The URL can be used to link to this page

Home My WebLink About200-128By Grace Christianson at 8:39 am, Jun 20, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.06.18 10:33:49 - 08'00' Sean McLaughlin (4311) 325-371 10-407 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. *Sealing whipstock with < 100' for liner lap cement JJL 6/24/25 A.Dewhurst 23JUN25 DSR-6/23/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.25 12:09:41 -08'00'06/25/25 RBDMS JSB 062625 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: June 18, 2025 Re:H-07A Sundry Request Sundry approval is requested to set a whipstock in the H-07A wellbore as part of the drilling and completion of the proposed H-07B CTD lateral. Proposed plan: A RWO will be performed to pull the 7” tubing and install new 4-1/2" completion and MIT (separate Sundry). Prior to drilling activities, screening will be conducted to drift for whipstock. Caliper 7" before setting whipstock. E-line will set a 4-1/2"x7" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See H-07B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x7" whipstock. A single string 3.80" window + 10' of formation will be milled (if not milled pre- rig). The well will kick off drilling in the Sag/Shublik and lands in Ivishak Zone 4. The lateral will continue in the Sag to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in July 2025) 1. RWO : 4-1/2" Tubing Swap and MIT (separate sundry) 2. Slickline : Pull ball and rod. Dummy WS drift. 7" Caliper. 3. E-Line : Set 4-1/2"x7" Whipstock at 10,165’ MD at 180 degrees ROHS 4. Coil : Mill 3.80" Single String 7" Window (if window not possible, mill with rig). 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: x Reference H-07B Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,415 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Single String 7" Window (if not already done pre-rig). 3. Drill build section: 4.25" OH, ~742' (18 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,404' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 43 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. Set LTP* (if not on losses). 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM, liner CBL and perforate (~300’) 4. Testing : Portable test separator flowback. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 10,018'10,018' 9,960'9,960' 9,990'9,990' 9,449' 9,374'4-1/2"x9-5/8" TNT Packer9,374' 11,000'11,000' Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:21 Township:11N Range:13E Meridian:Umiat Drilling Rig:N/A Rig Elevation:N/A Total Depth:11,335 ft MD Lease No.:ADL 0028284 Operator Rep:Suspend:P&A:X Conductor:20" x 30"O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2,716 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 9,935 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 10,581 Feet Csg Cut@ Feet Liner:2-7/8"O.D. Shoe@ 11,335 Feet Csg Cut@ Feet Tubing:7"O.D. Tail@ 9,469 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 10,840 ft 10,238 ft Diesel Wireline tag Initial 15 min 30 min 45 min Result Tubing 2723 2674 2654 IA 2738 2690 2671 OA 3 3 3 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: This report reflects the the plug and abandonment of existing perfs for future sidetrack. Cement layed in on top of CIBP @ 10,840 ft MD up thru 2 7/8-inch liner and 7-inch liner to target of 10,240 ft MD. CMIT TxIA to 2500 passed. May 28, 2025 Sully Sullivan Well Bore Plug & Abandonment PBU H-07A Hilcorp North Slope LLC PTD 2001280; Sundry 325-226 none Test Data: P Casing Removal: Nick Draper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-0528_Plug_Verification_PBU_H-07A_ss                       PBU H-07A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-128 50-029-20242-01-00 341J ADL 0028284 11335 9076 80 2687 9905 1149 1066 10840 20" x 30" 13-3/8" 9-5/8" 7" 2-7/8" 8946 30 - 110 29 - 2716 27 - 9935 9432 - 10581 10269 - 11335 2520 30 - 110 29 - 2716 27 - 8401 8064 - 8841 8622 - 9076 Unknown10840 4930 6870 8160 13450 10798 - 10939 7" 26# N-80 25 - 94698935 - 8972 7" Baker SS Packer No SSSV Installed 9472, 8092 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 PRUDHOE BAY 5/15/2025 PRUDHOE OIL PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.14 15:07:30 - 08'00' Torin Roschinger (4662) 325-226 By Gavin Gluyas at 3:42 pm, Apr 14, 2025 DSR-4/17/25SFD 5/5/2025JJL 4/21/25 10-407 X AOGCC Witnessed tag TOC. AOGCC Witnessed MIT-T or CMIT-TxIA to 2500 psi. AOGCC Witnessed BOP test to 3500 psi, Annular test to 2500 psi. XX SFD SFD *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.05 14:32:40 -08'00'05/05/25 RBDMS JSB 050825 Page 1 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Well Name:H-07A API Number:50-029-20242-01 Current Status:Producer PTD #200-128 Estimated Start Date:5/15/2025 Rig:Innovation Reg.Approval Req’std?10-403, 10-404 Estimated Duration:10 days Regulatory Contact:Abbie Barker 907-564-4915 (O) First Call Engineer:Brenden Swensen 907-748-8581 (M) Second Call Engineer:Finn Oestgaard 907-350-8420 (M) Current Bottom Hole Pressure:3,200 psi @ 8,800’ TVD (7.0 ppge, based on offsets) Maximum Expected BHP:3,400 psi @ 8,800’ TVD (est.) 7.5ppg EMW Max. Anticipated Surface Pressure:2,520 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:2,100 psi (3/25/2025) H2S Level (Most Recent /Highest):20ppm 02/25/2023, 42ppm 05/20/2021 History H-07A was completed in September 2000with original perforations in Zone 2B. Additional perfs in Zone 2C were added in June of 2002. A PPROF in 2014 showed the lower perforations making most of the water. A plug was set in the liner at 10840’ MD as a successful water shut off. However, the PPROF also identified a hole in the liner at 10269’ MD which was contributing rich gas from Ivishak Z4. In 2017 another plug was set at 10720’ MD to isolate the remaining Z2 perfs and test just the Z4 rich gas. Slickline was unable to retrieve the plug and determined that the liner hole had collapsed, or the liner top was damaged. The well was then planned for a CTD sidetrack but service coil had issues retrieving the ArrowPak patch. Plans to sidetrack the well were abandoned and it has remained shut-in since late 2017. Objective Reservoir plug and abandon the existing perforations. Pull the existing 7” tubing and stuck ArrowPak patch. Run new 4.5” completion. Upon successful completion of the RWO, the well will be prepped for a CTD sidetrack. Well Condition Date Pressure Pass? Event Type 4/4/2025 2981psi Y MIT-IA 8/18/2021 2675psi Y MIT-IA 4/9/2025 5000psi Y PPPOT-T 4/9/2025 3500psi Y PPPOT-IC MIT-IA fails without dummy SSSV set at 2170’ MD. Tubing patch across tubing punch requires removal for CTD. well will be prepped for a CTD sidetrack Page 2 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Procedure (Page 1 of 4) Pre Rig Steps (Page 1 of 2) Slickline 1. Pull DSSSV from 2,170’ MD. Coil Tubing 2. Perform reservoir P&A by laying in ±5 bbls 15.8ppg class G cement from CIBP at 10840’ MD to above top of liner; target TOC 10,240’ MD. a. 2-7/8” liner volume to bottom perf at 10,808’ MD = 3.1 bbls b. 7” liner volume from top of 3.5” liner to target top of cement 10,240’ MD = 1 bbl c. Proposed kick out point for CTD 10,165’ MD, bottom set whipstock 10,183’ MD d. Expected BHT 220degF at 8,900’ TVD /10,720’ MD. e. Minimum cement thickening time target = 6 hours i. 1 hour to batch ii. 2 hours to place @ 1bpm iii. 3 hours contingency 3. Perform a hesitation squeeze to 1000psi above WHP. a. Monitor squeezed cement volumes to maintain TOC above final target top of 10,240’ MD. 4. Wash excess cement down to target 10,240’ MD. a. Target top of whipstock set depth 10,165’ MD, ensure area is well flushed to minimize leaving possible cement stringers. Slickline, Fullbore Assist 5. Wait 72 hours on cement before rigging up. 6. Contact AOGCC for witnessed tag and MITs 48 hours ahead of beginning work. 7. Drift and tag top of cement. a. Target top of whipstock set depth 10,165’ MD. 8. Perform MIT-T / CMIT-IA to 2500psi to confirm cement plug is holding. a. If tag is deep or CMIT-IA fails, will repeat cement squeeze as necessary. b. If tag is too shallow for whipstock set, coil will need to pick up motor and underream down to target TOC depth. Perform reservoir P&A Page 3 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Procedure (Page 2 of 4) Pre Rig Steps (Page 2 of 2) Eline, Fullbore Assist 9. Punch 10’ of tubing just above PBR assembly from ±9,415– 9,425’ MD. a. Not much jewelry to tie into. Target first collar above PBR assembly @ 9,432’ MD. b. 2017 caliper attached. Depths do not match schematic. Reference schematic depths on punch. 10. Confirm circulation between tubing and IA. a. If circulation is not established, contact OE and prepare to perform additional tbg punch. 11. Circulate ±790bbls or ±2.5 IA volumes of 1% KCL down the tubing and up the IA to fluid pack well with 8.5ppg KWF. a. Tubing volume 393bbls, IA volume 263 bbls DHD 12. Bleed WHP to 0psi. Confirm well is dead. Valve Shop 13. Set and test two way check (TWC). Proposed Rig Work Over Procedure (Page 1 of 3) 14. MIRU Innovation Rig. 15. Nipple down tree and tubing head adaptor. a. The current tubing hanger and THA are obsolete and will need to be replaced. b. A new THA and tubing hanger will be used so that the tree can be reused. 16. Nipple up BOPE. a. configuration top down: i. Annular BOP ii. 3.5” x 6” VBRs iii. Blind rams iv. Integral flow cross v. 7” fixed rams Page 4 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Procedure (Page 3 of 4) Proposed Rig Work Over Procedure (Page 2 of 3) 17. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 3.5” x 6” VBRs with 4” work string test joint. e. Test the annular with 4” work string test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 18. RU lubricator and pull TWC. 19. Rock out diesel freeze protect with 8.5ppg KCL or seawater. 20. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.5ppg = ±215k #. 21. RU control line spooler for SSSV control line. a. Original tubing tally suggests control line has 2 bands per joint to 2,138’ MD. b. 54 joints, anticipate 108 bands. i. Record band count in preparation for fishing any missing bands if necessary. 22. Make attempt to pull 7” tubing by releasing tubing from seal bore assembly at 9,432’ MD. 23. If tubing does not release from seal bore assembly, make tubing cut just above the ArrowPak patch at ±4,600’ MD with 4” work string mechanical cutter. a. No 7” tubing cutters available that will fit through 2.9” ID of patch to cut deep. b. Prefer to cut with work string vs rigging up eline due to shallow depth of cut. c. Will spear 7” tubing just above the patch with 5” work string and attempt a 7” tubing back off with an eline assisted string shot configured below the patch. i. Once speared, make another attempt to jar tubing free from seal bore prior to back off attempt. d. If back off is unsuccessful, burning over patch will be next option for retrieving patch and tubing. Subsequent tubing cuts will be made to get new packer to target depth. 24. Lay down 7” completion. Page 5 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Procedure (Page 4 of 4) Proposed RWO Procedure (Page 3 of 3) 25. Make clean out run with work string to top of cement prior to running new completion. a. Target TOC is 10,240’ MD. Confirm SL tag depth ahead of clean out run. 26. Run 4-1/2” gas lifted tubing string with stacker packer completion as detailed on tally attached. a. Torque turn connections. 27. Land hanger and reverse in corrosion inhibited 8.5 ppg KCl or seawater. 28. Drop ball and rod and set packer. Target packer set depth ±9,360’ MD. 29. Perform MIT-T to 3,000 psi and MIT-IA to 2,600 psi for 30 charted minutes. 30. Shear the shear out valve in the top GLM. a. Freeze protect well to 2,200’ with diesel. 31. Set TWC. 32. Rig down Innovation Rig. Post Rig Steps: Post rig valve shop work 33. ND BOPE. 34. NU tree and tubing head adapter. 35. Test both tree and tubing hanger void to 500psi low/5,000psi high. 36. Pull TWC. Post rig Slickline Work 37. Pull shear valve and run dummy gas lift valve. a. Will leave well dummied in prep for CTD. 38. Pull Ball and rod and RHC profile. Attachments: Current Wellbore Schematic Proposed Wellbore Schematic Innovation BOPE Schematics Original Tubing Tally Caliper Log Sundry Change Form Page 6 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Page 7 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Page 8 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Innovation RigBOP Schematic Innovation Rig Choke Manifold Page 9 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Original 7” Tubing Tally Page 10 of 10 Tubing Swap RWO For Pre-CTD Well: H-07A PTD: 200-128 Target ±5’ on either side of one of these 2 collars for initial 10’ punch Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 14, 2025Subject: Changes to Approved Sundry Procedure for Well H-07ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brenden Swensen To:Lau, Jack J (OGC) Cc:Torin Roschinger Subject:RE: [EXTERNAL] PBU_H-07A (200-128) Res P&A Date:Monday, April 21, 2025 2:55:59 PM Attachments:H-07_CBL_11May77.pdf Hello Jack, Attached is a CBL that was ran in 1977 after the original completion. Based on this CBL, I interpret TOC at 9,484’ MD when reviewing the amplitude shift as well as the visible changes in the variable density curves. This just below the 9-5/8” x 7” BOT SS packer at 9,472’ MD and above the 9-5/8” casing shoe at 9,935’ MD. The well is anticipated to take some volume of cement. However, the small excess volume is for 2 reasons. • The cement plug’s primary objective is to act as a well barrier for the RWO by isolating the well from the existing perforations. • A whipstock is intended to be ran after the RWO. Minimizing cement stringers across the setting intervals is ideal to ensure the highest chance of success of getting a whipstock to set. The current volume of cement allows us to keep all cement below the target whipstock setting depths. Step 11 does not specify for a freeze protect. The primary objective of this step is to ensure KWF as a second barrier for the RWO, and to flush/clear debris on the back side of the 7” tubing to increase chance of success of tubing retrieval. The well can be freeze protected at Well Site Leader discretion based on season and timing of the rig arriving after the fluids are pumped. Formation tops provided by our Geologist. Top MD TVDss TKNG/BHRZ 8,440 7,233 TJB 9,846 8,266 Casing Shoe 9,935 8,324 TJA 9,958 8,340 TSGR (above window) 10,093 8,429 TSHU (above window) 10,142 8,461 TSAD / TZ4 (above window) 10,266 8,544 TCGL / TZ3 (above window) 10,507 8,708 Top of Window 10,581 8,768 Base of Window 10,588 8,772 BCGL / TZ2C 10,651 8,808 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 23SB / TZ2B 10,808 8,867 21TS / TZ2A 11,117 8,949 TD 11,340 9,006 Thanks, Brenden Swensen GC2 Main Field Ops Engineer (HJNQRU pads) 907-748-8581 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, April 15, 2025 2:23 PM To: Brenden Swensen <Brenden.Swensen@hilcorp.com> Subject: [EXTERNAL] PBU_H-07A (200-128) Res P&A Brenden – Reviewing your sundry application for H-07A and have the following requests... Is there existing cement behind the 7" liner? If so, what is the top of cement (TOC) behind the liner? Is this well anticipated to take cement during the operation? Noting that only 0.9 bbls of excess cement is planned. Step 11 appears to leave the well without freeze protect. Is this intentional? Could you provide the formation top depths for well H-07A, particularly in the vicinity of the TOC and the coiled tubing kick-off (CTD KO) depth? Thanks! Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Plug for Redrill against P&A" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer 325-226 SFD 5/5/2025 SFD 5/5/2025 200-128 PBU H-07A CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Abbie Barker To:AOGCC Permitting (CED sponsored) Cc:Rixse, Melvin G (OGC); Stan Golis; Brodie Wages Subject:Cancellation: PBU H-07A (PTD #200-128) Sundry #321-275 Date:Friday, February 25, 2022 2:54:11 PM Attachments:Appr Sundry_321-275_060721 H-07A RWO.pdf Hello, Please cancel Sundry #321-275 (copy attached). No work covered by this sundry that requires a 10- 404 report has been completed and the RWO will not be executed at this time. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:200-128 6.API Number:50-029-20242-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028284 Property Designation (Lease Number):10. 341H 8. PBU H-07A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Tubing Swap RWO Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11335 Effective Depth MD: N-80 11. 6/1/2021 Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: David.Wages@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9076 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 9472, 8092 No SSSV Installed Date: Liner 1066 2-7/8" 10269 - 11335 8622 - 9076 13450 13890 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 29 - 2716 29 - 2716 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural 6870 Proposal Summary 13. Well Class after proposed work: 7" Baker SS Packer 10798 - 10939 8935 - 8972 7" 26# 25 - 9469 Liner 2170 2170 2170, 10720, 10840 10269 30 - 110 13-3/8" 9-5/8" Contact Phone:907.564.5006 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2687 4930 Intermediate 9905 27 - 9935 27 - 8401 1149 7"9432 - 10581 8064 - 8841 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2265 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:07 pm, Jun 02, 2021 321-275 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.02 12:45:03 -08'00' Stan Golis (880) X * Test BOPE to 3500 psi. Annular to 2500 psi. * Separate sundry approval required for e-line perforating. 2265 10-404 MGR04JUN21 DLB06/02/2021 DSR-6/2/21 dts 6/7/2021 JLC 6/7/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.07 10:01:05 -08'00' RBDMS HEW 6/7/2021 H-07A Integrity RWO Well: H-07A PTD:200-128 Well Name:H-07a API Number:50-029-20242-01 Current Status:Offline, Not Operable Rig:Thunderbird #1 Estimated Start:June 2021 Estimated Duration:3 days Operations Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Reservoir Engineer:Laurie Derrick (907) 564 5279 (O)(720) 308-3386 (M) Geologist:Ashlyn Murphy (907) 564-4889 (O)(832) 417-1640 (M) Current Bottom Hole Pressure:3125 psi @ 8600’ TVD 7.4 ppg | 2009 SBHP + Safety Max. Anticipated Surface Pressure:2265 psi 0.1 psi/ft gas to surface Last SI WHP:1042 psi Taken 4/28/2021 Min ID:2.9” tubing collapse @ 4620’ (7” Arrow Patch, 7/08) Max Angle:77.3 deg @ 11,290’ MD Objective:Restore tubing integrity and return the well to production from the Ivishak and add Sag perforations. Pull the existing tubing string to repair TxIA and remove the 7” arrow pac patch with stuck releasable spear. Post rig coil will fish the WRP elements and retrieve WRP from 10720’ md to regain Ivishak Zone 2 production. Allow Ivishak Z4 production to continue from CTD liner top. Eline to add Sag perforations. Brief Well History: H-07A was completed in September 2000. The original perfs were in Zone 2B and they made approximately 500 bfpd at 50% WC and 40,000 scf/bbl GOR. Additional perfs in zone 2C were added in June 2002, these perfs came online at 2000 bopd, 10% WC, 6,000 scf/bbl GOR. H-07A produced from these perfs until a PPROF in 2014 showed the lower perfs were making most of the water and a plug was set at 10840’md, which shut off all of the water. During that PPROF a hole in the liner at 10269’md was identified, which was making rich gas from Ivishak Z4. In 2017 a plug was set at 10720’ md to test the leaking Z4 liner hole to determine if the production was competitive. The well made 466 bopd, 22 mmscfd, 49,000 scf/bbl GOR during these tests. When slickline attempted to retrieve the plug, it was found that the liner hole was collapsed or the CTD liner top was damaged and they were unable to retrieve the plug. Shortly after, the well was planned for coil tubing sidetrack, but the fishing spear for the 7” patch was stuck and coil was unable to retrieve it. Plans to sidetrack the well were abandoned and it has remained shut-in since late 2017. Surface Infrastructure: H-07A has access to GC2 HP via the 42H header, GC2 LP via the 44H header and the GC1 HP annex via the 47H header. Package benefits were run assuming H-07A would flow to the GC1 annex where the MGOR is higher. Notes Regarding Wellbore Condition: >07/16/19: Set SSSV plug @ 2710' MD >03/03/19: Pulled SSSV Plug > 02/12/19: Set SSSV Plug @ 2170' MD >01/29/19: Pulled RBP from 4,265' MD >05/27/18: Set RBP @ 4265' MD (above packer) >03/26/18: PPPOT-T Passed, PPPOT-IC Failed >07/05/17: Caliper, MIT-IA Passed to 1744 psi > 07/04/17: MIT-IA Failed >04/03/17: Set WRP @ 10720' MD H-07A Integrity RWO Well: H-07A PTD:200-128 >03/29/15: MIT-OA Failed, MIT-OA W/ N2 Failed >03/28/15: MIT-IA Passed to 2500 psi Procedure: DHD – MIT OA – 1200 psi CMIT-TxIA to 3,500-psi, run eline LDL if failing. Cycle LDS PPPOT-T PPPOT-IC SL – Drift, pull plug in SSSV nipple, Drift EL – Shoot string shot at PBR (attempt to rattle PBR to make easier to pull) Load hole with KWF, set IBP, LDL if necessary DHD – Bleed WHP’s to 0 Valve Shop – Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. Tubing barriers: IBP and TWC Casing barriers: Production packer and tubing hanger NU BOPE configured top down, Annular, 4-1/2” x 7” VBRs, Blinds and integral flow cross. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 4-1/2” x 7” VBR’s with 4-1/2” and 7” test joints. Test the Annular preventer with a 4-1/2” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear 5. BOLDS and pull hanger to the floor. a. Per Baker rep: this PBR shouldn’t have a latch b. PU weights are expected to be ~220K c. 7” 26# N80 yield: 604k# d. If we are unable to pull out of sealbore, we will cut the tubing to ensure we can still latch onto the tubing stub 6. Circ out diesel freeze protect 7. Pull 7” tubing to floor, circulate bottoms up. If unable to pull out of the sealbore, options for pulling tubing string will be considered including jarring the tubing patch out and cutting the 7” tubing above the PBR: 8. Run 4 ½” L80 tubing proposed schematic. 9. Land Hanger and reverse in corrosion inhibited 8.5ppg 1%KCl 10. Drop ball and rod and set packer with 3,500psi pump pressure. IBP set depth: ~10,260' MD, 2.5" IBP rated to 2300 psi in 7" liner. Pressure test IBP to 1000 psi. H-07A Integrity RWO Well: H-07A PTD:200-128 11. Perform MIT-T to 3,500 psi and MIT-IA to 3,500 psi for 30 charted minutes. 12. Shear valve in upper GLM. 13. Set TWC 14. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. Pull PX plug set in tubing tail 4. RDMO & pop well Additional Post Rig Work: 1. E-line perforate Sag 2. Additional program(s) will be submitted to fish the WRP parts at the liner hanger Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing Separate sundry required for eline perforating. H-07A Integrity RWO Well: H-07A PTD:200-128 Current WBS: H-07A Integrity RWO Well: H-07A PTD:200-128 Proposed WBS: H-07A Integrity RWO Well: H-07A PTD:200-128 BOP Schematic: 4-1/2” x 7” VBR Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 12, 2021Subject: Changes to Approved Sundry Procedure for Well H-07ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday,July 15, 2017 7:22 PM To: AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer H-07 (PTD#2001280)Awaiting 2500 psi MIT All, Producer H-07 (PTD#2001280) requires a 2500 psi MIT of the tubing and production casing in order to verify well barriers and restore the well to operability.At this time,the well is reclassified as Not Operable while the plug set and pressure test procedure is developed. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) SCMOS AUG 0 8 2017 0:(907)659-5102 C:(907)943-0296 H:2376 From: AK, GWO Well Integrity Engineer ent: Tuesday, June 20, 2017 12:59 PM To: ', . A I SUPT Well Integrity; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; • OPS Prod Controllers; AK, OPS PCC Ops Lead; 'Regg,James B (DOA) (jim.regg@alaska.gov)'; AK, OPS GC2 OSM; AK, OP _ Field O&M TL; AK, OPS GC2 Wellpad Lead; Wellman, Julie Cc: AK, GWO DHD Well Integri , • GWO Projects Well Integrity; Sternicki, Oliver R; Tempel, Troy; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.go, K, GWO Completions Well Integrity; AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, • - • Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Worthington, Aras J; AKIMS App User Subject: UNDER EVALUATION: H-07 (PTD# 2001280) High In ; Annulus Casing Pressure Above NOL(Formerly MOASP) All, Producer H-07 (PTD#2001280)was reported to have sustained inner annulus casing pr- e over NOL (formerly MOASP) on June 18, 2017. The pressures were confirmed to be TBG/IA/OA= 1•i 5 2020/20 psi. A subsequent IA bleed showed fluid inflow on June 20, 2017. At this time, the well has been reclas ed as Under Evaluation and well barriers will be verified or repaired within 28 days. Plan Forward: 1. Slickline: Diagnose patch/LDL, set TTP, MIT-IA 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,June 20, 2017 12:59 PM To: AK, GWO SUPT Well Integrity; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Regg, James B (DOA);AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;Wellman,Julie Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Sternicki, Oliver R; Tempel, Troy;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Worthington,Aras J;AKIMS App User Subject: UNDER EVALUATION: H-07 (PTD#2001280) High Inner Annulus Casing Pressure Above NOL(Formerly MOASP) All, Producer H-07 (PTD#2001280)was reported to have sustained inner annulus casing pressure over NOL (formerly MOASP) on June 18, 2017. The pressures were confirmed to be TBG/IA/OA= 1900/2020/20 psi. A subsequent IA bleed showed fluid inflow on June 20, 2017. At this time,the well has been reclassified as Under Evaluation and well barriers will be verified or repaired within 28 days. Plan Forward: 1. Slickline: Diagnose patch/LDL, set TTP, MIT-IA 2. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 % Qo JUN 2 3 2.Th. 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other c i 5 P Ilr--- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-128 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20242-01-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PRUDHOE BAY UNIT H-07A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11335 feet Plugsmeasured 10720/10840 feet RECEIVED true vertical 9076 feet Junk measured feet Effective Depth: measured 10720 feet Packer measured 9507 feet MAY 0 3 2017 true vertical 8907 feet Packer true vertical 8117.17 feet "'"`(�,, Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-110 Surface 2686 13-3/8"72#N-80 29-2715 29-2715 4930 2670 Intermediate 9905 9-5/8"47#N-80 27-9933 27-8399 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10798-10808 feet 10874-10924 feet 10924-10939 feet True vertical depth: 8935-8938 feet feet 8955-8968 feet 8968-8972 feet Tubing(size,grade,measured and true vertical depth) 7"26#IJ-45 25-9507 25-8117 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED MAS' i 6 2017, 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: 626 30802 0 940 1952 Subsequent to operation: 337 16118 0 940 2001 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Authorized Name: Wellman,Julie Contact Name: Wellman,Julie Authorized Title: Production Engineer Contact Email: Julie.Wellman@bp.com Authorized Signature: /' Date: 5/3/c-3- Contact Phone: +1 9075644657 cp:1 Form 10-404 Revised 04/2017 V7-1- 5//b`/ /YJ! `�'�//''/�/7 RBDM1/vS 1, Me( 4, 2317 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 3, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for H-07A, PTD # 200-128 for setting a plug above the perforations and flow testing flow around the annulus of the liner top. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • w 0 O 12. (Doom • N NN co 0 M (0D S • O co — m ,cr (o oo ce) LO o) — (.0 N- 0 'Cr N- I,- CO CO O N- N CO CO 0) 00 N O 0) I,- CO N If) M N N 0 CO N Nc0 a O 0 C() OO M O f� O) Ln M Ln S 2 O Q = 0 0N- (O CO L() C>- N N CcDCN N Q CO.12 OI-• Ili O O 0 � 0_ - Z z oho -1 ,r • O d M N *k Z c •N N X N- N CUN a N0 (0 - (6 `16 () (' ° - co N O)0 CO O T- CO0OND J O N C 0)) C) W Q _0 O U W O 0 i OW tY tr Z Z LU LU 0D • • Packers and SSV's Attachment H-07A ADL0028284 SW Name Type MD TVD Depscription H-07A PACKER 4620 4482.27 7"Arrow PAC Packer H-07A PACKER 4649 4505.15 7"Arrow PAC Packer H-07A PACKER 9507.45 8117.17 7" BOT Packer 0 • _1 LI_ f k 2 Z t E 45 -a-) / Fo - ti 2 LL 2 o 2 § (n w4. © o �§ Q � O W / E cao ƒ o - Em to I 0 I O ®N a) 15,0 o E / >' CL I- D w e : w f m ® 0Z � IL: A- - -a \ _- TD = ce _1 n , cm : � - � � 1.1 5 CCG : � / k S tw 0 CO / _ cik � k2 � b a1 E •2 (4‘1 � �TD 0 ci � Z Win < " E4— ƒ / o� Cen - bxA � $ - # .- 0 O � 9@ o Z` , ril ' G # 2f » pc _ 7 \ o -a 0 a x o O RRRff33 \ � � o m k �_ bS22 / $ SEw - \ a � � 2PRb , u_ •-• :E.I u 1- 0 0 .i eL± ƒ 0 - W 2 a) o O 2 E L * w / a) § f | c i- | Ga. 2 | m ; 5 z O w I- 0 ¥ ¥ ¥ d d / k - � 2 > e e CO CO ¥ # # / TREE=I 6-3/8"CNV • WE.LHEAD= M EVOY H _0 7A SAFETY NOTES:WELL ANGLE>70°@ 10775'. ACTUATOR= OTIS OKB.ELEV= 76.4' BF.ELEV= 45.75' KOP= 3313' 2170' --16-OTIS SSSV MP,D=5.962" PMbx Angle= 77°@ 11020' HOT Datum M?= 10634' Datum TV D= 8800'SS [_ 2698 ff9 518"DV COLLAR J��_.-- 13-3/8"CSG,72#,N-80,BTRS,ID=12.34r JH 2716'i 8 4620'-4649' —7"ARROW PAC PATCH, Minimum ID =2.38" @10275' D=2-90"(07/15/08) 3-1/2" X 2-7/8" XO d 4631 --17"TBG HOLES 7"TBG,26#,N-80 U4S,.0383 bpf,ID=6.276"J— 9469' 9432' –TOP PBR ASSY Z 9472' —9-5/8"X r BOT SS PKR,D=???j 9-5/8"CSG,47#, N-80 BTRS,D=8.681"J—L 9936' j—A L 102_68._--1 5.8"SCOOP GUIDE,ID=_3.54" , L 10270 —13.75"BKR DEPLOY SLV,D=3.00" irm..1---1 � 10276' H 3-1/2'X 2-7/8'XO,D=2.38' tMILLOUT WPDOW 04.07A)10581'-10588' t 10720 J—{2-7/8"WFD WRP(04/03/17), 729#,N "LNR, -80 BTRS 0371 bpf,0= .184" — L-710681___.__ j 10840 —12.22"BKR CBP(11/23/14) .111111 / ` PERFORATION SUMV RY •�1111(19 REF LOG:BHI GR ON 09/15/00&SWS GR/CCL on 09/15/00 41 REF 111111111. ANGLE AT TOP PERF:73°0 10798' .%Nate:Refer to Roduction OB for historical pert data SIZE SIF INTER'VAL Opn/Sqz SHOT SOZ 1-9/16" 6 10798-10808 C 06/20/02 2" 4 10874-10924 C 09/15/00 i'• 2" 4 10924-10939 C 04/22/01 44, L PBTD 11271' [2-7/8"LNR,6.16#,L-80 FL4S,.0058 bpf,D=2.441" J— 11336' J DATE REV BY OOMvENTS DATE REV BY COMMENTS PRIDHOE BAY UNIT 07/09/77 ORIGINAL COMPLETION 11/23/14 RIMY PJC SET CEP WELL: H-07A 02/28/96 SCAB LNR 01/05/15 JCMJM3 SET IBP(12/23/14) PERIvIT No: 2001280 09/10/00 N4/3S CTD SIDETRACK(H-07A) 01/13/15 SWC/JM:RLL IBP(01/08/15) AR No: 50-029-20242-01 07/22/08 BSE/SV SET PATCH(07/15/08)&CORR 02/22/17 CRWJM3 MSC CORRECTIONS SEC 21,T11N,R13E,569'FAL&1266'FEL 03/01/11 DAV/PJC PATCH D CORRECTION 04/04/17 DG/JM) SET WRP(04/03/17) 02/10/12 PJPYJM3 PERF REF LOG ACTION BP Exploration(Alaska) Imag~roject,Well History File Cover~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ - ] ¢~ 4~' Well History File Identifier RESC~N DIGITAL DATA" OVERSIZED (Scannable) ia Color items: ~fai~ II Diskettes, No~. [] Maps: [] Grayscale items: [3 Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIt~~)SHERYL MARIA WINDY Scanning Preparation ~ x 30 = ~) BY: BEVERLY ROBIN~~SHERYL MARIA WINDY III IIl[lllllll II Ill Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: ,~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~ FOUND: YES NO RESCANNEDBY: BEVERLY F~OBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12110/02Rev3NOTScanned.wpcl • • p BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 aO © � ,g Mr. Jim Regg H Alaska Oil and Gas Conservation Commission SLANIVELLAUG 0 8 zw 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 ---f H -07A 2001280 50029202420100 0.8 NA 0.6 NA 3.40 2/15/2010 • H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 1-1-11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18 /2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 1-1-31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 • H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 STATE OF ALASKA C` r ALA OIL AND GAS CONSERVATION COM I~~' REPORT OF SUNDRY WELL C?PERATIONS ~~ 1. Operations Abandon ~ Repair Well Q ~ Plug Perforations ~ Stimulate ~ Other ~ Tubing Patch ' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ 4620'-4649' Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~aopment - Exploratory Zoo-12ao 3. Address: P.O. Box 196612 Stratigraphic Service N 6. API Number: Anchorage, AK 99519-6612 50-029-20242-01-00 7. KB Elevation (ft): 9. Well Name and Number: 71.25 KB PBU H-07A - 8. Property Designation: 10. Field/Pool(s): ADLO-028284 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11335 - feet Plugs (measured) 10292' true vertical 9076.06 feet Junk (measured) None Effective Depth measured 11272 feet true vertical 9062 feet Casing Length Size MD TVD Burst Collapse Surface 2687 13-3/8"72# N-80 29 - 2716 29 - 2716 4930 2670 Production 9907 9-5/8" 47# N-80 28 - 9935 28 - 8401 6870 4760 Liner 803 7" 29# N-80 9472 - 10275 8092 - 8626 8160 7020 Liner 6 3.7" BAKER DEPLOYty 10269 - 10275 8622 - 8626 Liner 1060 2-7/8" 6.16# L-80 10275 - 11335 8626 - 9076 13450 13890 ^'` rl `~ Perforation depth: Measured depth: SEE ATTACHED - _ ~~'a~~~~ J `~ ' ` ~~~ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 7" 29# N-80 28' - 9432' 0 0 - Packers and SSSV (type and measured depth) 7" BOT Packer 9472 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: SI Subsequent to operation: 2890 26170 304 1028 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory fi Devutrlopment Service I~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ WINJ J~' WDSPL 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/25/2008 Form 10-404 Revised 04/200( I ;`~ , Submit Original Only ~ ra'~6 44,x- eu.... /~"" ~ H-07A 200-1280 PERF ~TT~rHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-07A 9/14/00 PER 10,874. 10,924. 8,955.21 8,968.39 H-07A 4/22/01 APF 10,924. 1 0,939. 8,968.39' 72.01 8,9 H-07A 6/20/02 APF 10,798. ___ _ 10,808. ___ 8,934.85 _ ____ 8,937.77 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP _ BRIDGE PLUG P ULLED- SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO _ FILL CLEAN OUT- SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED _ MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • H-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CACTIVITYDATE SUMMARY 1 7/15/2008 "~*WELL S/I ON ARRIVAL***( post tree c/o) PULL 4.5 PX PRONG FROM 2,148' SLM. PULL 7" INSERT WITH 4.5 PX PLUG BODY FROM 2,153' SLM. ', PULL 4.5 L.T.T.P FROM 4,625' SLM DRIFT WITH 5.90 GAUGE RING TO 4,624' SLM. SET ARROW PACKER AT 4'632' SLM. O.A.L 29.33' MIN. I.D = 2.900' (PATCH SCHEMATIC IN WELL FILE) 7" ARROW PAC PATCH 4620' - 4649' ', *"*LEFT WELL S/I*** (dso notified of valve position) 7/28/2008T/I/0=70/30/70. Temp=S1. IA FL (for FB). NO A/L. IA FL C@ 36'. WV, SV=Closed, SSV, MV=Open, IA&OA=OTG. 7/29/2008s,T/I/0= 50/20/20 Temp= S/I MIT IA PASSED to 3000 psi. (Restore TBG ;integrity) Pumped 5.4 bbls 90* crude down IA to reach test pressure, IA lost 80 ;..psi in 1st 15 mins, IA lost 20 psi in 2nd 15 min. for a total loss of 100 psi in 30 -.min. test, Bleed IAP, Bled back ~ 4 bbls., Final WHP's 50/20/20 "Valve -,position on departure- Swab, Wing=Closed SSV, Master, IA & OA=Open" FLUIDS PUMPED BBLS 5.4 CRUDE 5.4 Total TREE 6-3/8" CM/ WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 71.3' BF. ELEV = 45.75' KOP = 3313' Max Angle = 77 @ 11290' Datum MD - 10634' Dat 2170' ~ 6" OTIS SSSV NIP, ID = 5.962" umTVD= 8800'SS FOC -• 13-3/8" CSG, 72#, N-80, BTRS, ID = 12.347" 2716' Minimum ID = 2.38" @ 10275' 3-1 /2" X 2-7/8" XO - 4649' ~--~ 7" ARROW PAC PATCH (07/15/08) 4640' I•-IWFLOWERSTRADDLEPKRANCHOR 4631 I~ 7" TBG HOLES 7" TBG, 29#, N-80 BTRS, .0383 bpf, ID = 6.276" ~~ 9432' 19-5/8" CSG, 47#, N-80 BTRS, ID = 8.681" I 9432' -1 TOP PBR ASSY 9472' 9-5/8" X 7" BOT SS PKR, ID = ??? 10269 ~~ 5.8" SCOOP GUIDE, ID = 3.54" 10270 3.75" BKR DEPLOY SLV, ID = 3.00" 10275' I-13-1/2" X 2-7/8" XO, ID = 2.38" PERFORATION SUMMARY REF LOG: BHI GR ON 09/15/00 & SWS GR/CLL ON 09/15/00 A NGLE AT TOP PERF: 73 @ 10798' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 10798 - 10808 0 06/20/02 2" 4 10874 - 10924 O 09/15/00 2" 4 10924 - 10939 O 04/22/01 MILLOUT WINDOW 10581' - 10588' PBTD --~ 11017' ~ PBTD 11272' 7" LNR, 29#, N-80, BTRS, .0383 bpf, ID = 6.276" 11058' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.44" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/09/77 ORIGINAL COMPLETION 01/15/07 MW/LWB/F'G GLV CORRECTION (07/13/06) 02/28/96 SCAB LNR 06/25/08 DSM/SV TREE C/O (06/20/08) 09/10/00 N4/3S CTD SIDETRACK (H•07A) 07/22/08 BSE/SV SET PATCH (07/15/08) & CORR 12/10/02 CAO/KK SET WFD STRADDLE PKR 05/18/06 KSB/TLH WRPSET(01/07/06) 07/15/06 CJN/PJC PULL UPPER STRADDLE PKR I 11333' I PRUDHOE BAY UNff WELL: H-07A PERMIT No: 2001280 API No: 50-029-20242-00 SEC 21, T11 N, R13E, 569' FNL & 1266' FEL BP Exploration (Alaska) ¿xu - Jd6 07/27/07 Scblullbepg8P RECErVE[) NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99603-2838 ATTN: Beth JUL 3 0 zam Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r\lasta Oil & Gas Cons. Commission Anchornge Field: Prudhoe Bay Endicott Well Job# Loa Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-0SA 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNI~G AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SCANNED AU G 0 1 2007 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: dlc> .. ~ ð ,....""'1-1 .... . STATE OF ALASKA ..r·/.-t11 ¿H¡:ÈB 2 8 2007 ALA Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPE~.TUDNSas Cons. commission 1 . Operations Abandon 0 Repair Well 0 . Plug Perforations 0 Stimulate 0 Rn rD Patch tubing/Liner Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P Exploratory 200-1280 I 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20242-01-00 ) 7. KB Elevation (ft): 9. Well Name and Number: 71.25 KB / PBU H-07A / 8. Property Designation: 10. Field/Pool(s): ADLO-028284 , PRUDHOE BAY Field/ PRUDHOE OIL Pool / 11. Present Well Condition Summary: Total Depth measured 11335 ¡ feet Plugs (measured) 10292' true vertical 9076.06 feet Junk (measured) None Effective Depth measured 11272 feet true vertical 9062 feet Casing Length Size MD TVD Burst Collapse Surface 2687 13-3/8" 72# N-80 29 - 2716 29 - 2715.92 4930 2670 Production 9907 9-5/8" 47# N-80 28 - 9935 28 - 8400.82 6870 4760 Liner 803 7" 29# N-80 9472 - 10275 8092.23 - 8626.32 8160 7020 Liner 6 3.7" Baker Deployment 10269 - 10275 8622.22 - 8626.32 Liner 1060 2-7/8" 6.16# L-80 10275 - 11335 8626.32 - 9076.06 13450 13890 Perforation depth: Measured depth: 1 0798 - 10939 - - - - True Vertical depth: 8935 - 8972 - - - - Tubing: (size, grade, and measured depth) 7" 29# N-80 28' - 9432' Packers and SSSV (type and measured depth) 7" BOT Packer 9472' Straddle Packer 4619' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): sCANNED MAR o 1 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing pressure Prior to well operation: shut in 0 0 0 0 Subsequent to operation: shut in 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development P Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil P Gas r WAG r GINJ r WINJ r WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Gary Preble RBDMS BFl MAR 01 20D7 Printed Name Gary Prebl~ /l A .., Title Data Engineer Signature I.'·~7/~ á//£ Phone 564-4944 Date 2/27/2007 Form 1 0-404 Revis~ 04/2006 Submit Ori inal Onl ORIGINAL g y . . H-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY TUBING HANGER VOID TO 5000 PSI HELD FOR 5 MIN, PRESSURE HELD STEADY AND WE WITNESSED NO LEAKING ON THE FLANGE. PUMPED 2 GALLONS INTO THE P/O VOID NEVER SAW THE VOID PRESSURE UP. CTU #8, Pull Arrowpac Retrieving Tool; MIRU unit. Pump 1.25" drift Recovered Ball .., Cont' on WSR 02/16/07 .., CTU #8, Pull Arrowpac Retrieving Tool; ... Cont' from WSR 02/16/07... RIH with up/dwn jars, PDM and pulling tool. Tag packer at Rotate motor at min rate and attempt to latch. Based on observed motor work, decide to POOH and see if we were successful. No fish. RIH with same assy. Found marks on @ end of tool string.Took tools to machine shop for modification. CTU #8, Pull Arrowpac Retrieving Tool;... from up/dwn jars, PDM, 5.78" OD stabilizer, and pulling tool. Tag retrieving at 4625'. Good indication tool is latched. Kick on pumps and rotate tool out of pkr. POOH. No fish. RBIH with same assy. Tag retrieving tool at 4625'. Set 6K down; jar down and rotate pulling tool into retrieving tool. PUH and observed 4K overpull. Slack off and rotate while POOH. RBIH and repeat procedure to ensure tool is latched. POOH. Successfully retrieved retrieving LD tools and RBIH with JSN and freeze protect well down to 2500'. *** Complete *** Note: 7" Arrowpac Pkr is still in well. Only the Arrowpac retrieving tool was FLUIDS PUMPED BBLS 20 60/40 METHANOL 100 DIESEL 120 TOTAL _ STATE OF ALASKA _ ALA" OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D RECEIVED FEB 1 4 2006 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development W1 Stratigraphic D P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: Exploratory Service D iD 9. Well Name and Number: 71.25 KB H-07 A ADL-028284 11.. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth Effective Depth Casing Conductor Surface Production Liner Liner Liner Perforation depth: measured 11335 feet Plugs (measured) 10292 WRP true vertical 9076.06 feet Junk (measured) None measured 11272 feet true vertical 9062.16 feet Length Size MD TVD Burst Collapse 80 20" x 30" 30 - 110 30 - 110 2687 13-3/8" 72# N-80 29 - 2716 29 - 2715.92 4930 2670 9907 9-5/8" 47# N-80 28 - 9935 28 - 8400.82 6870 4760 803 7" 29# N-80 9472 - 10275 8092.23 - 8626.32 8160 7020 6 3.7" Baker Deployment 1 0269 - 10275 8622.22 - 8626.32 1060 2-7/8" 6.16# L-80 10275 - 11335 8626.32 - 9076.06 13450 13890 Measured depth: 10798 - 10939 True Vertical depth: 8934.85 - 8972.01 Closed Closed Tubing: (size, grade, and measured depth) 7" 29# N-80 28 - 9432 Packers and SSSV (type and measured depth) 7" BOT Packer Straddle Packe~ '(f' P: ;~~\~~f¡;;J) ~~~O"ÌhJ ~t;,;-,~. 9472 4619 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft FEB 1 4 2006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 13. Oil-Bbl 398 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 18166 445 300 SHUT-IN 15. Well Class after proposed work: Exploratory Development W1 16. Well Status after proposed work: Oil W1 Gas WAG WDSPL Tubing pressure 1680 Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal P"oled N,me 8h,"",loe Ve,'" _ ~. . Signatu~~ Title Data Mgmt Engr Phone 564-4424 Date 2/8/2006 Form 10-404 Revised 04/2004 Submit Original Only .. e -- H-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AC"FI'IWYDA TEls"~,,dl_1' ", ~I 1/2/2006 T/I/O=700/1190/200 Temp=SI Bleed lAP < 300 psi post L&K (prob well day 23). IA FL @ 3643' (93 bbls). Bled lAP, to DHD upright tank, from 1190 psi to 30 psi in 90 minutes. While bleeding the lAP the TBGP & OAP remained unchanged. Shut in IA bleed and monitor for 30 minutes. lAP increased 20 psi. IA FL unchanged post bleed and monitor. Final WHP's=700/50/200. 1/3/2006 TIIIO = 700/400/200. Load Tbg. and IA. Pumped 43 bbls Crude down lA, and 30 bbls Crude down Tbg. Final WHP's 700/300/220. 1/5/2006 *** WELL SI ON ARRIVAL *** (secure well) MADE SEVERAL ATTEMPTS TO PULL GL STRADDLE @ 4596' SLM, UNABLE TO LATCH ON SECOND ATTEMPT, RIH W/4 1/2" GS. *** JOB IN PROGRESSI CONT ON 1-06-06 WSR *** 1/6/2006 *** CONT FROM 1-05-06 WSR *** (secure well) RELEASABLE SPEAR SET IN POGLUM @ 4594' SLM, MADE RUNS & JARRED FOR A TOTAL OF 3 HRS @ 1800#-2000#, ON THIRD RUN RIPPED TOP SUB OFF OF 4 1/2" GS, RAN 3.81" BOX TAP AND RECOVERED GS CORE, GS PINNING SUB, SKIRT & DOGS. *** JOB IN PROGRESSI CO NT ON 1-07-06 WSR *** 1/7/2006 *** CONT FROM 1-06-06 WSR *** (secure well ) PULLED RELEASEABLE SPEAR FROM WFD STRADDLE @ 4594' SLM, DRIFTED WI 2.33 CENT & SAMPLE BAILER TAGGED TOP OF LINER @ 10,252' SLM + 18' = 10,270' MD DEPTH ( FLAGGED WIRE FOR SETTING DEPTH OF WRP), DRIFTED TO 10,400' SLM, SET 27/8" WFD WRP WI HES ETD IN LINER @ 10,292' MD (MIDDLE OF FIRST FULL JOINT BELOW LINER TOP).RDMO *** WELL SHUT-IN, PAD OP NOTIFIED *** 1/8/2006 T/I/O=450/190/220. Temp=SI. Monitor WHP's. (Eval Secure). TBG FL @ 1374' (51 bbl). IA FL @ 732' (19 bbl). TP increased 230 psi overnight. lAP increased 10 psi overnight. No change in OAP overnight. ***NOTE*** Very warm in well house (Heater). FLUIDS PUMPED I BBLS I : TOTAL H-07A (PTD #2001280) Classified as Problem Well e e Suh.icct: H-07 A (PTD #20(1280) Classified as Problcm Well From: "NSU, ADW Wel1lntcgrity Engineer" <NSUADWWelllntegrityEnginccr@BP.com> Dutc: Mon. 12 Dec 2005 20:31 :30 -0900 To: "(iPH, GC2 Area ;\l1gr" <GPBGC2TL@BP.conf>, "Rossberg, R Steven" <RossbeRS@)BP.com>, "NSU, ADW \Veil Operations Supervisor" <NSUADWWeIlOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <~GPBWellsOptEng@BP.com>, "AOGCC Jim Rcgg (E-mail)" <jim..regg(Ù;admin.statc.ak.us>, "AOGCC \Vinton Auhert (E-mail)" <winton_..aubcrt@.admin.state.ak.us>, "NSU, ADW WI.. & Completion Supcrvisor" <NSlJADW\VL&CompletionSupervisor@BP.com>, "Kurz, John" <john.kurz@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "GPB, Prod Controllers" <GPBProdControllcrs~i]BP.com>. "Warren, Mikc" <WarrcnM@BP.com>, "GPB, GC2 Wellpad I,cad" <GPBGC2\VellpadLcad@BP.com> cc: "Hughes, Andrea (VECO)" <hugha4(4}ßP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWclllntcgrityEngineer@ßP.com>, "Frazier, Nicholas B" <Nieholas.Frazicr@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com> Hello All, Well H-07 A (PTD #2001280) has sustained casing pressure on the IA and has been classified as a Problem well. Wellhead pressures on 12/10/05 were 2100/2020/320. A TIFL failed on 12/10/05 due to IA repressurization. The plan forward for this well is as follows: 1. SL: Set DGL V in Sta #1 @ 4619' 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «H-07 A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.eom '..,;.,.. b.N!\~(¡,';;;¡ ~V&'~~;j'~·' \. ,;;.,;ø~... r x:t From: Hughes, Andrea (VECO) Sent: Monday, December 12, 2005 9:39 AM To: NSU, ADW Well Integrity Engineer Subject: H-07 New Problem Well :fA -=- 2--OZD f s: q ÇIß II J 4JiL "'-fu ^A;JÆ1P~ 6'670 ~ ~ 2'1. 'rlc cf MYttP-- ~ CSt / 5'K£?n IZb3/os- Joe- The Field Operator reported high lAP on 12/09/05 for H-07. The next day DHD performed a TIFL, which failed on pressure build up. Wellhead pressures on 12/10/05 before performing the TIFL were 2100/2020/320 psi. I recommend the well be classified as a Problem well and the following actions be taken to repair the well: 1. S: DGL V in Sta #1 at 4619' MD. lof2 12/13/2005 10:32 AM H-07A (PTD #2001280) Classified as Problem Well e 2.0: Re-TIFL What do you think? Thank You- Andrea Hughes Well Integrity Engineer Office: (907) 659-5525 Pager: (907) 659-5100 x1242 20f2 e Content-Description: H-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 12/13/2005 10:32 AM e 113-318" CSG. 72#, N-80, STRS, ID = 12.347" Minimum ID = 2.44" @4619' WFD STRADDLE PACKER T' TBG, 29#, .0383 bpf, 10 = 6.276" I 9432' H-07 A e SAfETY NOTES: 7" TBG, 29#, N-80 STRS, .0383 bpf, ID = 6.276" ITOP 2-718" LNR, 6.16, L-80, .0058 bpf, ID = 2.37" 9-518" CSG, 47#, N-80 STRS, 10 = 8.681" 9935' 10275' ÆRFORA TlON SUMMARY REF LOG: BHI GR ON 09115/00 & SWS GRlCLL ON 09/15/00 ANGLEATTOPÆRF: 72@ 10798' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 10798 - 10808 0 06/20/02 2" 4 10874 - 10924 0 09/15/00 2" 4 10924 - 10939 0 04/22/01 I FBTD I 11017' 11058' 7" LNR, 29#, N-80, BTRS, .0383 bpf, ID'" 6.276" I DATE 07109177 05/01/01 06/20/02 12/10/02 01/24103 03123103 REV BY COMMENTS ORIGINAL COMPLETION CORRECTIONS ADD ÆRFS SET WFD STRADDLE PKR WAIVER SAFETY NOTE WAIVER SAFETY NOTE REV. DATE 7114103 0102/03 8/09/05 REV BY COMMENTS CMOfTLP KB ELEVATION CORRECTION JCMlTLP GL V C/O EZLlPJC WAIVER SFTY NOTE DELETED PRUDHOE BA Y UNfT WELL: H-07A ÆRMfT No: 2001280 API No: 50-029-20242-00 SEC21, T11N, R13E, 569' FNL & 1266' FEL RNlKA K TMNltlh CAO/KK KBITP JMPIKK . 2170' --i 6" SSSV NIP (OTIS 5.962" 10) I 2-7/8" GAS LIFT MANDREL DEV TYPE VLV LATCH PORT DATE 38 CAMCO S/O BK 20 10/02103 WEA THERFORD STRADDLE PKR 7" TBG HOLES @ 4631' TOP FBR ASSY I 9-518" X 7" BOT SS PKR, ID = I --i 5.8" SCOOP GUIDE & DEP SUB, 10 = 3.00" -1 2-718" BAKER XO, 10 - 2.44" MILLOUT WINDOW 10581' - 10588' I 11333' 2-7/8" LNR. 6.16#, L-80, .00579 bpf, ID '" 2.44" BP Exploration (Alaska) H-07A (PTD #2001280) Internal Waiver Cancellation ) ) S!~j~9t: ·¥.~Ø1A;~tJt>#2pOl780).Tl1terg~1~äiV~1".·Ç.~c~Uªti~Ji'· .... .. . Fr~D:l: tl]lJ1JÞ~,,~ª,T"-<AAn.ª·Pllb~@BP.çom>. . Þªte: ·tù~,:9~A..1.),g10Q? 09:5~:08. -q8PQ Winton and Jim, The internal BP waiver for IAxOA communication on well H-07A (PTO #2001280) has been cancelled. The well has passed an OA repressure test proving there is no IAxOA communication. Internal approval has been obtained to return the well to normal status with operating limits of 2000 psi on the IA and 1000 psi on the OA. Please let me know if you have any questions. Thank you, }fnna Q)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (901) 659-5100 )(1154 c.:.:.:.~"-,,,d'..~' U"~Ec ~"" \~' r: I) ,,~ .,¡., 2 0 II t:- "'~n.d'"·'·'ti\!, 'tJ' U ...} c. ¡ (.) _ ',_ ".1J 1 of 1 8/10/2005 3:27 PM F:\LaserFiche\CvrPgs _I nserts\M icrofi 1m _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE '"'- 1~1I',4Ilr" ,..~- ,~"1..;r....... ) ') Permit to Drill 2001280 MD 11335--' TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT H-07A Operator BP EXPLORATION (ALASKA) INC · 907i'~'' Completion Dat 9/14/2000 --- Completion Statu 1-OIL. Current Status 1-OIL APl No. 50-029-20242-01-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample No Directional Survey ~X~/~ , DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval OH I Start Stop CH (data taken from Logs Portion of Master Well Data Maint) 10306 11333 Open Dataset Received Number Comments 10/9/2000 098134~306-11333 ED C GR Gamma Ray..~ ED D Ver LIS Verification Rpt Ver LIS Verification --- ED D Cn See Notes R MWD Survey Report MWD Survey Report 9813 IL 2/5 I 10186 11268 Case 1 10558 11335 Open 1 10558 11335 Open 1 10390 10689 Case FINAL FINAL 10570 11335 1 OH FINAL 10306 11333 OH 2/1/2002 10547 4/4/2002 10720 4/4/2002 10720 5/20/2002 10872 c,'~oil flag 2/2/2001 Digital Data 2/2/2001 10570-11335 Paper Copy 10/9/2000 98 I~.~DS IL 10/9/2000 10306-11333 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Cored? Y Well Chips Received? Analysis R~.c.~iv~.d? Daily History Received? (~ N Formation Tops (~'/N Comments: Permit to Drill 2001280 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT H-07A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20242-01-00 MD 11335 TVD 9071 Compliance Reviewed By: Completion Dat 9/14/2000 Completion Statu 1-OIL Current Status 1-OIL UIC N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ 4. Location of well at surface 569' FNL, 1266' FEL, Sec. 21, T11N, R13E, UM At top of productive interval 1160' FNL, 2117' FEL, Sec. 22, T11N, R13E, UM At effective depth 1292' FNL, 1869' FEL, Sec. 22, T11N, R13E, UM At total depth 1566' FNL, 1585' FEL, Sec. 22, T11N, R13E, UM (asp's 643307, 5960219) (asp's 647748, 5959714) (asp's 676068, 5956218) (asp's 648288, 5959319) 12. Present well condition summary Total depth: measured true vertical 11335 feet Plugs (measured) 9076 feet Effective depth: measured true vertical Casing Length Conductor 110' Surface 2685' Intermediate 9904' Liner 803' Sidetrack Liner 1060' 10924 feet Junk (measured) 8968 feet Size Cemented 20" 200 cf Concrete 13-3/8" 5337 cf 9-5/8" 2023 cf 7" 2-7/8" 76 cf Class 'G' 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-07A 9. Permit number / approval number 200-128 10. APl number 50-029-20242-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool TD Tag @ 10924' (06/17/2002) Measured Depth True Vertical Depth 141' 141' 2716' 2716' 9935' 8401' 9472' - 10275' 8092' - 8627' 10275' - 11335' 8627' - 9076' Perforation depth: measured Open Perfs 10798'- 10808', 10874' - 10924' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) true vertical Open Perfs 8935'-8938', 8950'-8953' REE~iVFF 7,,, 29#, L-80, TBG @ 9432' MD. JUL t 2002 ~. 9472~ TOP7. SSSVLN°f PKR ASSY@ 2170' @ MD.9432" 9-5/8" x 7" BOT SS Packer ~,laSl(a 0it &, .Was C0¢~s, L;Om~llSSJ0t3 13. Stimulation or.cement squeeze summary ~hurage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Shut-In Subsequent to operation 06/25/2002 Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2570 17594 1266 Tubing Pressure 225 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~'~~~ ~~,~~ ~-" / '-~ '-'~ ~' ~" Title: Technical Assistant DeWayne R. Sc~orr ~ Form 10-404 Rev 06/15/88 · ORIGINAL Date June 27, 2002 Prepared by DeWar, ne R. $chnorr 564-5174~ SUBMIT IN DUPLICATE ~ H-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/10/2002 PERFORATING: DRIFT/TAG 06/16/2002 PERFORATING: DRIFT/TAG 06/17/2002 PERFORATING: DRIFT/TAG 06/20/2002 PERFORATING: PERFORATING 06/10/02 06/16/O2 EVENT SUMMARY RIH W/2.0" DUMMY GUN & SAMPLE BAILER. TOOLS STOPPED @ 10753' SLM DUE TO DEVIATION. RD. SECURED WELL. NOTIFIED DSO OF WELL STATUS. WELL LEFT SHUT-IN. <<< NOTE: TARGET DEPTH IS 10810' >>>. D & T, W/5' X 2 1/8" STEM. TARGET DEPTH OF 10810', MADE 10789' SLM. TRY AGAIN W/2.25" CENT. MAKE 10921' SLM, FORMATION SAND IN S-BAILER. 06/17/02 D&T W/5' X 2" DD BAILER TO 10924' SLM. (BAILER FULL OF FORMATION SAND) <<< LEAVE WELL SHUT IN AND NOTIFY PAD OPERATOR >>>. O6/20/O2 PERFORATED 10798'-10808' IN TWO RUNS, 5' GUN EACH CORRELATED TO PDS INDUCTION LOG DATED 9-12-2000. GUN DATA: 1.56" 1606 POWERJET 6 SPF RANDOM ORIENTATION, 60 DEGREE PHASING, PENETRATION 10.7", ENTRANCE HOLE 0.19", GRAM WT 3.4. ALL SHOTS FIRED. (NOTE: UNABLE TO REACH PERF DEPTH WITH 2" GUNS). NOTIFY PAD OPER OF STATUS - WELL READY TO POP. Fluids Pumped BBLS 1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 1 TEST) I TOTAL ADD PERFS O6/20/20O2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1-11/16" PJ 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 10798'-10808' Page 1 ProActive Diagnostic Sewices, Inc. £L L L TRANS/V/ITTAL To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / deni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM CO~R Open Hole I I 1 Res. Eval. CH 1 1 1 H-OTA 4/6/02 Mech. CH 1 Caliper Survey ' ,,, Signed' Print Name: Date · ProAcTivE DiAq~£~ SERvices, I~¢., ~ IO K Sm~ Sui~ 200, A~om~q~, AK ~01 ?~oa¢:(907) ?-45-895 ! Fax:(90?) ?-45-895?- E-mail: pdsa~cbom§c~mcmo~lo~.com Wcbsit¢: ~ · ~ :-: ::. "~ :: :' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Operations performed: ACID STIM 2. Name of Operator REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing Alter casing _ Repair well _ 'A I~c;i(:3 ~ ,¥-~-t;,: :~ ~-'~'?~ g [;I~i'~J~liOSi0r' 5. Type of Well: 6. Datum elevation (DF or KB ~hora~.~e BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Development __X Exploratory__ Stratigraphic__ Service__ RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 569' FNL, 1266' FEL, Sec. 21, T11N, R13E, UM At top of productive interval 1160' FNL, 2117' FEL, Sec. 22, T11N, R13E, UM At effective depth 1518' FNL, 1623' FEL, Sec. 22, T11N, R13E, UM At total depth 1566' FNL, 3694' FWL, Sec. 22, T11N, R13E, UM (asp's 643307, 5960219) (asp's 647748, 5959714) (asp's 648249, 5959366) (asp°s 648288, 5959319) H-07A 9. Permit number / approval number 200-128 10. APl number 50-029-20242-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical 11335 feet 9076 feet Plugs (measured) Effective depth: measured 11272 feet true vertical 9062 feet Junk (measured) Casing Length Size Conductor 110' 20" Surface 2685' 13-3/8" Intermediate 9904' 9-5/8" Liner 803' 7" Sidetrack Liner 1060' 2-7/8" Cemented Measured Depth True Vertical Depth 200 cf Concrete 141' 141' 5337 cf 2716' 2716' 2023 cf 9935' 8401' 9472' - 10275' 8092' - 8627' 76 cf Class 'G' 10275' - 11335' 8627' - 9076' Perforation depth: measured Open Perfs 10874'- 10924' true vertical Open Perfs 8950'- 8963' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7", 29#, L-80, TBG @ 9432' MD; Top of PKR ASSY @ 9432'. 9-5/8" x 7" BOT SS Packer @ 9472'. 7" SSSVLN @ 2170' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 04/10/2002 Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In 254 4493 167 Casing Pressure Tubing Pressure 135 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing,is true and correct to the best of my knowledge. ,~~ ~'~L¢.~.~~~ Title: Technical Assistant DeWayne R. Schnorr ~ ORIGINAL Date April 12, 2002 Prepared by DeWayne R. Schnorr 564-51,Z~ ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE O3/3O/2OO2 03/31/2002 04/05/2002 04/O5/2O02 04/O6/2002 O4/07/2002 O3/3O/O2 03/31/02 H-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PACK-OFF GAS LIFT MANDREL: CALIPER TUBING; DRIFT/TAG; PACK-OFF GAS LIFT MANDREL; STATIC BOTTOM HOLE PRESSURE SURVEY PACK-OFF GAS LIFT MANDREL: CALIPER TUBING; DRIFT/TAG; PACK-OFF GAS LIFT MANDREL; STATIC BOTTOM HOLE PRESSURE SURVEY ACID: LOAD WELL TO SECURE ACID: ACID TREATMENT ACID: ACID TREATMENT ACID: ACID TREATMENT EVENT SUMMARY RAN 7" PRT. LATCHED 7" POGLM FROM CROSSOVER @ 10235' WLM. PUH TO PACKER. IN PROGRESS. FISHED 7" POGLM -- DRIFT W/2.20" CENT. TO 10,914' SLM (STOPPED DUE TO HAW) -- RAN PDS CALIPER SURVEY FROM 10,272' SLM -- RAN SBHPS W/ PETREDAT GAUGES ****NOTIFY PAD OPERATOR TO LEAVE WELL SHUT-IN**** 04/05/02 PUMPED 120 BBLS CRUDE DOWN IA TO LOAD FOR CTU. 04/05/02 MIRU UNIT #8. MOVE SNOW AND SPOT UNIT AND SUPPORT EQUIPMENT. 04/06/02 CONTINUE RIGGING UP. RIH WITH MEMORY GR/CCL LOGGING TOOLS AND LOG 11,000' TO 10,400' AT 40 FPM FOR TIE-IN. CORRECTED TAG @ 10,935'. RI W/WFD 2-1/8" JET-PACK TREATING PACKER SYSTEM. LOAD WELL WITH 2% KCL & DEAD CRUDE TO FLUID PACK & LIGHTEN THE COLUMN. INJECTIVITY PRE-ACID 3.1 BPM @ 1700 PSI. PUMPED ACID AS PER REVISED PROGRAM FOR TWO SETS. 0~0W02 POOH, RDMO. NOTIFY PAD OPERATOR TO POP WELL THRU TEST SEPARATOR. Fluids Pumped BBLS 74 METHANOL 250 KCL WATER 270 CRUDE 279 NH4CL 99 7.5% HCL (TITRATION 7.7% FE- LT 22 PPM) 52 9:1 % MUD ACID (TITRATION 9.2% HCL AND 1% HF FE- LT 22 PPM) 1024 TOTAL Page I Canada GEOSciences Centre Transmittal For Ir~/ BAKER HUGHES To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Baker Atlas Attention: Lisa Weepie Reference' BP Exploration, Inc. 18-32A Prudhoe Bay Unit~=~o BP Exploration, Inc. H-07A Pmdhoe Bay Unit BP Exploration, Inc.,?lS~!~BPB t~..~.Pmdhoe:B:ayUnit BP Exploration, Inc:~::4~.i~iilPB2!~i~:Fm~0e B a~U~it:~:~ ~0;~t~' BP Exploration, Inci: ~05,28A '~' Pmdh0eBay Unit :~D IC./ · ~ ......... ,,, 1 - LAS Format disk Sent By: JosefBerg Date: April 1, 2002 C_<~C~ Date: REGEIVi' ' ' ~ Received By: ,,, .~,~-r, 0 ,~ 2002 PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN{~ia~~~ OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 01/31/02 Schh berger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie NO. 1763 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD ~r D.S. 18-08A MEM PRODUCTION PROFILE 12/04/01 1 " 1 D.S. 7-19A MEM PRODUCTION PROFILE 12/24/01 1 1 D.S. 15-46 MEM PRODUCTION PROFILE 12/28/01 1 1 D.S. 7-35 MEM PRODUCTION PROFILE 12/07/01 1 1 D.S. 7-14A M EM PRODUCTION pROFILE 12/22/01 1 1 D.S. 15-44 PRODUCTION & INJECTION PROFILE 01/17/02 1 1 D.S. 9-26 PRODUCTION PROFILE/DEFT 01/16/02 1 1 D.S. 7-35 22031 MCNL/BORAX 12/07/01 1 1 1 H-07A 22033 MEMORY GR 09/13/01 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED FEB 0 1 2002 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie Received b~~~""~ ~ BP Amoco Baker Hughes INTEQ Survey Report ~ PB H Pad Verti~(TVD) ~ 11: 07 6/20/1998 12:~ 71.3 J Wd: I-bO'/ We# (0,00E,0.00N,126.00Azi) I We~mth: H.OTA ~:~~ ~ Omde FieM: Prudhoe Bay North Sk~pe UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomapetic Model: BGGM2000 Site: PB H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957572.25 ft Latitude: 70 17 30.055 N 641366.07 fl Longitude: 148 51 19.802 W North Reference: True GrM Convergence: 1.08 dog Well: H-07 Slot Name: 07 H-07 Well Position: +N/-S 2609.96 ft Northing: 5960218.99 ft Latitude: 70 17 55.721 N +E/-W 1991.51 ft Eastiag: 643308.00 ff Longitude: 148 50 21.747 W Position Uncertainty: 0.00 ft Wellpath: H-07A Drilled From: H-07 500292024201 Tie-on Depth: 10570.00 ft Current Datum: 11: 07 6/20/1998 12:00 Height 71.25 ft Above System Datum: Mean Sea Level Magnetic Data: 8129/2000 Declination: 26.92 deg Field Strength: 57342 aT Mag DIp Angle: 80.69 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 126.00 Survey: MWD Start Date: 9/11/2000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation Survey 10570.00 44.15 128.31 8831.78 8760.53 -566.26 4401.58 10600.00 53.40 129.00 8851.53 8780.28 -580.35 4419.17 10630.00 59.80 129.00 8868.03 8796.78 -596.10 4438.62 10660.00 66.40 129.00 8881.60 8810.35 -612.93 4459.40 10690.00 66.10 121.20 8893.69 8822.44 -628.71 4481.85 10719.00 66.10 112.50 8905.46 8834.21 -640.67 4505.47 10750.00 68.50 106.20 8917.44 8846.19 -650.12 4532.44 10780.00 71.10 109.20 8927.80 8858.55 -658.69 4559.25 10810.00 73.60 113.50 8936.89 8865.64 -669.10 4585.87 10840.00 75.30 116.50 8944.94 6873.69 -681.31 4612.06 10869.00 74.70 119.10 8952.45 8881.20 -694.37 4636.83 10900.00 74.30 124.00 8960.73 8889.48 -710.00 4662.28 10930.00 76.10 127.80 8968.40 8897.15 -727.00 4685.77 10960.00 75.80 131.10 8975.68 8904,43 -745.49 4708.24 10990.00 76.30 135.70 8982.92 8911.67 -765.49 4729.38 5959736.81 5959723.06 5959707.68 5959691.26 5959675.91 5959664.41 5959655.47 5959647.42 5959637.52 5959625.81 5959613.22 5959598.08 5959581.53 5959583.47 5959543.88 11020.00 77.00 140.10 8989.85 8918.60 -787.15 4748.95 5959522.61 11050.00 74.10 138.40 8997.34 8926.09 -809.15 4767.90 5959500.97 11080.00 71.20 134.00 9006.29 8935.04 -829.82 4787.71 5959480.69 647719.23 0.00 3893.79 647737.09 30.88 3916.31 647758.84 21.33 3941.30 647777.94 22.00 3968.01 647800.67 23.82 3995.43 647824.52 27.42 4021.58 647851.66 20.28 4048.95 647878.63 12.77 4075.68 647905.44 16.00 4103.33 647931.85 11.18 4131.70 647956.87 8.90 4159.42 647982.61 15.29 4189.19 648006.42 13.64 4218.19 648029.23 10.72 4247.23 648050.76 14.97 4276.10 648070.73 14.46 4304.65 648090.10 11.12 4332.92 648110.29 17.01 4361.09 ( ( JJjJ BP Amoco bp Baker Hughes INTEQ Survey Report mmm~ INTEO hie: 1/Z2/2001 'llme: 10.'04:26 ~ .3 Ce,a'a'baNN~ ~: We#: I-I-07, True Norlh ' Verti~l (TVB) Re~ere~ 11:076/20/1996 12.'0071.3 ~ (VS) RL'i,rem::e: Well (0.00E,0.00N,126.00Azi) · Survey Caleuhh Mb: Mblbllum CMFvahro Db: Oraolo Survey MI) IBd Azlm TVD SSTVD N/S F. TW MapN Mtpl: DIS VS 11110.00 70.20 131.10 9016.20 8944.95 -848.g6 4808.56 5959461.94 648131.51 9.71 4389.22 11140.00 71.60 129.50 9026.02 8954.77 -867.30 4830.18 595.e~.~?..03 648153.47 6.87 4417.49 11170.00 73.60 124.80 9035.00 8963.75 -884.57 4853.00 5959427.19 648176.61 16.37 ~446.10 11200.00 74.60 127.20 9043.22 8971.97 -901.53 4876.34 5959410.68 648200.26 8.38 4474.95 11230.00 75.80 132.10 9050.88 8979.63 -920.04 4898.66 5959392.61 648222.93 16.29 4503.88 11260.00 76.80 137.30 9057.99 8986.74 -940.53 4919.37 5959372.51 648244.03 17.17 4532.68 11290.00 77.30 142.10 9064.72 8993.47 -962.82 4938.27 5959350.59 648263.35 15.68 4561.08 11335.00 77.30 142.10 9074.61 9003.36 -997.46 4965.23 5959316.47 648290.97 0.00 4603.25 Illllllll , , I ANNOTATIONS No. ~ MD Annotallon I 8760.53 1(~?0.00 Kick-oflPo~ 2 90~.36 11~.~ P~ecledtoTO BP Amoco WELLPA TH DETAILS H~ZA 500292024201 Parent Wellpat~: H.07 Tie on MD: IO~TO. O0 Ve~lcal Section On, in: SIo!- 07 (0.00~0.00) Verl~cal Section Angle: 126.00~ Rig: Nabom 3S Deplh Reference: 11: 07 61~11998 12.~0 71.25ft REFERENCE INFORMATION ~,<m:linale (N,'E) Rderence~ Wel Certre: H-07. Tree ~ Ye~..al ('IVD) Re~anc~ ~ Mean Sea Le/el T, IRC~-T DGTA~$ BPAmoco BAKIR / ~~ HUGNESI [NTIBQ / LEGEND ~07,~7~ #1~ H-07 ~07) ~07A i W¢I~I~: (li~?/H.O?^) Azint]ths t o Tmc Ninth I M,'lagnctic Noflh: 26.921 C'rca~d By: Brij ~ais Ds~: 9/28/~ ~rcn~h: 57342nTi r ~ ~ o,m ~, Dip Anglc: 80.69° I ~ct ~uoT) ~7 6u ~3 I i : : : : : '.%.~ : ~ : / : : : : j ...... .~ .............. ~. .............. ..=. ...... .L...................i I ...... i ....... ; .............. ~ ............. ~ .............. -.'" ..................... ...... '~ ..................... ~----':': ............ [~----.---~.,.' '- -lOOO i i ; i i , E i ;,., ,.'~ , _.',.. : : : ~ .............. ~ .............. ~ ........... L ........... 4 ........................ ~ .............. ' ....... ~ ............................. L ......... -'.,. ....... ~.......~ .............. &.~ ' ..~ ...... ~ ...... ~ .............. : : : : : : : ~, /: : : I Prndia~_lad f, ~ Tm: : : I ~ .............. & ............... & ............. ~ ............ ~ ........................... ~ ..................... 4 ............................. ~ ............. ~ ............... 4 .............. ~ .............. ~ .............. & ...... 4--.-.-~ .............. ~- : '. i ~ ............... ..:- ............... f ...................... ~ ....... ½ ...... I .................... ~ ..................... 4 ............................. f ............. i .............. 4 .............. 4 .............. ; .............. ~ ...... 4 ..................... i ; :: i ! ! - !- ! ! !~ ~.~:--: ..... :-.'"::::- ..... ~ ....... :~::::::: i ; ~ ; i ; i i i i ~ 42oo 44o0 46oo 48oo 5ooo 5200 ~'"~""" ;"""~ Welt(.)/Ealt(+) [200ft/in] - -- I Pr~q~d a T~ I ~7 (H~TII 3600 3800 4~ 42~ ~ 4~ ~ ~ 5200 5400 Vertical Section at 126.00° [20Oft/in] Plot 1/22/2001 10:08 AM STATE OF ALASKA ALASI~ L AND GAS CONSERVATION COM~~' ~ION 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-128 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20242-01 _ _ 4. Location of well at surface .~' i~il.i..: '~'.."-i~i~i;i!'"~ LOC,.A?~ 9. Unit or Lease Name 569' SNL, 1266' WEL, SEC. 21, T11N, R13E, UM . ' ~'~D_ _.~_:. ~. ~ ) Prudhoe Bay Unit At top of productive interval ~ i{ 1160' SNL, 3163' NWL, SEC. 22, T11N, R13E, UM At total depth ~ ~,,,,, ~'; ~'~!~;~";~!:::' 1566' SNL, 3694' NWL, SEC. 22, T11N, R13E, UM ~.:~::.~ " . .,10. Well Number H-07A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 111. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool RKB = 71.25' ADL 028284 12. Date Spudded 9/9/2000 110' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'9/11/2000 9/14/2000 115' water depth' `, °ffsh°re N/A MSL 116' NO' Of C°mpleti°ns One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 11335 9071 FTI 11272 9057 FTI [] Yes [] No I (Nipple) 2170' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, Memory GR, CCLORIGINAL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUN~ PU~ED~.~,~. 20" x 30" Insulated Conductor Surface 110' 36" 200 cuft Concrete ~.' ,,, 13-3/8" 72# N-80 Surface 2716' 17-1/2" 5337 cuff .......... 9-5/8" 47# " N-80 Surface 9935' 12-1/4" 2023 cu ft ,-~ _. ,,~_ ~"1 29# N'SO '"9472' 10581' 8-1/2" 474 cuff I 2-7/8" 6.16# L-80 10269' 11335' 3-3/4" 76 cuft Class 'G' 24. Perforations pp, en to, Production (MD+TVD of Top and 25. TUBING RECORD Bottom and ~merva,, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 7", 26#, N-80 9472' 9432' MD TVD MD TVD 10874' - 10924' 8950' - 8963' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL {MD) AMOUNT & KIND OF MATERIAL USED 10260' Freeze Protect with 400 Bbls of Dead Crude 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 29, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL'BBL G^s-MCF WATER-BOL CHOKE S~ZE ~ GAs-OIL RATIO TEST PERIOD I Flow Tubing :casing Pressure CALCULATED OIL-BBL GAS-MCF ~WATER-BBL OIL GRAVITY'API (CORR) Press. 24-HOUR RATE , , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,,,, Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. , 27P 10622' 8860' 26P ,- 10738' 8909' 25N o 10814' 8934' 25P o 10858' 8946' 24P · 10937' 8966' 23N 11112' 9013' 23P 11120' 9016' 22N 11182' 9035' 22P 11186' 9036' HOT 11186' 9036' 31. List of Attachments: " Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble .~.~_/1[~,~_ ~ Title TechnicalAssistant Date ~)" ~'~) H-07A 200-128 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injectio~i~'~er~exp!ai~:- ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: H-07A Accept: 09/03/00 Field: Prudhoe Bay Spud: 09/09/00 APl: 50-029-20242-01 Release: 09/14/00 Permit: 200-128 CTD Unit: Nordic #1 PRE-RIG WORK 08/31100 MIRU DS CTU#8. Function test BOP. MU BHA #1. Pressure test surface lines. RIH, at 10600' begin batching cement. Start KCL water down backside, pressure test cementers. Start freshwater spacer. Pump 17 Bbls cement to abandon open perforations, park coil at 10600'. Switch to spacer. Switch to KCL water. Cement o~t coil, PU to safety. Bring squeeze to final pressure of 600 psi and hold. Squeeze held good. Contaminate with Biozan and clean to 10460'. Chase to surface and freeze protect. Blow coil down with N2. 09/01/00 Tag TOC at 10465' SLM w/2.625 Cent. Set 5-1/2" bait sub and PRT in POGLM at 4601' SLM. COIL TUBING DRILLING 09/04/00 NU BOP's, MIRU Dowell CTU #4. BOP Test passed. RIH with BHA #1 to fish POGLM. Fishing operations ongoing. 09/05/00 BHA #1, no fish recovered. BHA #2 - Recovered bait sub. BHA #3, tried to drive POGLM to bottom, stuck in SSSV. Call out slickline. Fished Y2 of PRT from POGLM. Run LIB to locate rest of fish. 09/06/00 Ran slickline to confirm the top of fishing neck is clear. Will need special fishing tool (reinforced PRT) to continue operations. Order PRT from Baker machine shop. Stand by. 09/07/00 Drift to fish with 5.75" drift. Bait fish with remanufactured PRT. Fish POGLM out of hole. Fish out pieces of rubber element. 09/08/00 POOH. Change to e-coil. Re-head and test same. MU pilot BHA. RIH. Mill pilot hole from 10470' to 10579'. POOH. 09/09/00 POOH. MU window mill assembly. RIH. Time mill window. POOH. RIH with dressing mill. 09/10/00 '~ Dress window. BHA / mill trip. Complete dressing window. BHA trip. MU drilling assembly. RIH. Displace to rio-pro. Drill build from 10630' to 10750'. 09/11/00 BHA trip. Test BOPE. Re-head and displace coil. RIH. Drill tangent from 10750' to 10920'. H-07A, Coil Tubing Drilling Page 2 09/12/00 Drill tangent from 10920' to 11335'. Condition hole for liner. Log GR tie-in. POOH. Stab pipe on ROC. MU and RIH with memory RES / GR tools. Log OH. POOH. 09/13/OO Make liner conditioning run. MU and run 35 joints of 2-7/8" liner. RU cementers. 09114/00 Cement liner with 13.5 bbls Class G. Run memory GR / CCL tie-in log. Pressure test lap to 2000 psi. Perforate 10874' to 10924'. 09/15/00 Lay down guns. RIH with nozzle to TOL and displace well to dead crude. Set BPV. Blowdown reels. ND BOPE, NU and PT flange on master. RDMO. Il I End of Well Survey Calculations ~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: BP Exploration Alaska, Inc. Rig: Nabors 3S Field: Prudhoe Ba~, Unit RKB Height: 71.250 Well: H-07A (Drilled from H-07) Vertical Sect. Plane: 126.000 Job No: 75854 Mag. Declination: 26.920 AFE No: 4P-1419 Grid Correction: 1.080 AP1 No: 50-029.20242-01 Job Start Date: 7-Sep-00 BHI Rep: lt, v. Gm'p, N. Radmilovic Job End Date: ll-Sep-00 Survey Date: ll-Sep-O0 Survey Type: MWD Meas. Incl. TRUE TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Depth Angle Azi. V. Depth TVD N(+)/S(-) E(+)fvV(-) N(+)/S(-) E(+)/W(-) Severity Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) Lat. (Y) Dep. (X) (°/100ft) (ft) 10570.00 44.15 128.31 8831.78 8760.53! -566.26 4401.58 5959736.81 647719.23 0.00 3893.79 10600.00 53.40 129.00 8851.53 8780.28 -580.35 4419.17 5959723.06 647737.09 30.88 3916.31 10630.00 59.80 129.00 8868.03: 8796.78 -596.10 4438.62 5959707.68 647756.84 21.33 3941.30 10660.00 66.40 129.00 8881.60 8810.35 -612.93 4459.40 5959691.26 647777.94 22.00 3968.01 10690.00 66.10 121.20 8893.69 8822.44 -628.71 4481.85 5959675.91 647800.67 23.82 3995.43 10719.001 66.10 112.50 8905.46 8834.21 -640.67 4505.47 5959664.41 647824.52 27.42 4021.58 10750.00 68.50 106.20 8917.44 8846.19 -650.12 4532.44 5959655.47 647851.66 20.28 4048.95 10780.00 71.10 109.20 8927.80 8856.55 -658.69 4559.25 5959647.42 647878.63 12.77 4075.68 10810.00 73.60 113.50 8936.89 8865.64 -669.10 4585.87 5959637.52 647905.44 16.00 4103.33 10840.00 75.30 116.50 8944.94 8873.69 -681.31 4612.06 5959625.81 647931.85 11.18 4131.70 10869.00 74.70 119.10 8952.45 8881.20 -694.37 4636.83 5959613.22 647956.87 8.90 4159.42 10900.00 74.30 124.00 8960.73 8889.48 -710.00 4662.28 5959598.08 647982.61 15.29 4189.19 10930.00 76.10 127.80 8968.40 8897.15 -727.00 4685.77 5959581.53 648006.42 13.64 4218.19 10960.00 75.80 ! 31.10 8975.68 8904.43 -745.49 4708.24 5959563.47 648029.23 10.72 4247.23 10990.00 76.30 135.70 8982.92 8911.67 -765.49 4729.38 5959543.88 648050.76 14.97 4276.10 11020.00 77.00 140.10 8989.85 8918.60 -787.15 4748.95 5959522.61 648070.73 14.46 4304.65 11050.00 74.10 138.40 8997.34 8926.09 -809.15 4767.90 5959500.97 648090.10 11.12 4332.92 11080.00 71.20 134.00 9006.29 8935.04 -829.82 4787.71 5959480.69 648110.29 17.01 4361.09 11110.00 70.20 131.10 9016.20 8944.95 -848.96 4808.56 5959461.94 648131.51 9.71 4389.22 11140.00 71.60 129.50 9026.02 8954.77 -867.30 4830.18 5959444.03 648153.47! 6.87 4417.49 11170.00 73.60 124.80 9035.00 8963.75 -884.57 4853.00 5959427.19 648176.6 ! 16.37 4446.10 11200.00 74.60 127.20 9043.22 8971.97 -901.53 4876.34 5959410.68 648200.26 8.38 4474.95 11230.00 75.80 132.10 9050.88 8979.63 -920.04 4898.66 5959392.61 648222.93 16.29 4503.88 11260.00 76.80 137.30 9057.99 8986.74 -940.53 4919.37 5959372.51 648244.03 17.17 4532.68 11290.00 77.30 142.10 9064.72 8993.47 -962.82 4938.27 5959350.59 648263.35 15.68 4561.08 11335.00 77.30 142.10 9074.61 9003.36 -997.46 4965.23 5959316.47 648290.97 0.00 4603.25 BP Amoco WELLPA TH DETAILS H-O7A ~00292024201 Parent WMIpath: H.07 Tie on MD: 10570.00 Vertl~lSec'8onOHgln: Slot-07(O.O0,O. O0) Vertical Section Angle: 126.00' Rig: Nabors 3S Depth Reference: 11: 076120Hg98 12:00 REFERENCE INFORMATION Co.o~dinate (N/E) Reference: Well Centre: H-O7, Tree Nodh YeS, cai (TVD) Rel~ence: System: Mean Sea Level Section (WB) Refemr~e: Slo{ - 07(0.00,0.00) Measured Depth Reference: 11 :O76/20/199812:OO 71.3 Ca~uiat~:m Methed: Minimum Curvature 90~3.~ 11335.00 Pro~tedlo'TD ePArnoco ]~,~j~ ..~~j LEGEND H-OT.H-OTA.Pla~ ~109 H-07 (H-07) H*O7A wcu~: M Magnetic No~lh: 26.92' ICr~ By: B,j Poems I)a~e: 9~ A~m~hs to T~e N~h ~ M naic Field . ~m~: 57342~T I C~ta~ ~te: ~ I E.~I ~j ~lnbOl~ c~ I 8400 - ' 8600 ~1_r_ -,,,~-~!-. 400~ 4200 4400 4000 4~00 5000 6200 wost(-yE,,st(+) [ax.an] H-07A T1 . "]: : / J H.-07,1-1~07A,Plan #109 I 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 Vertioal ~ection at 126.00° [200fffin] Prepared by Baker Hughes INTEQ Il' ProActive Diagnostic Services, Inc. LOG To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey ProActive Diagnostic Services, Inc. 3:!.0 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99508 LOG ,-"~'ITAL -") MYLAR / BLUE REPORT WELL DATE TYPE ~ SEPIA LINE OR CD-ROM FILM PRINT(S) BLUELINE H-O7a 9-12-00 Open Hole ri._. 1 1 Res. Eval. CH I I 1 Mech. CH ,, Caliper Survey I Rpt or OECEIVEn ,"-.. ]%, i~ Signed' (~~ 3 Date' 0!~T 09 ~-000 . 'n Print Name: ~ 0ii& Gas Cons. Comm~ss~o. Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: www.memorvlog.com ALASIIA OIL AND GAS CONSERVATION CO~vIISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas McCarty CT Drillng Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit H-07A BP Exploration (Alaska) Inc. Permit No: 200-128 Sur Loc: 569'SNL, 1266'WEL, Sec. 21, T11N, R13E, UM Btmhole Loc. 3793'NSL, 1658'WEL, sec. 22, TllN, R13E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE _CO~I, MISSION DATED this '~ ~ day of August, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat' Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~"',-/' ALASKA(' _AND GAS CONSERVATION COMI~ .{ION ~/;~ PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work B Drill [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 74.45' Prudhoe Bay Field / Prudhoe .. 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028284 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 569' SNL, 1266' WEL, SEC. 21, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1000' SNL, 2318' WEL, SEC. 22, T11N, R13E, UM H-07A Number 2S100302630-277 At total, ~,d~th 9. Approximate spud date 3793,~S~, ~58' WEL, SEC. 22, T11N, R13E, UM 09/01/00 Amount $200,000.00 12. Distance to nearest property line ~13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028285, 1658' MDI No Close Approach 2560 11228' MD/8969' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10580' Maximum Hole Angle 76.2 ° Maximum surface 2109 psig, At total depth (TVD) 8800' / 3165 psig 18. Casing Program l "- Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin.q Wei.qht Grade Couplinq Len,qth MD TVD MD TVD (include sta.qe data) 3" 2-3/8" 4.39# L-80 FL4S 858' 10370' 8615' 11228' 8969' 95 cu ft Class 'G' .. 19. To be completed for Redrill, Re-entry, and Deepen OperationS.Present well condition summary Total depth: measured 11060 feet Plugs (measured) true vertical 9199 feet Effective depth: measured 10756 feet Junk (measured) Multiple junk in hole - See diagram true vertical 8968 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds 110' 110' Surface 2685' 13-3/8" 5337 cu ft 2716' 2716' Intermediate Production 9904' 9-5/8" 2023 cu ft 9935' 8401' Liner 1586' 7" 474 ca ft RECE~VE~472,. 11058' 8092'- 9198' Perforation depth: measured Open: 10765'-10795' AU{~ 2.2 2000 true vertical Open: 8975' - 8997' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarly, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas McCa~----'~,,~,~z',~_~,~~'~ Title CT Drilling Engineer Date r.~/,~ Z..//~ t Permit Number APl Number Api~rovaI.Date See cover letter ~ - / ~ .50-029-20242-01 ~' L~,.Z~/~(~) fo.r other requirements Conditions of Approval: Samples Required [] Yes ,l~,No Mud Log Hequired [] Yes 'l~No Hydrogen Sulfide Measures '~Yes [] No Directional Survey Required ~Yesl"l'No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~3,:,.5K psi for CTU Other: by order of (~/ Approved By ORIGINAL,. -,- , SIGNED,, BY, Commissioner the commission Date Form 10-401 Rev. 12-01-85 D T~yluf SUaTTlUU~I[ SA I'riplicate BPX H-O7a Sidetrack Summary of Operations: H-07 is currently shut in. The H-07a sidetrack will be a replacement wellbore to access remaining lower Zone 2 (25P) reserves in the central portion of the eastern H-Pad area. This sidetrack will be conducted in two phases. Phase 1: Downsqueeze cement, Mill window off of cement whipstock. Planned for August 27, 2000. · Service coil will downsqueeze approx. 26 bbls cement to shut off existing perfs. · Service coil will mill the window off of a cement whipstock with the KOP at approx. 10576'md Phase 2: Drill and Complete sidetrack: Planned for Sept 1, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented 2 3/8" liner that will overlap the existing 7" liner by approx. 200 ft above the window. The top of 2 3/8" liner planned to be approx. 10,370' MD with the cement brought to the top of the liner. Approx. 17 bbls cement will be used for this liner cement job. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.9 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8", 4.39#, L-80, FL4S cemented liner will be run from TD to approx. 10,370' MD. Top of liner cement will be at approx. 10,370' MD. Well Control: · BOP diagram is attached. · .Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to"~l~si. /_,.,~.,..~ · The annular preventer will be tested to 400 psi and 2000 psi. ~,.-~~k"c~~ ~ T~<~¢~- ~.~%~'~ Directional ~c.,~.~%,,5~ ~,.,~--¥r,,'~% ~\xv,(,, · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A memory resistivity log will be run once td is reached. Hazards No lost circulation is expected. Max. recorded H2S on H Pad in the last two years is 170 ppm. The last H2S reading on H-07 was 1 lppm on Jan. 1, 1999. Reservoir Pressure Res. pressure is estimated to be 3165 psi at 8800ss (based on 5/3/00 static). Maximum surface pressure with gas (0.12 psi/ft) to surface is 2109 psi. RECEIVED AUG 22 2000 Alaska Oi'J & Gas Cor~,s. Commission Anchorage H-07a Potential Drilling Hazards Post on Rig 1. H2S is not expected on this well. The last H2S reading on H-07 was 1 lppm on Jan. 1, 1999. Maximum recorded H2S in the last two years on H Pad is 170 ppm. 2. BHP is expected to be 3165psi@ 8800' tvdss, 217 deg. F. 3. Maximum anticipated well head pressure w/full column of gas 2109psi. 4. No major faults are anticipated in the planned polygon, although there are mapped conductive faults past the end of the polygon which should not be drilled into. 5. Uncertainty in the oil/water contact is high RECEIVED AUG 2 2 Alaska Oi,~ & Gas Co~s. ~ch~age H-07 Vertical Section 8500 855O 8600 9000 0 500 -TSAD -TZ2C Path Distance (Feet) 1,000 1,500 I I 2,000 I H-07a Tiny Tool Sidetrack Case 109 4/28/00 Kicks off just above the 3 1/2" pkr. Angle @ K.O.= 44 deg MD:10580 Tot Drld:648 ft 11228 TD Marker Depths ~Orig Wellbore "' 8'8671 8,8671.'rvD 8,9681 8,9681ff TVD I 8,? 0'l wD TSAD I 8,6461"TVD Kick Off } 8,7641ft TVD I 10,580Jff MD Deprtr ~KO 4,456 ff MD KO Pt MD New Hole Total MD TVD TD 10.580I 648I 11,228I 8,969'I Curve I DLS de~]/100 6 Curve 2 22 Curve 3 22 Curve 4 22 Curve 5 22 Tool Face Length 0 20 20 140 -88 170 90 169 -90 149 648 Drawn: 4/28/2000 9:48 Plan Name: Case 109 RECEIVED AUG 2£ 2000 Alaska 0ii & Gas Cons. Commission Anchorage H-07 -500 -1,000 -1,500 4,000 I 4,500 5,000 X distance from Sfc Loc 5,500 Iwell Name ' H-07 '" I CLOSURE IDistance 4,973 ff Az 99 deg NEW HOLE E/W (X) N/S (Y) Kick Off 4,414 -484 TD 4,'905 -8'2~ State Plane 648,213 5~959,39~ Su~ace Loc 643,308 5,960,219 DLS deg/100 Tool Face Length Curve I " 6 0 20 ~Curve 2 22 20 t40 Curve 3 22 -881 t70 ,,, Curve 4 22 90 169 ,,, C u rve 5 22 -90 149 64§ i Drawn: 4/28/2000 9:48 Plan Name: Case 109 ,.000 AUG 2 2 '"' ': Alaska Oi-i & A~cherage '1 TREE: 6-3/8 ....CIW WELLHEAD: McEVOY ACTUATOR:6" OTIS 13'3/8", 72#/ft, I 2716,I N-80, BTRS "07a Proposed Completion KB. ELEV = 76.40 BF. ELEV = 45.75 SSSV LANDING NIPPLE ( OTIS )( 5.962" ID) I2170' I FOC-- KOP:2900' MAX ANGLE: 49° @ 10188' TUBING ID: 6.276" CAPACITY: 0.0383 BBL/FT 7", 26#/ft, N-80 PERFORATION SUMMARY REF: LOG: CBL 5/12/77 I 6 I INTERVAL (,PEN/SQZ'D 10672-10707' 10749-10759' 10765-10769' 10765-10772 10769-10795' 10795'-10799' 10809-10834 SQZ SQZ OPEN Reshot 6/12/96 SQZ/Reshot SQZ SQZ BOT SS PACKER 9-5/8", 47#/ft, N-80, BTRS 9432' I IHole punched @ 4631 ft 7" tubing PBGLM @ 4620' Min ID through 2.875" Min ID packoff only 3.958 RECEI FED AUG 22 2000 ~ ~Jas ~ons. Commission Anchorage OF SEAL ASSY. I 9472' OF SEAL ASSY I 9510' 2 3/8" Liner cemented to approx. 200 ft abv. window Cement whipstock approx. 10,570' Existing perfs to be abandoned by downsqueezing cement 10,624' top of FB-1 Baker Prod Pkr. Pkr ID=4.00", 3 1/2" TBG ID=2.997" 10668' top of cement sheath 5.5" pilot hole through cement 10,700 btm of 3 1/2", 9.3#, L-80, Scab liner 10710-10743 ft joint of 3 1/2" tubing unscrewed from scab liner 10756 ft Fish 12' CTU drilling BHA as per telex 3/31/96 PBTD 7", 29#/ft, N-80, BTRS 10816' bottom of 5.5" pilot hole 4.4" pi!ot10885 bottomh°le tohfr~.u~h, cement 10887' base of cement JUNK I10962' IMore Junk (9-12-95) (3) 4-1/2" RQ Keys TREE: 6-3/8"" ClW WELLHEAD: McEVOYH-07KB. ELEV = 76.40 ACTUATOR'6" OTIS i~' BF. ELEV = 45.7~ · i-- I I-~ '1 i-- SSSVL~ND~NGN~"'PLE 1217rrl ,3 ~- 72#~. -~' I ~' I / ( OTiS )( 5.962 'ID) I v .~. ~.s '- .cc_ I r-~ i ,, m mm i Ho,epunchod · 1JBING lB' 6 276' _~ =mi ~---- ,I I~__~o. o~ s~ss~. 1 9472'1 ,-~o.,,,s 199351------~-, / { ~ { 10608-10615 ft p{ugo! cement m | I 10,624' top of FB-1 Baker Prod Pkr. ~ '~ .__Pkr 10=4.00", 3 1/2" TBG I0=2.997" PERFORATION SUMMARY m ) 10668, top of cement sheath REF: LOG: CBL 5/12/77 F -I 5'_5" pil°t h°le thr°ugh cement SIZE SPF INTERVAL C PEN/$QZ'D I 10,700 btm of 3 1/2", 9.3#, L-80, Scab liner 4' 4 !10749-10759' soz I/ ' ' 1 a~o' 6 ! 10765-10769' :OPEN 1075~. ~i~h 12' c~ ~,~n~ B.^ 3~/8': 6 10760-10795' SQ7_/Reshotil_.m_m ' 4 4 10795 10799 SQZ ct hole " " ' -F - 10816' bottom of 5.5" pil i !/ I ' ~ DATE REV. BY COMMENTS PRUDHOE BAY UNIT 5-1-78 COMPLETION WELL: H-07(22-11-13) 10-10-89 Uullin ORIGINAL MAC DIAGRAM APl NO: 50-029-20242 8/15/91 REVISED SEC 22; TN 11; RGE 13 02/28/96 RRW 3 1/2" SCAB LINER, FOR GSO 6/12/9 EBK Re Perf BP Exploration (Alaska) n AUG 22 2000 AJaska Oii& Gas Cor~s, Commission Anch0F~g~ C T Drilling Wellhead Detail ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection Otis 7' WLA Quick Connect 7' Riser Annular BOP (Hydril),7-1/16' ID 5000 psi WP Alignment Guide Flange 7-1/16', 5M Ram Type Dual Gate BOPE ~ Flanged Rre Resistant Kelly Hose to Dual HCR Choke Manifold Cuttel~ or Combination Cutter/Blinds Slip/Pipe Rams Valves Drilling spool 7-1/16', 5M by 7-1/16', 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16' ID with Pipe/Slip Rams Manual Master Valve e 0.458' (5.5') 2' Pump-In Hanger Fire resistant Kelly Hose to Range by Hammer up 1/4 Turn Valve on DS Hardline toStandpipe manifold Upper Annulus Lower Annulus 'RECEIVED .o AUg 22 2OOO Aiaska Oi,i & Ga~, ~;o~s. Anchorage i DATE i GHEC;K NO. H 1 72568 ~01725&8 -- VENDOR AL~ :SKASTAT 10 __ DATE INVOIC;E / CREDIT MEMO DE,~CRJ~¥1ON GRO,S,5 DhSCOUNT NET 080:300 :KOSOs~OOL 100. O0 100. O0 I-~NDL I I ~0 I NST: TERR I E X46~8 THE AI'rACHED CHECK I$ IN PAYMENT FOR ITEMS DESCRIBED ABOVE~ 1 OO. OO 1OO_ OO m:Om,&20~qSm: OO~NN&q," STATE OF ALASKA ALASK( '~IL AND GAS CONSERVATION COMi~~' '~SION ~,- PLICATION FOR SUNDRY APPROVe,. 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Suspend [] Repair Well [] Operation Shutdown [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 569' SNL, 1266' WEL, SEC. 21, T11N, R13E, UM At top of productive interval 1000' SNL, 2318' WEL, SEC. 22, T11N, R13E, UM At effective depth 1214' SNL, 2047' WEL, SEC. 22, T11N, R13E, UM At total depth 1339' SNL, 1894' WEL, SEC. 22, T11N, R13E, UM RECEIVED AUG 2 2. 2000 Atasks C;."; & Gas Cons. mm ion Anchorage [] Perforate [] Other Plug Back for Sidetrack 6. Datum Elevation (DF or KB) 74.45' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-07 9. Permit Number 177-011 10. APl Number 50- 029-20242-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11060 feet true vertical 9199 feet Effective depth: measured 10756 feet true vertical 8968 feet Casing Length Structural Conductor 110' Surface 2685' Intermediate Production 9904' Liner 1586' Plugs (measured) Junk (measured) Size 20" x 30" 8 cu yds 13-3/8" 5337 cuft 9-5/8" 2023 cu ft 7" 474 cu ft Multiple junk in hole - See diagram Cemented MD 110' 2716' 9935' 9472' - 11058' TVD 110' 2716' 8401' 8092' - 9198' Perforation depth: measured Open: 10765' - 10795' ORIGINAL true vertical Open: 8975' - 8997' Tubing (size, grade, and measured depth) 7", 26#, N-80 stabbed into top 7" liner at 9472' Packers and SSSV (type and measured depth) 3-1/2" Baker 'FB-I' packer at 10624'; 9-5/8" POT packer at 9432'; 4-1/2" SSSV Landing Nipple at 2170' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation August 27, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Thomas McCarty, 564-5697 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge SignedThomas~McCArb7 --'~- ~ ~"~'~'~'~ Title CT Drilling Engineer Date Conditions of Approval: Nofi~ ~mmi~ion so representative may ~e~ II Approval Plug integ~ ~ BOP Test ~ L~afion clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ~,pproved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate WELL PERMIT CHECKLIST COMPANY J~: WELL NAME FIELD & POOL ~-/--~/~ INIT CLASS - ~'1,/ PROGRAM: exp dev .... v/reddl ~,'/~ serv wellbore seg ann. disposal para req. GEOL AREA r~:~4:~ UNIT# ~//~:~.~ ON/OFF SHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary ..... 6. Well located proper distance from other wells.'~' ~'~ ~.r.,'<_...4~_ 7. Sufficient acreage available in drilling unit ........ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adeqUate to tie-in long string to surf csg .... .... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet:regulation ................ 26. DOPE press rating appropriate; test to %5OL.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ADMINISTRATION DATE ENGINEERING FDATE ~_/~' GEOLOGY R DATE 30. Permit can be issued wlo.hydro'gen sulfide measures ..... Y~ Z,~..~/-~~.~, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ........... :. ~,i/~ ~-Y N 33. Seabed condition survey (if.off-shore) ......... .~,,,,~(" -- Y N 34. Contact name/phone for weekly progress reports [~,v, plbratory only] Y N Comments/Instructions: ANNULAR DISPOSAL35. With proper cementing reCOrds, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UICIAnnular COMMISSION: ,/-"~' TEM:~?' ,. _..,c.,. J§ c:~msoffice\wordian\diana\checklist (rev. 02117100) Well Histo.ry 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. **** REEL HEADER **** MWD 02/03/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/27 75854 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame -Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10558.0000: Starting Depth STOP.FT 11335.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration, Inc. WELL. WELL: H-07A FLD . FIELD: Prudhoe Bay Unit LOC , LOCATION: 569' SNL, 1266' WEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC, SERVICE COMPANY: Baker Hughes INTEQ TOOL, TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: ll-Sep-00 API. API NUMBER: 500292024201 ~Parameter Information Block #MNEM.UNIT Value Description SECT. 21 : Section TOWN.N llN : Township RANG. 13E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 71.25 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 71.25 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks 1) Ail depths are Measured Depths (MD) unless otherwise noted. 2) All depths are Bit Depths unless otherwise noted. 3) All Gamma Ray data (GRAX) presented is realtime data. 4) Well H-07A was kicked off from the wellbore of Well H-07 through a window in the 7" liner at 10570' MD (8761' SSTVD). 5) Well H-07A was drilled to TD at 11335' MD (9003' SSTVD). 6) The interval from 11311' MD (8998' SSTVD) to 11335' MD (9003' SSTVD) was not logged due to sensor to bit offset. 7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 13-Sep-00). (8) A Magnetic Declination correction of 26.92 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 4 25.57 ft. 30.60 ft. 5 25.57 ft. 30.60 ft. CURVE SHIFT DATA BASELINE 10761 8 10774 2 10813 0 10833 0 10846 5 10851 1 10869 3 10917 0 11104 1 11138 9 11176 4 11199 5 EOZ END MEASURED, 10764 5 10775 0 10815 0 10835 8 10847 9 10853 3 10871 1 10919 7 11108 6 11143 1 11179 8 11204 5 DISPLACEMENT 2.62598 0.807617 2.02051 2.82812 1.41406 2 22266 1 81836 2 62598 4 44531 4 24219 3 43457 5 05078 BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 83 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN H-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 13-Sep-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... GR GR GRAX12 0.0 ROP ROP ROPS12 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Na~ne Tool 1 GR MWD 2 ROP MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Length 4 4 8 Total Data Records: 19 Tape File Start Depth = 10558.000000 Tape File End Depth = 11335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 28 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MN-EM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN H-07A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COM~4ENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MN-EM CHAN DIMT CNAM ODEP ................ GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MWD Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Length 4 4 8 Total Data Records: 19 Tape File Start Depth = 10558.000000 Tape File End Depth = 11335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: 28 records... 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/27 75854 01 **** REEL TRAILER **** MWD 02/03/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 10558. 10558. 10600. 10700. 10800 10900 11000 11100 11200 11300 11335 0000 5000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GR 14.9446 15.9316 23 8296 25 4256 20 6414 21 3729 18 3511 16 3191 14.9204 20.7860 -999.2500 ROP -999.2500 -999.2500 6.5004 39.3700 73.5890 97.3698 123.4600 57.6150 111.9508 90.1600 49.1010 Tape File Start Depth = 10558.000000 Tape File End Depth = 11335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 10558.0000 10558.5000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11335.0000 GRAX 16.0100 15.4740 21.4670 24 2240 20 6300 21 8020 24 2240 21 0990 27 4800 23 5210 -999.2500 ROPS -999.2500 -999.2500 0.6140 19.8740 76.2000 73.1330 49.1100 57.6150 123.8920 87.4890 -999.2500 Tape File Start Depth = 10558.000000 Tape File End Depth = 11335.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS