSD PJl2506 PJ,60deg ph 6/7/2005 APERF 2.5"HSD PJl2506 PJ, 60deg ph 6/7/2005 APERF 2.5"HSD PJl2506 PJ,60deg ph 12/22/1998 IPERF 2.5" HC, BH,60 DEG PH 6/7/2005 APERF 2.5"HSD PJl2506 PJ,60deg ph 6/7/2005 APERF 2.5"HSD PJl2506 PJ,60deg ph 8548 - 8556 5337 - 5341 8 6 8586 - 8604 5357 - 5366 18 6 8648 - 8688 5388 - 5408 40 6 8690 - 8700 5409 - 5414 10 6 8712 - 8722 5421 - 5426 10 6 Gas Lift MandrelsValves St MD TVD Man Man Type Mfr 5283 3536 CAMCO KBG29 2 8307 5213 CAMCO KBG29 Other(pIÜQsleqÜip"ietc.)·~...JEWEI..RY Depth TVD Type 511 511 NIP 8257 5186 SLEEVE-C 8359 5240 NIP 8367 5244 SEAL Fish-FISH Depth I 9000 FISH Description V Mfr V Type VOD Latch Port TRO CAMCO DMY 1.0 INT 0.000 0 CAMCO DMY 1.0 INT 0.000 0 Description Date Run 12/6/1998 11/13/2004 Vlv Cmnt ID 2.870 2.813 2.750 2.985 CAMCO DS NIPPLE BAKER CMU SLIDING SLEEVE; closed 9/30/2000. CAMCO D NIPPLE BAKER 80-40 SEAL ASSY I Comment 1.85" ROLLER WHEEL LOST IN RATHOLE 6/4/2001 MEMORANDUM ') State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg "P¿¿. Iv",.,.Jb4 P.I. Supervisor J ~é{1 51 DATE: Thursday, December 09,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-305 KUPARUK RIV U TARN 2L-305 / q~-;Atf6 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. suprv:n5L Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2L-305 API Well Number: 50-103-20279-00-00 Insp Num: mitCS041206182905 Permit Number: 198-240-0 ReI Insp Num: Inspector Name: Chuck Scheve Inspection Date: 12/6/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L-305 Type Inj. G TVD 5244 IA 1100 2000 1960 1950 P.T. 1982400 TypeTest SPT Test psi 1311 OA 250 260 260 260 Interval INIT AL P/F P Tubing 2560 2560 2560 2560 Notes: Pretest pressures were observed and found stable. Well was recently converted ITom producer to injector' SCANNED DEC 2, 7 20 Thursday, December 09, 2004 Page 1 of 1 e . 11.,~2.ifD RECEI\/J:"f) DEC 0 7 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name: ConocoPhiflips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 146' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING PROD CASING Perforation depth: 5. ,PJrmit to Drill Number: 9f02¿ft70204 016 -~ 6. API Number: 50-103-20279-00 9. Well Name and Number: 2L-305 10. Field/Pool(s): Tam Oil Pool measured 9210' feet true vertical 5661' feet measured 9071' feet true vertical 6276' feet Length Size MD 108' 16" 108' 2521' 7-5/8" 2667' 8223' 5-1/2" 8369' 830' 3-1/2" 9199' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2291' 5245' 5656' Measured depth: 8648'·8688' true vertical depth: 5388'-5408' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8384' MD. f') IÌ Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 511' Form 10-404 Revised 04/2004 n n I·C. \~d l1, \ J ',' ~ ~_. ,,".' . RBDMS BFl DEC 0S7b?nnA '. I 0 I . u fflí'l bnglna n y · 2L-305 e DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11127120041Converted well from Oil Producer to Wag Injection service ~) ') .~~t~!=f ~::~~~«!Æ AI,A.SHA. OILA5D GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~,Çtt¡,..~Lþë Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Tarn 2L-305 Sundry Number: 304-456 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Commissioner . ~t)v . DATED this/Z 1 day of~r, 2004 Encl. SCANNED DEC 0 1 2004 ) PAGE 01/06 j-¡ilt~ 11/18/2004 17:06 9076597':'~1 NSK WELLS GROUP STATE OF ALASKA ¡ ALASKA Orl AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL , " ,20,AAC 25.280 . , ,: t' 'fy~é' :6' ~eqö~ät:, " A~~~,don 0','"'' ~~~'~¡'d' 0,' operation'ShutdOwn "p" ÞB~öraté' :'ÇJ, '" , ,'Wa¡"er ,', 0 , A~~~'ra~ DISP,'"O ,,' ",,' "':~~~~~-~k~I~~~'2:g,:":,:;;',:~t~~t':':g;,;,:.~:~~:.~~?::;.':'::g:::,::::~~\~,¡~;':,::~¿"~~!"~:;,~:g,:,;,':C.,',::;;~~t,ø: 2: Operator Name: ' " ' ",,, '4. CI)r1ent"\,vell ClasS:': ",' "',.... ..... '-.,,' , Š. përmit t~' D~iiiNu~ber:-" çonocoPhi,Uips AJa$~a, Inc, " 'è~\1ëlo~m:ÈI~~:~::, 0', ,:E~I'Ö~;~~,', Lb':,;;;;:,: ;~::,': .., . 198-240 - ~. Address: 'Stratjttt1iþhl~" ,:: 0",">" "',:$~~it:êí:';':'D!:": ;::~: ,,::~ 6. API Nurriber: P. '?~ BQX 100~60 ...... \' ", ,': '::..,:" ,:,'~',.'" ':;: '::"~'::'::"::'::~,\:,::,:,:':i';'::;.';:';:::::'~~':;'¡::,:;:,,/, ..::, ",,50- ~ 03-20?7~"OO 7, KS ElevatiQn (ft): 9. Well Name and Numbs"; RKB 1461 21.-305 e:'Property Designation: ' 1Ò, Fièld/Pool(s); ;::::~~::":'::K~~~~~~:~~i~~~~Y'~¡t . .. Tarn ,?" POQI 11":'" ,,,.., PÃESENT We'LL CONDITION SUMMARY 'Tòtal depth'MD {ft):'''' Tòtal Depth-TVD (ft): Effectlv~ tJepth MD (ft):' Effectlvê-Dšpth TVO (It): Plugs (mêasured)~' Junk (mess'urad): , 9210'.",,, 56611 ' ' :':,~:Øö!if, ,:,,':' ::" :;,;:: ":;',' ,,:'5.S~71 ,:.:' ,', ',:' :;/:'::::::,~:~'::: ,;:"::':': '::"~';'~;:\i:!,:,:::':' :'!::,:',:',:~;..:,,,,""::: :"':' ::,;:.:, ;::'i<~' ""i' i,;"': ':";: '" '::" """.:,!:: C~,SI~,~.." l..ength Sl~e' .. MD TVD Burst Collapse ~ONDUCT~R 108' 16" ..- 1 OS' .. ':':!'\:"I,:,~:',::,,:IçØ~ ':" '~::.. ,",:!", ","",,' , .sURF CASING 25211 7-S/ø." 2667_~. , , PROD CASING _,82231 S..1l?" 8369' ". PROD CASING _.8S01 3-1/2" . ,. 9199' ,:.." I' ,,1111 JILI\;:':' .::'. 2~9~ r :1:'::; ~~, I,,;:,.' ':",'::':,,:':, ',:',", ':::,,: ,,' : ~:,2:'c:.'::5\,,~~~:'C:<':'~" :~::,::,.,'::;",::';,::, c,:, ',,, C 'c:" ,C, ," 'C ',:::: ...., , '::":':::',;~': " : ,,,,',:,', ':säSSj ," ," ,,' " , ",", ,,',' :" ,,,'II" ': ",',,' " II' .1,1, . , ' . . ,,II .,; 1:"I~',:;~.t~:1 ','-',",',~,~,.JJ,II",I' '.""'1/ .I'IAI . . , '''>f ,,' II' .' ::'> :::' I';: :'.~' . ,11" ",1.1101,11,,11\ ,.,....J.LIt;'" : ': :: ;: ':,: ',:;: ::I~. ; :.'. . .~: II~; I;; ;; 11 III:' I,ll.: : :1 ,: ~:;I'" ',1':":," '~"II , _.4 F'erforation Depth MD (ft): ,a~ø.,:~~~~~~lll;::: : ," ::; ,;, ;;:::;:::' Packers and SSSV Typë': no packer $SS,!~NIP - ...., , ~SSV=511r.. '. .. - ,1:~~':,A.~,¡;tdh~~~~~; t>escrlptlon,SUffimaryo1'~r:~AA~är" ::[~l " . :": 13.' w~n ClâSs'äft~r P~,~~~~::work:',:"::,,;,:,,,: "" ':" ' :: <,: " , """."':" ' ','" '6ëtäiI~:d:::bp~r.atiòn~":PFo~ram, ",: ,::,,:0, :,,,. ,':,SOP iSk:~tCtî:'D'" '" , 'ExþlðratoŒ tJ :," '.' ,",',"'Dø.vèlóþir1~rit';' 0,: I,:' '::,:'::; ~ :':"::'~ërvjö~'...(21:'", :',: :c~~;~i;f~~~::;;;".':::;~."')i;.:!.,::,::'::,.:;,:1:~~:c,'..c',',"~,:- :'15?i~~II.'~~,a~~~p:O~f~"';".::,;:',"i,i~~~~;:DD"'~ :",d:":'~~~i.~q :::1.e~,~~~r-þa;I.'~p~~~~;', \I~,'~<l.~!,!!,tjate.l.\l"ì~J~):'1 ,,'.. WAG. 0,,, ,', :<: ' ',SIl\U:', [J, : ;.,,'. ,"":'WINj .',", ,:::.:' ,,' :"Wtj,SP.~i,' 0' , '.;\;,~,,~pìjj~¡~~~9um:I~,~p~~~h~t!y'~':'~I,,:IM-~t:\iU;~~::,,:,,,: ' "" ' -..,' ",.: . ',' :' :,' :';"";:I:";'::':':;">::::::::::':~:':"<'"'' ':':''':i,',;;:::~i;~;¡:;i;,,:,::> ", . ,,' :,': ,,:::~ic'\I:l::':'::::::': :,', '~? ~ :,T h~r~~y :ö~r1jfY.: th3.Hh:~ 'p'ør:$going;:is :ÙI~~ !~~~ çôrr.ë6Ú~{1~$ :bëst of my 'knoW,ls!:tge; " ":' : :" ,,:.': :;:, q9~mc~(;':' , ", ", : ;:" : i:.: ,~,atttss' :TÚ=tØØgii,,;s: !@: :eS~,~722$:; : ,',:' ""'''~~i~te. ~~~~~~~Ð~)lii,":C'I!~l'ii$efi' ""',"c"..c'. " , "" ""~-Iof' c:: """, c,.Piwd¿¿¡~.Ê~tÌ¡M.~;¡n."9ìt~¿hhicr~~" ,,' s¡g~_aturei::~ .../"t.J{MJ.f ¿' ',,,j~h(]r,1~d~~,9~~~~~:;, ',',,:i:,: ;:'.R~~é;,!.~I~/d)'~'i'''::'' ," ~~mmissio~"Use Only, :::i:,;:,', ",,':}:, :,1, ",:":,,, :. 'I "'" "..:~,::,::, :'~: '::~: ::: 'i:' 11',1'111''., " ¡, II...!.,. Perfor~t,i?~ D,epth TVD ,(ft): ~3f3:8',-54'08' " ' , "" "", ' . . .""" "" '¥1M.' . ," " '. .;;...:. ,..I. I, '~I"'_I. I. '" t ',I I', Pac-kers and SSSV MO (ft) Tubing Size: 3-1/211 Tubing Grede; L~8Q.. Tubing MD (tt)= 8384' Conditions of approval: Notify CommIssion $0 that a repre$entatlvg may witness Sundry Number= .~Lf-C¡Óh . Plug Integrity 0 SOP Tê$~ 0 MechanlcaJlntegrity Test ~ Location Clearance ~ Other: "'-Sl~c;.~ \-\ \.T shc~ \~ b ~ sch~ \áJ . ' í'~ 5U,bSeqUer¡t,For.m~~~ Y ¿," ApprQVed br.0y¡ /y Form 10-40~ Revised 12/2003 RBDMS BFL NOV 3 0 2004 De!e: j?/21jf.- COMMISSIONER EiV ORDER OF THI! COMMI~SION INSTRUURiCjit1 A L Submit In Duplicate 11/18/2004 17:06 907659T'~1 NSK WELLS GROUP PAGE 02/05 ) 2L-30S DESCRIPTION SUMMARY OF PROPSAL . ' ~' ConocoPhìllíps Alaska Inc. requésts approval to change the approved program for Tarn wen 2L-305 from Oil production to Water Alternating Gas (MI) injection service. This conversion to injection service is required to provide support to the offset producers. 2L-305 was completed as a 5-1/t' x 3-1/2" Oil producer on Dec. 6, 199B. The targeted Tarn Bermuda zone was encountered between 8383' - 8920' md (52521-55241 tvd). The 5-1/2" produotion casing Inner Annulus is isolated utilizing a Baker Baker 80-40 Sealbore Assembly at 8367' md (5244' tvd). A Cement Bond Log (SCMT..A with PSP) was obtained on May 15,2001. The log indicates uniformly exoellent cement bond from 5250' tvd (8379' md) to the top of perforations at SSSSI tvd (8648' md). WeU 2L.305 Pa$sed an MITIA conducted on November 14~ 2004. 11/18/2004 17:06 9076591'" '1 ..", .",.' "COnOCöPhmlþšAJ8.~":'~. ",',", KRU, , . 2t-3Q51.I.1,,, . ,,,I. '''','' . ..'IL,'It~'.Wl:!:t'l'.: . '~".~",',~. .,/"H, ',.." :'Hli;;;II:¡~'4"litJ;.H.,:L:,:~;:!;;;;;~1:':'1IL;''', .°"':"":''')1 "PI; 50 1 O~2[:: i90Ò W'3.!.IJy~, PROD" ""Ar,QIC!1@ "is: dltl~ @' '"'' , ,- . .. '",,', ,," :, SSS"'T.~è; NfPP~Ê", Orm Cort.lÞJètion: 12/$1ï995 Apg¡e@TD: 62<km tßJ ~2'Q ;~'::' ,: Annular Fluid: DSUSW . L~t W/O; ,-. Re~,-Rgegon: T~G FILL, cU,t,paraffln I", "Refe~~,cq'Lot:l; :-1' Ref LÞI1 Date: ," , ~$t UpdBte:1.01Sf2004 NIP (/!11.$12'YSI TaQ; 8683 ' "TD: 9.:!'JO_1.tKB O~~é~~~ ".' "C.!I~~~~'~;Î~:'~ÅL~~~~~[l4" "'::",:':' ,,~:a~ ,;~~~;~t~::,:;,~~i,~~::~;i~:~,~;:i..;I'.''' !:;il,:;;:,'( ;'::,<ii":::::~"","" ',:,::::;:<::;:;;';:,,,, ': :~;,/ ,:":"1'" :' ::,::, :,~:: o~:.~~~: Dl!liçrlDtJøn "',,' . '":,, 'Size Toþ Bottom We> WtGradtt Threed 10:2.992) CONOUCTO~ . Hi. 000 .. 0 ': 108 -::~, 108 ,. ,Ö2.58 -Pj-40 ,~ELDEC. PROO I' $ÜRF CASING-' . 7.625 0 .2667 .... 2290 ._45.50 1,..80 S:rC.MOO ~SING ,': .. PROD CASING . .5.500 " 0 ' .8369 a245 , 23,00 ".I..gO S.TC-MOD o~:.;gg: "I T:Obll:tt::~~ ~~ß -. 3~500 :, ,," ,~~69 , ,," ,9199 ",' ",,~6~6 '", :,9,30 "õ'" .':~80 ,,'IS).Je.s~D W'~,OO) ;, ':-.:'~ ' ,':1' "T~- I , "~~~~ . 'I' "",:~' ,"'I.,;#'"I:\~r,':,:¡,'.;,'~~~" ' ,,' " P'êtfó~~,S,~'rh~D'::, ",,' ,. ,.",,,;', "'''' I' , , , ," , , '" ,,', \ " '" ,," " 1 I' "" . s~~e_~:~a', ¡ S3S~~ IZO,~ê ¡ 'st*~s'1:'~~""(s~~}12~~;~~-~1','~~~~' ~":5.,,~:'~'qJ~~~~:~~ ,~","',' '" ,;Gj.~~;IA:Mijr/U~l!It~èlV.(i$:::::':,,,,,,,,::,:,:' ,:"'::'::';:',::' ':'\,",' ",,""":"';',:':,' ,", ",'":",,',,i,'¡ """:""",::::,''':';,:',, '",,',, " St MO iVD Man Mfr M~n Type ,{11M,,:' V Type"" "v 00 I8tch . Þori'" TRO . -- D8t~ V1v Rut'! cm~ 121eJ'5I98 9/30;2000 I''''''''J¡, ."._~ "1/': ,, I roll 1': : I " :: :,~"" I .~, ," :: . t; .: I " : '.D, 2,670 2.8~'¡,3 2,'7õQ "'~ Giis: Lilt ~ndl'lr/DUmm)l VøMi1 (S~53-5284, OD:4.72.$) SLEEVE (6257-&:a~, OD~4.500) Gae WI MándrolNAl1II;I 2 (8307.9308, NIF' (ð3G~3eOI 00:4,4'7'0) SEAt., (~3e7-83B8, OD:MÒO) Pari (B618-86M) FROD CASING (8369-9199, OD:3.5oo. WI:9"~O) 1 ' I' !:: , ,', .:" , : :',::1\ 1 ]., ,,\1 "I' :' I , ~ I, I" . ,': ~ ~; :' "'J , , ' I. I' " I' "~'I ;::¡\ , ,,;:i\ . - '11~i\~ \~,(\'I~~\!~~~,~~~q\;,\*\:!:~::: ' we¡t:):)." a" ,-...."" " '!.!.'~rl;1:",,:I,,;,~,I:?ji~I,~1! ' .:: ~; i ), ',' ::::.! :::1 1= --F NSK WELLS GROUP) PAGE 03/06 2L-305 1"""" S:;¡S3 353Ef -cAMeo KBG29 CAMCO' 2 .83'07 5213 éÁMCO KBG2S'. CAMCO J~1ïii~r.:{tJla~rl.t::,~tìip;yl~tt..:l~ ~l¡;WELR'(", ,:, . ,'~~', '"" paptt! ND. -, Type ~. ' " G11 S11 NIP .ÇAMCODSNlPPL.E '8257 51SEi. - St.EEVEBAKER CMU SLÏDING SU:EVE: clOSed 9/3OJ2ÖOO, -""8359 5Z40 NIP 'CAMOO 0 NIPPI.Ei .,- ~' 8367 ,,'" ~ s~~. BAKER80~49,~eALASSX".', ,,," ,,,' ' ¡"E~'hh~liF,ISH' ,:::,,".. ',,',.. :.,..",' " ' ..,. ',',".";:,: ,.'"..i,' '''', ',.;~::", ,,,,:::':; :"::', ,.: '" DePth I. D~.acrl)t;h;m T ",,,Comment,, ~,Q.":,, rFISH 11.85" ~QLJ.eR WHEEL Loj;T IN RATHOL~j~/4f2001 DMY , . ,1.0 INT'.. 0.000 C OV 1.0 ""...II\IT O,31~_,. 0 :11:,::1". "', "':11 '..:.11':". ,::('.(,:::,~I" ',' 'I De$çriPtïQ~, '11, .,1'1 I~ , ,.. Iii""' j' ..~-~--- m ¡ Æ ~ ~ ~ - :w, I ,.". ~ ~. 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If ÞI r; M ~) , (GA~) 10lI - - ~~ - - Cbl 5..1't 'blJ'l1bll!l D~nDlty L IHI!PllrlIlIftllIIIfIIDaIWI"'~~~ U \!II" / 100 (VPLJ .,1111 UWI ¡¡¡ ~;~ .......0 fUID~ ' ,,",ent Map II'II~~ C~ £11 I ~I ~200 (MV), -~ 9076597~~f FAX NSK WELLS GROUP ) PAGE 06/06 ~OO3/003 Pr"p~ø~ Pe '" 0 i~¡8Ctiíiïiñiif' --,~- , !:lei t:.CL $amt Rølðtlvo raoatlnQ {RB\ Cbl :L1'1,AI'tIl~lftUde roFlL) (Cç:hP)~.. 'õ -- ..." .. .. - (öËê1w.. . ... ,(3lfù,(¡ , "{MVì~' 10~ :.i tV) ..1" J ~.. .. C~I3.~ l'ro-.¡t~¡1111W ~' ^",pJI1I41d CõoJ~,n; ¡\InPIi1-i~l,_". ~- ~",. ~-~- ~II!UéfJl.\lL¡¡;M;'f~ :!(,VI) ~B} 4Ø<I'."""r."""~~=lõi: ",.,~"~I..!II"'N,",,,,!Jwdl'lllr)"-~t~ ') ) 1,\ <25-d-L{ù MECHANICAL INTEGRITY REPORT' '.., :.1: G RELEJ...S:::: . \ '/dd ~,,~-. \'ã J~-c;)s' OPER & FIELD (.? ~.~ 't-Q () \~'" --- ð'L--~a~ =?UD DA:Z: : w"'"ELL NUMBER 7~t;.LL DATA TD: ~d\\J,HD..5bb \ TVTI j ?BTD: ~a"\ \ MD Ss~1 TVD Ca.s i~g : S '(,~ ~ S'KG: Ss ~<1 0 11D TVD j DV: ~~ 11D . Tvu _:..:¡e:: : "3> \/~ Shoe: S~C) MD TVD i :CP: ~3~() HD :VD -: 'J '0 i:; g: 3 \/~ ~:!:" <i5'3C09 MD T\7TI i Set: E t ~ole Size b ~ Il.{ anå P e:r£ 5 to ~ C?--Þ..l-1I Cl-..r. INTEGRITY - P llliT ¡ 1 Annulus Press Test: :p ¡ 15 min ; 30 min Comments: C~~ T ~~\CC? C).~ ~ \\ \)..,),,~ ~~t \l/\'-\-aL\ "<'I.\-~l:G\')~. \N~~~~~ \-'\ \. ,~\;\ \ rC~~. ~CHÞ~ICÞ~ INTEGRITY - PART /2 Cement Volumes :', Þ..mt.. Liner '3S0s'{; Csg ; DV . C;¡¡ t 701 to C QV e:r: p e r£ 5 N\.~.!.- \..-0.. '"' c;.á,c '$(""- \- '-.<i::..t'-\f..V\-\- ~~ Theoretical TOe TO C. \<" ~o-\\ c~'-.)~ \op ö\-\~~\JQ\. Cement Bond Log (Yes or No) '(<<.. ~ ; In AOGCC File' CBL ~valuation, ::one above perfs \o~ Q...~C\~\~~ '1\ i-a \ w( \è.K.. ~Q\\~-\~o.b~\J£. ~~, P roåuc.tion La g : Type Evaluation CONCLUSIONS: '. ?art fl: , .' ~ 'O~~I'Q\'Y~'-JQ\~ 'YZkJ 0 \ ?ar:: ~ 2: \-\.::ç "\ ~ \~t'Cú ~'., Sa \ \ '&- d..... $\""-,-\\c~\,\,,-~~\-\Ð'" ~Q"\3~~~ . '- \\Á<:.co'1 - d~Cc..'? \'-C'\- s~\t:)~ ~~ '~4.\,\ ~\\~'\"". .' 'I - \r" ~ \;-.. tf"\«..~.~~\-~O f' \t\.. ~SCè..\~(:)\.\, . "'"\ ~\ "'f-. ~. v - Re: 2L-305 (198-240) ) Sp.bject: Re: 2L-305 (198-240) From: Thomas Maunder <tom_maunder@admin,state,ak.us> Date: Fri, 19 Nov 2004 14:06:44 -0900 To: NSK Problem Well Supv <n1617@conocophillips,com> Jerry , No need to send in any other copy of the application, We can work from a fax as long as it is signed. Tom Thomas Maunder wrote: Jerry , I have completed my review of the subject well. I have confinned the information submitted in support of the proposal to convert 2L-305 from producer to WAG injector, It is interesting to note that in researching our file, I find that an application was made in July 2001 to convert the well to injection service, It does not appear that such conversion ever took place, I would appreciate if you could send in the MIT report form for the test reportedly done on 11/14. That test allows provisional approval to initiate injection, however once the well is "wanned up" and thermally stable arrangements should be made to have an Inspector witness an MIT. Please call or message with any questions, Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: I had to do some checking to see what the hurry was. It appears that all the piping and wellwork is complete and the conversion can be done very quickly. However, we realize you need time to evaluate the request so please do so. At this point we did not want to wait for snail mail. So please do not feel hurried as my previous emaì! suggested. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, November 18, 2004 4:26 PM To: NSK Problem Well Supv Subject: Re: Kuparuk conversion Jerry, I was just trying to give you a call. I got the fax, this is really a short fuse!! I can have a look at it tomorrow, I think. Why the RUSH?? Tom lof2 11/19/2004 2:06 PM Re: 2L-305 (198-240) 20[2 ) ) NSK Problem Well Supv wrote: Tom: Kuparuk well (Tarn) 2L-305 is a well ConocoPhillips would like to convert immediately from a producer to an injector. The 10-403 is being faxed to your office for review. Would you please respond to our request before the weekend? We will wait for your response before sending the hardcopy in the mail. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 11/19/20042:06 PM RE: 2L-305 (198-240) , ',.",,, ) ) Subject: RE: 2L-305 (198-240) From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 19 Nov 2004 17:36:19 -0900 To: Thomas Maunder <tom - maunder@admin.state.ak.us> CC: bob - fleckenstein@admin.state.ak.us Tom: Attached is the MIT test performed in support of conversion of 2L-305 from a producer to an injector. Other items: the hardcopy of the Sundry is already in the mail and I cannot retrieve it Secondly, Engineering does not have any plans at this time for additional injectors at Tarn. Last, as always we will notify the Inspectors to witness an MIT once the well is on line. Please let me know if you have other questions, and thanks for your patience! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, November 19, 2004 2:05 PM To: NSK Problem Well Supv Subject: Re: 2L-305 (198-240) Jerry, I have completed my review of the subject well. I have confirmed the information submitted in support of the proposal to convert 2L-305 from producer to WAG injector. It is interesting to note that in researching our file, I find that an application was made in July 2001 to convert the well to injection service. It does not appear that such conversion ever took place. I would appreciate if you could send in the MIT report form for the test reportedly done on 11/14. That test allows provisional approval to initiate inj ection, however once the well is "warmed up" and thermally stable arrangements should be made to have an Inspector witness an MIT. Please call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: I had to do some checking to see what the hurry was. It appears that all the piping and wellwork is complete and the conversion can be done very quickly. However, we realize you need time to evaluate the request so please do so. At this point we did not want to wait for snail mail. So please do not feel hurried as my previous email suggested. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska SCANNE[, NOV 2, 4: 200Li, 10f2 11/22/20047:56 AM RE: 2L-305 (198-240) ) 907 -659-7224 -----Original Message----- From: Thomas Maunder rmailto:tom, maunder@admin.state.ak.us] Sent: Thursday, November 18, 2004 4:26 PM To: NSK Problem Well Supv Subject: Re: Kuparuk conversion Jerry, I was just trying to give you a call. I got the fax, this is really a short fuse!! I can have a look at it tomorrow, I think. Why the RUSH?? Tom NSK Problem Well Supv wrote: Tom: Kuparuk well (Tarn) 2L-305 is a well ConocoPhillips would like to convert immediately from a producer to an injector. The 10-403 is being faxed to your office for review. Would you please respond to our request before the weekend? We will wait for your response before sending the hardcopy in the mail. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 Content-Description: MIT KRU 2L-305 11-13-04.xls KRU 2L-305 11-13-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 11/22/20047:56 AM ') STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2L-305 11/13/04 Rainey 1 HES Packer Depth Pretest Initial 15 Min. 30 Min. Well2L-305 Type Inj N T.V.D. 5244 Tubing 350 450 450 450 Interval 0 P.T.D.1982400 Type Test P Test psi 1500 Casing 950 2500 2475 2475 P/F P Notes: Test performed in support of conversion from producer to injector Well Type Inj TV.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Well Type Inj TV.D. Tubing P.TD. Type Test Test psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.TD. Type Test Test psi 1500 Casing Notes: Test Details: Interval P/F Interval P/F Interval P/F Interval P/F TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2L-305 11-13-04-1.xls 11/22/2004 MICROFILMED 7/30/02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilrn_marker.doc ,,""'7--, ( .' ~ (t~~7;~ ,\..; ~~j .~~~1 ,~ "{ Casing Detail 7.625" Surface Casing ( 9 t - ~l-(o ARca Alaska, Inc. WELL: TARN 2L-305 DATE: 11/26/98 1 OF 1 PAGES Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RKB to LR = 28.50' TOPS Above RKB 7 5/8" Landing Joint 28.50 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.71 28.50 jts. 40-62 75/8", 29.7#, L-80 BTC-mod(23 jts) 976.05 31.21 TAM 7 5/8" Port Collar 2.47 1007.26 its. 3-39 75/8",29.7#, L-80 BTC-mod (37 its) 1571.50 1009.73 Gemeco Float Collar 1.33 2581.23 its 1-2 75/8",29.7#, L-80 BTC-mod(2 its) 83.16 2582.5&.. Gemeco Float Shoe 1.49 2665.72 \ Casina shoe @ 2ß67.21 } '-..,,,,, ,,/ T.D. @ 2685' leavina 10' of rathole 30 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1. 2. 39. 40. over stop collars and over casing collars on Jts. 3-14 and over collars of its. 17,20,23,26,29,32,35,37,43,46,49,52,55,58. Joints 63 - 70 (8 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 80K Up, 55K On" 12k Blocks. Ran 62 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. " .. I ,.. Doyon 141 ~~!r"\\!\~~J DrHling Supervisor: R. W. SPRINGER ~~ ...." ARCa Alaska, Inc. Well Name: 2L.305 AI Name: DOYON 141 Casing Size 7-518" Centralizers Comments: Mud Comments: REDUCED VIS F/145 TO 96 Wash Comments: ARCO 8-47, PRECEDED FLUSH WI3 BBL CELLO FLAKES 0 Spacer Comments: ARCO B-45 0 Lead Cement 0 Comments: Tall Cement 0 Comments: Displacement < 0 Comments: UNABLE TO RECIPROCATE D.IJË TO>JUNK(LOST . CENTRALIZER BLADE) Cementin Deta ils Report Date: 11/27/98 AFC No.: AK9421 Report Number: 7 Field: TARN Hole Diameter: '3-718" Angle thru KRU: Shoe Depth: 2677 LC Depth: % washout: State type used, intervals covered and spacing 30 GEMOCO BOW SPRING, CENTER JTS 1,2,39,40, OVER CLRS JTS 3-14 EVERY 3RD CLR JTS 17 THRU 58 Weight: PV(prior con d): PV(after cond): VP(prior cond): VP(after cond): 10.1 36 28 47 29 Gels before: Gels after. Total Volume Circulated: 15119 12/15 2+ Type: Volume: Weight: ARCO Wash 17 BBL 10.5 Type: Volume: Weight: ARCO 40 10.5 Type: Mix wtr temp: Weight: ASIII 70 10.7 Additives: 3.5%D44,30%D53,50%D124, 1.5%D79,0.4%D46 Type: Mix wtr temp: Weight: G 70 15.8 Additives: 1%S1 +0.3%D65+0.2%D46 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: 5 6 Reciprocation length: Reciprocation speed: Str. WI. Down: Theoretical Displacement: Actual Displacement: Str. WI. In mud: 108.4 108.8 CP: Bumped plug: Floats held: Date: 11/26/98 YES YES Time:1530 Cement Company: DS E, RIH OPENED PORT COLLAR WITAM PACKER, DISPLACED MUD & CEMENT OUT RECEMENTED THRU PORT @1007' W/ASIII Rig Contractor: DOYON Approved By: R.W. SPRINGER ~~ ...." ARCa Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since AccepUEst: 4.8 /1.5 Rig Relase - hrs: AK9421 11/26/98 6 11/22/98 Well: 2L-305 Depth (MDITVD) 2685/2308 Prev Depth MD: 2685 Progress: 0 Contractor: DOYON Daily Cost $ 137430 Cum Cost $ 623476 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5/8 @ 2675' Next Csg: Shoe Test: Operation At 0600: TESTING BOPE Upcoming Operations: DRILL OUT CSG. FIT, DRILL AHEAD MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO, BIT NO, INCIDENT LAST BOPIDIVERT LAST BOP/DRILL LSND 1RR1 N TST 11/18/98 11/15/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 10.1ppg 9.875 1 0/28/98 11/19/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 96sqc HTC N SPACE 11/22/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 28 I 29 MX1 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1600 12/151 A56ZC APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1600 3.4 2685 11/26/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 130 ml/30 min 2675 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 10 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTlAST SOURCE WELL TEMP of 10 114bbl 800 III I I 2L.305 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 20.0 11211 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 75' 9.5 61611 80 - 500 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 5.90 35.95% 60160 II Water Base Muds 1657 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 100 252 I 252 I I 161161161 I I 11111 135 Diesel 65 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $4376 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $79747 III III III 1857 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 14 BAROID III III III 19336 PERSONNEL TOTAL 48 :...' TIME.. I . END.. HOURS I.. OPS.CODE I HOLE SECT . I PHASEOPS .. ., . ..: r ... ., .:.OPE:RATIONSFRQMOOOO ~..OOOO 12:00 AM 12:30 AM 0.50 PRB_CSG SURF Casing and POH WIWIPER-REAMER ASSY. Cementing 12:30 AM 01 :30 AM 1.00 PRB_CSG SURF Casing and UD D.CLRS. REAMER & BIT. Cementing 01 :30 AM ,02:30 AM 1.00 CASG SURF Casing and RlU TO RUN SURFACE CSG & PJSM. Cementing 02:30 AM 05:30 AM 3.00 CASG SURF Casing and RUN 7-5/8" CASING. Cementing 05:30 AM 08:30 AM 3.00 CEMENT SURF Casing and MIU CEMENTING HEAD, CIRC & CONDITION MUD, CUT Cementing VISCOSITY F/150-90. 08:30 AM 10:30 AM 2.00 CEMENT SURF Casing and TESTED LlNES.PUMPED 3 BBL CELLO FLAKES-17 BBLS Cementing ARCO PREFLUSH-40 BBL ARCO SPACER @10.5# 237 BBL (330 SX) LEAD CMT- DROP PLUG.49 BBL(235 SX) TAIL CMT-DROPPED TOPPLUG-DISPLACED W/RIG USING MUD TO CALC AMT-BUMPED PLUG- FLOATS HELD NO CEMENT TO SURFACE. 10:30 AM 11:30 AM 1.00 CEMENT SURF Casing and RID CMT HEAD & LID LANDING JT. Cementing 11:30 AM 01 :00 PM 1.50 CEMENT SURF Casing and RlU TO PICKUP DRILLPIPE & TAM COMBINATION TOOL- Cementing RIH TO 1007' 01 :00 PM 01:30 PM 0.50 CEMENT SURF Casing and ENGAGE RUNNING TOOL & OPEN PORT COLLAR. Cementing 01 :30 PM 02:30 PM 1.00 CEMENT SURF Casing and ESTABLISH CIRC BUILD TO 4 BPM CEMENT TO SURFACE Cementing AFTER 30 BBL CIRC OUT REMAINDER OF CMT TO SURFACE. 02:30 PM 04:00 PM 1.50 CEMENT SURF Casing and CMT W/180 BBL(230 SX) LEAD CMT 10.7 PPG GOOD CMT Cementing TO SURFACE. 04:00 PM 04:30 PM 0.50 CEMENT SURF Casing and POH & LID PORT COLLAR RUNNING TOOL. Cementing Daily Drilling Report: 2L-305 11/26/98 Page 7 04:30 PM 05:30 PM 1.00 CASG SURF Casing and CLEAR FLOOR OF CASG EQUIPMENT. Cementing 05:30 PM 06:00 PM 0.50 NU_ND SURF Other NID FLOWLINE- TURN BUCKLES & DRIP PAN EQUIPMENT. 06:00 PM 07:00 PM 1.00 NU_ND SURF Other ANNULUS CHARGED UP. FILLED CELLAR W/CMT- CLEANED OUT CELLAR. 07:00 PM 10:30 PM 3.50 NU_ND SURF Other CONTINUED NID DIVERTER. 10:30 PM 12:00 AM 1.50 NU_ND SURF Other N/U CSG SPOOL & TBG SPOOL- TEST SPEED HEAD-OK. 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-305 11/26/98 Page 8 CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 11/27/1998 2L-305 Supervisor: R.W. SPRINGER Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2667 TMD 2,311' TVD Mud Weight: 9.1 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 2,311' TVD 970 psi + 9.1 ppg EMW LOT= (0.052 x 2,311') = 17.2 ppg Fluid Pumped = 1.32 BBL Pump output = 0.101 BBUSTK ..-1 TIME LINE ì I I I ! I I ! I I ¡ I ONE MINUTE TICKS I I I I I J J I I ! . . I I I I I ¡I! 1 I ¡ I I I I . i I I I ~ ~ .....< "',' ':cL I ! I I ¡ i! I ! I / I i I ' ! I ! I I I I I ¡ I I I ! If I i I i ¡ I I I I I I I I ! I i I I I I 1/1 I ¡ I I i I I I I I I ! I! I I ! J I I ! I I i I !, I I I I I I i I, 'I ! I I I , ....... LEAK-OFF TEST I i I i~*" I I , ! 1 ---CASING TEST I I itif Pi""",., . I I --'1,-- LOT SHUT IN TIME I -k-CASING TEST SHUT IN TIME ' I r I i/ ! I I -+- TIME LINE I I ' I I I I I I I I II I I I , I I I II ,! I I I / I I I i I I I J I " I I I I i I I Y I ~ I I I I J4¡ .--.... I I !! I I I I i 2.300 psi 2,200 psi 2,100 psi 2,000 psi 1.900 psi 1.800 psi 1,700 psi 1,600 psi 1,500 psi W 1,400 psi a: 1,300 psi ~ 1,200psi æ 1,100psi a: 1,000 psi a. 900psi BOO psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 62 64 86 88 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE f------------l--------------Y------------------' I I I I F======F==~-~~~=t~~~~~;¡~~i=~~i ¡-----------¡---6-S¡-ks--I---2"õõ--pšT--1 I--------------~-------------+-------------------I ! ! 9 stks ! 470 psi. i r-:;------,.-T--'Ï'istks---T---S3õpš-t-l Þt--------------r--12-S¡-kŠ----r---Õ7õ-pšT-1 > ----~----------+-------------I \ ~ ~~-=--:--=~:::::=:~!:~~-:::t-====:~ ~=~~==~~-~~l~~==j 1------"---1------------1----------"-----1 ~=~=i~~==~~~t==:===:=:1 Ë=:=~l--~===::t====l ~~~~*~~~~~í~~~~~~~1 i§HUT .!~_!!.~~L--------------~~l!.!.~-~~~~~~~E L__9.:..~- mi"!____L______--______L__~Q_e.~---j ! 1.0 min ! i 950 psi ¡ 8~~~~==t~~jEJ i 4.0 min ¡ ! 870 psi ¡ 1=~fn=~:E:=3]ïf~~B ! 7.0 min ! ! 840 psi! [---ã~~~~=1=~~~~~~==~=~=l~~~~~~p~~Ij ! 9.0 min i i 830 psi! Dg;Q_!!lI~=[~===~=~~~I=~~~~~~~~] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [=~=~~=~=~=~I~~~=~~~=~~~~~~~¡=~~~~~~==~~~~J ! I 0 stks I 0 psi ¡ ~---------------t-------------------...----------------.. L._--______m___-t---_1~-~~~----i-----~-~_J?~~----~ ~-------------------.-____1~_~!_~~---+----_?_Q.J?~~---..J ! ! 14 stks I 30 psi! [~~~~~~~~~=~~=~I~~=!~~~1~~~~~I~=-~~p~P~---_J ! i 18stks J 70 psi ! r-------------------r--"2Ö-Stkš---t---1-Š-Õ"i,š¡--1 [~~~~~~~~~==~~~~I~~~~~~~~~~~=L~~~~~fp~~I] i I 24 stks I 650 psi i t-___m_m______-t-----2s-šikš---+--:¡::¡õõ-pš¡-1 ....-----------------~------------------l-------------, L---_-------___--_L--?_t!.~!.~~___~__1!~~~_e~~-J L._---------___-!_m_~~!~~___~__1~~~_e~L~ ~-----______m___¡__--~!~!~~___~__1!Z~~E~1_-1 ¡ i 34 stks I 2,000 psi ¡ [~=~~~~~=~~~~=[~~~~~~=~~~~~~~~~~I~~~~~~~=--~=] . , I I ~-------------------t-----------------r---------------~ I I I 1 r-------------------¡-----"----------r--------------, t-------------------¡------------------t------------------1 ! SHUT IN TIME: SHUT IN PRESSURE f-----õ~õ-ñiiñm-t---_--------------r-1-'-9-9Õ-psf--l ¡---Tõ-ñiiñ---l------------------¡--:¡:9šõ-pšT-i ~--------..,.------t----------------t---------------:--1 ~----~~~-~~~---.--------------------~--~!~!~-~!~--~ ! 3.0 min ! i 1,960 psi! ~-------------------t-------------------ï----------------.. i_--_i:Q_!n~~___L______---______L__'L~~~_e~L.J ~---_É;Q_!n~!:'_---I--------------------L--_!!~~_e~l_-i' ! 6.0 min I ¡ 1,950 psi r---7~õ-ñiiñ----r---------------"---~95-õ-pšT-l ~----------------t--------------______l____-------------.. i 8.0 min I I 1,950 psi! r---9~Õ-ITiiñ----!------------------t--:¡:9šõpši1 r--"iõ~õ-ñifñ----t-------------------t--:¡:94Õ-pšil r--"iK'"õ-ñifñ---l-------------------¡-:¡:94õ-pšTl .----------------t-----------------¡-----------------; L--_?Q;Q_!!!~!:'_---¡------------------- __1!~~~_e~L_~ L-'?§;Q-'!!~!:'_---!---------------- __1!~~~_e~1__j L._-~g;Q_!n~~__L______------------ _1!~~~_e~1_.J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ~~ ~" ARCa Alaska, Inc. Daily Drilling Report AFC No. ¡Date RptNo I Rig Accept - hrs Days Since AccepUEst: 5.8 /1.5 Rig Relase - hrs: AK9421 11/27/98 7 11/22/98 Well: 2L.305 Depth (MDITVD) 2685/2308 Prev Depth MD: 2685 Progress: 0 Contractor: DOYON Daily Cost $ 115771 Cum Cost $ 739247 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7.5/8181 2675' Next Csg: Shoe Test: 17.1 Operation At 0600: DRILLING 6.3/4" HOLE @ 3099' Upcoming Operations: CONTINUE DRILLING MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 2705 2 3 N TST 11/27/98 11/27/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1 ppg 6.75 6.75 11/27/98 11/19/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 50sqc STC HTC N SPACE 11/27/98 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 50/10 ECONOMILL STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1585 3/5/ N104 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 400 9.8 2705 11/27/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 135 Oml/30 min 2685 2705 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 3.0% 20 0 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADT/AST SOURCE WELL TEMP of 5 995bbl 480 III .51 / 2L-305 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 2 22.5 11 I 1 5 -15 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 90° 10.0 6111 70 - 90 550 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 5.00 2.09% 60 III OPEN Water Base Muds 715 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 2 500 252111 11111 13113113 1131 I 90 Diesel 45 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 27 $8343 III 1029 26435 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $88090 III III III 850 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID 9.111 I III III 20249 PERSONNEL TOTAL 48 TIME I END HOURS I OPS CODE T HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 04:30 AM 4.50 NU_ND SURF Other CONTINUE N/U BOPE. 04:30 AM 05:00 AM 0.50 BOPE SURF Other RIU TO TEST BOPE. 05:00 AM 09:00 AM 4.00 BOPE SURF Other TEST BOPE TO 250PSI LOW-3500 PSI HIGH. 09:00 AM 09:30 AM 0.50 BOPE SURF Other INSTALL WEAR BUSHING. 09:30 AM 10:30 AM 1.00 BHA SURF Other M/U MILL-2 BOOT BASKET BHA. 10:30 AM 11:30 AM 1.00 TRIP_IN SURF Other RIH TO 426'. 11:30AM 12:00 PM 0.50 REAM SURF Other WASH CMT STRINGER F/426-526' 12:00 PM 12:30 PM 0.50 TRIP_IN SURF Other CONTINUE RIH. TAG CMT @2550' 12:30 PM 01 :30 PM 1.00 CIRC SURF Other KELLY UP & CBU F/CASING TEST. 01 :30 PM 02:30 PM 1.00 TEST_CSG SURF Other TEST CASING TO 2000# F/30 MIN. 02:30 PM 06:30 PM 4.00 DRIL SURF Other DRILL HARD CEMENT.FLOAT EQUIPMENT & WASH OUT RATHOLE TO 2685'- NO JUNK IN RATHOLE( LOST CENTRALIZER BLADE WHEN PULLING CSG). 06:30 PM 07:00 PM 0.50 DRIL SURF Other DRILL 20' NEW FORMATION F/2685-2705'(2311, TVD). 07:00 PM 08:30 PM 1.50 CIRC PROD Other DISPLACE WELL TO NEW 9.1 PPG MUD & CONDITION HOLE. 08:30 PM 09:00 PM 0.50 EVAL PROD Other PERFORM LEAK OFF TEST- 17.1 PPG E.M.W. (UNABLE TO SHUT PUMP DOWN @ 16.0 F.I.T.. 09:00 PM 10:00 PM 1.00 TRIP_OUT PROD Other POH F/BHA. 10:00 PM 12:00 AM 2.00 BHA PROD Other M/U BHA #4. ORIENT & INITIALIZE MWD/FRT. 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-305 11/27/98 Page 9 Casing Detail 5-1/2" X 3-1/2" Production Casing WELL: TARN 2L-305 DATE:12104/98 1 OF 1 PAGES ARC a Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LOS = 25.25 TOPS 51/2", LANDING JT. 34.0' OVERALL LENGTH 25.25 5-1/211 GEN V CASING HANGER 3.01 25.25 Jts. 1-194 5-1/2",15.5# L-80, LTC MOD (194 joints) 8330.16 28.26 PUP 5-1/2", 15.5# L -80, LTC MOD 10.67 8358.42 Baker Csg Seal Receptacle (CSR), SIZE 80-40, 5-1/2" x 4" 21.01 8369.09 XO 3-1/211 9.3# L-80 8rd EUE X 5 1/2" EUE 8rd (XO) 8390.10 pup 3-1/2" 9.3# L-80 8rd EUE 10.12 8390.10 Jts.273-275 3-1/2" 9.3# L-80 8rd EUE (4 joints) 94.75 8400.22 pup 3-1/2" 9.3# L-80 8rd EUE (marker) 8.33 8494.97 Jts.254-272 3-1/211 9.3# L-80 8rd EUE (18 joints) 599.97 8503.30 Weatherford Gemoco Float Collar 1.17 9103.27 Jts.251-253 3-1/211 9.3# L-80 8rd EUE (3 joints) 93.32 9104.44 Weatherford Gemoco Float Shoe 1.85 9197.76 Bottom of Shoe @ 9199.61 ACTUAL TD= (92101) 10.0' RATHOLE. Bypass plug latch in receptical @ 9071.66'. (top of jt. #254) (25) 3-1/211 x 6-1/211 straight blade centralizers(Jts.251-275) (12) 5 1/211 x 6 3/411 bow spring centralizers (Jts.1-12 1 ST 12 JTS IN HOLE) (16) 5-1/2" x 6-1/2" centering guidess on jts 193,188,183,180, jts 177,174,171,168,165,162,159,156,153,150,147,144 Remarks: String Weights with Blocks: 135k Up, 50K On, 12K Blocks. Ran 25 Joints 3-1/211 and 194 Joints of 5-1/2" casing. Drifted 5.5" (4.7511)& 3.5" (2.867") casing with plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: R. W. SPRINGER ...~ ....~ ARCa Alaska, Inc. Well Name: 2L.305 Rig Name: DOYON 141 Cementing Details Report Date: 12/05/98 AFC No.: AK9421 Report Number: 15 Field: TARN Casing Size Hole Diameler: Angle thru KRU: Shoe Depth: I LC Depth: % washout: 5.1/2 X 3.1/2" 6.3/4" 62 8199 9103 Centralizers State type used. intervals covered and spacing Comments: 25 @ 3.1/2 X 6.1/2" STRAIGHT BLADE CENTRALIZERS, 12@ 5.1/2 X 6.3/4" BOW SPRING CENTRALIZERS, 16@ 5-1/2 X 6.1/2" CENTERING GUIDES Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.8 24 15 22 11 REDUCED WT F/10.3 TO 9.8, Gels before: Gels after: Total Volume Circulated: REDUCED VIS F/64 TO 43 6/9 4/6 4+ Wash 0 Type: Volume: Weight: Comments: ARCO 847 20 BBL Spacer 0 Type: Volume: Weight: Comments: ARCO 845 20 BBL 11.0 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: G 80 360 15.8 1.16 Additives: 2 gps D600+0.1gps D135+0.1gps D47+3%D53+0.8%D65+ 0.12% D800 Tall Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 4.8 3.5 75 Reciprocation length: Reciprocation speed: Str. WI. Down: 10 40 Theoretical Displacement: Actual Displacement: Str. WI. in mud: Calculated top of cement: CP: Bumped plug: I Floats held: 7000' Date: 12/5/98 yes yes Time:0109 Remarks:calc displacement, bumped plugs w/2000# held f/10 mln Cement Company: Rig Contractor: IAPproved By: DS DOYON R.W. SPRINGER ....... ...." ARCa Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since Accept/Est: 12.8/1.5 Rig Relase - hrs: AK9421 12/04198 14 11/22/98 Well: 2L.305 Depth (MDfTVD) 9210/5661 Prev Depth MD: 9210 Progress: 0 Contractor: DOYON Daily Cost $ 111791 Cum Cost $1610890 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-518 @ 2667' Next Csg: 5.1/2 X 3.1/2 @ 9200' Shoe Test: 17.1 Operation At 0600: RIGGING UP SCHLUMBERGER Upcoming Operations: CASED HOLE SONIC LOG, RUN COMPLETION. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOP/DRILL LSND 3 4RR1 N TST 12/01/98 12/03/98 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 6.75 6.75 12/02/98 12/03/98 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 43sqc HTC STC N SPACE 12/01198 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER 15/11 STR554 FDS GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1500 3/51 0322873 LP9142 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 500 5.4 9210 12/04198 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 ml/30 min 2705 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 9.0% 6505 9210 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP OF 3 207bbl III 37.55/9.4 I 2L-305 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 10 17.5 III 5 - 10 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION 45° 9.0 III 75 - - 550 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -17.24 61.79% III Water Base Muds 331 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 165001 I I I B 131131131131 I IIIII 45 Diesel 60 DAIL Y MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $ III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $ III III III 436 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 III III III 24337 PERSONNEL TOTAL 46 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 01 :00 AM 1.00 REAM PROD Other WASH & REAM F/8715-8876'. 01 :00 AM 01 :30 AM 0.50 TRIP_IN PROD Other RIH F/8876-9210'. 01 :30 AM 03:30 AM 2.00 CIRC PROD Other PUMP HI-VIS SWEEP & CIRC HOLE CLEAN, OBSERVE WELL, PUMP DRY JOB. 03:30 AM 10:00 AM 6.50 TRIP_OUT PROD Other POH LAYING DOWN 4" DP - HWDP- D.CLRS & BIT. 10:00 AM 10:30 AM 0.50 CASG PROD Casing and PULL WEAR RING. Cementing 10:30 AM 07:00 PM 8.50 CASG PROD Casing and RIU F/3.1/2" CSG- PJSM- RUN 3-1/2"- RIU & RUN 5-1/2" Cementing CSG- MIU HANGER. LANDING JT & CEMENTING HEAD. 07:00 PM 10:00 PM 3.00 CEMENT PROD Casing and BREAK CIRC- STAGE UP TO 5 BPM. CONDITION MUD Cementing TOTAL FLUID LOSS UNTIL MUD CONDITIONED 113 BBL. 10:00 PM 12:00 AM 2.00 CEMENT PROD Other PJSM. TEST LINES 3500# CEMENT W/350 SX CLASS G W/ADDITIVES. 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-305 12/04/98 Page 16 ..~ ...." ARCa Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I Rig Accept - hrs Days Since AccepVEst: 13.8/1.5 Rig Relase - hrs: AK9421 12/05/98 15 11/22/98 Well: 2L-305 Depth (MDITVD) 9210/5661 Prev Depth MD: 9210 Progress: 0 Contractor: DOYON Daily Cost $ 347144 Cum Cost $ 1958034 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7-5/8 @ 2667' Next Csg: 5.1/2 X 3.1/2 @ 9200' Shoe Test: 17.1 Operation At 0600: RIG RELEASED PREPARING TO MOVE. Upcoming Operations: MOVE TO 2L.315 & SPUD. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL SW 3 4RR1 N TST 12/01198 12/03/98 WEIGHT ROTwr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 8.6ppg 6.75 6.75 12/02/98 12/05/98 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL sqc HTC STC N SPACE 12/01/98 PVIYP sowr TYPE TYPE TYPE FUEL & WATER I STR554 FDS GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1300 I I 0322873 LP9142 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 275 9210 12/05/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 100 ml/30 min 2705 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 6505 9210 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 0 Obbl III 37.55/9.4 / 2L.305 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 0 III 5 - 10 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTION III 75 - 600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 0.00 % III Water Base Muds 1222 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 165001 I I I B 131131131131 I 11111 45 Diesel 60 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $500 III 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $165501 III III III 1327 COMPANY MUDwr GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID III III III 25664 PERSONNEL TOTAL 46 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 01 :30 AM 1.50 CEMENT PROD Casing and CON'T CEMENTING BUMP PLUG @ CALC. DISPLACEMENT Cementing W/2000 PSI F/10 MIN- BLED OFF- FLOATS HELD- RID CEMENTING HEAD & LDG JT. 01 :30 AM 02:30 AM 1.00 NU_ND COMP Casing and INSTALL 5-1/2" PACKOFF & TEST TO 5000 PSI/10 MIN. Cementing 02:30 AM 03:30 AM 1.00 RIGS COMP Other SLIP & CUT DRLG LINE. 03:30 AM 07:30 AM 4.00 CEMENT COMP Other WAIT ON CEMENT & CLEAN MUD PITS. 07:30 AM 06:00 PM 10.50 EVAL COMP Evaluation RlU SCHLUMBERGER & RUN DSI (SLOW RUNNING SPEED DUE TO BACKGROUND NOISE). 06:00 PM 06:30 PM 0.50 EVAL COMP Other RID SCHLUMBERGER. 06:30 PM 12:00 AM 5.50 RUN_COMP COMP Completion RIG UP & RUN 3-1/2" COMPLETION ASSY. 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-305 12/05/98 Page 17 CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: 11/30/1998 2L-305 Supervisor: R.W. SPRINGER Casing Size and Description: 75/8",29.7 ppf, L-80, BTC Casing Setting Depth: 2,311' TVD 2,667' TMD Mud Weight: 9.2 ppg EMW = Leak-off Press. + MW 0.052 x TVD Hole Depth: 4,554' TVD 680 psi + 9.2 ppg EMW LOT= (0.052 x 2,311') = 14.9 ppg Fluid Pumped = 5.1 bbl Pump output = 0.1010 bps Fluid Returns = 2.5 bbl 900 psi JTIM. E. LINE AONE MINUTE ¡ I Hi , I ' i ' I , I I TTl I I I , I Tl ., J ~-II I i ~ -+-LEAK-OFF TEST : I I ""'CASING TEST I I --,0,,- LOT SHUT IN TIME I I I -4-- CASING TEST SHUT IN TIME I. II I -+- TIME LINE ++--1 I: ¡ I I , tI ¡ ! mm:m:m' I I ! I I . ¡I, I I! 700 psi 600 psi 300 psi I 200 psi I 100 psi 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ ¡ I i ; I I ' irl I I , r i i ~~ I I ì W II: 500 psi :J U) U) ~ 400 psi a.. I I I ì I ì I I STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r==~~====--c=~====] ! ! 0 stks ! 0 psi ¡ r--------l----Š-šïkš---¡--14õ-psil ¡-----r--10stkS"¡--- 24-Õ-ps¡---1 ~-----~----------+-----------I L----j- 15 stk!!--l~Q-.p..~L_.J L__-L 20 stk!!..__l- 43Q.'p.!~j ! ! 25 stks i 690 psi! I----------i------------+-----------~ ! ! 27 stks i 740 psi ¡ r--==~---l=-_!~ stkš---r !I~p~[] ! ! 31 stks ¡ 790 psi! t-----i-------+----------"¡ ~------J-- 33 st~!!..-l~Q..p.!L__~ i-----L-- 35 st.!!!..-L!J!J.Q.p-!'L.J L_______L- 37 stk!!..__l- 80Q.~L_-I ! ! 39 stks i 780 psi; I----------i --+----------1 ! ! 41 stks ! 730 psi! r----------¡--- 43 stks--r 70õpsi--l ¡-------¡----45 stks---r--67Õ"jiST-1 ~----------i------------+-------------f ! ! 48 stks ! 670 psi! r~-=-~==¡--§O Stk~~=¡=~~~I~p_!~=~ I I I I Ë~~---t~-=t==j I I I ! t----------l----------î-------"-", L~!I_':'.!.!N TIME L--___~.!!!.~RE~~_Y-~E LJ?;Q. min _L____--___L2gQJ?~_j ! 1.0 min ! ! 500 psi! I-------------i--------+---------------I L_2.0 min_-L------_-J...-_~90J?_!~---j ! 3.0 min ! ! 480 psi! !4:Oñifri----r-----------r--4ãÕ-psi--1 t----~----------+------------.-"¡ ~--~Q-~~-!------------.i-~ZQ_.P~L__~ L--~;Q-~~l--------L-~~-Q..p.!L.J L_...?.:.~_~.!!!_L_______i_~_~Q..p..!L__~ ! 8.0 min ! ! 450 psi I ~------------i-----------+------------I L.~;Q.!TIi~--J----------l--~É-Q..p.!L_J L.:æ.:Q~L______.i_i~.Q..p~L_j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r--------------1------------I---------' ~~~=====i~=:==~~~:l-~=~-~~ ~~~====~=~~t==~~~-~=~~~ ~~~~==~~~~~~-1 L______--------t-------------- ---------------_J r---------------i-----------------i-------------1 [=-~~~~~=~~~~=I=-~~~~====~- =~=~-===~=] 'I ' ~----------------t-------------- -------------~ ~=~=~~=~~~==-~~=~==~~-=== ==~====-1 r-------------i--------------t-------------1 t-----------i------------i-----"--------i r I I : r--------------t---------------T------------' f=:::=::::=t-:===::::::t=:::::::::::~ r------------------¡---"---"---------r--------------l L----------------f---------------_J._--------------J ! I I ¡ t SHUT !~-J~~~~----------~!iI.':'!_!~.!_~~SS_':'lRE í----~~~-~f~----t------------_.._.._-- ------------------, t-----------~------t-----_.._-------- ---"---------1 I 2.0mm I I t---3~õ-rñiñ--l-------------- I --------------1 r-¡õ-rñrñ---ï-------------------r--------------l f~==é~~~~r~~~=F~-~~=~~~=-~=~~f==~~~~~~==~l '-------------1'--------------..----------------.. t----ij~~-~~~----t------------_._-t-----------------i ~~=~~~!!}I~~~~~t~~=~~~~=~~~~~~~~~¡=~~==~===~ I 10.0 mm I ~ I [=I~![rñI~_~~C===~~~~=~~- -~=~~=~=~~~=~] t---~K~-~~~--t------------------- -----------------1 [=l~~~~I~ C~==~-=---=~~[~~~~~--=~=~~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ...~ ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I Date RptNo I ~ig Accept - hrs Days Since AccepUEst: 8.8 /1.5 Rig Relase - hrs: AK9421 11/30/98 10 11/22/98 Well: 2L.305 Depth (MDITVD) 8113/5111 Prev Depth MD: 7017 Progress: 1096 Contractor: DOYON Daily Cost $ 141349 Cum Cost $1138278 Est Cost To Date $ Rig Name: DOYON 141 Last Csg: 7.5/8 ~ 2667' Next Csg: Shoe Test: 17.1 Operation At 0600: DRILLING @ 8646' Upcoming Operations: DRILL TO T.D., WlPERTRIP & LOG. MUD DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND 8311 3 N TST 11/29/98 11/27/98 WEIGHT ROT wr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.1 ppg 85 6.75 11/27/98 11/30/98 VISCOSITY puwr MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 52sqc 140 HTC N SPACE 11/29/98 PVIYP sowr TYPE TYPE TYPE FUEL & WATER 11/14 60 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME FUEL USED 1200 5/71 40 0322873 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 1100 4.8 11/30/98 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 125 0.OmV30 min 5000 2705 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 5.0% 5000 5408 2L-329 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP of 10 286bbl 2600 III 27.9/9.4 I 2L-305 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 5 17.5 1 I I I 5 -10 2.5 ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WIND DIRECTlQN 45° 10.0 6111 75 - 600 LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR of 5.90 36.76% 70 III Water Base Muds 789 PIT VOL GPM2 JETS' JETS Fresh Water ARCO PERSONNEL 2 550 300 III 131131131131 I 1I1II 180 Diesel 80 DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 26 $17978 III 26435 0 PERSONNEL 0 TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 6 $130780 III III III 1049 COMPANY MUDwr GRADE GRADE TOT FOR WELL (bbl) SERVICE 15 BAROID 9.11 I I III III PERSONNEL TOTAL 49 TIME I END HOURS I OPS CODE I HOLE SECT I PHASE OPS I OPERATIONS FROM 0000 - 0000 12:00 AM 04:00 AM 4.00 DRIL PROD Making Hole DRLD F/6642-7018' AST 1.2 HR.ART 1.0 HR. 04:00 AM 05:00 AM 1.00 CIRC PROD Other PUMP HI-VIS SWEEP- CIRC BTMS up. OBSERVE WELL- PUMP DRY JOB. 05:00 AM 07:00 AM 2.00 WIPERTRP PROD Other WIPER TRIP TO SHOE. 07:00 AM 07:30 AM 0.50 EVAL PROD Evaluation PERFORM L.O.T. @ SHOE TO 12.1# E.M.W.. 07:30 AM 09:00 AM 1.50 WIPERTRP PROD Other RIH TO 7018'- HOLE IN GOOD SHAPE. 09:00 AM 12:00 AM 15.00 DRIL PROD Making Hole DRLD F17018-8113' AST 1.0HR- ART 8.0 HR CONTROL DRILL @ 100'IHR THRU ICEBERG @ 7730-7737' 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: 2L-305 11/30/98 Page 12 198-240-0 KUPARUK RIV U TARN 2L-305 50- 103-20279-00 PHILLIPS ALASKA_lINC Roll #1: Start: Stop Roll #2: Start Stop MD 09210 TVD 05661 Completion Date: 12/6/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D 8872 2 SPERRY MPT/GR/EWR4/CNP/SLD OH 3/4/99 ~//L DGR/CNP/SLD-MD FINAL 2675-9210' ~/L DGR/CNP/SLD-TVD FINAL 2300-5661 · ~' L DGR/EWR4-MD ~' L DGR/EWR4-TVD i/'L DSI ~'L FMS ~" R SRVY CALC w'/T 9031 FINAL 2675-9210~ FINAL 2300-5661 · FINAL 2668-5120 · FINAL 2668-5120 BHI 0-9210. 1,2 SCHLUM DSIfFMS 3/3/99 OH ~,. · ~ 3/9/99 3/9/99 OH gt ~' 3/9/99 3/9/99 OH ~ ~" 3/9/99 3/9/99 OH ~! .,~ 3/9/99 3/9/99 OH 3/18/99 3/26/99 OH 3/18/99 3/26/99 OH 1/28/99 1/28/99 OH 3/18/99 3/26/99 / Thursday, January 18,2001 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI-~-~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ (Prod -> MWAG Inj) Change approved program _ Pull tubing _ Vadance _ Perforate _ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska Inc Development._X RKB 28 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 150' FNL, 573' FEL, SEC. 22, T10N, R7E, UM 2L-305 At top of productive interval 9. Permit number / approval number 983' FNL, 1285' FEL, SEC. 23, T10N, RTE, UM 98-240 At effective depth 10. APl number 50-103-20279-00 At total depth 11. Field / Pool 1524' FNL, 1124' FEL, SEC. 23, T10N, R7E, UM Tarn Oil Pool 12. Present well condition summary Total depth: measured 9210 feet Plugs (measured) true vertical 5661 feet Effective depth: measured 8690 feet Junk (measured) true vertical 5490 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 108' 16" 9 cu. Yds. High Early 108' 108' Surface 2639' 7-5/8" 330 sx AS III, 235 sx Class 2667' 2290' Production 8341' 5.5" 360 sx Class G 8369' 5245' 830' 3.5" included above 9199' 5656' Liner 8356' 3.5" included above 8384' 5245' Perforation depth: measured 8648' - 8688' true vertical 5388'- 5408' RECEIVED JUL Tubing (size, grade, and measured depth) 3-1/2", 9.3¢, L-80 EUE-8rd, tubing @ 8384' MD. Alaska 0it & Gas Cons. Commission Packers and SSSV (type and measured depth) Baker 80-40 seal assembly @ 8367' MD; No SSSV in place. Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 15, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I here, by certify that the ~g. oing is true and correct to the best of my knowledge. Signed ~ ' b~-'/--..-- ~ Title Tarn Engineer Date J,,s~ _~amh, p,~n FOR COMMISSION USE ONLY Conditions of~pproval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test_ Location clearance__I ~t Mechanical Integrity Test_~ Subsequent form required 10- Approved by order of the Commission .O*'~'"~[-, ''G~'~ ~i'' 7~~'/ :. ~ ~ M~,~r- Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN ,3' TE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 2L-305 NIP (511-512, 0D:3.500) TUBING (0-8384, OD:3.500, ID:2.992) Gas Lift andrelDummy Valve 1 (5283-5284, 0D:4.725) PROD CASING (0-8369, OD:5.500, Wi:23.00) SLEEVE (8257-8258, 0D:4.500) Gas L~t MandrelNalve 2 (8307-8308, OD:4.725) NIP (8359-8360, OD:4.470) SEAL (8367-8368, OD:5.500) 2L-305 APl: 501032027900 Well Type:! PROD SSSV Type: NIPPLE Od§ Completion:~ 12/6/98 Annular Fluid: DSL/SW Last Reference Log: ~ Ref Log Date:i Angle @ TS: 'r deg @ Angle @ TD: :62 deg @ 9210 Rev Reason: iTag fill, cut paraffin i by ImO Last Update: ;4/17/01 Last Tag: 8670 TD: ! 9210 ftKB ' Max Hole Angle: ~66 deg @ 4470 Last Tag Date: i 4/13/01 Casing Stdng- ALL !Description CONDUCTOR SURF CASING PROD CASING PROD CASING Size 16.000 7.625 5.500 3.500 Top = Boffom 0 ~ 108 0 2667 0 8369 8369 9199 'rVD 108 2290 5245 5656 Wt 62.58 45.50 23.00 9.30 Grade H-40 L-80 L-80 1-80 Thread WELDED BTC-MOD BTC-MOD EUE-8RD Tubing String - ALL Size Top Bottom ~ TVD Wt : Grade 3.500 0 8384 5253 9.30 L-80 Thread EUE-8RD Perforations Summary Interval TVD ! Zone :.Statusl Ft !SPFi Date ~ Type i Comment 8648-8688 5388-5408 '. , O ! 40 i 6 i 12/22/98 i IPERF j2.5"HC, BH,60 DEC PH Gas Lift Mandrels/Valves [St= MD iTVD Man ! ~ i Mfr i I I 5283i 3536~ CAMCO ' 2 i 8307! 5213 CAMCO Man Type KBG29 KBG29 VMfr ! VType CAMCO! DMY CAMCO' OV VOD !Latch i Port ! 1.0 , INT ] 0.000 1.0 ' INT ! 0.313 TRO; Date ~ Run 0 ! 12/6/98 0 ~ 9/30/00 Vlv Cmnt Other (plugs, equip., etc.) - JEWELRY i Depth TVD Type Description 511 511 NIP CAMCO DS NIPPLE 8257 5186 SLEEVE BAKER CMU SLIDING SLEEVE; closed 9/30/2000. 8359 5240 NIP CAMCO D NIPPLE 8367 5244 SEAL BAKER 80-40 SEAL ASSY ID 2.87O 2.813 2.750 2.985 Perf (8648-8688) 2L-305 Rpt Date 21-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 22-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 23-Nov-98 24-Nov-98 24-Nov-98 24-Nov-98 24-Nov-98 24-Nov-98 24-Nov-98 24-Nov-98 Start End Hole Section 19:00 24:00 MOVE 00:00 05:00 MOVE 05:00 08:00 SURF 08:00 11:00 SURF 11:00 11:30 SURF 11:30 12:00 SURF 12:00 13:00 SURF 13:00 14:00 SURF 14:00 24:00' SURF 00:00 12:00 SURF 12:00 14:00 SURF 14:00 15:00 SURF 15:00 17:00 SURF 17:00 18:00 SURF 18:00 19:30 SURF 19:30 22:00 SURF 22:00 24:00 SURF 00:00 00:30 SURF 00:30 05:00 SURF 05:00 06:30 SURF 06:30 08:30 SURF 08:30 09:00 SURF 09:00 18:00 SURF 18:00 21:00 SURF Type Op MIRU MIRU NU ND OTHER BOPE OTHER PRB MWD BHA DRIL DRIL DRIL CIRC WIPERTRP PRB HOLE PRB TH PRB HOLE WlPERTRP WlPERTRP CIRC TRIP OUT BHA CASG CASG CIRC TARN PARTICIPATING AREA - 2L-305 Operations PJSM. Move rig to well 2L-305. PJSM. Set in Rig complexes, hook up service lines, Highline power on @ 0300 hrs. Install Divertor spool and fill pits with water. Rig accepted @ 0500 hrs. NU Divertor system and mix spud mud. Load pipe shed, mix spud mud, pu motor and bit. Perform Divertor test, witnessed and approved by Larry Wade (AOGCC). Fill conductor, test mud lines and inspect circulating system for leaks. PU mwd, repair damaged connector in tool. MU mwd, scribe and initialize tool. Drill from 108' to 1149'. ART=3.0 hrs. AST=2.75 hrs. Encountered 1580 units of gas @ 1130'. PJSM. Drill from 1149' to 2460'. ART=2.8 hrs. AST=3.5 hrs. PJSM. Drill from 2460' to 2675'. ART-0.6 hrs AST=0.4 hrs. Pumped high vis sweep and circ clean, monitor well, pump dry job. POH to 520', tight from 859' to 560', very tight from 560' to 550'. Kelly up and work tight spot @ 556', large amounts of fine sand across shakers. Wiped hole to 200', RIH, pipe stopped @ 575', Kelly up. Wash and ream tight hole from 556' to 816'. Large amount of fine sand across shakers. RIH to 2064', tight to 1800'. RIH to 2630' Circ and condition mud. Drill 10' to 2685'. Pump hi vis sweep. Circ hole clean. Trip out of hole to bha Stand back dc's. Download mwd. LID mwd and motor. Clear rig floor R/U casers and hold safety meeting Run 7-5/8" casing to 1028'. Worked thru tight spot from 745' to 800'. Free to 1000' and worked to 1028'. Hole started packing off. LID one jt and circ and condition mud and add lubricant. Pump Io vis/hi vis sweeps Monday, July 02, 2001 - 1 24-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 21:00 24:00 SURF 00:00 00:30 SURF 00:30 04:00 SURF 04:00 04:30 SURF 04:30 05:30 SURF 05:30 06:30 SURF 06:30 08:00 SURF 08:00 09:00 SURF 09:00 09:30 SURF 09:30 12:00 SURF 12:00 12:30 SURF 12:30 13:00 SURF 13:00 13:30 SURF 13:30 14:00 SURF 14:00 15:00 SURF CASG PRB CSG PRB CSG PRB CSG PRB CSG -- PRB CSG PRB CSG -- PRB CSG PRB CSG PRB CSG PRB CSG PRB CSG -- PRB CSG PRB CSG PRB CSG TARN PARTICIPATING AREA - 2L-305 Circulate casing to 1068' and attempt to work deeper. PUMP DRY JOB POH, L/D 7-5/8" CASING. CLEAR FLOOR OF CASING EQUIPMENT. P/U DRILLING/REAMING BHA. RIH & L/D 11 JTS HWDP. REAM F/880-1222' PUMP LO-HI VIS SWEEP. ATTEMPT TO RUN IN HOLE TIGHT @1223', LID 6 JTS DRILLPIPE. REAM F/1222-1535' RIH TO 1956', REAM F/1956-2099' RIH TO 2363' REAM F/2363-2460' RIH TO 2685', no fill on bottom. 25-Nov-98 25-Nov-98 25-Nov-98 25-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 26-Nov-98 27-Nov-98 15:00 17:00 SURF 17:00 21:30 SURF 21:30 23:00 SURF 23:00 24:00 SURF 00:00 00:30 SURF 00:30 01:30 SURF 01:30 02:30 SURF 02:30 05:30 SURF 05:30 08:30 SURF 08:30 10:30 SURF 10:30 11:30 SURF 11:30 13:00 SURF 13:00 13:30 SURF 13:30 14:30 SURF 14:30 16:00 SURF 16:00 16:30 SURF 16:30 17:30 SURF 17:30 18:00 SURF 18:00 19:00 SURF 19:00 22:30 SURF 22:30 24:00 SURF 00:00 04:30 SURF PRB CSG PRB CSG PRB CSG PRB CSG PRB CSG PRB_CSG CASG CASG CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CEMENT CASG NU ND NU ND NU ND NU ND NU ND ClRC BTMS UP TWICE. SHORT TRIP TO 230'(D.CLRS) TIGHT ON TRIP OUT @ 1736'/1641', 1455' on way in @ 1611'/1767'/2082'/2082' (centralizer blade lost on pulling casing dragging up and down hole). CIRCULATE HOLE W/HI-VIS SWEEP. POH TO RUN CSG, Pulled tight @ 2360'. POH W/WIPER-REAMER ASSY. LID D.CLRS, REAMER & BIT. R/U TO RUN SURFACE CSG & PJSM. RUN 7-5~8" CASING. M/U CEMENTING HEAD, CIRC & CONDITION MUD, CUT VISCOSITY F/150-90. TESTED LINES-PUMPED 3 BBL CELLO FLAKES-17 BBLS ARCO PREFLUSH-40 BBL ARCO SPACER @10.5# 237 BBL (330 SX) LEAD CMT- DROP PLUG-49 BBL(235 SX) TAIL CMT-DROPPED TOPPLUG-DISPLACED W/RIG USING MUD TO CALC AMT-BUMPED PLUG- FLOATS HELD NO CEMENT TO SURFACE. RID CMT HEAD & LID LANDING JT. R/U TO PICKUP DRILLPIPE & TAM COMBINATION TOOL- RIH TO 1007' ENGAGE RUNNING TOOL & OPEN PORT COLLAR. ESTABLISH CIRC BUILD TO 4 BPM CEMENT TO SURFACE AFTER 30 BBL CIRC OUT REMAINDER OF CMT TO SURFACE. CMT W/180 BBL(230 SX) LEAD CMT 10.7 PPG GOOD CMT TO SURFACE. POH & LID PORT COLLAR RUNNING TOOL. CLEAR FLOOR OF CASG EQUIPMENT. N/D FLOWLINE- TURN BUCKLES & DRIP PAN EQUIPMENT. ANNULUS CHARGED UP- FILLED CELLAR W/CMT- CLEANED OUT CELLAR. CONTINUED N/D DIVERTER. N/U CSG SPOOL & TBG SPOOL- TEST SPEED HEAD-OK. CONTINUE N/U BOPE. Monday, July 02, 2001 -2 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-§8 27-Nov-98 27-Nov-98 27-Nov-98 27-Nov-98 28-Nov-98 28-Nov-98 28-Nov-98 28-Nov-98 28-Nov-98 28-Nov-98 29-Nov-98 29-Nov-98 30-Nov-98 30-Nov-98 30-Nov-98 30-Nov-98 30-Nov-98 30-Nov-98 01-Dec-98 01-Dec-98 01-Dec-98 01-Dec-98 01-Dec-98 02-Dec-98 02-Dec-98 02-Dec-98 02-Dec-98 02-Dec-98 02-Dec-98 04:30 05:00 09:00 09:30 10:30 11:30 12:00 12:30 13:30 14:30 18:30 19:00 20:30 21:00 22:00 00:00 01:00 02:00 03:00 22:00 23:00 00:00 01:30 00:00 04:00 05:00 07:00 07:30 09:00 00:00 14:00 15:30 20:00 22:00 00:00 02:00 03:30 04:00 04:30 08:00 05:00 09:00 09:30 10:30 11:30 12:00 12:30 13:30 14:30 18:30 19:00 20:30 21:00 22:00 24:00 01:00 02:00 03:00 22:00 23:00 24:00 01:30 24:00 04:00 05:00 07:00 07:30 09:00 24:00 14:00 15:30 20:00 22:00 24:00 02:00 03:30 04:00 04:30 08:00 09:30 SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD BOPE BOPE BOPE BHA TRIP IN REAM TRIP IN CIRC TEST CSG DRIL DRIL ClRC EVAL TRIP OUT BHA BHA TRIP IN RIGS DRIL CIRC WlPERTRP WlPERTRP DRIL DRIL CIRC WlPERTRP EVAL WlPERTRP DRIL DRIL CIRC WIPERTRP CIRC TRIP OUT TRIP OUT BHA BHA EVAL EVAL EVAL TARN PARTICIPATING AREA - 2L-305 R/U TO TEST BOPE. TEST BOPE TO 250PSI LOW-3500 PSI HIGH. INSTALL WEAR BUSHING. M/U MILL-2 BOOT BASKET BHA. R IH TO 426'. WASH CMT STRINGER F/426-526' CONTINUE RIH- TAG CMT @2550' KELLY UP & CBU F/CASING TEST. TEST CASING TO 2000# F/30 MIN. DRILL HARD CEMENT-FLOAT EQUIPMENT & WASH OUT RATHOLE TO 2685'- NO JUNK IN RATHOLE( LOST CENTRALIZER BLADE WHEN PULLING CSG). DRILL 20' NEW FORMATION F/2685-2705'(2311' TVD). DISPLACE WELL TO NEW 9.1 PPG MUD & CONDITION HOLE. PERFORM LEAK OFF TEST- 17.1 PPG E.M.W. (UNABLE TO SHUT PUMP DOWN @ 16.0 F.I.T.. POH F/BHA. M/U BHA ~4.- ORIENT & INITIALIZE MWD/FRT. CONTINUE INITIALIZING MWD & FRT & LOAD SOURCES. RIH TO 2616' CUT & SLIP DRILLING LINE, INSPECT BRAKES. DRLD F/2705-4638' ART 7.7- AST 1.9 HR. SWEEP WELL, CIRC BTMS UP, OBSERVE WELL, PUMP SLUG POH TO SHOE. CONTINUE POH TO 2650' RIH TO 4638' HOLE GOOD. DRLD F/4638-6642' AST 6.5 HR- ART 9.8 HR. DRLD F/6642-7018' AST 1.2 HR-ART 1.0 HR. PUMP HI-VIS SWEEP- CIRC BTMS UP- OBSERVE WELL- PUMP DRY JOB. WIPER TRIP TO SHOE. PERFORM L.O.T. @ SHOE TO 12.1# E.M.W.. RIH TO 7018'- HOLE IN GOOD SHAPE. DRLD F/7018-8113' AST 1.0HR- ART 8.0 HR CONTROL DRILL @ 100'/HR THRU ICEBERG @ 7730-7737' DRLD F/8113-9210' ART 9.65 HR. CONTROL DRILL F/8552-9053' CIRC BTMS UP- OBSERVE WELL (STATIC) PUMP SLUG. WIPER TRIP TO SHOE- NO HOLE PROBLEMS. CIRC BTMS UP- OBSERVE WELL- PUMP SWEEP- PUMP SLUG. POH F/WIRELINE LOGS. FINISH POH TO MWD. REMOVE SOURCES & DOWNLOAD MWD & FRT. LAY DOWN HANG OFF SUB, MWD, FRT- MOTOR & BIT. CLEAR FLOOR & RIG UP SCHLUMBERGER. ATTEMPT WIRELINE LOG #1-TROUBLE IN SURFACE EQUIPMENT- DSI/FMS RIH COULD NOT GET PAST 2824', POH 2ND RUN W/DSI TO 2824' Monday, July 02, 2001 - 3 02-Dec-98 02-Dec-98 02-Dec-98 02-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 03-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 04-Dec-98 05-Dec-98 05-Dec-98 05-Dec-98 05-Dec-98 05-Dec~98 05-Dec-98 05-Dec-98 06-Dec-98 06-Dec-98 06-Dec-98 06-Dec-98 06-Dec-98 06-Dec-98 06-Dec-98 09:30 12:00 12:30 13:30 00:00 03:00 04:00 07:30 10:00 10:30 14:30 15:00 18:30 19:00 20:00 00:00 01:00 01:30 03:30 10:00 10:30 19:00 22:00 00:00 01:30 02:30 03:30 07:30 18:00 18:30 00:00 00:30 01:30 02:30 04:00 05:00 05:30 12:00 12:30 13:30 24:00 03:00 04:00 07:30 10:00 10:30 14:30 15:00 18:30 19:00 20:00 24:00 01:00 01:30 03:30 10:00 10:30 19:00 22:00 24:00 01:30 02:30 03:30 07:30 18:00 18:30 24:00 00:30 01:30 02:30 04:00 05:00 05:30 06:00 PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP EVAL EVAL EVAL EVAL EVAL EVAL EVAL EVAL EVAL EVAL BOPE BOPE BOPE BHA TRIP IN REAM TRIP IN CIRC TRIP OUT -- CASG CASG CEMENT CEMENT CEMENT NU ND RIGS CEMENT EVAL EVAL RUN COMP RUN COMP -- RUN COMP TEST CSG CIRC OTHER RUN COMP -- EVAL TARN PARTICIPATING AREA - 2L-305 3RD RUN W/DSI TO 3475' (LOG UP) LAY DOWN LOGGING TOOLS & RIG DOWN SHEAVES. TRANSFER BHA F/RIGHT TO LEFT HAND SIDE OF DERRICK & RECOVER XO'S SUBS FROM JARS. RIG UP F/DRILLPIPE CONVEYED LOGS- PJSM- P/U 39 JTS DRILLPIPE RIH W/13 STDS- P/U SIDEDOOR ENTRY SUB- LATCH UP- LOG F/2580-4937'. CONTINUE DP CONVEYED LOGGING TO 5123' LOG UP TO 2580' UNLATCH- RETRIEVE WIRELINE & SIDE DOOR ENTRY SUB. RIH TO 4905'. M/U SIDE DOOR SUB- LATCH UP & LOG F/4905-5147' UNABLE TO GET PAST 5147'. UNLATCH- RETRIEVE WIRELINE & SIDE DOOR. POH W/D.P. CONVEYED LOGGING TOOLS & LAY DOWN SAME. PULL WEAR BUSHING. INSTALL TEST PLUG & TEST BOPE INSTALL WEAR BUSHING. LID 18 JTS DRILLPIPE. M/U CLEANOUT BHA #5 & RIH. WASH & REAM F/8715-8876'. RIH F/8876-9210'. PUMP HI-VIS SWEEP & CIRC HOLE CLEAN, OBSERVE WELL, PUMP DRY JOB. POH LAYING DOWN 4" DP - HWDP- D.CLRS & BIT. PULL WEAR RING. R/U F/3-1/2" CSG- PJSM- RUN 3-1/2"- R/U & RUN 5-1/2" CSG- M/U HANGER - LANDING JT & CEMENTING HEAD. BREAK CIRC- STAGE UP TO 5 BPM- CONDITION MUD TOTAL FLUID LOSS UNTIL MUD CONDITIONED 113 BBL. PJSM- TEST LINES 3500# CEMENT W/350 SX CLASS G W/ADDITIVES. CON'T CEMENTING BUMP PLUG @ CALC. DISPLACEMENT W/2000 PSI F/10 MIN- BLED OFF- FLOATS HELD- R/D CEMENTING HEAD & LDG JT. INSTALL 5-1/2" PACKOFF & TEST TO 5000 PSI/10 MIN. SLIP & CUT DRLG LINE. WAIT ON CEMENT & CLEAN MUD PITS. R/U SCHLUMBERGER & RUN DSl (SLOW RUNNING SPEED DUE TO BACKGROUND NOISE). R/D SCHLUMBERGER. RIG UP & RUN 3-1/2" COMPLETION ASSY. CONTINUE RUNNING 3-1/2" TUBING. BREAK CIRC, STING INTO CSR, SPACE OUT. R/U & TEST 5-1/2" CSG TO 3500# F/30 MIN-GOOD. DISPLACE W/CLEAN SEAWATER. FREEZE PROTECT TBG & TBG ANNULUS W/DIESEL TO 2000'. LAND TUBING & LOCK DOWN HANGER. TEST TBG TO 3500# F/10 MIN- TEST ANNULUS TO 3500# F/10 MIN- BOTH TESTS GOOD. Monday, July 02, 2001 - 4 06-Dec-98 06-Dec-98 06-Dec-98 06:00 06:30 COMP NU ND 06:30 08:00 COMP NU ND 08:00 09:00 COMP NU ND TARN PARTICIPATING AREA - 2L-305 L/D LANDING JT & INSTALL TWO WAY CHECK VALVE, NIPPLE DOWN BOP'S. N/U ADAPTER FLANGE & MASTER VALVE- TEST PACKOFF TO 5000# F/10 MIN. RELEASE RIG @ 0900 HR 12/06/98. Monday, July 02, 2001 - 5 1 Cementing Summary Dowell Admin Data Well Number: Field: 2L-305 Company: Arco Alaska Date: 6/27/01 Tarn Company Rep: Tom Brassfield String: Production Well Data TMD Bit Size Top of Cement Fluid Properties 1 Fluid Density 9,418' Type of Casing 5-1/2 x 3-1/2 Spacer 12.0 ppg 6-3/4" Top of 3-1/2 ~',~'9~-~ il Cement 15.8 ppg 7,900 ft Fracture Gradient 0.65 psi/ftI Mud 9.8 ppg Vise 55 Pumping Schedule Y Fluid JCement around 3-1/2 in. casing (1,020 ft) (0.1817 cf/fi) (150%) = 278 ctI Fresh Water 0.0 bbls JCement around 5-1/2 in. casing (498 ft) (0.0835 cf/ft) (150%) = 62 ct] ARCO Wash 20.0 bbls JCement for Shoe Joint (90 ft) (0.0474 cf/ft) = 4 c~J ARCO Spacer 40.0 bbls JTotal Cement 345 c '1 Cement 54.0 bbls JSacks required (345 cf) /(1.20 cf/sx) = 287s×I Seawater 246 bbls JAllowing for excess/bottoms 310 sxI System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% DS00 (ret.) Cement Adds GasBLOK Spacer and Mud I Notes I Recommended Mud Properties J To Optimize mud removal in effective laminar flow, using the Density 9.8 ppg proposed centralizer program, recommeded mud conditions Yield Point 16 outlined to right. Plastic Viscosity ~ Centralizers Section # per joint Funnel Viscosity 3-1/2" by 6-1/2" OD Rigid ROTCO Turbolizer 3-11Z' Casing 1 Mud -Displacement 1-5 'BPM 5-1/2" Weatherford Bl102551 Bow Spring 5-11Z' Casing I /Cement Rates 5.0 BPM *Above this rate formation breakdown could occur. fMComments aximum 9.8 ppg Mud (Pv 18, Ty 16) recommended circulating rate to avoid losses is 6.0 BPM (from CemCADE wellbore hydraulics calculations). Minimal U-tubing is expected while cementing, for first 3-5 minutes of displacement at 5 bpm. Maximum recommended rate during cementing to avoid losses is 5.0 BPM, as long as 1:1 returns can be maintained.. As low a rate as 2-3 BPM may be required towards end of displacement to avoid losses. Make efforrts to maintain 1:1 returns. Expected Surface Pressure with top plug at float collar is 1250 psi with seawater displacement. BKD 6/27/01,3:23 PM Office 265-6205, Cellular 223-5148, Home 694-2770 Tubing Detail 3-I/2" Production Tubing WELL: TARN 2L-305 ARCO Alaska, Inc. DATE: 12/05198 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RKB to Tubing Hanger LDS = 23.40' 23.40 FMC Gen V 5m, 3.5" Hanger w/3.5" EUE pup 3.28 23.40 pups Space out pup. 3.5", 9.3#, L-80,8.16', 8.12', 4.06' 18.20 26.68 Jts.249-263 3.5", 9.3#, 8 rd EUE Mod tubing (14 its) 466.78 44.88 2.875" CAMCO DS 3.5" EUE Mod 8rd Box X Pin 1.58 511.66 Jts.97-248 3.5", 9.3#, 8 rd EUE Mod tubing (166 its) 4755.65 513.24 XO 3.5" BTC Pin x 3.5" 9.3 ppf 8rd EUE Mod Box 14.62 5268.89 GLM #2 Camco 3.5" X 1", KBG-2-9,,3.5"BTC box X pin,w/ Int. DV. 6.63 5283.51 XO 3.5" BTC Pin x 3.5" 9.3 ppf 8rd EUE Mod Pin 14.16 5290.14 Jts#3-96 3.5", 9.3#, 8 rd EUE Mod tubing (140 its) 2952.74 5304.30 Baker CMU Sliding Sleeve, 8rd EUE Mod w/2.813" Camco profile 3.91 8257.04 Jt.#2 3.5", 9.3#, 8 rd EUE Mod tubing 31.40 8260.95 ×O 3.5" BTC Pin x 3.5" 9.3 ppf 8rd EUE Mod Box 14.68 8292.35 GLM #1 Camco 3.5" X '1", KBG-2-9,,3.5"BTC box X pin,w/ Int. DV. 6.63 8307.03 ×O 3.5" BTC Pin x 3.5" 9.3 ppf 8rd EUE Mod Pin 14.23 8313.66 Jt.#1 3.5", 9.3#, 8 rd EUE Mod tubing 31.29 8327.89 CAMCO 2.75" D nipple .99 8359.18 pup 6' Handling Pup Joint 3.5" 9.3 ppf 8rd EUE Mod 6.15 8360.17 Locator Baker 5.5", 80-40 Csg Seal Assy, 4.00" OD X 2.985" ID.Locator .80 8366.32 Seals 15' effective seal stroke w/3.5" 9.3 ppf 8rd EUE Mod Box 16.97 8367.12 TUBING TAIL AT >>>>> 8384.09 Note: Tagged top of CSR spaced out with Iocator sub 2' above CSR. Remarks: String Weights with Blocks: 75K# Up,40K# Dn,12k~ Blocks. Ran 263 its of 3-1/2" tubing Drifted tubing with 2.867" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Tubing is non-coated. Doyon 14 ~ Drilling Supervisor: R.W. SPRINGER " ( ~' ~, ,"~. ,-- ~:~ :O~p;:::r PM ~ It ", To: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us, Brian D Noel/PPCO@Phillips "';;., , " ' cc: Jason Putnam/PPCO@Phillips,SatellitesProd Engrs/PPCO@Phillips,StephenBross/PPCO@Phillips .. Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tarn Field development. Attendance: AOGCC Tom Maunder Bob Crandall Phillips Jeff Spencer Brian Noel RECEiVED JUL ;j 11001 Well 2L-317 A: (New Injection Well) '-- dc:L>"- d \ è) Ala$kiOil & Gas Cons C'omm' . . 185100 Anchorage Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to during an April 19th meeting. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. 2. Establish injection into the well using water from a pump truck/transport at 1-2 BPM. Note: The expected maximum water injection rate into 2L-317A is <3000 BWPD. 3. Run WFL to determine if there is any behind pipe upward flow out of the Bermuda interval. 4. Review WFL with AOGCC. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix. The WFL did not show any upward flow and was reviewed with AOGCC personnel on June 13th. Once we provide copies of the WFL and a completed Sundry Form 403, we can proceed with Steps #5,6 & 7, as outlined below. Note: Copies of the CBL, wellbore schematic and details of primary cement job were previously provided to AOGCC. 5. If no upward flow is detected, add perforations in the net pay intervals below the initial perforations and complete well as an MWAG injector. Note: Leave well SI until water is available for injection. 6. Commence water injection at normal operating rates and monitor daily rates & pressures. Note: Injection rates and pressure data are to be reported on a monthly basis similar to other MIT waivered injection wells. of .. ..¡1' I, ( 7. After 2-3 months of water injection, run another WFL log to confirm that injection is staying within desired interval. AOGCC prefers WFL be run after 3 months of water injection. 8. If second WFL shows no upward flow or behind pipe channelling, commence normal MWAG operations after reviewing log with AOGCC. Producer-to-Injector Conversions: 2L-305 )98 ' ¿)) J-fO ~ Reviewed CBL on 2L -305 with AOGCC and it showed excellent bonding throughout the zone of interest. Approval to convert to MWAG injector will be forthcoming from AOGCC once we provide copies of the CBL, wellbore schematic, primary cement job information and a completed Sundry Form 403. Note: Future P-to-I Conversion candidates showing good cement bonding can be submitted for approval directly to the AOGCC (with appropriate supplementary information as shown above). 2N-326 ::- dCO " (SS Reviewed CBL on 2N-326 with AOGCC and it showed what appeared to be contaminated cement throughout the zone of interest. The VOL indicated some bonding to the formation but either due to weak compressive strength of the cement and/or incorrect CBL tool settings, the bond to the pipe appeared relatively poor. So although the CBL provides some evidence of cement behind pipe and it was our recollection that the frac job went as planned, the AOGCC requested that we run a WFL to ensure no upward flow above the Tarn producing horizon (Bermuda interval). Therefore, the action plan for 2N-326 is as follows: 1. Establish injection into the well using water from a pump truck/transport at 4 - 5 BPM. Note: The expected maximum water injection rate into 2N-326 is'" 7000 BWPD. 2. Run WFL to determine if there is any behind pipe upward flow above the Bermuda interval. Note: This well was fracture stimulated from a 10' perf interval near the base of the Bermuda. 3. If upward flow is detected above the Bermuda interval, determine an appropriate remedial fix and review with AOGCC. 4. If no upward flow is detected, send copies of the CBL, WFL, well bore schematic, fracture stimulation summary, primary cementing information and Sundry Form 403 to AOGCC. 5. Upon receiving approval from AOGCC, complete well as an MWAG injector. Other Tarn P-to-I Conversion candidates will follow procedures similar to those outlined above for receiving approval from AOGCC. Thanks again for taking the time to meet with us and have a great week, Jeffrey A. Spencer Tarn Development Coordinator Phillips Alaska, Inc. 907 -265-6813 jspencer@ppco.com Jason Putnam 07/02/01 01:39 PM To: tom_maunder@admin.state.ak.us, bob_crandall@admin.ak.us cc: Subject: Tarn Development - AOGCC Meeting Notes (06/13) Mr. Maunder, We are ready to move forward on the P to I conversion of 2L-305 and also the final well work (perforations) to begin injecting water into 2L-317A. I will drop off the 403 Sundry Forms for both wells along with the additional requested information to your office today. If you have any questions please don't hesitate to call. Thank you, Jason D. Putnam Tarn Surveillance Engineer Phillips Alaska Inc. (907) 265-6970 JUL 0 Forwarded by Jason Putnam/PPCO on 07/02/01 01:43 PM ..... Alaska Oil & Gas Cons Anchorag-e' Cornrnission ~A Jeff A Spencer ~1~~06/18/01 05:39 PM IF' ':.~ To: tom maunder@admin.state.ak.us, bob crandall@admin.ak.us, Brian D Noel/PPCO@Phillips cc: Jas~'n Putnam/PPCO@Phillips, Satellites Prod Engrs/PPCO@Phillips, Stephen Bross/PPCO@Phillips Subject: Tarn Development - AOGCC Meeting Notes (06/13) Gentlemen, Please find below a summary of what was discussed at last Wednesday's (06/13) meeting regarding Tarn Field development. A~endance: AOGCC Phillips Tom Maunder Jeff Spencer Bob Crandall Brian Noel Well 2L-3'17A: (New Injection Well) Because a CBL showed poor cement bonding in and immediately above the Bermuda interval, an alternative method was proposed by Phillips to demonstrate zonal isolation using a Water Flow Log (WFL). After reviewing the CBL, cement job data and other completion related information, the following plan was agreed to during an April 19th meeting. Note: Provide a detailed procedure, wellbore schematic, copy of CBL, details on the initial 2L-317A cement job, and a completed Sundry Form 403 to AOGCC prior to commencing any field work. 1. Perforate a 5' interval approximately 70' MD below the top of the Bermuda interval (T3). Projected depths of the initial perfs are expected to be 12182-12187' MD. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp,q/~,/u~ ~,, SUBJECT: Petroleum Irffspector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tarn, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorC¥CL~ }2L~'305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70' 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [] 90 r>av Remarks: 7/97/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc'xls ARCO Alaska, Inc. " Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 27, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2L-305 (Permit No. 98-209) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2L-305. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Drilling Team Leader AAI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS ~] SUSPENDED E~ ABANDONED~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-240 3 Address 8 APl Number P.O. Box '100360, Anchora~le, AK 99510-0360 50-'103-20279 4 Location of well at surface 9 Unit or Lease Name 150'FNL, 573'FEL, Sec. 22, T10N, RTE, UM :~. [ :..i,.:;'..~! : ~~'~.~:~'~ Kuparuk River Unit 983' FNL, 1285' FEL, Sec. 23, T10N, R7E, UM ~.~yd.~ ~ 2L-305 At Total Depth ~r "~ ~'3.' ..... ,,. ~~ 11 Field and Pool 1524' FNL, 1124' FEL, Sec. 23, T10N, R7E, UM ~¢-~~' KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 117' ADL 380051 ALK 4599 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Depth, if offshore 16 No. of Completions 22-Nov-98 01-Dec-98 06-Dec-98~ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 9210' MD & 5661' TVD 9071' MD & 5597' TVD YES ~ NO ~ NA feet MD 1050 APPROX 22 Type Electric or Other Logs Run G~Res/Neu/Dens, CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD J CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENf BECORD 16" 62.5~ H-40 SURF. 108' 24" 9 cu yds High Early 7.625" 29.7~ L-80 SURF. 2667' 9.875" 330 sx AS III, 235 sx Class 5.5" x 15.5¢ L-80 SURF. 8390' 6.75" 360 sx Class G 3.5" 9.3¢ L-80 8390' 9200' 6.75" (included above) 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER SET (MD) 3.5" 8384' 8369' (CSR) 8648'-8688' MD 5388'-5408' TVD 6 spf 26 ACID, F~CTURE, CEMENT SQUE~E, ~C DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8648'-8688' MD see a~achment 27 PRODUCTION TEST__ RiGINAL Date First Production Method of Operation (Flowing, gas lift, etc.) U ~j 1/2~99 Flowing Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL~~ Mil ~ ~S Anchora~ ~/2~e9 12 TEST PERIOI: 502 876 58 0~ 1004 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (corr) Press. 310 0 24-HOUR RATE: ] ~3 ~7 116 37° 28 CORE DATA Brief descriptign of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-]-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 8563' 5345' T-2 8748' 5439' Annulus left open - freeze protected with diesel. 31. LIST OF AI-DACHMENTS Summary of Dally Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~.,~~/'/~ Title ~0~d,~. -~'1 L4~-~fi"~ DATE ~/~'~ ~ (] ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/25/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2L-305 WELL ID: AK9421 TYPE: AFC: AK9421 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KU?ARUK RIVER UNIT SPUD:ill22/98 START COMP: RIG:RIG # 141 BLOCK: FINAL: WI: 0% SECURITY:0 AP1 NUMBER: 50-103-20279-00 11/21/98 (D1) TD: 108' ( 108 SUPV:D.BURLEY 11/22/98 (D2) TD: 1149' (1041 SUPV:D.BURLEY 11/23/98 (D3) TD: 2675'(1526 SUPV:D.BURLEY 11/24/98 (D4) TD: 2675'( 0) SUPV:G.R. WHITLOCK 11/25/98 (D5) TD: 2685'( 10) SUPV:R.W. SPRINGER 11/26/98 (D6) TD: 2685' ( 0) SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIGGING UP, MIXING SPUD MUD. APIWL: 0.0 Move rig to well 2L-305. MW: 10.1 riSC: 118 PV/YP: 27/34 DRILLING FROM 1850' APIWL: 7.2 Rig accepted @ 0500 hrs. 11/22/98. NU diverter and perform diverter test. Drill from 108' to 1149' MW: 10.2 VISC: 180 PV/YP: 17/40 POH FOR CASING. APIWL: 3.8 Drill from 1149' to 2675' POH, tight from 859' to 550' Large amounts of the sand across shakers. Wash and ream tight hole from 556' to 816' MW: 10.0 VISC: 98 PV/YP: 29/37 APIWL: 3.4 RIH W/ CLEANOUT BHA RIG/CAMP ON HIGHLINE 24 HRS Drill to 2685' Run 7-5/8" casing. Worked thru tight spot from 745' to 800'. Freee to 1000' and worked to 1028'. Hole started packing off. MW: 10.0 VISC: 154 PV/YP: 37/52 RUNNING 7-5/8" CASING APIWL: 3.0 RIH w/reaming BHA. Ream from 880'-1222'. Attempt to run in hole tight @ 1223'. Ream 1222'-1535'. Ream from 1956' to 2460'. MW: 10.1 VISC: 96 PV/YP: 28/29 TESTING BOPE APIWL: 3.4 Run 7-5/8" casing. Pump cement. Date: 1/25/99 11/27/98 (D7) TD: 2685' ( 0) SUPV:R.W. SPRINGER 11/28/98 (D8) TD: 4638' (1953) SUPV:R.W. SPRINGER 11/29/98 (D9) TD: 7017' (2379) SUPV:R.W. SPRINGER 11/30/98 (Ol0) TD: 8113' (1096) SUPV:R.W. SPRINGER 12/01/98 Dll) TD: 9210' 1097) SUPV:R.W. SPRINGER 12/02/98 D12) TD: 9210' 0) SUPV:R.W. SPRINGER 12/03/98 D13) TD: 9210' 0) SUPV:R.W. SPRINGER 12/04/98 D14) TD: 9210' 0) SUPV:R.W. SPRINGER ARCO ALASKa% INC. WELL SUMMARY REPORT Page: 2 MW: 9.1 VISC: 50 PV/YP: 50/10 DRILLING 6-3/4" HOLE @ 3099' APIWL: 9.8 Test BOPE to 250/3500 psi. Drill hard cement, float equipment and wash out rathole to 2685' Drill 20' new formation from 2685' .to 2705' Perform LOT, 17.1 ppg EMW. MW: 9.1 VISC: 55 PV/YP: 15/18 DRILLING @ 5012' APIWL: 5.0 Drilled from 2705' to 4638' MW: 9.1 VISC: 58 PV/YP: 17/22 WIPER TRIP APIWL: 4.6 Drilled from 4638' to 6642' MW: 9.1 VISC: 52 PV/YP: 11/14 DRILLING @ 8646' APIWL: 4.8 Drilled from 6642' to 7018' Perform LOT, 12.1% EMW. Drilled from 7018' to 8113' MW: 9.8 rISC: 51 PV/YP: 13/15 RIH W/SONIC LOG APIWL: 2.8 Drilled from 8113'-9210'. Control drill from 8552'-9053' CBU. Observe well (static) pump slug. No hole problems. MW: 9.9 VISC: 51 PV/YP: 17/17 D.P. CONVEYED LOGGING. APIWL: 4.2 Attempt wireline log %1, trouble in surface equipment, DSI/FMS RIH could not get past 2824' 2nd run w/DSI to 2824' 3rd run w/DSI to 3475'. RIH w/drillpipe conveyed logs and log from 2580' to 4937' MW: 9.9 VISC: 51 PV/YP: 14/16 POH LAYING DOWN DRILLPIPE APIWL: 4.8 Continue DP conveyed logging to 5123'. Log from 4905'-5147'. Unable to get past 5147'. RIH w/cleanout BHA. MW: 9.8 VISC: 43 PV/YP: 15/11 RIGGING UP SCHLUMBERGER APIWL: 5.4 wash and ream from 8715' to 9210'. Run 3.5" and 5.5" casing. Pump cement. Date: 1/25/99 12/05/98 (D15) TD: 9210' ( 0) SUPV:R.W. SPRINGER 12/06/98 (D16) TD: 9210'( 0) SUPV:R.W. SPRINGER ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 8.6 VISC: 0 PV/YP: 0/ 0 RIG RELEASED PREPARING TO MOVE. APIWL: 0.0 Continue cementing, bump plug. Run DSI. Run 3.5" completion assembly. MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED MOVED TO 2L-315 APIWL: 0.0 Continue running 3.5" tubing. Freeze protect well. ND BOPs. NU master valve and test packoff to 5000%. Release rig @ 0900 hrs. 12/6/98. Date 12/21/98 Well Name 2L-305 Service Type ELECTRIC LINE Desc of Work INITIAL PERFORATIONS. Supervisor SMITH Complete [~ Accident I-~ Injury I-~ Spill I~1 Summary Uj~.~ming Job Num 1213981616.5 Unit 2158 Contractor Key Person Successful [~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 0 CYCA AFC K85106 1 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED 8648'-8688' WITH SWS 2.5" HOLLOW CARRIER, 6 SPF, BH CHARGES, 60 DEG. PHASING. [Per'f] Prop 180KNU2 Upl~)aded to S Date printed: 01125199 at: 16:29:16 Date 12/26/98 Well Name 2L-305 Service Type Desc of Work Supervisor RIGGS Complete Accident Injury [~] Spill Summary PUMPING CAPITAL FRAC U¢¢omJng Job Num Unit 1222981704.1 Contractor Key Person Successful Initial Tbg Press 245 Initial Int Csg Press 250 Initial Out Csg Press 0 AFC K85106 0 Final Tbg Press 200 Final Int Csg Press 250 Final Out Csg Press 0 Prop 180KNU2 Uploaded to S PUMPED FRAC PER PROCEDURE W/50 # XL DELAYED GEL @ 15 BPM AND AVG. PRESSURE OF 3000 PSI . PUMPED 226,937 LBS OF PROP W/201,983 LBS AND 10 PPG IN PERFS. LEFT 24,954 LBS IN 3.5" TBG. MAX PRESSURE ON JOB 6550 PSI. DID NOT LOOK LIKE A SCREEN OUT. EXPECT TUBING TO BE FULL DID NOT PUMP ANY FLUSH. [Frac-Refrac] Date printed: 01/25/99 at: 16:29:41 i~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451.02512 S~detrack No. Page 1 of 5. Company ARCO ALASKA, INC. Rig Contractor & No. Doyon - 141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 21_/305 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~rr~l~ WELL DATA Target'l'VD (FT) Target Coord. N/S Slot Coord. N/S -149.44 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord, E/W Slot Coord. E/W -572.98 Magn. Declination 26.792 Calculation Method MINIMUM CURVATURE ._ Target Direction (DD) Build\Walk\DL per: lOOftr~ 30m~ 1omD Vert. Sec. Azim. 107.98 Magn. to Map Corr. 26.792 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) (DD) (FT) (FT) (FT) (F'~ (Per 100 FT Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 22-NOV-98 MWD 108.00 0.00 0.00 108.00 108.00 0.00 0.00 0.00 0.00 0.00 "' 22- NOV-98 MWD 218.24 0.39 55.78 110.24 218.24 0.23 0.21 0.31 0.35 0.35 22-NOV-98 MWD 309.69 0.50 76.75 91.45 309.69 0.76 0.48 0.96 0.21 O. 12 22-NOV-98 MWD 401.86 0.29 38.97 92.17 401.85 1.19 0.75 1.49 0.35 -0.23 22-NOV-98 MWD 496.84 0.34 25.31 94.98 496.83 1.31 1.19 1.77 0.09 0.05 22-NOV-98 MWD 584.35 2.23 20.30 87.51 584.32 1.41 3.02 2.47 2.16 2.16 22-NOV-98 MWD 875.00 4.05 32.22 90.65 674.83 2.27 7.39 4.79 2.12 2.01 22-NOV-98 MWD 770.46 6.55 37.82 95.46 769.87 4.95 14.54 9.92 2.67 2.62 5.87 22-NOV-98 MWD 860.70 9.03 35.58 90.24 859.27 8.84 24.37 17.20 2.77 2.75 -2.48 22-NOV-98 MWD 953.11 12.00 30.58 92.41 950.12 13.13 38.54 26.31 3.36 3.21 -5.41 22-NOV-98 MWD 1042.25 15.41 28.33 89.14 1038.71 17.28 56.95 36.65 3.87 3.83 -2.52 23-NOV-98 MWD 1132.96 19.04 31.07 90.71 1123.34 22.80 80.24 50.01 4.10 4.00 3,02 ,_ 23-NOV-98 MWD 1221.53 21.11 34.26 88.57 1206.53 · 30.54 105.80 66.44 2.64 2.34 3.60 23-NOV-98 MWD 1317.06 23.32 38.89 95.53 1294.97 42.11 134.74 88.00 2.95 2.31 4.85 23-NOV-98 MWD 1412.24 25.37 41.44 95.18 1381.68 56.96 164.69 113.33 2.42 2.15 2.68 23-NOV-98 MWD 1505.65 28.15 45.30 93.41 1465.09 75.04 195.20 142.24 3.51 2.98 4.13 23-NOV-98 MWD 1599.35 30.38 48.31 93.70 1546.83 97.16 226.51 175.65 2.85 2.38 3.21 23-NOV-98 MWD 1694.50 32.99 52.59 95.15 1627.80 124.03 258.26 214.21 3.62 2.74 4.50 23-NOV-98 MWD 1787.48 35.17 56.19 92.98 1704.81 154.98 288.55 256.58 3.19 2.34 3.87 -- 23-NOV-98 MWD 1882.07 38.06 60.95 94.59 1780.74 191.71 317.88 304.72 4.28 3.06 5.03 23-NOV-98 MWD 1975.90 41.09 63.33 93.83 1853.06 233.38 345.77 357.57 3.61 3.23 2.54 -- 23-NOV-98 MWD 2069.83 42.79 64.77 93.93 1922.93 278.59 373.23 414.02 2.08 . 1.81 1.53 23-NOV-98 MWD 2165.13 45.31 69.36 95.30 1991.44 328.67 398.97 475.03 4.27 2.64 4.82 " ' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02512 Sidetrack No. Page 2 of 5,' Company ARCO ALASt/,.A. lNG. Rig Contractor & No. Doyon- 141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/305 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~Jlilr~/~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -149.44 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SS~- Target Description Target Coord. ENV Slot Coord. E/VV -572.98 Magn. Declination 26.792 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft[~ 30mD 10mD Vert. Sec. Azim. 107.98 Magn. to Map Corr. 26.792 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'D (F'T) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 23-NOV-98 MWD 2258.20 48.84 70.27 93.07 2054.81 382.26 422.47 538.99 3.86 3.79 0.98 · 23-NOV-98 MWD 2353.06 51.70 71.21 94.86 2115.44 440.34 446.52 607.85 3.11 3.01 0.99 23-NOV-98 MWD 2444.95 53.77 72.45 91.89 2171.08 499.39 469.31 677.34 2.50 2.25 1.35 23-NOV-98 MWD 2539.27 56.52 71.33 94.32 2224.98 561.92 493.38 750.89 3.07 2.92 -1.19 28-NOV-98 MWD 2683.74 61.82 71.09 144.47 2298.99 661.25 533.33 868.29 3.67 3.67 -0.17 28-NOV-98 MWD 2780.09 62.68 72.26 96.35 2343.86 729.97 560.14 949.23 1.40 0.89 1.21 28-NOV-98 MWD 2872.04 62.87 72.16 91.95 2385.92 796.31 585.12 1027.08 0.23 0.21 -0.11 28-NOV-98 MWD 2965.93 63.12 71.09 93.89 2428.55 863.68 611.49 1106.47 1.05 0.27 -1.14 28-NOV-98 MWD 3061.25 63.50 71.70 95.32 2471.37 932.06 638.66 1187.18 0.70 0.40 0.64 28-NOV-98 MWD 3155.26 61.86 70.76 94.01 2514.51 998.98 665.53 1266.26 1.96 -1.74 -1.00 28-NOV-98 MWD 3250.97 61.74 74.33 95.71 2559.75 1067.69 690.82 1346.71 3.29 -0.13 3.73 28-NOV-98 MWD 3345.01 61.87 74.06 94.04 2604.19 1136.58 713.40 1426.46 0.29 0.14 -0.29 28-NOV-98 MWD 3438.91 62.23 73.95 93.90 2648.20 1205.36 736.25 1506.19 0.40 0.38 -0.12 28-NOV-98 MWD 3534.21 62.87 73.82 95.30 2692.13 1275.40 759.73 1587.44 0.68 0.67 -0.14 28-NOV-98 MWD 3627.21 63.39 74.35 93.00 2734.16 1344.26 782.48 1667.22 0.76 0.56 0.57 · 28-NOV-98 MWD 3718.36 60.86 72.47 91.15 2776.78 1410.61 805.46 1744.43 3.32 -2.78 28-NOV-98 MWD 3811.97 60.85 73.97 93.61 2822.37 1477.77 829.07 1822.70 1.40 -0.01 1.60 28-NOV-98 MWD 3906.35 59.16 71.93 94.38 2869.55 1544.70 853.02 1900.84 2:59 -1.79 -2.16 28-NOV-98 MWD 4000.30 58.49 72.56 93.95 2918.19 1609.95 877.53 1977.40 0.92 -0.71 0.67 28- NOV-98 MWD 4092.70 58.69 69.66 92.40 2966.35 1673.03 903.06 2052.00 2.69 0.22 -3.14 i 28-NOV-98 MWD 4187.30 60.59 66.60 94.60 3014.17 1735.66 933.48 2127.72 3.44 2.01 -3.23 28-NOV-98 MWD 4282.24 61.25 64.76 94.94 3060.32 1797.03 967.65 2203.33 1.83 0.70 -1.94 _ . 28- N OV-98 MWD 4375.44 63.44 67.81 93.20 3103.58 1858.67 1000.83 2278.90 3.73 2.35 3.27 28-NOV-98 MWD 4469.96 65.77 67.37 94.52 3144.11 1923.70 1033.38 2357.83 2.50 2.47 -0.47 i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02512 Sidetrack No. Page 3 of i i · '- Ll[~ '- I =/t~"~ Company ARCO ALASKA, lNG. Rig Contractor & No. Doyon - 141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 21_/305 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN I~I1~"~1~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -149.44 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSD Target Description Target Coord. E/W Slot Coord. E/W -572.98 Magn. Declination 26.792 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10mo Vert. Sec. Azim. 107.98 Magn. to Map Corr. 26.792 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~-r) (DD) (DD) (F'I') (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 28-NOV-98 MWD 4566.35 63.82 70.00 96.39 3185.17 1991.17 1065.09 2439,06 3.19 -2.02 2.73 29-NOV-98 MWD 4660,79 62.10 72,99 94.44 3228,11 2058.78 1091.80 2518.80 3.36 -1.82 3.17 . 29-NOV-98 MWD 4755.59 61,34 74.49 94.80 3273.02 2127.79 1115.18 2598.95 1.61 -0,80 1,58 29-NOV-98 MWD 4848.26 61.28 80,65 92.67 3317.54 2197.85 1132.66 2678.28 5.83 -0.06 6.65 29-NOV-98 MWD 4941.01 61.43 84.84 92.75 3362.02 2271.45 1142.94 2759.00 3.97 0,16 4.52 29-NOV-98 MWD 5037.65 60.28 88.76 96.64 3409.10 2350.13 1147;66 2843.24 3,74 -1.19 4.06 29-NOV-98 MWD 5131,05 59.05 88.78 93.40 3456.27 2426,25 1149,39 2923,84 1.32 -1.32 0.02 29-NOV-98 MWD 5223.81 58.68 90.63 92.76 3504,24 2501.64 1149.80 3003.23 1,75 -0.40 1,99 29-NOV-98 MWD 5315.79 57.50 94.56 91.98 3552,87 2576,89 1146,29 3081.20 3.85 -1.28 4.27 29-N OV-98 MWD 5411.13 56.37 97.05 95,34 3604.89 2654.98 1138.22 3160.68 2.49 -1.19 2.61 29-NOV-98 MWD 5505.20 55.22 99.80 94.07 3657.78 2731.68 1126.83 3237.63 2.71 -1.22 2.92 29-NOV-98 MWD 5595.37 54.53 101.72 90.17 3709.66 2804.84 1113,07 3310.08 1.90 -0.77 2.13 29-NOV-98 MWD 5689.87 53.55 104,51 94,50 3765,16 2881.04 1095.73 3384.56 2.60 -1.04 2.95 29-NOV-98 MWD 5783.12 53.18 108.27 93,25 3820.82 2955.82 1074.63 3456.33 3.26 -0.40 4.03 -- 29-NOV-98 MWD 5876.20 52,96 112.17 93.08 3876.76 3030.14 1048.92 3526.13 3.36 -0.24 4.19 29-NOV-98 MWD 5970.94 53.51 114.57 94.74 3933.47 3105.69 1018.82 3595,79 2.11 0.58 2,53 29-NOV-98 MWD 6065.32 53.50 117,68 94,38 3989,61 3180.78 985.41 3663.89 2.65 -0.01 3.30 29-NOV-98 MWD 6157.75 54.02 121.46 92.43 4044.26 3253.79 948.63 3728.71 3.35 0.56 4.09 29-NOV-98 MWD 6252.33 53.40 124.26 94.58 4100.25 3327.46 907.28 3792,74 2.47 -0.66 2.96 29-NOV-98 MWD 6346.89 53.08 128.07 94.56 4156.85 3399.41 862,59 3853,88 3.25 -0.34 4.03 -- 29-NOV-98 MWD 6440.72 51.45 132.08 93.83 4214.29 3468.15 814,86 3910,66 3.80 -1.74 4,27 -- 29-NOV~98 MWD 6536.01 51.34 137.78~ 95,29 4273.78 3534.48 762,31 3963.34 4.68 -0.12 5.98 29-NOV-98 MWD 6634,30 52.07 140.18 98.29 4334.69 3600.59 704,11 4013.96 2.06 0.74 2.44 29-NOV-98 MWD 6729.79 53.93 144.50 95,49 4392.18 3663.49 643.74 4060.51 4.10 1,95 4.52 [~ SURVEY CALCULATION AND FIELD WORKSHEET job No. 0451_02512 S~detrack No. Page 4 of 5~.._ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon - 141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/305 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~lrr~/=~ WELL DATA Target'l'VD (FT) Target Coord. N/S Slot Coord. N/S -149.44 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~] SSD Target Description Target Coord. E/W Slot Coord. E/W -572.98 Magn. Declination 26.792 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~] 10mo Vert. Sec. Azim. 107.98 Magn. to Map Corr. 26.792 Map North to: OTHER SURVEY DATA _ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DD) (DD) (FT) (FT) (F-r) (FO (Per 100 FO Drop (-) Left (-) 30-N OV-98 MWD 6823.53 55.79 149.32 93.74 4446.15 3723.07 579.54 4102.30 4.65 1,98 5.14 -- ,, 30-N OV-98 MWD 6917.53 56.02 152.46 94.00 4498.85 3780.07 511.54 4140.16 2.78 0.24 3.34 30-NOV-98 MWD 7009.31 56.88 153.02 91.78 4549.57 3834.38 443.54 4175.19 1.07 0.94 0.61 30-NOV-98 MWD 7103.03 57.19 158.08 93.72 4600.59 3887.40 372.00 4207.72 4.54 0.33 5.40 30-NOV-98 MWD 7192.24 57.76 162.01 89.21 4648.57 3933.62 301.32 4233.37 3.77 0.64 4.41 30-NOV-98 MWD 7286.41 59.73 164.17 94.17 4697.43 3979.65 224.30 4256.77 2.87 2.09 2.29 30-NOV-98 MWD 7380.90 60.19 163.28 94.49 4744.74 4025.69 145.78 4279.69 0.95 0.49 -0.94 30- NOV-98 MWD 7474.43 61.07 162.28 93.53 4790.6i 4072.68 67.93 4303.83 1.32 0.94 -1.07 30-NOV-98 MWD 7569.17 61.43 162.97 94.74 4836.18 4120.74 -11.34 4328.63 0.74 0.38 0.73 30-NOV-98 MWD 7663.16 62.59 161.97 93.99 4880.29 4168.95 -90.48 4353.63 1.55 1.23 -1.06 30-NOV-98 MWD 7757.83 61.65 164.03 94.67 4924.56 4216.92 -170.49 4378.10 2.16 -0.99 2.18 30-NOV-98 MWD 7850.15 58.25 166.29 92.32 4970.79 4260.25 -247.71 4398.59 4.25 -3.68 2.45 30-NOV-98 MWD 7944.17 57.61 162.77 94.02 5020.72 4304.15 -324.48 4419.83 3.24 ,0.68 -3.74 30-NOV-98 MWD 8039.25 57.61 163.95 95.08 5071.65 4349.76 -401.41 4442.82 1.05 0.00 1.24 , 01 -DEC-98 MWD 8138.68 58.24 163.69 99.43 5124.45 4397.07 -482.32 4466.30 0.67 0.63 -0.26 01 -DEC-98 MWD 8231.76 58.44 164.69 93.08 5173.31 4441.13 -558.55 4487.88 0.94 0.21 1.07 , 01 -DEC-98 MWD 8325.66 58.76 164.24 93.90 5222.23 4485.38 -635.77 4509.35 0.53 0.34 -0.48 .. 01 -DEC-98 MWD 8419.98 58.73 163.52 94.32 5271.17 4530.59 -713.23 4531.73 0.65 -0.03 -0.76 01 -DEC-98 MWD 8514.75 59.00 162.03 94.77 5320.18 4577.35 -790.71 4555.75 1.38 0.28 -1.57 -- 01 -DEC-98 MWD 8608.96 59.46 163.34 94:21 5368.37 4624.12 -867.98 4579.84 1.29 0.49 1.39 -- 01 -DEC-98 MWD 8701.45 59.72 162.76 92.49 5415.19 4669.79 -944.28 4603.10 0.61 0.28 -0.63 ___ 01 -DEC-98 MWD 8794.97 59.78 164.96' 93.52 5462.31 . 4715.10 -1021.88 4625.55 2.03 0.06 2.35 -- 01-DEC~98 MWD 8891.13 60.50 162.92 96.16 5510.19 4761.78 -1102.01 4648.63 1.99 0.75 -2.12 01 -DEC-98 MWD 8984.38 61.1 8 161.75 93.25 5555.63 4809.24 -1179.60 4673.34 1.32 0.73 -1.25 r "1 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02512 Sidetrack No. Page 5 of 1-=[ll~-=l :~"~1 Company ARCO ALASKA, lNG. Rig Contractor & No. Doyon - 141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2L/305 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~li~Jl"L~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -149.44 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSD Target Description Target Coord. E/W Slot Coord. E/W -572.98 Magn. Declination 26.792 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ lOm~ Vert. Sec. Azim. 107.98 Magn. to Map Corr. 26.792 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (OD) (DD) (FT) (FT) (FT) (FT) (Per lO0 FT) Drop (-) Left (-) 01 -DEC-98 MWD 9072.14 62.02 164.91 87.76 5597.37 4853.11 -1253.54 4695.47 3.31 0.96 3.60 01 -DEC-98 MWD 9134.91 62.44 162.76 62.77 5626.62 4884.29. -1306,88 4710.94 3.10 0.67 -3.43 01-DEC-98 MWD 9210.00 62.44 162.76 75.09 5661.37 4922.68 -1370.46 4730.66 0.00 0.00 0.00 Projected Data - NO SURVEY -- . 3/18/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12450 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL Sepia LIS Tape KRU 2L-305 ~ ~O'~{ 99099 DST/FMS 981205 1 ~U 2L-305 99099 DSI 981205 1 1 ~U 2L-305 ~055 ~S ~8~203 1 1 DATE: SIGNE Please sign and return one copy of this transmittal to Sherrie al' the above address. Thank you. I-~ ~ ? 6 1999 Alaska Oil & Gas Cons. Co~.mis~ion Anohorage 0 F! I i--I_l IM G SEFIL/I ~--E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 9, 1999 2L-305, AK-MM-90021 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2L-305: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20279-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20279-00 2"x 5" MD Neutron & Density Logs: 50-103-20279-00 2" x 5" TVD Neutron & Density Logs: 50-103-20279-00 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia t',,!AR 0 9 !999 Gas Cons. Commission 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company I-~ FI I /1_ I I~J CS S i~ F! U'I i-- 1~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 3, 1999 2L-305, AK-MM-90021 1 LDWG formatted Disc with verification listing. API#: 50-103-20279-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TltE ATYACHED COPY OF THE TRANSMITTAL LETYER TO THE ATrENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company DEPARTMENT OF NATURAL RF~OURCF_,S DIVISION OF OIL AND GAS December 4, 1998 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Attention: Dora I. Soria Senior Landman Subject: Kupamk River Unit DS 2L-305 Tract Operation on KRU Tract 131 ADL 380051 Dear Ms. Soria: TONY KNOWLE$. GOVERNOR 3601 "C" STREET, SUITE 1380 ANCHORAGE, ALASKA 99503-5948 PHONE: (907) 269-8800 i COMM iMM ' :NR~ i_SR GEOL l r GEOL ASST _ . STAT TECH STAT TEOH Your November 10, 1998, letter requested approval to drill Well 2L-305 and conduct testing operations of the well using Kuparuk River Unit (KRU) facilities. The drilling of 2L-305 (the "Tract Operation") is designed to further develop the Bermuda formation in the Tarn reservoir and obtain information on the Iceberg formation in the Tam reservoir. The testing of 2L-305 (the "Testing Tract Operation") proposes to test produce the Iceberg interval in the well. I approve the request to drill the 2L-305 Well. The Testing Tract Operation of the well is approved subject to the following terms and conditions: 1) ARCO shall notify the Division of Oil and Gas (division) in writing, of the spud and completion dates of the well, the actual target bottomho!e location, the interval, either Iceberg or Bermuda, to be completed for production, and proposed start date of the Testing Tract Operation. 2) This approval is only for 120 days of on-line testing of the Iceberg interval in the well. The Tam Owners should have sufficient information after 90 days of on-line testing to determine if the Iceberg interval in 2L-305 is capable of producing or contributing to production of hydrocarbons in paying quantities to justify developing and producing the Iceberg formation in the Tam reservoir in an expanded TPA. The Tarn Owners must submit a TPA expansion application after the 120 days of on-line testing. If the TPA expansion application is not submitted at that time, the Testing Tract Operation automatically expires on that date. "Develop, Conserve and Enhance Natural Resources for Present and Future Alaskans" ~(T"'~..printed or~ recycled paper b y C.D. Ms. Doria I. Soria December 4, 1998 Page 2 3) The proposed well test allocation methodology with an allocation factor of 1.0 and a minimum of 2 well tests per well per month for the Iceberg production is acceptable to the division for the Testing Tract Operation. The Iceberg interval production from 2L-305 should be reported separately on the monthly Kuparuk Satellite Daily Allocation Summary and Well Test Summary Report. If 2L-305 is produced from the Bermuda formation within the limits of the Tarn Participating Area, those volumes should be reported as TPA production. 4) A gas disposition and reserves debit report that accounts for the gas produced from the KPA, WSPA, TPA, the Tabasco Tract Operation, and the Arete Testing Tract Operation and all utilization of that gas (fuel, sales, reinjection, etc.) should be submitted to the division with the monthly production allocation report. 5) Commingling of the Iceberg interval production fluids with TPA, KPA, WSPA, and TABPA fluids through the KRU facilities is approved for the period of the Testing Tract Operation only. The Tarn Owners in the decimals provided in your letter shall individually and separately account for the Iceberg production allocated to KRU Tract 131 on the monthly royalty reports. If you have any questions regarding this approval, please contact Mike Kotowski at 269-8812. Sincerely, DK~rne;~hr A. Boy~~......~ cc: J. E. Pilkinton - ADOR Jack Hartz - AOGCC Ryan Stramp - ARCO KRU.Bermuda2L305TO.txt 70NY KNOWLE$, GOVERNOR ALASKA OIL ~D GAS CONSERVATION COMMISSION November 20. 1998 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: t907) 276-7542 Paul Mazzolini Drilling Team Leader ARCO Alaska. Inc. PO Box 100360 Anchomee. AK 99510-0360 Kuparuk River Unit 2L-305 ARCO Alaska. Inc. Permit No: 98-240 Sur Loc: 149'FNL. 57YFEL. SEC 22. T10N. R07E. UM Btmholc Loc. 1696'FNL. 1088'FEL. SEC 23. TION. R07E. UM Dear Mr. Mazzolini: Enclosed is thc approved application for pcnnit to drill the above referenced well. Almular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records. FIT data. and any CQLs must be submitted to thc Commission on fom't 10-403 prior to tile start of disposal operations. Please note that mw disposal of fluids gcncratcd from tiffs drilling operation xvltich are pumped down tim surface/production casing annulus of a well approved for annular disposal on Drill Site 2L must coinply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35.000 barrels through thc annular space of a single x~ ell or to usc that well for disposal purposes for a period longer titan otto vcar. Tile permit to drill docs not cxcmpt you from obtaining additional permits rcquircd by law from other governmental agencies, and docs not auflmrize conducting drilling operations until all olhcr required permitting determinations arc made. Blo,~vout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25 035. Sut'ficicnt notice (approximately 24 hours)must be given to allow a representative of thc Comnussion to xvt,ness a test of BOPE installed prior to drilling ncxv hole. Notice may bc given by contacting tl~e Commission pager at 659-3607. David W. JohnsOn Chairman ~ BY ORDER OF TIlE COMMISSION dl I"En cl o su re.q Department o1' Fish & Game. ltabilat Section w o encl. Department of l';nviromnenlal Conservation w o encl. STATE OF ALASKA ALASr~& OIL AND GAS CONSERVATION COMM~oSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill / lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 149' FNL, 573' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1134' FNL, 1255' FEL, Sec. 23, T10N, R7E, UM 2L-305 #U-630610 At total depth 9. Approximate spud date Amount 1696' FNL, 1088' FEL, Sec. 23, T10N, R7E, UM 11/20/98 $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 2L-313 9418' MD 1088' @ TD feet 119.7' @ 500' feet 2560 5768' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 63.75° Maximum surface 1357 psig At total depth (TVD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 2633' 28' 28' 2661' 2300' 281 Sx Arcticset III & 240 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 8374' 28' 28' 8402' 5250' 290 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 1016' 8402' 5250' 9418' 5768' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet [~ 0V 1 Effective depth: measured feet Junk (measured) true vertical feet Alaska Oil & Gas Cons. 6ommissior Anchora_qe Casing Length Size Cemented Measured depth Tri~e Vertical depth Structural Conductor Surface Intermediate Production Perforatio~idnee:th: measured 0 R IGINAL true vertical 20. Attachments Filing fee X Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~ Refraction analysis [--~ Seabed report ~1 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drilling Team Leader Date Commission Use Only Per~:~m...b~r ~ IA~'5o- number//~ ~-~ -- z. o = ? IAppr°va' date ~ ~. ~---~.~ ~. "('-~'1~ Isee c°ver'etter f°rother requirements Conditions ofaplCroval Samples required F~ Yes ,J~ No Mud Icg required rm Yes ~ No Hydrogen sulfide measures E] Yes ~ No Directional survey required .~ Yes [~ No Required working pressure forBOPE F~ 2M E~ ~ ~ 5M F,~ 1OM E~ 15M Other: Original David W. by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA ALASC',TA OIL AND GAS CONSERVATION COMMFSSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of Work Drill X Reddll I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen[ Service Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 117' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380051, ALK 4599 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 149' FNL, 573' FEL, Sec.22, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1134' FNL, 1255' FEL, Sec. 23, T10N, R7E, UM 2L-305 #U-630610 At total depth 9. Approximate spud date Amount 1696' FNL, 1088' FEL, Sec. 23, T10N, R7E, UM 11/20/98 $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 2L-313 9418' MD 1088' @ TD feet 119.7' @ 500' feet 2560 5768' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 63.75° Maximum surface 1357 psig At total depth (TVD) 1610 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MOE 2633' 28' 28' 2661' 2300' 281 Sx Arcticset III & 240 Sx Class G 6.75" 5.5" 15.5# L-80 LTC-M 8374' 28' 28' 8402' 5250' 290 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 1016' 8402' 5250' 9418' 5768' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth (~r~tuUcrta~r R E C E iV E D Surface Intermediate Production DUPLICATE Liner l~ 0V 1 '7' Perforation depth: measured true vertical 0il & Con . Cornmissi°r' An(~hora,qe 20. Attachments Filing fee X Property plat E] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Timevs depth plot E~ Refraction analysis E] Seabed report E] 20 AA025.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~'~_..~_~.. ~~ ' Title Drilling Team Leader Date! [/~ i il ~ Commission Use Only Perrr~ Number ] APl number I Approval date ~ I _ ~_~ f~/_ (~-~....~ I See cover letter for ,~'o~' - ~ /--'//~:~ 50- ,,//d ~ -- ~ ~ ~ ~ ~ other requirements Conditions of approval Samples required r-] Yes '~ No Mud logrequired E] Yes j~ No Hydrogen sulfidemeasures [--] Yes ~ No Directionai survey required J~ Yes E] No Required working pressure for BOPE 2M r"] 3~BI 5M D 1OM [-] 15M Other: ,,id,, bi.Lj,, .... by order of i/ Approved by i ihV!~ ~./V..]¢lhl'l,s'~0F:commissioner the commission Date ................... Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 November 13, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2L-305 Surface Location: 149' FNL 573' FEL Sec 22 T10N R7E, UM Target Location: 1134' FNL, 1255' FEL Sec. 23, T10N, RTE, UM Bottom Hole Location: 1696' FNL, 1572' FEL Sec. 23, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-305, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. There is a secondary target in the Iceberg interval of this well. This explains the azimuth changes in the well bore path. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission' RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 17 998 David W. Johnstoh. :. Application for Permit to Drill Page 2 KRU 2L-305 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development GrOup Attachments cc: KRU 2L-305 Well File .... ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER KRU 2L-305 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface.. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +:~000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. . Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). . Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Additional E-line logs may be run across the Iceberg interval in this well. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. .... ARCO Alaska, Inc. 11. ND BOPE and install production tree. ].2. Secure well. Rig down and move out. :13. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. .---- DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-305 Drillinq.Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 _+10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2L-305 is 2L-313. The wells are 120' from each other at a depth of 500'. Drilling Area Risks: The primary risk in the 2L-305 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumpin~q Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.} The open annulus will be left with a non-freeTing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-305 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-305 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of'the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ARCO Alaska, Inc. ~- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51~'' 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2''9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). Ar4CO Alaska, Inc: / Field : Torn Development Field Location : North Slope, Alaska ~600 2000 2400 ;800 3600 I 4000 c.,,,.~ ~ .;.,, FOR: BRASSFIELD DeLe plett~d : 28-Oct-~8 Prat Refe,ence I~ 305 Ve,s;on ~. Coord;netes ore ;n feet reference East (feet) -> 400 · 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 1200 SURFACE LOCATION: 6~ ~....~~ ~'u ..... .~ ..... ~. ~ C40 149' FNL, 573' FELI 'i~.:~ "x~ 800 SEC 22, ~ION, ~7E I ~ 7 5/8~~CCes;ng~ ~ au , . ~ 400~ 0 NORTH 76 ~ -- 0 :RKB ELEVATION 145' ~ 400 400 , ~OP ~D=500 ?MD=500 D 800 V ~ o0 ~ 9.00 DLS: 5.00 de9 p ~200 soo ~ ~ 2.00 ~ EEGIN 7URN ]O ~6 95 ~D=5420 7B - Ccslno Pt $ ~1~ 17 B/ FEEMAFROST ~D=1195 7MD=1210 OEP=B4 TMD=8736 ' ~600 ;200 ~21'.57 T / W SAK SND~ ~D=1259 7MD=1257 BEP=?4 DEF=4579 ~24.09 ~ SOUTH 985 ~26.72 ~S7 4598 ~29.40 I 7D LOCATION %32.14 : %54.92 I ~' FNL, ~' FELI k I SEC 25, }~ON, RTE ~40.56 B / W SAK SNDS ~D=1897 TMD=2026 DEF=402 ~ ' ~C80 WD=2469 TMD=3033 DEP=l171 88 99 AZIMUTH ~ 4579' (TO ICEBERG TARGET) ~ 55.7g ~2.94 C50 WD=378g ff~D=5767 DEP=3475 ~52,18 ~5 ~ .91 -oo- ~'~ TAR G ET AN G LE ENO ANGLE DROP WD=466i TM'D=7249 DEP=4236 7.60 ,~oo- TARGET - ICEBERG TVD=4763 TMD=7449 DEP=4282 ..~ 59.3 DEG 5200 5600 6000 I I I 'l I I ' I I I I I I I I I I I I I I I I I I I I I ~00 0 400 800 ~ 200 ~ 600 2000 2400 2800 ~200' ~600 4000 4~00 4800 VeHicol Section (feeO-~ ~imu~h 88.99 wHh r~far~nze 0.00 N, 0.00 [ from Mot ~05 C,eo,ed by rixse FOR: BRASSFIELD Oete plo~.ted : 29-0ct-98 Prat Reference is 305 Version tl5. Cocrdlnotes are in [eet reference slot ARCO Alaska, Inc. Structure : Tarn Drill Site 2L Well: 305 Field : Tarn Development Field Location : North Slope, Alaska 28O 260 240 220 2O0 180 160 ",40 120 10o 60 4O 2O 20 60 East (feet) -> 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 I r I I I I I I f I I I ~ I I I I I I I I I I I I I I I ~ I 2300 ,,.-"[ 6O0 / / / ~.-~ 400 ~"1300 2800 .../' 2700 .-"' 2600 .. ............ e,'l 200 ................ '~500 ,,'" ..---' /,, 400 ,,,,' /"11 O0 ;" 1000 / 1100 ,, - ,,,/ 1000 ....................... ./900 ' _..-gO0 ........ 1200 ,,' 800 ......... 11 O0 ...................... / 700 ......... 1000 ....................... " 500 ........... '"~ .............. ' 800/ O'"'~.~-SeO ........ 900 700/' 1000 11 O0 ~-~500 ,-,500 800 900 1200 _800 '"~'b'O-8~ ..... :i~U~ ...... -1-'~6~ ........... -~-~,~ ..................................... 1300 '- ---* ...........I UU 3~/-'~-~. qr~ci ...... '~h~-~,~ 1100 ....... i~b~ ........... 1 300 .............. -~ ~ ' ...... "~-- ' '"'"':"' ' ....=~" .... 14 .............. .~1000 ....... ~..1..000 1~'~:::::::;-';-';; ........ O0 .......... ' ......... ' ........ ZL'.]--~-sne ..... ~ 5oo .... --. 1100 '" .... .,. 1100 ......... ',~' ....... ...... ..... ..... ..... & ' 'o ' b ' ' ' 'o' ;o ' lo ' b ............... 4 2 0 2 8 1 O0 120 140 160 180 200 220 Eost (fee]) -> 280 260 240 220 200 180 160 140 120 1 oo 8O 6o 4O 2O 2O 4O 6O 240 A I Z O 1800 165O 1500 135O 1200 1050 900 750 600 450 created by rix~ FOR: BRASSFIELD O~te plotteO: 30-Oc~-98 P~ot Reference is 305 Version ~5. Coorclinotes ere in feet reference slot True Ve~icel Depth~ o~ RKB (Do, on 1~1). 3OO E~sf (feet) -> 0 150 300 450 600 750 900 1050 1200 1550 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 I I I I I I I I I I I I I I I I I I I I I I I I I I [ I I II I [ I J I I II I I II " . ./1'~'00 3000 5500 / 4000 15o .... 1 oo 2000 /:~'~,~'~'- ..._/~ uuu .~e ...... ~a~ ............................. ~-OU~ ................. ' ...... 4500 ~Oa~ ~¢=~::~ ....................................... ' ............................ '-.. ..... i i i / i i i i $ i i i i i i i i i i i i i i ii i i i t i i i i i i i i / i i i i i i 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 East (feet) -> 1800 1650 1500 1350 1200 1050 I 9oo Z 0 750 600 450 300 150 150 Ic,~ot,a ~ ,;,,, FOR: BRASSFIELD Dote ptotted : 29-Oc[-flfl Plot Reference is 505 Version ~.~. Structure : Tarn Drill Site 2L Well : Field : 'l'orn Development Field Location : North Slope, AIo~kaJ / 1600 1400 1200 10o0 800 6OO 40O 200 0 2OO i 400 v East (feet) -> 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 I I I I I I ) I I I I 1 I I I I I I I I I I t I I I I I I I 1600 3300 3500 3700 3100 ....................................... ...~- .... ' ...... "-.. 3900 '~ 4100 · ,. 4300 '~,, 4500 · \ '\ \ ..... '-~..4500 ~o]fi). ............ ~_~.~ ...... 2700 "-. ,7o~- ................................................. ~o.~ ........ ',, 4900 ~ ............. .............................. 270b~ 2900 ................. ~'~-'y~-b-o ............................. W~C , 3100 3300 ' 4900 ................ 3300 " .............. 3500 ~ ...... 290o .............. ~'%';;~' .......................... ~ .......... ' ..... ~-0~ 2300 .............. 3500 '" .... ,,.. ~ ....... - ......... '~ 5300 600 .... f ........ - ............... - ............... ~oo /AC--..,, lOOO '"'" .... . / ................ ' .................. \ ,,. / ........ ~_ 4~oo '" ' ........ ' .......... _2700 ~00 12oo ..... .~ 3500 .... ~ ......... .2_.900 1800 "-,,. / ---...3300 --,,. 2300 "--. ,; ........ ~ ...... . ')":-.. 2500 ......... 14oo J -¢...~7oo "--%.. " ...... . .......... "-. ," '"-,~ 3300'"'.. '"'... 1600 ~l.'""' '"/',. 3900 " ....... '""-.,,.2700 ........ ,~.100 j-- ' .... ....... '" ........ "% I I I I I I I I I I I I I I I I I I I I I I , I , I I I ~ I I 1400 1200 1000 800 600 400 2OO 0 0 ~ ('D 200 400 I V 600 800 2200 2400 2600 2800 3000 3200 5400 3600 3800 4000 4200 4400 4600 4800 5000 5200 East (feet) -> 1600 1800 1400 1200 1aa0 ARCO Alaska, nC'i' Structure : Tarn Drill Site 2L Well: 305 Field : Torn Develcpment Field Location : North Slope, Alaska WELL PROFILE DATA ~ o.~ o.~ ~.~ o.~ o.~ o.~o o.~ o.~ ~.~ o.~ 2~,~ ~.~ o.~ o.oo o.~ o.~ ~c ~ ~ 4636.67~35 71.61~178.~1~2.~t 2524.6~ 254~ 0.~ T~rget ~D ICCB~r~ ~ 744B,~ ~ 1~.394763.~7~.~ 42~1.17 42~1~4 O.~ T.C & E-~ c~ HNC G317.62~g~ i~ 3S5717.10 -1464.43 47~.674714.070.~ 540 550 TRUE NORTH 550 0 10 2O 520 3O Cr¢ol,d by rJxse FOR: BRASSFIELD Date plo~ed : 2D-Ocl-9~ I Coordrnotes are in feet reference elal t~5. J ITrue Ve~;co] D ......... ~ EKB (Oo~ ..... ). 4O 310 50 300 60 290 7O 280 80 270 soo + go 260 100 250 / , ',250 ~, ~oo , , '- 110 220" 11~o %2 o 2oo 190 180 170 \', i'500 1300 ]~0 1500 140 120 Y30 ',. 1700 · Normal Plane Travelling Cylinder - Feet All depths shown ore Measured depths on ReferenCe Well A~CO Alaska, Inc. Tarn Drill Site 2L 3O5 slot #305 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 305 Version #5 Our ref : prop3164 License : Date printed : 29-Oct-98 Date created : 11-Oct-98 Last revised : 22-Oct-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nV0 12 49.742,w150 18 33.414 Slot locatlon is n70 12 48.272,w150 18 50.048 Slot Grid coordinates are N 5927695.115, E 461077.917 Slot local coordinates are 149.44 S 572.98 W Projection type: alaska ~ Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath 3294 Version #5,,329A,Tarn Drill Site 2L PMSS <0-???'>,,Arete,Tarn Drill Site 2L 313 Version 318 Version 301 Version 309 Version 310 Version 303 Version 323 Version 327 Version 317 Version 307 Version 308 Version 315 Version 319 Version 325 Version 311 Version #4 313, #3 318, #1 301, #2 309, #1 310, #3 303, #2 323, #2 327, #4 317, #3 307, #2 308, #3 315, #3 319, #3 325, #4 311, Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L Tarn Drill Site 2L 321 Version #4 321,Tarn Drill Site 2L Tarn #1 (Straight Hole),,1,TARN #1 PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance Last revised Distance 28-Oct-98 1452.0 M.D. 1544.4 27-0ct-98 358.0 400.0 5-Oct-98 119.7 500.0 2-Oct-98 178.2 766.7 1-Oct-98 60.3 300.0 1-Oct- 98 56.7 755.6 1-Oct-98 74.5 800.0 1-0ct-98 30.0 300.0 28-Sep-98 269.9 500.0 28-Sep-98 330.0 500.0 .23-Aug- 98 179.9 500.0 21-Aug- 98 28.0 688.9 23-Aug-98 39.1 688.9 1-0ct-98 150.0 500.0 26-Oct-98 209.6 677.8 28-Sep-98 299.9 500.0 26-Oct-98 86.8 766.7 26-0ct-98 239.9 500.0 12-Aug- 97 19232.1 500.0 12-Aug- 97 15435.5 9317.6 13-Jul- 98 11163.3 1433.3 26-0ct-98 2235.6 9317.6 method Diverging from M.D. 1544.4 8400.0 9317.6 9160.0 300.0 8300.0 8500.0 7300.0 9317.6 500.0 7600.0 8100.0 7600.0 9317.6 9317.6 9317.6 9100.0 9317.6 9317.6 9317.6 9317.6 9317.6 '~ARCO Alaska, Inc. Diverter Schematic Doyon 141 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT F--I MANUAL GATE V KILL LINE 3" 5,000 psi wP Shaffer GATE VALVE w/hydraulic actuator E~ / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE FJ r~T~~raulic actuator ~ 13-5/8" 5,000 psi WP w/two 3" 5M psi WP outlets J SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. "~ Post Office Box 100360 Anchorage, Alaska 99510-0360 November 13, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re' Application for Permit to Drill KRU 2L-305 Surface Location: 149' FNL 573' FEL Sec 22 T10N RTE, UM Target Location: 1134' FNL, 1255' FEI_ Sec. 23, T10N, RTE, UM Bottom Hole Location: 1696' FNL, 1572' FEL Sec. 23, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2L-305, located approximately six miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will be completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. There is a secondary target in the Iceberg interval of this well. This explains the azimuth changes in the well bore path. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany NOV 1998 Oil & (las Cons. Commission Anchorage David W. Johnstoi ¢.' Application for Permit to Drill Page 2 KRU 2L-305 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2L-305 Well File ARCO Alaska, Inc. · ..... GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD- PRODUCER KRU 2L-305 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/8" casing +~1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. A Top Job may only be performed after consulting with the AOGCC. This is based on the cement thickening time and time required to trip in the hole and open the Port Collar to perform the second stage cement job. See attached TAM Port Collar Utilization Decision Tree. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. , Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). . Drill 6.75" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Additional E-line logs may be run across the Iceberg interval in this well. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(0). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. '~" ARCO Alaska, Inc. 11. ND BOPE and install production tree. 1:~. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. ARCO Alaska, Inc. ._l. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2L-305 Drillincl Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Arete & Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2L pad are expected to be ~2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximitv Risks: The nearest well to 2L-305 is 2L-313. The wells are 120' from each other at a depth of 500'. Drillinq Area Risks: The primary risk in the 2L-305 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations- Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2L-305 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2L-305 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi .... ARCO Alaska, Inc. '- This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 51/~''15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 31/2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Diverter Schematic Doyon 141 21 iA" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline , I, i 21 iA" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE (~/ 16" OD DIVERTER UNE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / BSA 13-5/8" 5,000 psi WP '"'~b x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple L_ ! 3" 5,000 psi WP Shaffer GATE VALVE r.d [~~~~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL L_]'~.~ w/two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom cf~¢t~c W r~,e FOR: BRASSFIELD Oo~e plotted : 28-0c[-98 Plot Reference is 305 Version C 0 Alaska ructure : Tarn Drill Site 2L Il : 305 Id : Torn Development Field L°cat[on : North Slope, AlaskaI Easf (feel) -> 400 ' 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1200 i600 2000 2400 2800 3200 3600 I 4000 I SURFACE LOCATION: I - 6~ ~~c40 149' FNL, 573' FELI q~ ~ 800 SEC 22, ]'1ON, R7E [ ~ T 400 A~F'T I(~("ATI,qNI. I ~_~ ,,~ ,. n 40O 0 NORTH 76 4oo ~OP ~D=500 T~D=500 D 80o 3 O0 6'.O0 500 9.00 DLS: 3.00 deg ~200 12.00 EEGIN TURN TO TARG~ ~D=994 TMD=IO00 DEP=29 ' ' TD -Cos;ng Pt ~D=5420 [i1~ ~/ PERMAFROST ~D=I ~ TMD=1210 DEP=64 TMD=8756 ~26.72 ~sz k2s.~o I ZD ~ocAz~o~. I ~32 14 ' ~ 92 I ~' ~L, ~' ~EL I V ' I SEC 2~, Z~ON, ~Z[ I ~ 52.05 7 5/8" CSG PT ~0=2500 TMD=2661 DEP=oaS~' ~` ~ 57.85 - ' ~ ~367 EOC ~D=2367 TMD=2803 DEP=974 ~' cao ~=:~e T~=;o;; ~=~ 88 99 ~_ ~ 45?9' (TO ICEBERG TARGET) 63.?5 9gO ~so,, ANGLE DROP ~D-3~78 TMD-4637 DEp=2543 ' ~57.82 DLS: 3.00 deg per 100 ft ~ 55.79 . ~54.~ 5 ~2.94 C50 ~B=3789 TMD=5767 DEP=3475 ~52.18 ~5 ~ .91 .oo ~ ~ ~ s7 ~o TARGET ANGLE ~aoo TARGET - ICEBERG TVD=4763 TMD=7449 9EP=428g ~ 59.3 DEG 5200 5600 TD - CASING PI ~D=~ T~D=~ DEP=~ 3os 400 0 400 800 1200 1600 2000 2400 2800 ~200 5600 4000 4400 4800 5200 Vertical Secfion (feel)-> Azimuth 88.99 wiih reference 0.00 N, 0.00 E from sial ~305 c~¢oteo b~ .;~e FOR: BRASSFIELD ] Dote plotted : 29-0ct-98 Plot Reference is .305 Version t~5. ~ I A RCO Alaska, 280 26O 240 220 2OO 180 160 A [ 140 120 '4-- -'~ lOO 0 20 4O 6O East (feel) -> 60 40 20 0 20 ~0 80 80 1 O0 120 1 40 180 180 200 220 2/+0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t 28,0 ' 260 ?.-1'~00 /' ./ .- / . ,./ 71/400 #/~ 300 2800 /' 2700 .............. 240 22O 200 180 160 14o .-" 2600 .................. /'1 200 .~-- .................... 2500 ..." .................... 2400 .'"/" i- ~ co / / / /'1000 60 /,,,," 11 O0 1000 ....................... ./'900 _.~_.g430 ........ 1200 ~ 40 800 ......... 11 O0 ...................... ,'" 700 ..... --' 1000 / 80O/ 50O ........... '". .............. - (~-~"" 880 ........ 900 20 / 700/ G ..._7.ecr e ~o~,' e o ~..500 .-.500 800 900 1000 11 O0 1200 , lo~_O__O___9_~:~__~_ _477~-q]]----~-?~ ........... ]-~-~- .............................................. ~oo .... ::::::::::::::::::::::::: ........ ............................. 3/~'7T~_ a an ...... '~,~.~ 1100 ....... i~(~-~_ ............ 1300 ............... ~. 20 ~ - ....... .o..,_,_,.., , ur..~.... ' ....."~-="- ..... 1400 ............ j ooo ..... ~.1_oo0 ~ ~-':::::::::: ......... ........... - ......... - ........ --2-_---ysn~ '----._ 1 lO0 ....... ~. 1100 ......... - .......... ..... ..... ..... 6O ' ' ~'o ' 'o ' ' ' 'o ' ~' ' ~'o ' 'o ............ 60 2 0 2 0 8 100 120 140 160 180 200 220 240 Easf (feel) -> 120 A Z O 1 800 650 500 1350 ICreoted by rixsc FOR: BRASSFIELD Dote plotted : 30-0ct-98 Plot Reference is 305 Version #5. Ceordinotes ere in feet reference slot Truc Vertical Ompth .... ri~r~i R KB (Do,an 141)1 INTEQ 12OO 1050 I 900 750 -ii 0 600 z 450 300 ARCO Alaska, ~ne. [F?::llt~n TDlrvi1221el12eF~lLd LocaHon : V~eilrf:h %i~pe, Alaska East (feet) -> 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 2100 2250 2400 2550 2700 2850 3000 3150 ...-ZOO0 / 3000 3500 4000 150 2 50 0~,,_'_'i ....................................................................................................................................................... _..:~,.. w, 1 500 2000 .... . ~-- ?~--J/'ieee '~e ...... 15oo ............................. ~OUCr ................................... '-"--. ,...4,500 ~.L~3'~,q 5o0 .... - ..... """""~'~'~cr .......... - ............... '" ~'~ t ..... ..... ..... ............. ....................... I i J i ~ i J i i i i i i i i i i i--~ J- q i i ii i i i i i i i i -1 I r ii i i i i i i 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 21 O0 2250 2400 2550 2700 2850 5000 3150 East {feet) -> 1800 1650 500 1350 1200 1050 A I 90o Z 0 750 ~" 600 ~D 45O 3OO 150 150 C~,ot,d ~ ~;~ FOR: BRASSFIELD Dote plo[ted : 29-0c[-98 Plot Re(erence is 505 Version East (feet) -> 2200 2400 2600 2800 3000 .5200 5400 ,3600 5800 4000 4200 4-400 4-600 4800 5000 5200 1600 ~ I I I I I I I I J I I I I ~ I I I I I J I I I I I i J I 1600 1400 i 400 1200 5300 3500 1200 3700 .3100 ........................................ '~--.._.... ........... "-.. 3900 1000 3~._---''-'~' '"-...... 1000 ".. 41 O0 800 '", 8OO '.. 4-300 600 '"",, 600 ,, '~,, 4500 4O0 \, 400 ,, 200 "--%4500 ~ ............ .2,_5~_~_.._ 2700 / 0 ~ ...... .,.,~oo ................................... .............. _.2_ _7_0. ~ .... 2900 ....... T,- - "~-1-~)-0 ............................. ~ 200 ",, "; ", ' ........................ "¥ 3500 / ~ ', --, ................. i- 400 ........... .,~ 2900 " " ......... :::::: .......... i ~ oo ......... .~._;&o_? ',,, j .......... ' ..... ~ .~-O-,J. 2500 ............. 5500 ',, F .... .... ,~ ....... ' ........... '~ 5~oo I ~oo ..... ~ ........ ................. - .............. ~z_o_o ~ ~ ~oo ~oo ~ ooo ........... / ............... - ................. L '~ ...... ': ......... ~_~_oo ,ooo .~ ....... / ......... -....2300 --.. ,, --.__ ,~oo ~l.. ' ......... "--. 3100' ...... ," .... ...290(} '"'""--... '"' --~.2500 '"'""'--... ...... " --'-~ 1400 ~L ~?'" ........ :'~ .... -~ 3700 i400 ~.~-.~ 3700 "-< ....... '"-. 5700 .[~ .............. ~' '""' '.f3900 "'"" '"'"" ,..2700 '""" 5100 1600 1600. %......... ..:? "-. - ...... '-. .... '--. - ......... I "---...?<.. ~o~"--.. ' ..... ..~o~; ....... . ......... , oo1 , oo / i I i I i i i 2200 24-00 2600 2800 3000 .3200 3400 3600 5800 4-000 4-200 4400 4-600 4800 5000 5200 East (feet) -> 200 0 200 0 400 IStructure : Tarn Drill Site 2L I: 5a5 J JField : Tarn Developmenf Field Location : North Slope, AlaskaJ WELL PROFILE DATA ..... p~,,~ ..... ~o in¢ o~- ~ North £ ~:~, ¥. ~ ~ ~o~ 5oo.~ o.~ 25.~~o.~ o.~ o.~o o.~ o.~ ]~;n Turn To T~ct ~O~.OO ~5.~ 2~.~~g4.~l~,~8 27.~0 2~.~¢ 5.~ ~e ~, B~-~ffum 2S02.70~.75 71.6~ ~3~7.~583.51O~3.?g073.50 3.~ ~d of ~op~um 7248.5759.~ 1~.394680.89 2~.46 4231.gg +235.~ 3.00 T=r~L ~5 Ic~b~g ~ 744B.eO~.30 i~ 3~47fi3.~ 75.~ 4281.17 ~281.8~0.~ Tcr~ ~-B (P) ~d 2 8735.635g.301~ 3~~20.~-g8~.87 ~597.~0 ~57g.~ O.OO ~ o~ ~'d 9117.62~.~ 1~ 39~lb.~-1299.~ ~gl.51~67.82 0.~ TO · ~r~ el Ho'd g317.625930 163 3g 5717.10 --146'.43 47~.67¢714.07 340 .530 TRUE NORTH 350 0 10 2O 320 3O Created by rixse FOR: BRASSFIELD Dote plotted : 29-Oct-gB 4O 510 5O 500 6O 290 7O 280 50 80 270 soo + 9O 260 100 250 , / ',230 1100 220"' : '~ 110,'0 \ i 1500 ~ ',,% ~ ~2~0 200 -. "- II0 190 180 170 \'., i'SqO 1500 ~'e 150 160 1~oo 1 20 ~',,5 0 %, 170o 140 ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2L 305 slot #305 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 305 Version #5 Our ref : prop3164 License : Date printed : 29-Oct-98 Date created : 11-0ct-98 Last revised : 22-Oct-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 12 49.742,w150 18 33.414 Slot location is nT0 12 48.272,w150 18 50.048 Slot Grid coordinates are N 5927695.115, E 461077.917 Slot local coordinates are 149.44 S 572.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath 329A Version #5,,329A,Tarn Drill Site 2L PMSS <0-???'>,,Arete,Tarn Drill Site 2L 313 Version #4,,313,Tarn Drill Site 318 Version #3 301 Version #1 309 Version #2 310 Version #1 303 Version #3 323 Version #2 327 Version #2 317 Version #4 307 Version #3 308 Version #2 315 Version #3 319 Version #3 325 Version #3 311 Version #4 2L ,318,Tarn Drill Site 2L ,301,Tarn Drill Site 2L ,309,Tarn Drill Site 2L ,310,Tarn Drill Site 2L ,303,Tarn Drill Site 2L ,323,Tarn Drill Site 2L ,327,Tarn Drill Site 2L ,317,Tarn Drill Site 2L ,307,Tarn Drill Site 2L ,308,Tarn Drill Site 2L ,315,Tarn Drill Site 2L ,319,Tarn Drill Site 2L ,325,Tarn Drill Site 2L ,311,Tarn Drill Site 2L 321 Version #4 ,321,Tarn Drill Site 2L Tarn #1 (Straight Hole),,1,TARN #1 PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A,TARN #3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28-Oct-98 1452 27-Oct-98 358 5-Oct-98 119 2-Oct-98 178 1-0ct-98 60 1-Oct-98 56 1-Oct-98 74 1-Oct-98 30 28-Sep-98 269 28-Sep-98 330 23-Aug-98 179 21-Aug-98 28 23-Aug-98 39. 1-Oct-98 150. 26-Oct-98 209. 28-Sep-98 299. 26-Oct-98 86. 26-Oct-98 239. 12-Aug-97 19232. 12-Aug-97 15435. 13-Jul-98 11163. 26-Oct-98 2235. 0 1544.4 1544.4 0 400.0 8400.0 7 500.0 9317.6 2 766.7 9160.0 3 300.0 300.0 7 755.6 8300.0 5 800.0 8500.0 0 300.0 7300.0 9 500.0 9317.6 0 500.0 500.0 9 500.0 7600.0 0 688.9 8100.0 I 688.9 7600.0 0 500.0 9317.6 6 677.8 9317.6 9 500.0 9317.6 8 766.7 9100.0 9 500.0 9317.6 i 500.0 9317.6 5 9317.6 9317.6 3 1433.3 9317.6 6 9317.6 9317.6 ARCO Alaska, Inc, ~ &Al PAYABLES :.O. Box 102776 ~nchorage, AK 99510-2776 ~AY -O THE )RDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 2O5086414 NOVEMBER 4, 1998 VOID AFTER 90 DAYS 73-426 839 0997579 EXACTLY ***********100 DOLLARS AND O0 CENTS $***********100.00 he First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyv~lle, Kentucky TRACE NUMBER: 205086414 PROGRAM: exp [] dev'~ redrll [] serv [] wellbore segll ann. disposal para r_e!!X COMPANY ,~~-- _ WELL NAME/~",4~_..,/ 2.,/--"" FIELD & POOL ........... ~. ~.~.,/.~_~. ____ INIT CLASS Z~_~,,' .,/-,,-~/.~ GEOL AREA ADMINISTRATION 1. Peri'nit fee attached ....................... t¥ 2. Lease number appropriate ................... I ¥ 3. Unique well name and number .................. J ¥ 4 Well located in a defined pool ................. I Y 5. Well located proper dislance from drilling unit boundary. . . Y 6. Well located proper distance from other wells .......... ~ Y 7. Sufficient acreage available in drilling unil ......... Y 8. If deviated, is wellbore plat included .............. j Y 9. Operator only affected party ................... ~ Y 10. Operator has appropriate bond in force ............. / Y 11. Permit can be issued without conservation order ........ ] Y DA1-E 12. Permit can be issued without administrative approval ...... ~ Y , _ ./'~'.~/~,~/f;~ 13. Can permit be approved before 15-day wait ........... 1 Y ENGINEERING 14. ~~ / ~ 15. Surface casing protects all known USDWs ........... ~ Y 16. CMl' vol adequate to circulate on conductor & surf csg ..... \ _,Y APPR.. DA'rE N GEOLOGY DATE 17 CMI vol adequate to tie-in long string to surf csg ........ ~Y. N 18. CM I' will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, T, B & permafrost ....... (.~ N 20. Adequale tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... ~/%/'/~ 22. Adequate wellbore separation proposed ............. ~ N 23. If diveder required, does it meet regulations .......... ~ N 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to ,~ (~ (3(::::~ psig. (~) N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. Y ~.~ 30. 31. 32. 33. 34. UNIT// _///~"',,5",~ ON/OFF SHORE ANNULAR DISPOSAL 35. Wilh proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; JJ.1./,~J.'~, ...... .1~..~_. (C) will nol impair mechanical integrity of the well used for disposal; (r)) will nol damage producing formation or ilnpair recovery from a po()l; and ..................... i.'_ ................ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: UIC/Annular coMMISSION: Permit can be issued w/o hydrogen sulfide measures ..... ~YY N.~'~_ ~ .......................................................... Data presenled on potential overpressure zones ....... Y Seisrnic analysis of shallow gas zones. ' Seabed condition survey (if off-shore) ............. Con, tact,nam, elphon,e.for weekly progress reports / Y N lexpmramry omy] ....... / .......................................................................................... Y N Y N ~75 ~~, Y N Comments/Instructions: ENGINEERING: ',q wu ! JDH ~ Y N M chel;hsl *~;v 05129198 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. 1 Sperry-Sun Drilling Services LIS Scan Utility Fri Feb 26 14:04:42 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/02/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL xwn/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (~T FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM- 90021 B. HENINGSEN R. SPRINGER 2L-305 501032027900 ARCO Aff~ASKA, INC. SPERRY-SUN DRILLING SERVICES 26-FEB-99 22 10N 07E 149 573 146.10 144.60 117.10 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 30 DECEMBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2L-305. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9210'MD, 5661'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON (SANDSTONE MATRIX-FIXED HOLE SIZE). NCNT = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. FCNT = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES' SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SCO2 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = 6.75" MUD FILTRATE SALINITY = 350 450 PPM CL- FORMATION WATER SALINITY = 19149 PPM CL- MUD WEIGHT = 9.1 - 9.9 PPG FLUID DENSITY = 1.00 G/CC MATRIX DENSITY = 2.65 G/CC LITHOLOGY = SANDSTONE OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2667.0 6.750 9210.0 File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR PEF DRHO RHOB FET RPD RPM RPS RPX ROP FCNT NCNT NPHI $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 2623 5 2675 0 2675 0 2675 0 2675 0 2675 0 2675 0 2675 0 2675 0 2675 0 2677 0 2677 0 2677 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 9155.5 9133 5 9133 5 9133 5 9162 0 9162 0 9162 0 9162.0 9162.0 9209.5 9117.0 9117.0 9117.0 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 2675.0 9210.0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD API 4 1 RPD MWD OHMM 4 1 NPHI MWD P.U. 4 1 ROP MWD FT/H 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD O~IMM 4 1 FET MWD HOUR 4 1 FCNT MWD CNTS 4 1 NCNT MWD CNTS 4 1 RHOB MWD G/CC 4 1 DRHO MWD G/CC 4 1 PEF MWD BAR/~ 4 1 Rep 68 68 68 68 68 68 68 68 68 68 68 68 68 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name 'Min Max DEPT 2623.5 9209.5 GR 38.37 262.2 RPD 1.13 46.3 NPHI 14.52 65.54 ROP 0 9570.85 RPX 1.13 43.26 RPS 1.12 37.12 RPM 1.11 42.06 FET 0.2 15.2 FCNT 97.71 763.93 NCNT 13949.8 30883 RHOB 1.83 3.47 DRHO -0.14 1.32 PEF 1.02 6.22 Mean Nsam 5916.5 13173 124.021 13065 4.50299 12975 39.2394 12881 207.816 13070 4.36397 12975 4.42907 12975 4.3927 12975 0.716267 12975 228.1 12881 19847.2 12881 2.2973 12918 0.0482381 12918 2.51331 12918 First Reading 2623.5 2623.5 2675 2677 2675 2675 2675 2675 2675 2677 2677 2675 2675 2675 Last Reading 9209.5 9155.5 9162 9117 9209.5 9162 9162 9162 9162 9117 9117 9133.5 9133.5 9133.5 First Reading For Entire File .......... 2623.5 Last Reading For Entire File ........... 9209.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service nam~ ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2623.5 PEF 2675.0 DRHO 2675.0 RHOB 2675.0 FET 2675.0 RPD 2675.0 RPM 2675 0 RPS 2675 0 RPX 2675 0 ROP 2675 0 FCNT 2677 0 NCNT 2677 0 NPHI 2677 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 9155.5 9133.5 9133.5 9133.5 9162.0 9162.0 9162.0 9162.0 9162.0 9209.5 9117.0 9117.0 9117.0 01-DEC-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 9210.0 2675.0 9210.0 51.3 65.7 TOOL NUMBER Pl132NLM4 Pl132NLM4 Pl132NLM4 Pl132NLM4 6.750 6.8 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT FLAX CIRCULATING TERMPER/~TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.80 52.0 10.0 400 4.8 1.600 .839 4.000 3.700 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOLrR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 .CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DR_HO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 49.2 First Name Min Max Mean Nsam Reading DEPT 2623.5 9209.5 5916.5 13173 2623.5 ROP 0 9570.85 207.816 13070 2675 Last Reading 9209.5 9209.5 GR 38.37 262.2 124.021 13065 2623.5 9155.5 RPX 1.13 43.26 4.36397 12975 2675 9162 RPS 1.12 37.12 4.42907 12975 2675 9162 RPM 1.11 42.06 4.3927 12975 2675 9162 RPD 1.13 46.3 4.50299 12975 2675 9162 FET 0.2 15.2 0.716267 12975 2675 9162 NPHI 14.52 65.54 39.2394 12881 2677 9117 FCNT 97.71 763.93 228.1 12881 2677 9117 NCNT 13949.8 30883 19847.2 12881 2677 9117 RHOB 1.83 3.47 2.2973 12918 2675 9133.5 DRHO -0.14 1.32 0.0482381 12918 2675 9133.5 PEF 1.02 6.22 2.51331 12918 2675 9133.5 First Reading For Entire File .......... 2623.5 Last Reading For Entire File ........... 9209.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/26 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/02/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * . . ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : KRU 2L-305 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20279-00 REFERENCE NO : 99099 RECEIVED 1999 Alaska Oil & Gas Cons. Co~~ An~or~e LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:5~~- PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE ' 99/03/15 ORIGIN : FLIC REEL NAME : 99099 CONTINUATION # : PREVIOUS REEL : CON~4ENT : ARCO ALASKA INC, KRU 2L-305, KUPARUK, API #50-103-20279-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/15 ORIGIN : FLIC TAPE NAME : 99099 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, KRU 2L-305, KUPARUK, API #50-103-20279-00 TAPE HEADER KUPARUK RIVER OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN1 99099 KIRKEY RAY SPRINGER KRU 2L-305 501032027900 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 15-MAR-99 RUN2 99099 ALLDREDGE RAY SPRINGER 22 1 ON 7E 150 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 2667.0 6.750 5.500 8369.0 146.10 144.60 117.10 RUN 3 573 LIS Tape Verification Listing Schlumberger Alaska Computing Center i5-MAR-1999 15:~;=~ 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS DIPOLE SONIC AND FMS DATA ACQUIRED ON ARCO ALASKA'S KRU 2L-305 WELL. THE DIPOLE SONIC WAS ACQUIRED THRU CASING ON RUN#2. THE DIPOLE SONIC AND FORMATION MICROSCANNER WERE ACQUIRED ON RUN#1 IN OPENHOLE. THE DIPOLE SONIC DATA HAS BEEN RELABELED BY SCHLUMBERGER GEOQUEST. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged. DEPTH INCREMENT: O . 5000 FILE SUNk4ARY LDWG TOOL CODE DAS FMS $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8384.0 2587.0 5118.0 2683.0 BASELINE DEPTH 88888.0 8378.5 8354.0 8309.0 8304.5 8296.5 8280.5 8275.5 8261.5 8194.0 8157.5 8120.5 8112.0 8087.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... DAS/FMS ....... 88877.5 8368.0 8343.5 8298.5 8295.5 8288.0 8270.0 8264.5 8250.5 8184.5 8148.0 8111.0 81 O2.0 8077.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8079.5 8069.5 8054.0 8033.5 8002.5 7974.5 7917.0 7899.0 7895.5 7869.5 7863.0 7852 5 7839 5 7834 0 7802 5 7750 0 7698 0 7684 0 7657 0 7629 5 7601.5 7586.5 7576.5 7559.5 7536.0 7506.5 7498.0 7476.5 7418.5 7394.5 7359.5 7343.5 7309.5 7275.5 7266.0 7234.0 7222.5 7181.5 7162.5 7135.0 7103.0 7083.0 7054.0 7042.5 7031.0 7014.0 6986.0 6974.5 6956.5 6906.5 6876.5 6850.0 6833.5 6803.0 6784.5 8068.5 8060.0 8044.5 8024.0 7993.0 7965.0 791 O. 5 7891.0 7889.5 7862.5 7855.5 7847.5 7833.5 7828.5 7797.0 7743.5 7691.5 7676.5 7648.5 7620.5 7593.5 7579.5 7570.0 7553.0 7529.0 7499.5 7491.0 7470.0 7412 0 7387 0 7353 0 7337 5 7303 5 7270 0 7260 5 7229 0 7217.5 7177.0 7157.5 7129.0 7096.5 7077.5 7050.0 7039.5 7026.5 7010.0 6982.0 6971.0 6953.0 6901.5 6873.0 6846.5 6831.0 6800.0 6781.5 15-MAR-1999 15:5¥ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6742.0 6724.0 6702.5 6687.0 6664.5 6618.0 6529.0 6515 5 6494 5 6477 5 6442 0 6415 5 6400 0 6385 5 6375 5 6344 0 6328.0 6311.0 6283.5 6268.5 6241.5 6228.0 6193.5 6159.0 6130.0 6097.5 6062.5 6050.0 6034.0 6020.0 6008 0 5983 0 5960 5 5954 0 5937 5 5890 5 5885 0 5876.5 5860.5 5828.0 5815.0 5785.0 5765.0 5755.0 5724.0 5707.5 5701.0 5684.5 5668.0 5656.0 5635.0 5618.0 5613.0 5569.0 5563.5 6741.5 6721.0 6703.5 6686.0 6663.5 6614.5 6524.0 6512.0 6492.5 6475.0 6440.0 6412.5 6397.5 6383.0 6373.5 6341.0 6325.5 6309.0 6282.0 6266.0 6238.5 6225.5 6190.0 6157.0 6127.5 6095.5 6061.0 6048.0 6032.0 6018.0 6006.0 5980.5 5958.0 5952.5 5936.0 5888.5 5883.5 5875.0 5859.0 5826.5 5814.0 5782 5 5764 0 5753 0 5723 0 5707 0 5699 0 5682 0 5667 0 5656 5 5634.0 5618.0 5612.0 5567.0 5563.0 15-MAR-1999 15:~-~ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5534.5 5523.0 5511.5 5507.5 5502.5 5499.5 5466.0 5431.5 5428.5 5419.0 5405.5 5390.5 5359.5 5349.5 5334.0 5318.0 5269.0 5231.5 5059.5 5039 0 5005 5 5000 5 4990 0 4956 0 4941 0 4905.5 4876.0 4849.5 4815.5 4793.0 4757.5 4743.0 4737.0 4721.0 4689.5 4664.0 4655.0 4642.5 4636.0 4621.5 4582.5 4574.5 4556.5 4532.5 4520.5 4510.0 4503.0 4496.0 4488.0 4464.5 4429.0 4416.5 4400.0 4395.0 4391.0 5533.0 5522.0 551 O. 5 5502.5 5499.0 5496.5 5463.5 5430.5 5428.5 5417.5 5405.0 5389.5 5359 0 5349 0 5334 5 5317 5 5268 0 5230 5 5060 0 5039.0 5003.0 4998.0 4987.5 4954.5 4940.5 4903.5 4875.0 4849.5 4815.5 4793.0 4756.5 4741.5 4736.5 4721.5 4689.5 4665.0 4653.5 4642. $ 4635.5 4621.5 4582 0 4574 0 4557 0 4531 5 4521 0 4510 0 4503 5 4497 0 4487 5 4465 5 4429.5 4417.0 4400.0 4395.0 4391.5 15-MAR-1999 PACE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4374.0 4366.0 4363.0 4347.5 4339.5 4313.5 4310.0 4287.0 4284.5 4269.0 4262 5 4238 5 4231 5 4214 0 4207 5 4200 0 4180.5 4163.0 4140.5 4132.5 4106.5 4094.0 4057.0 4049.5 4033.5 4020.0 4016.0 4003.5 3997.5 3992.5 3979.5 3972.0 3947.0 3934.0 3902.5 3892.0 3884.0 3865.0 3857.5 3836.5 3829.5 3814.5 3808.0 3792.5 3783.5 3753.0 3724.5 3706.5 3693.0 3671.5 3662.5 3629.5 3619.5 3613.5 3589.5 4373.5 4366.0 4363.5 4347.5 4339.5 4314.5 4311.0 4289.5 4286.0 4270.0 4260.5 4238.5 4231.5 4215.5 4208.5 4200.0 4180.5 4163.5 4141.5 4132.5 4107.0 4095.0 4057.5 4O5O 0 4034 0 4019 5 4017 0 4003 5 3997 5 3990.5 3980.0 3971.0 3947.0 3934.0 3902.0 3892.5 3886.0 3867.0 3859.0 3837.0 3829.5 3814.5 3809.0 3792 5 3783 5 3753 5 3724 0 3705 5 3 692 0 3671 0 3 661.5 3630.0 3619.0 3613.0 3589.0 15-MAR-1999 15:$,--' PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3582.0 3574.0 3567.5 3560.0 3556.0 3544.5 3535.5 3531.5 3524.5 3501.5 3479.5 3435.5 3424.5 3405.5 3384.0 3373.0 3362.5 3351.0 3345.5 3337.0 3310 5 3304 0 3301 0 3297 0 3289 0 3278 5 3268 5 3240 0 3205 5 3194 5 3188 0 3173 5 3168.5 3165.0 3137.0 3128.0 3108.5 3104.5 3098.0 3071.5 3059.0 3028.5 3014.5 3009.5 2996.0 2978.5 2965.5 2949.0 2934.0 2927.0 2911.5 2895.5 2883.5 2869.5 2857.5 3584.0 3574.5 3567.5 3560.0 3556.0 3546.0 3536.5 3531.5 3524.5 3501.0 3479.5 3435.5 3424.5 3406.0 3385.5 3373 5 3362 5 3351 5 3347 0 3337 0 3310 0 3303 0 3300.5 3298.5 3289.5 3279.5 3269.5 3241.0 3206.0 3194.0 3188.0 3173.0 3168.0 3165.0 3137.0 3128.0 3108.0 3104.0 3096.5 3072.5 3059.0 3029.0 3016.5 3012.0 2997.0 2979.5 2965.0 2949.0 2934.5 2928.0 2911.5 2896.5 2885.0 2870.5 2858.0 15-MAR-1999 15:~ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15 :'5-7~ ' PAGE: 2840.0 2840.5 2820.0 2818.5 2817.5 2817.0 2790.5 2790.5 2761 . 0 2761 . 0 2747.5 2749.0 2735.5 2737.0 2722.5 2723.0 2711.5 2711.5 2694.5 2693.5 2667.0 2667.0 2652.5 2652.0 2641 . 0 2640.5 100.0 99.5 MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. DAS 1 1 DAS 2 1 $ REMARKS: MERGE TOP MERGE BASE 2587.0 5064.0 5064.0 8384.0 THIS FILE CONTAINS THE MAIN LOG DATA FOR RUNS 1 AND 2 THAT HAS BEEN DEPTH CORRECTED, MERGED AND CLIPPED. THE DIPOLE SONIC DATA HAS BEEN RELABELED FOR BOTH RUNS. THE DIPOLE SONIC WAS ACQUIRED THRU CASING FOR RUN #2 AND IN OPEN-HOLE FOR RUN #1. THE DATA FOR THE SONIC OVER THE INTERVAL FOR RUN #2 WAS ADVERSELY AFFECTED BY POOR CEMENT TO CASING BOND. THE FMS WAS ACQUIRED OVER THE INTERVAL FOR RUN 1 ONLY FOR CALIPER AND DIRECTIONAL INFORMATION. ALL THE DATA IN THIS FILE HAS BEEN DEPTH MATCHED TO SPERRY SUN MWD GA~4MA RAY LOGGED ON 2-DEC-98. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:B-._ ~, PAGE: TYPE REPR CODE VALUE 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 CR MWD GAPI 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 CRCH DAS GAPI 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 MRES DAS ObhVi~6004719 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDAS DEGF 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 DEV FMS DEG 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 6004719 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9155.500 GR.MWD 109.210 GRCH.DAS -999.250 TENS.DAS TEND.DAS -999.250 M~ES.DAS -999.250 MTEM. DAS -999.250 DT.DAS DTSH.DAS -999.250 SCRA.DAS -999.250 Cl3.FMS -999.250 C24.FMS AZ.FMS -999.250 DEV. FMS -999.250 RB1.FMS -999.250 DEPT. 2587.000 GR.MWD -999.250 GRCH.DAS 56.617 TENS.DAS TEND.DAS -999.250 MRES.DAS -999.250 MTEM. DAS -999.250 DT.DAS DTSH.DAS 232.348 SCRA.DAS -999.250 Cl3.FMS -999.250 C24.FMS AZ.FMS -999.250 DEV. FMS -999.250 RB1.FMS -999.250 -999.250 -999.250 -999.250 417.000 -999.250 -999.250 ** END OF DATA ** i rl LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~'~ PAGE: 10 **** FILE TRAILER **** FILE NAME : BDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : DSI $ LOG HEADER DATA DATE LOGGED: FILE HEADER FILE NUMBER 2 RAW CASED HOLE MAIN PASS Curves and log header data for logs run in casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8384.0 4683.0 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 5-DEC-98 8Cl-205 2100 1-DEC-98 920 5-DEC-98 9210.0 4683.0 8384.0 TOOL NUMBER ........... DSSTB 6.750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~? PAGE: 11 LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): 8369.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN #2 DIPOLE SONIC RUN THRU CASING. DEPTH CORRELATED TO SPERRY SUN GR LOGGED 2-DEC-1998. NO STANDOFFS WERE RUN ON THE DSI DUE TO CASING RESTRICTIONS. DSI RUN IN UPPER DIPOLE, LOWER DIPOLE AND P&S MODE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:5~~ PAGE: 12 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 GR DSI CAPI 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 DTCO DSI US/F 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 DTSM DSI US/F 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 RSHC DSI 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DSI LB 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 PR DSI 6004719 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8406.500 GR.DSI 61.759 DTCO.DSI 87.985 DTSM. DSI 198.544 RSHC.DSI 2.257 TENS.DSI 1532.000 PR.DSI 0.378 DEPT. 4683.000 GR.DSI 78.115 DTCO.DSI -999.250 DTSM. DSI -999.250 RSHC.DSI -999.250 TENS.DSI 2180.000 PR.DSI -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE · 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:b-~~ PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~E4ARY VENDOR TOOL CODE START DEPTH DSI 5070.0 FMS 5118.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 2600.0 2587.0 5 -DEC- 98 8Cl -205 2100 1-DEC-98 920 5 -DEC - 98 921 O. 0 0.0 2587.0 5118.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DSI DIPOLE SONIC FMS FORMATION MICROSCANNER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER DSSTB MEST 6.750 2667.0 2668.0 LSND LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~ PAGE: 14 MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S) : 50.0 MUD PH : 10.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (Ot~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3.890 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): 4. 740 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 4. 220 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN #1 FIELD REMARKS: FMS,DSI, C~IR, GR RUN IN COMBINATION ON TLC GEAR. STANDOFFS RUN ON FMS AND DSI. BRIDGED FIRST TWO ATTEMPTS WITH WIRELINE AT 2824'. BRIDGED THIRD ATTEMPT WITH WIRELINE AT 3500'. FOURTH ATTEMPT WAS MADE WITH TLC. DEPTH CORRELATED TO SPERRY 2-DEC-98 NEUTRON/DENSITY/GR. RAN DSI IN UPPER DIPOLE, LOWER DIPOLE, AND P&S MODES. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~' PAGE: 15 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 GR DSI GAPI 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 DTCO DSI US/F 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 DTSM DSI US/F 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 PR DSI 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 RSHC DSI 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DSI LB 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN DSI LB 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 MRES DSI 0tIMM6004719 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMDSI DEGF 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI FMS DEG 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 RB FMS DEG 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 PlAZ FMS DEG 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 HAZI FMS DEG 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 C13 FMS IN 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 C24 FMS IN 6004719 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 5126.500 GR.DSI 111.103 DTCO.DSI 102.963 DTSM. DSI PR.DSI 0.365 RSHC.DSI 2.171 TENS.DSI 2160.000 HTEN. DSI MRES.DSI 3.055 MTEM. DSI 88.633 DEVI.FMS 60.030 RB.FMS P1AZ.FMS 15.734 HAZI.FMS 88.323 Cl3.FMS 5.666 C24.FMS DEPT. 2587.000 GR.DSI 56.617 DTCO.DSI 78.105 DTSM. DSI PR.DSI 0.439 RSHC.DSI 3.035 TENS.DSI 378.000 HTEN. DSI MRES.DSI 4.093 MTEM. DSI 68.712 DEVI.FMS 57.359 RB.FMS P1AZ.FMS 58.310 HAZI.FMS 54.993 Cl3.FMS -999.250 C24.FMS 223.547 378.773 302.083 5.786 237.013 1245.363 7.390 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:b,, PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DSI 8406.5 8142.0 $ LOG HEADER DATA DATE LOGGED: 5-DEC-98 SOFTWARE VERSION: 8Cl-205 TIME CIRCULATION ENDED: 2100 1-DEC-98 TIME LOGGER ON BOTTOM: 920 $-DEC-98 TD DRILLER (FT) : 9210.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 8142.0 BOTTOM LOG INTERVAL (FT) : 8384.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER DSSTB 6.750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~?~ PAGE: 17 LOGGERS CASING DEPTH (FT) : 8369.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX.. MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: RUN#2 REPEAT NO STANDOFFS WERE RUN ON THE DSI DUE TO CASING RESTRICTION RAN DSI IN UPPER DIPOLE, LOWER DIPOLE, AND P&S MODES. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~'~ PAGE: 18 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 GR DSI GAPI 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 TENS DSI LB 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 PR DSI 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 RSHC DSI 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 DTSM DSI US/F 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 DTCO DSI US/F 6004719 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8406.500 GR.DSI 67.884 TENS.DSI 1406.000 RSHC.DSI 1.931 DTSM. DSI 177.461 DTCO.DSI 91.890 DEPT. 8142.000 GR.DSI 90.459 TENS.DSI 4063.000 RSHC.DSI 1.890 DTSM. DSI 176.282 DTCO.DSI 92.390 PR.DSI PR.DSI 0.317 0.306 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/15 ORIGIN · FLIC TAPE NAME : 99099 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA INC, KRU 2L-305, KUPARUK, API #50-103-20279-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAR-1999 15:~v~ PAGE: 19 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/15 ORIGIN : FLIC REEL NAME : 99099 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, KRU 2L-305, KUPARUK, API #50-103-20279-00