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Home My WebLink About199-062Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1G-07A 50-029-20872-01 909383029 Kuparuk River Packer Setting Record Field- Final 22-Jul-24 0 1 2 1G-11B 50-029-21008-02 909469734 Kuparuk River Correlation Record ans SBHP Records Field- Final 29-Jul-24 0 1 3 1G-11B 50-029-21008-02 909469734 Kuparuk River SBHP Record Field- Final 29-Jul-24 0 1 4 1G-17 50-029-22945-00 909422685 Kuparuk River Leak Detect Log Field- Final 13-Jul-24 0 1 5 1G-17 50-029-22945-00 909422685 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-24 0 1 6 1G-17 50-029-22945-00 909422685 Kuparuk River Packer Setting Record Field- Final 13-Jul-24 0 1 7 1L-24 50-029-22170-00: 909422478 Kuparuk River Patch Setting Record Field- Final 6-Jul-24 0 1 8 1Q-04 50-029-21250-00 909422479 Kuparuk River Leak Detect Log Field- Final 10-Jul-24 0 1 9 1Q-04 50-029-21250-00 909422479 Kuparuk River Multi Finger Caliper Field & Processed 10-Jul-24 0 1 10 1Q-09 50-029-21209-00 909422975 Kuparuk River Multi Finger Caliper Field & Processed 19-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 218-051 216-009 199-062 191-066 184-234 184-192 T39436 T39437 T39437 T39438 T39438 T39438 T39439 T39440 T39440 T39441 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:36:38 -08'00' 41G-17 50-029-22945-00 909422685 Kuparuk River Leak Detect Log Field- Final 13-Jul-24 0 1 51G-17 50-029-22945-00 909422685 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-24 0 1 61G-17 50-029-22945-00 909422685 Kuparuk River Packer Setting Record Field- Final 13-Jul-24 0 1 199-062 ! 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Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, November 15, 2021 11:42 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU 1G-17(PTD 199-062, Sundry 321-571) Set Whipstock CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Shane, Is the whipstock a flow through whipstock? Will you still be producing from the lower A Sand perforations? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Whipstock/CTD Set-up 2.Operator Name:4.Current Well Class:5. Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 7372 None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Baker FAB-1 Production Packer,Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Shane Germann James Ohlinger Contact Email: Contact Phone: 406-670-1939 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Staff CTD Engineer Shane.Germann@conocophillips.com Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 25640 199-062 P.O. Box 100360, Anchorage, Alaska 99510 50-029-22945-00 ConocoPhillips Alaska, Inc. N/A KRU 1G-17 Kuparuk River Field / Kuparuk River Oil Pool Length Size L-80 TVD Burst 6574' MD 110' 3934' 110' 4287' 6021'5-1/2" 16" 7-5/8' 79' Baker FAB-1 Production Packer, Baker FA-1 Liner Top Packer 5754' MD / 5140' TVD , 6487' MD / 5770' TVD , 6574' MD / 5851' TVD 11/12/2021 4256' 6755' Perforation Depth MD (ft): 6912'-7004', 7198'-7230' 6726' 3-1/2" 6159'-6235', 6411'-6441' 7358'785' 3-1/2" 6565' 6578 7303'6516'3062 None Perforate Repair Wepair Well Exploratory Stratigraphic Development Service BOP TestMechanicalIntegrity Test Location Clearance No No Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:56 am, Nov 08, 2021 321-571 Digitally signed by James Ohlinger DN: CN=James Ohlinger, O=ConocoPhillips, OU=CTD, E=James.J.Ohlinger@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.11.05 14:25:08-08'00' Foxit PDF Editor Version: 11.0.0 James Ohlinger X 10-404 DSR-11/8/21SFD 11/9/2021VTL 11/15/21 BOP test to 3500 psig Annular preventer pressure to 2500 psig X -00 PTD required for lateral SFD dts 11/15/2021 11/15/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.15 13:44:11 -09'00' RBDMS HEW 11/17/2021 Page 1 of 1 11/5/2021 KRU 1G-17 (PTD #199-062) CTD Summary for Sundry Steps in bold apply to sundry application (pumping cement plug & setting whipstock) Summary of Operations: KRU well 1G-17 is equipped with 3-1/2” liner and tubing, 5.5” production and 7-5/8” surface casing. The CTD sidetrack will utilize one lateral to target the A-sands to the south of 1G-17. A cement plug will be pumped from ~7020’ to ~6900’ RKB to abandon C-Sand perforations. A whipstock will then be set at ~7104’ MD to facilitate milling a window in 3-1/2” Liner CDR3-AC will mill a window in the 3-1/2” liner at ~7104’ MD and the 1G-17L1 lateral will be drilled to TD at 8980’ MD, targeting the A-sands to the south. It will be completed with 2-3/8” slotted liner up to ~7100’ MD. Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1G-17 was measured at 3704 psi @ 6421’ TVD (11.1 ppg) on 9/23/2021. The maximum downhole pressure in the 1G-17 vicinity is 1G-17. Using the maximum formation pressure in the area (1G-17) of 3704 psi, the maximum potential surface pressure in 1G-17, assuming a gas gradient of 0.1 psi/ft, would be 3062 psi. CTD Pre-Rig, CTD Drill and Complete, & Post Rig 1G-17 Operations: Pre-CTD Work (bold applicable to Sundry Application – other steps for reference) 1. Pre-CTD diagnostics 2. Slickline / DSL: Dummy whipstock drift, set RBP, measure SBHP, injectivity test 3. Service CTU: Mill nipples, set composite bridge plug, cement squeeze 4. Service CTU: Mill cement, composite bridge plug 5. E-Line: Set whipstock (Note: w/ WPPT), SBHP Rig Work (for reference) 1. MIRU Nabors CDR3-AC rig using 2” coil tubing. NU 7-1/16” BOPE, test. 2. Drill 1G-17L1 Lateral (A-sand - South) a. Mill 2.80” window at ~7104’ MD. b. Drill 3” bi-center lateral to TD of 8980’ MD. c. Run 2Ǫ” slotted liner up to ~7100’ MD 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work (for reference) 1. Return to production 1G-17 Proposed CTD Schematic 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface Includes 3-1/2" Plastic Coated Tubing 3-1/2" Camco gas lift mandrels @ 2812', 4404', 5202', & 5708' RKB Baker PBR 80-40 @ 5730' RKB Baker FAB-1 Packer @ 5748' RKB Baker FAB-1 Packer @ 6491' RKB 3-1/2" Halliburton DS-nipple @ 6510' RKB (ID = 2.75") Overshot @ 6539' RBK OLD COMPLETION Baker 3-1/2" KBH-22/80-40 seal assembly @ 6557' MD (3" ID) Baker FA-1 liner top packer at 6574' MD D-nipple at 6971' (in 3-1/2" liner) ID = 2.75" Mill out to 2.80" ID for CTD Polish bore at 7022' (in 3-1/2" liner) ID = 2.75" Mill out to 2.80" ID for CTD 7-5/8" 29.7# L-80 shoe @ 4286' MD 5.5" 15.5# L-80 shoe @ 6755' MD 3-1/2" 9.3# L-80 shoe @ 7358' MD A-sand perfs 7198' - 7230' MD KOP @ 7104' MD 16" 62# H-40 shoe @ 110' MD Modified by SJG 11/5/2021 C-sand perfs (sqz'd) 6912' - 7004' MD 1G-17L1 wp04 TD= 8980' MD Top of Liner~ 7100' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 7,212.0 9/23/2021 1G-17 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 9/23/2021 1G-17 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 31.4 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 30.4 Set Depth (ftKB) 4,286.5 Set Depth (TVD) … 3,933.6 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 29.5 Set Depth (ftKB) 6,755.0 Set Depth (TVD) … 6,021.9 Wt/Len (l… 15.50 Grade L-80 Top Thread BTC-MOD Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 6,573.8 Set Depth (ftKB) 7,358.3 Set Depth (TVD) … Wt/Len (l… 9.30 Grade L-80 Top Thread BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,573.8 5,851.2 20.17 PACKER BAKER FA-1 LINER TOP PACKER 3.000 6,578.1 5,855.2 20.17 SLEEVE BAKER C2 TIE-BACK SLEEVE 3.000 6,585.3 5,862.0 20.16 DEPLOY BAKER DEPLOYMENT SLEEVE 3.000 6,970.9 6,207.5 34.04 NIPPLE CAMCO 'D' NIPPLE 2.750 7,022.2 6,250.6 30.73 PBR HALLIBURTON POLISHED BORE NIPPLE 2.750 Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 7.5 Set Depth (ft… 6,539.0 Set Depth (TVD) (… 5,818.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7.5 7.5 0.02 HANGER Tubing Hanger, FMC Gen IV 7-1/16" x 3-1/2" EUE 8rd Top x Bottom, 3" H BPVG 2.992 5,731.3 5,121.3 34.28 SEAL ASSY Baker PBR Seal Assembly 80-40 2.990 5,737.3 5,126.2 34.23 PBR (Polished Bore Receptacle) PBR, Baker, 80-40 4.000 5,740.2 5,128.6 34.21 SEAL ASSY Baker KBH-22 Anchor Seal Assy 3.000 5,753.8 5,139.8 34.12 PACKER Baker FAB-1 Production Packer 3.000 6,486.8 5,770.1 23.16 PACKER Baker FAB-1 Production Packer 3.000 6,502.3 5,784.3 22.18 NIPPLE 2.75" D Nipple 2.750 6,528.8 5,809.0 21.09 OVERSHOT 3.970 Tubing Description Tubing – Production String Ma… 3.55 ID (in) 2.99 Top (ftKB) 6,520.3 Set Depth (ft… 6,573.8 Set Depth (TVD) (… 5,851.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,557.8 5,836.2 20.20 SEAL ASSY KBH-22 anchor seal assembly (PBR) 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,912.0 6,922.0 6,158.7 6,167.1 C-4, 1G-17 3/31/2000 4.0 APERF 2 1/8" EJ DP, 0 deg ph, 0 deg orient 6,932.0 6,942.0 6,175.4 6,183.7 C-4, C-3, 1G-17 4/9/2000 6.0 APERF 2" HSD PJ, 60 deg ph 6,994.0 7,000.0 6,226.7 6,231.8 C-1, 1G-17 3/22/2000 4.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg. oriented, FBSH 7,000.0 7,001.0 6,231.8 6,232.6 C-1, 1G-17 3/22/2000 8.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg. oriented, FBSH 7,001.0 7,004.0 6,232.6 6,235.1 C-1, 1G-17 3/22/2000 4.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg. oriented, FBSH 7,198.0 7,210.0 6,410.6 6,422.0 A-4, 1G-17 12/7/1999 4.0 IPERF 2 1/8" Enerjet, 0 deg. ph 7,210.0 7,218.0 6,422.0 6,429.6 A-4, A-3, 1G-17 1/10/2000 8.0 APERF 2 1/8" strip gun, 0 deg. ph 7,218.0 7,230.0 6,429.6 6,441.0 A-3, 1G-17 1/10/2000 4.0 APERF 2 1/8" strip gun, 0 deg. ph Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) FRAC 1/21/2000 0.0 0.00 0.00 Mandrel Inserts St ati on N o/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 2,809.9 2,715.9 35.59 Camco KGB 2- 9 1 GAS LIFT GLV BTM 0.188 1,289.0 11/3/2020 2 4,402.5 4,029.5 34.28 Camco KGB 2- 9 1 GAS LIFT OV BTM 0.250 0.0 2/17/2021 3 5,200.1 4,684.9 34.95 Camco KGB 2- 9 1 GAS LIFT DMY BTM 0.000 0.0 12/9/2018 4 5,706.2 5,100.5 34.46 Camco KGB 2- 9 1 GAS LIFT DMY BTM 0.000 0.0 10/13/2018 Notes: General & Safety End Date Annotation 10/8/2018 Note: Well has Plastic Coated Tubing from 5736' to 6494' 1G-17, 9/24/2021 5:43:31 AM Vertical schematic (actual) LINER; 6,573.8-7,358.3 APERF; 7,218.0-7,230.0 APERF; 7,210.0-7,218.0 IPERF; 7,198.0-7,210.0 APERF; 7,001.0-7,004.0 APERF; 7,000.0-7,001.0 APERF; 6,994.0-7,000.0 APERF; 6,932.0-6,942.0 APERF; 6,912.0-6,922.0 PRODUCTION; 29.5-6,755.0 SEAL ASSY; 6,557.8 OVERSHOT; 6,528.8 Tubing - Pup; 6,507.2 Tubing - Pup; 6,497.1 PACKER; 6,486.8 PACKER; 5,753.8 SEAL ASSY; 5,740.2 PBR (Polished Bore Receptacle); 5,737.3 SEAL ASSY; 5,731.3 GAS LIFT; 5,706.1 XO Threads; 5,668.6 XO Threads; 5,215.8 GAS LIFT; 5,200.1 XO Threads; 5,159.0 XO Threads; 4,960.3 GAS LIFT; 4,402.4 SURFACE; 30.4-4,286.5 GAS LIFT; 2,809.9 CONDUCTOR; 31.4-110.0 XO Threads; 35.8 HANGER; 7.5 KUP PROD KB-Grd (ft) Rig Release Date 11/13/1999 1G-17 ... TD Act Btm (ftKB) 7,365.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294500 Wellbore Status PROD Max Angle & MD Incl (°) 35.77 MD (ftKB) 2,750.00 WELLNAME WELLBORE1G-17 Annotation Last WO: End Date 10/6/2018 H2S (ppm) 50 Date 8/12/2016 Comment SSSSV: None From:Germann, Shane To:Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]KRU 1G-17(PTD 199-062, Sundry 321-571) Set Whipstock Date:Monday, November 15, 2021 11:45:17 AM Hi Victoria, Yes, the whipstock will be flow-through and the A sand perforations will remain open and able to produce. Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, November 15, 2021 11:42 AM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU 1G-17(PTD 199-062, Sundry 321-571) Set Whipstock CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Shane, Is the whipstock a flow through whipstock? Will you still be producing from the lower A Sand perforations? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, cJr) 0 • 0o v L f- > a0 -0 0 0, 7 .-a...-. _ - , p L_ � E Z ccp `- -O 03 td O OW O r 1 I i r ro 0 vy Cl) O Q0y. tJ a a C C C 4- 1--� ro +O' '0 -C 'p tW- n - co C v a > Q p - UJ r- n r- n r- N- r r` NI N. WI I I I I a) 0 6 CO < 0 f.) 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December 10, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 D,rA o/o c M.K.BENDER RE: Production Profile: 1G-17 Run Date: 10/7/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1G-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22945-00 Production Profile Log SNNE 1 Color Log 50-029-22945-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: M.AizamosoL..17) u��k `99-062 i • V4-19 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 17, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1G-17 scow Run Date: 4/12/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22945-00 Production Profile Log 1 Color Log 50-029-22945-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: J �- Signed: L99- 0C 2 2 09 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 7, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1G-17 Run Date: 8/27/2011 ' ' NNEO The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22945-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: frlitizat31) Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / (~q'- (~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: ~ - C~ Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA n OVERSIZED Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: (3 Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dian~athan Lowell STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMIS* , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well (""' Rug Perforations r Stimulate r Other Install Patch Alter Casing r Pull Tubing (— Ftrforate New Pool r Waiver E Time Extension r Change Approved Program r Operat. Shutdown r Perforate f Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory f - 199 - 062 3. Address: 6. API Number: Stratigraphic r Service I- P. 0. Box 100360, Anchorage, Alaska 99510 50 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25640 . 1G-17 9. Field /Pool(s): t Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7372 feet Plugs (measured) None true vertical 6578 feet Junk (measured) None Effective Depth measured 7303 feet Packer (measured) 6332, 6351, 6574 true vertical 6516 feet (true vertucal) 5630, 5647, 5851 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 SURFACE 4256 7.625 4286 3934 PRODUCTION 6725 5.5 6755 6021 LINER 785 3.5 7358 6565 RECEII 1 fCT t Perforation depth: Measured depth: 6912'- 6922', 6932'- 6942', 6994'- 7004', 7198' -7230' True Vertical Depth: 6159'-6167', 6175'- 6184', 6227'-6235', 6411'-6441' Alaska fill $ !"9$ :o: ission,4 S. Cor Tubing (size, grade, MD, and TVD) 3.5, L -80, 6574 MD, 5851 TVD NIPPLE - CAMCO DS LANDING NIPPLE @ 516 MD and 516 TVD Packers & SSSV (type, MD, and TVD) PACKER - WEATHERFORD ER PACKER @ 6332 MD and 5630 TVD PACKER - WEATHERFORD ER PACKER @ 6351 MD and 5647 TVD PACKER - BAKER FA -1 LINER TOP PACKER @ 6574 MD and 5851 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 175 758 522 -- 152 Subsequent to operation 260 1018 1252 -- 171 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ■ _ Service r Stratigraphic r 15. Well Status after work: . Oil j✓ Gas r VWSPL r Daily Report of Well Operations XXX GSTOR j"" WINJ la WAG r GINJ U SUSP r SPLUG r 16. 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: none Contact John Peirce a 265 -6471 Printed Name John Peirce Title Wells Engineer Signature ...6:::1511.. Phone: 265 -6471 Date l 74 Form 10-404 Revised 10 /201RBDMS OCT 17 Mt ° t- /0 ZO'ft Submit Original Only 1G -17 Well Work Summary DATE SUMMARY • 3/7/11 RE -TIFL- FAILED (INFLOWED 35 .) 3/22/11 SET ER TEST TOOL @ 6458' RKB. ATTEMPTED MIT, NO SUCCES. WITH HOLE FINDER @ 6005' SLM, TESTED TBG, PASSED. PULLED ER TEST TOOL @ 6458' RKB. JOB SUSPENDED. 4/21/11 SET 3" ER TEST TOOL @ 6458' RKB. ESTABLISHED LEAK RATE: 1 BPM. READY FOR E/L LEAK DETECT LOG. 5/23/11 PERFORMED LEAK DETECT AND 24 ARM MIT CALIPER LOG. PUMPED DIESEL DOWN TUBING TAKING RETURNS UP THE IA JUMPERED TO FLOWLINE. PUMPED 77 BBLS TOTAL. LEAK WAS LOCATED MID - JOINT AT 6344'. 7/17/11 PULLED 3" ER TEST TOOL @ 6458' RKB. MEASURED BHP @ 7067' SLM: 2217 PSI. BRUSHED & FLUSHED TBG FROM 6400' TO 6300' RKB. READY FOR E /L. 7/22/11 SET WEATHERFORD ER PACKER AT 6354' MID ELEMENT. CCL TO MID ELEMENT: 14.7'. CCL STOP AT 6339.3'. 8/19/11 SET ER TEST TOOL IN ER PKR @ 6354' RKB. ATTEMPTED TO COMBO MIT T X IA, FAILED. PULLED ER TEST TOOL, ER PKR MOVED DN HOLE TO TOP OF LOWER PATCH ASS'Y. PULLED ER PKR SET ON ,(// 7/22/11 @ 6354' RKB. JOB COMPLETE 8/27/11 SET WEATHERFORD 3.5" ER PACKER AT 6354' RKB. CORRELATE TO HES LEAK DETECT LOG DATED 23 MAY 2011, CCL TO MID ELEMENT: 14.9', CCL STOP DEPTH: 6339.1' 9/12/11 SET TEST TOOL IN LOWER ER PKR @ 6354' RKB. CIRCULATED 120 BBL DSL TO FLUID PACK. ATTEMPTED COMBO MIT T x IA TO 1500 PSI, FAILED. IN PROGRESS. 9/13/11 PULLED ER TEST TOOL @ 6354' RKB & REPLACED WITH NEW. COMBO MITT x IA 2000 PSI, PASSED. SET 21.39' UPPER PATCH ASS'Y (ER PKR, SPACER & SNAP LATCH ASS'Y) @ 6332' RKB. SET ER TEST TOOL IN UPPER ER PKR @ 6332' RKB. ATTEMPTED TEST TBG, IA COMMUNICATING. PULLED & SET FRESH TEST TOOL IN UPPER ER PKR. IN PROGRESS. 9/14/11 MIT TBG AGAINST ER TEST TOOL IN UPPER PKR TO 2000 PSI, PASSED. PULLED TEST TOOL. COMPLETE. 9/18/11 RE -TIFL (PASSED) KUP 1G -17 Como:A:411110 WVLl aA r1wteeeea_ Max Angle & MD TD ' Wellbore APYUWI (Field Name Well Status Ind (1 IUD (ftKB) Act Btin (ftKB) f.5rn�°o}7�nN(# 500292294500 JKUPARUK RIVER HMI T PROD 3577 2,75000 735/0 " Comment 'H2S (ppm) 'Date Annotation End Date KBGrtl (ft) Rig Release Date SSSV: NIPPLE 60 8/6/2009 Last WO: i 11 lS+.: _ — , ��AGlita) , A notation Depth (ftK6) End Date Annotation Last Mod .. End Date Last Tag: SLM 7,209 0 10/10/2010 Rev Reason: SET PATCH ASSEMBLY ninam 1 9/15 HANGER, 20 ' � ' — Casing Strings Casing Description String 0... String ID Top (ft66) Set Depth (f .. Set Depth (TVD) String Wt... String String Top Thrd CONDUCTOR 16 15.062 31.4 110 0 110 0 62.58 H - 40 WELDED Casing Dese pt String 0... String ID Top (ftKB) Set Depth (f Set Depth (TVD) ... String Wt... String String Top Thad "" SURFACE 7 5/8 6.875 30.4 4,286 5 3,933 6 29.70 L BTCM Casing Description String 0... Siring ID Top (ftKB) Set Depth (t Set Depth (ND) ... String Wt... String String Top Thad PRODUCTION 5 1/2 4.950 29 5 6,755 0 6,020 6 15.50 L BTC MOD Casing Description String 0._ String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 6,573.8 7,358.3 9.30 L -80 BTCM Liner Details CONDUCTOR, Top Depth 3t- 110 ° . (TVD) Top Inc! Noma... NIPPLE, 516 - - --- > t T9R9B) MKS) C) Item Description __.. _�. Comment ID(in) 6,573 -8 5,851.2 20.24 PACKER BAKER FA -1 LINER TOP PACKER 3.000 6,578.1 5,855.2 20.22 SLEEVE BAKER C2 TIE -BACK SLEEVE 3.000 6,585.3 5862.0 20.19 DEPLOY BAKER DEPLOYMENT SLEEVE 3.000 6,970.9 6,208.1 35.65 NIPPLE CAMCO D' NIPPLE 2.750 GASLIFT, 27+0 ^ 7,0222 6,250.8 30 73 PBR HALLIBURTON POLISHED BORE NIPPLE 2.750 illt Tubing Strings Tubing Description '.String 0... String ID _ Top ( Set Depth (f... Set Depth (ND) . IString Wt... Sting 'String Top Thrd I '1 1 UBINO 3 1/2 l 2992 I 27 6 1 6,573 8 5. 851 2 9 30 l L-80 EUE8RDMOD Completion Details Top Depth ND (TVD) Top Intl GAS LIFT, ____ —._. 6,276 Top (ftKB) (ftKB) C) Item Description Comment ID OM 0 20 BANGER FMC TUBING HANGER 3.500 27.6 27 6 __. s 6,518.3 5,799.3 0 54 NIPPLE CAMCO DS LANDING NIPPLE 2.812 300 -42 515.6 515 6 1 2152 NIPPLE CAMCO W NIPPLE 2.812 AV 6,557.8 5,836.2 20 31 PBR BAKER KBH- 22/80-40 PBR 3.000 Mt GAS LIFT, Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) " '" 5,264 , Top Depth .ti�L (TVD) Top Intl lit Topltitcg) (EKB) (3 Description Comment Run Date ID (in) lit 6,332 5,630.1 25 66 PACKER WEATHERFORD ER PACKER 9/13/2011 1.750 GAS LIFT.- - 5 - -- 6.334 5,631.9 25 63 PATCH SPACER PIPE, SNAP LATCH SEAL ASSEMBLY 9/13/2011 1 750 6.351 5,647 4 25 59 PACKER WEATHERFORD ER PACKER 8/27/2011 1 750 PACKER, 6.332 — r" 1 Perforations & Slots Shot PATCH, 6,334 —'- Top (TVD) Btm (TVD) Dens PACKER, 6,351 -- ' - Top (ftKB) Ban ULM_- ( WM) )ftKB) Zone ... _ Date (s - Type_ Comment 6,912 6,922 6,158.6 6,166.9 C-4, 1G-17 3/31/2000 4.0 APERF 2 1/8" EJ DP, 0 deg ph, 0 deg orient 6,932 6,942 6,175.3 6,183.7 C-4, C -3, 1G -17 4/9/2000 6.0 APERF 2" HSD PJ, 60 deg ph Gas LIFT, 6,994 7,000 6,226.8 6,231.8 C -1, 1G-17 3/22/2000 4.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg. 6A67 J oriented, FBSH u 7,000 7,001 _ 6,231.8 6,232.6 C -1, 1G-17 3/22/2000 8.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg. NIPPLE, 6,519 - --" odented, FBSH • 7,001 7,004 6,232.6 6,235.1 C -1, 1G-17 3/22/2000 4.0 APERF 2 1/8" EJ DP, 0 deg. ph, 0 deg . oriented, FBSH P8R,6,558 7,198 7,210 6,410.6 6,422.4 A -4, 1G-17 12/7/1999 4.0 IPERF 2 1 /8" Ener)et, 0 deg. ph - 7,210 7,218 6,422.4 6,429.8 A-4, A -3, 1G -17 1/10/2000 8 0 APERF 2 1/8" strip gun, 0 deg. ph III gun 7,218 7,230 6,429.8 6,441.1 A -3, 1G -17 1/10/2000 4.0 APERF 2 1 /8" strip gun, 0 deg. ph Notes General & Safety _ End Date Annotation aki I'; 9/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PRODUCTK)N, L 30 -6,755 APERF —� 6,912 -6,922 - APERF. 6,932 - 6.942 - ..... IN APERF.- w>ca. 6,994-7,000 APERF, 7,000 -7,001 ._ APERF. ._. ._ ._.. _... 7.091-7.001 Mandrel Details • Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run ,Stn Top (ftKB) (MKS) (1 Make Model (in) Sera Type Type (In) (psi) Run Date Can._ 1 2,740.3 2,659.4 35.68 CAMCO KBG29 1 GAS LIFT GLV BTM 0.156 1,160.0 2/222011 __-- 2 4,273.6 3,923.0 34.40 CAMCO KBG29 1 GAS LIFT GLV BTM 0.188 1,190.0 2/22/2011 3 5,2433 4,720.7 35.01 CAMCO KBG29 1 GAS LIFT OV BTM 0.188 0.0 2/22/2011 IPERF, 7,199 - 7,210 - ' - -- _„ 4 5,963.1 5,314.7 ® CAMCO KBG29 1 GAS LIFT DMY BTM 0.000 0.0 9/25/2008 APERF, 7,219 5 6,467.1 5,752.1 23.63 CAMCO KBG29 1 GAS LIFT PATCH 0.000 0.0 11/13/2008 TD, 7,357 .iii i LINER,__...__ -_ -_ 6,57x7,356 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1G -17 Run Date: 5/23/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-17 Digital Data in LAS format, Digital Log Image file d � 1 CD Rom 50- 029 - 22945 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: , 3 l Signed: al/LEI • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Settting: 1G -17 Run Date: 7/22/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-17 Digital Data in LAS format, Digital Log Image file v1 18(4.0 1 CD Rom 50- 029 - 22945 -00 ' ', !; ) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com ( ed: 11-0- Date: a L1 Si M ° • • WELL LOG TRANSMITTAL PROAcTivE DiAgnosTic SERVICES, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road , Suite C i- i Lo? Anchorage, AK 99518 Fax: (907) 245 -8952 lc( c- ©c 1) Caliper Report 23- May -11 1 G-17 1 Report / CD 50-029- 22945 -00 2) ig• Signed : OL Date : Print Name: 11.4kp.s of t43 --- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E -MAIL : PDSANCHORAGE(a)MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips_Transmit.docx 1 • • I 1111 Memory Multi- Finger Caliper rs Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1G -17 Log Date: May 23, 2011 Field: Kuparuk Log No.: 10258473 ZX70 State: Alaska I Run No.: 3 API No.: 50- 029 - 22945 -00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RDMOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 6,444 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage COMMENTS : 1 The caliper data is correlated to the tubing tally record per HES MIT log comments. This log was run to assess the condition of the 3.5" tubing between GLM 4 and the existing patch, where I TxIA communication is suspected. The caliper recordings do not indicate any significant wall penetrations or areas of cross- sectional wall Toss throughout this interval. A 3-D Log plot across this interval is included in this report. I The caliper recordings indicate the remainder of the 3.5" tubing logged appears to be in good condition with respect to internal corrosive damage. No significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the log interval. I This is the third time a caliper has been run in this well and the 3.5" tubing has been logged. A comparison between the current and previous log (October 22, 2008) indicates little if any increase in corrosive damage. A comparison plot illustrating the difference in maximum recorded penetrations between 1 logs on a joint-by-joint basis is included in this report. This summary report is an interpretation of data provided by Halliburton Energy Services. I MAXIMUM RECORDED R D WALL PENETRATIONS: 1 No significant wall penetration (> 12 %) are recorded throughout the logged interval. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: I No significant cross - sectional wall loss ( > 3 %) are recorded throughout the logged interval. 1 MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the logged interval. 1 1 I Field Engineer: Biery & C. Sobhon Analyst: C. Lucasan Witness: B. Boehme ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS,cymemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 # i Gt(o ( / -0 6a. I • • PDS Multifinger Caliper 3D Log Plot I c1P., Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1G-17 Date : May 23, 2011 I Description : Detail Caliper Recordings Across the Interval of Suspected Leak. Comments Depth Max. Penetration Maximum I.D. 3 -D Log Image Map 1111 =Sr i 1ft:240ft 0 % 100 2.5 Inch 3.5 0° 0 90° 180° 270° 0° I I Minimum I.D. f 2.5 Inch 3 -5 Nominal I.D. 2.5 -- - -- 3.5 . • a- 5920 - -- ti -- 5930 i Joint 186 I 5940 1 - . ' 5950 �._. ___. -1:1 --..,-.— Pup Jt. 186.1 I 5960 - - -- — — ____Iizt__. , GLM 4 ( _ . - I 5970 ill - - — — — Pup Jt. 186.3 5980 - 5990 -- - -- _ I Joint 187 6000 I 6010 — - -- __ _ ' 6020 } I 1 I Joint 188 6030 -- - - - -- 1 i 1—L - ' -- — — _ r 6040 _ � le I f 6050 i - - -- — - -- 1 ( — 6060 Joint 189 — � , I • i 6070 .— -- _ — I Nom ( i -�� 6080 ��N �� lE 6090 ��l� Ill . ! �- _I:7; Joint 190 1 � x . — w I 6100 — = a I 6110 IIIIII i simminowir No 111111MMIIIIlEMMIMINIM 6120 _____c ____• — M•� =�lr 11111•11111=11111 y Joint 191 IMM�IMlk I•MI�� - - -t� 6130 1 UlIlU It,l _ l. _ __ ��t�� I �EIM�IM M�MMItIM��MM - IM��MIIt ammimm 6140 IIIMMNIIIIIIbT AIIIIIMINIIIIII i .iiuru��iu :::::::::111 =MEM MU Joint 192 --_ .: 0170 6150 = •IIIMEMIIIl 0180 Joint 193 IN ilimm NI ' 6200 1111111 mum =mom MIME IIIIIMMINIs O ' 6210 1 mum ...... j . _ _ �m a �� Emil MEM. ; I __ EMU I Joint 194 6220 . .U.� �. - - -- _ II 6230 - - MENEM 6240 - - -- . -- -- ------ Joint 195 6250 III I 6260 111111111•111111." - I • • 6270 - - - - - -- _ —_ — Joint 6280 oint 196 - - - -- - - — . * _ _; 6290 — - - -- — — — 1 1 j ire,- 1 6300 — _.,....._ - =_ 4 ___ ....„,_ Joint 197 6310 = - I = '�" 6320 1 — ----- I I 6330 ur - . ��SF _- �� /F �� 6340 = �� t . r• IN ...,........ ..„. " Joint 198 IN L 1 6350 6360 °s.` Miff MI MI Fill =IFS =lit NI Mf F Illy Joint 199 6370 ��`f- 1111111 ME _ 6380 1 MHOS . 1 mho 11 ,....., , _,__ 4,.... _ 7.: 6390 Im 1 - --- 6 400 I -- _ — Joint 200 - 1 6410 4 -- I 6420 ' -- 1 I - i L 1= - - - -- - -- Joint 201 6430 it I1f 6440 - - -- -- I . i Nominal 1.D. 2.5 3.5 I I-- Minimum I.D. 2.5 Inch 3.5 Comments Depth Max. Penetration Maximum I.D. 3 -D Log Image Map —F-- I 1ft:240ft 0 % 100 2.5 Inch 3.5 0° 0 90° 180° 270° 0° I I • • Correlation of Recorded Damage to Borehole Profile I a Pipe 1 3.5 in (26.7' - 6421.1') Well: 1G-17 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 23, 2011 I I II Approx. Tool Deviation II Approx. Borehole Profile 1 30 . .-.3 25 794 i vo 1 50 1573 ..i ii4411ip 1 GLM 1 I 75 1 2350 -A 0 II iii 100 E a 3163 c Z - ti o 125 —1 3944 1 GLM 2 — 1 150 "4 4760 - 4 1 GLM 3 MI 175 5574 I GLM 47 iii 200 r 6390 1 201 6421 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 201 I I I I • • 1 Maximum Recorded Penetration I (—",„ S. Comparison To Previous Well: 1G-17 Survey Date: May 23, 2011 Field: Kuparuk Prey. Date: October 22, 2008 I Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 (HAL) Country: USA Tubing: 3.5" 9.3 lb L -80 EUE 8RD MOD I Overlay Difference Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) 0 50 100 150 200 250 -100 -50 0 50 100 0.1 0.1 7 7 16 16 26 26 E. i 36 36 46 46 ."'" 56 56 I 66 66 76 76 I 86 86 g 93 _ 93 E - E I Z 103 Z 103 S 0 113 a 113 j 123 123 v I 133 133 140 140 I 150 150 3 . 160 160 = 1 167 — 167 v 177 177`- 186.1 186.1 1 194 194 I -39 -19 0 19 39 ■ May 23, 2011 ■ October 22, 2008 Approx. Corrosion Rate (mpy) I I I 0 • I Report Overview �,.. Body Region Analysis I Well: 1G-17 Survey Date: May 23, 2011 Field: Kuparuk Tool Type: UW MFC 24 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD MOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins I Penetration(% wall) Damage Profile (% wall) I 250 ■ Penetration body Metal loss body 0 50 100 200 0 I 150 100 I 50 0 47 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 2131 I 213 0 0 0 GLM 1 95 I Damage Configuration ( body) 4 I GLM 2 143 GLM 3 a I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. NO GLM 4 189 Number of joints damaged (total = 0) I 0 0 0 0 0 Bottom of Survey = 201 I I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 1G -17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 23, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 27 0 0.03 1 1 0 2.93 Pup Lt. Deposits. 1 30 0 0.02 9 2 2.94 1.1 61 0 0.02 7 2 2.94 Pup 1.2 69 0 0.01 6 (1 2.94 Pup 1.3 72 0 0.02 9 I 2.96 Pup I 2 76 0 0.03 11 I 2.94 3 107 0 0.02 9 2 2.92 Lt. Deposits. 4 139 0 0.02 7 2 2.96 5 170 0 0.02 8 2 2.91 Lt. Deposits. I 6 201 0 0.02 7 1 2.97 7 232 0 0.03 10 2 2.93 Lt. Deposits. 8 264 0 0.03 12 2 2.95 9 295 0 0.02 9 2 2.93 Lt. Deposits. 1 10 326 0 0.03 11 1 2.93 Lt. Deposits. 11 358 0 0.02 9 1 2.96 12 389 0 0.02 8 2 2.93 Lt. Deposits. 13 421 0 0.03 10 2 2.94 14 452 0 0.02 9 2 2.94 I 15 483 0 0.02 9 2 2.94 15.1 514 0 0 0 0 2.81 Camco DS Landing Nipple 16 516 0.03 0.03 11 2 2.95 17 547 0 0.02 9 2 2.95 '' 18 578 0 0.02 9 2 2.94 19 609 0 0.03 11 2 2.94 20 639 0 0.02 9 1 2.94 21 670 0 0.02 8 1 2.94 I 22 701 0 0.03 11 2 2.94 23 732 0 0.02 7 1 2.91 Lt. Deposits. 24 762 0 0.02 9 1 2.96 25 794 0 0.03 11 2 2.90 Lt. Deposits. 26 825 0 0.02 7 2 2.94 I 27 856 0 0.03 11 2 2.96 28 887 0 0.03 11 2 2.94 29 919 0 0.03 12 2 2.95 30 950 0 0.02 9 2 2.95 I 31 981 0 0.02 8 2 2.96 32 1012 0 0.02 8 1 2.91 Lt. Deposits. 33 1043 0 0.03 10 2 2.93 Lt. Deposits. 34 1073 0 0.02 8 1 2.93 Lt. Deposits. I 35 1104 0 0.03 11 2 2.92 Lt. Deposits. 36 1135 0 0.02 9 2 2.95 37 1166 0 0.03 11 1 2.94 , 38 1197 0 0.03 10 2 2.91 Lt. Deposits. I 39 1228 0.04 0.03 12 1 2.96 40 1259 0 0.02 8 2 2.94 41 1291 0 0.03 11 1 2.95 42 1322 0 0.03 12 1 2.94 43 1353 0 0.02 8 2 2.94 I 44 1385 0 0.02 8 2 2.94 45 1416 0 0.02 9 2 2.94 I rat Metal Loss ion BoBody dy I Page 1 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 1G-17 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Nominal I.D.: 2.992 in Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 23, 2011 I Joint Jt. Depth Pee. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 46 1447 0 0.02 6 1 2.94 47 1479 0 0.02 9 1 2.96 48 1510 0 0.03 11 2 2.95 ni 49 1542 0 0.02 7 1 2.94 50 1573 0 0.01 6 1 2.92 Lt. Deposits. 51 1604 0 0.02 8 1 2.93 Lt. Deposits. 52 1636 0 0.02 9 1 2.95 53 1667 0 0.02 7 1 2.94 54 1698 0 0.01 6 2 2.96 I 55 1729 0 0.03 10 1 2.94 56 1760 0 0.02 9 1 2.92 Lt. Deposits. 57 1792 0 0.02 9 2 2.94 58 1822 0 0.02 7 2 2.92 Lt. Deposits. 59 1854 0 0.02 9 2 2.94 1 60 1885 0 0.02 9 2 2.94 61 1917 0 0.02 7 2 2.94 62 1948 0 0.03 12 1 2.94 63 1979 0 0.02 8 1 2.94 I 64 2009 0.12 0.02 6 1 2.94 65 2041 0 0.02 9 1 2.93 Lt. Deposits. ■ 66 2070 0 0.02 9 I 2.96 67 2101 0 0.01 6 2 2.95 I 68 2131 0 0.02 9 2 2.94 69 2162 0 0.02 8 3 2.96 70 2193 0 0.03 11 2 2.96 71 2224 0 0.02 7 1 2.95 I 72 2256 0 0.03 10 2 2.94 73 2287 0 0.02 7 3 2.91 U. Deposits. 74 2318 0 0.03 12 2 2.92 Lt. Deposits. 75 2350 0.22 0.02 8 1 2.92 Lt. Deposits. I 76 2381 0 0.02 7 2 2.93 Lt. Deposits. 77 2412 0.04 0.02 7 1 2.94 78 2444 0 0.02 9 I 2.92 Lt. Deposits. 79 2475 0 0.02 8 1 2.94 80 2506 0 0.02 8 2 2.94 I 81 2538 0 0.02 6 2 2.97 82 2569 0 0.02 7 2 2.94 83 2600 0 0.03 10 2 2.92 Lt. Deposits. 84 2631 0 0.02 8 1 2.94 I 85 2663 0 0.02 7 2 2.93 Lt. Deposits. 86 2694 0 0.02 9 2 2.94 86.1 2724 0 0.02 9 2 2.93 Pup Lt. Deposits. 86.2 2739 0 0 0 0 2.90 GLM 1 (Latch V/ 5:00) I 86.3 2745 0 0.01 6 1 2.94 Pup 87 2759 0 0.02 8 2 2.92 Lt. Deposits. 88 2791 0 0.02 8 1 2.95 89 2822 0 0.02 8 2 2.93 Lt. Deposits. 90 2853 0 0.01 6 1 2.94 I 91 2884 0.04 0.02 9 2 2.96 92 2916 0 0.02 9 2 2.93 Lt. Deposits. I Penetration Body Metal Loss Body Page 2 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 1G-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 23, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 93 2947 0 0.02 6 2 2.95 I 94 2978 0 0.03 10 2 2.93 Lt. Deposits. 95 3010 0 0.02 7 2 2.97 96 3040 0.05 0.03 10 1 2.93 Lt. Deposits. 97 3071 0 0.02 9 1 2.93 Lt. Deposits. I 98 3100 0 0.03 10 1 2.94 99 3132 0 0.02 7 2 2.94 100 3163 0 0.02 8 2 2.94 101 3194 0 0.03 11 2 2.93 Lt. Deposits. I 102 3226 0 0.03 10 2 2.93 Lt. Deposits. 103 3257 0.04 0.03 11 2 2.94 104 3288 0 0.02 7 2 2.97 105 3319 0 0.01 6 1 2.96 I 106 3350 0 0.02 9 2 2.94 107 3381 0 0.02 7 1 2.94 108 3413 0 0.02 7 1 2.93 Lt. Deposits. 109 3444 0 0.01 6 2 2.97 110 3475 0 0.02 6 1 2.93 Lt. Deposits. I 111 3506 0 0.02 7 1 2.95 112 3537 0.03 0.03 11 2 2.95 113 3569 0 0.03 12 2 2.92 Lt. Deposits. 114 3600 0 0.02 8 1 2.96 I 115 3631 0 0.03 10 2 2.95 116 3663 0 0.02 7 1 2.96 117 3694 0 0.02 7 2 2.92 Lt. Deposits. 118 3725 0 0.03 10 1 2.93 Lt. Deposits. I 119 3757 0 0.03 10 2 2.95 120 3788 0 0.02 9 1 2.94 121 3819 0.04 0.02 7 2 2.94 122 3850 0.03 0.03 10 1 2.92 Lt. Deposits. 123 3881 0 0.03 10 1 2.94 I 124 3912 0.03 0.02 9 1 2.93 Lt. Deposits. 125 3944 0 0.02 9 1 2.92 Lt. Deposits. 126 3975 0.03 0.02 7 2 2.95 127 4006 0 0.02 9 2 2.94 , I 128 4038 0 0.03 12 1 2.91 Lt. Deposits. 129 4069 0.03 0.02 8 1 2.96 130 4100 0 0.02 9 2 2.96 131 4131 0 0.02 9 1 2.94 I 132 4163 0 0.03 12 1 2.93 Lt. Deposits. 133 4194 0 0.02 9 2 2.94 134 4226 0 0.02 8 1 2.92 Lt. Deposits. 134.1 4257 0 0.02 9 2 2.98 Pup I 134.2 4272 0 0 0 0 2.90 GLM 2 (Latch @ 8:30) 134.3 4278 0 0.03 11 3 2.98 Pup 135 4292 0 0.02 9 1 2.93 Lt. Deposits. 136 4324 0 0.03 11 2 2.94 137 4355 0 0.03 11 1 2.93 Lt. Deposits. i I 138 4387 0 0.03 11 1 2.94 139 4418 0 0.03 11 1 2.96 Penetration Body I Metal Loss Body I Page 3 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 1 G -17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 23, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I cuss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 140 4449 0 0.02 7 2 2.95 I 141 4481 0.03 0.03 10 1 2.90 Lt. Deposits. 142 4512 0 0.02 8 1 2.92 Lt. Deposits. 143 4543 0 0.02 8 1 2.96 144 4574 0 0.02 9 2 2.92 Lt. Deposits. I 145 4605 0 0.03 11 2 2.94 146 4637 0 0.02 9 2 2.92 Lt. Deposits. 147 4667 0 0.02 9 2 2.92 Lt. Deposits. 148 4698 0 0.02 9 2 2.93 Lt. Deposits. I 149 4728 0 0.02 6 1 2.94 150 4760 0 0.02 8 1 2.92 Lt. Deposits. 151 4791 0 0.03 10 1 2.93 Lt. Deposits. 152 4822 0 0.03 11 2 2.94 I 153 4854 0 0.02 9 2 2.93 Lt. Deposits. 154 4885 0 0.03 10 1 2.91 Lt. Deposits. 155 4916 0 0.03 10 1 2.91 Lt. Deposits. 156 4947 0 0.03 11 2 2.93 Lt. Deposits. 157 4979 0.03 0.03 12 1 2.90 Lt. Deposits. I 158 5010 0 0.03 11 2 2.91 Lt. Deposits. 159 5040 0 0.02 9 2 2.92 Lt. Deposits. 160 5071 0 0.02 9 2 2.93 Lt. Deposits. 161 5102 0 0.02 7 1 2.92 , Lt. Deposits. I 162 5133 0 0.03 10 2 2.90 Lt. Deposits. 163 5164 0 0.03 11 1 2.93 Lt. Deposits. 164 5196 0 0.02 9 2 2.91 Lt. Deposits. 164.1 5227 0 0.02 8 2 2.92 Pup Lt. Deposits. 164.2 5241 0 0 0 0 2.90 GLM 3 (Latch @ 8 :00) 164.3 5248 0 0.03 11 1 2.95 Pup 165 5262 0 0.02 9 2 2.91 Lt. Deposits. 166 5293 0 0.03 11 2 2.92 Lt. Deposits. 167 5325 0 0.02 6 2 2.95 I 168 5357 0.04 0.02 7 2 2.92 Lt. Deposits. 169 5388 0 0.01 6 1 2.96 170 5419 0 0.02 8 2 2.96 171 5450 0 0.02 6 2 2.94 I 172 5481 0 0.03 11 2 2.94 173 5513 0 0.03 10 2 2.94 174 5543 0 0.03 10 2 2.93 Lt. Deposits. 175 5574 0 0.02 8 1 2.95 I 176 5607 0 0.02 7 1 2.96 177 5637 0 0.03 11 2 2.91 Lt. Deposits. 178 5669 0 0.02 8 2 2.94 179 5699 0 0.02 8 2 2.94 180 5729 0 0.02 7 2 2.91 Lt. Deposits. I 181 5760 0 0.02 7 2 2.92 Lt. Deposits. 182 5792 0 0.02 8 2 2.95 183 5823 0 0.02 8 2 2.95 184 5854 0 0.02 7 1 2.91 Lt. Deposits. I 185 5886 0 0.03 11 1 2.94 186 5917 0 0.02 7 1 2.95 I Penetration Body I Metal Loss Body Page 4 I 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8RD MOD Well: 1G-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 23, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 186.1 5948 0 0.02 8 1 2.93 Pup Lt. Deposits. I 186.2 5963 186.3 5969 0 0 0 0 2.89 GLM 4 (Latch @ 7:00) 0 0.03 12 2 2.93 Pup Lt. Deposits. ■ 187 5984 1) 0.02 9 1 2.95 is 188 6015 0.04 0.03 11 2 2.94 I 189 6046 0 0.02 8 2 2.93 Lt. Deposits. 190 6077 0 0.02 7 2 2.93 Lt. Deposits. 191 6109 0 0.02 7 2 2.95 192 6140 0 0.03 10 2 2.93 Lt. Deposits. I 193 6172 194 6203 0 0.02 7 2 2.93 Lt. Deposits. 0 0.03 12 1 2.94 195 6235 0.03 0.03 10 2 2.93 Lt. Deposits. m 196 6266 0 0.02 8 2 2.94 3 I 197 6296 0 0.02 7 1 2.94 198 632 7 0 0.02 9 2 2.94 199 6359 0 0.02 9 1 2.94 200 6390 0 0.02 6 2 2.96 201 6421 0 0.02 7 2 2.93 _ Lt. Deposits. I I Penetration Bo Metal Loss Body I I I I I I I 1 Page 5 I I I i, , KUP ConocoPhillips $ ` . Attributes ogle & MD TD WeIlbo,e APUOWI Field Name Well Status Ind ( °) MD pace) 1G -17 Act Bin (RKB) ConooRate� 500292294500 KUPARUK RIVER UNIT PROD 35.77 2,750.00 7,357.0 Comment H2S (ppm) Date Amotation End Date KBCrd (ft) Rig Release Date ' contra: - ic - 4/22n01110:22:27 AM SSSV: NIPPLE 60 8/6/2009 Last WO: 11/13/1999 Schematic - Actual HANGER. 26 s 'F Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,209.0 10/10/2010 Rev Reason: SET TEST TOOL Imosbor 4/21/2011 - nn Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth B... Set Depth (TVD) ... String Wt... String ... String Top Bird CONDUCTOR 16 15.062 31.4 110.0 110.0 62.58 H40 WELDED ' Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 30.4 4,286.5 3,933.6 29.70 L-80 BTCM Casing Description String 0... String ID . Top (9KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 29.5 6,755.0 6,020.6 15.50 L-80 BTC -MOD Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrtl LINER 31/2 2.992 6,573.8 7,358.3 9.30 L-80 BTCM Liner Details CONDUCTOR, Top Depth 31 - 110 (TVD) Top 3 Nom... N PPLE, 516 .1 Top (1ticB) BBB) ( °) Item Description Comindt ID (m) 6,573.8 5,851.2 20.24 PACKER BAKER FA -1 LINER TOP PACKER 3.000 11 [ 9 6,578.1 5,855.2 20.22 SLEEVE BAKER C2 TIE -BACK SLEEVE 3.000 i GAS LIFT, 6,585.3 5,862.0 20.19 DEPLOY 6,970.9 6,208.1 35.65 NIPPLE BAKER DEPLOYMENT SLEEVE CAMCO'D' NIPPLE 3.000 2.750 2,740 7,022.2 6,250.8 30.73 PBR HALLIBURTON POLISHED BORE NIPPLE 2.750 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth B... Set Depth (ND) ... String Wt... String ... String Top Bird TUBING 31/2 2.992 27.6 6,573.8 5,851.2 9.30 L-80 EUE8RDMOD Completion Details GAS LET. .1M 1 T (ND) Top Ind Nona... 4.274 Top pUKB) BOOB) 19 Item Description Comment ID (m) , 27.6 27.6 0.20 HANGER FMC TUBING HANGER 3.500 I SU3RFACE. 515.6 515.6 0.54 NIPPLE 0d 288 6,518.3 5,799.3 21.52 NIPPLE CAMCO W NIPPLE 2.812 6,557.8 5,836.2 CAMCO DS LANDING NIPPLE 20.31 PBR BAKER KBH- 22/804 2.812 0 PBR 3.000 GAS L 244 Other In Hole (Mreline retrievable plugs, valves, pumps, fish, etc.) GAS LET. _ Top Depth - (ND) Top Intl Top ptice) 18 1 De scriptlon Comment Run Date ID (In) 6,457.0 5,743.0 24.04 TEST TOOL 3" ER TEST TOOL FOR Mine LEAK DETECT LOG 4/21/2011 5,963 6,4 5,743.9 24.00 PACKER UPPER WEATHERFORD ER PACKER 12/28/2008 1.750 6460.0 5,745.7 232243...229020 3.92 PATCH SPACER PIPE & SNAP LATCH ASSY. (OAL- 23.57') 12/28/2008 1.750 i 6,477.0 5,761.1 23.22 PACKER LOWER WEATHERFORD ER PACKER 12/23/2008 1.750 TEST TOOL. 6457 B 1 Perforations & Slots PACNER.6.a58 _ ' �i shot PATCH, 6,4601 I WI Top (TVD) Btm (TVD) Dens GAS LFT, Top (RKB) Bon (IIB) ((MB) (MB) zone Date 1sh... Type Comment 6467 � '� 6,912.0 6,922.0 6,158.6 6,166.9 C-4, 1G-17 3/31/2000 4.0 APERF 2 1/8" El DP, O deg ph, 0 deg orient ' PACKER, 6477 _ 6,932.0 6,942.0 6,175.3 6,183.7 C-4, C -3, 1G-17 4/9/2000 6.0 APERF 2" HSD PJ, 60 deg ph 6,994.0 7,000.0 6,226.8 6,231.8 C -1, 10-17 322/2000 4.0 APERF 2 1/8° E l DP, 0 deg. ph, 0 deg. oriented, FBSH NIPPLE, 6,518 11 7,000.0 7,001.0 6,231.8 6,232.6 C -1, 1G-17 3/22/2000 8.0 APERF 21/8" El DP, 0 deg. ph, 0 deg. oriented, FBSH i PeP esaa I 7,001.0 7,004.0 6,232.6 6,235.1 C -1, 1G-17 3/22/2000 4.0 APERF 2 1/8" El DP, 0 deg. ph. 0 deg. oriented, FBSH - - 7,198.0 7,210.0 6,410.6 6,422.4 A-4, 1G -17 12/7/1999 4.0 (PERF ' 2 1/8" Enerjet, 0 deg. ph 7,210.0 7,218.0 6,422.4 6,429.8 A-4, A -3, 1G -17 1/10/2000 8.0 APERF 2 1/8" strip gun, 0 deg. ph ■ 7,218.0 7,230.0 6,429.8 6,441.1 A -3, IG -17 1)10/2000 4.0 APERF 2 1/8" strip gun, 0 deg. ph Notes: General & Safety End Date Annotation 12/28/2008 NOTE: LEAK PATCHED AT 6467' RKB 9/22/2010 NOTE: View Schematic w/ Alaska Schernatic9.0 356,755 APERF. 6,912 -6,922 APERF. 6,9328942 { RF, APEERF. 6,99E - APERF, 7000-7,001 APERF, 7001-1,004 - Mandrel Details Top Depth Top Port I Sin (TVD) Ind OD Valve Latch Size TRO Rut S Top (RKB) PCB) r) Mdse Model M) Sery Type type (in) (Psi) Run Date Com_ _ 1 2,740.3 2,659.4 35.68 CAMCO KBG29 1 GAS LIFT GLV BTM 0.156 1,160.0 2/22/2011 2 4,273.6 3,923.0 34.40 CAMCO KBG29 1 GAS LIFT GLV BTM 0.188 1,190.0 2/22/2011 3 5,243.7 4,720.7 35.01 CAMCO KBG29 1 GAS LIFT OV BTM 0.188 0.0 2/22/2011 i -,210 7:198 4 5,963.1 5,314.7 32.52 CAMCO KBG29 1 GAS LIFT DMY BTM 0.000 0.0 9/25/2008 7.21oi2ie 5 6,467.1 5,752.1 23.63 CAMCO KBG29 1 GAS LIFT PATCH 0.000 0.0 11/13/2008 APERF. 7.218 -7230 I TO, 7,357 , , LIVER, 8,574 -7,358 I I • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360- February 1, 2010 U RECEIVED MAID U ~ Z0 i~ Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite l OQ ,, ~~~ ~ v Anchorage, AK 99501 '~"~ ~A t? " ~ ~ 1 Dear Mr. Dan Seamount: Alaska Qd & bas Cans. Cammissifln Anchorage ~ q-o 6a- i G- I'1 Enclosed please find a spreadsheet with alist of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December 5th, 2009. The corrosion inhibitor/sealant was pumped December 22nd, 25~', 26th & 28th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ..~~ v Kleilf 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 3/1 /2010 1 G. 1 L~ 1 R Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1G-17 50029229450000 1.990620 SF n/a 17" n/a 7.65 12/26/2009 1L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22!2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'5" n/a 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1 L-09 50029220250000 1900340 11 " n/a 11 " n/a 1.27 12!26/2009 1 L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L-23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" n/a 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" n/a 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • ~~1 N Jain 2 ~ 2009 January 22, 2009 Alaska Oil & Gas Cans. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 r F, Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notice for ConocoPhillips Alaska, Inc., well 1G-17 (PTD 1990620). The Sundry Notice reports the completion of a tubing patch installed above the ./ packer. Please call Brent Rogers or Martin Walters at 907-659-7224 if you have any questions. Sincerely, Brent Rogers ConocoPhillips Problem Well Supervisor Attachments ! ~~ -v~ a ~ RE ' STATE OF ALASKA ~ ~A~ ~ '~ ~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONI'ka ~~ ~ Gas Co~t~. ~sr,~~~~s;~~l00 1. Operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other ~`" Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillipsAlaska, InC. Development^• Exploratory ^ 199-062 3. Address: Stratigraphic ^ Service ^ 6. APt Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22945-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 88' 1 G-17 , 8. Property Designation: 10. Field/Pool(s): ADL 25640' ALK 2571 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7372' ' feet true vertical 6578' • feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURFACE 4198' 7-5/8" 4286' 3933' PRODUCTION 6667' S-1/2" 6755' 6020.6' LINER 784' 3-1/2" 7357' 6563.69' Perforation depth: Measured depth: Intervals from 6912' - 7218' true vertical depth: Intervals from 6158.6' - 6441.1' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6557' MD. Weathertord Patch from 6455' - 6480' Packers &SSSV (type & measured depth) Baker FA-1 Packer Packer= 6573' SSSV=Cameo DS NIPPLE SSSV= 515' 12. Stimulation or cement squeeze summa ry: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Exempt: N/A Contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone 659-7224 Date 1/22/2009 r `'~~ ~ ~~, JAI`J (- L~1Q~+ ~~~ i'~ ~ ~~,• ~ E`~. ~ ~ ~ 1 ~ ~1~ (• z,?. Form 10-404 Revised 04/2004 ~, ,> ~ ~~ ~ ~,...~ ~ ~ ~ ~+~ ~ / ~ Submit Ori ' ~~~~ • 1 G-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/14/08 12/28/0 12/29/08 BRUSHED & FLUSHED TBG FROM 6400' - 6500'. D_ RIFT TBG WITH 14' x 2.74" DUMMY TO 6500'.SLM,_READY FOR TBG PATCH. SET MID-ELEMENT OF WEATHERFORD' CONFIRMED SET BY TAGGING PACKER. 3 ET UPPER ER PACKER SPACER PIPE AND SNAP LATCH A ' 1.75 MIN. ID N TOP OF LOWER ER PACKER Cad 6478' RKB. (BLEED IA PRESSURE FROM 1850 PSI TO 1500 PSI TO ENSURE PATCH IS HOLDING) SET AVA CATCHER SUB ONTOP OF PATCH 645 ' ULLED GLV @ 4273' RKB. (IN PROGRESS ). SET OV @ 4273' RKB. PULLED GLV AND SET NEW GLV @ 2740' RKB .PULLED CATCHER SUB @ 6455' RKB. JOB COMPLETE. 01/12/09 Re-TIFL post patch installation (passed ), T/I/0= 150/820/630. SI well and GL, shot initial If FL @ 6435' station # 5 PATCH. Stacked T, T/I/0= 700/700/300. Bled IA, shot second IA-FL @ same location. Final T/I/0= 860/200/100. Summary Set Weatherford retrievable patch from 6455' - 6480'. TIFL passed followin the patch set. („a~QCQ~~jjjjps Well At tributes Max An le & MD TD AJAtik.1. I' 1 Welloore APIIU WI Field Name Wsll Slatue Prod/lnJ Typa Incl (°) MD IRKS) Act Btm IRKS) ° 500292294500 KUPARUK RIVER UNIT PROD 35.77 2,750.00 7,357.0 Comment N23 (ppm) Dets Annobtlon Entl Data KB-Grtl (R) Rlg Release Dats well :-1-v v1ar2DO 91osz:3e AM SSSV: NIPPLE 80 7/1/2008 LastWO: 11/13/1999 e8c-ACN eI Annobtlon Depth (RKB) End Deb A nnobtlon End Da[e Last Tag: SLM 7,199.0 9/52006 R ev Reason: SET UPPER PATCH ASSY. ADD NOTE 1/192009 Casin Strin s so-ing o D sabg to set o.ptn Sat Depth (TVD) srring m stung I Laeing D eacrlptlon (In) (In) Top (RKB) (RKB) (RNB) pOSM) Gnde gtring Top Thrtl coNDUCroR. Ito CONDUCTOR 1 6 15.062 0.0 110.0 110.0 62.58 H-40 WELDED SURFACE 751 8 8.750 0.0 4,286.0 3,933.2 45.50 L-80 BTCM NIPPLE. 515 PRODUC TION 51 2 4.950 0.0 6,755.0 6.020.6 15.50 L-80 BTCM LINER 311 2 2.992 6,573.0 7.357.0 9.30 L-80 EUEBRD Tubin Strin s Shing O D Slring 10 Se[ Dsplh Sat Daplh (TVD) String Wt Siring GAB LIFT. TuEing Deacrlptlon (In) (In) Top IRKS) (RKB) (RKB) (Ibalfl) Grade Slring TOp Thrd 2,740 TUBING 3 1/ 2 2.992 0.0 6,557.0 5,835.4 9.30 L-BD EUE6RD Other I n Hole A ll Jewei :Tubin Run 8i Retrievable Fish etc. Top Depth (TVD) ToP Incl GAS UFT, Top (RKB) (RKB) (°) Deacrlptlon Comment Run Dab 10 (In) s273 515.0 515.0 0.54 N IPPLE CAMCO DS NIPPLE 112311999 2.812 2.740.0 2,659.2 35.67 G AS LIFT CAMCOMBG2911/GLVIBTMl.156/1279/ Comment: STA 1 12292008 2.900 BURFACE, 4.288 4,273.0 3,922.5 34.40 G AS LIFT CAMCO/KBG2911/OVIBTM///Comment: STA2 12292008 2.900 5,243.0 4,720.1 35.01 G AS LIFT CAMCO/KBG29/1IDMY/BTMII/ Comment: STA 3 11/112008 2.900 GAB LIFT, 5,963.0 5,314.6 32.52 G AS LIFT CAMCO/KBG29/1/OMY/BTM/// Comment: STA 4 9252008 2.900 s,z4a 6,455.0 5,741.2 24.13 P ATCH PATCH ASSY: LOWER WEATHERFORD ER PACKER 12282008 1.750 (OAL 4.34' 2.61 MIN ID) SET 12232008 Q 6478'RKB, UPPER ER PACKER, SPACER PIPE, 8 SNAP LATCH ASSY (23.57' OAL, 1.75 MIN ID) SET 12282008 Q 6455' RKB GAS LIFT, s.~3 6,467.0 5,752.0 23.63 G AS LIFT CAMCOMBG29/1/OPENIIII Comment: STA 5 111132008 2.900 6,518.0 5,799.0 21.53 N IPPLE CAMCO W NIPPLE 112311999 2.812 6,557.0 5,835.4 20.31 P BR BAKER KBH-22/80-00 1112311999 3.000 6.573.0 5,850.4 20.24 P ACKER BAKER FA-1 PACKER 1123/1999 3.000 6,970.0 6,207.4 35.74 N IPPLE CAMCO D NIPPLE. 1123/1999 2.750 cnsuvr. 8.481 7.022.0 6,250.7 30.74 P BR HOWCO POLISH BORE 1123/1999 2.750 PATCH. 8.455 Perfora tions Shot Top (TVD) Btm (TVD) Dena Top (RNB) Btm (RKB) (RNB) (RKB) lone Dab (sh.- Type Comment 6,912.0 6,922.0 6,158.6 6,166.9 C-0, 1G-17 31312000 4.0 APERF 2 1/8' EJ DP, 0 deg ph, D deg orient NIPPLE. Bs1e 6,932.0 6,942.0 6,175.3 6.183.7 C-0, C-3, 1G-17 4192000 6.0 APERF 2' HSD PJ, 60 deg ph 6.994.0 7,000.0 8,226.8 6,231.8 C-1, 1G-17 3222000 4.0 APERF 2 1/8' EJ DP, 0 deg. ph, 0 deg. oriented, FBSH 7,000.0 7,001.0 6,231.8 6,232.6 C-1. 1G-17 32220170 8.0 APERF 2 1/8' EJ OP, 0 tleg. ph, 0 deg. PeR. Bss7 oriented, FBSH 7,001.0 7,004.0 6,232.8 6,235.1 C-1, 1G-17 3222000 4.0 APERF 2 1/8' EJ DP, 0 deg. ph, 0 tleg. oriented, FBSH PACKER. 8,573 7,198.0 7,210.0 6,410.6 6,422.4 A-4, iG-17 12/711999 4.0 IPERF 2 1/8' EnerjeL 0 deg. ph 7,210.0 7,218.0 6,422.4 6,429.8 A-4 , A-3, 1G-17 11702000 8.0 APERF 2 1/8' strip gun, 0 deg. ph 7,218.0 7,230.0 6,42 9 .8 8,441.1 A-3 , 1G-17 1/102000 4.0 APERF 2 1/8'strip gun, Odeg. ph PRODUCTION, PICtaS: t ianaral I e ~ $t .Bata 8,755 End Date Annobtlon 12/282006 NOTE: LEAK PATCHED AT 6467' RKB APERF, 8,912-8,922 APERF, 8.932-8.942 NIPPLE. 8,970 APERF, 8.881-7,OOp APERF. 7.000-7 001 APERF. 1,001-7.001 PBR. 7,022 IPERF, 1.198-7.210 APERF, 1210-7.218 APERF, 7.2181230 LINER. 7.357 TD. ),357 ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~~; y ~_ ~/ d~ \~ ~~ i Job # Log Description N0.4985 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11 /25/08 2V-07 12096561 INJECTION PROFILE - j ~ 10/31/08 1 1 3A-11 12100434 INJECTION PROFILE 10/31/08 1 1 iG-09 12100434 INJECTION PROFILE 3 ~- 11/01/08 1 1 2V-11 12061724 PRODUCTION PROFILE S- ~ 11/02/08 1 1 2C-14 12096565 PRODUCTION PROFILE L~ - 11/04/08 1 1 30-01 11975792 LDL 3 11/05/08 1 1 3F-09 12100435 PRODUCTION PROFILE 11/06/08 1 1 2V-12 12096567 PRODUCTION PROFILE 11/06/08 1 1 3A-07 12096568 INJECTION PROFILE 3 11/07/08 1 1 2A-20 12100434 INJECTION PROFILE - - 11/08/08 1 1 iG-17 11975792 LDL ~ - 11/09/08 1 1 2U-04 12100434 INJECTION PROFILE j 11/10/08 1 1 2U-05 12096572 INJECTION PROFILE _ " j 11/12/08 1 1 iF-06 12100457 PRODUCTION PROFILE 11/13/08 1 1 iB-06 12080456 PRODUCTION PROFILE 11/13/08 1 1 1 B-05 12080457 INJECTION PROFILE ~~} 11/14!08 1 1 2U-10 12080459 PRODUCTION PROFILE ~- ~ 11/16/08 1 1 2C-15 12100462 PRODUCTION PROFILE Z 11/18/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. u ~~ • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 r~ U ~~~„ RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report / M17 16-0ct-08 2L-313 2j Caliper Report 22~Oct-08 1 G17 Signed Print Name ~9 -o~ ~ ~ 3c~ ~- c. 1 Report / EDE 1 Report / ESE 40-103-20277-00 50-029-22945-00 Date - _ _ . , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~~5~'"i~i3•Ci~~~(:L~,'lef.':£t~i1a:C?.CJi73 WEBSITE:'NiI`iV,tT'ri~~3''I~~~~.i~Ti "~ C:\DocumenCC and Settings\Owner\Desktop\Transmit Conoco.doc Memory Multi-Finger Caliper LOg Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1G-17 Log Date: October 22, 2008 Fieki: Kuparuk Log No.: 7275 State: Alaska Run No.: 2 API No.: 50-029-22945-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 6,512 Ft. (MD) Inspection Type : Corrosion & Mechanical Damage Inspection COMMENTS This ca/iper data is tied into the top of GLM 5 @ 6,467' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damage to help locate the source of TxIA communication. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. This is the second time a PDS caliper has been run on this well and the first time the 3.5" tubing has been logged above 6,650'. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 17%) are recorded throughout the interval of 3.5" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional Walt loss (> i3%) are recorded throughout the interval of 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval of 3.5" tubing logged. Field Engineer: W. McCrossan Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-90$5 Fax: {281} 555-1369 E-mail PDS@memorylog.com Prudhoe Bay Field Office Phone: {907} 659-2307 Fax: {907} 659-2314 ~.~9 -oroa, l ~~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (9.5' - 6488.1') Well: 1 G-17 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 22, 2008 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 13 780 1562 2341 GLM 1 3157 -' Y s a 3939 ~ GLM 2 4757 GLM 3 5573 GLM 4 GLM 5 6390 202 6488 0 5 0 1 00 Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 202 1 25 50 75 w 100 I_ Z c ~0 12 i 150 175 200 • PDS Report Overview ~~. ~.,. Body Region Analysis Well: 1 G-17 Survey Date: October 22, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: _ _ C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ meta- loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1 `% 10% 20`% 40% 85% 85% Number of ~oints anal sed total = 216 pene. 0 159 57 0 0 0 loss 117 99 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body i~ metal loss body 0 50 100 0 47 GLM 1 95 GLM 2 143 GLM 3 GLM 4 GLM 5 Bottom of Survey = 202 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Feld: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 G17 Kuparuk ConocoPhillips Alaska, Inc. USA October 22, 2008 Joint No. Jt. Depth (Ft) Pc~n. l)I,.~~t (In<.) Pen. Body (Ins.) Nc~n. `;~, b1c~t,~l I oss ";, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 9 0 0.01 5 5 2.91 P P 1 13 0 0.02 7 I 2.93 1.1 46 U 0.03 12 I 2.90 PUP 1.2 54 1) 0.02 ? ? 2.92 PUP 1.3 56 ~~ 0.01 2.94 PUP 2 0 ti 0.02 ti I 2.92 3 92 a 0.02 - I 2.90 4 123 a 0.01 b I 2.93 5 155 U 0.02 f3 a 2.90 6 186 t I 0.02 t3 1 2.94 7 217 t~ 0.03 11 1 2.91 8 249 l~ 0.02 ~~ I 2.93 9 280 c ~ 0.03 I < 2.92 10 311 t ~ 0.02 - I 2.92 11 343 t 1 0.02 2.94 12 374 U 0.02 ~i I 2.91 13 406 0 0.01 6 I 2.93 14 437 0 0.02 7 U 2.93 15 469 t ~ 0.02 1 2.92 15.1 500 (1 0 (~ ~ ~ 2.81 CA CO DS-Ni le 16 502 t~ 0.03 11 2.92 17 532 (a 0.01 i I 2.93 18 563 t~ 0.02 ~~ I 2.92 19 595 0 0.03 11 2.93 20 625 U 0.02 ~ 2.92 21 656 a 0.03 II I 2.91 22 687 t 1 0.02 7 .' 2.91 23 718 t~ 0.02 ~) t 2.90 24 49 t ~ 0.03 1 1 2.93 25 780 t ~ 0.03 1 I 2.89 26 812 U 0.02 ~~ I 2.92 27 843 0 0.02 ~ 2.93 28 874 U 0.03 11 I 2.91 29 906 t t 0.03 1 Z 2.91 30 937 t) 0.03 10 1 2.92 31 968 U 0.04 14 t ~ 2.92 32 999 t) 0.01 (, I 2.91 33 1030 ~~ 0.01 (~ I 2.91 34 1061 tl 0.02 '~ 1 2.91 35 1091 t) 0.02 2.91 36 1122 U 0.03 l:.' ~' 2.93 37 1154 t1 0.03 Li 2 2.92 38 1185 u 0 01 t~ 1 2.91 39 1216 i ~ 0.03 1 I ~~ 2.92 40 1247 i ~ 0.03 I 1 I 2.91 41 1279 ~~ 0.02 ~~ 1 2.93 42 1310 i ~ 0.03 I I 2.92 43 1342 ~ ~ 0.01 5 I 2.92 44 1373 t ~ 0.02 ti I 2.92 45 1404 a 0.01 b 2.91 _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: -LATION SHEET 1 Cr17 Kuparuk ConocoPhillips Alaska, Inc USA October 22, 2008 Joint No. Jt. Depth (Ft.) Nen. I )I~set (Ins.) Pen. Body (Ins.) F'en. °4, ,Metal Lass °~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 46 1436 U 0.01 5 U 2.93 47 1467 U 0.01 b 2.93 48 1499 U 0.02 ~) Z 2.94 49 1530 U 0.02 ~) r? 2,93 50 1562 a 0.02 7 1 2.91 51 1593 U 0.03 1 t? 2.91 Lt. De osits. 2 1625 t) 0.02 ~~ I 2.92 53 1656 tt 0.02 '~~ ~? 2.92 54 1687 i 1 0.03 1 1 2.91 55 1719 t ? 0.02 ~l I 2.90 56 1750 t ~ 0.02 8 I .93 57 1781 (? 0.04 14 2.91 58 1813 ~? 0.02 9 I 2.91 59 1844 t? 0.03 11 2.90 60 1875 U 0.02 ~) 1 2.9 61 1907 0 0.02 t5 1 2.93 62 1938 tt 0.0 11 2 .93 63 1969 t) 0.01 4 2 .92 64 1999 tr 0.02 t3 t? 2.93 65 2031 t? 0.02 ~) I 2.92 66 20 0 t? 0.03 1u 1 2.92 67 2092 U 0.03 10 1 2.92 68 2122 l) 0.02 8 1 2.92 69 2153 O 0.03 11 2.93 70 2184 t? 0. It) 1 .9 71 2215 U 0.03 1 I I 2.94 72 2247 U 0.03 1 U _' 2.93 73 2278 l) 0.02 ~) I 2.91 74 2310 U 0.02 8 2 .92 75 2341 (1 0.02 7 1 2.92 76 2373 O 0.01 t, 1 2.91 77 2404 tt 0.03 1tt 2.91 78 2435 U 0.02 ti 2.94 79 2467 U 0.03 1 u _' 2.92 80 2498 a 0.03 1 c) 2.94 81 2529 t? 0.03 1 Z I 2.93 82 2561 t? 0.02 - 1 2.90 83 2592 U 0.03 1_S I 2.90 84 2623 U 0.03 1 Z _' 2.92 85 2655 a 0.03 1t) z 2.93 86 2686 tt 0.03 13 2 2.93 86.1 2716 U 0.04 1 i U 2.92 PUP 86. 2731 t? 0 t? t! N A G M 1 Latch ~ 5:30 86.3 2738 t? 0.02 ~t 1 2.95 PUP 87 2752 ~) 0. 2 8 .' 2.92 88 2783 U 0.02 8 ? 2.94 89 2815 U 0.04 15 2.93 90 2846 O 0.02 t ~ I 2.94 91 2877 ~! 0.04 I ; 2.92 ~)2 2909 0.02 ~~ 1 2.93 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 1 G17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 22, 2008 Joint No. Jt. Depth (Ft) Pc~n. Ul,c<~t (In..) Pen. Body (Ins.) P~~n. °~~~ ~~I~~t,il lu.~ ., Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 93 2940 n 0.03 II 2.94 94 2972 t? 0.01 o n 2.93 9 3003 t) 0.02 9 I 2.93 96 3033 U 0.02 £i I 2.92 97 3064 O 0.03 12 2.93 98 3094 c ~ 0.0 i 1 2.95 99 3125 n 0.04 16 ~ 2.91 100 3157 t ~ 0.02 t3 1 2.93 101 3187 i ~ 0.03 1 3 .? 2.92 102 3219 ~ ~ 0.01 3 I 2.93 103 3250 ! ~ 0.01 6 2.93 104 3281 ! ~ 0.02 7 1 2.96 10 3313 t ~ 0.02 ~) I 2.92 06 3345 t i 0. 2 £3 .93 107 3376 tt 0.02 £i I 2.93 108 3407 ti 0.01 (> t~ 2.93 109 3438 U 0.0 £3 1 2.96 110 3469 U 0.02 7 ' 2.93 111 3500 1) 0.03 I 1 I 2.94 112 3532 U 0.02 ~ 1 2.93 113 3563 (1 0.03 t l -l 2.91 114 3595 t~ 0.02 U 2.96 115 3626 U 0.02 7 1 2.93 116 3657 U 0.01 4 1 2.89 117 3689 U 0.03 1 U 2.93 118 3720 t l 0.01 5 I 2.94 119 3752 t t 0.02 ') ~ 2.93 120 3783 U 0.02 7 i 2.93 121 3814 l) 0.01 (> I 2.93 122 3846 ll 0.04 1 i 1 2.92 123 3877 U 0.04 I5 I 2.92 124 3908 t~ 0.02 9 Z 2.91 125 3939 tt 0.04 17 ? 2.92 126 3971 t~ 0.02 ~) 2 2.91 127 4002 U 0.02 7 2.94 128 4033 n 0.01 5 ~ 2.93 129 4065 n 0.02 ,' 2.93 130 4096 t ~ 0.03 1 1 2.93 131 412 7 U 0.03 1 Z I 2.94 132 4159 (1 0.02 7 ~' 2.94 133 4191 O .0 t3 1 2.91 134 4221 t ~ 0.02 'J 1 2.93 134.1 4253 (t 0.02 £i 2.96 PUP 134.2 4268 U 0 U t t N A GLM 2 Latch ~ 8:30 134. 4274 (~ 0.03 I_ > 2.97 PUP 135 4289 t ~ 0.02 ~ I 2.95 136 4320 t~ 0.02 7 I 2.95 137 4352 t! 0.02 £3 I 2.96 138 4384 i ! 0.02 ti I 2.95 139 4415 ~~~ 0.02 ~~ I 2.96 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 1 G-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 22, 2008 Joint No. )t. Depth (Ft.) I'cvi. L Ipset (In~.l Pen. Body (Ins.) I'c°n. °i~ Metal I c~tis ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 140 4446 (1 0.03 1 Z I 2.92 141 4478 U 0.02 2.96 142 4509 U 0.02 - I 2.95 143 4539 U 0.02 I 2.93 144 4571 U 0.02 ?~ I 2.95 145 4602 t ~ 0.02 ~ 2.93 146 4634 U 0.02 7 2.96 147 4664 I ~ 0.03 12 ~ 2.91 148 4696 I) 0.02 8 u 2.93 149 4725 U 0.04 14 ti 2.93 150 4757 (> 0. 2 9 I 2.92 151 4788 U 0.02 8 2.94 152 4820 I~ 0.02 7 I 2.95 153 4851 ~ ~ 0.01 U I 2.93 154 4882 ~ ~ 0.02 7 I 2.95 155 4914 ~ ~ 0.02 fi 1 2.93 156 4945 ~ ~ 0.02 7 1 2.96 157 4977 ~ ~ 0.02 ' 2.95 158 5008 I ~ 0.02 t3 _' 2.92 159 5038 ~! 0.02 7 I 2.93 160 5069 I~ 0.02 ~~ 2.93 161 5100 c) 0.02 ~ 1 2.93 162 5130 (~ 0.02 i _' 2.92 163 5162 ~ ~ 0.02 9 _' 2.94 164 51 4 O 0.0 8 1 2. 5 164.1 5225 O 0.02 ~i I 2.98 PUP 164.2 5240 II 0 11 U N A GLM 3 Latch ®8:00 164.3 5246 t? 0.03 1 I 2.96 PUP 165 5260 ti 0.01 6 I 2.89 166 5292 (~ 0.02 8 I 2.97 167 5323 U 0.03 11 I 2.92 168 5355 t~ 0.02 ti I 2.93 169 5386 a 0.03 I~~ Z 2.92 170 5418 I I 0.03 1 Z ? 2.93 171 5450 I ~ 0.02 7 1 2.91 172 5480 ~) 0.02 fi I 2.94 173 5511 ~ ~ 0.02 2.95 174 5542 ~ ~ 0.02 ti I 2.94 175 5573 U 0.02 t3 I 2.96 176 5605 U 0.03 12 ~ 2.92 177 5636 t) 0.02 t3 1 2.95 178 5667 (1 0.01 6 2 2.94 179 5698 l~ 0.02 E3 ~' 2.9 180 5729 U 0.03 11 ~' 2.91 181 5760 I ~ 0.02 ti I 2.94 182 5790 i ~ 0.03 13 2.93 183 58 2 t ~ 0.02 ~ 2.96 184 5854 t ~ 0.02 ti 2.96 185 5885 U 0.02 9 2.9 186 5917 I ~ 0.02 ~ I 2.96 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 1 G-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 22, 2008 Joint No. Jt. Depth (Ft.) I'i~n. l lhs~~i (liu.) Pen. Body (Ins.) f'c~n. °/~ Metal I oss `~~<~ Min. LD• (Ins.) Comments Darnage Profile (% wall) 0 50 100 18 .1 594 ~~ 0.03 12 ~~ .93 P P 186.2 5962 I) 0 l) )) N A GLM 4 Latch ~ 7:00 186.3 5968 a 0.03 1 ~' 2.93 PUP 187 5984 U 0.02 t3 I 2.95 188 6015 O .03 1 Z 2.92 189 6046 ~) .03 1 I ' 2.92 190 6077 ~) 0.04 11 2.93 191 6109 U 0.02 ti I 2 94 19 6140 t) 0.0 ~~ 2 89 193 617 ~) 0.02 t3 I 2.94 194 6203 O .02 9 3 2.93 195 6235 U 0.0 ~J 7 2. 3 196 6267 U 0.03 I1 2.92 197 6297 n 0.0 ~) 2.92 198 6328 U 0.02 ~ I 2.9 199 6359 U 0.02 ti I 2.93 Z00 6390 U 0.02 ~) 2.91 201 423 O 0.02 i 2.95 201.1 64 a 0.02 ') I 2.97 PUP 201.2 6467 !) 0 ~) i ~ N A G 5 Latch @ 5:30 201.3 6473 ~) 0.03 1 I .94 PUP 2 2 6488 a 0.02 ti I 2.94 Penetration Body Metal Loss Body Page 5 ~1, KUP 1 G-17 ConoeoPhillip s ~ ~ Well Att ributes aL .w I ` we~loore awut+n ~Ido Nsne 500292294500 KUPARUK RIVER UNfT wex :taus promq we PROD u typ. Intl PI ~ feel ro 1~ Itl-.. 35.77 2.750.00 7.357.0 -_--- Coroners SSSV: NI S D PPLE 80 wa Artrotetlon 7/1n008 Last WO: K8-QCllt) Rlg Relpul>efe 1 111 3/1 999 - - oe s v 3z ni.1 Amotrlon 1 tl e Arrtotatlon 6M ab Last Tag: SLM 7.199.0 9152006 Rev Reason: GLV CIO 10/14n006 Cesin Stri s o e.alpnon OO Itil r IRKeI IR KSI pbsllq t7atle rap Thrtl coNOUC7oR. ~ CONDUC TOR 1 6 15.062 0.0 110.0 110.0 62.58 H~dO WFIDFD no SURF C E 7 6.750 0.0 4,2 .0 3,933.2 45.50 L-80 BTCM ~ PRO C TION 5 12 4.950 0.0 6.755.0 6.020.6 15.50 L-80 BTCM NIPPLE. 518 LINER 312 2.992 6,573.0 7.357.0 9.30 L$0 EUEBRD ~' Tubin 9trin deny 8tdrtg ID set pet set Oe pdt (ND) sting wt !:bins 7bbwtg D esert n Iin) pn) T IRKS) (s K8) Ilbetlll tootle tltrYtp T mrtl cAS UFr, TU&NG 31n 992 2 0 0 6 557 0 58354 9 30 L$0 EUEBRD 2.740 . . . . . Otltar I n Hole All Jewel . Tu Run b Retrievab Fish etc. lop DepM (iVD) Top T I~el httl (') Catnswtl Run Dote D ons uEr, a z73 - 515.0 515.0 0.54 NIPPLE CAMCO DS NIPPLE 1123/1999 2.812 . 2,740.0 2,859.2 35.67 GAS LIFT CAMCOIICBG2911/GLV/BT MI.15d1 30N Cttmment: SiA 1 9252008 2.900 4,273.0 3,922.5 34.40 GAS LIFT CA KBG2911/GLVlB M1.188/i 1/Comment: SiA2 9242008 2.900 suRFACE. 5 243.0 4 720.1 35 01 GAS LIFT CAMCO/KBG29/1/OV/BTM l 18&/ C mrnent: STA 3 9242008 2 900 e.1es . , . . . 5.983.0 5.314.6 32.52 GAS LIFT CAMC /KBG29/1/DMY/BT NV// Co mment STA 4 9252008 2.900 6,467.0 5,752.0 23.63 LI CAMC BG29/1IDMVlBT M/// Cor mient: w/EXT PKG STA 10/132008 2.900 ons uFT, 5 s.za3 6,518.0 5,799.0 21.59 NI CAAACO W NIPPLE 1123/1999 2.812 6,518.0 5, 99.0 21.53 PLUG 2.81' MA-2 UG 10/132008 0.000 6.557.0 5,835.4 20.31 PBR BAKER KBH-27/80-40 112311999 3.000 cas uFr. 6 573 0 5 850 4 20 24 PACKFJt BAKER FA-1 PACKER 1123/1999 3 000 s.96a , . , . . . 6,9 0.0 6, 07.4 35.74 P8R CAMCO D NIPPL 1123/1999 2.750 7,022 0 6,250.7 30.74 NIPPLE HOWCO POLISH BORE 1123/1999 2.750 ~<s uFr, Pertora tions 6.067 $11Q Top (TVd) Bbrt (TWj Dens r ebn ImKel ~b zone Dele I+it-- comment NIPPLE 6518 6,912.0 6,922.0 6.158.6 6,166.9 Ci, 1G7 31312000 4.0 APERF 2 1!8' EJ DP, 0 deg ph, 0 deg orient . PLUG. 6.518 8,932.0 6,942.0 6,175.3 6,183.7 C-4, C-3. 1G77 4!92000 6.0 APERF T HSD PJ, 60 deg pA 6.994.0 7,000.0 6,226.8 6,231.8 C-1, 1G-17 3n2n000 4.0 APERF 2 1!8" EJ DP, 0 deg. ph, 0 deg. oriented, FBSH 7.000.0 7,001.0 6,231.8 6.232.8 C-1, 1G77 32711000 8.0 APERF 2 1B' EJ DP, 0 deg. qt, 0 des. ortented. FBSH PBR, s ss7 7.001.0 7,004.0 6, .6 6,235.1 C-1, 1G17 322n000 4.0 APERF 2 1/8' EJ DP, 0 deg. plt, 0 deg. oriented. FBSH 7,198.0 7,210.0 6,410.8 6.4 .4 A-4, 1G77 12!7/1999 4.0 IPERF 2 1!8' EnerjeL 0 deg. ph PACt~R, 6,573 7,210.0 7,218.0 6,422.4 6,429.8 Ate, A-3, 1G77 1/10/2000 8.0 APERF 2 1/8' Strip gun, 0 deg. ph 7.218. 7,230.0 6,429.8 6.141.1 A-3, 1G77 1/102000 4.0 APERF 1/8'strq gut, Odeg. ph PROWCTION, 8.785 APERF, 8,911-8.912 APERF, 8,931b 911 PRR,6B)0 APERF. 6,991-] 000 PPERF, 7.000-7,001 PPERF, 7,001-7,004 NIPPLE. ] 011 IPERF. 7,196-7,210 P-ERF 7,110-7.118 PPERF, 7.118-7.130 LINER, 7 357 TD. 7 357 1 G-17 (PTD 199-062) Report Of ~ed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, September 14, 2008 3:43 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Regg, James B (DOA) Subject: 1G-17 (PTD 199-062) Report Of Failed TIFL Attachments: 1G-17 Wellbore Schematic.pdf; 1G-17 TIO Plot.ppt Tom, i' Kuparuk gas lifted producer 1G-17 (PTD 199-062) failed a TIF n 09/12/08 and has been added to the Weekly SCP report. The T/I/O pressures prior to the TIFL were 200/1200/450. A leaking GLV is suspected so slickline will troubleshoot the leak and repair if possible. The well is currently producing an wi a repaired or shut in by 10/10/08. Attached is a 90 day TIO plot and schematic. «1G-17 Wellbore Schematic.pdf» «1G-17 TIO Plot.ppt» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 ~'~~`~'~~~-~ ,.;;~,` ~~~ y `- e r` `~` Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 12/10/2009 l f j L ~, ~ IAP 1200 1000 800 N a 600 400 200 0 OAP Tl1I0 Plot -1 G-17 200 150 ^ - i ~ 5 I .. 4 ~ ...... ? ....... ~~!.,.. ~ ytli •1• •L ....7. •5. f S ............. .... .~~ ....I`.l,'„l~j... 'I~~..~~f ... ~4 . ' .1.........................................~.......... . a 100 ~ Y O L V 50 01-Jul-08 01-Aug-08 Date 01-Sep-08 a # • ;~~ KRU 1 G-17 t' ~ Conocophillips Alaska, Inc. ,-.r _ 1G-17 -- API: 500292294500 Well T e: PROD An le TS: 32 de 6908 TUBING - SSSV T e: NIPPLE Ori Com letion: 11/13/1999 An le TD: 14 de 7372 (o-s55~ Annular Fluid: DSUSW Last W/O: Rev Reason: TAG , oD:3.5o0, Reference Lo : Ref Lo Date: Last U date: 9/23/2006 iD:2.ss2) -- -'-- Last Ta : 7283' RKB TD: 7357 ftKB ? Last Ta Date: 9/5/2006 Max Hole An le: 36 de 2750 "~ _ _ _ _ _ __ _ ~'~ Casin Strip -ALL Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.58 H-40 WELDED '° , ~ SURF CASING 7.625 0 4286 3933 45.50 L-80 BTCM } `' PROD CASING 5.500 0 6755 6022 15.50 L-80 BTCM ~~ ~ `` ~~ LINER 3.500 6573 7357 7357 9.30 L-80 EUE8RD ' ' ~ Tubin Strip -TUBING ~ ~ Size To Bottom ND Wt Grade Thread ' ~` 3.500 0 6557 5835 9.30 L-80 EUE8RD ~ .' , _ Perforations Summa ~~ Interval TVD Zone Status Ft SPF Date T e Comment ' 6912 - 6922 6159 - 6167 C-4 10 4 3/31!2000 APERF 2 1/8" EJ DP, 0 deg ph, 0 deg orient ~ 6932 - 6942 6175 - 6184 C-4 C-3 10 6 4/9/2000 APERF 2" HSD PJ 60 de h ~ 'y ," ~ 6994 - 7000 6227 - 6232 C-1 6 4 3/22/2000 APERF 2 1/8" EJ DP, 0 deg. ph, 0 de .oriented FBSH ~ ~~~ T`~ 7000 - 7001 6232 - 6233 C-1 1 8 3/22/2000 APERF 2 1/8" EJ DP, 0 deg. ph, 0 de .oriented FBSH :j 7001 - 7004 6233 - 6235 C-1 3 4 3/22/2000 APERF 2 1/8" EJ DP, 0 deg. ph, 0 de .oriented FBSH 7198 - 7210 6411 -6422 A-0 12 4 12/7/1999 IPERF 0 de h 2 1/8" stri un 7210 - 7218 6422 -6430 A-4 A-3 8 8 1/10/2000 APERF 0 de h 2 1/8" Ener et ~~ 7218 - 7230 6430 -6441 A-3 12 4 1/10/2000 APERF 0 de h 2 1/8" Ener et _ Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt ' 1 2740 2659 CAMCO KBG29 CAMCO GLV 1.0 BTM 0.156 1317 5/2/2000 y ~ ~~~ 2 4273 3922 CAMCO KBG29 CAMCO GLV 1.0 BTM 0.188 1346 5/2/2000 , , 3 5243 4720 CAMCO KBG29 CAMCO GLV 1.0 BTM 0.188 1336 5/3/2000 4 5963 5315 CAMCO KBG29 CAMCO GLV 1.0 BTM 0.250 1432 5/3/2000 5 6467 5752 CAMCO KBG29 CAMCO OV 1.0 BTM 0.250 0 5/3/2000 Other lu s 'e u i .etc. -JEWELRY ~ De th ND T e Descri lion ID _~ 515 515 NIP CAMCO DS NIPPLE 2.812 ,~;. "' 6518 5799 NIP CAMCO W NIPPLE 2.812 PBR - ' 6557 5835 PBR BAKER KBH-22/80-40 3.000 (s5s~-ease, 6573 5850 PKR BAKER FA-1 PACKER 3.000 oD:a.~so) 6970 6207 NIP CAMCO D NIPPLE. 2.750 7022 6251 NIP HOWCO POLISH BORE 2.750 Perf (6994-7004) Perf (7000-7001) NIP (7022-7023, OD:4.000) Pert (7198-7218) Perf (7210-7230) ~ ..__ .. ----~~~ -_--- ---- - --_ -- o - - --- -~~~~-~~-~~- -- ...-___ _-......._ i c~ 04/20/07 Schlumbel'gel' NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 D t1AY () 4 zom 10'1 -(:k ';) ~, SGANNEDMAY 0'7 2007 Field: Kuparuk Well BL CD Color Job# Log Description Date 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. rO . . Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # 2C-05 2Z-09 20-09 3F-03 3F-01 3F-15 1 F-03A 1 G-17 1J-164 3G-25X 1 Q-20A 11072930 11057062 11141218 11141219 11057064 11057065 11141222 11141221 N/A 11141229 11144038 SIGNED:¿>-'(~~..\ 1___ ~ - l..(í J E:,(~Er\lE 0 ,/ t\ ;.:-:' , ¿ 1 :~-}}5 ¡¡ j:ì i \D0 i Gas GGns. OJJ¡¡iE&S;cr; NO. 3604 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk l\r;d~oL~ge ¡ 61 n 2005 '"'CANNED \'iO'J (.; iiJ Log DescriP~on Date INJECTION PROFILE INJECTION PROFILE LEAK DETECTION LOG INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE USIT SBHP SURVEY SBHP SURVEY ¡qq.. OCP;). 11102/05 11/03/05 11/04/05 11/05/05 11/05/05 11/07/05 11108/05 11/07/05 11/12/05 11/16/05 11/17/05 BL Color CD 1 1 1 1 1 1 1 1 1 1 1 DATE: n)pI)0-f:) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 11/18/05 ì53 - Oc¡c¡ U í ¡t/5-~ \3& L'lC i54- \ò3 i'ôS-;ì.;ìl U 'I C iS5-dd5 Iff) -,~"13. u, L ,q ~- 090 j c¡ C¡ -00:::{ :Jo5 - I '1- 'Í- /Cfl£J - i 30 195 - f 51..0 _/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 199-0621 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-22945-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 88' 1G-17 8. Property Designation: 10. FieldlPool(s): ADL 25640, ALK 2571 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7372' feet true vertical 6578' feet Plugs (measured) Effective Depth measured 7230' CTMD feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SURF CASING 4198' 7-5/8" 4286' 3933' PROD CASING 6667' 5-1/2" 6755' 6022' LINER 784' 3-1/2" 7357' 6564' REC'Ei 'oJ .,u,!' Perforation depth: Measured depth: 6912'-6922',6932'-6942',6994'-7004',7198'-7230' OCT 2 1 2004 true vertical depth: 6159'-6177',6175'-6184',6227'-6235',6411'-6441' Alaska Oil & ,""." Tubing (size, grade, and measured depth) 3-1/2' , L-80, 6557' MD. Packers & SSSV (type & measured depth) pkr= BAKER FA-1 PACKER pkr= 6573' SSSV= NIP 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6880'-7010' MD Treatment descriptions including volumes used and final pressure: SEE ATTACHED SUMMARY 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casino Pressure Tubino Pressure Prior to well operation NIA -- Subsequent to operation 247 276 1241 -- 186 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name ~;Æoo~e¡ Title Wells Group Team leader Signature Phone Date /ó Z¿)/:~ p, 'l,.,,~_n":;~ð ?"?4R? --"""" Form 1 0-404 Revised 04/2004 OR\G\NAL ~s ~nal Only . conOCOPhlllijØlAl:~ Inc. . API: 500292294500 SSSV Type: NIPPLE TUBING (0-6557, 00:3.500, 10:2.992) PBR (6557-6558, 00:4.760) Perf (6994-7004) Perf (7000-7001) NIP (7022-7023, 00:4.000) Perf (7198-7218) Perf (7210-7230) - - - - - - - - - - - - = == = - - - - - - - = == = - - - Annular Fluid: DSUSW Reference Loa: Last Taa: 7230 CTMD Last Taa Date: 4/1512004 Casino StrIne - ALL DescrlDtion CONDUCTOR SURF CASING PROD CASING LINER Tubina StrIne - TUBING Size I Top 3.500 I 0 Perforations Summarv Interval TVD 6912 - 6922 6159 - 6167 6932 - 6942 6994 - 7000 6175 - 6184 6227 - 6232 6232 - 6233 7000 - 7001 7001 - 7004 6233 - 6235 - - - - - - - - ',"'" "',,,,' ',," Well Type: PROD Orig 11/13/1999 Completion: Last WID: Ref Loa Date: TD: 7357 ftKB Max Hole Anale: 36 dea @ 2750 Size 16,000 7.625 5.500 3.500 I I Bottom I 6557 I Zone C-4 Status C-4 C-3 C-1 C-1 C-1 A-4 A-4 A-3 A-3 Top 0 0 0 6573 Bottom 110 4286 6755 7357 KRU 1G-17 Anole (éì) TS: 32 dea (éì) 6908 Angle @ TD: 14 deg @ 7372 Rev Reason: TAG FILL Last UDdate: 4/25/2004 TVD 110 3933 6022 7357 Grade H-40 L-80 L-80 L-80 Wt 62.58 45.50 15,50 9.30 Thread WELDED BTCM BTCM EUE8RD TVD 5835 I WI I Grade I I 9.30 I L-80 Thread EUE8RD Ft SPF Date Type Comment 10 4 3/3112000 APERF 21/8" EJ DP, 0 deg ph, 0 dea orient 10 6 4/912000 APERF 2" HSD PJ 60 dea Dh 6 4 3/2212000 APERF 2 1/8" EJ DP, 0 deg. ph, 0 dea. oriented FBSH 8 3/2212000 APERF 21/8" EJ DP, 0 deg. ph, 0 dea. oriented FBSH 3 4 3/22/2000 APERF 2 1/8" EJ DP, 0 deg. ph, 0 dea. oriented FBSH IPERF 0 dea. Dh 2 1/8" stria aun APERF 0 dea Dh 2 1/8" Eneriet APERF 0 dea oh 21/8" Eneriet 1 12 4 8 8 12_- 4 GLV GLV GLV GLV OV 12/7/1999 1/1012000 1/10/2000 1.0 BTM 1.0 BTM 1,0 BTM 1.0 BTM 1,9_- BTM Port TRO Date Run 0.156 1317 5/2/2000 0.188 1346 5/2/2000 0.250 1336 5/3/2000 0,250 1432 5/3/2000 0.250 0 5/3/2000 _n-- .., 7198 - 7210 6411 - 6422 7210 - 7218 6422 - 6430 7218 - 7230 6430 - 6441 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 1 2740 2659 CAMCO KBG29 CAMCO 2 4273 3922 CAMCO KBG29 CAMCO 3 5243 4720 CAMCO KBG29 CAMCO 4 5963 5315 CAMCO KBG29 CAMCO 5 6467 5752 CAMCO KBG29 CAMCO , Other (pl!:l9.!!J E Quip., etc.) - J~)lVELRY. ~.: .. ....- Depth TVD - Type ._~ 515 515 NIP CAMCO DS NIPPLE 6518 579! -~n'~CAMCO W NIPPLE ..... -65si" '5835 PBR ' BAKËR KBH-22/80-40 i 6573 5850 PKR. . BAKER FA-1 PAC-KER ¡ 6970 6207 n. NIP ;CAMCODNiPPLE.'" : 7022 6251 NIP !ï-iowcc)"pO.LlSI-j ê.o"RE Vlv Cmnt .. - n ,_n_~ I ID I f!:_~~- ¡J 2:812..n 3.000 I 3.000 "-.'-1 n 2.750' J_..P50 . "Descripti9'1_.. ..n- ..-- ....... -. ...... .- . .m.. .... --- ---....... -- . . ---- .... . ...n___.. n- .n_. 1G-17 Well Events Summary Date Summary 04/15/04 RIH FOR FCO WITH 2% KCL WATER, WELL STARTED DRINKING FLUIDS WITH NO RETURNS, SWAPPED TO DIESEL, WELL CONTINUED TO DRINK. FCO'D WITH GL ON TO ASSIST FLUIDS TO SURFACE - CALCULATED BHP -2100 PSI- HARD TAG 7230'. CHASED GEL SWEEP TO SURFACE. PUMPED 7.5 BBLS 15% HCI PICKLE, 7 BBLS U66 PREFLUSH, AND 30 BBLS 7.5% HCI FOLLOWED BY 25 BBLS 2% KC!. LAYED INTO THE C SAND PERFORATIONS FROM 6880'-7010'. Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPhilii ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 G-17 (APD # 199-062) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 G-17. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, J/!, II/~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEf\/F OCT 2 1 2004 Alaska Oil &. :::'~'c~r. Permit to Drill No. 1990620 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. KUPARUK RIV UNIT IG-17 Operator PHILLIPS ALASKA 1NC. APl No. 50-029-22945-00-00 MD 7372 TVD 6578 Completion Date 12/7/1999-~'' Completion Status l-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples N.__~o Directional Survey N.__~o -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log Log TlPe Media Format _ Na~r.~._.~ Scale Media .............................. ~ GYRO- CON:F. Mb[Ti '~'""SCMT 5 .,g'/ GR MD 5 cl~ GR TVD 5 C ~ SCMT 5 D ,~'~L 5 L--."~P ress/Tem piG rad/ 5 ~STAT BHP 5 ¢.,J;~' Log Results Summ ~ LIS Verification ~'"/MWD LIS ~, q ~. ~ ).. (data taken from Logs Portion of Master Well Data Maint) Interval Run OH / Dataset No Start Stop CH Received Number Comments 0 7283 OH 1/10/2000 TBNG . FINAL 5970 7290 CH 2/25/2000 FINAL 6726 7371 CH 1/9/2001 FINAL 6726 7371 CH 1/9/2001 FINAL 5960 7290 CH 3/14/;~000 FI NAL 6500 6934 OH 12/1/1999 FINAL 600 7050 CH 1/3/2001 FINAL 6900 7215 CH 12/29/1999 FINAL 6700 7100 8/22/2001 FINAL 2/22/2001 FINAL 1/9/2001 O 12/1/1999 .L-/" DGR/EWR4-MD 2/6 FINAL 110 6755 ~ DGJA/EWR4-TVD 2/6 FINAL 110 6027 ¢.R'~S P~VY RPT 0 6755 09072 BL(C) 12/3/99 BL, Sepia BL, Sepia 12/3/99 BL, Sepia Log Results Summary LIS Verification Paper Copy Lis Verification 6500-6934 Well Cores/Samples Information: O 8/31/1999 09292 39-6700 OH 9/21/1999 OH 9/21/1999 OH 8/5/1999 SPERRY . C 2/22/2001 09823. 39-7380 C 3/14/2000 09452 5970-7290 Permit to Drill No. MD 7372 Ntlme 1990620 TVD DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. KUPARUK RIV UNIT 1G-17 Operator PHILLIPS ALASKA 1NC. AP1 No. 6578 Completion Date 12/7/1999 Completion Status I-OIL Interval Start Stop Sent Received Current Status I-OIL Dataset Number Comments 50-029-22945-00-00 UIC N ADDITIONAL INFORMATION Well Cored? Y/{~ ~hip~ 1~ ece~ . Anal~' ' . Daily History Received? (~/N Formation Tops Receuived? (~y N Comments: Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: Phillips Alaska, Inc. August 13, 2001 4401 1 3.5" 9.3 lb. L-80 EUE Tubing Well: 1G-17 Field: Kuparuk State: Alaska APl No.: 50-029-22945-00 Top Log Intvl: 6,700 Ft. (MD) Bot. Log Intvl: 7,100 Ft. (MD) Inspection Type' Pre.Jet-Pack Stimulation Inspection COMMENTS - This log was run to assess the condition of the tubing over the interval where a Jet-Pack stimulation is planned. The caliper recordings indicate the pipe is in good condition over the interval logged, with no significant corrosive damage or scale buildup recorded. Some slight to moderate tubing buckling is indicated over the interval 6,780' - 6,860'. The minimum ID recorded through this interval is 2.85". A dummy run should confirm whether this buckling is severe enough to hinder Jet-Pack stimulation operations. A detail 3D Log Plot of the interval 6890' - 7050' is included in this report. All depths repo.rted in this Summary ReDo,rt are tied into the D-Ni.pple.a,t..a depth of 6970'. MAXIMUM RECORDED WALL PENETRATIONS ' Other than the Perforated Intervals, no significant wall penetrations (> 13%) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · Cross-sectional metal loss as high as 50% is indicated in the perf intervals, 6918' - 6928' & 7001' - 7011'. It is most probable that the indicated metal loss is actually an increased tubing ID (and OD) due to pipe expansion over these intervals, rather than actual metal loss. A cross-sectional drawing of the point of apparent maximum pipe expansion is included in this report. MAXIMUM RECORDED ID RESTRICTIONS: A minimum ID of 2.85", or 0.14" ID restriction, is indicated @ 6784' and 8841', where pipe buckling appears to be the cause. A slip mash is also recorded @ 7033', with a minimum measured ID of 2.85" as well. A cross-sectional drawing of the tubing at the location of the slip mash is included in this report. [Field Engineer- J. Burton Analyst: J. Burton Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Well: 1G-17 Field: Prudhoe Bay Company: PHILLIPS ALASKA Country: USA PDS Caliper Overview Body Region Analysis Survey Date: August 13, 2001 Tool Type: MFC24 No.00387 TooJ Size: 1.69" No. of Fingers: 24 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nora. OD Nora.iD Nora. Upset 3.5 ins 9.3 ppf L-g0 EUE 3.5 ins 2.992 ins 3.5 ins Penetration and Metal Loss (% wall) penetration body ~:~ metal loss body 0to ! to ~0to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 16) Pene 0 12 1 1 1 ~ Loss 0 14 0 0 2 0 Damage Configuration ( body ) Number of joints damaged (total = 3) 0 0 0 0 3 Dama§e Profile (% wall) penetration body ~;~ metal loss body 50 100 Bottom of Survey = 13 Descdp~ion PD.S ~X4ultifinger C;fiiper ~D log Pfo! Company: Phillips Alaska, lnc, F'ieid Kuparu~ River Unit Detai/ of per~orated inte~als where Jet-Pac~ Sti~ulatio~ witi be applied~ Appare.t Metal Loss (%I 50 6900 6910 PERFS ~ 6930 I 6940 PERFS ' 6960 D-Nipple 6970 6980 6990 PERFS POLISH 7020 BORE PDS CALIPER JOINT TABULATION SHEET~ Pipe: 3.5 ins 9.3 ppf L-80 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Penetration Metal Projection Minimum No. Upset Body Loss Upset Body ID [inches finches[% ~ % lincheslincheslinches 3I 0 I .0el 9[ 4[ 0 I 0I ~ I ~ I .o~ ~ ~o I o~ 2.8~ ~ 0 .01 41 6-'~ 0 0 288 6 0 .01 3~ 3 [0 I 0I 2.85 7 0 .01 5] 2 J 0 [ 0[ 2.92 [ 8] 0 ] J7 69/ 44 ]0 .07l_ 2.96 9 0 [ .10 I38[ 3 ~0 [ .06~ 2.97 9.1 B 0 O] 0 ] 0 0 2.88 9.2 0 .B2 9 [ 2 ] 0 .06 2.88 ~0 .~ a~ 9~ s2 ~ .021 .08~2.~6 10.1 0 ] .02] 9] 2 ]0 ~ 0 ] 2.92 ~o.2o /o I °/ o/o Io I zgo 1-~2 [ 0 .01 [ ~/ 2 l0 I 0 2.95 13 ~ ( .01 ~ 5[ 2 [0 0 2.97 Well: 1G-17 Field: Prudhoe Bay Company: PHILLIPS ALASKA Country: USA Date: Augusl I ~, 2081 Top Jr. Logged, Pipe Buckling. Pipe Buckling. Pipe Buckling. PerforaSons. Perforations D-NIPPLE PUP Pertorations PUP POLISH BORE PUP Slip Mash @ 7031' Last IL Logged. Damage Classifications Penetration / projection class, in order of damage severiiy Hole - penetration exceeds 85% of nominal wall thickness Ring- damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds I * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20%. of circumference Damage reporting lhreshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0~193 feet. penetration body metal loss body Damage profile % wa 50 I O0 Well: 1G-I 7 Field: Prudhoe Bay Company: PHILLIPS ALASKA Country: USA Tubin 3.5 ins 9.3 ppf L-80 EUE PDS Caliper Sections Survey Date: August 13, 2001 Tool Type: MFC24 No.00387 Tool Size: 1.69" No. of Fingers: 24 Analysed: J. Burton Cross section for Joint 10 Tcx~l speed = 50 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area -- 54 % Tool deviation = 35 ° at depth 7006.15 ft Finger 22 Penetration = 0.239 ins Expanded Pipe in Perf Interval 8918 - 8928 ft.' Well: 1G-17 Field: Prudhoe Bay Company: PHILLIPS ALASKA Country: USA Tubing: 3.5 ins 9.3 ppf L-80 EUE PDS Caliper Sections Survey Date: August 13, 2001 Tool Type: MFC24 No.00387 Tool Size: 1.69" No. of Fingers: 24 Analysed: J. Burton Cross section for Joint 11 Tool speed = 53 Nominal ID = 2.992 Nominal OD = 3~500 Remaining wall area = 97 % Tool deviation = 30 ° at depth 7033.26 ft Finger 14 Projection =-0.108 Slip Mash Min. ID = 2.85 PDS CALIPER .JOINT TALLY SHEET Pipe: 3.,5 ins 9.3 ppf L-80 EUE Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint j Depth No. ] fee t 1216679-56 6711.34 3 [ 6743.69 4 6775.83 i 6BO&15 6840.57 7 I 6871.99 g i 690.3.92 9 6935.48 I9.11 6967.74 9.2i 6970.90 0 ~ 6979.09 10.1~ 7010.85 0.2~ 7019.02 0.3 ! 7022.35 Length feet 31.78 32.35 32.14 31.42 9 31. 3 31.56 3.16 8.19 31.76 8.17 9.98 Measured 1D inches 3.007 3.014 3.006 3.001 2.983 3.005 2.995 3.003 3.( -'1 nonlinal 2.975 3.010 nominal 3.002 Type Ped-s Perfs I D-Nip Pup Peris Pup Poi. Bore[ Pup j J / 0J_.J3 31.57 2.c~96 7063.90 31.87 3.007 7095.77 unknown 3.003 Well: 1G-17 Field: Prudhoe Bay Company: PHILLIPS ALASKA Country: USA Date: August 13, 2001 JointNo. Depth Length i MeasurectiD :i]Type feel feet , in_ches- ] I ', I .... Joint Tally page 1 WELL LOG 'roActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 Alaska 0il & Gas Cc~,$..r, ommissir~r: Anchor .~.. RE: Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT{S) OR OD-ROM FILM BLUE LINE (::)pen Hole 1 1 1 Res. Eval. CH I I 1 Mech. CH 1G-17 8/13/01 Caliper Survey 1 Rpt or 2 Color Signed: Print Name: ProAcTive Diagnostic Services, Inc., 310 K StreeT Suite 200, Anchorage, AK 99501 Phone:(90?) 245-8951 F'ax:(90?) 245-8952 E-mai]: pdsanchorag¢~mCmorylog.com WCbsit¢: www.memorylo~.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Slimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 953' FSL, 302' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 368' FNL, 1948' FEL, Sec. 31, T12N, R10E, UM At effective depth At total depth 574' FNL, 1971' FEL, Sec. 31, T12N, R10E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic__ Service__ (asp's 540076, 5981600) (asp's 537835, 5980268) (asp's 537814, 5980061) 6. Datum elevation (DF or KB feet) RKB 88 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1G-17 9. Permit number / approval number 199-062 10. APl number 50-029-22945 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE 7372 feet Plugs (measured) 6578 feet PRODUCTION LINER 7197 feet Junk (measured) 6410 feet Length Size Cemented 110' 16" 263 SxAS I 4198' 7-5/8" 450 SxAS III LW & 385 Sx Class G 6667' 5-1/2" 280 Sx Class G 784' 3-1/2" 18.7 bbls Class G Tagged PBTD (4/08/2000) @ 7197' MD. Measured Depth TrueverticalDepth 110' 110' 4286' 3933' 6755' 6022' 7357' 6564' Perforation depth: measured true vertical tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 6912 - 6922'; 6932 - 6942'; 6994 - 7004'; 7198 - 7230' 6159- 6177'; 6175 - 6184'; 6227 - 6235'; 6411 - 6441' 3-1/2", 9.3#, L-80 Tbg @ 6557' MD. BAKER FA-1 PACKER @ 6573' MD. CAMCO DS @ 515' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure RECEIVED FEB 200! /Uaska 0il & Gas Cons. O0mmissior Anchorage 14. OiI-Bbl Prior to well operation 560 Subsequent to operation 1221 Representative Da y Average Production orlnjection Data Gas-Mm Water-Dbl 821 27 389 137 Casing Pressure Tubing Pressure 183 198 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /I~, ~~ Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1G-17 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/3/00: MIRU & PT equipment. RIH w/perforating gun & shot 1' of 'C' sand perforations as follows: Added perforations: 7000 - 7001' MD Used 2-1/8" Enerjet carrier & shot the perfs at 4 spf at zero degree phasing. POOH w/guns. RD. 3/22/00: MIRU & PT equipment. Added perforations: 6994 - 7000' MD 7001 - 7004' MD Reperforated: 7000 - 7001' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf at zero degree phasing. POOH w/guns. RD. 3/31100: MIRU & PT equipment. RIH w/perforating gun & shot 10' of 'C4' sand perforations as follows: Added perforations: 6912 - 6922' MD Used 2-1/8" Enerjet carrier & shot the perfs at 4 spf at zero degree phasing. POOH w/guns. RD. 4/9/00: MIRU & PT equipment. RIH w/perforating gun & shot 10' of 'C3' sand perforations as follows: Added perforations: 6932 - 6942' MD Used 2" HSD carrier & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. RIH w/perforating gun & shot 10' of perforations in the 'C1' Sand as follows: Returned the well to production w/gas lift & obtained a valid well test. TRANSMITTAL FORM BAKER HUGHES Baker Atlas Canada Geoscience Centre TO' Attn: AOGCC 3010 Porcupine Drive Anchorage, Alaska 99501 Lori Taylor Reference' Package contents: Kuparuk River Unit, 1G-17 /1 Digital data on LAS format disk /2 Sepia films /2 GR prints (TVD & Measured depth) Sent by: Glen Hotel Received by: ~/_ _/~_'_ l, ~ Date: December 11, 2000 Date: i/~/O/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (403) 537- 3767 Baker Atlas, 1300, 401 - 95` Avenue S.W., Calgary, Alberta T2P 3C5 (403) 537-3400, Fax (403) 537-3767 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I1. Status of well Classification of Service Well Oil ~1 Gas r~ Suspended D Abandoned r~ Service E~ 2. Name of Operator !~ 7. Permit Number ARCO Alaska, Inc. I! ~ ' 199-62 3. Address ~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~.~ 50-029-22945 4. Location of well at surface _ . . ~ 9. Unit or Lease Name 953' FSL, 302' FWL, Sec. 29, T12N, R10E, UM (ASP: 540076.1, 5981599.5) Kuparuk River Unit At Top Producing Interval ' /~'. ' '~ ¢9¢ 10. Well Number 368' FNL, 1948' FEL, Sec. 31, T12N, R10E, UM (ASP: 537834.8, 5980267.9) ..... 1G-17 At Total Depth ,,~ ;· 11. Field and Pool 574' FNL, 1971' FEL, Sec. 31, T12N, R10E, UM (ASP: 537813.87, 5980061.5) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool 28' RKB feetI ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions July 11, 1999 July 22, 1999 November 13, 1999 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7372' MD / 6578' TVD 7303' MD / 6516' TVD YES [~1 No F1I N/A feet MD 2204' 22. Type Electric or Other Logs Run GR/Res, CBL, MWD/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 110' 24" 263 sx AS 7.625" 29.7# L-80 Surface 4287' 9.875" 450 sx AS III LW, 385 sx Class G 5.5" 15.5# L-80 Surface 6755' 6.75" 280 sx Class G 3.5" 9.3# L-80 6559' 7339' 4.75" 18.7 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6557' 6573' 7198'-7210' MD 6411'-6422' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7210'-7218' MD 6422'-6430' 'I'VD 8 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7218'-7230' MD 6430'-6441' TVD 4 spf 7198'-7218' MD 7.2 ppa 12/18 on perfs, 65000# behind pipe, 18000# in wellbore 7210'-7230' MD 147,000# 16/20 proppant 27. PRODUCTION TEST ! ¢ ! k ! ^ I Date First Production Method of Operation (Flowing, gas lift, etc.) U F~ I LP I I ~1 ~ L December 15, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/8/2000 7.3 Test Period > 222 429 13 176I 1049 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) ~ress. 191 50-9 24-Hour Rate > 731 1413 43 Not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RECEIVED 900 & Gas Cons Commi / r Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 6905' 6984' 7167' 7261' 6161' 6231' 6395' 6479' Annulus left open - freeze protected with diesel. 31. LIST OF A'I-I'ACHMENTS Summary of Daily Operations, Directional Survey ,32. I hereby certify that the following is true and correct to the best of my knowledge. ! Signed ~-J~,;.~'~ ~,"-- ~'~ Title Drilling EnqineerinqSupervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain.~"~ ;~'~, ,~.~ ,: '~' ~"' I~' ~ ~'._. , V_ ~,.~.~ ~'''''.._ Item 28: If no cores taken, indicate "none". Fo rm 10-407 ! · O ""~'~ Date: 08/24/99 ARCO ALASKA INC. WELL SUFfMARY REPORT Page: 1 WELL:iG-17 WELL_ID: AK0039 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/ll/99 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22945-00 07/08/99 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 TD/TVD: 110/110 ( 110) CENTERING RIG OVER 1G-17 SUPV:D. WESTER / S. GOLDBERG Move rig from 2T-1G. Move 15.3 miles. UPCOMING OPERATIONS:N/U DIVERTER AND TEST APIWL: 0.0 07/09/99 (D2) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TV-D: 110/110 ( 0) FINISHING WORK ON DIVERTER LINE SUPV:D. WESTER / S. GOLDBERG Continue rig move from 2T to 1G. MIRU. Accept rig at 0600 hrs. 7/9/99. Work on modifications to cellar to accept diverter system. N/U diverter system. UPCOMING OPERATIONS:FUNCTION TEST DIVERTER AND P/U DRILLPIPE 07/10/99 (D3) MW: 8.6 VISC: 102 PV/YP: 15/31 APIWL: 14.0 TD/TVID: 110/110 ( 0) LOWERING NEW RISER INTO PLACE SUPV:D. WESTER / S. GOLDBERG Held safety drill. Level out diverter line. Discovered 7-5/8" hanger is 15.125" diameter. Will not pass through Hydril or riser. N/D 13-5/8" Hydril and riser. N/U 21-1/4" annular to Nordic diverter. Function test diverter system. Test failed. UPCOMING OPERATIONS:FUNCTION TEST DIVERTER AND SPUD WELL 07/11/99 (D4) MW: 8.6 VISC: 155 PV/YP: 23/37 APIWL: 12.0 TD/TVD: 181/181 ( 71) SHUT DOWN. ATTEMPTING TO ESTABLISH ADEQUATE FLOWRATE SUPV:D. WESTER / S. GOLDBERG Held safety drill. Build new riser. Test annular preventer. Hold pre-spud meeting. Tag bottom ~ 100' (10' of cement in conductor). Clean out cement with water. Change over to mud and drill to 181'. Unable to keep flow rate. Mud running over shakers. Flowline from bell nipple to shakers plugged off. Flow rate too low for MWD to function. UPCOMING OPERATIONS:REMAIN SHUT DOWN UNTIL ABLE TO ESTABLISH GOOD RATE BEFORE PROCEEDING Date: 08/24/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/12/99 (DS) MW: 8.8 VISC: 145 PV/YP: 20/36 APIWL: 12.6 TD/TVD: 351/351 (170) CONTINUE RIG MODS SUPV:D. WESTER / S. GOLDBERG Change screens on #3 shaker to 20 mesh, jet out flowlines. Drilling ahead from 181' to 351' POOH. Flowrates possible without surface problems is not adequate to clean hole. Modify flowline upstream of shakers to distribute mud. Modify flowline downstream of shakers to take partial flow to tank and pump back to pits. Add jets to system. UPCOMING OPERATIONS:TEST MODIFICATIONS TO SYSTEM, DRILL AHEAD 07/13/99 (D6) MW: 8.9 VISC: 117 PV/YP: 16/38 APIWL: 13.2 TD/TVD: 660/659 (309) DRLG 9 7/8' HOLE ~ 980' MD SUPV:D. GLADDEN / R. OVERSTREET Continue to modify flowline. Modify mud system. Test mud system. Drilling 9-7/8" hole from 351' to 660' MD. UPCOMING OPERATIONS:DRLG TO TD - RUN & CMT 7 5/8" CSG 07/14/99 (D7) MW: 9.1 VISC: 65 PV/YP: 15/24 APIWL: 15.0 TD/TVD: 1650/1648 (990) DRILLING 9-7/8" HOLE 8 2127' SUPV:D. GLADDEN / R. OVERSTREET Continued drilling from 660' to 1224' Circulate and condition. P~mped dry job, blow down top drive. POOH, MWD failure. Change out MWD. RIH to 1164' Break circulation, survey, wash and ream 60' to bottom. Continued drilling from 1224' to 1650' UPCOMING OPERATIONS:DRILL TO TD - RUN & CMT 7-5/8" CSG. 07/15/99 (D8) MW: 9.6 VISC: 70 PV/YP: 27/39 APIWL: 7.0 TD/TVD: 3278/3055 (1628) DRILLING 9-7/8" HOLE @ 3817' SUPV:D. GLADDEN / R. OVERSTREET Drill from 1650' to 2512' Circulate and condition mud. POOH to 1171'. Wiper trip. RIH. Replace hydraulic hose on load cell f/torque guage. Wash down from 2418' to 2514' Continued to drill from 2512' to 3278' UPCOMING OPERATIONS:DRILL TO TD - RUN & CEMENT 7-5/8" CASING. 07/16/99 (Dg) MW: 9.6 VISC: 120 PV/YP: 30/63 APIWL: 5.2 TD/TVD: 4292/3891 (1014) CIRCULATING AND CONDITIONING MUD W/HOLE OPENER ~ TD. SUPV:D. GLADDEN / R. OVERSTREET Continued drilling from 3278' to 4292' TD. Circulate and condition mud. TOH, short trip. TIH to 2340', tight hole. UPCOMING OPERATIONS:CONDITION MUD, POOH W/HOLE OPENER. RIH W/7-5/8" CSG. & CEMENT. Date: 08/24/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/17/99 (D10) MW: 9.6 VISC: 71 PV/YP: 26/27 APIWL: 5.8 TD/TV-D: 4292/3891 ( 0) WITH 7-5/8" CASING ~ TD (4286'), CIRCULATING AND CONDI SUPV:D. GLADDEN / R. OVERSTREET RIH w/hole opener. Wash and ream @ 2549' to 2644' RU to run 7-5/8" casing. PJSM. RIH w/7-5/8" casing. UPCOMING OPERATIONS:CEMENT 7-5/8" CASING. ND DIVERTER AND NU BOPE STACK. 07/18/99 (Dll) MW: 8.4 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 4292/3891 ( 0) N/U BOPS SUPV:D. GLADDEN / R. OVERSTREET PJSM. Pump cement in 7-5/8" casing. N/D diverter, NU BOPs. UPCOMING OPERATIONS:FINISH N/U - TEST BOPS - P/B BHA 07/19/99 (D12) MW: 8.4 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 4292/3891 ( 0) DRLG OUT FLOAT & SHOE JOINTS SUPV:D. GLADDEN / R. OVERSTREET N/U BOPs and test to 300/3000 psi. RIH w/HWDP. UPCOMING OPERATIONS:MAKE 20' NEW HOLE - PERFORM LOT - TD HOLE(TOP SET KRU) - RUN 5 1/2 CSG 07/20/99 (D13) MW: 9.5 VISC: 42 PV/YP: 14/18 APIWL: 5.8 TD/TVD: 5270/4745 (978) CONTROL DRILLING FOR LOGS THROUGH CAMP SS SUPV:D. WESTER/S. GOLDBERG Tag cement at 4102'. Test 7-5/8" casing to 1500 psi, OK. Drill cement from 4102' to 4312' Perform LOT to 15.4 ppg. Hold safety meeting. Drill from 4312' to 5270' UPCOMING OPERATIONS:DRILL TO TD AT APPROX. 6700' AS PER GEOL 07/21/99 (D14) MW: 9.6 VISC: 42 PV/YP: 16/15 APIWL: 4.4 TD/TVD: 6530/5815 (1260) REPAIR FLUID PACKOFF ON TOP DRIVE SUPV:D. WESTER/S. GOLDBERG Wash to bottom. No fill on bottom. Drilling from 5270' to 5580'. Begin control drilling to get good logs, from 5822' to 6179' Work on top drive torque tube. Will not slide freely. Clean torque tube and guide. Continue drilling from 6179' to 6530' Sliding to drop angle. UPCOMING OPERATIONS:RUN BACK IN HOLE AND TD WELL AS PER GEOLOGIST 07/22/99 (D15) MW: 9.7 VISC: 46 PV/YP: 18/20 APIWL: 4.2 TD/TVD: 6755/6028 (225) LAYING DOWN DRILLPIPE FROM DERRICK SUPV:D. WESTER/S. GOLDBERG Continue drilling from 6530' to 6679' Pull up into 7-5/8" casing shoe. Repair packing from standpipe into top drive. Repair torque tube guide. Run back in hole. Precautionary wash and ream last stand to bottom. Continue drilling from 6679' to 6755' POOH. UPCOMING OPERATIONS:RUN 5 1/2" INTERMEDIATE CASING 07/23/99 (D16) MW: 9.8 VISC: 47 PV/YP: 18/16 APIWL: 4.2 TD/TV-D: 6755/6028 ( 0) MAKING FIRST CUT ON 5 1/2" CASING TO SET ON SLIPS SUPV:D. WESTER/S. GOLDBERG Continue tripping out of hole laying down drillpipe and BHA. Hold safety meeting. RIH with 5.5" casing. UPCOMING OPERATIONS:MAKE UP TUBING HEAD, LAND TUBING HANGER, FREEZE PROTECT 5 1/2" X 7 5/8" ANNULUS 07/24/99 (D17) MW: 8.5 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TV-D: 6755/6028 ( 0) MOVING RIG FROM 1G TO 3G SUPV:D. WESTER/S. GOLDBERG Hold PJSM. Pump cement. Bump plug. Install packoff and N/U tubing head. Test packoff to 2500 psi. Back off well and prep rig for move. Release rig at 2000 hrs. 7/24/99 UPCOMING OPERATIONS:CONTINUE MOVING; MIRU 1G-17 DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 11/07/1999: 11/08/1999: 11/09/1999: 11/10/1999: 11/11/1999: 11/12/1999: 11/13/1999: 11/14/1999: 11/15/1999: 11/16/1999: 11/17/1999: 11/18/1999: 11/19/1999: 11/20/1999: 11/21/1999: 11/22/1999: 11/23/1999: 11/24/1999: MIRU of 3S & CTU. NU BOPE. Rig accepted @ 0700 hrs. Full BOPE test to 5000 psi. RIH w/BHA & tagged TOC @ 6666' MD. Displaced well to mud. Milled float shoe to 6755' & POOH w/BHA. RIH & resumed milling float shoe. POOH. RIH & completed milling float shoe. Milled 10' ofFM & POOH. RIH w/bi- centered bit & performed LOT to EMW of 15.1 ppg. Drilled to 6809' MD. Drilled to 6863' & POOH. RIH w/BHA. Reamed tight spot @ 6822'. Drilled to 7070'. Drilled to 7091' & POOH. RIH & reamed to 7092'. Drilled to 7190'. Drilled to TD @ 7372' MD. POOH. BHA left in hole as fish (coil connector came off coil). RU Slickline unit. RIH w/LIB and tagged fish @ 6775'. POOH w/LIB. RIH w/fishing assembly & attempted to latch on fish. Sheared off w~ POOH. Fish still in hole. RD Slickline. RIH & successfully retrieved fish f/wellbore. PT'd BOPE. RIH w/BHA to TD. Reamed OH & POOH. RIH & logged well f/6500' - 6940'. POOH. RIH & conditioned OH to 7372'. Conditioned OH & POOH. Weather delays. RIH & reamed OH. Weather delays. Conditioned OH for liner. Reamed shaley intervals in OH in prep for liner. POOH. MU 3-1/2" liner. RIH & landed the 3-1/2" liner @ 7339' MD. TOL = 6559'. Cemented liner in place by pumping 18.7 bbls of 15.8 ppg Class G Cement (LARC). Launched dart & plug bumped. 1:1 returns. Squeezed to 1000 psi. Unstung f/liner & POOH. RIH w/nozzle & cleaned out to 7909'. POOH w/CT. WOC. CT RDMOL. PT'd liner for 30 rain to 1700 psi - held tight & passed. RU pipe shed. MU 3-1/2" completion tubing. Drifted casing to 4.80" w/SL. PU completion jewerly & pipe. RIH w/completion string. Continued to RIH w/3-1/2" completion. RU SL. Equalize well. RIH & pulled tbg check valve. RIH w/tbg. Latch PBR & shear of same. Space out. Displace well. Landed tbg. ND BOPS. RDMOL. Displaced tbg to Diesel. Rig release 2100 hrs. Summary of Coiled Tubing Drilling Operations on: Kuparuk 1G- 17 Starting Date: 11/06/99 EXTENSION Date DepthDaily Summary' Comments 07-Nov. 6,755 Rig up rig & CTU #4 on 1G-17. Take on fluids & N/U BOPE on (2) full opening master valves. Pull BPV, set TP. Full test on BOPE to 5000 psi. Pull TP, set wear bushing. PT MVs to 3000 psi. 08-Nov. 6,755 MU Milling BHA. RIH & displace well to mud. Mill 5-1/2" float equipment. POOH due to poor milling speed...c/o motor & mill & RIH w/BHA #2. Tag @ 6755' & mill on float equipment. 09-Nov. 6,809 Mill on float shoe. Trip for bit. Mill float shoe & 10' of formation. POOH. RU to pressure deploy. MU BHA #4 (build assy). Press dep same. RIH. Perform FIT to 15 ppg. Drill build to 6809'. 10-Nov. 6,863 Drill ahead f/6782'-6863'. ROP 5-10 fph. Uncertain of location of target sand. POOH f/ 2 7/8" motor & 4.75" PDC bit to increase ROP & take a load off the pumps. RIH w/ BHA #5. 11-Nov. 7,070 Log tie-in. Orient & ream to btm. Drill tangent to 6982'. Short trip to csg. Had to reem hole f/6920' back to bottom. Drill ahead to 7070'. 12-Nov. 7,190 Repair brake on injector. Orient and drill to 7091'. Trip for hours on motor. MU BHA #6 (str motor, no mwd). RIH, tag & motor work @ 6900', ream down to 7092' & drill to 13-Nov. 7,372 Drill ahead f/7190'-7372', short tripping as necessary to bring cuttings to surface. Pump paking out on Dowell pump. Pull up into shoe, get Nabors pump on line. RIH, tag w/ no motor work. POOH. 14-Nov. 7,372 OOH. 2 3/8" dimple con. & BHA left in hole. Wait on slickline unit. R/U slickline & m/u LIB. RIH & tag @ 6775'. POOH, imp of dimp con on LIB. Fish BHA #6 w/slickline. Shear off. R/D SL. P/U injector. 15-Nov. 7,372 M/U fishing BHA & RIH. Tag & latch up fish @ 6775'. Jar down 3 times & pull 15K over & POOH. Pressure undeploy & L/D fish. Recovered all. Test BOPE. RIH w/BHA #8 to TD well. RIH w/BHA #8. Set dh. @6875'. Pulling 80k#. Free @ 8610'. Ream slowly to TD of 7372'. POOH. RIH w/PDS tools. Log f/ 6500'-6940'. Hard tag. POOH. RIH w/bi cent, ream hole to TD. 16-Nov. 7,372 Summary of Coiled Tubing Drilling Operations on: Kuparuk 1G- 17 17-Nov. 7,372 Condition hie to 7365', (TD). POOH to 500' chasing a goodly amount of cuttings ahead of the bit. RIH & ream to 7365'. Phase 3 cond. Pull to shoe & circulate @ .5 bpm holding 1300 psi on wellhead. 18-Nov. 7,372 Wait on weather (phase 3). Ream shales in OH for liner. Trip to changeout BHA (HD washout). Ream shales to TD. 19-Nov. 7,365Swap to 14.4 ppg KWM. Condition hole for running liner. MU liner. 20-Nov. 7,365 Run and cement liner. Run liner top/production packer. Begin RD of CT. 21-Nov. 7,365 RDMO CT. MIRU pipe shed. Pressure test liner, good. Continue to RU pipe shed. Load, drift, and strap 3 1/2" production tubingl 22-Nov- 7,365 Drift and strap production tubing. Drift casing to 4.80" w/SL. PU completion jewelry and pipe. RIH with 3-1/2" completion. 23-Nov. 7,365 RIH with 3-1/2" completion. RU slickline. Equalize well. RIH & pull tbg check valve. RIH with tbg. Latch PBR & shear off same. Space out. Displace well. Land tbg. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT ,~' KI(1G-17(W4-6)) WELL JOB SCOPE JOB NUM'BER " 1G-17 DRILLING SUPPORT-CAPITAL 1126991118.1 DATE DAILY WORK UNIT NUMBER 12/03/99 CEMENT BOND LOG SWS 2158 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 NO YES SWS-STEPHENSON SCHUDEL FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AK0039 230DS10GG $5,418.00 $42,443.50 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 300 PSI 300 PSI 450 PSI 450 PSII 250 PSI 250 PSI DAILY SUMMARY [ CEMENT BOND LOG COMPLETE- PBTD @ 7298' TIME LOG ENTRY 15:00 DEPART FROM 3F-19 TO 1G-17 15:20 ARRIVE ON LOCATION - HOLD SAFETY MEETING - START RIG UP 16:00 PRESSURE TEST TO 3000# 16:15 RIH WITH PRESSURE / TEMPERATURE / CCL / GAMMA / SCMT 17:10 TAG PBTD @ 7298', WHP @ 1500 PSi 17:15 LOG 200' SECTION FROM PBTD 17:30 LOG MAIN PASS FROM PBTD TO 6000' 18:05 POOH 18:45 START RIG DOWN 19:45 COMPLETE RIG DOWN - LEAVE LOCATION 20:00 RETURN TO KIC SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $612.00 APO $200.00 $3,550.00 ARCO $900.00 $6,472.00 DOWELL $0.00 $7,699.00 GYRODATA $0.00 $6,000.00 HALLIBURTON $0.00 $1,400.00 LITTLE RED $0.00 $1,599.00 SCHLUMBERGER $4,318.00 $15,111.50 TOTAL FIELD ESTIMATE I $5,418.00] $42,443.50 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,~' KI(1G-17(W4-6)) WELL JOB SCOPE JOB NUMBER " 1 G-17 DRILLING SUPPORT-CAPITAL 1126991118.1 DATE DAILY WORK UNIT NUMBER 12/07/99 PERFORATING & STATIC BOTTOM HOLE PRESSURE 2158 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 YES YES SWS-STEPH ENSON REEM FIELD AFC# CC# Signed ESTIMATE AK0039 230DSl 0GG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 400 PSI 350 PSI 350 PSII 300 PSI 300 PSI DAILY SUMMARY PERFORATED FROM 7198'- 7218', SBHP @ 7208' = 3801 PSI. TAGGED PERF DEBRIS AT 7215' ELM. TIME LOG ENTRY 07:00 DEPART FOR 1 G-17 07:30 ARRIVE AT LOCATION - HOLD SAFETY MEETING - START RIG UP 08:30 CALL FOR RADIO SILENCE 09:00 PRESSURE TEST TO 3000# 09:15 RIH WITH CCL- MPD - SAFE - 20' ENERJET WITH BIG HOLE CHARGES 10:00 LOG TIE IN STRIP 10:10 LOG INTO SHOOTING POSITION 10:15 PERFORATE FROM 7198'- 7218' WITH 20' ENERJET WITH BIG HOLE CHARGES EHD = 0.57", TTP = 17.1", 4 SPF 10:20 POOH 11:00 RIG DOWN GUN - ALL SHOTS FIRED 11:30 RELEASE RADIO SILENCE 11:45 RIG UP PSP 11:55 RIH WITH 3 WGT BAR & PRES - TEMP - CCL - GAMMA 12:25 12:40 13:50 14:05 LOG TIE IN STRIP - TAG PBTD @ 7215' (IN PERFORATED ZONE) PERFORM SBHP @ 7208', PRESSURE @ 4510 PSI PRESSURE @ 4390 PSI & DROPPING STEADY, BLEED OFF 150 PSI AT WELL HEAD (INITIALLY 1700 PSI) BLEED OFF ANOTHER 100 PSI 14:10 BLEED OFF AGAIN- BHP @ 3980 PSI 14:30 BLEED WHP, BHP @ 3900 PSI 14:50 BLEED DOWN WHP - BHP @ 3860 PSI 15:15 BLEED DOWN LUBRICATOR - BHP CHANGING SLIGHTLY 15:50 PRESSURE STABLE FOR 30 MIN @ 3801 PSI & 160 DEG F, POOH 16:30 START RIG DOWN 17:30 COMPLETE RIG DOWN - LEAVE LOCATION 18:00 RETURN TO KCC ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~, K1(1G-17(W4-6)) WELL JOB SCOPE JOB NUMBER 1 G-17 FRACTURING. 1209991604.1 DATE DAILY WORK UNIT NUMBER 12/10/99 FRACTURE TREATMENT DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES NO DS-YOAKUM ODELL FIELD AFC# CC# Signed ESTIMATE AK0040 230DS10GG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 1320 PSI 0 PSI 460 PSI 500 PSI 0 PSI 0 PSI DALLY SUI~IMARY PUMPED FRACTURE TREATMENT, HAD NEAR WELLBORE SCREENOUT W/7.2 PPA 12/18 ON PERFS. 65000# BEHIND PIPE, 18000# IN WELLBORE. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS EQUIPMENT. HEAT DIESEL TRANSPORT. 08:00 SAFETY MEETING (JOB REVIEW, COLD WEATHER, SLICK SPOTS). WARM UP AND PRIME UP PUMPS. TRY TO SET TREESAVER, WELL PRESSSURES UP. LOOKS LIKE AN ICE PLUG IN TUBING MOVING DOWNHOLE. PUMP 15 BBLS DIESEL HOT DIESEL, -2 BPM, 3500 PSI. TREESAVER WOULD NOT SET, SROKE TREESAVER, TRY TO RESET, UNSUCCSESSFUL. SUSPECT ICE IN TUBING PUP WHERE TREESAVER TRYING TO SET. 09:40 RIG HOT OIL UP TO TREE TO PUMP 150 DEG DIESEL DOWN WELL TO THAW. 10:00 PUMP 15 BBLS DIESEL, 150 DEG, 1.5 BPM, 3200 PSI. 10:15 ATTEMPT TO SET TREESAVER AGAIN, UNSUCCESSFUL. BLEED DOWN TO PULL TREESAVER. MASTER VALVE PRESSURE LOCKED, CALL VALVE CREW. 11:00 12:30 VALVE CREW ON LOCATION, MASTER WORKING. RIG DOWN TREESAVER. ELEMENT WAS SPLIT. RE-RUN TREESAVER WITH NEW ELEMENT AND CUPS. TEST TREESAVER. UNSUCCESSFULL. PULL TREESAVER. ELEMENT SPLIT AGAIN. MARKS ON ELEMNET LOOK LIKE IT IS HITTING SOMETHING (COLLAR ON BOTTOM OF HANGER?) ON THE WAY IN THE HOLE. REPLACE ELEMENT AND RIG TREESAVER TO WELL. RIG UP HOT OIL TO PUMP 150 DEG DIESEL DOWN WELL TO WARM UP ELEMENT BEFORE ATTEMPTING TO SET IT. WARMED UP ELEMENT, SET TREESAVER. GOOD TEST. 13:15 PRESSURE TEST LINES TO 8200, GOOD TEST. 13:30 PUMP BREAKDOWN, 200 BBLS 20# LINEAR GEL, SAW BREAKBACK AT 6630 PSI TO 5450 PSI. PERFORM SDT, XS FRIC = 1993 PSI @ 30 BPM. BUILD GEL IN PCM. TIME 13:55 14:35 15:35 16:35 18:00 LOG ENTRY PUMP SCOUR STAGE. 100 BBL 50# XL PAD, 100 BBL 50# XL W/1 PPA SAND SCOUR, 100 BBL 20# FLUSH. PERFORM SDT, XS FRIC = 530 PSI, ISIP = 2140 PSI, FG = .79. MAKE MORE GEL FOR DATAFRAC. PUMP DATAFRAC. 150 BBLS 50# XL GEL, FLUSHED W/65 BBLS 20# LINEAR GEL. PERFORM DECLINE ANALYSIS, ISIP = 2340 PSI, FG = .83, PC = 2261 PSI, TC = 4.7 MIN, EFFC = 32%. ADJUST PAD TO 380 BBLS. PUMP PROPPANT STAGES. HAD INSTANTANEOUS NEAR WELLBORE SCREENOUT IN 2-10 RAMP STAGE. 7.2 PPA ON PERFS, 69000# BEHIND PIPE. 18000# IN WELLORE. FLUSH LINES, RD DS EQUIPMENT. DS RIGGED OFF WELL. WELL SECURE. ALL TREESAVER RUBBERS RECOVERED. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1(1G-17(W4-6)) WELL JOB SCOPE JOB NUM'BER ' " 1G-17 PERFORATIONS-E-LINE 0108001904.5 DATE DAILY WORK UNIT NUMBER 01/10/00 PERF 2145 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES SWS-VETROMILE GOBER FIELD AFC# CC# Signed ESTIMATE AK0040 230DS10GG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 200 PSI 200 PSI 600 PSI 600 PSI 500 PSII 500 PSi DAILY SUMMARY PERFORATED 7210'-7230' W/2.125" ENERJET 4SPF/BH/0 DEG PHASING - TOOL STUCK RIGHT AFTER SHOOTING. PUMPED 105BBLS 150 DEGF DIESEL. DID NOT UNSTICK TOOL. PULLED UP TO WEAKPOINT BREAKING TENSION AND TOOL CAME FREE. POOH - RECOVERED TOOLS[Perf] TIME LOG ENTRY 07:45 MIRU 08:40 SAFETY MEETING TEST FIRE ON SURFACE 08:45 RADIO SILENCE 08:55 ARM GUN 09:05 PRESSURE TEST TO 3000 PSI 09:15 RIH WITH CCL, 20' 2-1/8" BH ENERJET 09:50 CALL WELL SUP. AND LET HIM KNOW THAT WE ARE AT 5000 FT, ALMOST TO TIE IN 10:10 TIE INTO SWS PERF DATED DEC. 7, 99 10:20 IN SHOT POSSlSlON, WAITING ON WELL SUP. 11:10 11'12 11:22 11:50 12:05 WELL SUP LOOKS AT LOGS, TIED IN AND SHOT7210'-7230' INTERVAL W/2.125" ENERJET/4 SPF/BH/0 DEG PHASING LOG OFF, PULL TIGHT, AND GOT STUCK. DID NOT MOVE AT ALL. WORK THE LINE TO GET FREE. CALL HOT OIL TO PUMP DIESEL (150 DEG F). HOT OIL MIRU PUMPS START 3BPM, 150 DEG F DIESEL 12:25 45 BBLS AWAY AT 400 PSI 13:00 PUMPS SHUT DOWN, DECIDED TO PULL OFF. WORKING LINE 12:20 PULLING TO BREAK WEAKPOINT AND TOOL COMES FREE. POOH - RECOVERED ALL TOOLS 14:00 START RIG DOWN 15:00 RDMO ARCO Alaska. Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT ,, K1(1G-17(W4-6)) WELL JOB SCOPE JOB NUMBER " 1G-17 FRACTURING. 0115000539.3 DATE DALLY WORK UNIT NUMBER 01/21/00 FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 NOI YES FERGUSON FIELD AFC# CC# Signed ESTIMATE AK0040 230DS10GL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY RU DOWELL PUMP EQUPMENT AND PUMP BREAKDOWN TREATMENT AT 25 BPM AND 3900 PSI. PUMP SCOUR TREATMENT OF 1 PPA AT 20 BPM AND 3200 PSI. PERFORM SDT. FG=0.77 PSI FT. EXCESS FRICTION 130 PSI. ATTEMPTED 2 DATAFRACS, WAS NOT ABLE TO OBTAIN PRESSURE DATA DUE TO FAILED TRANSDUCER. REPLACED PRESSURE TRANSDUCER AND PUMPED FRAC USING DESIGNED PAD VOLUME. PLACE 147,000#'S 16/20 PROPPANT WITH MAX CONCENTRATION OF 12 PPA. SCREENED OUT 13 BBLS INTO THE 59 BBL FLUSH. ESTIMATE TOP OF FILL AT 1500'.[Frac- Refrac] TIME LOG ENTRY 07:30 ARRIVE LOCATION. DOWELL RU PUMP EQUIPMENT. 07:55 HOLD SAFETY MEETING 08:30 PT LINES TO 9000 PSI. 08:45 START HPBD AT 25 BPM. PERFORM SDT. ISIP=1671 PSI, FG=0.71 PSI/FT, XS FRICTION= 805 PSI. TREATING AT LOWER PRESSURES AND FRICTION THAN PREVIOUS FRAC ATTEMPT. 09:00 START SCOUR STAGE. PUMP 100 BBLS OF 1 PPA AT 20 BPM AND FLUSH. PERFORM SDT AND ISIP AT 2010 PSI. FG=0.77 PSI/FT. XS FRICTION WAY DOWN AT 130 PSI AT 20 BPM. 09:45 START DATAFRAC WITH 50# XL GEL. PRESSURE SENSORS FROZE UP, UNABLE TO COLLECT VALID PRESSURE DATA FOR DATAFRAC. WILL FLUSH DATAFRAC AND REPEAT. 10:30 REPEAT DATAFRAC. HAVE TRANSDUCERS THAWED OUT AND GETTING GOOD PRESSURE DATA. 10:35 STILL GETTING ERRATIC PRESSURE DATA FROM TRANSDUCER. RETIGHTEN TRANSDUCERS AND APPEAR TO BE GETTING GOOD DATA AGAIN. 10:45 LOST PRESSURE DATA AGAIN. ANOTHER BAD DATAFRAC. LOCATE REPLACEMENT TRANSDUCERS AND C/O. 11:10 START FRAC. PLAN TO PUMP USING DESIGN PAD. LENGTHENED 4 PPA FLAT STAGE FROM 100 TO 250 BBLS, CUT 4-10 PPA RAMP STAGE FROM 400 TO 300 BBLS. TOTAL PROP DESIGN IS THE SAME. TIME LOG ENTRY 12:20 PLACED 147,126#'S PROPPANT WITH MAX CONC. OF 12 PPA ON FORMATION. SCREENED OUT 13 BBLS INTO THE 59 BBL FLUSH. LEFT APPROX 16,000#'S OF PROPPANT IN WELLBORE. ESTIMATED TOP AT 1500'. 13:30 RDMO FRAC EQUIP ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 2000 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1G-17 (Permit No. 199-62) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1G-17. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad RECEIVED Oil & Gas Cons. C0mm~ ~chora~ ORIGINAL ARCO ALASKA INC. DRILLSITE 1G, WELL NO. 1G-17 KUPARUK RIVER UNIT, ALASKA Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date :03- DECEMBER, 1999 Job number · AK1299GCE536 RECEIVED , ,~','.,., 10 2000 ~Oil&OasCe~s. Cm~ Ar~ora~ CONTENTS JOB NUMBER · AK1299GCE536 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL '5. EQUIPMENT AND CHRONOLOGICAL REPORT RECEIVED N~hor'4te 1. DISCUSSION, SURVEY CERTIFICATION SHEET RECEIVED ,. 10 2000 Alaska 0il & Gas Co~s. Commisskm Anchorage DISCUSSION JOB NUMBER: AK1299GCE536 Tool 789 was run in WELL# 1G-17 on SCHLUMBERGER 7/32" wireline inside 3.5" TUBING. The survey was completed without any problems. RECEIVED 2000 All. Oil &Gas Co~s. Com~ Anchora,~e SURVEY CERTIFICATION SHEET JOB NUMBER' AK1299GCE536 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set for[h by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JIM GILMORE OPERATIONS MANAGER RECEIVED ~011 & Gas Oons. Commimion 2. SURVEY DETAILS RECEIVED ~'?,I'.,! 10 2000 SURVEY DETAILS JOB NUMBER ' AK1299GCE536 CLIENT · ARCO ALASKA INC. RIG · SCHLUMBERGER LOCATION · DRILLSITE 1G WELL · LATITUDE · LONGITUDE' SURVEY DATE' SURVEY TYPE · 1G-17 70.33 N 149.66W 03- DECEMBER, 1999 GYRO CONTINUOUS RECEIVED 10 2000 Alaska 0il & Gas Cu~s. Commimk~ Anchorage DEPTH REFERENCE' ROTARY TABLE ELEVATION 88' MAX. SURVEY DEPTH' 7283' SURVEY TIED ONTO ' N/A SURVEY INTERVAL' 0-7283' APl NUMBER' TARGET DIRECTION · 50-029-2294500 240.29 GRID CORRECTION · N/A CALCULATION METHOD' MINIMUM CURVATURE SURVEYOR' TOM STODDARD RECEIVED 2000 Ala~a 0ti & Gas Cons. Co~mission Ancho~ 3. INRUN SURVEY LISTING gyro/data A Gyrodata Directional Survey for Arco Alaska Inc. Well: 1G~17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536 Run Date: 12/3/99 2:30:00 PM Surveyor: Tom Stoddard Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.330000 deg. N Sub-sea Correction from Vertical Reference: Azimuth Correction: Gyro: Bearings are Relative to True North 88.00 ft. Proposed Well Direction: 240.290 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location '-:~;¢ 70 2000 ,~aska ~ & Gas Co~s. Horizontal Coordinates Calculated from Local Horizontal Reference gym/data A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location' DRILLSITE 1G, KUPARUK RIVER ~NIT, ALASKA Job Number: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 0.0 0.00 0.00 0.00 0.0 -88.0 0.0 100.0 0.29 89.35 0.29 100.0 12.0 -0.2 200.0 0.42 120.00 0.23 200.0 112.0 -0.6 300.0 0.34 92.66 0.19 300.0 212.0 -1.1 400.0 0.45 94.01 0.11 400.0 312.0 -1.6 RECEIVED CLOSUR~~ ONTAL DIST. AZIMUTH '-" COORDINATES feet deg. feet 0.0 0.0 0.00 N 0.00 E 0.3 89.3 0.00 N 0.25 E 0.8 102.2 0.18 S 0.82 E 1.5 104.6 0.37 S 1.43 E 2.2 101.1 0.41 S 2.12 E 500.0 0.54 106.56 0.14 600.0 0.54 108.15 0.02 700.0 0.54 110.71 0.02 800.0 0.49 109.97 0.05 900.0 0.47 111.51 0.02 500.0 600.0 700.0 800.0 900.0 412.0 512.0 612.0 712.0 812.0 -2.3 -2.9 -3.5 -4.1 -4.7 3.0 101.0 0.58 S 2.96 E 4.0 102.5 0.86 S 3.86 E 4.9 103.8 1.17 S 4.75 E 5.8 104.8 1.48 S 5.59 E 6.6 105.6 1.78 S 6.37 E 1000.0 0.49 108.43 0.03 1100.0 0.53 110.24 0.05 1200.0 0.53 87.23 0.21 1300.0 0.61 116.18 0.29 1400.0 0.68 122.83 0.11 1500.0 1.00 166.60 0.69 1600.0 3.90 218.39 3.38 1700.0 9.66 232.93 5.96 1800.0 10.16 235.92 0.72 1900.0 13.70 238.08 3.57 1000.0 1100.0 1200.0 1300.0 1400.0 1499.9 1599.8 1699.1 1797.6 1895.4 912.0 1012.0 1112.0 1212.0 1312.0 1411.9 1511.8 1611.1 1709.6 1807.4 -5.2 -5.8 -6.5 -7.2 -7.8 -7.8 -4.4 7.1 24.2 44.8 7.5 106.1 2.06 S 7.16 E 8.3 106.4 2.36 S 8.00 E 9.2 105.7 2.50 S 8.90 E 10.2 105.4 2.71 S 9.83 E 11.3 106.8 3.27 S 10.81 E 12.3 111.1 4.43 S 11.51 E 12.5 129.6 7.94 S 9.60 E 15.7 177.1 15.67 S 0.78 E 28.9 207.2 25.67 S 13.21W 47.9 219.7 36.88 S 30.57W 1950.0 15.37 239.28 3.39 2000.0 16.15 240.15 1.62 2050.0 16.84 241.01 1.47 2100.0 17.52 241.29 1.36 2150.0 18.98 241.43 2.92 1943.8 1992.0 2039.9 2087.7 2135.2 1855.8 1904.0 1951.9 1999.7 2047.2 57.4 71.0 85.2 99.9 115.6 59.9 223.6 43.39 S 41.30W 73.0 226.5 50.24 S 53.03W 86.9 228.8 57.21 S 65.40W 101.4 230.6 64.34 S 78.33W 116.8 232.0 71.84 S 92.07W 2200.0 20.22 241.56 2.47 2182.3 2094.3 132.3 133.4 233.2 79.84 S 106.81W gyro/data A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. RECEIVED CLOSURE HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 2250.0 22.04 242.43 3.71 2300.0 23.27 242.60 2.46 2350.0 24.67 242.68 2.79 2400.0 25.17 242.77 1.00 2228.9 2275.0 2320.7 2366.1 2140.9 2187.0 2232.7 2278.1 150.4 151.2 234.3 88.30 S 169.6 170.3 235.2 97.19 S 189.9 190.4 236.0 106.53 S 210.9 211.4 236.7 116.18 S 122.73W 139.81W 157.85W 176.58W 2450.0 25.37 241.86 0.87 2500.0 26.78 238.89 3.85 2550.0 29.81 238.62 6.05 2600.0 31.27 239.15 2.98 2650.0 33.84 239.85 5.19 2411.3 2456.2 2500.2 2543.3 2585.4 2323.3 2368.2 2412.2 2455.3 2497.4 232.3 232.6 237.2 126.10 S 254.2 254.6 237.4 136.97 S 277.9 278.2 237.6 149.26 S 303.3 303.6 237.7 162.39 S 330.2 330.5 237.8 176.04 S 195.47W 214.57W 234.83W 256.58W 279.76W 2700.0 35.26 240.31 2.90 2750.0 35.77 241.12 1.39 2800.0 35.71 241.13 0.13 2850.0 35.10 240.99 1.23 2900.0 35.01 241.08 0.21 2626.6 2667.3 2707.9 2748.6 2789.6 2538.6 2579.3 2619.9 2660.6 2701.6 358.6 358.9 238.0 190.18 S 304.34W 387.6 387.9 238.2 204.39 S 329.67W 416.8 417.1 238.4 218.49 S 355.25W 445.8 446.0 238.6 232.51 S 380.60W 474.5 474.7 238.7 246.42 S 405.73W 2950.0 34.51 240.78 1.06 3000.0 34.34 240.69 0.34 3050.0 34.08 240.42 0.61 3100.0 33.58 240.23 1.01 3150.0 33.58 240.14 0.09 2830.6 2871.9 2913.2 2954.8 2996.4 2742.6 2783.9 2825.2 2866.8 2908.4 503.0 503.2 238.9 260.27 S 531.3 531.4 239.0 274.08 S 559.4 559.5 239.0 287.90 S 587.2 587.4 239.1 301.68 S 614.9 615.0 239.1 315.43 S 430.64W 455.30W 479.78W 503.97W 527.97W 3200.0 34.54 239.77 1.96 3250.0 34.78 239.39 0.64 3300.0 34.67 239.28 0.24 3350.0 34.13 239.36 1.09 3400.0 34.23 239.37 0.21 3037.8 3O79.0 3120.1 3161.3 3202.7 2949.8 2991.0 3032.1 3073.3 3114.7 642.9 643.0 239.2 329.45 S 552.20W 671.3 671.4 239.2 343.85 S 576.72W 699.8 699.9 239.2 358.38 S 601.22W 728.0 728.2 239.2 372.79 S 625.51W 756.1 756.3 239.2 387.10 S 649.68W 3450.0 33.63 239.16 1.22 3244.2 3156.2 784.0 784.2 239.2 401.37 S 673.68W gyro/data A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. C LOS U i~fl~l~r¢~ HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 3500.0 33.90 238.88 0.63 3285.7 3197.7 811.8 3550.0 35.05 238.74 2.30 3327.0 3239.0 840.1 3600.0 35.07 238.54 0.23 3367.9 3279.9 868.8 3650.0 35.07 238.40 0.16 3408.8 3320.8 897.5 812.0 239.2 415.67 S 697.50W 840.3 239.2 430.33 S 721.71W 869.0 239.2 445.28 S 746.24W 897.7 239.2 460.30 S 770.73W 3700.0 34.71 238.14 0.77 3449.8 3361.8 926.1 3750.0 34.41 237.96 0.63 3491.0 3403.0 954.5 3800.0 34.38 237.81 0.18 3532.3 3444.3 982.7 3850.0 34.11 237.75 0.54 3573.6 3485.6 1010.8 3900.0 33.85 237.64 0.53 3615.0 3527.0 1038.7 926.3 239.1 475.34 S 795.05W 954.7 239.1 490.35 S 819.12W 982.9 239.1 505.37 S 843.04W 1011.0 239.0 520.37 S 866.85W 1039.0 239.0 535.30 S 890.47W 3950.0 34.10 238.10 0.71 3656.5 3568.5 1066.6 4000.0 35.09 240.21 3.12 3697.7 3609.7 1095.0 4050.0 35.15 240.56 0.42 3738.6 3650.6 1123.8 4100.0 34.81 240.08 0.86 3779.5 3691.5 1152.4 4150.0 34.49 240.21 0.66 3820.7 3732.7 1180.9 1066.9 239.0 550.17 S 914.13W 1095.3 239.0 564.72 S 938.50W 1124.1 239.0 578.93 S 963.51W 1152.7 239.0 593.12 S 988.41W 1181.1 239.1 607.28 S 1013.07W 4200.0 34.10 240.16 0.78 3862.0 3774.0 1209.0 4250.0 34.08 239.91 0.29 3903.4 3815.4 1237.1 4300.0 34.28 239.13 0.97 3944.7 3856.7 1265.2 4350.0 34.05 238.89 0.53 3986.1 3898.1 1293.2 4400.0 34.29 238.73 0.52 4027.5 3939.5 1321.3 1209.3 239.1 621.29 S 1037.52W 1237.3 239.1 635.28 S 1061.79W 1265.4 239.1 649.53 S 1086.00W 1293.5 239.1 663.99 S 1110.07W 1321.6 239.1 678.53 S 1134.09W 4450.0 34.04 238.36 0.66 4068.9 3980.9 1349.4 4500.0 34.27 238.12 0.54 4110.2 4022.2 1377.4 4550.0 34.39 237.81 0.43 4151.5 4063.5 1405.6 4600.0 34.47 237.73 0.17 4192.8 4104.8 1433.8 4650.0 34.72 238.04 0.61 4233.9 4145.9 1462.2 1349.7 239.1 693.18 S 1158.05W 1377.7 239.1 707.96 S 1181.91W 1405.9 239.1 722.91S 1205.82W 1434.2 239.0 737.99 S 1229.73W 1462.6 239.0 753.08 S 1253.78W 4700.0 34.87 241.36 3.80 4275.0 4187.0 1490.7 1491.1 239.0 767.47 S 1278.41W A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. RECEIVED 1 0 200 CLOSUR~i.a~ HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 4750.0 34.87 241.78 0.48 4316.0 4228.0 4800.0 35.05 241.73 0.37 4357.0 4269.0 4850.0 34.75 241.89 0.63 4398.0 4310.0 4900.0 35.03 241.67 0.62 4439.0 4351.0 1519.3 1519.6 239.1 781.08 S 1303.54W 1547.9 1548.3 239.1 794.64 S 1328.78 W 1576.5 1576.8 239.2 808.15 S 1353.99W 1605.1 1605.4 239.2 821.67 S 1379.19W 4950.0 34.87 241.80 0.35 5000.0 34.84 241.59 0.25 5050.0 35.20 241.85 0.78 5100.0 35.01 241.60 0.48 51 50.0 34.96 241.43 0.22 4480.0 4521.0 4562.0 4602.9 4643.8 4392.0 4433.0 4474.0 4514.9 4555.8 1633.8 1634.0 239.3 835.23 S 1404.42W 1662.3 1662.6 239.3 848.78 S 1429.58W 1691.0 1691.2 239.3 862.38 S 1454.85W 1719.8 1720.0 239.4 876.00 S 1480.17W 1748.4 1748.6 239.4 889.68 S 1505.37W 5200.0 34.95 241.75 0.37 5250.0 35.02 241.35 0.48 5300.0 35.46 241.44 0.88 5350.0 34.90 241.08 1.20 5400.0 34.95 241.45 0.43 5450.0 34.73 241.16 0.54 '5500.0 34.44 241.27 0.58 5550.0 34.67 241.04 0.52 5600.0 34.41 241.24 0.55 5650.0 34.63 241.02 0.50 4684.8 4725.8 4766.6 4807.5 4848.5 4889.5 4930.7 4971.9 5013.1 5054.2 4596.8 4637.8 4678.6 4719.5 4760.5 4801.5 4842.7 4883.9 4925.1 4966.2 1777.1 1777.2 239.5 903.30 S 1530.56W 1805.7 1805.9 239.5 916.96 S 1555.77W 1834.6 1834.7 239.5 930.77 S 1581.10W 1863.4 1863.5 239.5 944.63 S 1606.36W 1892.0 1892.1 239.6 958.39 S 1631.45W 1920.5 1920.7 239.6 972.10 S 1656.51W 1948.9 1949.0 239.6 985.77 S 1681.38W 1977.3 1977.4 239.6 999.45 S 1706.22W 2005.6 2005.7 239.7 1013.13 S 1731.05W 2033.9 2034.1 239.7 1026.82 S 1755.87W 5700.0 34.50 240.96 0.26 5750.0 34.14 240.86 0.73 5800.0 33.93 240.74 0.45 5850.0 33.37 241.09 1.18 5900.0 32.91 241.33 0.95 5095.4 5136.7 5178.2 5219.8 5261.6 5007.4 5048.7 5090.2 5131.8 5173.6 2062.3 2062.4 239.7 1040.57 S 1780.67W 2090.5 2090.6 239.7 1054.28 S 1805.31W 2118.5 2118.6 239.7 1067.93 S 1829.74W 2146.2 2146.3 239.7 1081.40 S 1853.95W 2173.5 2173.6 239.8 1094.56 S 1877.90W 5950.0 32.63 240.64 0.92 5303.7 5215.7 2200.6 2200.7 239.8 1107.69 S 1901.57W gyro/data A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER u'NIT, ALASKA Job Humber: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 6000.0 32.57 240.75 0.18 6050.0 32.63 240.63 0.18 61 O0.0 32.34 240.46 0.60 6150.0 32.37 239.87 0.64 5345.8 5387.9 5430.1 5472.3 5257.8 5299.9 5342.1 5384.3 -,.ii lO 200 . ~a Oil &Gas Ceas. Com~ Anchoral~ CLOSURE HORIZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 2227.5 2227.6 239.8 1120.87 S 1925.06W 2254.5 2254.5 239.8 1134.06 S 1948.55W 2281.3 2281.4 239.8 1147.26 S 1971.93W 2308.1 2308.1 239.8 1160.58 S 1995.15W 6200.0 31.49 239.69 1.78 6250.0 31.20 239.83 0.60 6300.0 26.23 239.86 9.93 6350.0 25.34 239.83 1.78 6400.0 25.62 239.49 0.63 5514.8 5557.5 5601.3 5646.3 5691.5 5426.8 5469.5 5513.3 5558.3 56O3.5 2334.5 2334.6 239.8 1173.89 S 2018.00W 2360.5 2360.6 239.8 1186.98 S 2040.47W 2384.5 2384.6 239.8 1199.05 S 2061.23W 2406.3 2406.4 239.8 1209.98 S 2080.04W 2427.8 2427.9 239.8 1220.84 S 2098.61W 6450.0 25.66 240.27 0.68 6500.0 22.27 238.45 6.92 6550.0 20.21 236.37 4.39 6600.0 20.13 236.17 0.21 6650.0 19.93 236.15 0.41 5736.5 5782.2 5828.8 5875.8 5922.7 5648.5 5694.2 5740.8 5787.8 5834.7 6700.0 19.23 236.59 1.43 5969.9 5881.9 6750.0 18.79 233.77 2.03 6017.1 5929.1 6800.0 25.82 214.11 20.32 6063.4 5975.4 6850.0 34.59 192.69 27.56 6106.7 6018.7 6900.0 31.96 188.29 7.14 6148.5 6060.5 2449.4 2449.5 239.8 1231.70 S 2117.32W 2469.7 2469.8 239.8 1242.03 S 2134.80W 2487.8 2487.9 239.8 1251.77 S 2150.07W 2505.0 2505.1 239.8 1261.34 S 2164.41W 2522.1 2522.2 239.7 1270.88 S 2178.64W 2538.8 2538.9 239.7 1280.16 S 2192.59W 2555.0 2555.2 239.7 1289.45 S 2205.95W 2572.9 2573.1 239.6 1303.26 S 2218.59W 2592.3 2592.7 239.2 1326.24 S 2227.86W 2610.0 2610.9 238.8 1353.19 S 2232.88W 6950.0 34.88 182.98 8.27 6190.3 7000.0 32.86 184.26 4.29 6231.8 7050.0 28.05 190.90 11.72 6274.9 7080.0 25.72 193.53 8.73 6301.6 7100.0 25.09 193.37 3.16 6319.7 6102.3 6143.8 6186.9 6213.6 6231.7 2625.9 2627.5 238.3 1380.57 S 2235.54W 2641.2 2643.7 237.8 1408.38 S 2237.29W 2656.4 2659.8 237.4 1433.48 S 2240.52W 2665.5 2669.4 237.2 1446.74 S 2243.38W 2671.4 2675.6 237.1 1455.08 S 2245.37W 7150.0 21.53 193.95 7.13 6365.6 6277.6 2684.9 2690.0 236.8 1474.31 S 2250.04W gyro/data A Gyrodata Directional Survey Arco/klaska Inc. Well: 1G~17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536 MEASURED I N C L AZIMUTH DOGLEG VERTICAL SUBSEA VERTICAL DEPTH SEVERITY DEPTH DEPTH SECTION feet deg. deg. deg./ feet feet feet 100 ft. 7200.0 18.79 194.19 5.48 6412.5 7250.0 16.55 195.18 4.52 6460.2 7283.0 14.42 195.55 6.47 6492.0 6324.5 6372.2 6404.0 2696.9 2707.5 2713.7 Final Station Closure: Distance: 2720.70 ft Az: 236.18 deg. CLOSURE DIST. AZIMUTH feet deg. 2702.7 236.5 2714.0 236.3 2720.7 236.2 HORIZONTAL COORDINATES feet 1491.03 S 1505.71 S 1514.21 S 2254.23 W 2258.07W 2260.40W RECEIVED ~ .,t~ 1 0 2000 AIm~ka Oil & G~s Cons. Anc~or~je gym/data A Gyrodata Directional Survey Job Number: AK1299GCE536SS Run Bate: 12/3/99 2:30:00 PM Surveyor: Tom Stoddard for Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.330000 deg. N Sub-sea Correction from Vertical Reference: Azimuth Correction: Gyro: Bearings are Relative to True North 88.00 ft. Proposed Well Direction: 240.290 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference RECEIVED ~Jaska ~ & 6as C,~s. Com~ A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location: DRILLSlTE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536SS SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. -88.0 0.00 0.00 0.00 0.0 0.0 12.0 0.29 89.35 0.29 100.0 -0.2 11 2.0 0.42 120.00 0.23 200.0 -0.6 212.0 0.34 92.66 0.19 300.0 -1.1 312.0 0.45 94.01 0.11 400.0 -1.6 RECEIVED ,,i 1 0 2000 L. ~ i ",~ ~ Ala~a 0ii & Gas Cees. Commi~on CLOSURE AIi~ho~IZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 0.0 0.0 0.00 N 0.00 E 0.3 89.3 0.00 N 0.25 E 0.8 102.2 O. 18 S 0.82 E 1.5 104.6 0.37 S 1.43 E 2.2 101.1 0.41 S 2.12 E 412.0 0.54 106.56 0.14 500.0 -2.3 51 2.0 0.54 108.15 0.02 600.0 -2.9 612.0 0.54 110.71 0.02 700.0 -3.5 712.0 0.49 109.97 0.05 800.0 -4.1 812.0 0.47 111.51 0.02 900.0 -4.7 3.0 101.0 0.58 S 2.96 E 4.0 102.5 0.86 S 3.86 E 4.9 103.8 1.17 S 4.75 E 5.8 104.8 1.48 S 5.59 E 6.6 105.6 1.78 S 6.37 E 91 2.0 0.49 108.43 0.03 1000.0 -5.2 1012.0 0.53 110.24 0.05 1100.0 -5.8 111 2.0 0.53 87.23 0.21 1200.0 -6.5 1212.0 0.61 116.18 0.29 1300.0 -7.2 131 2.0 0.68 122.83 0.11 1400.0 -7.8 141 1.9 1.00 166.60 0.69 1499.9 -7.8 151 1.8 3.90 218.39 3.38 1599.8 -4.4 161 1.1 9.66 232.93 5.96 1699.1 7.1 1709.6 10.16 235.92 0.72 1797.6 24.2 1807.4 13.70 238.08 3.57 1895.4 44.8 7.5 106.1 2.06 S 7.16 E 8.3 106.4 2.36 S 8.00 E 9.2 105.7 2.50 S 8.90 E 10.2 105.4 2,71 S 9.83 E 11.3 106.8 3.27 S 10.81 E 12.3 111.1 4.43 S 11.51 E 12.5 129.6 7.94 S 9.60 E 15.7 177.1 15.67 S 0.78 E 28.9 207.2 25.67 S 13.21W 47.9 219.7 36.88 S 30.57W 1855.8 15.37 239.28 3.39 1943.8 57.4 1904.0 16.15 240.15 1.62 1992.0 71.0 1951.9 16.84 241.01 1.47 2039.9 85.2 1999.7 17.52 241.29 1.36 2087.7 99.9 2047.2 18.98 241.43 2.92 2135.2 115.6 59.9 223.6 43.39 S 41.30W 73.0 226.5 50.24 S 53.03W 86.9 228.8 57.21 S 65.40W 101.4 230.6 64.34 S 78.33W 116.8 232.0 71.84 S 92.07W 2094.3 20.22 241.56 2.47 2182.3 132.3 133.4 233.2 79.84 S 106.81W A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TI3G Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536SS SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. Alaska Oil & Gas C, eas. CLOSURE ~ZONTAL DIST. AZIMUTH COORDINATES feet deg. feet 2140.9 22.04 242.43 3.71 2187.0 23.27 242.60 2.46 2232.7 24.67 242.68 2.79 2278.1 25.17 242.77 1.00 2228.9 2275.0 2320.7 2366.1 150.4 169.6 189.9 210.9 151.2 234.3 88.30 S 122.73W 170.3 235.2 97.19 S 139.81W 190.4 236.0 106.53 S 157.85W 211.4 236.7 116.18 S 176.58W 2323.3 25.37 241.86 0.87 2368.2 26.78 238.89 3.85 2412.2 29.81 238.62 6.05 2455.3 31.27 239.15 2.98 2497.4 33.84 239.85 5.19 2411.3 2456.2 2500.2 2543.3 2585.4 232.3 254.2 277.9 3O3.3 330.2 232.6 237.2 126.10 S 195.47W 254.6 237.4 136.97 S 214.57W 278.2 237.6 149.26 S 234.83W 303.6 237.7 162.39 S 256.58W 330.5 237.8 176.04 S 279.76W 2538.6 35.26 240.31 2.90 2579.3 35.77 241.12 1.39 2619.9 35.71 241.13 0.13 2660.6 35.10 240.99 1.23 2701.6 35.01 241.08 0.21 2626.6 2667.3 27O7.9 2748.6 2789.6 358.6 387.6 416.8 445.8 474.5 358.9 238.0 190.18 S 304.34W 387.9 238.2 204.39 S 329.67W 417.1 238.4 218.49 S 355.25W 446.0 238.6 232.51 S 380.60W 474.7 238.7 246.42 S 405.73W 2742.6 34.51 240.78 1.06 2783.9 34.34 240.69 0.34 2825.2 34.08 240.42 0.61 2866.8 33.58 240.23 1.01 2908.4 33.58 240.14 0.09 2830.6 2871.9 2913.2 2954.8 2996.4 503.0 531.3 559.4 587.2 614.9 503.2 238.9 260.27 S 430.64W 531.4 239.0 274.08 S 455.30W 559.5 239.0 287.90 S 479.78W 587.4 239.1 301.68 S 503.97W 615.0 239.1 315.43 S 527.97W 2949.8 34.54 239.77 1.96 2991.0 34.78 239.39 0.64 3032.1 34.67 239.28 0.24 3073.3 34.13 239.36 1.09 3114.7 34.23 239.37 0.21 3O37.8 3079.0 3120.1 3161.3 3202.7 642.9 671.3 699.8 728.0 756.1 643.0 239.2 329.45 S 552.20W 671.4 239.2 343.85 S 576.72W 699.9 239.2 358.38 S 601.22W 728.2 239.2 372.79 S 625.51W 756.3 239.2 387.10 S 649.68W 3156.2 33.63 239.16 1.22 3244.2 784.0 784.2 239.2 401.37 S 673.68W gyro, , ,ata __ A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location' DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536SS SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. · c osuR DIST. AZIMUTH ¢~~I~)INATES feet deg. feet 3197.7 33.90 238.88 0.63 3285.7 811.8 3239.0 35.05 238.74 2.30 3327.0 840.1 3279.9 35.07 238.54 0.23 3367.9 868.8 3320.8 35.07 238.40 O. 16 3408.8 897.5 3361.8 34.71 238.14 0.77 3449.8 926.1 3403.0 34.41 237.96 0.63 3491.0 954.5 3444.3 34.38 237.81 0.18 3532.3 982.7 3485.6 34,11 237.75 0.54 3573.6 1010,8 3527.0 33.85 237,64 0.53 3615.0 1038.7 3568.5 34.10 238.10 0.71 3656.5 1066.6 3609.7 35.09 240.21 3.12 3697,7 1095.0 3650.6 35.15 240.56 0.42 3738.6 1123.8 3691.5 34.81 240.08 0.86 3779.5 1152.4 3732.7 34.49 240.21 0.66 3820.7 1180.9 3774.0 34.10 240.16 0.78 3862.0 1209.0 3815.4 34.08 239.91 0.29 3903.4 1237.1 3856.7 34.28 239.13 0.97 3944.7 1265.2 3898.1 34.05 238.89 0.53 3986.1 1293.2 3939.5 34.29 238.73 0.52 4027.5 1321.3 3980.9 34.04 238.36 0.66 4068.9 1349.4 4022.2 34.27 238.12 0.54 4110.2 1377.4 4063.5 34.39 237.81 0.43 4151.5 1405.6 4104.8 34.47 237.73 O. 17 4192.8 1433.8 4145.9 34.72 238.04 0.61 4233.9 1462.2 4187.0 34.87 241.36 3.80 4275.0 1490.7 812.0 239.2 415.67 S 697.50W 840.3 239.2 430.33 S 721.71 W 869.0 239.2 445.28 S , 746.24 W: 897.7 239.2 460.30 S 770.73W 926.3 239.1 475.34 S 795.05W 954.7 239.1 490.35 S 819.12W 982.9 239.1 505.37 S 843.04W 1011.0 239.0 520.37 S 866.85W 1039,0 239.0 535.30 S 890.47W 1066.9 239.0 550.17 S 914.13W 1095.3 239.0 564,72 S 938.50W 1124.1 239.0 578.93 S 963.51W 1152.7 239.0 593.12 S 988.41W 1181.1 239.1 607.28 S 1013.07W 1209.3 239.1 621.29 S 1037.52W 1237.3 239.1 635.28 S 1061.79W 1265.4 239.1 649.53 S 1086.00W 1293.5 239.1 663.99 S 1110.07W 1321.6 239.1 678.53 S 1134.09 W 1349.7 239.1 693.18 S 1158.05W 1377.7 239.1 707.96 S 1181.91W 1405.9 239.1 722.91 S 1205.82W 1434.2 239.0 737.99 S 1229.73 W 1462.6 239.0 753.08 S 1253.78W 1491.1 239.0 767.47 S 1278.41W gyro/data A Gyrodata Directional Survey Arco Alaska Inc. Well: 1 G-17, 3.5"TBG Location: DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536SS SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. C LO S U R E AJtllka Oil & G~ ¢~lN~i~fl~ DIST. AZIMUTH ,'l~(ll~l~ RD INATES feet deg. feet 4228.0 34.87 241.78 0.48 4316.0 1519.3 4269.0 35.05 241.73 0.37 4357.0 1547.9 4310.0 34.75 241.89 0.63 4398.0 1576.5 4351.0 35.03 241.67 0.62 4439.0 1605.1 1519.6 239.1 781.08 S 1303.54W 1548.3 239.1 794.64 S 1328.78W 1576.8 239.2 808.15 S 1353.99 W 1605.4 239.2 821.67 S 1379.19W 4392.0 34.87 241.80 0.35 4480.0 1633.8 4433.0 34.84 241.59 0.25 4521.0 1662.3 4474.0 35.20 241.85 0.78 4562.0 1691.0 4514.9 35.01 241.60 0.48 4602.9 1719.8 4555.8 34.96 241.43 0.22 4643.8 1748.4 1634.0 239.3 835.23 S 1404.42 W 1662.6 239.3 848.78 S 1429.58W 1691.2 239.3 862.38 S 1454.85W 1720.0 239.4 876.00 S 1480.17W 1748.6 239.4 889.68 S 1505.37 W 4596.8 34.95 241.75 0.37 4684.8 1777.1 4637.8 35.02 241.35 0.48 4725.8 1805.7 4678.6 35.46 241.44 0.88 4766.6 1834.6 4719.5 34.90 241.08 1.20 4807.5 1863.4 4760.5 34.95 241.45 0.43 4848.5 1892.0 1777.2 239.5 903.30 S 1530.56W 1805.9 239.5 916.96 S 1555.77W 1834.7 239.5 930.77 S 1581.10W 1863.5 239.5 944.63 S 1606.36 W 1892.1 239.6 958.39 S 1631.45W 4801.5 34.73 241.16 0.54 4889.5 1920.5 4842.7 34.44 241.27 0.58 4930.7 1948.9 4883.9 34.67 241.04 0.52 4971.9 1977.3 4925.1 34.41 241.24 0.55 5013.1 2005.6 4966.2 34.63 241.02 0.50 5054.2 2033.9 1920.7 239.6 972.10 S 1656.51W 1949.0 239.6 985.77 S 1681.38W 1977.4 239.6 999.45 S 1706.22 W 2005.7 239.7 1013.13 S 1731.05W 2034.1 239.7 1026.82 S 1755.87W 500 7.4 34.50 240.96 0.26 5095.4 2062.3 5048.7 34.14 240.86 0.73 5136.7 2090.5 5090.2 33.93 240.74 0.45 5178.2 2118.5 5131.8 33.37 241.09 1.18 5219.8 2146.2 5173.6 32.91 241.33 0.95 5261.6 2173.5 2062.4 239.7 1040.57 S 1780.67W 2090.6 239.7 1054.28 S 1805.31W 2118.6 239.7 1067.93 S 1829.74W 2146.3 239.7 1081.40 S 1853.95W 2173.6 239.8 1094.56 S 1877.90W 5215.7 32.63 240.64 0.92 5303.7 2200.6 2200.7 239.8 1107.69 S 1901.57W A Gyrodata Directional Survey Arco Alaska Inc. Well: 1G-17, 3.5"TBG Location' DRILLSITE 1G, KUPARUK RIVER UNIT, ALASKA Job Number: AK1299GCE536SS SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. .. '10 ZOO0 Alaska 011 & Gas C s. Coa H~I~31~AL COORDINATES feet 5257.8 32.57 240.75 0.18 5345.8 2227.5 5299.9 32.63 240.63 0.18 5387.9 2254.5 5342.1 32.34 240.46 0.60 5430.1 2281.3 5384.3 32.37 239.87 0.64 5472.3 2308.1 2227.6 239.8 2254.5 239.8 2281.4 239.8 2308.1 239.8 1120.87 S 1925.06 W 1134.06 S 1948.55W 1147.26 S 1971.93W 1160.58 S 1995.15W 5426.8 31.49 239.69 1.78 5514.8 2334.5 5469.5 31.20 239.83 0.60 5557.5 2360.5 5513.3 26.23 239.86 9.93 5601.3 2384.5 5558.3 25.34 239.83 1.78 5646.3 2406.3 5603.5 25.62 239.49 0.63 5691.5 2427.8 2334.6 239.8 236O.6 239.8 2384.6 239.8 2406.4 239.8 2427.9 239.8 1173.89 S 2018.00W 1186.98 S 2040.47 W 1199.05 S 2061.23 W 1209.98 S 2080.04 W 1220.84 S 2098.61W 5648.5 25.66 240.27 0.68 5736.5 2449.4 5694.2 22.27 238.45 6.92 5782.2 2469.7 5740.8 20.21 236.37 4.39 5828.8 2487.8 5787.8 20.13 236.17 0.21 5875.8 2505.0 5834.7 19.93 236.15 0.41 5922.7 2522.1 5881.9 19.23 236.59 1.43 5969.9 2538.8 5929.1 18.79 233.77 2.03 6017.1 2555.0 5975.4 25.82 214.11 20.32 6063.4 2572.9 6018.7 34.59 192.69 27.56 6106.7 2592.3 6060.5 31.96 188.29 7.14 6148.5 2610.0 2449.5 239.8 2469.8 239.8 2487.9 239.8 2505.1 239.8 2522.2 239.7 2538.9 239.7 2555.2 239.7 2573.1 239.6 2592.7 239.2 2610.9 238.8 1231.70 S 2117.32W 1242.03 S 2134.80W 1251.77 S 2150.07W 1261.34 S 2164.41 W 1270.88 S 2178.64W 1280.16 S 2192.59W 1289.45 S 2205.95 W 1303.26 S 2218.59W 1326.24 S 2227.86 W 1353.19 S 2232.88 W 6102.3 34.88 182.98 8.27 6190.3 2625.9 6143.8 32.86 184.26 4.29 6231.8 2641.2 6186.9 28.05 190.90 11.72 6274.9 2656.4 6213.6 25.72 193.53 8.73 6301.6 2665.5 6231.7 25.09 193.37 3.16 6319.7 2671.4 2627.5 238.3 2643.7 237.8 2659.8 237.4 2669.4 237.2 2675.6 237.1 1380.57 S 2235.54 W 1408.38 S 2237.29 W 1433.48 S 2240.52 W 1446.74 S 2243.38 W 1455.08 S 2245.37 W 6277.6 21.53 193.95 7.13 6365.6 2684.9 2690.0 236.8 1474.31 S 2250.04W A Gyrodata Directional survey Arco/klaska inc. Well' 1G-17, 3.5"TBG Location: DRILLSITE lC, Job Number: AK1299GCE536SS sUBSEA I N C L AZIMUTH DEPTH deg. deg. feet KUPARUK R~VER ~NIT, ALASKA 194.19 6324.5 18.79 6372.2 16.55 195.18 14.42 195.55 6404.0 Distance: 2720,70 Final Station Ctosure: DOGLEG SEVERITY deg./ 100ft. VERTICAL DEPTH feet VERTICAL SEcTiON feet 2696.9 5.48 6412.5 4.52 6460.2 2707.5 6492.0 2713.7 6.47 Az: 236.18 deg. CLOSURE DIST. AZIMUTH feet deg. 2702.7 236,5 2714.0 236.3 2720.7 236.2 HoRtZONTAL cooRDiNATES feet 1491.03 S 1505.71 S 15i4.21 S 2254.23W 2258.07W 2260.40W RECEIVED ,.,:,N 1 0 2000 NaCa 0it & Gm Ceos. Commission An~lO~ 4. QUALITY CONTROL RECEIVED 2000 · qaeka Oil & Gas Co~s. Commission QUALITY CONTROL REPORT JOB NUMBER' AK1299GCE536 TOOL NUMBER' 789 MAXIMUM GYRO TEMPERATURE · 79.17 C MAXIMUM AMBIENT TEMPERATURE · 76.51 C MAXIMUM INCLINATION' 35.77 AVERAGE AZIMUTH · 236.18 WIRELINE REZERO VALUE · el REZERO ERROR/K · N/A CALIBRATION USED FOR FIELD SURVEY' 2833 CALIBRATION USED FOR FINAL SURVEY · 2833 PRE JOB MASS BALANCE OFFSET CHECK: -.80 POST JOB MASS BALANCE OFFSET CHECK1 · USED .00 CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG · OK UPON COMPLETION OF SURVEY' OK -.65 RECEIVED 2000 AI~ 011 & Gm Cons. Commi~ Ar~orage BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD SURVEY 6399 25.57 244.87 5696.6 -1191.1 -2107.5 FINAL SURVEY 6400 25.62 239.49 5691.5 -1220.8 -2098.6 FUNCTION TEST JOB NUMBER' AK1299GCE536 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1900 13.66 13.66 13.66 13.66 13.66 AZIMUTH RECEIVED 2000 M.D. ft 1 2 3 4 5 1900 237.97 237.96 238.17 238.01 238.20 5. EQUIPMENT AND CHRONOLOGICAL REPORT RECEIVED bAN 10 2000 AIl~OIJ&G~m Cons. Com~ EQUIPMENT REPORT JOB NUMBER · AK1299GCE536 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION A0084 C0154 C0188 COMPUTER POWER SUPPLY PRINTER INTERFACE A0527 A0107 A0079 A0143 BACKUP TOOL No. 795 GYRO SECTION DATA SECTION POWER SECTION A0188 C0159 C0237 WIRELINE CC~MPANY · COMPUTER POWER SUPPLY PRINTER INTERFACE SCHLUMBERGER A0433 A0228 A0029 A0036 RECBVED ,,:,iq 10 000 Gas Oons. Oommbs~ CABLE SIZE' 7/32" RUNNING GEAR 2.25" HOUSING W/WEIGHT BARS AND ECCENTRIC BAR TOTAL LENGTH OF TOOL · 26' MAXIMUM O.D.' 2.25" INCHES TOTAL WEIGHT OF TOOL · 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK1299GCE536 TUESDAY, 11/30/99 13:50 TO SLOPE/CHECK TOOLS/STAND BY/JOB THURSDAY MORNING WEDNESDAY, 12/01/99 12:00 CHECK TOOLS/STANDBY JOB TOMORROW A.M. THURSDAY, 12/02/99 06:00 06:30 08:00 09:00 09:30 14:.>0 16:15 17:30 18:30 20:30 LOAD OUT EQUIPMENT TO LOCATION ARRIVE LOCATION MU TOOL/WARM UP TOOL/PICK UP TOOL STAND BY PRESSURE TEST LUB,BAD TEST/STAND BY SURVEY 1N TO 7282 SURVEY OUT LD TOOL.RETURN TO ATLAS ARRIVE ATLAS/CHECK TOOL/PROCESS SURVEY FRIDAY, 12/03/99 06:00 07:30 17:30 17:00 18:00 TO KUPARUK SUBMIT FINAL RESULTS TO ANCJHORAGE RECHECK TOOLS FAX FINAL RESULTS TO CO REP. RECEIVED '?AN 1 0 2000 Naska 0il & Gm Cons. Commission ARCO Alaska, I c. Structure : Pad 1G Well : 1G-17A, 50-029-22945-J3 Field : Kuparuk River Unit Location : North Slope, Alaska <- Wesf (fee Date platted: 29-Oec-1999 Plot Reference ;s 1G- 17A. Coordlnotea ora in feet reference 1C-17. True Vertical Depths ere reference RKB - MSL = 88.0 ft. Brij Potnis 267-6613 --- Baker Hughes IN/EQ --- ) 2440 2400 2360 2320 2280 22¢0 2200 2160 2120 2080 2040 2000 I I I I I t t I I I I I I I I I I 1120 1160 1200 5700 58OO 5900 6000 6100 .__0 .~ 6200 6300 6400 I 6500 6600 6700 Tie-in Point Projected to TD 1700 1600 1900 2000 2100 2200 2300 2400 2500 2600 Verficol Secfion (feel) -> Azimufh 202.00 wlfh reference 0.00 N, 0.00 E from 1G-17 Projected to TD Tie-in Point RECEIVED 03 2000 1240 1280 1520 1360 1400 I 1440 V 1480 1520 1560 160o 1640 ARCO Alaska, Inc. Pad 1G 1G-17A 1G-17 KuparukRiver Unit North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ RECEIVED Your ref : 1G-17A Our ref : svy269 License : 50-029-22945-01 Date printed : 29-Dec-1999 Date created : 29-Dec-1999 Last revised : 29-Dec-1999 ~:,i'i 0 3 2000 Alas~ 0~ & C-,as Cons. Commiss~ Anchorage Field is centred on 487754.621,5948985.821,999.00000,N Structure is centred on 539782.886,5980644.645,999.00000,N Slot location is n70 21 38.404,w149 40 28.078 Slot Grid coordinates are N 5981599.480, E 540076.040 Slot local coordinates are 953.36 N 298.25 E Projection type: alaska - Zone 4, Spheroid: Clarke ~ 1866 Reference North is True North ARCO Alaska, Inc. Pad 1G,1G-17A Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth RECTANGULAR COORDINATES 6687.71 19.61 238.34 5875.34 6752.00 19.60 238.34 5935.90 6787.00 22.60 217.90 5968.59 6837.00 31.20 199.80 6013.22 6868.00 33.50 194.80 6039.41 1244.65S 2201.32W 1255.97S 2219.68W 1264.37S 2228.83W 1284.21S 2239.15W 1300.04S 2244.06W 6905.00 32.90 190.30 6070.37 6935.00 34.00 186.50 6095.41 6970.00 35.30 184.30 6124.20 7002.00 31.80 186.00 6150.86 7027.00 33.10 186.10 6171.96 1319.80S 2248.46W 1336.15S 2250.87W 1355o96S 2252.74W 1373.57S 2254.31W 1386.91S 2255.73W 7372.00 15.00 186.00 6485.70 1526.14S 2270.53W SURVEY LISTING Page 1 Your ref : 1G-17A Last revised : 29-Dec-1999 Dogleg Vert G R I D C O 0 R D S Deg/100ft Sect Easting Northing' 0.50 1978.65 537881.57 5980343.28 0.02 1996.03 537863.27 5980331.86 22.57 2007.24 537854.18 5980323.41 23.58 2029.50 537843.96 5980303.52 11.38 2046.02 537839.14 5980287.67 6.85 2065.99 537834.84 5980267.89 7.88 2082.05 537832.52 5980251.52 5.15 2101.12 537830.76 5980231.71 11.32 2118.04 537829.27 5980214.09 5.20 2130.93 537827.93 5980200.74 5.25 2265.57 537813.87 5980061.45 RECEIVED 0 2000 , laske Oil & 6as Co s. Comrr s Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 1G-17 and SSTVD from RKB - MSL = 88.0 ft. Bottom hole distance is 2735.76 on azimuth 236.09 degrees from wellhead. Vertical section is from wellhead on azimuth 202.00 degrees. Grid is alaska - Zone 4. Grid co%~rdinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Prudhoe Bay Unit Alaska State Plane ZOne 4 Kuparuk 1 G, Slot ~ G-17 ~G.~ Job NO. AKMMgOf36, Surveyed: 13 July, f999 S UR VEY REPORT 2 August, f999 ORIGINAL Your Reft API500292294500 Surface Coordinates: 5981599.48 N, 540076.04 E (70° 2f' 38.4043" N, 149° 40' 28.0784" VII) Kelly Bushing: 88.0Oft above Mean Sea Level nPi IL., I- li'~ ~ S m P~VfC dsl; Survey Reft svy8670 Sperry-Sun Drilling Services SurVey Report for 1G.17 Your Ref: API500292294500 Job No. AKMM90f36, Surveyed: 13 July, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) fit) fit) 0.00 O.000 0.000 -88.00 0.00 290.11 0.420 96.000 202.11 290.11 386,76 0.520 g8.500 298.75 386,75 477.83 0,520 110.660 389.82 477.82 568.65 0.540 100.350 480.64 568,64 748.81 0.330 112.660 660.79 748.79 837.85 0.300 1 as. 1 oo 749.83 837.83 929.87 0,320 97.080 841.85 929.85 1111,12 0.520 90.760 1023.09 1111.09 1206.27 0.570 g0.420 1118.24 1206.24 1301.06 0.550 101.400 1213.02 1301,02 1397.65 0.670 107,200 1309,61 1397.61 1494.42 0.920 161 .glo 1406.37 1494.37 1591,00 3.190 215.420 1502.89 1590.89 1687.83 9.220 235.360 1599.12 1687,12 1782.82 9.780 234.740 1692.80 1780.80 1878.70 12.860 238,510 1786.81 1874.81 1975.18 15.9E~ 240.980 1880.24 1968.24 2071.60 17.240 242.950 1972.65 2060,65 2167.47 19.790 241.410 2063.55 2151 2263,45 22.630 241.720 2153,02 2241.02 23¢::~.29 25.200 242.760 2240.62 2328.62 2646.34 33.800 23g.650 2491.53 2579.53 2741.76 35.790 241.240 2569.88 2657.88 Local Coordinates Northings Eastings (ft) fit) 0,00 N 0.00 E 0,1i S 1.08E 0.21 S 1.84 E 0.42 S 2.64 E 0.64 S 3.45 E O.g9 S 4.76 E 1.15 S 5.22 E 1.25 S 5.71 E 1.32 S 7.03 E 1.41 S 7,g3 E 1.57 S 8.84 E 1.83 S 9.84 E 2.74 S 10.62 E 5.66 S 9.30 E 12.28 S 1.35 E 21.26 S 11.50 W 31,54 S 27,25 W 43.58 S 48.00 W 56.5O S 72.31 W 70.73 S 99,22 W 87.26 S 129.76 W 105.34 S 164.14W 148.17 S 240.99 W 174.05 S 284.65 W 200.88 S 332.22 W Alaska State Plane Zone 4 Kuparuk 1G Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOoff) fit) 5981599.48 N 540076,04 E 0,(30 5981599.37 N 540077,10 E O. t45 -0,87 5981599.28 N 540077.88 E O. 106 -1.50 5~61~.07 N 540078.68 E 0.121 -2.09 5981598.86 N 54G379.49 E 0. i07 -2.68 5981598.5i N 540080.80 E 0. i27 -3.65 5981598.35 N 540081,27 E 0.057 -3.g8 5981598.26 N 540081.76 E 0.052 -4.35 5981598.20 N 540083.08 E 0.113 -5.47 ~1598,t2 N 540083,98 E 0.101 -6.21 5981597.96 N 540084.89 E 0.029 -6.92 5981597.70 N 540085.89 E 0.140 -7.66 5981596.80 N 540086.67 E 0.789 -7.90 5961~.87 N 540085.37 E 2.842 -5.31 5961587.21 N 540077.46 E 6.522 4.87 5981578.16 N 540064.65 E 0.599 20.47 5981567.80 N 540048.96 E 3.302 39.24 5981555,65 N 540028.27 E 3.265 63.24 5961542.59 N 540004.03 E 1.459 90.76 5~81528.22 N 53gg77.20 E 2.708 121.19 5961511.53 N 539946,75 E 2.961 155.90 5981493.26 N 539912.46 E 2.717 194.73 5981450.03 N 538836.85 E 2,590 282.70 5981423,91 N 539792.12 E 4.085 333.63 5981396.82 N 539744.90 E 2.292 388.07 Comment 2 August, 1999 - 13:07 .2. Continued... DrillQuest Sperry-Sun Drilling Services Survey RePort for fG~l? Your Ret: AP1~00:~2~94~00 Job No. AKMMgOf36, surVeyed: 13 july, 1999 Prudhoe Bay Unit Measured Depth Incl. Azim. fit) 2837.46 35.210 241.510 2935.18 34.540 241.710 3012.4~ 33.930 240.950 3127.75 33.390 2401850 3223.52 34. g60 240.160 331848 34.300 240.490 341 4.45 33.720 239.380 3510.57 33.620 239.5~0 3606.37 35.070 L::~J8.840 3702.61 34.590 238.810 3796.93 34.170 238.470 3893.35 33.790 237.570 4064.63 34.570 240.910 4179.63 33.990 240.520 4234.87 33.58O 240.790 438,4.11 33.860 238.050 4481.16 34.080 239.680 4673.13 34.760 239.980 4770.38 34.590 241 4864.88 34.480 241.340 4~60.38 34.490 242.170 5O56.72 34.65O 242.28O 5152.94 34.740 243.720 Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Easflngs Northings Eastlngs (ft) (ft) (ft) fit) (ft) fit) 2647.80 2735.80 227.5! S 38t .00 W 5981369.94 N 539696.26 E 272796 2815.g6 254.08 S 430. i6 W ~1343,11 N 539647.25 E 2791.88 2879.88 274.94 S 468.32 W 5981322.04 N 539609.20 E 2887.82 2975.82 306,0t S 524~t4 W 5981290.67 N 5,39553,55 E 2967.05 3055.08 332,50 S 570.96 W 5961263.93 N 539506,87 E 3045.18 3133.18 359.22 S 6t7.84 W 5961236.g6 N 539460.13 E 3124.74 3212.74 386.10 S 664.30 W 5981209.83 N 539413.82 E 3204.73 3292.73 413.19 S 7t0.19 W 5981182.50 N 539368.07 E 3283.83 3371.83 440,88 S 756.61 W 5961154,56 N 5.~t321.80 E 3362.83 3450.83 469.33 $ 803.64 W 5981125.85 N 539274.93 E 3442.32 3530.32 497.64 S 850.08 W 5961097,30 N 539228,63 E 3520.62 3608.62 525,58 S 894,84 W 5~1069.12 N 539t84,02 E 3600.71 ,3688.71 553,85 S 941.66 W 5981040.60 N 539137.35 E 3678.21 3766,21 580.28 S 988.42 W l~;61013,92 N 5,39090.73 E 3756.70 3844.70 606,45 S 1035.09 W 5980~7.50 N 539044.21 E 3802.62 3890.62 621.50 S 1061.87 W 5980972.30 N 539017,51 E 3926.75 4014.75 663.65 S 1133.18 W 5~t80929.78 N 538946.43 E 4(307.24 4095.24 691.68 S 1179.59 W 5960901.419 N 538900.17 E 4085,38 41 73.38 718.55 S 1225.23 W 5~0874.38 N 538854.67 E 4165.82 4253.82 746.44 S 1272.89 W 5980846.24 N 538807.16 E 4245.80 4333.80 773.40 S 1321.20 W 5980819.02 N 538759.00 E 4323.65 4411.65 798.95 S 1368.29 W ~;180793.22 N 538712.05 E 4402.78 44~0.78 824.67 S 1416.17 W 5980767.24 N 538664.30 E 4481.70 4589.70 850.02 S 1464.29 W 5980741.64 N 538616.32 E 4560.81 4648.81 874.88 S 1513.08 VV 5960716,52 N 538567,66 E Alaska State Plane Zone 4 Kuparuk 1G Dogleg Vertical Rate Section (°/lOOft) (~) 0.628 443.64 0.696 499.5o o.~s4 542.g9 o.471 6o6.87 1.689 660.67 o. 723 714.63 0.885 768.3o o. i35 821.58 1.567 875.61 0.499 93o.56 0.479 984.92 0.668 1037.64 1.874 1092.31 0.565 11 46.02 0.653 1199.53 0.790 1230.24 1.036 1313.06 0.965 1367.26 0.223 1420.22 0.698 1475.43 1.015 1530.75 0.240 1584.32 . 0.,490 1638.66 0.179 1693.02 0.857 1747.73 Comment 2 August, 1999- 13:07 .3. Cont/nued. . . DdllQuest Sperry. Sun Drilling Services su~ey Report fi~r' *fG'l? Yo~Ir Reft API500292294500 Job No. AKMMgof36, Surveyed: f3 july, f999 Prudhoe Bay Unit Measured Depth Incl. Azim. (ft) 5247.07 34.940 241.310 5344.~ 34.910 242.310 5440.38 34.600 241.860 5632,36 34.280 243.220 5728.67 34.1 O0 243.300 5824.80 33.320 239.980 5919.43 32.730 241.330 6015.53 32.250 240.240 6112.55 32.090 240.020 6207,73 31.250 241.130 6303.66 26.570 243.400 6399.83 25.570 244.840 6495.72 23.410 241.600 6590.63 20.060 237.830 6687.71 19.610 238.340 6755.00 19.610 238.340 Sub.Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) ,(ft) (ft) (ft) (ft) 4638.07 4726.07 899,(~ S i560,78 W 5980691.45 N ~38520,10 E 4717.91 48(35.91 926,03 S t609.92 W ~4,85 N ~538471. t0 E 4796.73 4884,73 951,63 S 1658.24 W ~.g9 N 538422.92 E 4875.72 4963.72 976.47 S 1706.52 W 5980613,89 N 538374,77 E 4955.08 5043.08 t000.7t S t 755.04 W ~,3~ N 538326.38 E 5034.75 5122.75 1025.07 S t803.38 W 5980564.78 N 538278.17 E 5114.72 5202,72 10~).39 S 1850,32 W 5~80539.21 N 53823i .37 E 5194.08 5282.06 i075.66 S 1895,27 W 5980513.69 N 538186.56 E 5275.12 5363.12 1t00.858 1940.32 W 5980488.26 N 538141.64 E 5357.25 5445.25 1126.58 S 1985.12 W 5980462.29 N 538096.~ E 5438.25 5526.25 1151.13 S 2028.64 W 5980437.51 N 538053.59 E 5522.21 5610,21 1 t 72.77 S 2069.63 W 5980415.65 N 538012.71 E 5608.59 5696.59 1191.22 S 2107.65 W I~EK)397.00 N 537974.79 E 5695.85 5783.85 t209.08 $ 2143.14W 5980378.95 N 537939.40 E 5784.01 5872.01 1226.72 S 2173.52 W ~1.14 N 537909.12 E 5875.33 5963.33 1244.14 S 2201.48 W 5980343.58 N 537881.25 E 5938.71 6026.71 1255.99 S 2220.70 W 5960331.62 N 537862.09 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska state Plane Zone 4 Kuparuk 1G Dogleg Vertical Rate Section ("/'~OOft) (ft) 1.478 1801 o.t:eg 1~57.20 0.419 1911.86 1.096 1966.12 0.312 2020.29 0.193 2074,34 2.081 2127.67 ,0.997 2i 79.24 0.788 2230.86 O.2O4 2282.51 1 .O74 2332.48 5.010 2378.82 1.230 2420.99 2.652 246O.68 3.822 2495.80 0.497 2528.71 0.000 2551.28 Comment PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 240.508° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6755.00ft., The Bottom Hole Displacement is 2551.28ft., in the Direction of 240.508° (True). 2 August, 1999 - 13:07 .4 - Continued.,. DrillQuest Sperry-Sun Drilling Services Survey R port f~r YoUr Ref: APt500202294500 JOb No, AKMM90f36, Surveyed: f3 JUly, f999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1G Comments Measured Station CoOrdinates Depth TVD Northlngs Eastings (ft) (ft) (ft) (ft) 6755.00 60'26.71 1~--~.~ S 2220.70 W comment PROJECTED sURVEY 2 August, 1999.13:07 - 6- DrlllQuest 3~2~00 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121236 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 2B-11 ~.~ ~-- INJECTION PROFILE 000225 I 1 2K-06 ] INJECTION PROFILE 000220 I 1 3K-12,~ INJECTION PROFILE 000221 I 1 1G-17 .~..c~,-/... 20083 :SCMT (GR/CCL) 991203 I I 1 DF-(-I I\it'l) SIGNEQ;~\ .,,/'\L,~. ~ 1 DATE: Alaska Oil & Gas u~.~. ~ .... " .... '~' Ar~ch0tage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 2/23/00 Schlumberger NO. 121212 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2Z-23 ~-.LX.~,(.-. WATER INJECTION PROFILE 000211 I 1 3F-20 STATIC BH P W/TEMP 000214 I 1 1G-17.F,- 20012 SCMT 991203 I r~ r rr l~lEl~ iciq,c~uq SIGNED: DATE: FEB 25 2000 Alaska Oil & Gas Co:'~s. u~.~ssion ~3ch0rage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. -Tr~ank you. ,o q Scblmberger NO. 121024 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1(~"-02" mCWSLRY ,,oe '" 991208 1 1 1F-06 bM t... PRODUCTION PROFILE W/PSP 991206 I 1 1 G-17 STATIC BOTTOM HOLE 991207 1 I ,, 2A-03 ~t ~ INACTION PROFILE W/PSP 991204 I 1 2N-345 ~L/PSP/aST 991104 I 1 .... 2X-04 ~l ~ MI INJECTION PROFILE 991201 I 1 3M-08 PRODUCTION PROFILE WIPSP 991205 I 1 ,, 3M-13 GAS LI~ SURVEY W/PSP 991201 I 1 3N-04 ~ INJECTION PROFILE w/PsP 991208 I I SIGNE DATE: " ' ' Z~ska 0i/& Gas Co~s. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. 12/15/99 ~oActive Diagnostic Services, Inc. To: ARCO Alaska, Inc. AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG DIGITAL MYLAR / ' BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR q¢~ - o ~'7._ ~-- ~ o'-7 ?_._ ~_. CD-ROM FILM BLUE LINE Open Hole I I 1 1G-17 i [ Res. Eval. CH I I 1 I Mech. CH Caliper Survey , .~,,---~¢ .... [ .~- ... I Signed ' L_j--' Dat,'"~il~b~ Oii& Gae ~1~. 2 .... ,,,~lo~, Print Name: ,~¢10f~ i999 ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, '' Phone:(907)659-2307 Fax:(907)659-2314 E-maih pdsprudhoe@NA800.net Website: www m. ~.com C:XMy Documents\Excel_Word_DocumentsxDistribution_FormsxArc°-kup-f°rm'd°c MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson, ¢~~ DATE: November 14, 1999 Chairman THRU: Blair Wondzell, ~~ SUBJECT: P. I. Supervisor FROM: John H Spaulding/~~ Petroleum Inspec~r BOP Test Nabors/DS 3S KRU well 1 G- 17 Kuparuk River Field PTD 199-62 November 14, 1999: I witnessed the BOP test on Nabors/Dowell Schlumberger rig 3S, located at ARCO's KRU well 1G-17. The AOGCC BOP Test Report is attached for reference Prior to my arrival the rig had been fishing a bottom hole assembly. I was notified of the impending test, and my presence was requested in a timely manner. Unfortunately my arrival was much to soon resulting in a long wait. Testing, once we started went quite quickly with the crew working in a very professional manner. SUMMARY: I witnessed the BOP Test on Nabors/DS rig 3S. 22 components, 0 failures, 10 hrs. (test time 3.5 hrs) Attachment: BOP NABORS/DS 3S 11-12.99js Non Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors / Schlumberger/Dowell Operator: AA/ Well Name: 'IG-'I7 Casing Size: Set @ Test: Initial Weekly X Rig No. 3S PTD # '199-62 Rep.: Rig Rep.: Location: Sec. Other DATE: 11/'14/99 Rig Ph.# 659-7~82 Andy Kirk Paul Haynes 29 T. 12N R. tOE Meridian Umiat BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 250/5000 P 250/5000 P 25~5000 P 1 1 1 25O/5OOO P 1 slip rams 1 250/5000 P 1 25O/5OOO P 2 250/5000 P 1 250/5000 P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Meth Gas Detector OK OK / H2S Gas Detector OK OK -' CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan. Pressure P/F 250/5000 P 250/5000 P P Func~oned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: ~ 2200 avg. 3,100 P 2,200 P minutes 8 sec. minutes 32 sec. X Remote: X Psig. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK Permit to drill: YES Standing Order Posted YES Well Sign YES Drl. Rig OK Hazard Sec. YES Number of Failures: 0 ,Test Time: Hours. Number of valves tested 4 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P, I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES x NO 24 HOUR NOTICE GIVEN YES x NO Waived By: Witnessed By: Form Revised 2/20197 L.G. bop n abors-ds 3s 11-14-99js 11/17/99 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1G-17, AK-MM-90136 September 16, 1999 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Yma Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1G-17: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22945-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22945-00 1 Blueline 1 Folded Sepia 1 Blueline - 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company To,- WELL LOG TRANSMITFAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 19, 1999 1G-17, AK-MM-90136 1 LDWG formatted Disc with verification//sting. API#: 50-029-22945.00 ,o, a~ AI'FENT/ON OF: "~' IALHED COPY' -'----'--'- Sperry-Sun Drilling Service Attll: JLrrl OaJv/31 5631 Silverado Way, Suite G Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535 A Halliburton Company [~ !:! I I--I_ I I~1 G 02-Aug-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1G-~ Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,755.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson, DATE: July 11, 1 999 Chairman THRU: Blair Wondzell, 6~~ FILE NO: P. I. Supervisor ea21gkgf.doc FROM: John H Spaulding,~ j SUBJECT: Petroleum Inspector~[ i~l :~ ~ Diverter Function Test Nordic 3 ARCO KRU 1G-17 PTD 99-6 2 July 11, 1999: I traveled to ARCO's Kuparuk River Unit well 1 G-1 7 to witness the Diverter Function test on Nordic rig 3. The AOGCC Diverter Function test report form is attached for reference. Initially I was contacted for the test to take place on 7/10/99 in the morning. I arrived as requested at 7 am. Don Wester ARCO Company Man informed at this time that the well program had specified a 13 5/8" annular preventer and also specified a 15" hanger. The hanger has to fit inside the annular preventer. Obviosley this was not possible. A search was made for a rental 20" preventer, one was found and installation was started. I went on to other work and returned as requested at 6 pm on 7/10/99. I inspected the annular element prior to installation of the riser and flow line. During this inspection I found several chunks of rubber were missing and informed Mr. Wester that the element would need to be replaced prior to drilling. I returned on 7/11/99 at 1 2 noon and found that the replacement was installed and the test was completed with no further delays. From all indications this appears to either be a case of inexperience in writing well programs or just cutting and pasting with the computer. In either case the drilling program was signed by ARCO management, evidently without reading what they were signing. SUMMARY: I witnessed the diverter function test on Nordic 3 with no failues. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report R, Drlg Contractor: Nordic Operator: ARCO Well Name: 10-17 Location: Sec. 29 T. 12N Date: Operation: Development Rig No. 3 PTD// Oper. Rep.: Rig Rep.: 10E Merdian Umiat X Exploratory: 99-62 Rig Ph.// Don Wester Lance Johnson 7/11/99 659-7872 MISC. INSPECTIONS: Location Gen.: ok Well Sign: yes Housekeeping: ok (Gen.) Drlg. Rig: ok Reserve Pit: na Flare Pit: na DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 16 Vent Line(s) Length: 75 Line(s) Bifurcated: na Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted / Long Radius: na in. in. ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig Pressure After Closure: 1850 psig 200 psi Attained After Closure: min. 19 sec. Systems Pressure Attained: 1 min. 41 sec. Nitrogen Bottles: 4 @ 2200 avg. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: ok ok Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok psig Rig Camp and shop about 300+ feet from the rig N~ S wind direction NOrdic 3 existing well houses motors entrance road 75'x 16" ~/ent line with full opening automatic knife valve, 100+ feet from ignition source NOn Compliance Items Remarks: RePair Items Within Day (s) And contact the Inspector @ 65~3607 Distribution orig. - Well File C- ODer/Rep c - Database c - Trip Rpt File c -Inspector AOGCC REP.: OPERATOR REP.: ea21gkgf.xls DVTRINSP.XLT (REV. 1/94) TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION June 24. 1999 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit IG-17 ARCO Alaska, Inc. Permit No: 99-62 Sur Loc: 953'FSL. 302'FWL, Sec. 29. T12N, R10E, UM Btmhole Loc. 329'FNL. 1948'FEL. Sec. 3 I, T12N, R10E. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required bx' law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular 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 are 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 the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1G must comply with the 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 the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given ector on the North Slope pager at 659-3607. D_avid .W.. Johns, ton-- C°mmlssi°ner BY ORDER OF THE COMMISSION dlf/Enclosures CC:' Department of Fish & Gmne. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 "ia.'Typeofwork: Drill [] Redrill [] I 1;~':rypeo'f'w~ll. Exploratory Bi Stratigraphio Test [--I DevelopmentOiI• Re-entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 88 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 ADL 25640 ALK 2571 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 953' FSL, 302' FWL, Sec. 29, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 236' FNL, 1785' FEL, Sec. 31, T12N, R10E, UM 1G-17 #U-630610 At total depth 9. Approximate spud date Amount 329' FNL, 1948' FEL, Sec. 31, T12N, R10E, UM June 24, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) 236' @ Target feet 1G-02 32.6' @ 900' feet 2560 7281 ' MD/6614' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 1500 MD Maximum hole angle 31.6° Maximum surface 3570 psig At total depth (TV•) 4400 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of Cement Hole Casing Wei~lht Grade Coupling Length MD -rVD MD TV• (include sta~e data) 24" 16" 62.5# R-3 Weld 22' 88' 88' 110' 110' 9 cu yds. High Early 9.875" 7.625" 29.7# L-80 BTCM 4152' 88' 88' 4240' 3938' 490 sx AS Ill L & 310 sx Class G 6.75" 5.5" 15.5¢ L-80 BTCM 6587' 88' 88' 6675' 6044' 115 sx Class G 4.75" 3.5" 9.3# L-80 EUE8RD 606' 6675' 6044' 7281' 6614' 12 sx Class G 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 Conductor Surface ,o uo, RECEIVED Liner Perforation depth: measured Alaska 0ii & Gas Cons. C0mr,qissio~ true vertical Anchorage 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Driliing program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Torn Brockway263-413~. Signed ~ ~',. ~ Title: Drilling Engineering Supervisor Date Prp_n~rp.d hv ,qh~rnn Commission Use Onl,~ Permit Ny,~_ A Plnumber [ A pprov&ldate__ .~, ~",Z.. 50-4:::).;~_~'._ ,2.,~ ,~,.~...~ ~ "" c:~.~ - P~' [Seecoverletter I for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required [] Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directionalsurvey required J~ Yes [] No Required working pressure for BOPE r-] 2M; [] ~ [] ~ [] lOMb[] [] ~t~. ~2, ~.~ Other: (::~V'l t¢~,~'-o,~-¢_._ -pS; [~11~itidl 0.,~ ;,.,j.-.~ byorderof Approved by D~,/id W Johnstorl ...... Commi..ssi.one, r the commission Date ..... Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER UNIT- PRODUCER KRU 1G-17 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up Nordic Rig 3. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/4240') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering 4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using 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. Displace cement with mud. 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. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 7. 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). 8. Drill 6-3/4" hole to intermediate casing point (+/- 6675') according to directional plan, running LWD logging equipment as needed. 9. Run and cement 5-1/2" 15.5# L-80 BTCM intermediate casing string. Adequate cement will be pumped to place cement top +\- 500' above the casing shoe. Displace cement with mud. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 10. Pressure test casing to 3,500 psi for 30 minutes per AOGCC regulations. Record results. 11. Freeze protect well. Nipple down BOP stack and nipple up 7-1/16" full opening master valve. Pressure master valve. 12. Secure well. Release rig. 13. Move in / rig up Nabors 3S/CTU #4 coil tubing drilling rig. 14. Nipple up BOPE above 7-1/16" master valve. Pressure test BOPE to 5000 psi. Record results. 15. Drill out intermediate casing shoe 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). 16. Drill 4-3/4" hole to well TD (+/- 7281') according to directional plan. MAD pass with open hole memory logging equipment as needed. 1 Go17 TAB, 6/16/99, v2 Note: Dynamically overbalanced drilling techniques will be employed for the coiled tubing drilling portion of this well to address expected high reservoir pressures through the Kuparuk sands. This procedure has been successfully employed on previous Kuparuk CTD wells. Current plans are to use +/- 10ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for requlating surface pressure will be installed between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke. At least two times the hole volume of kill weight fluid will be on location as a contingency. Frequent monitoring and rolling of the kill weight fluid will be done to ensure proper weight distribution. 17. Run and cement 3-1/2" 9.3# L-80 EUE8RD liner with Baker SABL-3 permanent packer assembly. Hydraulically set packer +150' inside intermediate casing shoe to provide appropriate liner lap. 18. Pressure test liner to 3500 psi. 19. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 20. Freeze protect well. Pull landing joint. Install BPV. Nipple down BOP stack and master valve and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. 21. Shut in and secure well. 22. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 1G-17 TAB, 6/16/99, v2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1G-17 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Nordic Rig 3 Spud to 7-5/8" surface casin~ 8.5-10.0 16-26 25-50 150-250* 10-20 10-30 8-15 8-10 4-6% Nordic Rig 3 Drill out to 5-1/2" intermediate casin~ 8.8-10.5 4-8 5-8 35-40 2-4 4-8 8-15 9.5-10 4-7% Nabors 3S/CTU #4 Drill out to TD +/- 10.0 7-9 20-25 50k (LSRV) 9-13 22-25 5-8 8.5-9 0-1% Drilling Fluid System: Nordic Riq 3 Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Flow Line Cleaner Nabors 3S/CTU #4 Shale shakers Degasser Pit Level Indicator (Visual / Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices from spud through intermediate casing TD will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Coil tubing drill out through the production interval will employ dynamically overbalanced drilling techniques as noted in the attached drill and complete procedure. Maximum Anticipated Surface Pressure: In the surface hole section, maximum anticipated surface pressure is calculated using an expected surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2764 psi. Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3938 ft)(0.70 - 0.11) = 2323 psi In the intermediate hole section, maximum anticipated surface pressure is calculated using an expected intermediate casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 4246 psi. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. MASP = (6050 ft)(0.70 - 0.11) = 3570 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 1G -17 target location are expected to be -4400 psi (0.72 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 14.4 ppg would be predicted as the maximum mud weight needed to safely drill in this formation using conventional drilling methods, assuming a TVD of 6098'. ARCO Alaska, Inc. will perform a coil tubing drill out through the Kuparuk sands and will employ dynamically overbalanced drilling techniques to maintain a bottom hole pressure of 14.4 ppg EMW. BOP equipment for this drill out operation will be tested to 5000 psi. Well Proximity Risks: The nearest existing well to 1G-17 is 1G-02. As designed, the minimum distance between the two wells would be 32.6' at 900' MD. Drilling Area Risks: Risks in the 16-17 drilling area include high pressures in the Kuparuk C sands, lost circulation and potential borehole instability in and below the permafrost formation. High Kuparuk formation pressures will be addressed by setting intermediate casing above the Kuparuk C sands and drilling out with a coiled tubing drilling rig using dynamically overbalanced drilling techniques to control formation influx. Lost circulation and borehole instability will be addressed with lost circulation material (LCM), high viscosity spud mud, and reduced circulating rates as needed. Based on previous DS 1G drilling results, 10 ppg mud should be adequate to control formation pressures from spud through intermediate hole TD without resulting in lost circulation. The 7-5/8" casing shoe will be tested to leak off or a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on 1G 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 1G-17 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 1G-17 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 200' vertically below the base of the West Sak into the head 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 Max Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052)* (3938') + 1,500 psi = 3957 psi 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 BTCM 4,790 psi NA 6,890 psi 5,856 psi 5-1/2" 15.5 L-80 !3 BTCM !4,990 psi 4,242 psi 7,000 psi 5,950 psi 3-1/2" *9.3 L-80 12 8rd EUE Mod ~10,530 psi 8,951 psi 10,160 psi 18,GSG psi * if needed 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). an~re,, For: BROCKWAY] Dote plotted: ~O~un-~ggg Plot Re~e~nae i~ RKB ELEVATION: 0.00 ARCO Alaska,. ,nc. Struafure: Pad 1G Well : F~eld: Kuparuk RNer UnH Looaflon: North Slope, A aaka 4OO 800 1200 1600 2000 24OO ¢- 2800 -i-- 3200 ~ 5600 $ 4000 44OO 4800 5200 5600 6000 6400 6800 240.29 AZIMUTH 2398' (TO TARGET) ***Plane of Proposal*** <- West (feet) 2500 2250 2000 1750 1500 1250 1000 750 500 250 0 250 I I I I I I I I I I I I I I I I I I I I I I 250 TARGET LOCATION: 236' FNL, 1785' FEL SEC. 51, T12N, RIOE TD LOCATION: I ~'~ '~ 329' FNL, 1948' FEE SEC. 31, T12N, RIOE SURFACE LOCATION: 953' FSL, 302' FWL SEC. 29, T12N, RIOE KOP 3.00 6.00 9.00 DLS: 3.00 deg per 100 f[ 12.00 15.00 18.00 ~ 21.00 ~ 24.00 ". 27.00 30.00 ~oc ~ M~IMUM ANGLE 31.57 DEG ~ Base Wes~ Sok ~KOP 1500,00 0.~ 240.2g 1~,~ 0.00 0,00 ~ [EOC 2552~8 51.57 240.29 2499,~ -~,09 -245.47 ~ 7 5/8 Csg Pt IBestBese West S~k ~05.49 51~7 2~.29 37~00 -5,7.17 -g06.~ C90 [75/'8 Csg ~ ~2~25 51~7 240.29 39~00 -578.08 -1012.95 ~ [C90 ~275.~ 51~7 240.29 39~ -587.~ -1028.96 ~ [CBO(KIO) / Comp SS 497539 51~7 240.29 4~.00 -768.43 -1545.49 ~ [C50 5678.00 51~7 240.29 51~.00 -951.16 -1666.69 ~ [C~(KS) 5756.03 51~7 240.29 ~.00 -974.01 -1706.71 ~ [Begin ~gle O~ 6155.~ 5~7 240.29 ~1.35 -1069.44 -1875.94 ~ C80(K10) / Comp SS[C20 (HRZ ~d-Pt) 6~7.41 20.98 240.29 ~.~ -1146.09 -20~.e4 ~ (EOC / Bo~ HRZ / Top 6519.~ 20.OO ~40.29 ~98.00 -1152.44 -2019.58 ~ [K-1 Me.er / Top L 66~7.14 20.00 240.29 ~18.00 -1174.09 -2057.51 ~ [Ro[o~ TO / 5 ~/2 C 667~1 20.00 Z~.29 ~.00 --1178.78 -2065.53 ~ [1~-17 Top ~ 6/9/99 673227 20.00 240.29 ~.~ -I1aa.52 -20~.60 ~ ~Top Ct 6~935 20.00 240.29 ~.00 -1208.37 -2117.37 ~ ~ ~Top B ~ole ~70.61 20.00 240.29 ~.O0 -12~ ~.97 -2123.69 ~ --~ ..... ~Top A(4) 6998,52 20.00 240.29 ~,00 -1255.62 -2161.65 ~ ~U[~O) ~To~ A(5) 7055,56 20.00 Z40.29 ~,00 -1239.9~ -2172.69 ~ [~p;I ~ / 3 1/2 Cse 7281.52 20.00 24029 6615.9% -~281.60 -~45.69 Begi~ngle' Drop ~ 30 O0 ............... ~ 2).oo DL~ 5.00 ~g per 100 ft 24.00 ~ . . . C20 (HRZ M~d EOC / Bos/H~Z / Top U. ~lub[k ~, - Roterv ~D / 5 1/2 Csq Pt ~ K-1 M~rker / Top L. Kolu~ik , ,,~,z ,~ / ¢ '/= ~ov ' ' *~ 10-17 Top C4 6/9/99 Top Cl % Top B Shale Top A(4) (~ Top A(3) TARGET ANGLE Coil TD / 5 1/2 Csg ~ ~0.00 DEG 25O 500 0 C- 750 1000 --~_ I 125o V 1500 1750 2000 V. Sect Oecj/lO0 0.00 0.00 282.63 5.00 1043.41 0.00 1166.30 0.00 1184..750.00 1550..5.5 0.00 191g.00 0.00 1 g 65.08 0.00 2157.65 0.00 2.315.885.00 2525.08 5.00 2568.76 0.00 2378~_.20.00 2397.87 0.00 24-57.910.00 2445.19 0.00 2488,87 0,00 2501 ,§10.00 25B5.66 0.00 i i i i i i ! f i, J ! i I i ~ 0 400 800 1200 1600 2000 2400 2800 VerHcol Section (feet) -> Azimuth 240.29 with reference 0,00 S, 0.00 E from slot #17 Crent=d by endrew= For: BI~OCKWA¥ Dote p~otted: ~o-Jun-1999 P~ot Ref=r=nc¢ ]= 17 v=r=~on #5. Co~rdinotee ere in feet reference slot True Vertical Depths ere reference RKB (Nordrc III). ARCO Alaska, Inc. Structure : Pad 16 Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska 16O 120 00 40 4O O~ 80 '+- 120 0 160 I ¥ 200 240 280 320 360 400 <- West (feet) 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 I I I I 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 J I I I I I I I I 160 120 80 500 ]00 9OO 1000 20O0 1900 1800 26(0 1700 3000 3100 3200 1700 3300 3400 O0 1600 5400 1500 O0 1500 ~200 1400 1600 3600, 2300 37OO 5100 I I I I I I I I I I I I I I I I I I I I I II I I 720 680 640 600 560 520 4BO 440 400 560 520 280 240 200 160 120 80 40 0 40 80 120 <- West (fee0 40 40 (J) 0 80 120 --~ 160 I ¥ 20O 240 280 320 360 4OO crooto~ by ondre*s For: BROCKWAY Dote plotted: lO-Jun-1999 Plot Reference is 17 Version ~5. Co0rdlnote~ ~re ~n feet reference slot ~117~ true VerUcol Depth~ ore reference RKB (Nordrc Ill). ll~ITE~ ARCO Alaska, Inc. Structure : Pad 1G Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 11 O0 1000 900 800 700 600 500 400 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 I I I I I I I 200 300 4OO 4O0 500 500 600 600 % 70O ~lO0 0 800 --4- ¢00 "~ ~o 1000 I 2500 V 1100 1100 % 1200 1200 700 1300 ~00 //~ 1300 ~00 800 1400 1400 1500 ~00 1500 2600 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 400 <- West (feet) 700 ~ 800 -~- 900 0 1000 I ARCO Alaska, Inc. Pad 1G 17 slot #17 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 17 Version~U3 Our ref : prop3354 License : Date printed : lO-Jun-99 Date created : 16-Mar-99 Last revised : lO-Jun-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 21 29.028,w149 40 36.799 Slot location is n70 21 38.404,w149 40 28.078 Slot Grid coordinates are N 5981599.449, E 540076.053 Slot local coordinates are 953.35 N 298.26 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <6130-8494'>,,6,Pad 1Y PGMS <0-8325'>,,2,Pad 1Y PMSS <O-9354'>,,34,Pad 1Y PGMS <O-7840'>,,31,Pad 1Y PGMS <O-8285'>,,28,Pad 1Y PGMS <O-9187'>,,18,Pad 1Y PGMS <O-7635'>,,21,Pad 1Y PGMS <0-10010'>,,27,Pad 1Y PGMS <O-8375'>,,20,Pad 1Y PGMS <O-6665'>,,22,Pad 1Y PGMS <0-7500'>,,23,Pad 1Y PGMS <0-8050'>,,17,Pad 1Y PGMS <0-7665'>,,19,Pad 1Y PGMS <O-8865'>,,13,Pad 1Y PGMS <O-10115'>,,10,Pad 1Y PGMS <O-7426'>,,25,Pad 1Y PGMS <0-8052'>,,9,Pad 1Y MSS <7376-7890'>,,26,Pad 1Y PGMS <0-7604'>,,26A,Pad 1Y PGMS <O-6827'>,,32,Pad 1Y PGMS <O-9595'>,,30,Pad 1Y PGMS <O-7708'>,,29,Pad 1Y PGMS <O-7337'>,,1,Pad 1Y PGMS <0-8895'>,,3,Pad 1Y PGMS <O-7420'>,,4,Pad 1Y PGMS <O-7266'>,,5,Pad 1Y PGMS <O-7725'>,,11,Pad 1Y Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 4-Sep-98 8069.7 7281.3 7281.3 3-Aug-92 6929.0 7281.3 7281.3 30-Nov-98 9581.0 6503.4 6503.4 30-Nov-98 5805.2 7281.3 7281.3 30-Nov-98 3263.1 7281.3 7281.3 30-Nov-98 8083.4 7281.3 7281.3 30-Nov-98 5739.1 7281.3 7281.3 30-Nov-98 2529.8 7281.3 7281.3 30-Nov-98 9971.2 6363.9 6363.9 30-Nov-98 7819.6 7281.3 7281.3 30-Nov-98 9328.6 7281.3 7281.3 30-Nov-98 9790.6 6511.4 6511.4 30-Nov-g8 8488.8 7281.3 7281.3 30-Nov-98 10266.4 6386.1 6386.1 3-Aug-92 10470.2 6375.0 7035.6 3-Aug-92 9635.1 6900.0 7160.0 3-Aug-92 10206.5 6341.7 7200.0 3-Aug-92 10299.7 6308.3 7260.0 3-Aug-92 10299.7 6308.3 7260.0 3-Aug-92 8978.6 7281.3 7281.3 3-Aug-92 9454.0 7100.0 7100.0 3-Aug-g2 10085.5 6463.9 7280.0 3-Aug-92 7666.8 7281.3 7281.3 3-Aug-g2 3952.2 7281.3 7281.3 3-Aug-92 5461.9 7281.3 7281.3 3-Aug-92 7858.0 7281.3 7281.3 3-Aug-92 9795.6 6780.0 7180.0 PGMS <0-8470'>,,12,Pac PGMS <0-7386'>,,14,Pad 1¥ PGMS <D-8750'>,,16,Pad 1Y PGMS <0-8210'>,,7,Pad 1Y PGMS <O-6600'>,,8,Pad 1Y PGMS <0-9447'> (Depth Shifted),,15,Pad 1Y PMSS <6146-10430'>,,15A,Pad 1Y MMS <6350 - 7760'>,,lOA,Pad 1G PMSS <6390 - 7906'>,,lOA, Pad 1G PGMS <0-7970'>,,lO,Pad 1G PGMS <0-9225'>,,16,Pad 1G GMS <O-7415'>,,4,Pad 1G GMS <O-7970'>,,1,Pad 1G GMS <O-8489'>,,3,Pad 1G GMS <O-lO086'>,,5,Pad 1G PMSS <2156-2674'>,,6,Pad 1G GMS <O-9250'>,,6A,Pad 1G PGMS <0-8851'>,,7,Pad 1G PGMS <O-8715'>,,8A,Pad 1G PMSS <2232-3720'>,,8,Pad 1G PGMS <0-8360'>,,9,Pad 1G PGMS <O-8208'>,,11,Pad 1G PGMS <0-9116'>,,12,Pad 1G PGMS <O-8110'>,,13,Pad 1G PGMS <O-7950'>,,14,Pad 1G PGMS <O-7533'>,,15,Pad 1G MSS <1651-2529'>,,2,Pad 1G GMS <0-9754'>,,2A,Pad 1G 3-Aug-92 3-Aug-92 3-Aug-92 3-Aug-92 3-Aug-92 16-0ct-98 30-0ct-98 2-Feb-99 8-Sep-96 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 11-Dec-92 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 2-Feb-99 10542.3 9932.1 9237.5 9563.0 8917.5 10000.4 10000.4 4440.6 4440.6 751.9 416.5 297.1 60.0 177.6 365.2 215.6 215.6 402.5 468.5 468.5 699.8 802.8 859.2 775.9 685.7 649.1 32.6 32.6 6319.4 6495.4 7281.3 6441.7 7240.0 6430.5 6430.5 3300.0 3300.0 0.0 1400.0 1500.0 500.0 1100.0 0.0 1955.6 1955.6 0.0 0.0 0.0 0.0 700.0 0.0 500.0 2433.3 2333.3 900.0 900.0 7220.0 6495.4 7281.3 6441.7 7281.3 6430.5 6430.5 3300.0 3300.0 0.0 1400.0 1500.0 1811.1 1100.0 0.0 2580.0 1955.6 0.0 1511.1 1511.1 1555.6 700.0 300.0 500.0 2433.3 4640.0 900.0 900.0 i l]6/3/99~MRT AJR Per..9068ACS ~ C.P.F.1 : ' CONDUCTOR 1~17 ~~ ~ ~ ~ SCALE: 1= MILE LOUNS~URY A ASSOCiATgS, INC. E~NEERS P~NNE~ SURVEYORS 1G XXXX D1 AROO Alaska, [.c. ~ ~ co,9~CTO, ~ ~7 Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON LK61~7D9 6/~/99 CEA-D1GX-61~TD9 ~ o~ 2 NOTES:ID ~=, IS Y 1. BASIS OF LOCATION AND ELEVATION ARE D.S. 1G / ~ ~~~"~ 2. ELEVATIONS SHO~ ARE BPMSL DATUM. 2 3s 4 3. COORDINATES SHO~ ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 4. WELL IS LOCATED WITHIN PROTRACTED SEC. 29, T~.12 N., RGE. I~ E., UMIAT MERIDIAN, ALASKA. 5. REF: DRAWINGS NSK 9.~5.1~7d2 ~ NSK 9.~5.1~7d4 ' FOR EXISTING CONDUCTOR LOCATIONS. BOOK L99-56, PAGE 5~. FROM A.S.P. ZONE 4 GRID NORTH. 7 SCA[: 1'= 1 MILE Sec. 29, ~. 12 N., R. le E. NO. Y X LATITUDE LONGITUDE F.S.L. F.W.L. O.G. PAD 17 5,981,599.48 54e, e76.e4 7e'21'38.4e4" 149'4e'28. e78" 953' 3e2' 54.~ 57.6 ~ ~ = ~ · ~ ,, SUR~YOR'S CER~FICA~ ................................~ / HEREBY CERTIFY mAT / AM PROPERLY REGISTERED AND . . LICENSED TO PRACTICE LAND SUR~Y/NG IN THE STATE OF ~ ......... ~ ALASKA AND ~AT THIS PLAT REPRESENTS A SURLY 3.~ ~~ d. ROOKUS fi ~ DONE BY ME OR UNOER MY DIRECT SUPERVISION AND ~ ~ ~~'~'--- ~ ~ ~ ~AT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT ~ ~ % L~-8035 .. .ej~ .... ~./~/__ ...,. ~ ~s OF JUN~ & ~999. LOUNSBURY & ~SS0CI~T~S. INC. ~N~E~ P~N~RS SURVEYORS 1G ~XX D1 ARCO Alaska, Inc. DS1G ~ ~LL CONDUCTOR ~ 17 Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON ' LK61~7D9 6/5/99 _ CEA-D1GX-61~7D9 2 ~ 2 1 16" DI~,~RTER SCHEMATIC- ~,ordic Rig 3 Kuparuk River Unit Operations l b~ Open -~ I ~ · To Accumulator I I /'1,, ~ Closed ~L_. I I I I I ~.. .... From Accumulator 5 Closed Open Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 16" Conductor 2. 16-3/4" 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21-1/4" 2000 psi, Double-Studded Adapter Flange 4. 16" Diverter Spool with APl 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange 6. 13-5/8" Hydril GK 5000 psi Annular Preventer 7. 16" Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line TAB, 07/29/98, v.1 7-1/16" )00 psi BOP Stack-- t' rdic Kuparuk River Unit Operations Rig 3 Kill Line 3 Choke Line Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 psi Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 5000 psi Hydril Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ Manual Locks 4. 7-1/16" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 5. 7-1/16" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 6. 7-~/~0" 5000 p~i Idydrll ^nnular Preventer, Hub Bottom Connection TAB, 10/01/98, v.2 C T Drilling BOPE ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold __~~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I-- 7" Riser I I ' ,~ ,. (3.5") ~ t~ Cutters or '~- Combination Cutter/Blinds Man~ ~ Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" I D with Pipe/Slip Rams 2" Pump-In Tubing Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Inner Annulus Outer Annulus Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement / above Port / Collar / ¢OOO'TVD)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One1 Stage Cement JobI I to Surface / Cement below Port Collar (lOOO' TVD)/ If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 June 16, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 1G-17 953' FSL, 302' FWL, Sec 29, T12N, R10E, UM 236' FNL, 1785' FEL, Sec. 31, T12N, R10E, UM 329' FNL, 1948' FEL, Sec. 31, T12N, R10E, UM Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1G pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1 G pad. The well is designated as a producer and is planned to penetrate the Kuparuk C and A sands using a 7-5/8" surface casing string, a 5-1/2" intermediate casing string to the top of the producing horizon, and a 3-1/2" cemented liner in the reservoir section. The surface and intermediate hole sections will be drilled and cased using Nordic Rig 3. After this rig moves off the well, Nabors 3S/CTU#4 will move onto location to drill out the production interval and run the completion. Completion plans call for running a 3-1/2" production tubing string with gas lift mandrels. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APB package,ii?])'~ F ........ ( ~iV ,~ i-~,~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 8) 9) 10) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) B) Completion Report (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling Technologist 263-4612 Tony Hillegeist, Geologist 265-1534 Please note that the anticipated spud date for this well is June 24, 1999 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Chip Alvord at (907) 265-6120. Sincer - ,.~.~ /'~/ Thomas A. Brockway ~ Operations Drilling Engineer Attachments: CC: KRU 1G-17 Well File Chip Alvord Dan Kara Jim Burd Mark Chambers ATO-1 O3O ATO- 1532 ATO- 1282 ATO- 1032 ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF:REVENuE ALASKA OIL. & GAs CONSERVATION COMMI 3001 PORCUPINE, DRIVE .. 230097162 73-426 839 JUNE 11, 1999 VOID: AFTER 90 DAYS 0997587 ',~i EXACTLY ***********,100 !DOLLARS AIVD OO '¢ENTs '~**;******** 100.00 The First National. B~nk of"Ch'icago-0710 Payable Thl;~gh Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230097162 ~l'2~OOq?&g211' m:O~qOh2P, 2m: oqq ? 58 WELL NAME ~ /~:~ "l' ? WELL PERMIT CHECKLISTL~¢:;i/~, .~CO_MPANY ~ FIELD & POOL-~ ~'~~ 'U~U INIT CLASS /-- ADMINISTRATION ENGINEERING Permit fee attached ....................... GEOLOGY APPR ~ . 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to._2, 0OO /.~'oOc") psig. 27. Choke manifold complies w/APl RP-53 (May 8~) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA N N N N N N N N N N N N N ®N ¥ N Y N Y N Y N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N // 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. ~ N 34. Contact name/phone for weekly progress reports [exploratory onmY N ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan ,/~~L~ P- (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N PROGRAM: exp ~ dev ~ redrll __ serv ~ wellbore seg ann. disposal para req ~ ~?<::~ UNIT# I//_~_(JN/OFFSHORE ~ GEOLOGY: ENGINEERING.; UIC/Annular COMMISSION: RNC '~- CO ~:~ Comments/Instructions: Z c:\msoffice\wordian\diana\checklist 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, Tape Subfile 1 is type: LIS **** REEL HEADER **** ~D 00/12/08 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 00/12/08 108588 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ! !!!!!!!!!! ! !! !! !! ! Remark File Version 1.000 ! !!!! !! !!!!!! ! ! ! !!! Extract File: template.las ~Version Information VERS. 1.20: WRAP. NO: -Well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.FT 39.5000: Starting Depth STOP.FT 7380.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ARCO Alaska, Inc. WELL. WELL: 1G-17 FLD . FIELD: Kuparuk River Unit LOC . LOCATION: 953' FNL, 302' FEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 13-Nov-99 API . API NYUMBER: 500292294501 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 29 : Section TOWN.N 12N : Township RANG. 10E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 88 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 88 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F 6018 : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) (2 (3 Ail depths are Measured Depths (MD) unless otherwise noted. Ail depths are Bit Depths unless otherwise noted. Ail Gamma Ray data (GRAX) presented is real time data. This log is an extension from the original 1G-17 wellbore, starting at 6746' MD (5931' SSTVD) . The M~D data recorded by Sperry-Sun (07-23-99) above 6746' MD has been combined with the Baker Inteq MWD data recorded below 6746' MD. (5) The Sperry-Sun data was previously depth corrected to the PDC. Only the Baker Inteq portion of the final spliced data (below 6746' MD) was depth corrected to the PDC during the construction of this tape. The data presented is final and has been depth shifted to the PDC sup- plied by ARCO Alaska, Inc. The PDC used is a Schlumberger Gamma Ray dated 12-March-99. 6) The well was drilled without an MWD tool from 7091' MD (6228' SSTVD) to 7372' MD (6486' SSTVD). 7) The well was drilled with a hole size of 5 1/4" from 6746' MD (5931' SSTVD) to 6864' MD (6037' SSTVD) . The hole size from 6864' MD (6037' SSTVD) to 7372' MD (6486' SSTVD) was 4 3/4". 8) Well 1G-17 was drilled to 7372' MD (6486' SSTVD) on Run 3. 9) A magnetic declination correction of 26.74 degrees has been applied to the Directional Survey. CURVE SHIFT DATA BASELINE, MEASURED, 6700 45, 6700.45, 6745 38, 6748 71, 6794 03, 6797 16, 6802 39, 6809 22, 6852 34, 6860 98, 6882 83, 6904 95, 6908.57, 6917 06, 6922 89, 6943 59, 6947 41, 6954 05, 6963 04, 6974 29, 6984 15, 7003 39, 6743.17, 6746.70, 6792.63, 6798 57, 6802 19, 6809 22, 6854 75, 6863 39, 6885 25, 6908 37, 6911 99, 6920 88, 6925.50, 6945.00, 6950.23, 6956.46, 6967.06, 6978.31, 6988.17, 7006.80, 7015 05, 7018.87, 7021 68, 7025.30, 7039 17, 7044.00, 7046.61, 7051.84, 7065.70, 7070.93, DISPLACEMENT 0 -2.21143 -2.01025 -1.40723 1.40723 -0.201172 0 2.4126 2.4126 2.4126 3.41748 3.41797 3.81982 2.61377 1.40771 2.81445 2.4126 4.021 4 021 4 02051 3 41797 3 81982 3 61865 4 8252 5 22705 5 22754 Tape Subfile: 1 90 records... Minimum record length: Maximum record length: _ Tape Subfile 2 is type: LIS 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN STAT splice.xtf 150 ARCO Alaska, Inc. 1G-17 Kuparuk River Unit North Slope Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!! !!!! !!!! !!!! !!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska 3. The PDC used is a Schlumberger Gamma Ray dated 12-Mar-99. 4. The data presented is merged from Sperry-Sun MWD recorded above 6746 MD and Baker Inteq MWD recorded below 6746 MD. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX10 0.0 2 ROP ROPS10 0.0 * FO~4_AT RECORD (TYPE# 64 Entry Type 1) Size 1 Repcode(66) Data record type is: 0 Entry Type 2) Size 1 Repcode( 66) Datum Specification Block Type is: 0 Entry Type 3) Size 2 Repcode(79) Datum Frame Size is: 12 bytes Entry Type 4) Size 1 Repcode( 66) Logging direction is down (value= 255) Entry Type 5) Size 1 Repcode 66) Optical Log Depth Scale Units: Feet Entry Type 8) Size 4 Repcode 68) Frame spacing: 0.500000 Entry Type 9) Size 4) Repcode 65) Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode 68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode 66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a IF ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 ROP MWD 68 1 F/HR 4 *** Record Type (47) not decoded... API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Record Type (47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 175 Tape File Start Depth = 39.500000 Tape File End Depth = 7380.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 44050 datums Rep Code: 79 2 datums Tape Subfile: 2 184 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1024 *** INFO,RATION TABLE: CONS MNEM VALU WDFN inteq.xtf LCC 150 CN ARCO Alaska, Inc. WN 1G-17 FN Kuparuk River Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !! !!!!! !!!! !!!! !!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Entry Type( 1) Size( !) Repcode( 66) Data record type is: 0 Entry Type( 2) Size( 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type( 3) Size( 2) Repcode(79) Datum Frame Size is: 12 bytes Entry Type( 4) Size( 1) Repcode( 66) Logging direction is down (value= 255) Entry Type( 5) Size( 1) Repcode( 66) Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4) Repcode(68) Frame spacing: 0.500000 Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type(13) Size( 1) Repcode( 66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 ! 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 FRA/gE SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 GRAX I~'~D 68 1 API 4 2 ROPS ~l~D 68 1 F/HR 4 *** Record Type (47) not decoded... **3 Record Type ( 47) not decoded... * DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 17 AP1 AP1 AP1API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 Tape File Start Depth = 6700.000000 Tape File End Depth = 7380.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 4087 datums Rep Code: 79 2 datums Tape Subfile: 3 26 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes Tape Subfile 4 is type: LIS *~** TAPE TRAILER **** 00/12/08 108588 O1 **** REEL TRAILER **** M?~D 00/12/08 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 8 DEC *~ 3:43p Elapsed execution time = 0.50 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS DEPTH 39 5000 40 0000 100 0000 200 0000 300 0000 4OO 0000 500.0000 600 0000 7OO 0000 800 0000 900 0000 1000 0000 1100 0000 1200 0000 1300 0000 1400 0000 1500 0000 1600.0000 1700 0000 1800 0000 1900 0000 2000 0000 2100 0000 2200 0000 2300 0000 2400 0000 2500 0000 2600 0000 2700 0000 2800 0000 2900 0000 3000 0000 3100 0000 3200 0000 3300 0000 3400.0000 3500 0000 3600 0000 3700 0000 3800 0000 3900 0000 4000 0000 4100 0000 4200 0000 4300 0000 4400 0000 4500 0000 4600.0000 4700.0000 4800.0000 4900.0000 5000.0000 5100.0000 5200.0000 5300.0000 5400 0000 5500 0000 5600 0000 5700 0000 5800 0000 5900 0000 6000 0000 6100 0000 6200 0000 6300 0000 6400 0000 6500 0000 6600 0000 6700 0000 6800 0000 6900 0000 7000.0000 7100.0000 GR 43 64 22 54 75 67 7O 86 74 72 28 43 102 46 59 58 58 41 67 52 63 87 80 52 38 73 34 67 72 65 72 71 89 88 114 101 117 100 95 114 110 113 117 126 104 86 103 145 203 163 156, 143 169 149 118 115 291 217 153 137 40 -999 38 5400 35 4800 23 5700 53 9300 49 6500 70 0600 57 1400 72 4800 24.2100 76.6800 81.5300 .2600 .5600 7800 9600 7600 6200 7300 2900 2500 5500 4400 3800 8900 7500 2500 7400 8300 9500 0400 .2200 .5900 9400 1500 6000 6400 7400 4200 1800 1900 6400 6700 9000 6600 6400 7800 0600 1500 4500 0300 .2600 .2500 1700 8600 8900 0900 7200 8800 5500 5600 5000 9600 7800 1600 0600 8900 6100 4000 6800 7329 4653 3777 2500 ROP -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 3.4601 27.0018 35.8288 17.1285 7200.0000 -999.2500 23.7700 7300.0000 -999.2500 15.7080 7380.0000 -999.2500 -999.2500 Tape File Start Depth = 39.500000 Tape File End Depth = 7380.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH 6700.0000 6700 5000 6800 0000 6900 0000 7000 0000 7100 0000 7200 0000 7300 0000 7380 0000 GRAX ROPS -999.2500 -999.2500 -999.2500 -999.2500 142.0250 17.4000 141.3600 22.8350 49.5720 34.9240 -999.2500 22.0000 -999.2500 24.8000 -999.2500 6.1670 -999.2500 -999.2500 Tape File Start Depth = 6700.000000 Tape File End Depth = 7380.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 17 12:24:42 1999 Reel Header Service name ............. LISTPE Date ..................... 99/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-90136 RANDY KRELL DON WESTER 1G-17 500292294500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-AUG-99 MWD RUN 2 AK-MM-90136 RANDY KRELL DEARL GLADDE MWD RUN 3 AK-MM-90136 RANDY KRELL DEARL GLADDE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-90136 E. CRIBBS D. GLADDEN 29 12N 10E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 953 302 88.00 88.00 57.60 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 24.000 16.000 110.0 3RD STRING 9.875 7.625 4286.0 PRODUCTION STRING 6.750 6755.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 3. MWD RUN 4 IS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 08/04/99. MWD DATA IS PDC. 4. MWD RUNS 1-4 REPRESENT WELL 1G-17 WITH API# 50-029-22945-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6755'MD, 6027'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ MEDIUM). DEEP). File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 39.5 ROP 110.0 FET 4190.0 RPD 4190.0 RPM 4190.0 RPS 4190.0 RPX 4190.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: STOP DEPTH 6700 5 6755 0 6707 0 6707 0 6707 0 6707 0 6707 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 110.0 351.0 2 351.0 1226.0 3 1226.0 4292.0 4 4292.0 6755.0 MERGED MAIN PASS. $ 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD OHMM 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 GR MWD API 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 FET MWD HOUR 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Name Min Max Mean Nsam Reading Last Reading DEPT 39.5 6755 3397.25 13432 RPX 0.51 15.33 2.45851 5035 RPS 0.06 14.03 2.46275 5035 GR 9.92 562.74 88.7263 13323 RPM 0.06 2000 5.57539 5035 RPD 0.38 2000 7.18553 5035 FET 0.2842 90.~1683 4.63039 5035 ROP 0 458.38 119.367 13291 39.5 4190 4190 39.5 4190 4190 4190 110 6755 6707 6707 6700.5 6707 6707 6707 6755 First Reading For Entire File .......... 39.5 Last Reading For Entire File ........... 6755 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 39.5 311.5 ROP 110.0 352.0 $ LOG HEADER DATA DATE LOGGED: 12-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.02 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 351.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS 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 MAX CIRCULATING TERMPERATURE: 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...0 110.0 351.0 .0 .0 TOOL NUMBER P1334HWG6 9.880 9.9 S PUD MUD 8.90 155.0 8.0 1900 12.0 .000 .000 .000 .000 29.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 39.5 352 195.75 626 GR 16.57 81.19 39.375 545 ROP 4.79 327.68 111.74 485 First Reading 39.5 39.5 110 Last Reading 352 311.5 352 First Reading For Entire File .......... 39.5 Last Reading For Entire File ........... 352 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Nuraber ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 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 STOP DEPTH GR 312.0 1189.5 ROP 352.5 1229.5 $ # LOG HEADER DATA DATE LOGGED: 14-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.02 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 1226.0 TOP LOG INTERVAL (FT): 351.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS 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 MAX CIRCULATING TERMPERATURE: 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 1226.0 .0 .5 TOOL NUMBER P1334HWG6 9.880 9.9 SPUD MUD 8.90 117.0 8.0 1100 13.2 .000 .000 .000 .000 31.7 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 312 1229.5 770.75 1836 GR 16.63 125.29 59.0021 1756 ROP 0 159.32 74.2825 1755 First Reading 312 312 352.5 Last Reading 1229.5 1189.5 1229.5 First Reading For Entire File .......... 312 Last Reading For Entire File ........... 1229.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1190.0 4251.5 ROP 1231.0 4291.5 $ LOG HEADER DATA DATE LOGGED: 16-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.02 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 4292.0 TOP LOG INTERVAL (FT): 1226.0 BOTTOM LOG INTERVAL (FT): 4292.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 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 MAX CIRCULATING TERMPERATURE: 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 .4 35.8 TOOL NUMBER P1334HWG6 9.880 9.9 SPUD MUD 9.60 70.0 7.5 50O 7.0 .000 .000 .000 .boo 44.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 1190 4291.5 2740.75 6204 GR 9.92 135.49 66.3399 6124 ROP 14.47 458.38 135.484 6122 First Reading 1190 1190 1231 Last Reading 4291.5 4251.5 4291.5 First Reading For Entire File .......... 1190 Last Reading For Entire File ........... 4291.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.000 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4190 0 4190 0 4190 0 4190 0 4190 0 4252 0 4292 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 6707.0 6707 0 6707 0 6707 0 6707 0 6700 5 6755 0 22-JUL-99 Insite 4.02 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 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 MAX CIRCULATING TERMPERATURE: 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 MEMORY 6755.0 4292.0 6755.0 19.6 34.9 TOOL NUMBER P1331GRV4 P1331GRV4 6.750 6.8 LSND 9.60 46.0 9.9 5OO 4.2 2.400 1.410 2.200 2.500 50.8 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 RPS MWD 4 OHMM 4 1' 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 RPX MWD 4 OHMM 4 1 68 FET MWD 4 HOUR 4 1 68 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Min Max Mean DEPT 4190 6755 5472.5 GR 45.68 562.74 132.864 RPS 0.06 14.03 2.46275 RPM 0.06 2000 5.57539 RPD 0.38 2000 7.18553 ROP 4.81 404.47 116.176 RPX 0.51 15.33 2.45851 FET 0.2842 90.1683 4.63039 First Last Nsam Reading Reading 5131 4190 6755 4898 4252 6700.5 5035 4190 6707 5035 4190 6707 5035 4190 6707 4927 4292 6755 5035 4190 6707 5035 4190 6707 First Reading For Entire File .......... 4190 Last Reading For Entire File ........... 6755 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 99/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Scientific Technical Services Physical EOF Physical EOF End Of LIS File