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197-240
1 Christianson, Grace K (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, June 10, 2025 8:59 AM To:AOGCC Permitting (CED sponsored) Subject:FW: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Follow Up Flag:Follow up Flag Status:Flagged Operator is requesting to withdraw these sundries. Andy From: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Sent: Thursday, 5 June, 2025 10:11 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Byrne, Jan <Jan.Byrne@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Andy, et al, This new interpretaƟon of 20 AAC 25.112(c) and the requirement to P&A each zone within the same pool is a signiĮcant change from what was deemed acceptable by the AOGCC in the past. This has led to hal Ɵng the execuƟon of these 1D P&A operaƟons. ConocoPhillips Alaska requests that our current sundry applicaƟons are withdrawn for the following wells: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) Based on informaƟon presented by the AOGCC at the AADE/SPE luncheon meeƟng on May 22, 2025, ConocoPhillips does not agree that this new requirement will achieve the stated goals or mi Ɵgate the risks menƟoned. We will request a meeƟng on this topic and its implicaƟons aŌer compiling data for discussion. Thank you, Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1D-106 (Sundry 325-159) RBDMS JSB 061225 2 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, May 28, 2025 2:58 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments 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. Jan, Regarding: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) In reviewing the three KRU 1D West Sak abandonments, the proposed work does not meet the requirement of 20 AAC 25.112(c). I do see that there is an exisƟng plug within 50’ of the shallowest perforated interval, but leaving all the perforated zones open to each other does not conĮne all hydrocarbons to their respecƟve indigenous strata and prevent them from migraƟng into other strata. As such, I will not be recommending these sundries for approval. Jack and I are available to discuss this further. Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 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: ___________________ 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?N/A Yes No 9. Property Designation (Lease Number): 10. Field: KRU West Sak Oil West Sak Oil- P&A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5126'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: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:Jan Byrne Contact Email:Jan.Byrne@conocophillips.com Contact Phone: 907-265-6471 Authorized Title: Staff Intervention Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU WSAK 1D-106 4335'4444'3682'4444'0 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 4378' / 3621' 4434' /3675' No SSSV Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 197-240 P.O. Box 100360, Anchorage, AK 99510 50-029-22847-00-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: L-80 TVD Burst 4378' MD 121'121' 4317'5.5" x 3.5" 16"80' 5117' Perforation Depth MD (ft): 4462'- 4794' 5077' 3699'- 4011' 6/1/2025 3.5" Baker GBH 22 Seal Assembly Baker 35 KB packer No SSSV m n P 1 6 5 6 t _ V N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.03.21 12:47:48-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 325-159 By Grace Christianson at 1:44 pm, Mar 21, 2025 AOGCC Witnessed tag TOC and MIT-T to 1500 psi. AOGCC witness casing cuts before top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut. X JJL 4/25/25 10-407 XX 1D-106 P&A Procedure Date: 3/21/25 Network Number: 10460676 Prepared by: Jan Byrne 808-345-6886 1 CContents Objective ....................................................................................................................................................... 2 Current Well Status ....................................................................................................................................... 2 Job Design Data ............................................................................................................................................. 2 Design Envelope ............................................................................................................................................ 2 Volumes ........................................................................................................................................................ 2 P&A ............................................................................................................................................................... 3 Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T ................................................. 3 Slickline – Drift for Eline ............................................................................................................................ 3 Eline – Punch holes in tubing and perform injectivity test ....................................................................... 3 Cementing Unit - Pump Tubing x IA Plug to Surface ................................................................................. 3 Surface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar ........................................ 4 Appendix ....................................................................................................................................................... 6 Tubing Tally ............................................................................................................................................... 6 Liner tally ................................................................................................................................................... 7 Wellbore Schematic .................................................................................................................................. 8 2 OObjective In 2022 a 1D-Pad mechanical well review identified six wells to be Plug and Abandoned (P&A) due to single casing well designs, mechanical integrity damage, and subsidence damage. 1D-106 tubing surveillance subsidence drifts are reporting deteriorating drift-ability. The objective of this project is to P&A 1D-106. It is recommended that a full P&A be performed by cementing the well to surface and excavating 4 feet below original ground level, removing the wellhead and cellar, and backfilling with gravel/fill to ground level. As subsidence driven deformation continues, the risk of losing well access increases with time. This non-rig P&A ultimately saves money and mitigates future risk to the company. Current Well Status x Baker 35 KB packer w/ 1.81” D nipple set at 4444’ x 1.81” CA-2 plug set in D nipple at 4444’ x Owen X-span perm patch w/ 2.25” ID set at 4295’ x Able to drift 2.0” x 10’ to 4444’ RKB on 10/29/24 x Passed CMIT TxIA to 2000 psi on 1/6/25 x Passed C-DDT TxIA to 0 psi on 2/28/25 Job Design Data x Last SBHP: 1602 psi at 3620’ TVD on 4/26/22 x Reservoir temperature: 70- 75°F in West Sak D sand x Fracture gradient: 0.67 psi/ft x Fracture pressure: 2478 psi (.67 x 3699’ TVD top slot) Design Envelope x Tubing: 3.5”, 9.3 lb/ft, L-80. MASP Normal WOG. x Liner: 3.5”, 9.3 lb/ft, L-80. MASP Normal WOG. x Prod Casing: 5.5”, 15.5 lb/ft, L-80 MASP Normal WOG. x Wellhead: Vetco Gray horizontal. MASP Normal WOG. Volumes x 3.5” Tubing from 0’ to 4279’= 37.3 bbls (.0087 x 4279’) x 3.5” x 5.5” Annulus from 0’ to 4279’= 51 bbls (0.0119 x 4279’) x 3.5” Casing 35’ above plug = 0.30 bbls (0.0087 x 35’) x Diesel FP, to 2000’ TVD = 2115’ RKB = 18.4 bbls (.0087 bbl/ft x 2115’) 3 PP&A P&A Plug #1: Reservoir Plug Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T 1) MIRU Slickline. PJSM. 2) RIH to set catcher. 3) Install dummy valve in open pocket at 4286’. Pull catcher. 4) Perform MITT to 1500 psi. Record initial, start, 15 & 30 min pressures. 5) Dump bail 35’ (0.30 bbls) of 15.8 class G cement on top of CA-2 plug at 4444’. a. This will put TOC at ~4409’. b. The minimum required cement dump bailed on top of a plug is 25’ (0.22 bbls). 6) WOC a minimum of 48 hours before proceeding to the AOGCC witnessed Tag and MITT. 7) RIH for AOGCC witnessed TOC tag (estimate ~4409’ RKB) and perform MIT-T to 1500 psi. Record Results in WSR. a. Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 8) Only proceed to next steps if MIT-T passes and TOC is acceptable. P&A: Plug #2 Slickline – Drift for Eline 1) Fullbore drift tubing down to ~4286’ to verify Eline will make it down with punches. 2) RDMO, ready for Eline. Eline – Punch holes in tubing and perform injectivity test 1) RIH with tubing punch to punch holes in 3.5” at ~4278.5’ (middle of 15’ pup joint above GLM at 4286’). Punch sufficient holes for 2 BPM circulation rate. Do not punch through 5.5” casing. 2) Verify injectivity through punches. Pump down tubing taking returns off IA to tanks. a. If 2 BPM circ rate is not achievable punch more holes and repeat injectivity test. b. 1500 psi Max pump pressure. 3) RDMO, ready for Cementing. Cementing Unit - Pump Tubing x IA Plug to Surface Cement Volume Calculations: x 3.5” Tubing from 0’ to 4278.5’= 37.3 bbls (.0087 x 4279’) x 3.5” x 5.5” Annulus from 0’ to 4278.5’= 51 bbls (0.0119 x 4279’) x Excess: 25% x Total volume: 37.3 + 51 = 88.3 x 1.25 = 110.4 bbls 4 1) Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Bryce Hinch 307-359-0067). The job is designed for 110.4 bbls of ArcticSet 1 (AS1) cement. 2) Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3) RU HES Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3.5” x 5.5” annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4) Open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5) After circulation to IA is confirmed batch up AS1 cement. 6) Line up to pump cement down the tubing, taking returns from the IA. 7) Follow Pump Schedule below: 8) 20 bbls fresh water spacer ahead 9) 75 bbls (2x Tbg) surfactant wash. 10) 75 bbls fresh water spacer. 11) 110.4 bbls of Permafrost Cement (AS1) to surface in tubing and IA (including 25% excess). 12) After approximately 88.3 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud density scale to confirm proper weight Permafrost Cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 13) After good IA cement is seen at surface, shut down pumps and close in the IA valve. 14) Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 15) RDMO SSurface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar 1) MIRU required equipment. 2) DHD to perform drawdown test on tubing and IA. 3) Remove well house. 4) Bleed off T/I to ensure all pressure is bled off the system. 5) Remove production tree in preparation for excavation and casing cut. 6) If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 7) Cut off wellhead and all casing strings 4 feet below original ground level. 8) Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 9) Send the casing head with stub to materials shop. Photo document. 10) Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. AOGCC witness casing cuts before top job commences.- JJL 5 ConocoPhillips 1D-106 PTD #: 197-240 API #: 50-029-22847-00-00 11) Remove cellar. Back fill cellar with gravel/fill as needed. Back fill the remaining hole to ground level. 12) Obtain site clearance approval from AOGCC. RDMO. 13) Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment. 6 AAppendix Tubing Tally 7 LLiner tally 8 WWellbore Schematic Current Completion Proposed P&A 1D-106 PTD# 197-240 Proposed P&A Schematic 16” 62.5# H-40 Conductor @ 108' KB 5.5" x 3.5" 15.5# L-80 Production Casing at 5117' MD 3-½” 9.3# L-80 Tubing at 4378' MD KB packer w/1.81" CA-2 plug at 4444' MD West Sak D sand upper perfs at 4462' West Sak D sand upper perfs at 4462' Seal Assembly at 4378' MD 5.5" x 3.5" 15.5# L-80 Production Casing at 5117' MD Reservoir Cement Plug Slickline dump bails 35' of cement on top of KB packer w/ 1.81" CA-2 plug to place TOC at ~4409' Tubing and IA cement plugs from punches at ~4278' to surface Calculated Top of Cement (5.5 x 3.5" x OH) = 2,241'MD 5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) &3) Q#FRQRFRSKLOOLSVFRP! 6HQW 0RQGD\-XO\ $0 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW .58'3DGQRQZLWQHVVHG0,7,$V $WWDFKPHQWV 0,7.58'3$'6,7(676[OV[ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨLJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001900 Type Inj N Tubing 580 585 585 585 Type Test P Packer TVD 5977 BBL Pump 2.1 IA 145 1800 1770 1770 Interval 4 Test psi 1500 BBL Return 2.1 OA 43 54 54 54 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2001830 Type Inj N Tubing 150 160 160 160 Type Test P Packer TVD 3626 BBL Pump 0.3 IA 380 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 0.3 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1972400 Type Inj N Tubing 100 1800 1740 1730 Type Test P Packer TVD 3621 BBL Pump 1.7 IA 25 1800 1740 1730 Interval 4 Test psi 1500 BBL Return 1.6 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2000470 Type Inj N Tubing 500 505 505 505 Type Test P Packer TVD 3526 BBL Pump 0.8 IA 140 1800 1700 1690 Interval 4 Test psi 1500 BBL Return 0.5 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1D Pad Galle / Borge 07/14/22 Notes: Notes: 1D-40A 1D-101 1D-137 Notes:Single casing well 1D-106 Notes:Single casing well. Tubing plug at 4444' MD. Open Pocket at 4286' MD. CMIT T x IA. Notes:Single casing well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0714_MIT_KRU_1D-pad_4wells 9 9 ¿ 9 9 9 9 9 - 5HJJ CMIT T x IA. 1D-106 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday,August 11, 2017 3:36 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE:West Sak injector 1D-106 (PTD 197-240) Report of IA pressure anomaly Update 8/11/17 Chris, The 30 day monitor period is coming to an end and the IA has maintained pressure. The repair to the needle valve was effective in eliminating the IA pressure fall off. The well will be returned to its'normal' status. Please let us know if you disagree. Attached is an updated 90 day TIO plot. SCANNED AUG 2 i 2017 1 • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday,July 16, 2017 8:12 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE:West Sak injector 1D-106 (PTD 197-240) Report of IA pressure anomaly Update 7/16/17 Chris, On 7/13/17,we did find a small gas-only external leak at a needle valve attached to the main API IA valve on 1D- 106. We replaced the needle valve which stopped the observable gas leak. We did not perform an MITIA so as to avoid fluid packing the annulus and potentially masking the leak. Instead,we left a nitrogen gas cap with elevated pressure ("950psi)on the IA and are now in monitor mode. Thus far,the IA pressure looks to be holding, but we will continue the monitor out for a full 30 days. A follow-up email will be provided at the conclusion at the monitor. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907)943-0170 SCANNED AUG 0 8 2017 From: NSK Well Integrity Supv CPF1 and 2 Se uesday,July 11,2017 7:58 AM To:Walla : Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R. er<R.Tyler.Senden@conocophillips.com> Subject: RE:West Sa jector 1D-106(PTD 197-240) Report of IA pressure anomaly Update 7/11/17 Chris, 1D-106 (PTD 197-240) is displaying a rep-. ed unexplained very-slow IA pressure fall off, after being returned to water injection on May 18,2017. It had been shut i 'rice March 2016 for reservoir pressure management reasons. This same phenomenon was observed several years ago in th ell,as was reported in 2014(see the attached email below). But the issue resolved itself following diagnostics,without a repair work being performed. Speculation is that perhaps there is a small tubing gas leak near surface or even an exter gas leak from the API valve. We may have masked this leak when fluid packing the annuli during the diagnostic MIT per • • ed in 2014. But over time,operations personnel have used gas to charge the annulus when needing to establish prope •ifferential pressures. Thus,the leak is now observable. We plan to initially look for an external gas leak and perform . •ing packoff tests in hopes that this issue can be easily remedied. If there is no obvious leak source observed,we will pe •rm an MITIA and then monitor the well on water injection for 30 days. Based on the results of the diagnostics,we will cra` - path forward and submit proper paperwork as necessary. Please let me know if you disagree with the plan. Attached is the latest 90 day TIO plot. « File: 1D-106 90 day TIO 7-11-17.jpg>> Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 1 N • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, July 11, 2017 7:58 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE:West Sak injector 1D-106 (PTD 197-240) Report of IA pressure anomaly Update 7/11/17 Chris, 1D-106 (PTD 197-240) is displaying a repeated unexplained very-slow IA pressure fall off, after being returned to water injection on May 18, 2017. It had been shut in since March 2016 for reservoir pressure management reasons. This same phenomenon was observed several years ago in this well, as was reported in 2014(see the attached email below). But the issue resolved itself following diagnostics,without any repair work being performed. Speculation is that perhaps there is a small tubing gas leak near surface or even an external gas leak from the API valve. We may have masked this leak when fluid packing the annuli during the diagnostic MIT performed in 2014. But over time, operations personnel have used gas to charge the annulus when needing to establish proper differential pressures. Thus,the leak is now observable. We plan to initially look for an external gas leak and perform tubing packoff tests in hopes that this issue can be easily remedied. If there is no obvious leak source observed, we will perform an MITIA and then monitor the well on water injection for 30 days. Based on the results of the diagnostics,we will craft a path forward and submit proper paperwork as necessary. Please let me know if you disagree with the plan. Attached is the latest 90 day TIO plot. CHOKE FTP FTT IAP T/I/O Plot - 1D-106 OAP 1600 -- %ANNE® JUL 2 0 2017 5 1000 600 _ 0 - I I I I I I I ` I I I LH I I I I I I I III I , 07-Apr-17 20-Apr-17 03-May-17 16-May-17 29-May-17 11-Jun-17 24-Jun-17 Date • Kelly Lyons/Brent Rogers • • Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907)943-0170 From: NSK Problem Well Supv Sent:Sunday, November 09, 2014 9:06 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com> Subject: RE:West Sak injector 1D-106 (PTD 197-240) Report of IA pressure anomaly Update 11/9/14 Chis, West Sak injector 1D-106 (PTD 197-240)was reported on January 12, 2014 for an IA pressure anomaly. After reviewing the TIO trends the well appears to demonstrate IA pressure responses to local changes in injection rate and temperature, but does not exhibit indications of pressure communication or anomalies at this time. A passing witnessed MIT-IA was performed on July 19, 2014(see attached form). CPAI intends to leave the well on water injection and return the well to 'normal'status. If at any time in the future the well displays a suspect condition,the proper notifications will be submitted and precautionary actions taken. Attached are the 90 day TIO trend and MIT form. Please let me know if you disagree or have any questions with this plan. Thank you, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7126 Pager(907) 659-7000 pgr. 123 IEear << File: MIT KRU 1D PAD 07-19-14.xls>> << File: 1D-106 90 day TIO 11-9-14.1PG >> From: NSK Problem Well Supv Sent: Sunday, January 12, 2014 10:37 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R. Tyler Subject: West Sak injector 1D-106 (PTD 197-240) Report of IA pressure anomaly Chris, West Sak injector 1D-106 (PTD 197-240)appears to have a slow pressure anomaly with the IA. A 10' permanent patch was set on 11/04/13 followed by a passing witnessed MITIA on 11/18/13. The IA has been pressured up above the tubing pressure to gain a differential pressure and appears to have a slow decline in pressure. Initial diagnostics will 2 include an MITIA and continued pressure monitoring if the MITIA passes. If the MITIA fails,the well will be SI and freeze protected as soon as reasonably possible. It is ConocoPhillips intention to leave the well on water injection for diagnostics and pressure monitoring. A follow up email will be sent once the results of the diagnostics(including pressure monitoring) have been reached. Attached is a wellbore schematic and 90 day TIO plot. Please let me know if this is acceptable and if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 « File: 1D-106 90 day TIO plot.jpg>> « File: 10-106 schematic.pdf» 3 I . - STATE OF ALASKA AL, \OIL AND GAS CONSERVATION COMI.,....SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Install Tubing Alter Casing r Pull Tubing r Stimulate-Frac Waiver r Patch r r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 197-240 • 3.Address: 6.API Number: Stratigraphic r Service 1 P. 0. Box 100360,Anchorage,Alaska 99510 50-029-22847-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 , 1D-106 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool . 11.Present Well Condition Summary: Total Depth measured 5126 feet Plugs(measured) 4995' true vertical 4326 feet Junk(measured) none Effective Depth measured 5021 feet Packer(measured) 4434 true vertical 4235 feet (true vertical) 3673 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 121 PRODUCTION 5076 5.5"x 3.5" 5117 rr 4317 RECEIVED NOV 18 2013 Perforation depth: Measured depth: 4462-4496,4530-4570„4580-4600,4668-4680,4722-4762,4779-4794 AOGCC True Vertical Depth: 3699-3730,3762-3799,3809-3828,3892-3903,3943-3981,3997-4011 Tubing(size,grade,MD,and TVD) 3.5, L-80,4378 MD, 3621 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PACKER @ 4434 MD and 3673 TVD no SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 300 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run _ Exploratory r Development r Service rj. . Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ 1; • WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-467 Contact John Peirce a 265-6471 Email John.W.Peirceaconocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date I I.`1S-13 6-)??.. --.„- V/ RBE NOV 21 Form 10-404 Revised 10/2012 Submit Original Only I KUP INJ 1D-106 Conoc i hiHHips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellborc Status ncl(°) MD(ftKB) Act Btm(ftKB) t,,,,,�,w,,,l,l,., 500292284700 WEST SAK INJ 51.18 3,100.00 5,126.0 °.° Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1D-106,11/13/201331527 PM SSSV:NONE I Last WO: 49.10 1/19/1998 Vedical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 4,446.0 8/11/2010 Rev Reason:SET PATCH lehallf 11/13/2013 _II_ Strings Casing g Description OD(in) ID(in) Top(ftKB) Se[Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread HANGER 38.7 I CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 40.6 5,116.7 4,316.7 15.50 L-80 ABM-BTC L 1 1 Tubing Strings 'I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.9921 38.7. 4,378.4 3,621.5 9.301 L-80 ABM-EUE "w Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top net(°) Item Des Corn (in) 38.7 38.7 0.00 HANGER VETCO GRAY TUBING HANGER 3.500 4,339.1 3,585.4 23.66 NIPPLE CAMCO W-1 NIPPLE w2.812"SELECTIVE PROFILE 2.812 CONDUCTOR;40.0-121.0 d I 1 4,377.6 3,620.8 23.01'SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY Other Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc! W. .-y Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 4,295.0 3,545.2 25.42 PATCH PERMANENT OWEN X-SPAN 11/4/2013 2.250 4,433.7 3,672.5 22.40 PACKER 2.80"BAKER 35 KB PACKER WI 1.81"D NIPPLE @ 10/28/2013 1.790 4444.(OAL=13.84') 4,444.0 3,682.0 22.29 NIPPLE ATTACHED TO BAKER KB PACKER 10/28/2013 1.810 GAS LIFT;4,296.2 4,995.0 4,201.3 18.62 PLUG Drillable bridge plug-4600'-3 1/2"Halliburton. 7/19/1998 2.992 Bridge plug was drilled out by CTU pushed to bottom @ 4995'RKB. Perforations&Slots PATCH;4,295.0 Shot Dens Top(ND) Btm(ND) (shotsk Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn `® 4,462.0 4,496.0 3,698.7 3,730.3 WS D,1D-106 8/11/1998 4.0 IPERF 2 12"HC,DP,180 deg phasing,90 deg orientation •it NIPPLE;4,339.1 al 4,530.0 4,570.0 3,7619 3,799.3 WS C,WS B, 9/9/1998 4.0 IPERF 2 1/2"HC,DP,180 deg ! 1D-106 phasing,90 deg • orientation 4,580.0 4,600.0 3,808.7 3,827.5 WS A4,1D- 9/9/1998 4.0 IPERF 2 1/2"HC,DP,180 deg 106 phasing,90 deg orientation 4,668.0 4,680.0 3,891.9 3,903.2 WS A3,10- 9/9/1998 4.0 IPERF 2 1/2"HC,DP,180 deg 106 phasing,90 deg orientation SEAL ASST;4.377.6 4,7220 4,762.0 3,943.0 3,980.9 WS A2,11D- 7/19/1998 4.0 IPERF 2 1/2"HC,DP,180 deg 106 phasing,90 deg orientation 4,779.0 4,794.0 3,997.0 4,011.1 WS A2,10- 7/19/1998 4.0 IPERF 2 1/2"HC,DP,180 deg 106 phasing,90 deg orientation a, Mandrel Inserts St PACKER;4,4331 IIi ati C on�i Top(ND) Valve Latch Port Size TRO Run 0 NIPPLE;4,4440 No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date n, 1 4,286.2 3,537.3 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 8/12/2010 ' ii Notes:General&Safety End Date Annotation 1/5/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 IPERF;4,462.0.4,496.0 IPERF;4,530 0-4,570.0 IPERF;4,500 44.600.0 r IPERF;4.668.04.69 5 IPERF;4,722.0-4,762.0 IPERF;4,779.0.4,794.0-L-..• PLUG;4.995.0 PRODUCTION 5.5913.5":40.6- .4 5,1167- 1D-106 Well Work Summary DATE SUMMARY 10/6/2013 PULLED 2.81"MA-2 PLUG @ 4339' RKB. IN PROGRESS. 10/7/2013 TAGGED @ 4471' SLM, EST. 296' FILL. MEASURED BHP @ 4497' RKB: 1957 PSI. BRUSHED & FLUSHED TBG TO 4339' RKB. DRIFTED TBG WITH 16'x 2.74" DUMMY TO 4339' RKB. READY FOR NIPPLE. 10/13/2013 RIG UP TO DO A FCO,APPROXIMATELY 300'OF FILL 10/28/2013 SET 2.80" BAKER 35 KB PACKER W/ 1.81" D NIPPLE AT 4444'. LOG CORRELATED TO TUBING/LINER DETAIL RECORD DATED 19 JAN 1998. TROUBLE WORKING THROUGH NIPPLE AT 4339', USED LRS TO PUSH FLUID TO ASSIST IN WORKING PAST NIPPLE. 10/29/2013 SET 1.81"CA-2 PLUG @ 4441' RKB. CMIT 2500 PSI, PASSED. READY FOR E-LINE. 11/4/2013 LOG CORRELATED TO HES LEAK DETECT LOG DATED 8-SEPT-2010. SET 2.71"x 10'OWEN X-SPAN PERMANENT PATCH UPPER MID-ELEMENT AT 4295'. LOWER MID-ELEMENT AT 4306.5'. CCL TO UPPER MID-ELEMENT OFFSET: 10.3'. CCL STOP DEPTH: 4284.7' MIT-T AND MIT-IA BOTH PASSED. READY FOR SL 11/6/2013 PULLED 1.81" CA-2 PLUG @ 4444' RKB. COMPLETE. • OF Tit + w Al I%%sV THE STATE Alaska i and as ®f l ls Conservation ommissio 1 GOVERNOR SEAN PARNELL 333 West Seventh Avenue of Anchorage, Alaska 99501-3572 ALAS" Main: 907.279.1 433 Fax: 907.276.7542 John Peirce i' s Wells Engineer SCOSE ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-106 Sundry Number: 313-467 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this ,S day of September, 2013. End. i STATE OF ALASKA ',ci RECEIVED A OIL AND GAS CONSERVATION COMIV�ION '� 1 5 l3 a gUG282013 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Ap ro PI'@P Suspend r Plug Perforations fl Perforate r Rill Tubing r Time Extension (""' Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Install Tubing Patch P'•.' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 197-240 ` 3.Address: 6.API Number: Stratigraphic r Service p- P. O. Box 100360,Anchorage,Alaska 99510 50-029-22847-00. 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1D-106 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 5126 4326 • 5021' • 4235' • 4339',4995' Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16" 121' 121' PRODUCTION 5076 5.5"x 3.5" 5117' 4317' Perforation Depth MD(I 4462-4496,4530-4570, Perforation Depth TVD(ft): 3699-3730,3761-3799 Tubing Size: Tubing Grade: Tubing MD(ft): 4580-4600,4668-4680,4722-4762,4779-4794 3809-3828,3892-3903,3943-3981,3997-4011 3.5 L-80 4378 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no packer no SSSV no SSSV 12.Attachments: Description Summary of Proposal • 13. Well Class after proposed work: Detailed Operations Program r' BOP Sketch r Exploratory r Stratigraphic r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/15/2013 Oil r' Gas r WDSPL r Suspended E 16.Verbal Approval: Date: WINJ � . GINJ n WAG r" Abandoned r" Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title: Wells Engineer Signature feta_li/ , Phone:265-6471 Date / /X13 Commission Use Only Sundry Number: ';`PS _44.Cfa Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r i" Other: BDMS OCT 1 0 20 Spacing Exception Required? Yes ❑ No II Subsequent Form Required: APPROVED BY ? Approved by: ( , ' p•r. cd application is va � orl��m�nths from tInEk41l30N8val. Date: �' S - J Form 10-403(Revised 10/2012) Submit Form and Attachments in Duplicate 14 \� V/.r �;/-�;3 ORIGINAL • • Proposed 1D-106 Permanent Tubing Patch Installation 1D-106 injector was drilled and completed in 1998 with pert intervals in West Sak A, B, D sands. On 8-11-10 a Plug was set in the Nipple at 4339' RKB to diagnose annular communication. A MITT then failed, but a CMIT to 2500 psi passed. A 9-8-10 LDL verified a tubing leak exists at 4297' RKB in the pup joint located immediately below the only GLM in the tubing. 1D-106 has been SI since June 2010 due to this leak. A Permanent Tubing Patch will be set across the tubing leak. 1D-106 will become a RWO candidate if the tubing patch fails to repair annular communication. Procedure: Slickline 1. Pull the Plug from the 2.812" Nipple at 4339' RKB. 2. Tag PBTD & obtain SBHPS at PBTD. Last PBTD tag was 8-11-10 at 4487' RKB; 307' fill. 3. Brush &flush tubing around ann comm leak at 4297' RKB where a tubing patch is to be set. 4. RIH with 2.75" OD x 15' OAL dummy perm patch drift assembly to simulate running a 10' OAL perm patch with running tools. Drift the bottom of the assembly to 4305' RKB. 5. If dummy patch drift was successful, set a 1.81" ID Nipple Reducer in the 2.812" Nipple at 4339' RKB. Set a 1.81" Plug in the Nipple Reducer and CMIT to 2500 psi. Unless the CMIT passes no patch will be set. If CMIT passes, leave 1.81" Plug set to pull after setting the patch. E-line 6. RIH & set a 10' OAL Perm Patch at 4295' RKB (top seal), to set the patch in the middle of a 14' OAL pup joint located immediately below the only GLM in the tubing. Perform an MITT to 2500 psi to test set integrity of the patch and the 1.81" Plug in the Nipple Reducer. Also perform an MITIA to 2500 psi. Slickline 7. RIH & pull the 1.81" Plug from the Nipple Reducer at 4339' RKB. Coil Tubing 8. RIH with 1.5" CT to perform a fill cleanout in 3-1/2" liner through the 10' OAL x 2.259" ID perm patch set at 4295 - 4305' RKB and through the 1.81" Nipple Reducer at 4339' RKB. FCO to as deep as possible to uncover all the pert intervals located between 4462 - 4794' RKB currently covered by fill. POOH with CT. RD CTU. Return 1D-106 to PWI service. JWP 8/27/2013 t , • .- er" KUP 1 D-106 ConocoPhilhips } � Well Attributes Max Angle&MD TD Alaska.I Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) (n„nvny„,lnpn 500292284700 WEST SAK INJ 51.18 3,100.00 5,126.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ""• Well Confp'-1D-106,8/1420106:10:20 AM SSSV:NONE Last WO: 49.10 1/19/1998 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 4,446.0 8/11/2010 Rev Reason:TAG,GLV C/O Imosbor 8/14/2010 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd .' CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 Welded I z t I Casing Description String 0... String ID...'Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thea HANGER,39 a PRODUCTION 51/2 4.950 40.6 5,116.7 4,316.7 15.50 L-80 ABM-BTC ( 5.5"x3.5" Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd TUBING 3 1/2 2.992 38.7 4,378.4 3,624.5 9.30 L-80 ABM-EUE Completion Details Top Depth (TVD) Top Intl Nomi... _ Top(RKB) (ftKB) (°) Item Description Comment ID(In) L.E 38.7 38.7 -0.55 HANGER VETCO GRAY TUBING HANGER 3.500 -- 4,339.1 3,585.4 24.05 NIPPLE CAMCO W-1 NIPPLE w/2.812"SELECTIVE PROFILE 2.812 1--__-- 4,377.6 3,623.8 25.23 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 CONDUCroR,� ° - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 40.121 ---- I Top Depth (TVD) Top Intl I Top(ftKB) MSS) (°) Description Comment Run Date ID(in) S, i 4,339 3,585.5 24.05 PLUG MA-2 PLUG SET IN NIPPLE 8/11/2010 0.000 if i 4,995 4,201.3 18.48 PLUG Drillable bridge plug-4600'-3 1/2"Halliburton. Bridge plug 7/19/1998 2.992 was drilled out by CTU pushed to bottom @ 4995'RKB. Perforations&Slots „6.,vu A�rG nQa Ai:::�a:vP"'::'1 A.. r1ai Shot Top(TVD) Btm(TVD) Dens GAS LIFT, Top(ftKB)Btm(ftKB) (RKB) (RKB) Zone Date (sh... Type Comment 4 28 4,462 4,496 3,699.2 3,730.3 WS D,1D-106 8/11/1998 4.0 IPERF 2 12"HC,DP,180 deg phasing,90 deg orientation ..... 4,530 4,570 3,761.4 3,799.2 WS C,WS B, 9/9/1998 4.0 IPERF 212"HC,DP,180 deg phasing,90 1D-106 deg orientation 4,580 4,600 3,808.6 3,827.5 WS A4,1D-106 9/9/1998 4.0 IPERF 2 1/2"HC,DP,180 deg phasing,90 NIPPLE,4,339 deg orientation PLUG,4,339 4,668 4,680 3,891.8 3,903.2 WS A3,1D-106 9/9/1998 4.0 IPERF 2 1/2'HC,DP,180 deg phasing,90 deg orientation I 4,722 4,762 3,943.0 3,980.9 WS A2,1D-106 7/19/1998 4.0 IPERF 2 1/2"HC,DP,180 deg phasing,90 deg orientation 4,779 4,794 3,996.9 4,011.1 WS A2,10-106 7/19/1998 4.0 IPERF 2 1/7'HC,DP,180 deg phasing,90 I deg orientation Notes:General&Safety End Date Annotation 1/52009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 vimai SEAL ASSY, » 4,378 IPERF, 4,462-4,496 IPERF, 4,530-4,570 .. z .-- IPERF, _ _-- 4,580-4,600 - - IPERF, — ' _ _— 4,fifi&4,600 -- - -_ IPERF, -_ _ - 4,7224,762 - - 4,77 IPE754 Mandrel Details R 4 = - - Top Depth Top Port (TVD) not OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) (1 Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 4,286.2 3,537.4 25.91 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 8/12/2010 PLUG,4,995 i PRODUCTION 5.5"x38, 41-5,117 TD,5,126 • • •? , 6. 1 D -106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. V 5. 1C -133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. 4. 1C-10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' SLANNED JAN I 0 2011 Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A-07, 1A-12 and 1B-02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1 A -12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. TA:N. -DA-0 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. 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 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPhillips Well 1D-106 Injection Data • Tbg Psi IA Psi • OA Psi I 4000 3500 - 3000 - .°) 2500 c. a 2000 - 1500 - 1000 - 500 ••••••wwwes••••• 0 09/10 10/10 11/10 12/10 01/11 Date PTD 197 -240 Single casing (monobore) well. Reason: Failed MITIA 7/16/2010 Well last injected 6/10 08/11/10 - TxIA OMIT to 2500 psi passed 09/08/10 - LDL identified leak at 4297' • • ConocoPhillips Well 1D-106 Injection Data • Water Injection *Gas Injection I 4000 3500 3000 - .2 2500 - a a 2000 - 1500 - 1000 - 500 1 0 , 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 471 6 30- Dec -10 0 0 472 5 29- Dec -10 0 0 471 5 28- Dec -10 0 0 471 5 27- Dec -10 0 0 474 5 26- Dec -10 0 0 480 6 25- Dec -10 0 0 485 6 24- Dec -10 0 0 492 6 23- Dec -10 0 0 498 6 22- Dec -10 0 0 511 7 21- Dec -10 0 0 512 7 20- Dec -10 0 0 506 6 19- Dec -10 0 0 499 6 18- Dec -10 0 0 496 6 17- Dec -10 0 0 500 7 16- Dec -10 0 0 506 6 15- Dec -10 0 0 510 6 14- Dec -10 0 0 507 7 13- Dec -10 0 0 508 7 12- Dec -10 0 0 504 6 11- Dec -10 0 0 503 7 10- Dec -10 0 0 506 7 9- Dec -10 0 0 505 6 8- Dec -10 0 0 503 6 7- Dec -10 0 0 502 6 6- Dec -10 0 0 508 6 5- Dec -10 0 0 513 6 • . 4- Dec -10 0 0 513 7 3- Dec -10 0 0 522 7 2- Dec -10 0 0 527 7 1- Dec -10 0 0 525 6 30- Nov -10 0 0 524 7 29- Nov -10 0 0 536 7 28- Nov -10 0 0 541 7 27- Nov -10 0 0 542 7 26- Nov -10 0 0 546 7 25- Nov -10 0 0 549 7 24- Nov -10 0 0 552 8 23- Nov -10 0 0 554 7 22- Nov -10 0 0 551 7 21- Nov -10 0 0 549 7 20- Nov -10 0 0 549 7 19- Nov -10 0 0 547 7 18- Nov -10 0 0 549 7 17- Nov -10 0 0 543 6 16- Nov -10 0 0 538 6 15- Nov -10 0 0 538 7 14- Nov -10 0 0 549 7 13- Nov -10 0 0 567 7 12- Nov -10 0 0 569 7 11- Nov -10 0 0 571 7 10- Nov -10 0 0 572 7 9- Nov -10 0 0 578 7 8- Nov -10 0 0 581 7 7- Nov -10 0 0 582 7 6- Nov -10 0 0 586 7 5- Nov -10 0 0 589 7 4- Nov -10 0 0 583 6 3- Nov -10 0 0 581 7 2- Nov -10 0 0 586 7 1- Nov -10 0 0 590 7 31- Oct -10 0 0 589 7 30- Oct -10 0 0 589 7 29- Oct -10 0 0 587 7 28- Oct -10 0 0 583 7 27- Oct -10 0 0 588 7 26- Oct -10 0 0 591 7 25- Oct -10 0 0 595 6 24- Oct -10 0 0 595 6 23- Oct -10 0 0 595 6 22- Oct -10 0 0 593 6 21- Oct -10 0 0 589 6 20- Oct -10 0 0 650 6 19- Oct -10 0 0 597 6 18- Oct -10 0 0 594 6 17- Oct -10 0 0 592 6 16- Oct -10 0 0 591 6 15- Oct -10 0 0 592 6 14- Oct -10 0 0 593 6 • • 13- Oct -10 0 0 593 6 12- Oct -10 0 0 592 6 11- Oct -10 0 0 593 6 10- Oct -10 0 0 591 6 9- Oct -10 0 0 591 6 8- Oct -10 0 0 593 6 7- Oct -10 0 0 601 6 6- Oct -10 0 0 605 6 5- Oct -10 0 0 606 6 4- Oct -10 0 0 604 6 3- Oct -10 0 0 604 6 2- Oct -10 0 0 602 6 Page 1 of 1 • • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Saturday, July 17, 2010 3:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs; Gangl, Melissa A; Pierson, Chris R Subject: 1D -106 (PTD# 197 -240) Report Of Failed MITIA Attachments: 1D-106 Wellbore Schematic.pdf; 1D-106 TIO Plot.pdf Jim /Tom /Guy, West Sak injector 1D-106 (PTD# 197 -240) failed MITIAs on 7/16/10 and 7/17/10 as witnessed by Bob Noble and Lou Grimaldi. The well has been shut in since 6/5/10 for reservoir pressure management and will remain so until the TxIA communication can be repaired. The well will also be added to the monthly injector report. Attached are a welibore schematic and 90 TIO plot. 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 Cell 907 - 943 -1720 / 1999 AN o 2°11 Pager 907 - 659 -7000 #909 1/3/2011 Well Name 1D-106 Notes: End Date 8/1/2010 Days 120 Start Date 4/3/2010 Annular Communication Surveillance 1400 - - - - 160 WHP IAP OAP 1200 - WHT _ - 140 - 120 1000 - 100 800 LL %%"..••■■ - 80 y Q- - C 600 - - 60 400 - 40 200 20 -- N 0 Apr -10 May -10 Jun -10 Jul -10 350 ammoDGI 300 — .MGI 250 .PWI zoo ■IINOSWI u 150 - 0,01 BLPD ioo 50 0 Apr -10 May -10 Jun -10 Jul -10 Date MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 To: Jim Regg ~~~~ vl,i(~~ P.I. Supervisor ~ ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-106 FROM: Lou Grimaldi xuPAxux Illy u wsAx 1D-]o6 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1D-106 API Well Number: 50-029-22847-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG100717120224 Permit Number: 197-240-0 Inspection Date: 7/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-106 'TType Inj. N ' TVD 3630 .~ IA 720 ( 1700 _ 830 780 P.T.D 19rzaoo TypeTest SPT Test psi ]soo OA ~ Interval oTI->ER p/F F '~ Tubing zzo z6o 790 ~ Aso Notes: Retest of failed mit from yesterday. Results same indicating communication tubing/IA.., y~PjnfF_. ~ tii°ak -,t ~,., Tuesday, August 10, 2010 Page 1 of 1 C~ MEMORANDUM TO: Jim Regg rJ P.I. Supervisor ~ ~~~~ 7 t2~ Ct~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-106 KUPARUK RIV U WSAK ID-106 Src: Inspector NON-CONFIDENTIAL C~ Reviewed By: P.I. Suprv ~~ Comm Well Name: xUPARUx RIV U wsAx 1D-lob Insp Num: mitRCN100718133743 Rel Insp Num: API Well Number: so-o29-22847-00-0o Permit Number: 197-240-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We ~ 1D-106 ' Type Inj. N TVD 3630 '~ jA 80 1860 ~ 870 870 P.T.D 1972400 ~ TypeTCSt SPT TBSt pSl 1860 ~ OA Interval 4YRTST p~,^ F ~ TUbing 775 800 875 850 Notes: IA pressure starting bleeding right after shutting the pump down. ~~~~, Thursday, July 22, 2010 Page 1 of 1 IiV~~~ ~~ T~A~1/~11~/~4L a a. ob`EM WE((sA Q0 `P~. ~ 9i M - Pawlcntrt DuG+osric SERViCFS _. r _ u r:.. _,.~.,.. .. ~,: Ta Inc. State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and/or t ubtng Inspection(Cafiper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to tote following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road d~~~ ~~1R ~:' l~ ~~~ Suite C Anchorage, AK 99518 Fax (907j 245-8952 1 j Caliper Report /MIT 23-Fe1r09 1 D~117 1 Report / E~ 50-029-2284400 Caliper Report /MIT 24Feb-09 1 D~106 1 Report / EDE 50-029-22847-00 ~~''1 r~ ,~ ~, ,' 1 i Signed : ~ ,~~~ I ( !4 ,.._ ~~,~ \~_ Print Name: Date PROACTNE DIAGNOSTIC SERVICES, INC., 730 W. INTERNATIONAL AIRPORT RD SUt7'E C, ANCHORAQE, AK 99618 PHONE: (907245-8851 FAX: (907)245-88952 E-MAIL: ~~~§~.y~r~~a~4~~~ .e~~vyi~ WEBSRE ~,~ r;~,, :~fiCf't°~~ ,~~ °"1 C:\Documents and Sett'rugs\Owner\Desktop\T~ut_Conoco.docx ._-., ~ ~ S Memory Caliper & Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-106 Log Date: February 24, 2009 Field: Kuparuk Log No.: 10541 State: Alaska Run No.: 4 (2"d MlTl3`d MTT} API No.: 50-029-22847-00 Pipet Desc.: 3.5" 9.3 Ib L-80 ABM-EUE Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 4,446 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib L-80 MBTC Top Log Intvl.: Surface Pipet Use: Surface Casing Bot. Log Intvl.: 212 Ft. (MD) Pipe3 Desc.: 16° 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage Inspecfion COMMENTS This MTT data is tied into the Mandrel Hanger ~ 0' Depth. This is the second time this well has been logged with a PDS caliper and the third time with the 12 Arm Magnetic Thickness Tool (MTl'). The MTT responds to the total thickness of metal of the 3.5° tubing, 5.5° surface casing and 16" conductor pipe. Passes at SHz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz pass selected for analysis in this report. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall incxease or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. INTERPRETATION OF CALIPER LOG RESULTS This log was run to assess the condition of the 3.5" cubing with respect to corrosive and mechanical damage. The caliper recordings indicate the tubing is in good to poor condition with wall penetrations from 20% to 74% recorded throughout the log interval. Recorded damage appears as a shallow line of pits from 850', gradually growing to lines of deeper pits, lines of corrosion and broader areas of corrosion. No significant areas of cross-secfional wall loss are recorded. Although no significant LD. restrictions are recorded, the caliper recordings indicate buckling throughout the log interval. A 3-D log plot of the caliper recordings across an interval of buckling from surface to 1,000' is included in this report. A comparison of the current log to the previous (July 28, 2005) indicates an increase in corrosive damage during the time between logs. A comparison plot illustrating the difference in maximum recorded penetrations on a joint by joint basis during the time between logs is included in this report. 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits (74%) Jt. 86 ~ 2,734 Ft. (MD) Line of Pits (65%) Jt. 93 ~ 2,984 Ft. (MD) Line of Pits (63%} Jt. 79 ~ 2,539 Ft. (MD) line Corrosion (62%) Jt. 134.3 ~ 4,300 Ft. (MD) Line Corrosion (58%) Jt. 134 @ 4,242 Ft. {MD) 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL. METAL LOSS: ProActive Diagnostic Services, Inc. ; P.O. Box 1369, Stafford, TX 7749? Phone: (281) or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~~memory(og.com Prudhoe Ba`t Field Office Phone: (907} 659-2301 ~~~- {_ ~,% ~~(~ . _, No areas of signifi•cross-sectional wall loss (> 9%) are recorded. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. GOMPARtSON TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous (December 13, 2006 and October 5, 2007) indicates no significant change in metal loss as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous logs is included in this report. Over the past three years, various logging operational changes have been implemented in pursuit of improved data qualify for assessing outer concentric string damage with the MTT. Significant reduction in signal to noise ratio was achieved by reduclng logging speeds from 40 fpm to 20 fpm in early 2008. More recent MTT system development has inducted support for reducing the minimum recording frequency from 8Hz to 5Hz. This log represents the first field application of logging a pass at the lower 5Hz frequency. The 5Hz pass shows further reduction in signal to noise ratio and supports increased confidence that detailed signal deflections are more predse indications of speclfic features of outer pipe strings. A comparison of the current log data recorded at 5Hz to the previous data recorded at 10Hz shows no signficant change in areas where substantial metal loss has been indicated in previous logs. However, the lower signal to noise ratio apparent in the 5Hz pass supports increased clarity of features of the outer pipe strings. The interval of signficant metal loss indicated from -13' to ~23' in the previous logs is indicated very similarly in the current log, but the current 5Hz pass data shows a more consistent metal loss response through this interval. The ability of the 5Hz frequency to permeate more metal than the 10Hz frequency is believed to be responsible for a more stable tool response and provides a more tally representative picture of this interval of metal loss. In the 2007 and 2006 Togs, calibration samples were only taken within the concentric pipe that included the conductor. As a result, calculated metal thickness below the conductor appears to show metal loss due to the absence of the extra metal from the conductor pipe. The current log includes an additional calibration sample below the conductor that has been applied to that portion of the data, so the calculated metal thickness no longer reflects a loss due to the absence of the conductor. INTERPRETATION OF MTT LOG RESULTS The 5Hz MTT log results cover the interval from surface to 212'. Changes in metal volume are relative to the calibration points at 26' and 143', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points. A maximum overall metal volume toss of 16% is indicated in joint i (12' - 22') in the 5Hz pass. A log plat of the MTT recordings at 5Hz is included in this report. The Delta Metal Thickness (%) curve in this plot refers to total metal surrounding the MTT tool. The percent dreumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is spedfic to the 5.5" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5a tubing or 16" conductor. Field Fr~gineer: G. Etherton Analyst: J. Burton/M. Lawrence/HY. Yang WMess: C. F+tzpatrick ProActive Diagnostic Services, Inc. ! P.O. Bo>: 1369, Stafford, TX 77497 Phone: {281) or (888} 565-9Q85 Fa{: (281) 565-1369 E-mail: PQS,^a~memorylag.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907} 659-?314 ' • • ,~~ PDS Multifinger Caliper 3D Log Plot ' ~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-106 Date : February 24, 2009 i ~ Description : Detail of Caliper Recordings Across Interval of Buckling from Surface to 1,000' Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map ft:750R 2500 3500 0' 90` 180" 270' 0° 0` 90' 180° 270` 0' Min ID (1/1000 in.) 2500 3500 Nominal ID (1/1000 in.) 2500 3500 ~ ~~" Buckling 50 0 Joint 15 - i ~_, 550 Joint 16 i - __ :,. Joint 17 - -- -- - - - naw;w . 600 --- - , , '<. ~ , Joint 18 Buckling - Joint 19 ~,,. 650 ~-~ _ _ -, ~*' Joint 20 , ~ - -r- - .,~ .;_._ _ , Joint 2l 700 ... "'`~~~+.~_.w,, w,1c .:. ~.r6rairr Joint 22 ~ - , 750 - __ Joint 23 i a~ ,~„~ ~, ~~~ 800 _.. Joint 24 Buckling _,_ ,: , Joint 25 - - - - - 850 - - _ _. ~~"" Joint 26 ~ I `.. '- " Buckling - ~""d~F~+°- i J t 27 900 ~ ~ o n »....~,....~, - •~ ,, ...~.: - Joint 28 r , Joint 29 950 , ~ i __ _ ~.: , - Win:; u, :_~ :; Joint 30 -- --- ~ - ;_ . i .,, r, '. Nominal ID (1/1000 in.) :...........................................................................: 2500 3500 Min ID (1/1000 in.) 2500 3500 Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750ft 2500 3500 0° 90° 180° 270° 0° 0° 90° 180° 270° 0° Maximum Recorded Penetration 1--~, ~~ Comparison To Previous Well: 1 D-106 Survey Date: February 24, 2009 field: Kuparuk Prev. Date: July 28, 2005 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 218183 Country: USA Tubing: 3.5" 93 Ib L-80 ABM-EUE Overlay 0 5 Max. R 0 10 ec. Pen 0 15 . (mils) 11 ?0 0 X5 0 0.1 7 17 ~7 ;7 47 57 ~ 67 e z . e 77 o 87 97 107 117 - 1.'7 1 4 .. , --, ---~ ^ Felxuaro ?4, ?00') ^ luly 28. 2005 Difference Dill. in Max. Pen. (mils) -100 -50 0 50 100 E e Z .. .e -~'8 -14 0 14 _'fi Approx. Corrosion Rate (mpy) 1 ''7 37 47 57 6 97 117 1 4._ Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (38.5' - 4432.2') Well: 1 D-106 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 24, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 i 41 10 352 ZO ~ 665 30 ~~ 979 ~. 40 _ - ~ 1292 5U 1605 ~ ~ ~ 60 1916 g ~ ~ t% ~ 70 2232 Z - ~ c _ fl- ° 80 2547 ~ 90 2860 100 ,s=i-.- 3174 110 3489 120 ~ 3800 130 1 ~ I 4115 GLM 1 I ,. _ 138 4432 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 138 • ~ s. Well: 1 p-106 Field: Kuparuk Inc. CompanY~ ConocoPhillips Alaska, Country: USA 1 Wei~nt Grade &Thread Tubing: Nom.OD 9.3 f L-80 ABM-EUE 3.5 ins L Penetration and Metal Loss (% vraJl) metal loss body _ penetration body >~ 150 100 50 20 to 40 to over 0 p to 1 to 10 to 40% 85% 85% 1 % 10% 20% total = 146 1 Nu_ tuber of'oints an 41 ~ 33 45 0 gene. 05 111 0 0 0 0 loss '- Damage Configunti°n (body ) i PDS Report Overview Body Region Analysis February 24. 200 218183 Survey Date: 1.lW MFC 24 No. Tool TYPe~ 1.69 Tool Size: 24 No. of Fingers: M, Lawrence Anal st: UPPer len. Lower len. Nom. Upset 6.0 ins Nom.ID 6.0 ins 2.992 ins 3.5 ins e Profile (% wall) Damag metal loss body 100 _ penetration bodyn ~ 50 0 1 ~ 60 4t z ~~ line "'° iblehole isolated general eortosion corrosion corrosion 1 Pitting Number of ~oints dama i 9 total O 113 0 63 31 GLM 1 Bottom of Survey =138 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 D-106 Kuparuk Conoco Phillips Alaska, Inc. USA February 24, 2009 Joint No. )t. Depth (Ft) I'c~n. lJlxc~t (Ins.) Pen. Body (Ins.) Pen. % Metal loss %> Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 38 0 0.01 6 1 2.90 PUP 1 41 0 0.02 7 1 2.95 Sli ht Bucklin . 1.1 72 0 0.02 7 U 2.89 PUP 1.2 80 0 0.02 8 4 2.94 PUP 1.3 91 0 0.02 7 1 2.91 PUP 2 101 0 0.03 11 1 2.93 Bucklin . 3 132 0 0.02 7 1 2.93 4 164 0 0.02 9 2 2.93 5 195 0 0.02 7 2 2.94 6 226 0 0.02 7 0 2.93 Bucklin . 7 258 0 0.01 6 2 2.94 8 289 0 0.02 7 2 2.94 9 321 0 0.02 7 2 2.94 10 352 0 0.02 7 2 2.94 Bucklin . 11 383 0 0.02 7 1 2.93 12 415 0 0.01 6 1 2.94 13 447 0 0.02 9 1 2.93 14 478 0 0.02 7 2 2.94 Bucklin . 15 510 0 0.02 7 1 2.93 16 541 0 0.02 8 2 2.93 17 573 0 0.02 7 1 2.94 18 604 0 0.03 12 2 2.94 Bucklin . 19 634 0 0.02 7 1 2.94 20 665 0 0.03 11 2 2.94 21 697 0 0.02 7 1 2.94 22 728 0 0.02 7 1 2.94 23 759 0 0.02 7 1 2.94 24 791 0 0.02 9 2 2.94 Bucklin . 25 821 0 0.02 9 1 2.93 26 853 0 0.03 13 2 2.93 Shallow Line of Pits. Bucklin . 27 884 0 0.04 14 1 2.94 Shallow Line of Pits. 28 916 U 0.04 15 1 2.94 Shallow Line of Pits. 29 947 0 0.04 17 2 2.93 Shallow Line of Pits. 30 979 0 0.04 17 1 2.94 Shallow Line of Pits. 31 1010 0 0.04 18 2 2.95 Shallow Line of Pits. Bucklin . 32 1041 0 0.04 15 1 2.94 Shallow Line of Pits. 33 1073 0 0.05 20 1 2.94 Shallow Line of Pits. 34 1104 U 0.04 15 2 2.94 Shallow Line of Pits. 35 1136 0 0.04 17 1 2.93 Shallow Line of Pits. 36 1166 0 0.05 19 2 2.94 Shallow Line of Pits. Bucklin . 37 1197 0 0.04 15 2 2.94 _ Shallow Line of Pits. 38 1229 t) 0.05 19 2 2.90 ___ Shallow Line of Pits. Lt. De osits. 39 1260 0 0.05 19 2 2.94 Shallow Line of Pits. 40 12 2 0 0.04 14 2 2.95 Shallow 'ne of Pits. 41 1323 0 0.03 13 2 2.94 Shallow corrosion. 42 1355 0 0.05 20 1 2.93 Shallow Line of Pits. 43 1385 0 0.04 14 1 2.96 Shallow Line of Pits. Bucklin . 44 1417 0 0.06 23 2 2.95 Line of Pits. 45 1449 0 0.06 24 2 2.94 Line of Pits. 46 1480 0 0.06 23 2 2.94 Line of Pits. Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 D-106 Kuparuk Conoco Phillips Alaska, Inc. USA February 24, 2009 Joint No. )t. Depth (Ft.) Pen. Ups<°t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1512 0 0.05 19 2 2.93 Shallow Line of Pits. 48 _ 1542 0 0.06 24 1 2.95 Line of Pits. 49 1574 O 0.05 21 2 2.94 Line of Pits. 50 1605 0 0.06 24 Z 2.94 Line of Pits. Bucklin . 51 1637 0 0.06 23 2 2.93 Corrosion. 52 1666 0 0.05 20 2 2.94 Line of Pits. 53 1697 0 0. 5 19 1 2.94 Shallow Line of Pits. 54 1728 0 0.03 13 2 2.95 Shallow Line of Pits. 55 1759 0 0.07 26 1 2.96 Line of Pits. Bucklin . 56 17_90 U 0.05 20 1 2.95 Shallow Line of Pits. 57 1822 0 0.05 19 2 2.94 Shallow Line of Pits. 58 1853 0 0.05 21 2 2.95 Line of Pits. 59 _ 1885 0 0.05 19 2 2.96 Shallow Line of Pits. 60 1916 0 0.05 19 2 2.95 Shallow Line of Pits. Bucklin . 61 1.948 0 0.04 17 2 2.95 Shallow Line of Pits. 62 1980 0 0.05 19 1 2.93 Shallow Line of Pits. 63 2011 0 0.04 17 3 2.95 Shallow Line of Pits. 64 2043 0 0.03 13 2 2.93 Shallow Line of Pits. 65 2074 () 0.06 25 1 2.95 Line of Pits. Bucklin . 66 2105 0 0.04 18 1 2.94 Shallow Line of Pits. 67 2137 () 0.04 14 L 2.96 Shallow Line of Pits. 68 2169 U 0.03 11 2 2.96 69 2200 0 0.04 18 2 2.94 Shallow Line of Pits. 70 2232 t) 0.03 12 2 2.94 Bucklin . 71 2263 t) 0.03 13 1 2.93 Shallow Line of Pits. 72 2295 0 0.03 12 1 2.96 7 2326 U 0.13 53 4 2.93 Line of Pits. 74 2358 0 0.03 10 2.95 75 2389 0 0.09 35 ; 2.97 Line of Pits. Bucklin . 76 2421 U 0.13 50 4 2.94 Line of Pits. 77 2452 0 0.11 44 4 2.94 Line of Pits. 78 2484 0 0.06 L5 2 2.95 Line of Piss. 79 2515 0 0.16 63 4 2.96 Line of Pits. 80 2547 0 0.06 22 Z 2.96 Line of Pits. Bucklin . 81 2578 0 0.12 46 4 2.96 Line of Pits. 82 2609 0 0.05 18 1 2.94 Shallow Line of Pits. 83 2640 0 0.12 46 5 2.96 Corrosion. 84 2671 0 0.06 24 2 2.93 Line of Pits. 85 _ ___2703 0 0.10 37 4 2.93 Corrosion. Bucklin . 86 2734 0 0.19 74 7 2.96 Line of Pits. 87 _2765 0 0.09 34 ; 2.93 Line of Pits. 88 2797 (1 0.11 44 5 2.96 Corrosion. 89 2828 O 0.11 42 4 2.95 Corrosion. 90 2860 0 0.10 40 5 2.96 Corrosion. Bucklin . 91 2891 0 0.09 36 3 2.94 Corrosion. 92 2923 0 0.14 56 3 2.92 Corrosion. 93 2954 0 0.17 65 4 2.95 Line of Pits. 94 _ 2985 _ 0 0.11 44 4 2.95 Line of Pits. 95 3017 0 0.15 57 4 2.93 Corrosion. Bucklin . 96 3048 t) 0.13 53 5 2.94 Line of Pits. Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: Body Wall: 0.254 in field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEEP 1 D-106 Kuparuk ConocoPhillips Alaska, Inc USA February 24, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Ut~se~t (Ins.j Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3080 0 0.12 46 4 2.94 Line o Pits. 98 3112 0.08 0.12 46 4 2.93 Corrosion. 99 3143 0 0.12 46 5 2.95 Corrosion. 100 3174 0.07 0.11 43 :3 2.93 Corrosion. Bucklin . 101 3206 0 0.09 35 3 2.94 Line of Pi . 102 3237 0.08 0.11 42 5 2.94 Corrosion. 103 3269 0.05 0.10 41 4 2.95 Corrosi n. 104 3300 l) 0.12 48 5 2.94 Corrosion. 105 3332 0.03 0.12 48 5 2.97 Corrosion. Bucklin . 106 3363 0.06 0.09 37 3 2.96 Line of Pits. 107 3394 0 0.13 50 4 2.94 Corrosion. 108 3426 0.05 0.10 39 3 2.94 Line corrosion. 109 3457 0 0.10 37 5 2.96 Corrosion. Bucklin . 110 3489 () 0.09 35 4 2.94 Corrosion. 111 3519 0.08 0.09 36 3 2.95 Line corrosion. 112 3549 0.06 0.09 :37 3 2.94 Line corrosion. 113 3580 0 0.08 33 4 2.95 Line corrosion. 114 3612 0.07 0.11 41 4 2.97 Corrosion. 115 3643 0 0.11 42 4 2.95 Line corrosion. Bucklin . 116 3674 0.05 0.12 47 3 2.93 Corrosion. 117 3706 O.U7 0.10 40 4 2.96 Line corrosion. 118 3737 0.06 0.09 35 4 2.94 Line corrosion. 119 3769 0.06 0.12 48 4 2.94 Line corrosion. 120 3800 0.05 0.10 41 5 2.95 Corrosion. Bucklin . 121 3832 0.08 0.12 47 5 2.91 Corrosion. 122 3863 0 0.12 46 4 2.96 Line corrosion. 123 3895 U.1 1 0.09 34 5 2.94 Line corrosion. 124 3927 0 0.09 35 4 2.97 Line corrosion. 125 3957 0.10 0.11 45 5 2.93 Corrosion. 126 3989 0 0.11 43 0 2.94 Line corrosion. Bucklin . 127 4021 0 0.11 42 5 2.96 Corrosion. 128 4052 U 0.13 53 5 2.92 Corrosion. 129 4084 O.U9 0.14 54 5 2.93 Line corrosion. 130 4115 0 0.12 48 4 2.94 Corrosion. Bucklin . 131 4146 0.1 U 0.13 50 6 2.93 Corrosion. 132 4177 0.1 U 0.13 51 5 2.94 Line corrosion. 133 4208 0 0.12 48 5 2.94 Corrosion. 134 4239 0.08 0.15 58 6 2.95 Line corrosion. Bucklin . 134.1 4271 U .0.10 39 3 2.93 PUP Line of Pits. 134.2 4286 0 0 0 0 N A GLM 1 Latch ®11:00 134.3 4292 0.12 0.16 62 9 2.98 PUP Line corrosion. 135 4307 0.09 0.14 54 (i 2.98 Line corrosion. 135.1 4339 U 0 0 O 2.81 W-1 Ni le 136 4341 0.06 0.13 50 6 2.91 Line corrosion. Lt. De osits. 136.1 4371 0 0.09 36 3 2.94 PUP Line of Pits. 136.2 4377 0 0 0 0 2.99 Seal Assembl 136.3 4395 0.07 0.08 32 9 2.97 PUP Line of Pits. 137 4401 0 0.14 57 7 2.79 Line corrosion. De osits. 138 4432 0.10 0.12 46 2.86 Corrosion. Lt. De sits. _. Penetration Body Metal Loss Body Page 3 ~c~ ,. PDS Report Cross Sections Well: 1 D-106 Survey Date: February 24, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size; 1.69 Country: USA No, of Fingers: 24 Tubing: 3.5 ins 9.3 ppf_ L-80 ABM-EUE Anal st: M. Lawrence Cross Section for Joint 86 at depth 2734.45 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 93 Tool deviation = 51 ° Finger 13 Penetration = 0.187 ins Line of Pits 0.19 ins = 74% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 r~ rr r~ rlr rr r~ rr r rr r r rr rr r~ r~ rr r^i rr rr `c.~ PDS Report Cross Sections Well: 1 D-106 Survey Date: February 24, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 ppf L-80 ABM-EUE Analyst: M. Lawrence Cross Section for Joint 93 at depth 2983.54 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 Tool deviation = 53 ° Finger 6 Penetration = 0.166 ins Line of Pits 0.17 ins = 65% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 ' ~ Comparison to Previous ~ Logs Overlay `~'`~- Februar 24, 2009, October 5, 2007 and December 13, 2006 ~CENE ~IAgI'IOSI~C SEMCB~ \~. ' Database File: mytest.db Dataset Pathname: merge Presentation Format: 24COMP--1 Dataset Creation: Thu Feb 26 14:50:16 009 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Mtl Thickness 2007 (%) 50 -50 Delta Mtl Thickness 2006 (%) 50 ' -50 Delta Mtl Thickness 2009 (%) 50 0 _:.; 4 Delta Metal Thickness 2006 I I I I I Delta Metal Thickness 2007 'I V 20 Delta Metal Thickness 2009 ' 30 s i I ^-. ~ ~-- ~ - ~ 50 nductor. 100 110 120 1 130 140 ' 50 1 1 60 170 ' ' 180 Delta Metal Thic kne ss 2006 0 Delta Me tal Thickness 2007 200 Dena Metal Thickness 2009 -50 Delta Mtl Thickness 2007 (%) 50 -50 Delta Mtl Thickness 2006 (%) 50 -50 Delta Mtl Thickness 2009 (%) 50 210 1 D-~6 Recorded Magnetic Thick~ss Log Data - 5Hz Pass ~` Surtace to 212' February 24, 2009 PwoA~~ive Diwgnnsric SeNic~, Inc. Database File: 1d-106.db Dataset Pathname: SHzPass.1 Presentation Format: 1.4 scale Dataset Creation: Wed Feb 2510:17:01 2009 by Calc Warrior 7.0 STD Cas Charted by Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.4 MTT Phase Shift -Sensor 01 (5 Hz) (rad) 11.4 0 LSPD {ft/min) 200 -7.4 MTT Phase Shift -Sensor 12 {5Hz) {rad) 2.6 ~_ ~ '--~T-~ Tree ~ HarxJer ~~-. d 3.5" Collar ~ ~ ~ Delta Metal Thickness Jt. 1 6°/u Metal Loss 20 3.5" Collar - 3.5" Collate Pup Jt. 40 3.5" Collate I ' Collar Pup Jt. Pup Jt. 60 5" Collar Jt.2 of 16" Con -1 tiU Collar I' KUP ConocoPhillips we~~ nmw~s ,~1, I,v..:: ',WeaDOre APWWI 19dd Name Wa~StaM Pr'otllllli I 500292280700 WEST SAK INJ PWI , ... ~ 'COmmert H23lppal) Dri Amotatlon 13x1 Date ~~~ - SSSV: NONE Last WO: W -1 / 985Q 55 AN, atic-omai __ _ _ M~danan DefptlRlf6) 9tUDae Amohtlon Last Tag.- F1MD 4,7140 fil2612006 Rev Reason: FORMAT UPDATE Gasin~ Strings CONDDezcrlDUOn ~j9rnn~g = 15gf~~lltlm) 1Dephlf_ SM Degh10T 49.10 1 D-106 Top lR~) m^ol 1-1 Descrlpaar Caranae RV1 Date ID Dry 4,995.0 4,21. 18.62 PLUG Driable bridge p g -4800' - 3 112" FIalRwrton. Bridge plug 7!19/1 ~8 .992 was dried out by CTU pushed to bottom ~ 4995' RKB. Zar I Dee IPERF, 6,~67~ 496 IPERF, a,s3o-e,sro Verve l.attlr a.n9a,rsa PLUG. a 995 Commera LNJER 5 5 x 15, 45,111 TD, 5.17fi • • ~~~L ~~~ 1"R~4/U~IVI/TT,4L ~: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 ~;~~,,~ NC~~t ~ ~A Z4G7 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) ~ 1r ,. _... .. The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road (J 3 C- 1°l~' ! Joel Suite C Anchorage, AK 99518 Fax: (907j 245,8951 1) MI? 05-0ct-07 1 D-106 1 Report 50-029-22847-00 2) NffT' 05~Oct~7 1 D~114 1 Report 50-029-22908-00 - ' ',~ Signed . Date _~ n n .~~ _, ~ _ _ ~ ~ Print Name:~~il(~~,-Fi u, IVl l~a~...~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCNORACE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88852 E-MAIL : YSC,I D~yi~©g 3tIE'~6'i"~°S7-~'d'la<3S~ WEBSITE : `fl.'~fi!`;d T~~T,~~'dltsD.i.~3~'9 D:\Master_Copy_00_PDSANC-20zot\Z_Word\Distribution\Transmit(ei_SheeLslTransmit_Origmal_New.doc • • Memory Magnetic Thickness TQOI Log Results Summary Company: ConocoPhillips Alaska,lnc. Well: 1Q-105 Log Date: October S, 2~7 Fie~i: Kuparuk Log No.: 8536 State: Alaska Run No.: 2 API No.: 50-029-22847-00 Pipet Desc.: 3.5" 9.31b L-80 EUE 8RD Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log lntvl.: 192 Ft. (MD} Pipet Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surtace Pipet Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.58 ib. H-40 Welded Top Log lntvl.; Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.; 121 Ft. (MD) Inspec#ion Type : Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS : This MTT data is tfed into dte Mandr+ei Hanger ~ 0' Depth. This is the second log of this well with the 12 Arm Magnetic Thickness Tool {MTT). The Magnetic Thickness Taol responds to the total thickness of metal of the 3.5' tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represen# undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous (December 13, 2006) indicates no significant change in metal loss as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surtace to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness {%) curve in these plots refers to fatal metal surrounding the MTT tool. A maximum of 16% arcumferential metal loss is recorded in the interval between 12' - 22'. A maximum of 5% circumferential metal loss is recorded in the interval between 51' - 58'. A maximum of 3% circumferential metal loss is recorded in the interval between 61' - 70'. A maximum of 2% arcumferential metal loss is recorded in the interval between 71' - 72'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" producction casing, the percent metal loss from that pipe atone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: K. Miller Analyst: M. Lawrence & J. 8un`on Witness: C. Kennedy ProActive Diagnostic Services, Inc. f P.G. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (~81) 565-1369 E-mail: PDSCa~memorylog.com Prudhoe Bay Field Gffice Phor?e: (907) 659-307 Fax; {907} 659-2314 Comparison to Previou~TT Log Overlay _L- October 5, 2007 and December 13, 2006 PIIOAL7~VE ~~1IIgNObl~t SEn-w.q ~IIC.. Database File: d:\warriorldatal1d-1061comp.db Dataset Pathnarr-e: merge Presentation Format: 2.4 comp Dataset Creation: Wed Oct 1010:39:44 2007 Charted by: Depth in Feet scaled 1:150 -50Delta Metal Thickness 2007 (%) 50 -50Delta Metal Thickness 2006 (%) 50 ~tal Thickness -10 1- J --~- Delta ~----i 0 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 -50Delta Metal Thickness 2007 (%} 50 -50Delta Metal Thickness 2006 (%) 50 Magnetic Thickness T~I (10 HZ Pass) --~ October 5, 2007 PwoAcihrc Dl~gnaadc Sewvlc0y Inc. Database File: d:Iwarriorldatal1d-10611d-106.db Dataset Pathname: 10hz.1 Presentation Format: 2.4 scale Dataset Creation: Sun Oct 07 21:02:06 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%} 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) ?00 -6.4 MTTP12 (rad) _ 3.6 ~-_1__ Tree F ~.,~.. ~ - -- ~° _ . - - T ~- - - -- - '~ g ~ - - - - -r- Ha-P~" - - ~ I up I ~~ -- - _. a=- 5" Metal 10 3.5" Jt. 1 20 3.5" Collar 30 ~~ 3.5" Collar Pup Jt. 5.5" Collar Pup Jt. 3.5" Collar -. j_ - .~. 5% Metal Loss Pup Jt. 5" Collar 3% Metal Loss I ~ ' ~ 2% Metal Loss 70 3.5.. Jt. 2 ~ttom of 16" Conductor TrT HO Magnetic Thickness T•I (10 HZ Pass) _ _ _ October 5, 2007 ~L-gN06iIC SEIN{G6~ ING. Database File: d:lwarriorldatal1d-10611d-106.db Dataset Pathname: 10hz.1 Presentation Format: 2.4 scale Dataset Creation: Sun Oct 07 21:02:06 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:50 -50 Delta Metal Thickness (%} 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 Tree ~~ i I I i Hanger _ ~~ Pup Jt. o 3.5" Collar 10 3.5" 6% Metal Loss Jt. 1 ~0 30 i 5" Co Pup Jt. 3.5" Collar 40 i.5"Collar Pup Jt. 3.5" Collar 50 5% Metal Loss Pup Jt. 3.5" Loss 2% Metal Loss 60 70 -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 TUBING (aa37s, OD:3.500, ID:2.992) SURFACE (aa37s, OD:5.500, VYI:15.50) NIP (4339.4340, OD:3.500) LINER (43765116, OD:3.500, 1Nt:9.30) Pert (4462-'~) Pert (4530.4570) Perf (45844600) Pert 1~~1 Pert (4722-4762) Pert (4779-4794) • ConocoPhillips Alaska, Inc. KRU 1 D-106 Descri lion Size To Bottom TVD Wt C3rade Thread I CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded SURFACE 5.500 0 4376 3629 15.50 L-80 MBTC 4462 -4496 3708 - 3740 WS D 34 4 8!1111998 IPERF 2 12' HC, DP, 180 tleg hasin 90 d orientation 4530 -4570 3771 -3808 WS C,WS 40 4 9/9/1998 IPERF 2 1/2" HC, DP, 180 deg B hasin 90 d orientation 4580 -4600 3818 -3837 WS A4 20 4 9/9/1998 IPERF 2112" HC, DP, 180 deg hasin 90 d orientation 4668 -4680 3901 -3912 WS A3 12 4 9/9/1998 IPERF 2 1/2" HC, DP, 180 deg as' 90 orientation 4722 - 4762 3952 -3990 WS A2 40 4 7!19/1998 IPERF 2 112" HC, DP, 180 deg asi 90 d orientation d779 - d79d d00R - d090 WS A? 15 4 7N 9H 998 IPERF 2 12' HC_ DP_ 180 dea was PLUG (49954996, OD:3.500) . . ~ ConocoPhillips Alaska RECEIVED .JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .!\Iaska Oil & Gas Cons. Commission Anchorage July 6,2007 .........."'.......".......... ..r""",.·.. ~, Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \QÎ,J-4-0 ; . r \jt 11 'l.QtJ7 L~('" f~N.\1eJ j .- ü~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/912007 10-106 197-240 2" na 3.2 6/9/2007 1 0-1 07 200-177 2" na 3.2 6/9/2007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/9/2007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/9/2007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-51 02 RE : Cased Hole/Open Holel Mechanical Logs and lor Tubing Inspection(Caliper I 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 : 1) 1 Report 2) 1 Report 3] 1 Report 4] 5] 6] 7) Signed: Print Name: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey SGA.N~~E!D: 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 t, 'í (\ 2nrrR ;;~) ~ ~1 . ~uu 1 0 - 1 06 10 - 122 13-Dec.Q6 U':¡:C-I~'T-õt:'fO r: 14-0ec.Q6 \..J:r Œ. I q "'6 - i 4./4 14-0ec.Q6 U¡é.;»O -~ '1 10 - 125A MTT Log MTT Log MTT Log j I . I ] V L, I ___~' \_/ ~~ (ì,' 1\/\ " . ( iJI.\ rì';:y41., ,I ,') I) V I t\J;1 " I! (). /\ .__~,,:,",~ 7- J ~ ._ ~~1 ._~-\.!'~.''''''"(.¡J.-, Ðête: .,' PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: :";,~,';,:}:,>;,}CCc·,3E'.':¡;}!·:O::\,:,:·:",·",,-.:c.;Y: WEBSITE :N',","P!JŒ:,:::?"L>?:;:0') D.IDO _ PDSANC·2DD6\Z _ W ordlDtstributionlTransrnittal_ SheetslTransrnit_ Original. doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 10-106 Log Date: December 13, 2006 Field: Kuparuk Log No, : 7630 state: Alaska Run No.: 1 API No,: 50-029-22847-00 Pipe1 Desc,: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 189 Ft. (MD) Pipe2 Desc.: 5,5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log I ntvl.: 189 Ft. (MD) Pipe3 Desc,: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl,: 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (NIetal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal ofthe 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3,5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 189'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 16% circumferential metal loss is recorded in the interval between 12' - 22'. A maximum of 5% circumferential metal loss is recorded in the interval between 51' - 58'. A maximum of 3% circumferential metal loss is recorded in the interval between 61' - 70'. A maximum of 2% circumferential metal loss is recorded in the interval between 71' - 72'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some ofthe metal loss indicated could be from either the 3.5" tubing or 16" conductor. RECEIVED Field Engineer: J, Halvorsen Analyst: M. Tahtouh & J. Burton PmÞ.ctíve Diagnostic Sell/ices, Inc ! P,O, Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: 565-1369 E-maii: PDS@r¡¡i3.!"!:eSYloQ.çprri., . . Prudhoe Bay Fie!d Office Phone: (907) 659-2307 Fax: ~~'l4J1I ôì LJdS Cons. CommIssIon Anchorage UId. ,q':f- e~Ò I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickness Tool (10HZ Pass) PnoAciIvE DIAqNOSTic SERvicES, INC. - Database Fíle: d\warrior\data\1d-106\after pro before las file 1d-106,db Dataset Pathname: 10hz, 1 Presentation Format: 2.4 scale Dataset Creation: Thu Dee 1412:38:432006 by Calc Sondex Warrior VTO Charted by: Depth in Feet scaled 1150 -... ..- -... ~ .-..- _. -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3,6 I T -20 lXi "- -10 I ~LineS I Tree Hanger .. -~~-------- -- Pup Jt --- ~ 1- - 35" Collar 10- "-- ~ þf= 10 = , / ".f' '7 ,ß 7' L·"/ /'/ ,/ [7 '/> l,þ.61 \-'6% Metal Loss 3.5" r I - Jt 1 :ij , 20 rç:: -.;¡¡ " f':- '.. '-- , r'-~ ~ ~ II I 30 ;: - ~ -- ... .- ,5" Collar- - ",--- -, - Pup Jt :;;;¡¡,¡¡¡¡ ¿!() ^---- ,-,,_., f.- 1-55" Collar ,,5" Collar- - - - i I ,-"" Pup Jt ..- 3,5" Collar .. - "in - 5% Metal Loss Pup Jt - - Rn .5" Colla I ~ - - -- I 11' ~ ~ 3% Metal Loss it I I T T 70 2o/~ Meta¥j 3,5" .. t"'m- I T 1 1 Jt 2 '--- ;:- ~~ =-~ --ªr!tºr °i~~ con:ctor ~.J ,.." __ V :r- l IT 7 :: ,~_ I-!_ <~ {t = >-. ,,_.I - I I I I I I I I fþ , "=- --, :> ;- 1_~''''5 5" Colla ---- t:§~, ::> - r- ~ -- ~ --.'''- I~ ; 90 ~ þ <:.. - "'4 ~ ,~- ~, - Q,5" Collar --- ,~ --., -,,-~ C"- ....m_ e-- ,,,- 100 I (. I 3,5" ! Jt. 3 ~- e---' , 110 # := - r-- :¡.. -"~_. - r-- " ;'i I;' ? , -- f---- $' 120 - "" i --., 1"1 j ~ ..- I ) 3,5" Collar t-- --., 130 14 i t-- -. : -- ~ t-- ~ --- 3,5" Jt. 4 ~ 140 ¡ ft f '- t--- 150 t I 4 im~r - " ~ ~ . I 160 0 ~T ;;¡: ~ ~ '- -- I ~r::,. ~ ......... ¡-- 3,5" 5.5" Collar Jt 5 ::::;¡. i:\:::? '-:::: <:::;> '" 170 ¡ ~. I [ - '-~ - -- ~ - i - - 180 -f--3,r.z°llar > ~<~ Iii! ~f--- '>1 -- ~ "- -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftlmin) -200 -6.4 MTTP12 (rad) 3,6 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 .CJ ~6. p~ DIAqN05J'Ic SERviCES, INC. Magnetic Thickness Tool (10 HZ Pass) Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: d\warrior\data\1d-106_1 12'-22'\after pro before las file 1d-106,db 10hz, 1 2.4 scale Thu Dee 1412:38:43 2006 by Calc Sondex Warrior VTO Depth in Feet scaled 150 . -50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 2.4 -6.4 MTTP01 (rad) MTTP12 (rad) 12.4 3,6 ¡-. Tree Hanger r-- 0 Pup Jt -- Ì'" - I I I I I I 3,5" Collar ( I 7 --~¡' <: I I ~ I :> \> -,j - ~ :~ .,..tr- ~ '~ ~,¡, ::;c, Line Speed < - 10 , lr/ I ( I I I'~'- I I I ~-16% Mer LrSS c-- I '\ .~, ¡ J / / ~ < ;:.. ~ ) j / / I J ~I t ,/ I/l / / <' II \ /1 I l_ 3,5" Jt 1 t ¿ \ \, ¡ ~ \ \ \ '\ \ {I" '\ ':' \ '1-) , 20 \ ì (\ (,\ ) '\ \ ~ !'l. L, ~: ~___M~~" ;, ~---_.,",. I ' MTTP01 (rad) MTTP12 (rad) 12.4 3.6 -50 Delta Metal Thickness (%) 50 o Line Speed (ftlmin) -200 2.4 -6.4 I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickness Tool (10 HZ Pass) ~ DIA.q"""",1c SERviceo, INC. Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: d\warrior\data\1d-106_2 50'-70'\after pro before ¡as file 1d-106,db 10hz. 1 2.4 scale Thu Dee 1412:38:43 2006 by Calc Sondex Warrior VTO Depth in Feet scaled 150 -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 :2.4 -6.4 MTTP01 (rad) MTTP12 (rad) 12.4 3.6 II ~I 1 I J I I 35" Collar I I I I - 5% Metal Loss I 50 ~~ Jfã_ I i1H S¡o- d. , - "'" 1;;-":: ;::=- - ¡,,,_..~. I ,,'" ':? I ~.'%L" I~ ; >.-r . ¡... ¡ 1 ¡ '*' - - Line Spee I I I I (rr I I-~~ ;;,5" Collar I '- 3,5" I ì ¡ ~ ':f ' [? (\ " .~ Pup Jt '-- (1 " ~~ .? i;>- (t;> '" 60 I 1 ?- " \ I ¿ I ~ ¡ I 0~ .,¿ =11 3% Metal Loss -" - ~. If-- 2% Metal Loss I 70 I I I ;;, ... ,. . ~ ,,- Î 3.5" Jt 2 ) ) ¡ ) I 1" ) ( .../1' "' Bottom of 16" Conductor / //1 '/ l// / 1// 1// // /' / //1 // "J ..j ,{ { i{ {I I f If If { l I f ( < I ".J::!Q.,.." -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3,6 I KRU 1 D-1 06 I 111"klflR < API: 500292284700 Well Tvoe: INJ Anale IâJ TS: deo IâJ TUSING / SSSV Type: None Orig 1/19/1998 Angle @ TO: 18 deg @ 5126 (0-4376, Comoletion: OD.3.500, Annular Fluid: LastW/O: Rev Reason: E-LlNE TAG TO ID2992) Reference Loa: Ref Loa Date: Last Uodate: 6127/2006 Last Taa: 4713 TO: 5126 ftKB SURFACE Last T 6/26/2006 Max Hole Anale: 50 de (0-4376, Casin OD.5,500, W(1550) DescriDtÎOn Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16,000 0 121 121 62.58 H-40 Welded SURFACE 5.500 0 4376 3629 15.50 L-80 MBTC LINER 3,500 4376 5116 4325 9.30 L-80 ABM-EUE IUBING< Size I Too I Bottom I TVD I Wt I Grade I Thread 3,500 I 0 I 4376 T 3629 I 9,30 I L-80 I ABM-EUE . Interval TVD lone Status Ft SPF Date Tvoe Comment NIP 4462 - 4496 3708 - 3740 WSD 34 4 8/11/1998 IPERF 21/2" HC, DP, 180 deg (4339-4340, ohasina, 90 dea orientation 00:3.500) 4530 - 4570 3771 - 3809 WS C,WS 40 4 9/9/1998 IPERF 21/2" HC, DP, 180 deg B nhasinn 90 deo orientation 4580 - 4600 3818 - 3837 WSA4 20 4 919/1998 IPERF 21/2" HC, DP, 180 deg nhasinn, 90 dea orientation 4668 - 4680 3901 - 3912 WSA3 12 4 9/9/1998 IPERF 21/2" HC, DP, 180 deg nhasinn 90 den orientation 4722 - 4762 3952 - 3990 WSA2 40 4 7/19/1998 IPERF 21/2" HC, DP, 180 deg nhasinn, 90 den orientation 4779 - 4794 4006 - 4020 WSA2 15 4 7/19/1998 IPERF 21/2" HC, DP, 180 deg LINER I nhasinn 90 den (4376-5116, OD.3.500, V MfrT V Type I V 00 I latch I Port I TRO T Wt9.30) ;¡¡ Man Type Date I Vlv SSE Mfr Run Cmnt (4377-4389, 1 BST AXT BST ì DMY I 3,5 I T-1 I 0,000 r 0 T6/15/1998 I 0004.000) Oth . Deolh TVD Tvoe Descriolion ID Perf - 4339 3595 NIP 3 1/2" W-1 w/selective nioDle 2.812 (4462-4496) - 4377 3630 SBE Baker locator seal assemblv stabbed into SBE 3.000 4995 4210 PLUG Drillable bridge plug - 4600' - 3 112" Halliburton, Bridge plug was drilled out 2,992 bv CTU nushed to bottom IâJ 4995' RKB. Perf 5116 4325 SHOE 3,000 (4530-4570) Perf - (4580-4600) -_.- Perf .-- (4668-4680) -- Perf -- (4722-4762) --. --- Perf --- (4779-4794) - PLUG I\ (4995-4996, 00:3.500) I I I I I I I I I I I I I I I I Scbllnbel'geP NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~. ~\i-^" , / .'-'~,t7''. j:C i~.' ·,i',i' 1*- "I r ~~~'; ~;..;' Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I C(} -;;)'-/0 U:I G Field: Kuparuk Well Job# Log Description Date BL Color CD Ñ ,/ 1 E-1 92 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-1{)5L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y -07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04106 1 1 H-04^ 11320991 INJECTION PROFILE 07/03/06 1 1D-10'1 N/A INJECTION PROFILE 06/27/06 1 2Z-13' 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy ofthis transmittal to Beth atthe above address or fax to (907) 561-8317. Thank you. 07/24/06 e e MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~ ~~ s~;;r~isor K:'¿f 11/ z) I Û.c DATE: Wednesday, July 12, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA fNC lD-106 KUPARUK RIV U WSAK !D- I 06 ~q 1..-';)..4-° FROM: JeffJones Petroleum Inspector Src: Inspector Reviewed By: I S "-;'SE'.- P.. uprv,_;;.- , Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-106 API Well Number 50-029-22847-00-00 Inspector Name: Jeff Jones Insp Num: miUJ0607I1174001 Permit Number: 197-240-0 Inspection Date: 7 II 0/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ! lD-106 ¡Type Inj. I W i TVD i , ! Well 3630 ! IA 300 I 1840 1790 ¡ 1780 I I I I 1972400 ITypeTest I SPT ¡ Test psi I OA I ! ! P.T. 1500 ! I I -L i I / Tubing ¡ I ! I Interval 4YRTST P/F P 1230 i 1230 1230 1230 ~ Notes Monobore injector, 0.8 bbls diesel pumped. I well house inspected; no exceptions noted. ~ -:-..._~ c'..... Wednesday, July 12, 2006 Page I of I SURFACE (0-4376, 00:5.500, Wt:15.50) NIP (4339-4340, 00:3,500) LINER (4376-5116, 00:3,500, Wt:9,30) SSE (4377-4389, 00:4,000) Perf (4462-4496) Perf (4530-4570) Perf (4580-4600) Perf (4668-4680) Perf (4722-4762) Perf (4779-4794) PLUG (4996-4996, 00:3.500) e e ConocoPhillipsAlaska, 'nc. '1D406 KRU 1 D-1 06 Bridge plug was drilled out by CTU ID 2.812 3,000 2.992 3,000 I --J I I I I I I I I I I ! ----! ---j I I i I ~ -j I =j ì i , I I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ) ) l q1'"'~ 12 4(1 1 Iz, 10 '5" Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak I KRUI 10-106 07126/05 Rodgers - AES Packer Depth Well 10-106 Type Inj. N TVD 3,630' Tubing P.T.D. 1972400 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. We1l1D-106 Type Inj. N TVD 3,630' Tubing P.T.D. 1972400 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: Pretest Initial 15 Min. 30 Min. 0 2050 1925 1900 Interval 0 0 0 0 0 P/F P 1900 2050 2050 2050 Interval 0 0 2550 2480 2480 P/F P Interval P/F Interval P/F Interval P/F SfC/\NNEJ) .AUG 0 9 20Œ) TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test MIT Report Form Revised: 06/19/02 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 10-106 07-26-05.xls MEMORANDUM TO: Randy Ruedrich Chair THRU' Jim Regg State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. P.I. Supervisor ' ) 06, 09, 106, 109, 111 FROM: John H. Spaulding ~ Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Welll 1D-06 P.T.D. I 1790960 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D,I Notes: WellI P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. IType,nj.I s I T.V.D. I~--~ I Tubing ] 1795 I 1790 11790 11790 I,nterva'l 4 TypetestI P ITestpsil 1566 I Casingl 1360I 25OOI 25OOI 249OI P/F I --P 1980650ITypetestl P ITestpsil 1538 I Casingl 390 I 2535 I 2520 I 2510 I P/F I P 1972400ITypetestl P I Testpsil 908 I Casingl 460 I 2620 I 2620 I 2610 I P/F I _.P 1972350 ITypetestl P ITestpsil 888 I Casingl POS. I 255°1 255°1 255°1 P/F I -P 1981660 ITypetestl P ITestpsil 893 I Casingl POS. I 25001 4OO I I P/F I F Type INJ. Fluid Codes F: FRESH WATER INJ. G = GAS I NJ. S - SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I- Initial Test 4= Four Year Cycle V= Required by Variance W- Test during Workover O= Other (describe in notes) .1DCl~had a positive pressure (basically 0 psi) when checked prior to rig up of the pump. The IA was pressured up to 2500 psi as noted and immediately started to bleed down. After 15 min. pressure was at 400 psi. Ultimately the IA went clear to 0 psi on the guage. As I was checking the IA the last time I noticed that diesel was coming up through the the hanger flutes. Approxiamtely 5 gals. over flowed into the cellar area. This was cleaned up. I contacted Tom Maunder and he suggested that the well be shut-in until CPAI offered a repair program to the AOGCC. Jerry Dethlefs Dethlefs CPAI rep. concurred with the shut-in advice. M.I.T.'s performed: _5 Number of Failures: 1_ Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. mit kru ld 6-20-03 jsl.xls 7/17/2003 Well Compliance Report File on Left side of folder 197-240-0 MD 05126 TVD 04335 Microfilm Roll / - KUPARUK RIV U WSAK 1D-106 50- 029-22847-00 PHILLIPS ALASKA INC Completion Date: r--~77T9/98 Completed Status: 1WINJ Current: Roll 2 / -- Name Interval Sent Received T/C/D D 8240 SPERRY MPT/GR/EWR4 OH 2/18/98 2/18/98 L CBL-SLIM c.4~[~L 4200-4965 ~/~ / ~ CH 5 7/24/98 7/24/98 L DGRJEWR4-MD ~'~AL 122-5126 l/Iq/c~g ~ [h(a~ OH 2/18/98 2/18/98 L 1NJP-SPINFFEM/ ~PREs 4410-4844 '20/~/~~ CH 5 4/22/99 5/13/99 R MWD SRVY ,.~qtxERhRY 0-5,126 OH 2/13/98 2/18/98 R SRVY CALCo//{ J~ '--//ttc/~/~?~ B.14-"I"~¥-5126. OH 7,27/98 7/30/98 Was the well cored? yes~ Analysis Descrip~~' Sa~~ Comments: Tuesday, August 01, 2000 Page 1 of 1 ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ECEJVED Alaska 0ii & Gas Cons. Commission Anchorage Subject: 1D-106 (Permit No. 97-240) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak iD-106. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad , '- -~ ' STATE OF ALASKA ~_ .r ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~---~ ~ ~"' 1 Status of Well Classification of Service Well ~ '~ [= "~ OIL ~ GAS ~ SUSPENDED ~ ABANDONE~ SERVICE ~ Injector 2 Name of Operator 7 Pe~it Number ARCO Alaska, Inc 97-240 NaS~ 0il & ~as 3 Addr~s 8 APl Number A~0~0~8~ P.O. Box 100360, Anchorage, AK 99510-0360 . ~~ 50-029-22847 4 Location of well at sudace ~ ry.. ..............~~ 9 Unit or Lease Name 104' FSL, 595' FEL, Sec. 14, T11N, R10E, UM ~' . ~A, 7~ ~ ~ ;,_~~~ Kuparuk River Unit At Top Producing lnte~al ~~~t~~~~1 10 WellNumber ~924' FSL, 2~4' ~L, Sec. ~3, T~N, R~0E, UM ~ V~J~I~ ~ j~~ ~' W~t Sak ~D-~06 At Total Depth j 11 Field and Pool 2124' FSL, 375' ~L, Sec. 13, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease D~ignation and Sedal No. W~t Sak Oil POol RKB 41', Pad 71'~ ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp, or Ab~nd. ~ 15 Water Depth, if offshore ~ 16 No. of Completions 13-Jan-98 15-Jan-98 ~ 7~~~ NA feet MSLII 1 . . 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Suwey 20 Depth where SSSV set 21 Thic~ of pe~afrost 5126' MD & 4335' TVD 5021' MD & 4235' ~D YES ~ NO ~ NA feet MD 1529' APPROX 22 Type Electric or Other Logs Run G~Res 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD I CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT ~ECO~D 16' 62.58~ H-40 SURF. 121' 24' 9 cu yds High Early 5.5' x 15.5~ L-80 SURF. 4375' 8.5' 414 sx AS III LW, 435 sx Cla~ G, & 3.5' 9.3~ L-80 4375' 5117' 8.5' 60 sx AS I 24 Pedorations open to Production (MD+~D of Top and Bo~om and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ~7~'-47~2' MD 3952'-397~' ~D 3.5' 4378' 4742'-4762' MD 3971'-3990' ~D 4779'-4794' MD 4006'-4020' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf Date First Production IMe,,od of OperatiOnlnjector(Flo~ng, gas lift, etc.) t Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MOF WATER-BB[ CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Oasing Pressure OALCU~TED OIL-BBL GAS-MOF WATER-BB[ OIL 8RAVITY-API (corr) Press. 24-HOUR RATE: 20~ 28 OORE DATA B~ef desc~ption of lithology, porosity, fractures, apparent dips and pr~ence of oil, gas or water. Submit core chips. N/A ED L Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ _, 30. ~- GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 4458' 3704' Base West Sak Sand 4932' 4151' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drillin~ Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 2/20/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-106 WELL_ID: AK8973 TYPE: AFC: AK8973 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:01/13/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22847-00 01/13/98 (D1) TD: 170'(170) SUPV:DEB 01/14/98 (D2) TD: 3343'(3173) SUPV:DEB 01/15/98 (D3) TD: 5126' (1783) SUPV:DEB 01/16/98 (D4) TD: 5126'( SUPV:DEB 01/17/98 (D5) TD: 5126'( SUPV:DEB o) o) 01/18/98 (D6) TD: 5126'( SUPV:DEB o) 01/19/98 (D7) TD: 5126'( SUPV:DEB o) MW: 8.8 VISC: 360 PV/YP: 34/42 APIWL: 7.6 DRILLING AT 526' Move rig from 1D-109 to 1D-106. Accept rig @ 1630 hrs 1/13/98. NU diverter system. Function test. Spud in at 121' and drill to 170' MW: 9.1 VISC: 345 PV/YP: 28/58 APIWL: 9.6 DRILLING @ 3550' Drill from 170' to 3343' MD. Tight and swabbing at 2364' MW: 9.1 VISC: 310 PV/YP: 25/51 APIWL: 8.8 POH FOR HOLE OPENER-WIPER TRIP Wash & ream through bridges at 1942' and 2567' Drill from 3343' to 5126' MD. MW: 9.2 VISC: 265 PV/YP: 28/48 APIWL: 7.2 PUMPING 1ST STAGE CEMENT JOB Hold pre-job safety meeting. Run 3.5" x 5.5" casing. MW: 9.0 VISC: 40 PV/YP: 12/ 8 APIWL: 20.0 POH LD 2-7/8" DP Run 5.5" x 3.5" casing. Pump 1st and 2nd stage cement job. ND diverter system. NU tubing head. NU BOPE and test. Drill cement to 1906', drill out plug & stage tool to 1909', wash down to 1956' MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MU TUBING HANGER & LANDING JT Run 3.5" completion string. Debris from drilling out stage tool lodged in sealbore. Clean out. MW: 6.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" completion string. Freeze protect well with diesel. ND BOPE. NU tree and test to 5000 psi, OK. Release rig @ 1200 hrs. 1/19/98. End of WellSummary for Well:AK8973 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-106(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-106 RESV DATA GATHERING 0718982202.1 DATE DAILY WORK UNIT NUMBER 07/19/98 PERFORATE "A3 / D" SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-STEPHENSON SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 100 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY RAN 2-1/2" HC, DP, 4 SPF, 180 DEG PHASING, 90 DEG ORIENT FROM LOW SIDE. PERF ASSEMBLY #1, 15'. PEERFORATE 3- 1/2" LINER F/4794' - 4779'. RUN #2, 20' PERF ASSEMBLY PERFORATE F/4762' - 4742'. RUN #3 PERF ASSEMBLY PERFORATE F/4742' - 4722'.[Ped] TIME 08:00 09:15 LOG ENTRY MIRU SWS (STEPHENSON AND CREW) TGSM. COMMUNICATION. NOTIFIED ALL PERSONNEL ON LOCATION OF OPERATIONS.MU PRF ASSEMBLY #1.2-1/2" HC 15', DP, 4 SPF, 180 DEG PHASING, 90 DEG ORIENT F/LOW SIDE. ( 2-1/2" GUN, SAVE, MPD, CCL, ) TL 30'. PT 3000 PSI. Rill. TIE IN WITH SCHLUMBERGER CMT LOG DATED 7/6/98. PERFORATE 3-1/2" LINER F/4794' - 4779'. GOOD SURFACE INDICATIONS POH. 10:30 AT SURFACE, RD. ALL SHOTS FIRED. MU #2 PERF ASSEMBLY 20 GUN, SAME AS ABOVE. TIE IN AND PERFORATE 3-1/2" LINER F/4762' - 4742'. GOOD SURFACE INDICATIONS. POH. 12:15 AT SURFACE RD. ALL SHOTS FIRED. MU #3 PERF ASSEMBLY, 20' GUN. SAME AS ABOVE. RIH. TIE IN AND PERFORATE 3-1/2" LINER F/4742' - 4722'. GOOD SUFACE INDICATIONS. POH. 14:30 AT SURFACE RD. ALL SHOTS FIRED. LEAVE WELL SHUT IN FOR ZONE TESTING. NOTIFIED DSO. I " SURVEY CALCULATION AND FIELD WORKSHEET i ~I JobNo. 0450-93471 9idetrackNo. ~ Page 1 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. 1D-PAD/1D-106(DS) Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. ~Jlll~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S 104.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~I Target Description Target Coord. E/VV Slot Coord. E/W -595.00 Magn, Declination 27.750 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert, Sec. Azim, 25.58 Magn. to Map Corr. 27.750 Map North to: OTHER SURVEY DATA I Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (F'r) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0,00 0.00 0.00 0,00 0,00 0.00 TIE IN POINT . _ . 14-JAN-98 MWD 121,00 0,00 0.00 121,00 121.00 0.00 0.00 0.00 0,00 0,00 6 3/4"MACH 1C-AKO-1.4 DEG, 14-JAN-98 MWD 259.00 1.50 42,00 138,00 258.98 1,73 1,34 1.21 1,09 1,09 ****GYRO**** .... 14-JAN-98 MWD 488,56 0.34 27.28 229.56 488.51 5,30 4.18 3,53 0.51 -0,51 14-JAN-98 MWD 652,43 0.12 142.84 163.87 652,38 5.70 4.48 3.86 0.25 -0,13 14-JAN-98 MWD 924,96 0.15 206,83 272.53 924.91 5,22 3.93 3.87 0,05 0,01 14-JAN-98 MWD 1016,05 4,03 45,04 91,09 1015,93 8.12 6.09 6,08 4.58 4,26 14-JAN-98 MWD 1107,80 7.07 38,55 91,75 1107.24 16,66 12,78 11,88 3,38 3,31 -7,07 14-JAN-98 MWD 1202.46 11,30 36.46 94.66 1200,66 31,45 24.80 21,03 4,48 4.47 -2.21 14-JAN-98 MWD 1297.81 16.03 34,86 95,35 1293.29 53,63 43.13 34,11 4,98 4,96 -1.68 14-JAN-98 MWD 1394,01 18,38 31.70 96.20 1385,18 81.82 66.94 49.68 2,63 2.44 :3.28 14-JAN-98 MWD 1488,80 20,73 30,26 94,79 1474.49 113,41 94.14 65.99 2,53 2,48 -1,52 14-JAN-98 MWD 1584,39 24,01 28.48 95,59 1562.88 149,70 125.86 83.79 3,50 3.43 -1.86 14-JAN-98 MWD 1676.90 26,05 27,88 92,51 1646.70 188,80 160,36 102.27 2.22 2,21 -0,65 ill'' 14'JAN'98 MWD 1773,89 30.40 26.08 96.99 1732,14 234,64 201 .25 123.02 4,57 4.48 '1.86 14'JAN'98 MWD 1870,11 35,61 25.64 96,22 1812,80 287.04 248.40 145,86 5.42 5,41 '0,46 14-JAN'98 MWD 1966,68 39,49 25.24 96.57 1889.35 345,88 301 .54 171.13 4,03 4,02 '0,41 14'JAN'98 MWD 2061 ,72 43,30 25,44 95,04 1960.63 408.71 358.33 198.03 4.01 4.01 0.21 14-JAN'98 MWD 2156,71 48.41 26.21 94,99 2026,77 476.85 419.66 227,73 5,41 5,38 0,81 14'JAN'98 MWD 2438.67 48,53 25,36 281 ,96 2213,71 687.92 609.71 319,54 0.23 0.04 '0.30 14'JAN'98 MWD 2723,36 47.45 27,57 284.69 2404.26 899,40 799,07 413.77 0,69 '0,38 0.78 14-JAN-98 MWD 3007,41 49,78 27,62 284,05 2592.03 1112,37 987.93 512.48 0.82 0.82 0.02 14-JAN'98 MWD 3286.57 50,09 20,84 279,16 2771 ,84 1325,73 1182.56 600.04 1 .86 0,11 '2,43 I 5-JAN'98 MWD 3384,07 45,55 22.71 97.50 2837,29 1397,80 1249,65 626.80 4.87 '4.66 1 ,92 i I I SURVEY CALCULATION AND FIELDWORKSHEETJob No. 0450-g3471 Sidetrack No. Page 2 of 2 ~=ll_rr3-'l ::~-,~ Company ARCO ALASKA, INC. Rig Contractor& No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. 1 D-PAD/1D-106(D6) Survey Section Name Definitive Survey BHI Rep..ROBBY BARNARD. IN~~ WELL DATA Target TVD (~T) Target Coord. N/S Slot Coord, N/S 104.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -595.00 Magn, Declination 27.750 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert, Sec. Azim, 25.58 Magn. to Map Corr, 27,750 Map North to: OTHER SURVEY DATA -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT) (FT) (FT) (Per ~00 FT) Drop (-) Left (-) -- 1 5-JAN-98 MWD 3479.20 42.02 22.31 95,13 2905.96 1463,52 1310,45 652,00 3.72 -3,71 -0.42 6 3/4"MACH 1C-AKO-1.4deg, 1 5-JAN-98 MWD 3668.60 41.54 21.56 189,40 3047.20 1589.45 1427,50 699,14 0.37 -0.25 -0.40 1 5-JAN-98 MWD 3857.35 40,68 24.85 188,75 3189.43 1713,41 1541,54 748,00 1.23 -0,46 1.74 1 5-JAN-98 MWD 3951,51 37,49 24,25 94,16 3262.51 1772,76 1595,53 772,67 3.41 -3.39 -0.64 15-JAN-98 MWD 4047.59 34,45 25,96 96.08 3340,26 1829,18 1646.63 796,58 3.33 -3.16 1.78 15-JAN-98 MWD 4141.65 31,38 25.69 94,06 3419.21 1880.28 1692.63 818.85 3.27 -3,26 -0,29 15-JAN-98 MWD 4235.35 27.44 25,97 93.70 3500,82 1926.28 1734,04 838.89 4,21 -4,20 0.30 15-JAN-98 MWD 4330.37 23.56 25,18 95,02 3586,57 1967,18 1770,92 856,56 4.10 -4.08 -0.83 15-JAN-98 MWD 4520.35 21.45 22,65 189.98 3762.07 2039,85 1837,35 886,10 1.22 -1.11 -1,33 15-JAN-98 MWD 4614.76 18.95 25,40 94,41 3850,67 2072.43 1867,14 899.32 2,83 -2,65 2.91 15-JAN-98 MWD 4710.05 18,68 25.59 95.29 3940.87 2103,16 1894.88 912,55 0,29 -0.28 0.20 15-JAN-98 MWD 4803.60 19.06 25,44 93,55 4029,39 2133,42 1922.18 925,58 0,41 0,41 -0.16 15-JAN-98 MWD 4898.11 18.96 24.85 94,51 4118.75 2164.20 1950,05 938.66 0.23 -0,11 -0,62 15-JAN-98 MWD 4992.57 18.62 24,44 94.46 4208,17 2194,62 1977.70 951.35 0,39 -0.36 -0,43 15-JAN-98 MWD 5076.46 18,48 23.09 83,89 4287.70 2221.29 2002.12 962,11 0,54 -0,17 -1,61 15-JAN-98 MWD 5126,00 18,48 23.09 49,54 4334.69 2236.98 2016,57 968,27 0,00 0.00 0,00 PROJ*BHC=2236,98'@ 25,65deg, , i i i iii lENT BY :ARCO ALASKA ' 1-28-99 · ,3',30P?,{ ' KPS/WELLS/CNST/PROJ--,. WEL. L I-IISTORY HANDOVER FORM Wel_/.D-106i/'~ W_e_st_ Production XX ...... AFE Number #AK 8973 / ~ / To Drilling WELL INFORMATION DOWNHOLE.iN~,,ORMATiON SITP 0 psi Drillers 'FD {5120' I~D - Parker 245 907 276 7542'# 5/11 5-~/2 Casing Pressure: 0 psi PBTDrTop of fill or Jun~5012' PBTD Date Tagged BP,,V Installed: __Yes XX No BHP Downhole Plugs; ~ Yes XX No psi/depth Date Instrument Annulus fluid Del/3% KCl Weight 6.8/8.7 ppg Tubing fluid Del/3% KCI/Mud 6.8/8:7/9.3 ppg \ Cond. DIRECTIONAL INFORMATION Surf. RKB 38.66' T_bcl H~r_L_D_ KOP 1000' Surf. Avg Hole Angle .......... _4.8* Tubing: Max angle of 50.1' @ 3287' Tubing: Hole Angle @ TD t8.5' CASING/TUBING DATA Size VVt. Grade Conn. Depth 16" 62_.58,¢ H-40 Welded 12.1' 5-1/2" x t5.5# L-80 MBTC 4376' 3-1/2" 9,3# L-80 ABM-EUE 5117' 3-'1t2" 9.3# Well Head Vetco Gray, 3-1/8" 5 Ksi (TypelPr~ssure Rating) L-80 ABM-EUE 4376' Tl~e Cap Corm OTIS Union Tbg Hgr Corm Gray 3.725" MCA N.E..W,.,;_~DD OR RE-PERFED INTERVALS Type Guns S_PF From To (W_e..ll has NOT been Perforated~ Rig released subsequent to full welt completion as required on State Drilling parrnt ?? Yes No If no, spe .cify remaining operations; Perforate, FRAC GLM NIPPL[ LSA CO_,Q~....PLETION INFORMATION Mf.qr/Type/Size/dummy or Orifice/Latch Tops _..(MD) BST 3-112" x 1" AXT, Dummy Valve, T-1 Latch 4;~86' CAMCO 3-1/2" W-1 Selective Nipple, 2.812" ID 4339' Baker Locater Seal Assy 4377' ENVi~_ .ONMENTAL SITE INSPECT[ON Location clean, SHE LC FC FS Seals s~bbed into SBE atXO In 5.f/2" x 3.1/Z" CasinR _.. Baker 4" ID Seal Bore Extension. 4376' Gemoco Insert Baffle Collar PBTD ~> fi021' Gemoco Float Collar 5052' Gemoco Float Shoe 5117' "GENERAL INFORMATION Tubing & Annulus have Diesel freeze protection down to -2350', ,with Sea Water with 3% KCl from there to SBE at 4376', There is below the ~BE to PSTD at 5021'. Tubing & Annulus tested good to 30q0 psi .... _Expect debris from drilling 0u.__t_..stage tool to be in 3-1/2" casing below SBE. (Attach Tubing & Casing Detail) Drillin~ Department Rep. Don E, Breeden,,~-/~.e,,,~'B~e ...D.._dlli_ng Supervisor Date Production/Oper D~_pt. Rep. /~~ Title ..~' Date 1/19198 SEaNT BY:ARCO ALASKA · 1-28-00 ' .3'31PM · KPS/~,qq. II.S/CNST/PROJ-' 1307 276 7.542:# 6/11 ARCO Alaska, Inc. ' 'IPARUK RIVER UNIT . . WE-LL SERVICE REPORT K1(D-106(W4-6)) WELL ' JOB SCOPE JOB'NUMBER 1D-t05 MISC RESERVOIR MANAGEMENT 0811980402.1 DATE DAILY WORK UNIT NUMBER 08/10/98 SET DRILLABLE BRIDGE PLUG/TOOL PROBLEM. DAY- OPERATION COMPLETE I ~UCCESSFUL KE~ PERSON '" SUPER[/ISOR " 1 (~ Yes ~) No ,! O Yes ~ No SCHWENDERMAN FIELD AFC# CC# DALLY COST A~CUM CO~T' " Signed ESTIMATE AK8973 18WSTF7SC $12,837 $12,837 li~ifial-rbg Pr'ess Final Tbg Press Inll~tl Inner Ann Final Inner Ann I Inil:i~l Outer Ann [ I~inal Outer.~n ,.1,200PSI , 0PSI 12o0PS! ,. OPSll 0PSI[ cps,! [}ALLY SUMMARY RAN HALLIBURTON 3-1/2" DRILl_ABLE BRIDGE PLUG AND SET AT 4600' RKB. [P'r -rub-Csg, Equip. Breakdown] TIME LOG ENTRY 07:30 10:00 12:00 LRS RIGGED UP ND PUMPED 40 BBLS OF 60/40 METHANOL DOWN TUBING.MIRU SWS(STEPHENSON AND CREW). TGSM, PERFORATING PROCEDURE. OBTAIN RADIO SILENCE AND NOTIFIED ALL PERSONNEL ON LOCATION, MU HALLIBURTON 3-1/2" FAST DRILL BRIDGE PLUG ASSEMBLY ( B. PLUG, SETi-ING TOOL, CCL, WT, SWIVEL, HEAD). PT 3000 PSI. RIH TIE IN W/ SCHLUMBERGER CBL DATED 7/6/98. SET DRILl_ABLE BRIDGE PLUG W/COE @ 4600' RKB, HAD GOOD SURFACE INDICATIONS. RELEASED SETI'ING TOOL AND TAGGED TOP OF B.PLUG @ 4599' RKB, OK. PRESSURE TESTED TUBING AND B. PLUG TO 2200 PSI, GOOD. POH. MU SAFE PERF GUN ASSEMBLY 2-1/2~ HC/DP/180 DEG PHASING/g0 DEG ORIENT F/LOW SIDE. (GUN/SAFE/MPD/CCI_/SWIVEI_/HEAD) TL--29', PT 3000 PSI. RIH. TIE IN AND ATTEMPT TO FIRE. NO GOOD, TOOL NOT WORKING. POH. TOOL AT SURFACE RD AND TROUBLESHOOT. UNABLE TO FIND PROBLEM. 13:30 16:00 RD. MOVE OFF. LEAVE WELL SHUT IN, NOTIFIED DSO. MOVE TO 1D-134. SERviCE COMPANY - SERVICE ' In DAILY COST ACCUM TOTAL APO $0,00 $0.00 LIT:I'LE RED ' $780.00 $780.00 SCHLUMBERGER " . $6,937.47 " . $6,.9. 37;47 ] TOTAL FIELD EsTiMATE " $1:2,837.47 .... $12,837.47 ra Fi I I_1_1 N G 13-Feb-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-106 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 5,126.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASNA. -PAGE I ARCO ALASKA_ ~n KRU / !D-106 500292284700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011398 MWD SURVEY JOB NUMBER: AKMM80086 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.40 0 0 N .00 E .00 121.00 121.00 9.60 0 0 N .00 E .00 259.00 258.98 147.58 1 30 N 42.00 E 1.09 488.56 488.49 377.10 0 20 N 27.28 E .51 652.43 652.36 540.96 0 7 S 37.16 E .25 924.96 924.89 813.49 0 9 S 26.83 W .05 1016.05 1015.91 904.51 4 1 N 45.04 E 4.58 1107.80 1107.22 995.82 7 4 N 38.55 E 3.38 1202.46 1200.65 1089.25 11 18 N 36.46 E 4.48 1297.81 1293.27 1181.87 16 1 N 34.86 E 4.98 .00N .00E .00 .00N .00E .00 1.34N 1.21E 1.73 4.18N 3.53E 5.30 4.48N 3.86E 5.70 3.93N 3.87E 5.22 6.09N 6.08E 8.12 12.78N 11.88E 16.66 24.80N 21.03E 31.45 43.13N 34.11E 53.63 1394.01 1385.15 1273.75 18 22 N 31.70 E 2.63 1488.80 1474.45 1363.05 20 43 N 30.26 E 2.53 1584.39 1562.84 1451.44 24 0 N 28.48 E 3.50 1676.90 1646.64 1535.24 26 2 N 27.88 E 2.22 1773.89 1732.08 1620.68 30 23 N 26.08 E 4.57 66.93N 49.67E 81.82 94.14N 65.98E 113.40 125.85N 83.78E 149.69 160.35N 102.26E 188.79 201.24N 123.02E 234.63 1870.11 1812.75 1701.35 35 36 N 25.64 E 5.42 1966.68 1889.30 1777.90 39 29 N 25.24 E 4.03 2061.72 1960.58 1849.18 43 17 N 25.44 E 4.01 2156.71 2026.72 1915.32 48 24 N 26.21 E 5.41 2438.67 2213.66 2102.26 48 31 N 25.36 E .23 248.39N 145.86E 287.02 301.53N 171.13E 345.86 358.32N 198.02E 408.70 419.64N 227.72E 476.84 609.70N 319.54E 687.91 2723.36 2404.18 2292.78 47 27 N 27.57 E .69 799.04N 413.75E 899.37 3007.41 2591.93 2480.53 49 46 N 27.62 E .82 987.87N 512.45E 1112.31 3286.57 2771.74 2660.34 50 5 N 20.84 E 1.86 1182.50N 600.01E 1325.66 3384.07 2837.19 2725.79 45 32 N 22.71 E 4.87 1249.59N 626.77E 1397.73 3479.20 2905.86 2794.46 42 1 N 22.31 E 3.72 1310.39N 651.97E 1463.45 3668.60 3047.10 2935.70 41 32 N 21.56 E .37 1427.44N 699.11E 1589.38 3857.35 3189.31 3077.91 40 40 N 24.85 E 1.23 1541.47N 747.96E 1713.33 3951.51 3262.38 3150.98 37 29 N 24.25 E 3.41 1595.45N 772.64E 1772.67 4047.59 3340.14 3228.74 34 27 N 25.96 E 3.33 1646.56N 796.55E 1829.09 414i.65 3419.09 3307.69 31 22 N 25.69 E 3.27 1692.56N 818.81E 1880.20 4235.35 3500.70 3389.30 27 26 N 25.97 E 4.21 1733.97N 838.85E 1926.20 4330.37 3586.45 3475.05 23 33 N 25.18 E 4.10 1770.85N 856.52E 1967.10 4520.35 3761.93 3650.53 21 27 N 22.65 E 1.22 1837.27N 886.06E 2039.76 4614.76 3850.53 3739.13 18 57 N 25.40 E 2.83 1867.05N 899.28E 2072.33 47!0.05 3940.72 3829.32 18 40 N 25.59 E .29 1894.79N 912.51E 2103.06 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. KRU / 1D-i06 500292284700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011398 MWD SURVEY JOB NUMBER: AKMM80086 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 4803.60 4029.25 3917.85 19 3 N 25.44 E 4898.11 4118.60 4007.20 18 57 N 24.85 E 4992.57 4208.03 4096.63 18 37 N 24.44 E 5076.46 4287.56 4176.16 18 28 N 23.09 E 5126.00 4334.54 4223.14 18 28 N 23.09 E .41 1922.10N 925.54E 2133.32 .23 1949.96N 938.62E 2164.10 .39 1977.62N 951.31E 2194.53 .54 2002.04N 962.07E 2221.20 .00 2016.48N 968.22E 2236.89 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2236.89 FEET AT NORTH 25 DEG. 38 MIN. EAST AT MD = 5126 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 25.58 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 5,126.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. KRU / 1D-106 500292284700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011398 JOB NUMBER: AKMM80086 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.40 1000.00 999.89 888.49 2000.00 1914.76 1803.36 3000.00 2587.15 2475.75 4000.00 3301.25 3189.85 .00 N .00 E .00 5.36 N 5.35 E .11 .11 320.96 N 180.30 E 85.24 85.13 982.86 N 509.83 E 412.85 327.61 1621.80 N 784.73 E 698.75 285.90 5000.00 4215.07 4103.67 5126.00 4334.54 4223.14 1979.78 N 952.29 E 784.93 86.18 2016.48 N 968.22 E 791.46 6.52 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA .PAGE 4 ARCO ALASKA INC. KRU / iD-106 500292284700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011398 JOB NUMBER: AKMM80086 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.40 111.40 111.40 .00 211.41 211.40 100.00 311.44 311.40 200.00 411.46 411.40 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .42 N .37 E .01 .01 2.36 N 2.13 E .04 .04 3.77 N 3.32 E .06 .02 511.47 511.40 400.00 611.47 611.40 500.00 711.47 711.40 600.00 811.47 811.40 700.00 911.47 911.40 800.00 4.30 N 3.59 E 4.54 N 3.81 E 4.38 N 3.93 E 4.20 N 4.00 E 3.96 N 3.89 E .07 .00 .07 .00 · 07 .00 .07 .00 .07 .00 1011.53 1011.40 900.00 1112.02 1111.40 1000.00 1213.45 1211.40 1100.00 1316.67 1311.40 1200.00 1421.67 1411.40 1300.00 5.90 N 5.89 E .13 .06 13.22 N 12.23 E .62 .49 26.61 N 22.35 E 2.05 1.43 47.40 N 37.09 E 5.27 3.23 74.35 N 54.26 E 10.27 5.00 1528.50 1511.40 1400.00 1637.69 1611.40 1500.00 1750.06 1711.40 1600.00 1868.48 1811.40 1700.00 1995.58 1911.40 1800.00 106.73 N 73.20 E 145.17 N 94.22 E 190.63 N 117.77 E 247.57 N 145.46 E 318.37 N 179.08 E 17.10 6.83 26.29 9.19 38.66 12.37 57.08 18.42 84.18 27.10 2133.95 2011.40 1900.00 2284.29 2111.40 2000.00 2435.26 2211.40 2100.00 2586.14 2311.40 2200.00 2734.03 2411.40 2300.00 404.53 N 220.31 E 505.25 N 269.86 E 607.39 N 318.44 E 709.41 N 366.98 E 806.01 N 417.39 E 122.55 38.37 172.89 50.33 223.86 50.97 274.74 50.88 322.63 47.89 2882.69 2511.40 2400.00 3037.56 2611.40 2500.00 3192.68 2711.40 2600.00 3346.62 2811.40 2700.00 3486.66 2911.40 2800.00 903.49 N 468.30 E 1008.35 N 522.99 E 1115.80 N 573.08 E 1224.47 N 616.46 E 1315.01 N 653.87 E 371.29 48.66 426.16 54.87 481.28 55.12 535.22 53.94 575.26 40.04 3620.91 3011.40 2900.00 3754.51 3111.40 3000.00 3886.25 3211.40 3100.00 4012.49 3311.40 3200.00 1398.03 N 687.49 E 1480.42 N 720.05 E 1558.38 N 755.77 E 1628.38 N 787.84 E 609.51 34.25 643.11 33.60 674.85 31.74 70i.09 26.24 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA. -PAGE 5 ARCO ALAS~ INC. KRU / 1D-106 500292284700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/12/98 DATE OF SURVEY: 011398 JOB NUMBER: AKMM80086 KELLY BUSHING ELEV. = 111.40 FT. OPERATOR: ARCO ALASKA INC iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4132.61 3411.40 3300.00 4247.37 3511.40 3400.00 4357.59 3611.40 3500.00 4466.06 3711.40 3600.00 4573.25 3811.40 3700.00 1688.28 N 816.75 E 721.21 20.12 1738.88 N 841.24 E 735.97 14.75 1780.70 N 861.15 E 746.19 10.23 1818.95 N 878.41 E 754.66 8.47 1854.45 N 893.48 E 761.85 7.18 4679.10 3911.40 3800.00 4784.72 4011.40 3900.00 4890.50 4111.40 4000.00 4996.13 4211.40 4100.00 5101.60 4311.40 4200.00 1885.85 N 908.23 E 767.70 5.85 1916.53 N 922.89 E 773.32 5.62 1947.72 N 937.58 E 779.10 5.78 1978.65 N 951.78 E 784.73 5.64 2009.37 N 965.19 E 790.20 5.47 5126.00 4334.54 4223.14 2016.48 N 968.22 E 791.46 1.26 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. KRU .... 1D-106 CONDUCTOR . APl: 500292284700 Well Type:llNJ Angle @ TS:I deg @ (0-121, SSSV Type: None Orig Compltn:11/19/98 Angle @ TD: 18 deg @ 5126 OD:16.000, , -- --~, Annular Fluid: Last W/O:I Rev Reason: PERF by vg Wt:62.58) Reference Log: Ref Log Date: Last Update: 9/9/98 TUBING Last Tag: 4940' w/CTU TD: 5126 ftKB (0-4376, Last Tag Date: 9/9/98 Max Hole Angle: 150 deg @ 3287 0D:3.500, Casing string,CONDUCTOR:::::::::: :: :::: SURFACE 16.000I I I I t i 0 121 121 62.58 H-40 Welded (0-4376, Casing string:;:SURFACE : :: : : ::::: :: : ::::: :: ::: : :: ::: : : ::::: 0D:5.500, Size I Top Bottom TVD t 195.W~00 I GradeI Thread Wt:15.50) 5.500 0 4376 3629 L-80 MBTC 3.500 4376 5116 4325 . L-80 ABM-EUE GasLift Tubing String::, TUBING:::: : :: : i::::::: ::: :::: ::::::: :: ::::: ::~ Valve 1 3.500 0 4376 3629 9.30 L-80 ABM-EUE (4286-4293, PerforatiOns summary :: 0D:4.700) Interval TVD Zone Status Feet SPFI Date Type Comment 4462 - 4496 3708 - 3740 34 4 8/11/98 2 1/2" 180 deg phasing, 90 deg orientation HC, DP 4530 - 4570 3771 - 3809 40 4 9/9/98 2 1/2" 180 deg phasing, 90 deg orientation HC, DP 4580 - 4600 3818 - 3837 20 4 9/9/98 2 1/2" 180 deg phasing, 90 deg orientation HC, DP 4668 - 4680 3901 - 3912 12i 4 9/9/98 2 1/2" 180 deg phasing, 90 deg orientation HC, DP 4722 - 4762 3952 - 3990 40 4 7/19/98 2 1/2" lB0 deg phasing, 90 deg orientation HC, DP 4779 - 4794 4006 - 4020 15 4 7/19/98 2HC,1/2"Dp 180 deg phasing, 90 deg orientation Gas Lift MandrelS/ValveS::::: Stn MD TVD Man Man V Mfr VType VOD Latch Port TRO I Date VIv Mfr TypeI Run Comment 1 4286 3547 BST 3 1/2"XAxT 1" BST DV 3.5 T-1 0.000 0 6/15/98 Other (plUgs;equiP.;:etc~) ~ JEWELRY:: :: :: :: ::::: :::: :: :: ::::: : ::: :::::: :: Depth TVD Type Description ID 4339 3595 NIPPLE 3 1/2" W-1 w/selective nipple 2.812 4377 3630 SBE Baker Iocator seal assembly stabbed into SBE 3.000 4995 4210 PLUG Halliburton ddllable bridge plug. 2.992 5117 4326 SHOE 3.000 NIPPLE (4339-4340, 0D:3.500) SBE (4377-4389, 0D:4.000) SURFACE (4376-5116, 0D:3.500, Wt:9.30) 7/24/98 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11363 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk WS 1D-106 ~/--~O CBLSLIM-CMT 980706 I 1 W.$ 1 D-109 ~ '-/ -- ;~ ~ ~ CBL SLIM-CMT 9 8 0 7 0 6 I 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: OF! I I-I-I ~ G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-106, February 18, 1998 AK-MM-80086 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-106: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-22847-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22847-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company I::] FI I I--I-- I I~1 G SEFI~JICE S ~/V-ELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-106, AK-MM-80086 February 18, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin. Sperry-Sun Drilling Services. 5631 Silverado Way,//G. Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22847-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 19, 1997 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 West Sak ID-106 (D6) ARCO Alaska. Inc. Permit No 97-240 Sur. Loc.: 104'FSL, 595'FEL, Sec. 14. T11N, R10E, UM Btmhole Loc: 2119'FSL, 367'FWL, Sec. 13, TllN, R10E. UM Dear Mr. Zanghi: 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 bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. KI-LEI V EIJ STATE OF ALASKA DEC~ 5 199 ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska 0il & GasCons. Commission 20 AAC 25.005 Anchorage la. Type of Work Drill X Reddll I lb Type of Well Exploratory [--] Stratigraphic Test E] Development Oil F~ Re-Entry DeepenI Service X Development Gas E] SingleZone X Multiple Zone F~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 104' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1961' FSL, 294' FWL, Sec. 13, T11N, R10E, UM West Sak 1D-106 (D6) #U-630610 At total depth 9. Approximate spud date Amount 2119' FSL, 367' FVVL, Sec. 13, T11N, R10E, UM 1/15/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-02 5126' MD 2119' @ TD feet 14.0' @ 480' feet 2560 4322' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1000' feet Maximum hole angle 47.5° Maximum surface 1447 psig At total depth 1902 psig (q'VD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I'VD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' __.200 CF 8.5" 5.5" 15.5# L-80 BTC MOD 4316' 41' 41' 4357' 3611' 520 Sx Arcticset III & 8.5" 3.5" 9.3# L-80 8rd 769' 4357' 3611' 5126' 4322' 434 Sx Class G & 60 sx AS I 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 Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true verticaln tGtNAL 20. Attachments Filing fee X Property plat [] BOP Sketch [] -'~)i~er~e~' Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe~'~~//~, /~~~"~F~//~'/-~'~~~/ Title Drilling Superintendent Date /'Z,"" ?---- ?? Commission Use Only I IApprovaldate_ _ _ See cover letter for Permit !~umber APl number .~. -.~ ~.~. / ¢~' 7- ~-~ ~"~O 50- O 2:~- ~ ? /-"'~" ? ff'"' ~" 7 other requirements Conditi~)ns of approval Samples required [~ Yes ~.~ No Mud log required F Yes [~, No Required working pressure for BOPE E]2M ~ 3M F'~ 5M E~ l OM E~ 15M Other: · .;, ,,..J,, ~a, Signed By by order of,,') !C Approved by 0avid W. Johnston Commissioner the commission Date/cZ '"'// ~y / Form 10-401 Rev. 7-24-89 Submit in tripl 2ate Drill, Case and Completion Plan for West Sak 1D-106 (D6) Monobore Iniector 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 drilling rig. Install diverter & function test same. 3. Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. NOTE: A 9-7/8" hole may be drilled depending on the hole conditions encountered. 4. Condition hole for casing, trip out. 5. Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. 7. Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. 8. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. Page 1 13. 14. 15. 16. 17. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. Install back pressure valve, shut in and secure well. TAB, 11/20/97, Rev. 1 Page 2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-106 (D6) Drillinq Fluid Tvr)e Extended Bentonite Slurry Drillin~ Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5-9.O ppg 35-70 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.5-10.0 ppg 35-7O 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-106 (D6) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,693' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/fi from the West Sak base in the West Sak 1D-106 (D6) well to surface, the following MASP can be computed: MASP = (4134 ft)(0.46 - 0.11 psi/fi) = 1447 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 5-1/2" 15.5# LB0 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Page 2 Drilling Area Risks: Drilling risks in the West Sak 1D-106 (D6) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-106 (D6). Well Proximity Risks: The nearest existing well to West Sak 1D-106 (D6) is KRU 1D-02. As designed, the minimum distance between the two wells would be 14' at 480' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. In addition, the West Sak 1D-106 (D6) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. TAB, 12/O8/97 Page 3 25O 500 75O lOOO 1250 1500 1750 2OOO 2250 25OO 275O 3000 3250 3500 375O 4000 4250 45OO Cceuted by finch For: T McKAY D~te pl~tted : 8-0ct-97 Plot Reference is WS 1D-106/06 Vers.~3. Coardinotes ore in fe~ reference slot ~106. Vedic~l Oep~s ere r~ence tA]RCO Alaska, Inc. Structure: Pod 10 Well: 06 Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 112' 25.5 8 AZIMUTH 2059' (TO TARGET) ***Plane of Proposal*** K0P TVD=1000 TMD=IO00 DEP=O 4.00 8.00 BEGIN TURN TO TARGET TVD=1249 TMD=1250 DEP=21 11.91 15.81 19.74- DLS: 4.00 deg per 100 fl: 23.70 27.67 B/ PERMAFROST TVD=164-1 TMD=1664 DEP=14-8 51.64 .35.62 59.61 43.59 EOC TVD=2066 TMD=2199 DEP=467 MAXIMUM ANGLE 47.53 DEG East (feet) -> 0 200 400 600 800 1000 I I I I I I I I 1 I I I TO LOCATION: I 2119' FSL, 367' FWL SEC. 15, T11N, RIOE TD - Cosin9 ~j> Bose Wesl: Sok Sond~/ TARGET - A3/ Top West Sok Sands (EOD)~/~_~ / 1961' FSL, 294' FWL · / SEC. 13, T11N, TI OE Beg,n Angle Drop/ -~RDG_3ET845 /Top Ucjnu Sands TM~)~-4619 DEP=2059 NORTH 1857 Base Permafrost _~,,V(~i/Begin Turn to Target SURFACE LOCATION: I 104' FSL, 595' FEL SEC. 14, T11N, RIOE 2200 2000 1800 16OO 1400 1200 lOOO 800 600 4OO 2OO Z 0 46.28 42.28 38.28 .34.28 aLS: 4.00 deg per 100 ft 30.28 26.28 22.28 T/ UGNU SNDS TVD=5014 TMD=3602 DEP=1502 BEGIN ANGLE DROP TVD=3126 TMD=3769 DEP=1625 T/ W SAK SNDS(EOD) TVD=3695 TM0=4457 OEP=2004 __TARGET - A3 TVD=3845 TMD=4619 DEP=2059 TARGET ANGLE 20 DEG B/ W SAK SNDS TVD=4134 TMD=4926 DEP=2164 ~> TD - CSG PT TVD=4322 TMD=5126 DEP=8233 I I I I I I II I I II I I I I I I I 0 250 500 750 1000 1250 1500 1750 2000 2250 Vertical Section (feet) -> Azimuth 25.58 with reference 0.00 N, 0.00 E from slot //106 C~oted ~ f~ For: T McKAY D~te platted : 28-0ct-97 Plot Reference is V/S 1D-106/D6 Vers.tS. Coord/notes ore in feet reference slot ~106. True Verticol Oepths ore reference R~8 (Perker D~245). [XRC0 ALASKA, ][nc. Structure : Pad 1D Well: D~-- -- - Field : Kuporuk River Unit Location : North Slope, Alaska 280 260 240 220 200 180 160 140 I 120 '-4-- 100 '~C 0 20 2O 4o 60 8O East (feet) -> 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 I , , , ~ I , , I ,~1~ t , , I , , I I , , , ~ , , 1 00 000 89g.99 8OO 7OO 6OO 1500 1400 '~ 1100 · ,, '~,, 10 O0 ', '~ 900 · · · , · 1800, / / / / / / / , 2500 / ,' / · 1700~' ' " 1000 ~ / ,' ~ / ., i 1600/' // ! 2400 / /i/ 00 70O . 600 ./'/ . ..-8'6o/,,' ~ooe-' 3°°e"' ,"~ 200 ,,' ,, ~oo 61 1900 ,, 'x 800 "x 700 -,~ 600 "--~ 3oo 000 . 100 40O , , , i ,~ - 280 / / /"I 200 F - 260 1500 00 2,300 220O 2100 I I I I i i 8'0 6'0 4'0 ' 210 0 2'0 40 0 0 100 East (feet) -> i 120 240 22O 200 180 16O 140 A 120 I ~ z I- I o 1 O0 I 80 CD --4- ? 4o ~- ~o 4O ! 80 I I I I 140 160 180 200 220 C~eoted by f~nch For: T McKAY Dote f~atted : 28-0ct-g7 Plot Reference is W5 ID-ID6/D6 Vers.i~3. Ca~dMotes ore in feet reference srot ~106. jT~e Ve~ic~l Depths ore reference ~8 (Porker ~245). i-A_R_RC 0 AL___AS K_A__, Structure : Pod 1D Well: Field : Kuporuk River Unit Locofion : North Slope, Alosko Eosf (feet) -> 300 200 1 O0 0 100 200 500 400 ,500 600 700 800 900 1000 1100 1200 1.300 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 2100 t 2100 , 2000 2000 / 4100// 1goo 9oo/ , / · / / 3700g' /2500 1800 / ,," 1800 / / 3500i / 1700 ,,' 1700 , , , , 3300~' ,' 16OO ' ,' F 1 600 / 2300 , / , " 150o 150o / ,, / / 3~oo~' ,, / iI I1 / ,' 1400 /I ti / itI 11 /2100 / 1300 / / 2900 ,, tt / 1200 / i1 ~ " ~I00 /'1900 41 O0 2700 / " 1000 ,," i000 ~ 3900 / ~, ,///' 9OO [ 3700 ~00 ~ 2500 /'~ 7OO ~00 8003 "}, //'/ ,,/,"'"" 800 [ 3300 // /,,, 70o [ ~07oo : / ," ~ ~50500 ~ 2300: ,," O0 600 [ 3~ O0 ~00 ~ OD 2 {2900 2soo) ',, 2300 300 ~ 300 i i i i ~ ~ i i i i i i i 300 200 1 O0 0 1 O0 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 Eosf (feet) -> 1400 ~ 300 1200 1100 ARCO ALASKA, Inc. Pad 1D D6 slot #106 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : WS 1D-106/D6 Vers.#3 Our ref : prop2220 License : Date printed : 28-0ct-97 Date created : 17-Apr-97 Last revised : 8-0ct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 18 2.339,w149 30 36.255 Slot Grid coordinates are N 5959768.680, E 560491.115 Slot local coordinates are 104.00 N 595.00 W Projection type: alaska - Zone 4, Spheroid: Clarke o 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <O-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D PMSS <O-?????>,,H4,Pad 1D WS 1D-105/C7 Version #4,,CT,Pad 1D WS 1D-118/E5 Version #4,,ES,Pad 1D WS 1D-119/F4 Vers.#3,,F4,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-133/J5 Version #4,,J5,Pad 1D WS 1D-135/G7 Version #4,,GT,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D M.D. Diverging from M.D. 4-Aug-92 110.2 1510.5 1510.5 16-Oct-96 702.7 1025.0 1025.0 4-Aug-92 344.4 1000.0 1000.0 4-Aug-92 227.1 20.0 1300.0 4-Aug-92 106.1 1025.0 1025.0 4-Aug-92 14.0 480.0 480.0 25-Oct-97 467.0 20.0 680.0 25-Oct-97 587.0 460.0 460.0 8-0ct-97 32.1 760.0 760.0 27-Oct-97 510.0 600.0 4618.6 28-Oct-97 509.9 420.0 420.0 22-Oct-97 30.0 380.0 380.0 28-Oct-97 210.0 1000.0 1000.0 6-0ct-97 255.0 1000.0 1000.0 6-0ct-97 270.0 980.0 980.0 22-Oct-97 375.0 900.0 900.0 22-Oct-97 495.0 300.0 5000.0 22-0ct-97 555.0 300.0 300.0 22-0ct-97 630.0 780.0 780.0 28-Oct-97 143.7 780.0 780.0 28-0ct-97 165.3 940.0 940.0 23-0ct-97 285.0 1000.0 1000.0 West SaklD-106 (D6) Monobor' Injector Well Proposed Completion Diagram Tapered Monobore Injector Isolate Injection Thief Zones Using Patches 3-1/2" Tubing 9.3# L-80 8RD EUE (tied back to surface from Seal Bore/PBR) 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 5-1/2" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 5-1/2" Combination Surface/Production Casing 15.5# L-80 BTC (Cemented to Surface) Baker Seal Bore Extension - 12' Size 80-40 with 80-40 bottom sub to 3-1/2" tbg and 80-40 top sub, 5-1/2" to 3-1/2" (ASN 461-3435) (positioned +/- 100' above perfs) XO From 5-1/2" Casing to 3-1/2" Casing D Sands B Sands A Sands 3-1/2" Tapered Casing/Tubing 9.3# L-80 8RD EUE (Cemented to Surface) ARCO Alaska, Inc. TAB, 11/20/97, Rev. 1 KUPARUK RIVER UNIT- WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC 6 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 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. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 8 6 5 4 3 13 5/8" 5000 PSI BOP STACK West Sak Operations - Injector Wells AC(~t,JMULATOR 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 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 AND 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 TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR 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 LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'i-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI 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 KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3.1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HEAD 2. 7-1/16" - 5000 PSI TUBING HEAD 3. 7-1/16" - 5000 PSI X 13-5/8" - 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13.5/8" 5000 PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/6" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8' - 5000 PSI ANNULAR TWM, 9/18/97 REVI .;ATE ', 3Y ; CX J xPP ) 2ESCRIPTION 'REVI GATE i 8Y ! 2X I APP ! DESCRIPTION ' i9/02/97t A~ PC I I AS-BUILT PER K~ K97082ACS 2 i9/17/97i A~ ~ PC ~IAS-BU'LT PE~ K~K97082A~ 105~ 2 i06 · ~ ~ 2~ : ~ 2 ~ ~ ' ,,~ ~~ ~CINI TY MAP ~ ~ e 117 ~ SCALE: 1" = I MILE 119 ~ 120 ~ 121 . I 124 ~ e 129 m ~ ' ,~ ~o~ S 133 , I J i i~ j LEGEND s[E SHE~ , 2 FOR NOTES ~D LO~TION INFOR~TION o gx/s.~ conductors ~ gOUNSBURY · NEW CONDUCTOR LOCA ~OJ~~~/~ & ASSOCiATeS, ~EA' 1D U~U~ XX UNIT' D1 ~k DRILL S~ ARCO ~"""~--,~~~ Inc. ~ ~ST SAK PHASE ~ - ~ CONDUCTORS AS-BUILT CADD Fi~ NO. I ./02/.7 I ORA--NG NO: I ~EET: I I Kg10410 ~FA--~I~Y--RI~4DlO 1 REV I ' ~,]'E i -3';' ' CK i APP J, ..... .'DESCRIPTION -REVt OATS I 3Y I CK i APP I OE$CRIPTION 1 ,9/02/97t AiR i PC j J AS-BUlL[ PER KSBI X97082ACS j 2 i9/17/g7i AiR i PC I lAS-BUILT PER XSB~ Kg7082ACS 1. C,ORDINATES SHOWN ARE A. XP. ZONE 4. N.A.D. 27. _~ -- l'--" ~D.S.1B ~_ /"~.. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN //r''r'- C.P.F.I[ ,., / i ? ZEA LEVEL. ALL DISTANCES SHOIIFIV ARE TRUE. ~"" ,~....~ I ,),~ ~ "", !3 2. £A$1S OF LOCATIONS AND ELEVATIONS ARE D.S. l-O PIT C ~ ~ "~0 :\J ~"~ L' '~,~ ~IONUMENTSPERLHDANDASSOCIAT~S. '., ~l ~-LAi~_)! ~ ? ~ 3. CCNDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS '"~ ~PIT ;4 & 2J, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. ~---~j .-/ ," / '~ ~ r~ ~' 5. DRILL SITE 1-0 GRID NORTH IS ROTATED 00' 01' 05'" '"~'~ t WEST FROM A.S.P. ZONE 4 GRID NORTH. 6. SEE DRAWING NSK-,3.5-;1 FOR AS-BUILT LOCATIONS ,.~.x,?:.'....'~"""'"~'"~ ......... ...... ....;..._.~.~, ~ Fo-- "-" SURVEY ~ ~ ,,..,) .-' 49th ~ ~:~ \ . / ~z / / ~ j ~ VICINITY MAP ' '~- : ~L/~N /2' SCALE: l" = , MILE '*.Dd"'.... .... .'"':. No. ,y, A.S.P., 'X' LA TITUDE LONGITUDE L~,~ELEV. i EL£V. , ~ ! ' ! S,=.c. 14, T. 11 N., R. IOE. F.$.L.F.E.L.i ~05 : 5,959,798.99 560,490.57 70' ;18' 02.6J7' ;149' ,,To' .,T6.26~' ~.,T4' 595° !70.5'!62.0'I ~06 I 5,959,768.95 560,490.67 70' ;18' 02.$4;1' ~49' ,.TO' ,.,76.268" ~04' 595' 70.4' 62.$'i ! ~09 . 5.959,72,.T. 89 560,490.60 70' ;18' 0;1.898' ;149' 30' 36.280" 59' 596'170.4' ~ 62.7'i S~=.c. 23, T. 11 N., : R. 10 E. F.N.L. F.E.L. 1~5 5,959,60,.,T. 95 560,490.68 70' ;I8' .00.718' ;149' ,,TO' 36.$06' 61' 597' 170.4' 6~4'i ! I;17 I 5,959,57.:,T. 95 5~0,490.65 70' 18' 00.423' 149' ,,TO' ,,T6.3~4' 9t' 597' !70.4' 118 I 5,959,558.95 560,490.68 70' ~8' 00.276' 149' ,,TO' 36,316' 106' 597' ~ 70.4' 6~4'! I 1;19 I 5,959,513.86 560,490.72 70' 17' 59.8J2' 149' ,.,TO' ,,T6.$26" 15I' 598' i 70.6' 120 I 5,959,499.0! 560,490.77 70' ;17' 59.686' 149' ,,,TO' 36.327' 166' 598' ' 70.6' 66.0' 12! I 5,959,485.89 : 560,490.67 70' 17' 59.538' 149' ,.,TO' J6.$$5' 18I' 598' 70.5' 66.0 '~24 i 5,959, J95.96 560,490.70 70' 17' 58.653' ~49° 30' 36.355' 271' 599'!70.3' '65.0' 129 5,959,27..,T. 92 . 560,490.79 70' ;17' 57.472' ;149' ,.TO' 36.380" $9~' 600' 70.$" 68.2' 130 I 5,959,259.09 ! 560,490.8;1 70' 17' 57.326' ;149' ,,TO' .:76.383' 406' 600' 70.5' 68.2' ' I35 I 5,959,2;13.89 560,490.68 70' 17' 56.882' 149' ,.,TO' 36.$97" 45~' 600''70.4' '69.0' 135 5,959,;139.02 560,490.80 70' 17' 56. I46' ~49' ,.TO' ~6.4;12' 526' 601' 70.5' 69.4' i SURVEYOR'S CER TIFICA ¢ HEREBr CERnn' TH,~r l A~ PRO~ERLr REGISTERED ,~ND UCENSED rD PR,~C77CE ~A~D SURVE,~G IN THE STARE ALASKA AND THAT THIS 'LAT RE RESENTS LOTJNS]3TJRY A SURVEY OONE BY' ME OR UNDER Mr OIRECr ~..., /& l DETA/LS ARE CORRECT AS OF AUGUST ,30, 199Z ,,~,'"---~.~RS pU~P,s SUR',rSYORS AREA' 1D aOOULE' XX UNIT' D1 DR LL S T[ ARCO Alaska, Inc. ,qr WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CABD FILE NO. ' ~i~V: LK610410 I 0/02/07 IO~A~"¢ "~' CEA-D1DX-6104010 Is"[~:2 ~ ~ ~ s c. ls c.l o No. ,y, A.S.P.$ 'X' LA nTUOE LONGITUDE L~/~ , L~/~ , ELEV.EL£V. S,=.c. 14, T. 11 N., R. IOE. F.S.L.F.£.L. 105 5,959,798.99 560,490.57 70' ;18' 02.6,.,T7' 149' ..,TO' .,T6.265" I,.,T4' 595' 70.5' 62.0' 106 5,959,768.9..) 560,490.67 70' 18' 02.34I' 149' ,.,TO' ,.,?6.268" 104' 595' 70.4' 62...,1' 109 5.959,725.89 560,490.60 70' 18' 01.898' ;149' ,,TO' ,.,T6.280" 59' 596' 70.4' 62.7'i S~=,c. 23, T. 11 N., R. 10 E. EN.L. F.£.L. 115 5,959,60,.,T. 95 560,490.68 70' 18' .00.718' 149" ,,TO' 36.306' 61' 597' 70.4' 6~4') I;17 5,959,57..,T. 95 5~0,490.65 70" 18' 00.425' 149" ,,TO' 36. JI4' 9I' 597' 70.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' JO' 36, J16' 106' 597' 70.4' 1;19 5,959,5~J. 86 560,490.72 70' ;17' 59.8J2' 149' ,.,TO' ,,T6.$26" 15~' 598' 70.6' 66.0'1 120 5,959,499.0! 560,490.77 70' ;17' 59.686' 149' ,,,TO' 36.327' 166' 598' 70.6' 66.0' 121 5,959,485.89 560,490.67 70' 17' 59.538' 149' ,:TO' J6.$$5' 18I' 598' 70.5' 66.0 124 5,959,395.96 560,490.70 70" 17' 58.65,.,T' 149' 30' 36.$55' 271' 599' 70.3' 65.0' 129 5,959,27..,T. 92 560,490.79 70' 17' 57.472' 149' 30' 36.380" 391' 600' 70.3' 68.2' 130 5,959,259.09 560,490.8;1 70' 17' 57.$26' 149' JO' 36.38.,T' 406' 600' 70.5' 68.2' IJ$ 5,959,215.89 560,490.68 70' 17' 56.882' 149" 30' 36.397' 451' 600' 70.4' 69.0' 135 5,959,159.02 560,490.80 70' 17' 56. I46" I49' ,.TO' ~6.412' 526' 601' 70.5' 69.4' ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor December 9, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-106 (D6) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. 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). Note the 40 acre spacing requirements governed by the West Sak pool rules. 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). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 106 (D6), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 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 APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Aisc note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) 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 Icg generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is January 15, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay a~t (907) 265-6890. Thomas A. Brockway ~ Operations Drilling Engineer Attachments CC: West Sak 1D-106 (D6) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 RECEIVED ~,laska 0il & Gas Cons. C0mmissio- ^nchora§¢ · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'"'~ ' /,'~"~/,_.~0 INIT CLASS ADMINISTRATION , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. ,~ ,DATE/ 12. ,,/ ENGINEERING WELL NAME/'~',~/ //~""/-(")~'~ PROGRAM: exp [] dev~"'~edrll [] serv~Twellbore seg l:: ann. disposal para req GEOL AREA ~>' .~'? _('~j UNIT# ,/.//'_'~_f~'7/_/~ ON/OFF SHORE Permit fee attached ....................... IY* N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included .............. N Operator only affected party ................... N Operator has appropriate bond in force ............. Y ~ N Permit can be issued without conservation order ........ Y I N Permit can be issued without administrative approval ...... Y ~ N Can permit be approved before 15-day wait ........... LY/N _'W_. 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... ~ N 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...,,_Y N 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 ................ y~(~N 26. BOPE press rating appropriate; test to '~~r'o'Z~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. REMARKS GEOLOGY APPR , D~,TE.2 30. Perrnit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. Y~ / c× 33. Seabed condition survey (if off-shore) ............. /I' N 34. Contact name/phone for weekly,progress reD?ts // Y N lexploratory omyj G E O/L..;,~,~G,Y: E NGI N.E_I~.~I N G' COMI~tlSSION: ~ ' .... ' JDH ¢' ~ RNC~.g,¢~ Comments/Instructions: HOW/lit - A \FORMS\chekhst rev 09/97 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. /Q7-2L.(Ù Memory Multi-Finger Caliper Log Results Summary iI' Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLlPS (ALASKA) INC. Ju Iy 28, 2005 6508 1 3.5" 9.3 lb. L-80 ABM-EUE Tubing Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 D-1 06 Kuparuk Alaska 50-029-2284700 Surface 4,433 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Kl..1 wlse/ective nipple @ 4,339' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosivé and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximu m recorded penetration of 71 % in Jt. 79 @ 2,541'. Wall penetrations in excess of 20% wall thickness are recorded in 67 of the 146 joints logged. The damage recorded appears in the form of Line Corrosion, Line of pits and isolated pitting. There are no areas of significant Cross Sectional Wall loss or 1.0. restriction recorded throughout the interval oftubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits Line Corrosion Line Corrosion Line of Pits Line of Pits ( 71 %) ( 68%) ( 63%) ( 59%) ( 59%) Jt. Jt. Jt. Jt. Jt. 79 @ 134.3 @ 134 @ 76 @ 81 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>10%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. 2,541 Ft. (MD) 4,293 Ft. (MD) 4,242 Ft. (MD) 2,427 Ft. (MO) 2,592 Ft. (MD) <'''',t),a..tïA..u.:.::r "UG. Cj -? 20r¡¡;,- "",-:,Cß·''/,B~H~¡ç",..' h" Jj (C) J. _ t¡,.J I Field Engineer: N. Kesseru Analyst: J. Thompson Witness: C. Fritzpatrick ProActive Diagnostic Services, Inc. I 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 ~s '..- iI' Well: Field: Company: Country: 10-106 KUPARUK CONOCOPHILLIPS ALASKA INC USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 ABM-EUE Penetration and Metal Loss (% wall) _ penetration body 150 !alii metal loss body 100 50 o 0 to 1% 1 to 10 to 20 to 40 to over 10% 20% 40% 85% 85% Number of joints analysed (total = 146) pene. 0 11 68 18 49 0 loss 4 142 0 0 0 0 Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 115) 35 16 64 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 28,2005 MFC 24 No 00387 1.69 24 J. Thompson Nom. Upset Upper len. 3.5 ins 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) lam! metal loss body 50 _ penetration body o O==- r::::- c:.. æ::. == "=" 47- e;- ll:::' t 100 97 GLM 1 Bottom of Survey = 138 Analysis Overview page 2 i I~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: 1 0-1 06 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 2.992 in Country: USA Survey Date: July 28, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) (:y;) (Ins.) 0 50 100 .1 43 0 0.02 9 2 2.90 PUP 1 46 0 0.03 12 2 2.94 1.1 77 0 0.02 9 2 2.90 PUP 1.2 85 () 0.03 10 2 2.91 PUP 1.3 96 0 0.03 12 2 2.90 PUP 2 106 0 0.03 11 2 2.93 3 137 0 0.03 12 2 2.92 4 169 0 0.03 13 2 2.93 Shallow corrosion. 5 200 0 0.03 12 2 2.94 6 232 0 0.04 14 2 2.93 Shallow pitting. 7 263 0 0.04 16 1 2.93 Shallow corrosion. 8 294 0 0.03 12 2 2.92 9 326 0 0.03 10 1 2.91 10 357 0 0.04 15 2 2.94 Shallow pitting. 11 388 0 0.03 12 3 2.94 12 420 0 0.03 13 2 2.95 Shallow pitting. 13 451 0 0.03 12 2 2.92 14 483 0 0.03 10 J 2.94 15 514 0 0.03 12 2 2.94 16 546 0 0.03 13 2 2.93 Shallow pitting. Lt. Deposits. 17 577 0 0.03 13 2 2.93 Shallow pitting. 18 609 0 0.04 16 3 2.94 Shallow corrosion. 19 638 0 0.03 13 2 2.93 Shallow pitting. 20 670 0 0.03 11 2 2.94 Lt. Deposits. 21 701 0 0.03 13 2 2.94 Shallow pitting. 22 732 0 0.03 13 2 2.93 Shallow corrosion. 23 764 0 0.03 11 2 2.93 24 795 0 0.04 14 2 2.93 Shallow corrosion. Lt. Deposits. 25 826 0 0.03 10 3 2.94 26 857 0 0.04 15 2 2.92 Shallow pitting. Lt. Deposits. 27 889 0 0.02 9 2 2.93 28 920 0 0.02 9 1 2.94 29 951 0 0.04 14 2 2.93 Shallow pitting. Lt. Deposits. 30 983 0 0.03 13 2 2.93 Shallow pitting. 31 1014 0 0.04 14 :3 2.94 Shallow pitting. 32 1045 0 0.03 13 2 2.94 Shallow pitting. 33 1077 0 0.04 16 2 2.93 Shallow pitting. 34 1108 () 0.03 13 2 2.94 Shallow pitting. Lt. Deposits. 35 1140 0 0.04 14 3 2.94 Shallow pitting. 36 1170 0 0.03 12 3 2.94 37 1201 0 0.03 13 2 2.94 Shallow corrosion. 38 1233 0 0.04 16 2 2.90 Shallow corrosion. Lt. Deposits. 39 1264 0 0.04 16 4 2.94 Shallow corrosion. 40 1296 0 0.03 12 2 2.93 41 1327 0 0.03 13 2 2.92 Shallow corrosion. 42 1359 0 0.02 9 2 2.93 43 1389 0 0.04 15 2 2.94 Shallow corrosion. 44 1420 0 0.03 13 2 2.93 Shallow pitting. 45 1452 0 0.04 17 :3 2.93 Shallow pitting. Lt. Deposits. 46 1484 0 0.03 13 3 2.95 Shallow pitting. I Penetration Body !~¡;;! Metal Loss Body Page 1 ,( ~. PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: 1 0-1 06 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC Nominal 1.0.: 2.992 in Country: USA Survey Date: July 28,2005 Joint Jt. Depth Pen. Pen. Pen. MC't(] Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) 01<) (Ins.) 0 50 100 47 1515 0 0.04 16 2 2.93 Shallow corrosion. Lt. Deposits. 48 1546 0 0.03 11 4 2.95 49 1577 () 0.03 13 2 2.94 Shallow pitting. 50 1609 0 0.03 12 2 2.93 51 1640 0 0.04 14 2 2.91 Shallow corrosion. 52 1669 0 0.04 14 5 2.94 Shallow pitting. 53 1701 0 0.03 13 2 2.93 Shallow pitting. 54 1731 0 0.03 13 2 2.93 Shallow pitting. 55 1762 0 0.03 13 2 2.95 Shallow pitting. 56 1794 0 0.03 13 2 2.94 Shallow pitting. 57 1825 0 0.04 14 2 2.95 Shallow pitting. 58 1857 0 0.04 14 :3 2.90 Shallow pitting. 59 1888 0 0.03 11 2 2.93 60 1919 0 0.05 19 2 2.94 Shallow pitting. 61 1951 0 0.04 15 2 2.95 Shallow pitting. 62 1983 0 0.03 10 :3 2.91 63 2014 0 0.05 19 4 2.93 Shallow corrosion. 64 2046 0 0.04 16 5 2.88 Shallow corrosion. Lt. Deposits. 65 2077 0 0.03 11 3 2.92 66 2108 0 0.03 11 2 2.94 67 2140 0 0.03 11 4 2.92 68 2171 0 0.04 17 4 2.89 Shallow pitting. 69 2203 (lOb 0.04 14 5 2.87 Shallow corrosion. 70 2234 0 0.03 12 3 2.91 Shallow pitting. 71 2266 0 0.04 16 3 2.92 Shallow pitting. 72 2297 0 0.03 12 4 2.91 Shallow pitting. 73 2329 () 0.12 48 7 2.89 Corrosion. 74 2360 0 0.03 11 4 2.91 75 2392 0 0.09 37 6 2.93 Isolated pitting. Lt. Deposits. 76 2423 0 0.15 59 5 2.92 Line of Pits. 77 2455 0 0.09 37 5 2.92 Line of Pits. 78 2486 0 0.06 25 4 2.86 Line of Pits. 79 2518 0 0.18 71 4 2.88 Line of Pits. 80 2549 0 0.07 26 5 2.90 Line of Pits. 81 2580 0 0.15 59 5 2.91 Line of Pits. 82 2612 0 0.05 18 :3 2.93 Line of Pits. 83 2642 () 0.12 49 9 2.86 Line of Pits. 84 2674 () 0.06 22 5 2.88 Line of Pits. Lt. Deposits. 85 2705 0 0.11 44 6 2.89 Line of Pits. 86 2736 0 0.13 53 10 2.90 Line of Pits. 87 2767 0 0.09 35 4 2.88 Line of Pits. 88 2799 0 0.13 51 6 2.88 Line of Pits. 89 2830 0 0.13 52 6 2.90 Line of Pits. 90 2862 0 0.14 54 6 2.92 Line of Pits. 91 2893 0 0.11 44 4 2.88 Line of Pits. 92 2924 0 0.13 51 6 2.85 Line of Pits. Lt. Deposits. 93 2956 0 0.14 54 5 2.88 Line of Pits. Lt. Deposits. 94 2987 0 0.12 48 5 2.90 Line of Pits. 95 3019 0 0.14 54 6 2.89 Line of Pits. 96 3050 0 0.13 52 7 2.90 Line of Pits. I Penetration Body ¿);: Metal Loss Body Page 2 ,'I '1, PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 ABM-EUE Well: 1 D-l 06 Body Wall: 0.254 in Field: KUPARUK Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA INC NominaII.D.: 2.992 in Country: USA Survey Date: July 28,2005 Joint Jt. Depth Pr ). Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 0/0 (Ins.) 0 50 100 97 3082 0 0.11 42 6 2.90 Line of Pits. 98 3113 0 0.11 42 6 2.88 Line of Pits. Lt. Deposits. 99 3144 0 0.12 48 7 2.89 Line of Pits. 100 3176 0 0.12 46 () 2.89 Line of Pits. Lt. Deposits. 101 3207 0.08 0.13 53 S 2.91 Line of Pits. 102 3239 0.10 0.11 42 7 2.92 Line Corrosion. 103 3270 0 0.09 37 5 2.88 Line Corrosion. 104 3302 0 0.11 45 6 2.90 Line Corrosion. 105 3333 0 0.11 42 7 2.92 Line Corrosion. Lt. Deposits. 106 3365 0 0.12 47 4 2.93 Line Corrosion. 107 3396 0 0.14 54 4 2.94 Line Corrosion. 108 3427 0 0.10 39 6 2.92 Line Corrosion. 109 3459 0 0.11 42 6 2.95 Line Corrosion. 110 3490 0 0.08 33 6 2.94 Line Corrosion. 111 3521 0 0.08 31 4 2.94 Line Corrosion. Lt. Deposits. 112 3550 0.09 0.08 31 4 2.92 Line Corrosion. 113 3581 0 0.09 34 4 2.93 Line Corrosion. 114 3613 0 0.10 41 5 2.94 Line Corrosion. Lt. DepQsits. 115 3644 0 0.10 40 5 2.93 Line Corrosion. 116 3676 0.06 0.08 32 4 2.91 Line Corrosion. 117 3707 0 0.10 39 4 2.91 Line corrosion. 118 3738 0 0.09 37 6 2.94 Line Corrosion. 119 3770 0 0.13 50 4 2.92 Line Corrosion. 120 3802 0 0.12 47 6 2.93 Line Corrosion. 121 3833 0 0.12 45 6 2.91 Line Corrosion. 122 3864 0 0.10 39 5 2.92 Line Corrosion. Lt. Deposits. 123 3896 0.08 0.10 41 6 2.93 Corrosion. Lt. Deposits. 124 3927 0 0.11 42 5 2.91 Line corrosion. 125 3959 0 0.10 38 5 2.94 Line Corrosion. 126 3990 0 0.14 55 6 2.92 Line Corrosion. 127 4022 0 0.13 50 7 2.93 Line Corrosion. 128 4053 0 0.12 46 7 2.92 Line Corrosion. Lt. Deposits. 129 4084 0 0.13 53 6 2.93 Line corrosion. 130 4116 0 0.14 54 5 2.92 Line corrosion. 131 .4147 0 0.12 49 6 2.92 Line Corrosion. 132 4178 0.10 0.14 54 6 2.93 Line Corrosion. Lt. Deposits. 133 4209 ' OJ)6 0.15 58 6 2.92 Line Corrosion. 134 4240 0.07 0.16 63 7 2.94 Line Corrosion. 134.1 4271 0 0.11 41 5 2.91 PUP Line corrosion. 134.2 4286 0 0 0 0 N/A GLM 1 (Latch @ 11 :00) 134.3 4293 0.06 0.17 68 7 2.91 PUP Line Corrosion. Lt. Deposits. 135 4308 D.07 0.13 53 6 2.94 Line Corrosion. 135.1 4339 0 0 0 0 2.81 W-1 NIPPLE 136 4341 0 0.15 57 6 2.91 Line Corrosion. 136.1 4371 () 0.11 43 8 2.89 PUP Isolated pitting. Lt. Deposits. 136.2 4378 0 0 0 0 3.00 SEAL ASSY 136.3 4395 0 0.12 46 8 2.91 PUP Isolated pitting. 137 4401 0 0.13 52 8 2.91 Line corrosion. Lt. Deposits. 138 4432 0 0.02 7 1 2.93 I Penetration Body Metal Loss Body Page 3 ..I-Is ~ g. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-106 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 ABM-EUE Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28, 2005 MFC 24 No 00387 1.69 24 J. Thompson Cross Section for Joint 79 at depth 2541 .21 ft Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 51 0 Finger 22 Penetration = 0.18 ins Line of Pits 0.18 ins = 71%Wall Penetration HIGH SIDE = UP Cross Sections page 1 ..1 ~. ou .. ·..5 ~ 5' Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-106 KUPARUK CONOCOPHILLlPS ALASKA INC USA 3.5 ins 9.3 ppf L-80 ABM-EUE Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28, 2005 MFC 24 No 00387 1.69 24 j. Thompson Cross Section for Joint 134.3 at depth 4293.04 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 24 0 Finger 6 Penetration = 0.172 ins Line of Pits 0.17 ins = 68% Wall Penetration HIGH SIDE::::; UP Cross Sections page 2 ~ 8' ''''''''', ConocoPhillips Alaska, Inc. 1 D-1 06 API: 500292284700 SSSV Type: None ìUBING (0-4376, 00:3.500, 10:2.992) SURFACE (0-4376, 00:5.500, Wt15.50) NIP (4339-4340, 00:3.500) LINER (4376-5116, 00:3.500, Wt9.30) SBE (4377-4389, 00:4.000) Perf (4462-4496) Perf (4530-4570) PLUG (4575-4576, 00:3.500) Perf (4580-4600) Perf (4668-4680) Perf (4722-4762) Perf (4779-47~4) PLUG (4995-4996, OD:3.500) 'II Annular Fluid: Reference Log: Last Tag: 4777 Last Tag Date: 6122/2002 Casing String - All STRINGS Description CONDUCTOR SURFACE LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 4462 - 4496 3708 - 3740 4530 - 4570 3771 - 3809 4580 - 4600 3818 - 3837 4668 - 4680 3901 - 3912 4722 - 4762 3952 - 3990 4779 - 4794 4006 - 4020 Gas Lift MandrelsNalves St MD TVD Man Man Type Mfr 1 4286 3547 BST AXT Other (plugs, equip" etc.) - JEWELRY Depth TVD Type 4339 3595 NIP 4377 3630 SBE 4575 3813 PLUG 4995 4210 PLUG 5116 4325 SHOE I' ~ KRU 1 D-1 06 Well Type: INJ Orig 1/19/1998 Completion: Last W/O: Ref Log Date: TD: 5126 ftKB Max Hole Angle: 50 deg @ 3287 Angle @ TS: deg @ Angle @ TD: 18 deg @ 5126 Rev Reason: Tag, set Plug Last Update: 3/5(2004 Size Top Bottom TVD Wt Grade Thread 16.000 0 121 121 62.58 H-40 Welded 5.500 0 4376 3629 15.50 L-80 MBTC 3.500 4376 5116 4325 9.30 L-80 ABM-EUE Bottom TVD Wt Grade Thread 4376 3629 9.30 L-80 ABM-EUE Zone Status Ft SPF Date Type Comment WSD 34 4 8/11/1998 IPERF 2 1(2" HC, DP, 180 deg phasing, 90 deg orientation WS C,WS 40 4 9/9/1998 IPERF 2 1(2" HC, DP, 180 deg B phasing, 90 deg orientation WSA4 20 4 9/9/1998 IPERF 2 1(2" HC, DP. 180 deg phasing. 90 deg orientation WSA3 12 4 9/9/1998 IPERF 21(2" HC, DP, 180 deg phasing, 90 deg orientation WSA2 40 4 7/19/1998 IPERF 2 1(2" HC, DP, 180 deg phasing, 90 deg orientation WSA2 15 4 7/19/1998 IPERF 2 112" HC, DP, 180 deg phasing, 90 deg orientation VMfr BST V Type VOD latch DMY' 3.5 T-1 Description Vlv Cmnt Port TRO o Date Run 6/15/1998 0.000 3 1/2" W-1 w/selective nipple Baker locator seal assembly stabbed into SBE WEATHERFORD RBP set 7/19(2002 Drillable bridge plug - 4600' - 3 1/2" Halliburton. Bridge plug was drilled out by CTU pushed to bottom @ 4995' RKB. ID 2.812 3.000 0.000 2.992 3.000 Sperry-Sun Drilling Services LIS Scan Utility Wed Feb 11 11:03:29 1998 Reel Header Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80086 P. SMITH D. BREEDEN 1D-106 500292284700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES Il-FEB-98 MWD RUN 2 AK-MM-80086 P. SMITH D. BREEDEN 14 liN 10E 104 595 .00 111.40 70.40 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 118.0 5.500 4357.0 3.500 5126.0 8.500 5126.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 09 FEBRUARY, 1998. 4. ALL GAMMA RAY DATA (SGRC) HAS BEEN CORRECTED TO PROPER CALIBRATION VALUES. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5126'MD, 4335'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMNARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ START DEPTH STOP DEPTH 92.0 5096.5 121.0 5089.5 121.0 5089.5 121.0 5089.5 121.0 5089.5 121.0 5089.5 122.5 5126.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 122.0 3344.0 2 3344.0 5126.0 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 DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OPIMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 92 5126 2609 10069 GR 9.2959 145.709 67.3889 10010 RPX 0.2908 2000 64.119 9938 RPS 0.2974 2000 73.9795 9938 RPM 0.3258 2000 89.9999 9938 RPD 0.274 2000 91.9884 9938 ROP 13.284 989.648 259.903 10008 FET 0.0601 10.5057 0.35344 9938 First Reading 92 92 121 121 121 121 122.5 121 Last Reading 5126 5096.5 5089.5 5089.5 5089.5 5089.5 5126 5089.5 First Reading For Entire File .......... 92 Last Reading For Entire File ........... 5126 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 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 ....... 98/02/11 Maximum Physical Recordo.65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLrMBER: 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 92 . 0 3313 . 5 FET 121.0 3306 . 5 RPD 121 . 0 3306 . 5 RPM 121.0 3306 . 5 RPS 121 . 0 3306 . 5 RPX 121 . 0 3306 . 5 ROP 122 . 5 3343 . 5 $ LOG HEADER DATA DATE LOGGED: 14-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 3344.0 TOP LOG INTERVAL (FT): 122.0 BOTTOM LOG INTERVAL (FT): 3344.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 50.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0891CRG6 EWR4 ELECTROMAG. RESIS. 4 P0891CRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER' S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD MUD DENSITY (LB/G) : 169.20 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...0 360.0 8.8 450 7.6 6.000 5.554 7.800 3.100 Name Service Order Units DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OPIMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 24.8 Name Min Max Mean Nsam DEPT 92 3343.5 1717.75 6504 GR 9.2959 145.709 63.725 6444 RPX 1.3386 2000 95.1372 6372 RPS 1.445 2000 110.504 6372 RPM 0.6696 2000 135.653 6372 RPD 0.9058 2000 138.669 6372 ROP 15.2271 989.648 296.652 6443 FET 0.0601 1.3472 0.223787 6372 First Reading 92 92 121 121 121 121 122.5 121 Last Reading 3343.5 3313.5 3306.5 3306.5 3306.5 3306.5 3343.5 3306.5 First Reading For Entire File .......... 92 Last Reading For Entire File ........... 3343.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 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 ....... 98/02/11 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 FET 3307 . 5 5089 . 5 RPD 3307.5 5089 . 5 RPM 3307.5 5089 . 5 RPS 3307 . 5 5089 . 5 RPX 3307 . 5 5089 . 5 GR 3315 . 0 5096.5 ROP 3345 . 5 5126 . 0 $ LOG HEADER DATA DATE LOGGED: 15-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 5126.0 TOP LOG INTERVAL (FT): 3344.0 BOTTOM LOG INTERVAL (FT): 5126.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .1 MAXIMUM ANGLE: 50.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0891CRG6 EWR4 ELECTROMAG. RESIS. 4 P0891CRG6 $ 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 8.5OO 8.5 SPUD MUD 175.00 370.0 8.0 50O 10.0 6.100 4.740 7.700 3.300 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHFLM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 34.5 Name Min DEPT 3307.5 GR 16.4307 RPX 0.2908 RPS 0.2974 RPM 0.3258 RPD 0.274 ROP 13.284 Max 5126 140 482 266 767 181 801 137 973 115 602 642 678 Mean 4216.75 74.0206 8.69364 8.71538 8.42316 8.57499 193.528 Nsam 3638 3564 3565 3565 3565 3565 3562 First Reading 3307.5 3315 3307.5 3307.5 3307.5 3307.5 3345.5 Last Reading 5126 5096.5 5089.5 5O89.5 5089.5 5089.5 5126 FET 0.1207 10.5057 0.583821 3565 3307.5 5089.5 First Reading For Entire File .......... 3307.5 Last Reading For Entire File ........... 5126 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/02/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/02/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
