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HomeMy WebLinkAbout190-129Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 4-1/2" PHL Perma Latch Ret Packer 4-1/2" TIW Packer 4-1/2" Otis WD Packer 12909 / 9657 13046 / 9763 13548 / 10176 Hilcorp Alaska, LLC 12/22/25Monty M Myers 325-771 By Grace Christianson at 3:47 pm, Dec 22, 2025 J.Lau 12.30.25 DSR-12/29/25TS 12/24/25 *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. Open hole window milling not to exceed 15'. 10-404 01/15/26 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: December 22, 2025 Re:END 02-38 Sundry Request Sundry approval is requested to set a whipstock in the END 02-38 wellbore as part of the drilling and completion of the proposed 02-38A CTD lateral. Proposed plan: Prior to drilling activities, a RWO will be performed (see separate Sundry) and lay in a cement plug to shut off lower Alapah perfs. Screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2"x7" whipstock. Coil will mill window pre-rig. If unable to set the whipstock or mill the window pre-rig, the rig will perform that work. See 02-38A 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 pre-rig, the rig will set the 4-1/2"x7" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling and land in the Ivishak. The lateral will continue in the Ivishak 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 Sag Delta North Ivishak Oil Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, 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 January 2026) 1. RWO : 7" cemented scab liner and tubing swap 2. Coil : MU Slim nozzle assy; Tag PBTD, lay in ~5 bbls 15.8 ppg cement from PBTD to ~13,500’ MD. Wait on 500 psi compressive and tag TOC w/ 10K down weight. 3. Slickline : Dummy WS drift and Caliper 4. E-Line : Set 4-1/2" x 7" Whipstock at 13,385’ MD at 0 degrees ROHS 5. Coil : Mill window in 7" Liner 6. Valve Shop : Pre-CTD Tree Work 7. Operations : Remove wellhouse and level pad. Rig Work: Reference 02-38A Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,750 psi high (MASP 3,504 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, ~162' (40 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~3,049' (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 6. Pump primary cement job*: 49 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 7. Only if not able to do with service coil extended perf post rig – Perforate Liner with 1-1/4" CS Hydril 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, CBL, and perforate (~500’). 4. Testing : Portable test separator flowback. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 SCHEMATIC ______________________________________________________________________________ Revised By: DH 12/16/2025 Duck Island Unit Well: END 2-38 Last Completed: 06/10/2016 PTD: 190-129 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 130’N/A 13-3/8”Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’0.150 9-5/8"Intermediate 47 / NT80S / NSCC 8.681 Surface 11,083’0.0732 9-5/8"Intermediate 47/ NT95HS/ NSCC 8.681 11,083’13,349’0.0732 7"Liner 29/ NT95HS/ TKC 6.184 13,087’13,831’0.0372 TUBING DETAIL 4-1/2"Tubing 12.6/ L-80/ TCII 3.958 Surface 13,002’0.0152 4-1/2”Tubing 12.6/ L-80/ TDS 3.958 13,002’13,554’0.0152 JEWELRY DETAIL No Depth Item 1 1,497’XXO SSSV Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: Camco 4-1/2” MMG w/ 1-1/2” valve, RK Latch 2 5,221’STA 6: Vlv= Dome, Dev.= 50, Port= 16/64, TVD= 4,070’, 6/16/2016 3 7,650’STA 5: Vlv= Dome, Dev.= 42, Port= 16/64, TVD= 5,884’, 6/16/2016 4 8,685’STA 4:Vlv= Orifice, Dev.= 45, Port= 32/64, TVD= 6,624’, 8/30/2018 5 10,413’STA 3:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 7,887’, 6/8/2016 6 11,642’STA 2:Vlv= Dmy, Dev.=46, Port= n/a, TVD= 8,762’, 6/8/2016 7 12,792’STA 1:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 9,569’, 6/8/2016 8 12,859’ X-Nipple, ID=3.813” 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813”, 4-1/2” PX Plug in X-Nipple set on 11/9/25 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958” - Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ivishak 13,324’ 13,354’ 9,987’ 10,012’30 7/23/25 Squeezed 2-7/8” 13,382’13,387 10,035’ 10,040’5 7/23/25 Squeezed 2-7/8” 13,393’ 13,454’ 10,045’ 10,096’61 7/23/25 Squeezed 3-3/8” 13,394’ 13,486’ 10,046’ 10,123’92 7/23/25 Squeezed 3-3/8” Alapah 13,605’ 13,628’ 10,226’ 10,246’23 6/11/91 Open 3-3/8” Reference Perf Log: DLL/ GR on 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8”3,394 cu/ft Permafrost in 17.5” Hole 9-5/8"3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7”400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 RWO – 06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV Proposed Schematic CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 130’N/A 13-3/8”Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’0.150 9-5/8"Intermediate 47 / NT80S / NSCC 8.681 Surface 11,083’0.0732 9-5/8"Intermediate 47/ NT95HS/ NSCC 8.681 11,083’13,349’0.0732 7”Tieback 26/L-80/TSH w563 6.276 Surface 12,850’0.0383 7"Liner 29/ NT95HS/ TKC 6.184 13,087’13,831’0.0372 TUBING DETAIL 4-1/2"Tubing 12.6/ 13CR/VT 3.958 Surface 12,850’0.0152 4-1/2”Tubing 12.6/ L-80/ TDS 3.958 13,002’13,554’0.0152 JEWELRY DETAIL No Depth Item 1 1,500’SSSV Landing Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: 4-1/2” KBG w/ 1” valves 2 5,200’ - 12,600’5 GLMS 3 12,650’X-Nipples 3.813” ID 4 12,700’7” x 4-1/2” Packer 5 12,750’X-Nipple 3.813” ID 6 12,800’4-1/2” WLEG 7 12,850’4-1/2” NCS Sleeve 8 12,850’7”x4-1/2” Overshot 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813”, 4-1/2” PX Plug in X-Nipple set on 11/9/25 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958” - Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ivishak 13,324’ 13,354’ 9,987’ 10,012’30 7/23/25 Squeezed 2-7/8” 13,382’13,387 10,035’ 10,040’5 7/23/25 Squeezed 2-7/8” 13,393’ 13,454’ 10,045’ 10,096’61 7/23/25 Squeezed 3-3/8” 13,394’ 13,486’ 10,046’ 10,123’92 7/23/25 Squeezed 3-3/8” Alapah 13,605’ 13,628’ 10,226’ 10,246’23 6/11/91 Closed 3-3/8” Reference Perf Log: DLL/ GR on 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8”3,394 cu/ft Permafrost in 17.5” Hole 9-5/8"3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7”400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 RWO – 06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV TOL = TOC at 12,990’ MD - 3-1/2” x nipple - 3-1/2”x 3-1/4” XO - 3-1/4” liner top packer Proposed Schematic CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 130’N/A 13-3/8”Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’0.150 9-5/8"Intermediate 47 / NT80S / NSCC 8.681 Surface 11,083’0.0732 9-5/8"Intermediate 47/ NT95HS/ NSCC 8.681 11,083’13,349’0.0732 7”Tieback 26/L-80/TSH w563 6.276 Surface 12,850’0.0383 7"Liner 29/ NT95HS/ TKC 6.184 13,087’13,831’0.0372 TUBING DETAIL 4-1/2"Tubing 12.6/ 13CR/VT 3.958 Surface 12,850’0.0152 4-1/2”Tubing 12.6/ L-80/ TDS 3.958 13,002’13,554’0.0152 JEWELRY DETAIL No Depth Item 1 1,500’SSSV Landing Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: 4-1/2” KBG w/ 1” valves 2 5,200’ - 12,600’5 GLMS 3 12,650’X-Nipples 3.813” ID 4 12,700’7” x 4-1/2” Packer 5 12,750’X-Nipple 3.813” ID 6 12,800’4-1/2” WLEG 7 12,850’4-1/2” NCS Sleeve 8 12,850’7”x4-1/2” Overshot 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813”, 4-1/2” PX Plug in X-Nipple set on 11/9/25 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958” - Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Reference Perf Log: DLL/ GR on 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8”3,394 cu/ft Permafrost in 17.5” Hole 9-5/8"3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7”400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 RWO – 06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV TOL = TOC at 12,990’ MD - 3-1/2” x nipple - 3-1/2”x 3-1/4” XO - 3-1/4” liner top packer 3-1/4”x2-7/8” XO at 13,750’ MD 2-7/8” 13Cr Solid Liner at 16,611’ MD 4-1/2”x7” Whipstock at 13,395’ MD Pinch point = 13,400’ MD Well Date Quick Test Sub to Otis - Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular CL Annular Bottom Annular CL Blind/Shears CL Coiled Tubing Pipe / Slips Kill Line Choke Line CL BHA Pipe / Slip CL Coiled Tubing Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR#-AC BOP Schematic CDR Rig's Drip Pan Fill Line Normally Disconnected HP hose to Micromotion LP hose open ended to Flowline (optional) Hydril 7 1/16" Annular Blind/Shear CT Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross CT Pipe/Slips BHA Pipe / Slips nneeeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Remove Plug Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,831' 13,525' Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,090psi Production 7,830psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Contact Phone: 907-564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13,002' TIW Pkr, Liner Top Pkr & Otis WD Pkr and HXO SSSV 13,046(MD/ 9,763(TVD), 13,087(MD)/ 9,795(TVD) & 13,548(MD)/ 10,176(TVD) and 1,553(MD)/ 1,539(TVD) 13,831' Perforation Depth MD (ft): 10,426' 9,690psi See Schematic See Schematic 12.6#/ L-80/ TCII 130' 30" 13-3/8" 9-5/8" 2,541' 4-1/2" 8,372' 13,349' 744' 7" MD N/A 13,558' 9-5/8"2,266' 11,083' 8,150psi 5,020psi 6,870psi 2,391' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 10,008' 2,541' 11,083' Length 190-129 AOGCC USE ONLY 12.6#/ L-80/ TDS 13,130'4-1/2" 1/1/2026 Subsequent Form Required: Suspension Expiration Date: Hilcorp Alaska LLC TVD Burst 10,426' 13,525' 10,157' 3,029 Size Proposed Pools: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22090-00-00 130' 130' IVISHAK OIL Same Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY DUCK IS UNIT MPI 2-38 ENDICOTT No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.12.16 17:01:54 -09'00' Justus Hinks (3691) 325-765 By Grace Christianson at 8:21 am, Dec 17, 2025 *AOGCC witnessed BOP test to 3500 psi, Annular to 2500 psi. *Ensure PX plug is pressure tested prior to RIH to float 7" casing. DSR-12/19/25A.Dewhurst 17DEC25 10-404 2:22 pm, Jan 02, 2026 *AOGCC witnessed tag TOC to verify Alapah reservoir abandonment. J.Lau 1/5/25 XX JLC 1/5/2026 01/05/26 AOGCC Addendum: DUI MPI 2-38 (PTD 190-129) RWO Sundry AOGCC Conditions of Approval: AOGCC witnessed BOP test to 3500 psi, Annular to 2500 psi. Ensure PX plug(s) are - Run a 9- – paused. o - - Redundant Hard Bottom - - Operator AOGCC-Witnessed Drills – - AOGCC. o Drill Detail Submittal - operations. - Rig Management: ASR Rig: o o o o o _____________ RWO END 2-38 PTD: 190-129 Current Bottom Hole Pressure: 4,034 psi @ 10,054’ TVD (SBHPs 6/17/25; 7.8 ppge) Max Proposed Surface Pressure: 3,029 psi Gas Gradient (0.1 psi/ft) Max Deviation: 56° at 4,981’ MD Minimum ID: 3.725” XN @ 13,563’ MD Last Tag: 13,620’ CTM w/ 2.0” JSN (11/04/25) SBHT: 208 Deg F @ 13,405’ MD (SBHPS 5//25/24) History Drilled and completed in 1990. Rig workover in 2016. Re-completed to the Lisburne in 2025 per Sundry #325-197. After the re-complete to the Lisburne an attempt was made to flow with AL without success. On 11/08/2025 water was found flooding the cellars of several wells on MPI. The water was sucked out of the cellars for about 10 days before subsiding to no flow. About four days after water was observed flowing to the cellars gas also started to bubble in the cellars in minimal quantities. Diagnostics on END 2-38 included setting a tubing tail plug and performing a CMIT-TxIA, which failed with a LLR of 1.5 bpm @ ~800 psi. The well was then classified as Not Operable. MIITT passed to 2,711 psi on 11/09/2025. Subsequent diagnostics on the OA indicated a fluid level that moved between ~600’ and 30’ MD when nitrogen pressure was applied to the OA and subsequently bled off. The OA would not pressurize above ~240 psi during these tests which corresponds roughly with the hydrostatic pressure of water @ 600’ MD. Additionally, the fluid level could not be pushed deeper than ~600’ which is indicative of a leak in the surface casing (SC) at that depth. An LDL was performed on 11/15/2025. Waterflow station stops before pumping down the IA showed upward flow @ 250’, 800’, 4,000’, and 6,000’ MD. While pumping hot water down the IA the baseline/pumping temperature overlays indicated a leak from the IA/OA between 850’ and 1080’ MD and waterflow up @ 800’, 1000’, and 1400’ MD. An OA downsqueeze was executed on 11/16/2025 with 158 bbls of 15.8 ppg cement with a final squeeze pressure of ~100 psi. The TxIA was circulated out with 992 bbls of SW through a flowsleeve set in the GLM @ 8,685’ MD while holding 100 – 300 psi on the IA to keep cement in place . The TOC was tagged @ surface in the OA on 11/23/2025. Well Name: END 2-38 API Number: 50-029-22090-00-00 Current Status: Not Operable Producer PTD # 190-129 Estimated Start Date: 1/8/2026 Rig: ASR Reg.Approval Req’std? Yes – 403 Estimated Duration: 14 days Regulatory Contact Darci Horner (907) 777-8406 First Call Engineer: Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Reservoir Engineer: Gavin Dittman (907) 564-5246 (O) (907) 903-1903 (M) Geologist: Brock Rust (907) 777-8394 (O) (615) 306-9509 (M) _____________ RWO END 2-38 PTD: 190-129 MITT to 2,711 psi passed on 11/09/25 with a PX plug set @ 12,986’ MD. CMIT-TxIA failed @ 600 psi on 11/26/2025. A second LDL was performed after the OA downsqueeze on 12/6/25 and indicated the leak @ 1,046’ MD with no other leaks. A PPPOT-IC failed on 11/10/25 to the IA but did not communicate to the OA. TH LDS were all cycled and PPPOT-T passed to 5000 psi on 12/7/25. Objective Execute a rig workover including a 7” casing string cemented to surface and 4-1/2” chrome tubing. Procedural steps Slickline/Fullbore 1. PT PCE to 3,500 psi high, 250 psi low. 2. Pull flowsleeve set @ 8,685’ MD and replace with DGLV. 3. MITT to 2,500 psi target pressure, 2,750 psi max pressure. Eline 4. PT PCE to 3,500 psi high, 250 psi low. 5. Cut tubing with Welltec mechanical cutter or chemical cutter @ ~12,881’ MD (middle of first full joint of tubing above packer – see attached tubing tally snapshot) Wells Support 6. RD well house and flowlines. 7. Remove wellhouses from subject well, 2-36, and 2-40. The GL line will need to be removed from 2-40 to accommodate rig mats. 8. Lift the pad around the well 3’ with rig mats and/or gravel. Drawing a line across the front of the wellhouses and standing facing the well, measuring 77’ to the right from center of wellhead, 65’ to the left from center of wellhead and 90’ out towards the pad with a 10-20% grade going up. Each side of the wellhead will also need to be lifted the 3’ up to the adjacent wells. Fullbore 9. PT PCE to 3,500 psi high, 250 psi low. 10. Reverse 38 bbls of diesel FP out of tubing pumping FW or SW down the IA; max IAP 500 psi. 11. Pump 5 bbls diesel down IA and u-tube TxIA to balance FP. Note that the well only needs FP for the upper 30’ and wellhead because the static temperature is ~40F @ 30’ MD (see temp log of 12/5/25). 12. Monitor well for buildup. Wells Support 13. Confirm well is dead w/ NFT. 14. Set BPV and CTS plug. 15. ND tree. NU BOPE. *See conditions of approval, 9-5/8" CBL required. Verbally approved tubing cut 1/3/25 - J.Lau _____________ RWO END 2-38 PTD: 190-129 NOTE: Wellhead is a 13-5/8” 5M w/ 4” H BPV profile and 4-½” TDS tubing hanger threads Volumes: OA (13-3/8” x 9-5/8”): 2,541’ MD * 0.0597 bpf = 152 bbls IA (9-5/8” x 4-1/2”) to Flowsleeve: 8,685’ MD * 0.0535 bpf = 465 bbls Tubing (4-1/2”) to Flowsleeve: 8,685’ MD x 0.0152 = 132 bbls RWO Procedure MIRU/Test BOPE: 16. MIRU Hilcorp ASR #1 Rig, ancillary equipment and lines to 500 bbl returns tank 17. Test BOPE to 250 psi Low / 3500 psi High, annular to 250 psi Low / 2500 psi High (hold each test of ram/valve for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform BOPE Test as per ASR 1 BOP Test Procedure b. Notify AOGCC 24-hrs in advance of BOPE test c. Confirm test pressure per the Sundry Conditions of Approval d. Test pipe rams on 2-7/8” and 4-½” test joints e. Submit completed 10-424 Blow-Out Preventer Equipment (BOPE) Test from within 5 days of BOPE test 18. Pull CTS plug. Bleed any pressure to the returns tank. Kill well w/ 8.6 ppg KWF as needed. Pull BPV. NOTE: If pressure is indicated underneath BPV, lubricate out BPV. Pull Tbg: 19. MU landing jt or spear, BOLDS, PU on the tbg hgr a. Tbg hgr is 13-5/8” x 4-1/2” TDS (btm) x 4.5” TDS (top) w/ 4” BPV profile b. ASR records from 2016 indicate 151K up weight, 77K down weight c. Casing Jacks will likely be needed to get tubing moving d. 80% of 4½”, 12.6 L-80 yield is 230K-lbs e. 80% of yield on the 4-½” TDS (btm) on the tbg hgr is also 230K-lbs 20. Confirm hgr free, lay down tbg hgr. 21. LD tubing. Tubing tally indicates 20 full clamps on control lines and one half-clamp. 22. Set test plug in the tubing hanger. 23. Test BOPE to 250 psi Low / 3500 psi High, annular to 250 psi Low / 2500 psi High (hold each test of ram/valve for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform BOPE Test as per ASR 1 BOP Test Procedure b. Notify AOGCC 24-hrs in advance of BOPE test c. Confirm test pressure per the Sundry Conditions of Approval d. Test pipe rams on 4-½” test joint (if needed; or test at one week interval from previous BOPE test). e. Test 7” pipe rams with 7” test joint. _____________ RWO END 2-38 PTD: 190-129 f. Submit completed 10-424 Blow-Out Preventer Equipment (BOPE) Test from within 5 days of BOPE test 24. Pull test plug. Drift for 7” completion: 25. RU Slickline and drift for packer w/ 8.125” x 80” drift. Run 7” Casing: MU 9-5/8” x 4-1/2” overshot, X-nipple with PX plug installed per attached casing tally. NOTE: Per the attached proposed casing tally ensure that the PX plug assembly has been pressure-tested in the shop to 4,500 psi from below and 3,300 psi from above. 26. Install 400 K-lb casing jacks as a contingency for the 7” casing leaking and needing to jack casing to bottom. NOTE: Plan is to float the 7” casing in due to lift limitations of the ASR rig (147K-Lb Derrick). Two PX plugs will be used as the closed bottom of the assembly. The buoyed weight of the pipe in 8.6 ppg fluid will be ~112 K-lbs when on bottom. NOTE: In the event that the casing or plug starts leaking and filling with sea water the contingency is to watch the hook weight continuously while MU and RIH. The casing jacks will already be rigged up and immediately install the floor slips if weight starts increasing so that the jacks will bear all of the weight and the 7” can be either POOH to fix the leak or RIH. Watch block weights continuously. Halt lift and ensure slips are engaged when weight exceeds 5k more than expected at that depth. Install floor slips if weights are rising out of line with expected Halt lift and ensure slips are engaged when hole fill volume exceeds 10% more than expected on a rolling 10barrel basis (ex. 11barrels added when 10 barrels should have been added). Jack OOH to find leak and fix or LDL in-situ Company Rep to discuss with crews the hazard and mitigation plan at each pre-tour meeting and ensure crew is competent in performing the mitigation steps. Company Rep to oversee drills at the start of each tour for setting slips in the event of weight increase due to leak in casing/plug or loss of fluid in the IA to formation Company Rep to document drills. The operator is required to set tubular into slips at first sign of weight deviation from the expected norm. The expected norm being a consistent trend of increased hook load based on metal weight of tubular that is run into the well. Continuous monitoring of wellbore fluids. Operator will taking returns to the trip tank as tubulars are being RIH. Trip sheets will be maintained to monitor the fluid gain trend and ensure it is equivalent to the total closed-end volume of pipe RIH. *See conditions of approval, two plugs in casing required for redundancy. - J.Lau _____________ RWO END 2-38 PTD: 190-129 Depth Dry Weight (Lbs) Buoyed Weight (Lbs) Floated Weight (Lbs) 2,000’ 52K 45K 18K 4,000’ 104K 90K 36K 6,000’ 156K 135K 53K 8,000’ 208K 181K 71K 10,000’ 260K 226K 88K 12,000’ 312K 271K 106K 12,763’ 332K 220K 112K Buoyancy Calculations: Bouyed Weight Floating = Total weight of 7” casing - Weight of displaced fluid Total weight of 7” casing: 12,763’ x 26lb/ft = 331,838 lbs Total weight of displaced fluid: 12,763’ x [(7x7)/1029 x 42 gals/bbl x 8.6 ppg] = 219,523 lbs Buoyed Weight Floating = 331,838 lbs – 219,523 lbs = 112,314 lbs Buoyed Weight filled with sea water = BF x Total weight of 7” casing = (65.5 – 8.6)/65.5 x 331,838 lbs = 288,268 lbs Collapse Calculations: 7” 26# L-80 Collapse Resistance = 5,410 psi Collapse pressure at depth = 8.6 ppg x TVD x 0.052 =8.6 ppg x 9,550’ x 0.052 = 4,271 psi 80% of collapse resistance = 4,328 psi which is > collapse pressure at depth 27. MU 4-1/2” x 7” L-80 26# TSH W563 casing. 4-1/2” 12.6# 13Cr80 VT Torques: Minimum 4000 ft-lbs Optimum 4440 ft-lbs Max 4880 ft-lbs 7” 26# TSH W563 L-80 Torques: Minimum 7800 ft-lbs Optimum 9400 ft-lbs Max 13,700 ft-lbs _____________ RWO END 2-38 PTD: 190-129 28. Shear the dual sets of pins in the overshot and space out with the overshot 8’ from no- go. The overshot has ~12’ of total swallow length over the tubing stub. NOTE: Modelling shows the casing will lengthen by 5’ after filling with seawater after landing the casing hanger so with the overshot spaced out 8’ from no-go the overshot should still be neutral and not stacking weight on the tubing stub. 29. Land casing hanger and RILDs. 30. Install secondary casing packoff through the BOPs. 31. Test casing packoffs to 500/3500 psi. 32. Fill the 7” casing with seawater. 33. Set 9-5/8” x 4-1/2” TNT Packer per HES representative. 34. MITT 7” casing to 3500 psi. 35. Set 7” J TWC in hanger. 36. ND BOPE. 37. NU Tubing spool. 38. NU BOPE. 39. Test BOPE to 250 psi Low / 3500 psi High, annular to 250 psi Low / 2500 psi High (hold each test of ram/valve for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform BOPE Test as per ASR 1 BOP Test Procedure b. Notify AOGCC 24-hrs in advance of BOPE test c. Confirm test pressure per the Sundry Conditions of Approval d. Test pipe rams on 4-½” test joint (if needed; or test at one week interval from previous BOPE test). e. Submit completed 10-424 Blow-Out Preventer Equipment (BOPE) Test from within 5 days of BOPE test _____________ RWO END 2-38 PTD: 190-129 Run Tubing 40. Pull 7” J TWC. 41. Run 4-1/2” 13Cr tubing per proposed tally (attached). 4-1/2” 12.6# 13Cr80 JFE Bear Clear Run Torques: Minimum 6080 ft-lbs Optimum 6750 ft-lbs Max 7430 ft-lbs 42. Tag 7” x 4-1/2” XO with WLEG and space out with WLEG at least 80’ above the 7” x 4- 1/2” XO. 43. Land tubing hanger and RILDS. 44. Test tubing packoffs to 500/5000 psi. 45. Drop ball and rod. 46. Set 7” x 4-1/2” TNT packer per HES representative. 47. MITT to 3500 psi. 48. CMIT-TxIA to 3500 psi. 49. Bleed down tubing pressure to shear out valve @ ~4200’ MD. 50. Freeze-protect IA with 5 bbls diesel. Note on MPI Freeze-protect is only needed for upper 30’ of the well; deeper than 30’ MD the temperature is ~40 degrees F. 51. Install BPV. 52. ND BOPE, Install CTS plug. 53. NU 4-1/16” 5M Tree. 54. Test tree to 500/5000 psi. 55. Pull CTS plug and BPV. 56. U-tube diesel Freeze-protect between tubing and IA. 57. RDMO ASR. _____________ RWO END 2-38 PTD: 190-129 Post-Rig: Slickline 58. PT PCE to 3,500 psi high, 250 psi low. 59. Pull Ball and Rod. 60. Pull RHC. 61. Pull PX plug from ~12,826’ MD. 62. Pull PX plug from ~12,850’ MD. 63. Pull PX plug from 12,986’ MD. Eline 64. PT PCE to 3,500 psi high, 250 psi low. 65. Set CBP @ ~12,855’ MD (middle of 10’ pup just below X-nipple and above 9-5/8” x 4- 1/2” Overshot). Coiled Tubing 66. PT PCE to 3,500 psi high, 250 psi low. 67. MU NCS Sleeve shifting tool. 68. Locate NCS sleeve and shift open. 69. Pump 350 bbls of 14-15.8 ppg Class G through NCS sleeve and up 9-5/8” x 7” annulus to surface (20 bbls excess). 70. Ensure good cement to surface and log in AWGRs. 71. Close NCS sleeve and POOH. 72. Wait on cement to reach 500 psi compressive strength. MU Motor and 3.80” Mill and mill out CBP @ ~12,855’ MD. Chase CBP debris out the tubing tail @ 13,130’ MD. 73. MU cementing nozzle and RIH. 74. Tag PBTD and correct depth to last tag of 13,624’ MD. 75. Lay in ~5 bbls of 15.8 ppg cement from PBTD to ~13,500’ MD to abandon the Alapah perforations. 76. Wait on 500 psi compressive strength and tag TOC w/ 10K down weight - AOGCC Witnessed. NOTE: The Ivishak perforations are cement squeezed per Sundry #325-197, however the squeeze did not pass a pressure test after reaching 500 psi compressive strength. The LLR was very low, but there is no chance it will pass an MIT to 2500 psi, thus the above proposal to verify the Alapah cement plug with a weight test instead of a pressure test. Volumes: 9-5/8” x 7” 12,800’ x 0.0256 bpf = 328 bbls 7” Liner 13,624’ – 13,500’ MD = 124’ x 0.0371 bpf = 4.6 bbls _____________ RWO END 2-38 PTD: 190-129 Attachments: 1. Current Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Casing Jack Schematic 5. Risk Assessment 6. Current Tubing Tally 7. Casing & Tubing Hanger Schematic 8. BOPE Schematic 9. 7” x 4-1/2” Proposed Tally 10. 4-1/2” Cr Proposed Tally _____________ RWO END 2-38 PTD: 190-129 Current Schematic CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 130’N/A 13-3/8”Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’0.150 9-5/8"Production 47 / NT80S / NSCC 8.681 Surface 11,083’0.0732 9-5/8"Production 47/ NT95HS/ NSCC 8.681 11,083’13,349’0.0732 7"Liner 29/ NT95HS/ TKC 6.184 13,087’13,831’0.0372 TUBING DETAIL 4-1/2"Tubing 12.6/ L-80/ TCII 3.958 Surface 13,002’0.0152 4-1/2”Tubing 12.6/ L-80/ TDS 3.958 13,002’13,554’0.0152 JEWELRY DETAIL No Depth Item 1 1,497’XXO SSSV Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: Camco 4-1/2” MMG w/ 1-1/2” valve, RK Latch 2 5,221’STA 6: Vlv= Dome, Dev.= 50, Port= 16/64, TVD= 4,070’, 6/16/2016 3 7,650’STA 5: Vlv= Dome, Dev.= 42, Port= 16/64, TVD= 5,884’, 6/16/2016 4 8,685’STA 4:Vlv= Circ, Dev.= 45, Port= 32/64, TVD= 6,624’, 11/14/2025 5 10,413’STA 3:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 7,887’, 6/8/2016 6 11,642’STA 2:Vlv= Dmy, Dev.=46, Port= n/a, TVD= 8,762’, 6/8/2016 7 12,792’STA 1:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 9,569’, 6/8/2016 8 12,859’ X-Nipple, ID=3.813” 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813”, 4-1/2” PX Plug in X-Nipple set on 11/9/25 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958” - Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD)Btm (TVD) FT Date Status Size Ivishak 13,324’ 13,354’ 9,987’ 10,012’30 7/23/25 Squeezed 2-7/8” 13,382’13,387 10,035’ 10,040’5 7/23/25 Squeezed 2-7/8” 13,393’ 13,454’ 10,045’ 10,096’61 7/23/25 Squeezed 3-3/8” 13,394’ 13,486’ 10,046’ 10,123’92 7/23/25 Squeezed 3-3/8” Alapah 13,605’ 13,628’ 10,226’ 10,246’23 6/11/91 Open 3-3/8” R f P f L DLL/ GR 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8”3,394 cu/ft Permafrost in 17.5” Hole 9-5/8"3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7”400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 RWO – 06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV _____________ RWO END 2-38 PTD: 190-129 Proposed Schematic CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 130’N/A 13-3/8”Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’0.150 9-5/8"Production 47 / NT80S / NSCC 8.681 Surface 11,083’0.0732 9-5/8"Production 47/ NT95HS/ NSCC 8.681 11,083’13,349’0.0732 7”Production 26/L-80/TSH w563 6.276 Surface 12,850’0.0383 7"Liner 29/ NT95HS/ TKC 6.184 13,087’13,831’0.0372 TUBING DETAIL 4-1/2"Tubing 12.6/ 13CR/VT 3.958 Surface 12,850’0.0152 JEWELRY DETAIL No Depth Item 1 1,500’SSSV Landing Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: 4-1/2” 13Cr KBG w/ 1” valves 2 5,408’ - 12,499’6 GLMS 3 12,583’7” x 4-1/2” Packer 4 12,609’X-Nipple 3.813” ID (One above packer, one below) 5 12,661’4-1/2” WLEG 6 12,741’7” x 4-1/2” XO and 4-1/2” NCS Sleeve 7 12,800’9-5/8” x 4-1/2” Packer w/ 3.813” Two X-nipples below 8 12,870’9-5/8” 4-1/2” Overshot 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813”, 4-1/2” PX Plug in X-Nipple set on 11/9/25 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958” - Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ivishak 13,324’ 13,354’ 9,987’ 10,012’30 7/23/25 Squeezed 2-7/8” 13,382’13,387 10,035’ 10,040’5 7/23/25 Squeezed 2-7/8” 13,393’ 13,454’ 10,045’ 10,096’61 7/23/25 Squeezed 3-3/8” 13,394’ 13,486’ 10,046’ 10,123’92 7/23/25 Squeezed 3-3/8” Alapah 13,605’ 13,628’ 10,226’ 10,246’23 6/11/91 Closed 3-3/8” Reference Perf Log: DLL/ GR on 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8”3,394 cu/ft Permafrost in 17.5” Hole 9-5/8"3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7”400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 RWO – 06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV _____________ RWO END 2-38 PTD: 190-129 BOP w/ Casing Jack Schema c Rig Floor Level ~6” below top of Jacks _____________ RWO END 2-38 PTD: 190-129 _____________ RWO END 2-38 PTD: 190-129 Risk Mitigations PX plugs or casing leaks; weight of pipe goes up Run two PX plugs in bottom of 7” string Pressure Test PX plugs in shop Largest credible TBG plug leak is expected to result in a noticeable IA level drop and string weight increase in 10minutes Casing Jacks Installed Watch block weights continuously. Halt lift and ensure slips are engaged when weight exceeds 15k more than expected at that depth. Install floor slips if weights are rising out of line with expected Halt lift and ensure slips are engaged when hole fill volume exceeds 10% more than expected on a rolling 10barrel basis (ex. 11barrels added when 10 barrels should have been added). Jack OOH to find leak and fix or LDL in-situ Company Rep to discuss with crews the hazard and mitigation plan at each pre-tour meeting and ensure crew is competent in performing the mitigation steps. Company Rep to oversee drills at the start of each tour for setting slips in the event of weight increase due to leak in casing/plug or loss of fluid in the IA to formation Company Rep to document drills. The operator is required to set tubular into slips at first sign of weight deviation from the expected norm. The expected norm being a consistent trend of increased hook load based on metal weight of tubular that is run into the well. Continuous monitoring of wellbore fluids. Operator will taking returns to the trip tank as tubulars are being RIH. Trip sheets will be maintained to monitor the fluid gain trend and ensure it is equivalent to the total closed-end volume of pipe RIH. Casing collapse due to hydrostatic pressure Casing collapse is <80% of applied pressure at depth Casing tensile force exceeded by Jacks 604K body strength of casing; 400K rating of jacks _____________ RWO END 2-38 PTD: 190-129 Cannot pump down the casing with plug in bottom PX plug set at bottom of existing completion and tested to 2500 psi (mechanical barrier to reservoir) Seawater already on the 9-5/8” x 7” annulus is KWF Can pump down 9-5/8” x 7” annulus if plug in well fails either to keep FL at surface or bullhead with annular BOP closed _____________ RWO END 2-38 PTD: 190-129 Current Tubing Tally _____________ RWO END 2-38 PTD: 190-129 Tubing and Casing Spools _____________ RWO END 2-38 PTD: 190-129 Well: 2-38 Proposed 7" x 4-1/2" Liner Tally Approx Depth Description 7" Casing Hanger 0' XO Pup to TSH W563 7" 26# L-80 TSH W563 XO Pup joint 7" 26# L-80 TSH W563 Box x 4-1/2" L-80 VT pin ~10' *Ensure inner bevel of ~45deg for wireline tools 12,741' MD Buffer Pup Joint 9Cr- 4-1/2” VT b x p, ~2’ 12,751' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 4-1/2" 13 Cr NCS HP2 Multicycle sleeve VT box x box ~7' 12,773' MD Pup Joint - 4-1/2” 13Cr VT p x p, ~10’ Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ 9-5/8”x 4-1/2” 13Cr HES TNT Packer Vam Top bxp 12,800' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ * Bakerlocked Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ * Bakerlocked X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p (with PX plug installed) * Bakerlocked * Pressure test PX plug to 4500 psi from below and 3300 psi from above in the shop 12,826' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ * Bakerlocked Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ * Bakerlocked X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p (with PX plug installed) * Bakerlocked * Pressure test PX plug to 4500 psi from below and 3300 psi from above in the shop 12,848' MD Pup Joint - 4-1/2” 13Cr VT b x p, ~10’ * Bakerlocked Pup Joint - 4-1/2” 13Cr VT b x p, ~15’ * Bakerlocked 9-5/8" x 4-1/2" 13Cr Northern Solutions Overshot * Bakerlocked 12,870' MD _____________ RWO END 2-38 PTD: 190-129 Well: 2-38 Proposed 4-1/2" Cr Tbg Tally Approx Depth Description 4-1/2” Tbg Hanger 0' 13Cr XO Pup Joint TDS to 4-1/2" JFE Bear Full Joint - 4-1/2" 13Cr JFE Bear b x p, 40’ 13 Cr Spaceout Pups (As Needed): 2 ft, 4ft, 6ft, 8ft etc. 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x p, ~10’ FXE SSSV Landing Nipple 1500' MD Pup Joint - 4-1/2” 13Cr JFE Bear b x p, ~10’ Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" SOV , 13Cr VT 5408' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" DGLV, 13Cr VT 7807' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" DGLV , 13Cr VT 9212' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" DGLV , 13Cr VT 10,295' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" DGLV , 13Cr VT 11,408' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 4-1/2" KBG-2 GLM w 1" DGLV , 13Cr VT 12,499' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ 4-1/2” 13Cr JFE Bear Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p 12,521' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ Full Joint - 4-1/2" 13Cr JFE Bear b x p, 40’ Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ 7”x4-1/2” 13Cr HES TNT Packer Vam Top bxp 12,583' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ Pup Joint - 4-1/2” 13Cr JFE Bear b x VT p, ~10’ X Nip (ID=3.813”), 4-1/2” 13Cr VT b x p (with RHC Installed) 12,609' MD Pup Joint - 4-1/2” 13Cr VT b x JFE Bear p, ~10’ Full Joint - 4-1/2" 13Cr JFE Bear b x p, 40’ 4-1/2" 13 Cr WLEG 12,661' MD Masts and Wire Rope on Drilling and Well Servicing Structures API RP 4G and API 9B - Time intervals for mast inspections and date of most recent Category III and Category IV mast inspections - Do Cat III and IV inspections include load lines? - - Design and operating limit for mast, load lines, guy lines, drawworks, and travelling blocks Include what factors are included in establishing the operating limit - -- operating lines, raising lines, guy lines, load lines - – scope of weight indicator inspection and testing after installation - Alarms and data recording for monitoring loads - Factors used in determining derated load limits and eventual replacement of mast and wire ropes From:Lau, Jack J (OGC) To:Aras Worthington Subject:RE: [EXTERNAL] MPI 2-38 (PTD 190-129) RWO Sundry Date:Saturday, January 3, 2026 11:19:29 AM Aras, You have verbal approval to proceed with the tubing cut given you agree with the below Conditions of Approval. Thanks Jack From: Lau, Jack J (OGC) Sent: Friday, January 2, 2026 12:02 PM To: Aras Worthington <aras.worthington@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Taylor Wellman <twellman@hilcorp.com>; Aaron Haberthur - (C) <Aaron.Haberthur@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] MPI 2-38 (PTD 190-129) RWO Sundry Good morning Aras, Thanks for sending the revision, I will let you know if I have any questions. We are willing to approve this sundry with the following conditions given Hilcorp manages ASR to the level detailed below the conditions. Any issues with these conditions? Jack Conditions of Approval: Isolation Verification - Run a 9-5/8” CBL before running and cementing new 7” casing to be able to rule out a deeper source of gas coming from this well. Once 7” casing is run, it will be too late to run the CBL in the future. Return Monitoring and Fluid Verification – While running and landing 7”, Operator shall monitor well returns and track volumes using the trip tank while running casing. A documented plan shall be implemented to verify casing fill and fluid volumes during static conditions when casing movement is paused. Trip Sheet Verification - While running and landing 7”, return volumes, casing fill, and movement shall be verified against a maintained trip sheet throughout the casing run. Hook Load Tracking - Operator shall prepare charts of anticipated casing weights and hook loads versus depth while running and landing 7”, including buoyancy assumptions. Actual hook loads shall be checked against predicted values at depth intervals not exceeding 500 feet, with any discrepancies investigated and documented. Redundant Hard Bottom - A second plug shall be installed in the casing to provide a hard bottom and redundancy during floating operations. Standing Orders based on Risk Assessment, Risk Indications and Response Protocol - Operator shall develop and implement a written protocol identifying specific risk indications for floating casing that may signal fluid loss, unanticipated change in hook load, well control, or casing integrity issues. The protocol shall define the parameters and thresholds the crew will monitor (e.g., unexpected hook load changes, loss of returns, casing fill discrepancies, pressure anomalies) and the required response actions for each indication. AOGCC-Witnessed Drills – Each crew shall conduct casing-running and well control drills associated with floating casing operations and crew response, with initial drills witnessed by AOGCC. Drill Detail Submittal - Hilcorp shall provide drill scope to AOGCC prior to commencing operations. Flow Contingency Inclusion - Operator shall update the risk assessment to include response procedures for any indication that the well begins to flow during casing operations. Rig Management: ASR Rig: AOGCC expects that the following are in place. We are not requiring evidence for these items. Let us know if this needs more discussion. Formal documented maintenance management program for ASR1 that ensures maintenance tasks are completed timely and in a consistent manner. A safety management system in place that includes the proposed work. A formal, documented risk assessment that ID’s potential risks and how they will be mitigated (covering rig ops, maintenance, and significant work activities by rig personnel as part of a rig workover) Record keeping that includes weight indicator certificate of factory/3rd party calibration, records that show the installation was done per manufacturer 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. recommendations and has been field calibrated. The rig is compliant with API RP 4G and 9B. See attachment. From: Aras Worthington <aras.worthington@hilcorp.com> Sent: Friday, January 2, 2026 10:10 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Taylor Wellman <twellman@hilcorp.com>; Aaron Haberthur - (C) <Aaron.Haberthur@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] MPI 2-38 (PTD 190-129) RWO Sundry Jack, Thanks again for your time meeting on Dec. 31, 2025 with regard to this Sundry application. Please see attached revision #3 that we believe addresses the comments and concerns that were raised in the meeting. Revisions include: 1. The installation of two PX plugs at the bottom of the 7” casing for 100% plug redundancy 2. Revised Risk Assessment and findings including pre-tour drills while running the 7” casing 3. Schematics of casing jacks and their stack up on the BOPE with rig floor elevation shown Also, while you consider this revision could we please get a verbal approval to perform the tubing cut pre-rig? Our time is short before ASR arrives (~six days from now) and we believe the only question is whether or not AOGCC will approve floating the casing in or not. Thanks again and Best Regards, Aras Worthington Sr. Operations Engineer PE, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Aras Worthington Sent: Tuesday, December 30, 2025 4:00 PM To: 'Lau, Jack J (OGC)' <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; 'McLellan, Bryan J (OGC)' <bryan.mclellan@alaska.gov>; Taylor Wellman <twellman@hilcorp.com>; Aaron Haberthur - (C) <Aaron.Haberthur@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] MPI 2-38 (PTD 190-129) RWO Sundry Jack, Please see attached revised program that answers most of the questions below. The rest of the responses are below. We are putting together some condensed information to share in tomorrow’s meeting that will also include the previous ASR tubular floating jobs that have been successfully executed: NS-15 (2017) NS-17 (2019) PBU 09-27 (2024) Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, PE, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, December 29, 2025 4:02 PM To: Aras Worthington <aras.worthington@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL] MPI 2-38 (PTD 190-129) RWO Sundry Aras – We have reviewed your sundry application and have concerns about floating the 7” casing. Please send over your buoyancy calcs for floating the 7” casing. Reference revised program for all of the buoyancy calculations Confirm ASR’s mast is rated to 150K. ASR Derrick is rated to 147K-lbs Please shoot me a copy of the deviation survey. Attached What mitigations are included to ensure buoyancy is not lost during the operation (identification and response)? Reference revised program for contingency plans How long would it take to install casing slips if the buoy effect is lost? Reference revised program; the casing jacks will already be rigged up for this contingency and it will take only seconds to install the floor slips. Will there be casing jacks available on site as a mitigation? Yes; reference above and revised program Has a risk assessment been completed for floating the casing including all the plausible failure scenarios? Yes Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. T41217END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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:Lau, Jack J (OGC) To:Rixse, Melvin G (OGC); McLellan, Bryan J (OGC) Cc:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Endicott Update 11/17/25 Date:Tuesday, November 18, 2025 9:21:49 AM Attachments:image001.png Triple Temperature Overlay.pdf END_2-38_WFL-TMD3D_14-15NOV25_Report.pdf From: Aras Worthington <aras.worthington@hilcorp.com> Sent: Monday, November 17, 2025 2:44 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] Endicott Update 11/17/25 Hi Jack, Attached is the LDL (two parts -one is the temp log overlays the other is the WFL stop counts). Responses to the other queries are below. Thanks and Best Regards, Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, November 17, 2025 10:48 AM To: Aras Worthington <aras.worthington@hilcorp.com> Subject: [EXTERNAL] Endicott Update 11/17/25 Aras – Please send an update on the ongoing Endicott water and gas release. See previous email forwarded Please include the info below along with anything else you deem pertinent. Status of water releases See previous email forwarded Status of gas releases See previous email forwarded Progress of surface casing integrity verification (MITOA with N2 testing) Surface Casing Pressure tests (OAITs – Outer Annulus Integrity Tests) performed on producers​ Ten passed (deep OAs & prior surface casing repair wells) ​ One fail (2-38)​ Progress of production casing integrity verification (MITIA or CMIT) Production Casing Pressure tests ​ CMITs – Combination Mechanical Integrity Tests performed on gas-lifted producers​ Four passed (1-03, 2-08, 2-28, 2-44) ​ One fail (2-38)​ MITIA - Mechanical Integrity Test Inner Annulus performed on natural flow producers​ Two passed (1-01, 1-29)​ Production Casing Pressure tests (MITIAs – Mechanical Integrity Test Inner Annulus) performed on injectors​ Four passed (1-05, 1-09, 2-02, 2-12) ​ No failures​ A copy of the LDL ran in 2-38 Attached is the LDL (two parts -one is the temp log overlays the other is the WFL stop counts) A summary of the OA cement down squeeze job in 2-38 MIRU LRS Unit #76. PT LRS to 3500 psi. MIRU HES Van. Conduct PJSM and review program. LRS pumped seawater down IA to push diesel out of tubing to OT. Swap LRS to establish consistent circulation down the tubing, taking returns from the IA. PT HES to 4000 psi. Pump 2 bbl FW spacer, 158 bbls of 15.8 ppg Class G Cement. Hesitate for 5 minutes. Squeeze to 50 psi. Hesitate for 5 minutes. Squeeze to 100 psi. Shut down. Close OA casing valve. RDMO HES Cementers. ***AWGRS continue by LRS Unit 70*** **Assist Cement** Pump 99 bbls Sea water down IA take returns out TBG to flush diesel. Pump 992 bbls 120* Sea Water down TBG take returns out IA continuously pre and post cement job. Pump 8 bbls Diesel down TBG for FP. Pump 5 bbls Diesel to FP surface lines. ***Job Continued to 11-17-2025*** U-Tube TBG and IA for 30 min. Pad-Op notified upon LRS departure. What was the native pressure in the cretaceous zone versus today? What was the FIT for the disposal well in that zone? The earliest SBHPS I have found in END 2-02 is from 12/24/2005: 3276 psi @ 6963’ ssTVD; 9.1 ppge From fluid levels shot last week in same well: T/I/O = 990/0/0/0. Temp = SI. T FL (Ops). SI @ CV. T FL @ 2050 (32 bbls); 8.8 ppge Below is a record of the LOT after drilling out the SC shoe (2500’ MD) on END 2-02 (from AOGCC files) Thanks for the communication on this issue. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell 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 youhave 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 byreturn email or telephone if the sender's phone number is listed above, then promptly and permanently delete this 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 attachmentswill 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. HALLIBURTON Triple Temperature Overlay Static Down, Pumping Down, Pumping Up Database File hilcorp_end2-38_wfl_111525.db Dataset Pathname FinalTemp1 Presentation Format Z_TEMP-1 Dataset Creation Sat Nov 15 15-03-54 2025 Charted by Depth in Feet scaled 1-1200 0 GR10 (GAPI) 150 0 Static Temp Down (degF) 200 CCL10 0 Pumping Temp Down (degF) 200 ------------------------------------------------------------------------------- 0 Pumping Temp Up (degF) 200 -50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 12200 12250 12300 12350 12400 12450 12500 12550 12600 12650 12700 12750 12800 12850 12900 12950 0 GR10 (GAPI) 150 0 Static Temp Down (degF) 200 CCL10 ---------------------------------------- 0 Pumping Temp Down (degF) 200 0 Pumping Temp Up (degF) 200 HALLIBURTON Triple Temperature Overlay Static Down, Pumping Down, Pumping Up Oxygen Activation Evaluation Water Flow Detection Company: Hilcorp Alaska, LLC. Well: END 2-38 Field: Endicott Borough: North Slope State: Alaska API#: 50-029-22090-00 Geoscience & Production Center of Excellence, North America Analyst: Fanny Haroun Email: fanny.haroun@halliburton.com Phone: 907-342-5550 Logging Date: 11/14/2025 Report Date: 11/15/2025 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA,CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM.ANY USER OF SUCH DATA, INTERPRETATIONS,CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT,FOR ANY LOSS,DAMAGES,OR EXPENSES RESULTING FROM THE USE THEREOF Page 2 of 43 Table of Contents 1.0 EXECUTIVE SUMMARY ................................................................................................................... 3 2.0 WELL INFORMATION ...................................................................................................................... 4 3.0 TOOL STRING DIAGRAM ................................................................................................................ 5 4.0 WATER FLOW LOG EVALUATION ................................................................................................. 6 4.1 IMPULSE TEST RESULTS (SHUT-IN) ............................................................................................ 9 4.1.1 Impulse Test @ 250 ft MD .................................................................................................. 9 4.1.2 Impulse Test @ 800 ft MD ................................................................................................ 11 4.1.3 Impulse Test @ 2000 ft MD .............................................................................................. 13 4.1.4 Impulse Test @ 4000 ft MD .............................................................................................. 15 4.1.5 Impulse Test @ 6000 ft MD .............................................................................................. 17 4.1.6 Impulse Test @ 8000 ft MD .............................................................................................. 19 4.1.7 Impulse Test @ 10000 ft MD ............................................................................................ 21 4.1.8 Impulse Test @ 12800 ft MD ............................................................................................ 23 4.1.9 Impulse Test @ 12980 ft MD ............................................................................................ 25 4.2 IMPULSE TEST RESULTS (PUMPING IN IA AT 1.3 BPM) .............................................................. 27 4.2.1 Impulse Test @ 250 ft MD ................................................................................................ 27 4.2.2 Impulse Test @ 800 ft MD ................................................................................................ 29 4.2.3 Impulse Test @ 1000 ft MD .............................................................................................. 31 4.2.4 Impulse Test @ 1400 ft MD .............................................................................................. 33 4.2.5 Impulse Test @ 1850 ft MD .............................................................................................. 35 4.2.6 Impulse Test @ 2500 ft MD .............................................................................................. 37 4.2.7 Impulse Test @ 2600 ft MD .............................................................................................. 39 5.0 TMD3D DYNAMIC PASS AND TEMPERATURE PROFILES ....................................................... 41 Page 3 of 43 1.0 Executive Summary Well: END 2-38 Oxygen Activation Evaluation Survey date: 14-15 NOV 2025 Logging Objective Logging was conducted during shut-in and while injecting 1872 BWPD into IA. Logging objective is to perform water flow log to determine water flow behind pipe. Conclusions The TMD3D Tool was run in oxygen activation impulse mode in the 4.5” tubing taking impulse tests at several station depths. The tool was run in normal configuration (generator positioned below the detectors) for water up flow detection. Impulse tests during shut-in condition were done at 9 different depths: 250, 800, 2000, 4000, 6000, 8000, 10000, 12800, and 12980 ft MD. Impulse tests during pumping condition were done at 7 different depths: 250, 800, 1000, 1400, 1850, 2500, and 2600 ft MD. Analysis of temperature and TMD3D data indicates two potential sources of water inflow: 1. Possible leak/s in the 9.625” casing at approximately 1028 ft MD, supported by the temperature anomaly observed at this depth and the OAIF curve indicating fluid migration into the formation. 2. Fluid migration from the formation within the 6000-8000 ft interval, consistent with the impulse test results showing upward water movement from 6000 ft to 4000 ft and cessation at 2600 ft, suggesting migration into the formation. Page 4 of 43 2.0 Well Information Page 5 of 43 3.0 Tool String Diagram Page 6 of 43 4.0 Water Flow Log Evaluation The TMD3D was run using stationary impulse tests across the zones of interest. Water flow can be detected by measuring gamma rays originating from activated oxygen within any water flowing past the neutron generator (activation) then moving past the detector section (decay). The fluid/water velocity is estimated from oxygen activation using impulse test data. The flow direction is determined by the position of the sensor relative to the neutron generator. The flow region, near or far, is derived by the ratio of Compton backscatter gamma rays compared to original gamma ray counts from activated oxygen. Lower Compton ratio indicates a flow region further from the tool i.e., behind the next string of pipe. Total oxygen activation will be a function of: x volume of water in the region of neutron cloud x flow velocity of water x tool speed x flow distance to detector x time exposure Below is a representation of the sequence of radioactive excitation and subsequent relaxation of Oxygen. Figure 1: Sequence events of oxygen activation The tool is configured in the normal mode with the neutron generator below the detector section. In the normal configuration, water will only be detected when moving up relative to the tool, in both the stationary impulse mode and continuous mode. Any oxygen activation detected by far and long detector should be from water flow upward. If there is water flow in the downward direction the GR sensor below the neutron generator will detect the activated oxygen. The near detector is not use for the calculation due to its proximity to the neutron generator. Page 7 of 43 Figure 2: Flow scenario related to TMD3D log tool Stationary Impulse Method This technique is a travel-time measurement and has the significant advantage of not requiring any calibration of the detectors. When the tool is stationary at a specified depth, the generator is turned on and allowed to stabilize. The count rate in each detector is then recorded for one or two minutes, at which time the generator is shut down. At some time later (depending on the fluid flow velocity and distance from the various detectors to the source), the count rate recorded in the detectors will drop to background level. The count rate will drop to zero in the spectral window encompassing the oxygen peak. The surface computer records the various detector count rates, steps down the generator, measures the time until the recorded count rates fall to one-half full value, and then computes a velocity from the travel time. The fluid velocity is the distance from the source to the detector divided by the time between the count-rate drop and the time when the generator was shut down. The procedure is completely automated. The spectral data can be processed to provide fluid velocity in one step because the count rate falls to zero after the activation passes. Processing the total gamma ray count rates requires two steps. The natural Page 8 of 43 background must be measured for approximately one minute after the drop to correct for the nonzero background activity. Fig. 3 is a graphical representation of the timing cycle used by the stationary impulse method. Figure 3: Stationary Impulse timing sequence The rate computation: Outer Casing ID = 8.681 inch (9.625” casing), Inner Casing OD = 1.6 inch (the tool OD) Vavg = average water velocity Qw (bpd) = Vavg (ft/min) x 1.4 x (Outer CasingID2 (inch) – Inner CasingOD2 (inch)) Page 9 of 43 4.1 Impulse Test Results (Shut-In) 4.1.1 Impulse Test @ 250 ft MD The impulse test at depth 250 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 10 of 43 Note: The calculated average velocity at depth 250 ft MD is 52.6 ft/min, indicating upward water flow. The GR sensor, located at the top of the TMD3D, typically detects water upflow when velocity exceeds 15 ft/min. Based on this, the weighted average velocity should be less than 15 ft/min. Impulse Test 3 confirms this, showing a weighted average velocity of 14.8 ft/min. Page 11 of 43 4.1.2 Impulse Test @ 800 ft MD The impulse test at depth 800 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 12 of 43 Note: The calculated average velocity at depth 800 ft MD is 18.1 ft/min, indicating upward water flow. The GR sensor, located at the top of the TMD3D, typically detects water upflow when velocity exceeds 15 ft/min. Based on this, the weighted average velocity should be less than 15 ft/min. Impulse Test 1 confirms this, showing a weighted average velocity of 11.5 ft/min. Page 13 of 43 4.1.3 Impulse Test @ 2000 ft MD The impulse test at depth 2000 ft MD shows no water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 14 of 43 Page 15 of 43 4.1.4 Impulse Test @ 4000 ft MD The impulse test at depth 4000 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 16 of 43 Note: The calculated average velocity at depth 4000 ft MD is 27.3 ft/min, indicating upward water flow. The GR sensor, located at the top of the TMD3D, typically detects water upflow when velocity exceeds 15 ft/min. Based on this, the weighted average velocity should be less than 15 ft/min. Impulse Test 2 confirms this, showing a weighted average velocity of 7.4 ft/min. Page 17 of 43 4.1.5 Impulse Test @ 6000 ft MD The impulse test at depth 6000 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 18 of 43 Note: The calculated average velocity at depth 6000 ft MD is 7.9 ft/min. Page 19 of 43 4.1.6 Impulse Test @ 8000 ft MD The impulse test at depth 8000 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 20 of 43 Page 21 of 43 4.1.7 Impulse Test @ 10000 ft MD The impulse test at depth 10000 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 22 of 43 Page 23 of 43 4.1.8 Impulse Test @ 12800 ft MD The impulse test at depth 12800 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 24 of 43 Page 25 of 43 4.1.9 Impulse Test @ 12980 ft MD The impulse test at depth 12980 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, due to no active injection in the wellbore. Page 26 of 43 Page 27 of 43 4.2 Impulse Test Results (Pumping in IA at 1.3 BPM) 4.2.1 Impulse Test @ 250 ft MD The impulse test at depth 250 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows change in readings when the generator is turned on or off, due to active injection in the wellbore. Page 28 of 43 Page 29 of 43 4.2.2 Impulse Test @ 800 ft MD The impulse test at depth 800 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows change in readings when the generator is turned on or off, due to active injection in the wellbore. Page 30 of 43 Page 31 of 43 4.2.3 Impulse Test @ 1000 ft MD The impulse test at depth 1000 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows change in readings when the generator is turned on or off, due to active injection in the wellbore. Page 32 of 43 Page 33 of 43 4.2.4 Impulse Test @ 1400 ft MD The impulse test at depth 1400 ft MD shows water flow up as indicated by the far and long detector and background detecting change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, indicating that at this depth, the injection is no longer reaching the sensor. Page 34 of 43 Page 35 of 43 4.2.5 Impulse Test @ 1850 ft MD The impulse test at depth 1850 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, indicating that at this depth, the injection is no longer reaching the sensor. Page 36 of 43 Page 37 of 43 4.2.6 Impulse Test @ 2500 ft MD The impulse test at depth 2500 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, indicating that at this depth, the injection is no longer reaching the sensor. Page 38 of 43 Page 39 of 43 4.2.7 Impulse Test @ 2600 ft MD The impulse test at depth 2600 ft MD shows no indication of water flow up as indicated by the far and long detector and background not detecting any reliable change in counts during neutron generator on and off. The GR2 sensor located below the TMD3D tool shows no change in readings when the generator is turned on or off, indicating that at this depth, the injection is no longer reaching the sensor. Page 40 of 43 Page 41 of 43 5.0 TMD3D Dynamic Pass and Temperature Profiles A continuous logging pass was conducted at 10 ft/min from 1043 - 814 ft. The minimum upward water flow detected by the TMD3D sensor is estimated at 10 ft/min. Temperature anomaly was observed at 1028 ft, which correlates with GR2 impulse test results that indicate injection in the IA dissipates below 1000 ft. The injected water exiting IA at approximately 1028 ft and migrating into the formation is confirmed by the oxygen activation curve (OAIF). Page 42 of 43 The impulse test at 6000 ft indicates upward water flow, which continues until approximately 4000 ft. At 2600 ft, the water flow stops. This suggests that water from 6000 ft is likely migrating into the formation between 2600 ft and 4000 ft. Page 43 of 43 End of Report 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Remove Plug Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement downsqueeze OA 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,831' 13,525' Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,090psi Production 7,830psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Contact Phone: 907-564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13,002' TIW Pkr, Liner Top Pkr & Otis WD Pkr and HXO SSSV 13,046(MD/ 9,763(TVD), 13,087(MD)/ 9,795(TVD) & 13,548(MD)/ 10,176(TVD) and 1,553(MD)/ 1,539(TVD) 13,831' Perforation Depth MD (ft): 10,426' 9,690psi 130' 30" 13-3/8" 9-5/8" 2,541' 4-1/2" 8,372' 13,349' See Schematic 744' See Schematic 7" 12.6#/ L-80/ TCII MD N/A 13,558' 9-5/8"2,266' 11,083' 8,150psi 5,020psi 6,870psi 2,391' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 10,008' 2,541' 11,083' Length 190-129 AOGCC USE ONLY 12.6#/ L-80/ TDS 13,565'4-1/2" 11/14/2025 Subsequent Form Required: Suspension Expiration Date: Hilcorp Alaska LLC TVD Burst 10,426' 13,525' 10,157' 3,222 Size Proposed Pools: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22090-00-00 130' 130' IVISHAK OIL Same Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY DUCK IS UNIT MPI 2-38 ENDICOTT No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2025.11.13 15:00:13 - 09'00' Aras Worthington (4643) 325-697 By Grace Christianson at 3:50 pm, Nov 13, 2025 10-404 TS 11/13/25 J.Lau 11/13/25 11/14/25 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Remove Plug Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement Squeeze 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,831'13,525' Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,090psi Production 7,830psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Contact Phone: 907-564-4763 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY DUCK IS UNIT MPI 2-38 ENDICOTT Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22090-00-00 Hilcorp Alaska LLC C.O. 462 TVD Burst 10,426' 13,525' 10,157' 3,222 AOGCC USE ONLY 12.6#/ L-80/ TDS 13,565'4-1/2" 4/21/2025 Subsequent Form Required: Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 10,008' 2,541' 11,083' Length 190-129 Size Proposed Pools: 130' 130' IVISHAK OIL N/A MD N/A 13,558' 9-5/8"2,266' 11,083' 8,150psi 5,020psi 6,870psi 2,391' 8,372' 13,349' See Schematic 744' See Schematic 7" 130' 30" 13-3/8" 9-5/8" 2,541' 4-1/2" 12.6#/ L-80/ TCII 13,002' TIW Pkr, Liner Top Pkr & Otis WD Pkr and HXO SSSV 13,046(MD/ 9,763(TVD), 13,087(MD)/ 9,795(TVD) & 13,548(MD)/ 10,176(TVD) and 1,553(MD)/ 1,539(TVD) 13,831' Perforation Depth MD (ft): 10,426' 9,690psi No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:23 pm, Apr 02, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.04.02 10:52:13 -08'00' Justus Hinks (3691) 325-197 JJL 4/10/25 CDW 04/02/2025 DSR-4/2/25A.Dewhurst 10APR25 Lisburne Undefiled Oil Pool 10-404 *&: 4/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 11:55:30 -08'00' RBDMS JSB 041025 _____________ Cmt Sqz, Open Lisburne, Acidize END 2-38 PTD: 190-129 Current Bottom Hole Pressure:4,222 psi @ 10,000’ ssTVD (SBHPs 5/25/24; 8.2 ppge) Max Proposed Surface Pressure: 3,222 psi Gas Gradient (0.1 psi/ft) Max Deviation: 56° at 4,981’ MD Minimum ID:3.725” XN @ 13,563’ MD Last Tag:13,550’ MD w/ 1.8” Cent/1.75” LIB (5/25/24) SBHT:208 Deg F @ 13,405’ MD (SBHPS 5//25/24) History Drilled and completed in 1990. Rig workover in 2016. Objective Execute a cement squeeze of the Ivishak perfs. Open the Lisburne perfs and and acidize. Slickline:(Non-Sundried work) 1. PT PCE to 250 psi low, 3500 psi high. 2. Coordinate with Operations to SI well three days prior for SBHPS. 3. Pull SSSV. 4. Drift through the tubing stub area (13,002’ MD) with a dummy 3.813” X-lock to ensure the X-plug can be pulled through this area. a. There have been numerous issues making it past the tubing stub but was drifted with a 3.80” centralizer on 5/18/2022. 5. MU TEL and bailer, locate Tubing Tail, tag TD and get corrected PBTD. 6. Set DSSSV. Well Name:END 2-38 API Number:50-029-22090-00-00 Current Status:Ivishak Producer PTD #190-129 Estimated Start Date:4/21/2025 Rig:SL / Coil Reg.Approval Req’std?Yes –403 Estimated Duration:3days First Call Engineer:Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Reservoir Engineer:Gavin Dittman (907) 564-5246 (O) (907) 903-1903 (M) Geologist:Brock Rust (907) 777-8394 (O) (615) 306-9509 (M) _____________ Cmt Sqz, Open Lisburne, Acidize END 2-38 PTD: 190-129 Coiled Tubing:(Sundry Required) 7. PT PCE to 250 psi low, 3500 psi high. 8. Drift to TD with ~2.0” cementing nozzle (WSS discretion). Tag TD, pick up and flag pipe for depth control. 9. Liquid pack well with diesel by pumping down the coil tubing and up the backside or bullhead (WSS discretion). 10. Perform pre-cement injectivity test. 11. Lay 17 bbls 15.8 ppg Class G cement @ 1:1 from flag depth. a. Minimum thickening time = 10 hours. i. 1 hour mixing at surface. ii. 1.5 hours pump down coil assuming 1 bbl / minute iii. 0.5 hour cement placement assuming 0.5 bbl / minute iv. 2 hour squeeze time v. 2 hour contingency b. Expected bottom hole temperature 208degF c. 13,550’ – 113,130’ = 420’ x 0.0372 bbls/ft = 15.6 bbls from PBTD to the tubing tail. 12. Pump pipe displacement while pulling coil tubing up above cement to keep hydrostatics stable and hold cement in place. 13. Hesitation squeeze for ~2 hours targeting 2500 psi squeeze in 250 psi increments. Hold each pressure for 5-15 minutes. d. Hold max squeeze pressure for target of 45-60 minutes. 14. If hesitation squeeze is successful cleanout cement with frequent gel sweeps down to PBTD. e. First contamination pass should be no later than 2/3 of thickening time. 15.Contingent If well is unable to build squeeze pressure, over displace cement by 2-3 bbls and prepare to repeat squeeze attempt once cement has reached compressive strength. Or consider leaving cement to set up and under-reaming cement with Hailey Under reamer & mill. 16. POOH and PU a down-jet nozzle to clean out fill to the top of the XX plug @ 13,558’ MD. 17. After cement has reached 1000 psi compressive strength perform post cement PT to 500 psi for five minutes. Slickline 18. PT PCE to 250 psi low, 3500 psi high. 19. Pull the DSSSV. 20. Pull the 2-7/8” XX plug @ 13,358’ MD (set 2/9/1993). 21. Pull the 2-7/8” Nipple Reducer @ 13,358’ MD (set 1/29/93). 22. Tag PBTD and obtain corrected tag to MD. Operations 23. Flow and test the Alapah. _____________ Cmt Sqz, Open Lisburne, Acidize END 2-38 PTD: 190-129 Coiled Tubing (contingent upon well tests) 24. PT PCE to 250 psi low, 3500 psi high. 25. MU JSN for acid stimulation. 26. Tag PBTD, correct depth and flag pipe ~10’ off bottom. 27. Perform acid stimulation per pump schedule below. a. Make every effort to keep acid off the squeezed Ivishak perforations (bottom @ 13,486’ MD) – this is <5 bbls of volume so if there is not injectivity initially, consider circulating acid down to the nozzle in ~20 bbl increments, circulating in ~3 bbls at a time across the perfs from 13,605’ – 13,628’ MD @ 1:1 and squeezing down the backside, then circulating in another ~3 bbls across the perfs and repeating until injectivity is established. b. Consider staging the acid in manageable increments with diesel or methanol in between to keep non-freezables in the reel and over the gooseneck while squeezing. c. Once injectivity is established, pump 1-2% KCl down the CT x Tubing annulus continuously while jetting acid and reciprocating the nozzle across all Lisburne perforations. This will keep the acid off of the Ivishak perforations. d. Maximum WHP 2000psi to stay under frac gradient. 1. 30 bbls 15% HCl 2. 45 bbls emulsified 15% HCl (70% - 15%, 30% Diesel) 3. 30 bbls 15% HCl 4. 45 bbls emulsified 15% HCl 5. 30 bbls 15% HCl 6. 45 bbls emulsified 15% HCl 7. 30 bbls 15% HCl 8. 400 bbls 1-2% KCl (overflush) Portable Test Separator (contingent) 28. Assist operations with initial flowback for 24-48 hours. a. Observe for any acid flow back and divert as necessary. Slickline 29. Set SSSV. Attachments: 1. Current Schematic 2.Proposed Schematic Maximum WHP 2000psi _____________ Cmt Sqz, Open Lisburne, Acidize END 2-38 PTD: 190-129 Current Schematic _____________ Cmt Sqz, Open Lisburne, Acidize END 2-38 PTD: 190-129 Proposed Schematic TD = 13,831’ (MD) / TD =10,426’(TVD) 30” KB Elev.:54.5’/ BF Elev.:15.3’ 7” 4 7 9 16 17 20 1 3 13 & 14 19 PBTD = 13,789’ (MD) / PBTD =10,157’(TVD) 5 7” Marker Joint @ 13,533’ 13- 6 18 11 15 8 10 21 22TOF @ 13,630’ Tag 6/18/91 12 2 MIN ID=3.725” @ 13,563’ –XN Nipple CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30" Conductor N/A / N/A / N/A N/A Surface 130’ N/A 13-3/8” Surface 68/ NT80CYHE/ Btrs 12.415 Surface 2,541’ 0.150 9-5/8" Production 47 / NT80S / NSCC 8.681 Surface 11,083’ 0.0732 9-5/8" Production 47/ NT95HS/ NSCC 8.681 11,083’ 13,349’ 0.0732 7" Liner 29/ NT95HS/ TKC 6.184 13,087’ 13,831’ 0.0372 TUBING DETAIL 4-1/2" Tubing 12.6/ L-80/ TCII 3.958 Surface 13,002’ 0.0152 4-1/2” Tubing 12.6/ L-80/ TDS 3.958 13,002’ 13,565’ 0.0152 JEWELRY DETAIL No Depth Item 1 1,497’ XXO SSSV Nipple w/ Single Control Line, ID=3.813” GLM DETAIL: Camco 4-1/2” MMG w/ 1-1/2” valve, RK Latch 2 5,221’STA 6:Vlv= Dome, Dev.= 50, Port= 16/64, TVD= 4,070’, 6/16/2016 3 7,650’STA 5:Vlv= Dome, Dev.= 42, Port= 16/64, TVD= 5,884’, 6/16/2016 4 8,685’STA 4:Vlv= Orifice, Dev.= 45, Port= 32/64, TVD= 6,624’, 8/30/2018 5 10,413’STA 3:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 7,887’, 6/8/2016 6 11,642’STA 2:Vlv= Dmy, Dev.=46, Port= n/a, TVD= 8,762’, 6/8/2016 7 12,792’STA 1:Vlv= Dmy, Dev.= 42, Port= n/a, TVD= 9,569’, 6/8/2016 8 12,859’ X-Nipple, ID=3.813” 9 12,909’ 9-5/8” x 4-1/2” HES PHL Perma Latch Retrievable Packer, ID=3.850” 10 12,936’ X-Nipple, ID=3.813” 11 12,986’ X-Nipple, ID=3.813” 12 13,002’ Overshot, ID=4.75”, Btm @ 13,010’ 13 13,045’ Latch and Receptacle 14 13,046’ 9-5/8” x 4-1/2” TIW Packer & Millout extension, ID of Packer= 4.0” 15 13,087’ 9-5/8” x 7” TIW Liner Hanger 16 13,097’ 4-1/2” SWS Nip, ID= 3.813” 17 13,119’ 4-1/2” SWS Nip, ID= 3.813” 18 13,130’ WLEG, ID=3.958”- Bottom @ 13,131’ 19 13,548’ 7” 26-32 OTIS Perma-Drill Type WD Packer, ID=3.946 20 13,558’ 4-1/2” TDS X Nipple,ID=3.813 21 13,563’ 4-1/2” TDS XN Nipple,ID=3.725 22 13,564’ 4-1/2” TPS WLEG - Bottom @ 13,565’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Ivishak 13,324’ 13,354’ 9,987’ 10,012’ 30 9/19/2016 Closed 2-7/8” 13,382’ 13,387 10,035’ 10,040’ 5 9/18/2016 Closed 2-7/8” 13,393’ 13,454’ 10,045’ 10,096’ 61 1/24/93 Closed 3-3/8” 13,394’ 13,486’ 10,046’ 10,123’ 92 11/7/90 Closed 3-3/8” Alapah 13,605’ 13,628’ 10,226’ 10,246’ 23 6/11/91 Open 3-3/8” Reference Perf Log: DLL/ GR on 10/29/1990 OPEN HOLE / CEMENT DETAIL 13-3/8” 3,394 cu/ft Permafrost in 17.5” Hole 9-5/8" 3,120 cu/ft Class ‘G’ in a 12-1/4” Hole 7” 400 cu/ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL Max Hole Angle = 56 deg. @ 4,981’ Angle at Top Perf = 33 Deg. @ 13,393’ TREE & WELLHEAD Tree MCEVOY Wellhead FMC GENERAL WELL INFO API: 50-029-22090-00-00 Initial Completion - 11/7/1990 Set WF Patch –7/18/04 XX TTP Set –9/7/05 RWO –06/10/16 SAFETY NOTES H2S Readings Average 230 – 260 PPM on A/L & Gas Injectors Well Requires a SSSV STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COMAION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing ❑ ❑ Operations shutdown Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing ❑ Cut Tubing ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: Run Upper Completion 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: c:445+N AC- Hilcorp Alaska LLC Development 0 Exploratory ❑ 190-129 S t's 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22090-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: HECEIVE ADL0312828 DUCK IS UNIT MPI 2-38 — !"• 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OCT 1 1 2016 N/A ENDICOTT/IVISHAK OIL 11.Present Well Condition Summary: cy cc Total Depth measured 13,831 feet Plugs measured 13,558 feet f true vertical 10,426 feet Junk measured 13,325(Fill) feet 12,909, 13,046& Effective Depth measured 13,525 WLM feet Packer measured 13,548 feet true vertical 10,157 feet true vertical 9,657, & 10,176 feet Casing Length Size MD TVD Burst Collapse Conductor 130' 30" 130' 130' N/A N/A Surface 2,541' 13-3/8" 2,541' 2,391' 5,020psi 2,260psi Intermediate 11,083' 9-5/8" 11,083' 8,372' 6,870psi 4,760psi Intermediate 2,266' 9-5/8" 13,349' 10,008' 8,150psi 5,090psi Production 744' 7" 13,831' 10,426' 9,690psi 7,830psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 4-1/2" 12.6#/L-80/TCII 13,002' 9,729' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/TDS 13,565' 10,191' HES PHL Perma -•• TIW 1,497'(MD) Packers and SSSV(type,measured and true vertical depth) OTIS Perma XXO SSSV See Above 1,486'(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A SCANNED FEB 2 42017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 0 Subsequent to operation: 129 7,436 3,849 1,850 313 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 17 Gas ❑ WDSPL 7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 316-266 Contact Taylor Wellman Email twellman a(�•hilcorp.com Printed Name Mike Dunn Title Operations Manager ia//6 Signature Phone 777-8382 Date. '6/2 16- Form 10-404 Revised 5/2015 ,! /c i p-t--JO Submit Original Only �A ,4/074 RBDMS L-'- OCT 1 1 2016 • Duck Island Unit • Well: END 2-38 , Ili SCHEMATIC Last Completed: 06/10/2016 IIileorp Alaska,LL( PTD: 190-129 SAFETY NOTES TREE&WELLHEAD KB Elev.:54.5'/BF Elev.:15.3' H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree MCEVOY Well Requires a SSSV Wellhead FMC 30' OPEN HOLE/CEMENT DETAIL 1 13-3/8" 3,394 cu/ft Permafrost in 17.5"Hole 9-5/8" 3,120 cu/ft Class`G'in a 12-1/4"Hole 13 3/8" A 7" 400 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL 1 2 Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 130' N/A 3 13-3/8" Surface 68/NT8OCYHE/Btrs 12.415 Surface 2,541' 0.150 9-5/8" Production 47/NT8OS/NSCC 8.681 Surface 11,083' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 11,083' 13,349' 0.0732 7" Liner 29/NT95HS/TKC 6.184 13,087' 13,831' 0.0372 4 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TCII 3.958 Surface 13,002' 0.0152 1 5 4-1/2" Tubing 12.6/L-80/TDS 3.958 13,002' 13,565' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=56 deg. @ 4,981' • 6 Angle at Top Perf=33 Deg.@ 13,393' JEWELRY DETAIL No Depth Item 1 1,497' XXO SSSV Nipple w/Single Control Line,ID=3.813" 8 III GLM DETAIL:Camco 4-1/2" MMG w/1-1/2"valve, RK Latch 9 1i`I 2 5,221' STA 6:VIv=Dome,Dev.=50,Port=16/64,TVD= 4,070',6/16/2016 3 7,650' STA 5:VIv=Dome,Dev.=42,Port=16/64,TVD= 5,884',6/16/2016 10 4 8,685' STA 4:VIv=Orifice,Dev.=45,Port=26/64,TVD= 6,624',6/16/2016 5 10,413' STA 3:VIv=Dmy,Dev.=42,Port=n/a,TVD= 7,887',6/8/2016 - 11 6 11,642' STA 2:VIv=Dmy,Dev.=46,Port=n/a,TVD= 8,762',6/8/2016 7 12,792' STA 1:VIv=Dmy,Dev.=42,Port=n/a,TVD= 9,569',6/8/2016 12 8 12,859' X-Nipple,ID=3.813" 1 �', 9 12,909' 9-5/8"x 4-1/2"HES PHL Perma Latch Retrievable Packer,ID=3.850" ►---ss. 13&14 I 3 u t 10 12,936' X-Nipple,ID=3.813" 11 12,986' X-Nipple,ID=3.813" 12 13,002' Overshot,ID=4,75", Btm @ 13,010' ` - 13 13,045' Latch and Receptacle ' `15 14 13,046' 9-5/8"x 4-1/2"TIW Packer&Millout extension,ID of Packer=4.0" MIN ID 3.725" • 16 4 15 13,087' 9-5/8"x 7"TIW Liner Hanger @13,563'-X 16 13,097' 4-1/2"SWS Nip,ID=3.813" Mpple i'`► ■ P 17 ' 17 13,119' 4-1/2"SWS Nip,ID=3.813" 4 18 13,130' WLEG,ID=3.958"-Bottom @ 13,131' 18 19 13,548' 7"26-32 OTIS Perma-Drill Type WD Packer,ID=3.946 20 13,558' 4-1/2"TDS X Nipple w/plug,ID=3.813 9.5/8" a ► 21 13,563' 4-1/2"TDS XN Nipple,ID=3.725 TOF @ 13,525' 22 13,564' 4-1/2"TPS WLEG-Bottom @ 13,565' WLMDFish:Spinner Cage PERFORATION DETAIL 7"MarkerJoint 1-11/16""x6"" Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Size @ 13,533' � 19 ,/ ±13,325' ±13,354' ±9,988' ±10,012' 29 Future Future 2-7/8" :mak 20 `" „/ ±13,384' ±13,388 ±10,037' ±10,040' 4 Future Future 2-7/8" Ivishak 13,393' 13,454' 10,045' 10,096' 61 1/24/93 Closed 3-3/8" e 21 13,394' 13,486' 10,046' 10,123' 92 11/7/90 Closed 3-3/8" TOF @13,630' Tag 6/18/91 t' 22 Alapah 13,605' 13,628' 10,226' 10,246' 23 6/11/91 Closed 3-3/8" Reference Perf Log:DLL/GR on 10/29/1990 GENERAL WELL INFO 7" a ',' .7 API:50-029-22090-00-00 TD=13,831'(MD)/TD=10,426'(TVD) Initial Completion -11/7/1990 PBTD=13,789'(MD)/PBTD=10,157'(TVD) See Perf Table for Dates Set WF Patch-7/18/04 XX TTP Set-9/7/05 RWO-06/10/16 Revised By:TDF 6/29/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 Slickline 50-029-22090-00-00 190-129 5/28/16 9/20/16 Daily Operations: 5/25/2016 Wednesday No activity to report. 5/26/2016-Thursday No activity to report. 5/27/2016- Friday No activity to report. 5/28/2016 -Saturday WELL S/I ON ARRIVAL. PRESSURE TEST PCE, LOW= 300psi/HIGH= 2000psi. RIH W/ DSL LOGGING TOOLS & 11' OF STRINGSHOOT AND SHOT ACROSS INTERVAL @ 13,023' - 13,034' MD. RIH W/ DSL LOGGING TOOLS &3.625" CHEMICAL CUTTER - CUT TUBING @ 13,031' MD. (TIED INTO TBG TALLEY DATED: 11/02/90) WELL LEFT S/I ON DEPARTURE - NOTIFIED DSO & ISLAND OF DEPARTURE.JOB COMPLETE 5/29/2016-Sunday No activity to report. 5/30/2016- Monday Crews Travel from Anchorage to MPU, Loaded work gear and misc. items needed for Rig at MPA-Pad,Travel from MPU to Endicott Island. Orientation with Crews covering Endicott Island camp &Work areas on pad. Held Safety meeting with ASR Crews and Endicott Supervisors&Safety. Held Sundry Meeting with ASR crews, Well Site Supervisors&Work over Engineer. Spot upright tanks, Spot Flow Back tank & Rig up hard lines from tree to flow back tank, Set matting boards for Rig, Start filling uprights with Kill fluid, 8.8 PPG. Brine water. 5/31/2016-Tuesday Continue filling upright tanks with 8.8 PPG Brine water, Rig up Little Red Pumping Services,Test Surface lines to 3500 psi. (Notified AOGCC of right to witness BOP Test&Casing jack inspection at 09:19 AM. 5-31-16) Circulate wellbore with 8.8 PPG. Brine water pumping down tubing taking returns up Annulus and to flow back tank, Pumping 3/4 BPM 400 PSI. Pumped Total of 1,500 bbl. With Returns @ 8.8 ppg at Surface with the Tbg and Annulas on a Vacuum.Well Head Rep (Greg Ruge) Installed BPV.Scaffolding Crew Rigged down Scaffolding around Tree, Endicott ASRC Crane Operator Assisted in Hosisting Nipple down Tree, Checked Hanger Threads 11.5 Turns (Good Condition) Check Travel on Lock Down Screws, (Good) Observed Gland Nut on Control Line Threads Were Damaged Pulled out& Repaired threads, Replaced Back into Flange Nipple up Bope Stack. Picked up Spotted Mud Boat into Place, Shut Down Neighboring well MPI 2-36, Attempt to Spot ASR Well House over BOP stack, out Riggers on House are sticking out to far catching on Neighboring Wells,ASRC Crane Operator worked 18 hours Decision was made to Pull ASR Well House off of well, Shut down Crane Operations for the night. Northern Energy Services, Spotted Co,man and Change House Trailers & Pit Module. Rig Crew Finished Torquing '' up Bope Flange Bolts, Installing Hydraulic Fittings on Bope Stack and Removing out Riggers on Well House. �� �� �� Hilcorp Alaska, LLC �����U�� �������^K��� ' ' --' x Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 S|ick|in '22090'00'00 198`120 5/28/16 9/70/16 Daily Operations: 6/1/2016 Wednesday Continue removing outriggers on Well Enclosure, Set well over BOP, Decided to pick BOP up &turn 1 bolt hole, Set BOP Enclosure in place. Raised Derrick half mast and verified fit, lowered Derrick, Set Rig floor on Well enclosure. Set Casing Jacks on BOP&Attach to BOP. Install Rig stairs,Set Cat walk, Install Koomey hoses on BOP, Nipple up Choke & kill lines. Install circulating hoses, pump suction & pop off line to pits. Connect casing jacks&function test same. Install hydraulic tensioner on BOP. Pull BPV, Install TWC. Rig up to Test BOPs, Function test BOPS, Body test BOPs to 3,000 psi.Test BOPs, Blind Ram seal started leaking, Open Doors, Grease seals, Close doors, attempt to test' Door seal still leaking. Locate Door seals for 13'S/8" Cameron,wait ontoarrive. 6v2/2016-Thursday Service Rig, Check fluid levels. Wait on Ram Door seals to arrive, Build berms for 4.S" tubing string. Install Door Seal on Blind Ram door&tighten up.Test BOPstoZS0psiLow/3,UOOpsiHigh.Tested �nnu|ar�o2,58UpsivvithZ'7/8"Testjoint� Tested Rams with 2'7/O" &4'1/2"Test joints. All gas alarms were tested good (BOP Test&Casing Jack inspection was c � witnessed by Matthew Herrera with AOGCC). Rig down Testing equipment. Pull TWC. Pick up & make up landing joint & XOs, Make up to Tubing hanger, Back out LDS. Unseat Hanger at 140K, PullRig tg_i5ajK^Start Jacking tobring Hanger to Rig floor. Bring P/U/W uput10K |ncermentsto23OkQ096Tensile 3tren0htof4.S 12.6#/ L-80/TDS Tubing. Land �� � .,Hanger, RuninLD3, Backoutand |aydovvn |andinQjoint /VVi||iann4rrnstrong\Sch|umoberQerE'LineVVasNotified. PrepRig Floor, Remove Stairs, Break over and Lower Derrick, Remove Pipe Racks.Schlumberger Crew Maxed out on Hours Worked Needed Personal and Equipment Shuttled to Location.ASRC Crane operater MIRU Hoisted and Removed Casing Jacks from Rig Floor Hoisted 13-5/8" x11" and 11" x7" Adapter Flange toRig Floor. Nipple up13-5/8" x11" and 1l" x7" Adapter ShnotingF|an8eontnpl3'S/D" Annu|arForE'LineOperations. K/USch|umbergerE-LineVVireLineBopeandLubricator' Test lubricator to l000psi. 6/3/2016 Friday `4, � Run in the hole with Jet cutter&Collar locator, Log into place, Make Jet cut below 10�puojoint @ 13,O33' POOH with ^:)- wire|ino, Break down tools& rig down. P/U Casing Jacks, Raise Derrick, Rig up stairs& Rig floor. Pick up Landjng joint, Make uptuTubing Hanger, Back out LDS, Pull Hanger Free, PUVVeiQht143K. Break out Lay Down Landing Joint and Hanger. Repair Hydraulic Leak on Power Tongs.TOOH Lay Down 4.5"TDS Tubing.Total 38 Jts to SSV R/D Halliburtion Spooler.TOOH Lay Down 4.S"TDSTubing, Displace well with 8.8 ppg Fluid every 15 Joints Layed Down Total Jts (130) @ 5,400 ft. 6, ' Service Rig, Fuel rig& Check fluid levels.TOOH, Laying down 4.5"TDS Tubing. Recovered Total Its (323 +3.9 Ft. Cut). Service Rig, Fuel rig& Check fluid levels. Rig Down and Remove Casing Jacks From Rig Floor. Pick up Landing Joint Install inverted Test Plug install wear Bushing (ID 8.875) RILDS X4 Lay Down Same. Install 2 +Spacer Spools and Washington Circulation Head on Annular and Nipple up, Load and Tally 2-7/8" RTS-6 Work string on Racks. Pick and make up 8-1/2" Tubing Dress off Mill Assembly. Load and Tally 2'7/8"Tubing While Running in the Hole to 1,500 ft. L � "��x~-, `- - ����^ J � C • • H i lcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 Slickline 50-029-22090-00-00 190-129 5/28/16 9/20/16 Daily Operations. � r 1 W w P 6/5/2016-Sunday Service Rig, Fuel rig& Check fluid levels. Continue to TIH with Dress off Assy on 2.875" Work String to 13,010'. R/U Stand Pipe Hose, Install Washington Circulating Rubber, Conducted Rotation Milling Parameters @ 13,010'. with a P/U/W=100k, S/O/W=47k T/L/S @ 4,000 ft/lbs. Free Rot wt= 62k Rpm=30. Pump Rate 84 Gpm -2bpm @ 290psi. Circulate &Wash down Tag top 4-1/2"Tubing Stump on Jt (419) 8 ft in @ 13,018'.ASR 1' RKB set 5k Down Pulled up 10 ft. Dress off top Stump 2 inches @ 2Bpm 700psi/30rpm/W/O/B=2K @ 13,018'.Stop Rotation Slide Down over Stump to 13,023'. Pulled up to 13,010'. Slide down over top of stump with No Rotation & No Pump @ 13,018'to 13,023' ( Good Solid Tag ) with 5k. R/U Reverse Circulate x 3 with a Pump Rate of 4bpm 340psi. Recovered 1/2 Cup Metal Shavings on Pit Magnet. Remove Washington Circulating Rubber, Install Wiping Rubber Below Slips, Blow Down Lines, Prep Rig Floor to Trip out of the Hole. TOOH with 2-7/8" Tubing& Dress off Assembly to 2,000'. 6/6/2016- Monday Rig, Fuel rig&Check fluid levels.TOOH with 2.875" Work String and Dress off Assembly. Rig, Fuel rig& Check fluid levels. Rig up Halliburton Wire Line RIH with 8.508" ID GR/1B to 13,017'. Pooh R/D Halliburton Wire Line. Nipple down Washington Circulating Head and Cross over Spacer Spool from Annular, Nipple up 4'Spacer Spool on Annular. Pick up Landing Joint and Retrieving Tool RIH BOLDS x 4 Remove Wear Bushing, Load and Tally 4-1/2" Completion Tubing on pipe Racks, Change over Handling Equipment from 2-7/8"to 4.5" Equipment. Pick and Make up over shot, 2 x-Nipples with Pups, 9-5/8" x 4-1/2" Packer Assembly, X-nipple.TIH with 4.5" Completion. 6/7/2016-Tuesday Fuel Rig&Check fluid levels. Continue to TIH with 4.5" Completion to 10,400'. Fuel Rig&Check fluid levels. Continue to TIH with 4.5" Completion. Ran 291 Joints Made up and Installed SSSV. Rig up Halliburton Control Line Spooler Ran 1/4" Control Line over Shieve in Derrick Tigh into SSSV Nipple P/T 5,000psi for 5 min bleed pressure Down to 3,500psi. Install Control Line Clamps on 4-1/2"Tubing Collars every other Joint.Total Clamps ( 12 & 1- 1/2 Clamp) Total Joints Ran (329). Work on Mud pump Tighen Packing on Pump. Mix and Pump 700bbl. of 8.8ppg Brine w/0.5% Baracor inhibitor with a Pump Rate of 3 bpm @ 160psi. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 ASR/SL 50-029-22090-00-00 190-129 5/28/16 9/20/16 laity Oiperatiions; 6/8/2016-Wednesday Mix and Pump 700 bbl. of 8.8 ppg Brine w/0.5% Baracor inhibitor with a Pump Rate of 3 bpm @ 160psi. Slack off on tubing &attempt to Shear pins on overshot, did not see pins shear @ 14K, continued working weight to 29 K, did not see the pins shear, Rig up to circulate, Pump 1.5 bbl per minute @ 80psi while slacking off, seen 40psi increase when taking weight. Discuss options with Engineer. Space out, make up pup joints&Tubing Hanger& Land Tubing Hanger, RILDS, Lay down landing joint. pick up Weight=151K, SO Weight= 77K. Rig up Halliburton Slick Line, Run# 1 RIH with 4.50 GX & Retrieve DSSV. (Run #2 )RIH w/4.5 GS (Steel) sit Down and Latch up to RHC Plug Body @ (12,958' SLM) ( 12,936' RKB) One 500# OJ Lick Plug Body Free POOH. ( Run#3) RIH w/QC, 3.70 Cent, 2' 1-7/8" STEM Tubing End Locator, 3.25' LIB, sit Down @ 13,025' SLM, 13,002'RKB Lightly Sit Down Two Times, unable to Get Past,Tap Down one Time to Get Impression, POOH (Good impression of top of Tubing Stump on LIB). (Run#4) RIH w/QC, 3.65 Cent,xo, 5' 1-1/2" Stem,xo, 3.70" Cent, 2 1-7/8" Stem,TEL, XO, 2.25 LIB Stacked out at 13,006'. WLM, POOH. ( Run#5) RIH w/3.70 CENT, 3.25, CENT, 5'x 1-7/8 Stem, 3.65 Cent, 3'x 1-7/8' Stem,4-1/4'Tel,xo, 2.25 LIB,Tools Fall Through overshot, Loc wleg @ 13,126' SLM/ 13,131'MD. Drift Down to 13,450' SLM Pooh,TEL Sheared, no impression on LIB c/o BHA. (Run#6) RIH w/4-1/2' X-Line (Selective) w/x-Lock(1/4 'Brass/Steel)4-1/2 RHC Plug Body set @ 12,958' SLM, Pooh. 6/9/2016-Thursday Pick up Landing joint, Drop Ball & Rod,Attempt to pressure up on Tubing, Mud pump on Rig had a seal out. Rig up Little Red Pumping Services, Pressure up on Tubing @ 3,600psi. Set Halliburton Packer, rig up on Annulus for MIT-IA, Start pumping down backside, discovered fluid was leaking up through hanger control line port. Discussed with Engineer plan j V\ 1 forward. Installed Landing joint in Tubing, closed pipe rams,Tested IA to 2,50Opsi charted for 30 minutes.Rig down little Red Pumping services, Lay down landing joint, Install BPV, Blow down Lines& BOP. Drain mud tanks, suck out fluid from Mud boat, Rig down, lay Derrick over.Well Kill Operations on MPI 2-52, While ASRC Crane Assisting in Rigging Down Stairs to Rig Floor, Remove and Haul Mud Boat, Remove and Hoist Rig Floor and Well House on to Bed Truck, Move Pit Module, Disconect Hydraulic Hoses to Bope Stack. Nipple down BOPE, Nipple up Production Tree.Test Hanger Void 500/5,000psi, Well Head Rep Pulled BPV. 6/10/2016- Friday No activity to report. 6/11/2016 Saturday PT 200/2,000 PSI (GOOD TESTS). RUN A 3.70" CENT,XO, 2" RB,SIT DOWN @ 12,934' SLM (12,936' MD),ATTEMPT TO LATCH UP FOR AN HOUR, UNABLE TO LATCH. GET CALL FROM RIG REP TO RIG DOWN/ PREP FOR RIG JOB. RDMO. 6/12/2016-Sunday No activity to report. 6/13/2016- Monday No activity to report. 6/14/2016-Tuesday PT 200/2,000 PSI (GOOD TESTS). PULLED BALL AND ROD @ 122932' SLM (12,938' MD). PULLED THE DGLV FROM ST#4 @ 8,686' SLM (8,718' MD). PULLED THE DGLV FROM ST#5 @ 7,644' SLM (7,675' MD). PULLED THE DGLV FROM ST#6 @ 5,220'SLM (5,266' MD). • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 ASR#1 50-029-22090-00-00 190-129 5/28/16 9/20/16 Daily Operations: 6/15/2016-Wednesday PT 200/2,000 PSI (GOOD TESTS). SET LGLV (16/64 TRO 1700#) IN ST#6 @ 5,217' SLM (5,266' MD). SET LGLV(16/64 TRO 1,699#) IN ST#5 @ 7,650' SLM (7,675' MD). SET OGLV (26/64) IN ST#4 @ 8,686' SLM (8,718' MD). PULLED RHC PLUG BODY @ 12,928' SLM (12,975'MD), HUNG UP @ 12,855' SLM, SHEARED PULLING TOOL, RHC PLUG BODY STILL IN WELL. RDMO. 6/16/2016-Thursday PT 250/2,000 PSI (GOOD TESTS). PULL RHC PLUG BODY @ 12,855' SLM. SET 4.5" FXE SSSV SER# HFXE-1 @ 1,486' SLM (1,500' MD). CLOSURE TEST A PASS. RDMO. 6/17/2016- Friday No activity to report. 6/18/2016-Saturday No activity to report. 6/19/2016-Sunday No activity to report. 6/20/2016- Monday No activity to report. 6/21/2016-Tuesday No activity to report. 4111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-38 ASR#1 50-029-22090-00-00 190-129 5/28/16 9/20/16 Daily Operations: 9/14/2016-Wednesday No activity to report. 9/15/2016-Thursday Well flowing on arrival, (P/T TO 300 LOW, 2„050 HIGH) (D&T PRE ELINE ADPERF). PULLED 4-1/2” FXE (ser# HFXE-01) FROM XXO NIPPLE @ 1,497' SLM. DRIFTED TO T/D @ 13,514' SLM (13,519' MD) W/ 18' x 3.50" BARBELL(USED 5' CORRECTION FROM TIEING INTO TT ON 6/9/16 WSR.) 9/16/2016- Friday No activity to report. 9/17/2016-Saturday No activity to report. 9/18/2016-Sunday WELL FLOWING UPON ARRIVAL(ELINE ADPERF). PT TO 250 PSI LOW& 2,050 PSI HIGH. RIH W/CH, WB, GAMMA PERF, HSC 2-7/8"X 11' -5' LOADED AT 6 SPF, 60 DEG PHASED, MAX FORCE CHARGES. PERFORATE INTERVAL @ 13,382'-13,387' -CCL TO TOP SHOT 7.7' -CCL STOP DEPTH 13,374.3'. POSITIVE INDICATION OF FIRE. CORRELATE TO JEWELRY LOG DATED 27- MAR-92 &SLB CMT EVALUATION LOG DATED 1-NOV-90. LAY DOWN EQUIPMENT FOR THE NIGHT. 9/19/2016 - Monday PT TO 250 PSI LOW & 2,050 PSI HIGH. GUN#2 - RIH W/20' X 2-7/8" HSC, 6 SPF, 60 DEG PHASED, MAX FORCE CHARGES. PERFORATED INTERVAL @ 13,3341-13,354'. GUN#3 - RIH WI 20' X 2-7/8" HSC, 6 SPF, 60 DEG PHASED, MAX FORCE CHARGES. PERFORATED INTERVAL @ 13,324'-13,344'. WELL LEFT SHUT IN UPON DEPARTURE-SL TO SET SSSV- NOTIFIED PAD OP AND ISLAND OF DEPARTURE. 9/20/2016-Tuesday Well flowing on arrival, (P/T TO 300 LOW, 2,050 HIGH) set fxe sssv. PURGED CONTROL LINE W/2 GALLONS HYDRO SET 3.813" X-LOCK W/4-1/2 FXE SSSV 2 sets std pkg, (ser#HFXE3) IN XXO NIPPLE @ 1,481' SLM, 1,495' MD. PASSING CLOSURE TEST TO 300 PSI DIFFERENTIAL. WELL TURNED OVER TO OPS TO POP. • 1, OF 714. • y*s_�\\�y/,��A THE STATE Alaska Oil and Gas 4' "��i�•"-9� O-f jL Js Conservation Commission SfF= IV • 0 STATE OF ALASKA • SAY 120' ALASKA OIL AND GAS CONSERVATION COMMISSION Pr-5S �Z¢/4� APPLICATION FOR SUNDRY APPROVALS G 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well Q , Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑✓ Cut Tubing Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run Upper Completion Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 9 190-129 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22090-00-00 ' 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 • Will planned perforations require a spacing exception? Yes ❑ No Q DUCK IS UNIT MPI 2-38 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • ENDICOTT/IVISHAK OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,831' 10,426' 13,525' 10,157' 160 13,558' 13,525' Casing Length Size MD TVD Burst Collapse Conductor 130' 30" 130' 130' N/A N/A Surface 2,541' 13-3/8" 2,541' 2,391' 5,020psi 2,260psi Intermediate 11,083' 9-5/8" 11,083' 8,372' 6,870psi 4,760psi Intermediate 2,266' 9-5/8" 13,349' 10,008' 8,150psi 5,090psi Production 744' 7" 13,831' 10,426' 9,690psi 7,830psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6#/L-80/TDS 13,131 See Attached Schematic See Attached Schematic 4-1/2" 12.6#/L-80/TDS 13,565 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 13,046(MD/9,763(TVD),13,087(MD)/9,795(TVD)&13,548(MD)/10,176(TVD)and TIW Pkr,Liner Top Pkr&Otis WD Pkr and HXO SSSV 1,553(M Dy 1,539(TVD) 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑.r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL Q WINJ p WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved - rldk. herein will not be deviated from without prior written approval. Contact Taylor Wellman Email twelIman( hilcom.corn Printed Name i Mik= • n Title Operations Manager Signature �Z! - Phone 777-8382 Date 5/6/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\A — 2 ce Cit_ Plug Integrity ❑ BOP Test ' Mechanical Integrity Test ❑ Location Clearance ❑ Other: s 3/100 rs z. 60 e fes+`: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 11 Subsequent Form Required: i 0--ii D RBDMS 1,V MAY 3 1 1016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: s- Ly co ihmi4 FnFrA4fnri r v Form 10-403 vised 1/2015 i li for 12 months from the date of approval. Attachments in Duplicate • • RWO—Tubing Swap Well: DUI MPI 2-38 PTD: 190-129 API: 50-029-22090-00 Hileorp Alaska,LLQ Well Name: DUI MPI 2-38 API Number: 50-029-22090-00 Current Status: SI - Producer Field: Endicott Estimated Start Date: July 27, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-129 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: 1621204 Current BHP (Ivishak): 4,041 psi @ 10,000' TVD (Based on offset BHP from MPI 1-11 on 2/11/16) Equivalent Mud Weight: 7.8 ppg MPSP: 160 psi Based on production of 96%WC (0.439psi/ft) and additional safety of 1500' of gas cap (0.1 psi/ft) Brief Well Summary: The well is currently shut in since March 2004 due to several tubing integrity issues.This well was originally drilled and completed (perfed) as an Ivishak producer in 1990.The Alapah was open from June 1991 to Feb • 1993.The 2-32 well (analog well) had a 24 day production test of the Alapah indicating very limited production with rapid depletion from an IP of 700bopd.The Ivishak was reperforated in January 1993.The well was shut in following a leak detection log found tubing leaks at 12,825' &at 5,125' (GLM#7).The tubing was unable to be patched successfully.The well last produced 316bopd, 198Mcfd, &7,591bwpd (96%WC). Since reservoir , pressure has declined,total fluid rate will likely be lowered to"5,000bfpd. Notes Regarding Wellbore Condition Current well status is in Not Operable and shut in due to leaks in the tubing string. A caliper run in May 2009 • indicated multiple possible holes but no areas of significant wall loss. Chances of parting the tubing string during pulling should be a minimum. RWO Objective: Cut and pull the existing tubing string and replace with a new 4-1/2" completion to restore wellbore integrity. • Pre-Workover Prep Procedure: Pre-Sundry Operations 1. CM IT-IA to 2000psi. 2. Spot Slickline unit and RU unit. 3. Pressure test lubricator to 300psi low/"2050psi high. a. Ensure enough lubricator to retrieve—25' of fish is used. 4. Drift with 3.772" dummy plug to top of tubing patch at 12,814' md. 5. MU fishing toolstring w/Weatherford pulling tool. 6. RIH and latch upper patch section,jar to release and POOH. a. The upper section of the WFD 4-1/2"Arrow-Pac Patch is OD=3.771" and OAL=19.74'. 7. RIH and latch lower patch section,jar to release and POOH. a. The lower section of the WFD 4-1/2"Arrow-Pac Patch is OD=3.771" and OAL=6.10'. 8. Pull 2-7/8" XX plug from 13,028' md. • • RWO—Tubing Swap Well: DUI MPI 2-38 PTD: 190-129 API: 50-029-22090-00 Hilcorp Alaska,LLI 9. Pull 4-1/2"x2-7/8" nipple reducer from 13,028' md. 10. Allow fluids to swap. This will require 1-2 days of time between steps. 11. MU SBHP memory gauges. RIH with gauges at a constant speed. a. While POOH make 5 min stops at the following depths: 13,340' md(10,000'tvd); 13,218' md(9,900'tvd); 13,093' md(9,800'tvd); 12,833' md(9,600'tvd). 12. RD Slickline. Sundry Operations(Approval required to proceed) 13. Spot E-Line unit to well and RU unit. 14. Pressure test lubricator to 300psi low and 2050psi high (GL system pressure). 15. RIH with low flare cutter. Cut tubing within the top 2'of the jointed connection in 2nd pup joint above packer(+/-13,031' md). Note pressure equalization in report. a. Use tubing tally dated 11/02/1990 as reference log. 16. Clear and level pad area in front of wellhouse. Spot rig mats and containment. 17. RU hardline from the IA of 2-38 to the swab cap of an adjacent well. Have LRS pump down the tubing and take returns from the IA and down the flowline of an adjacent well. 18. Circulate well clean with heated seawater down IA and up tubing while taking returns to the facility. a. Tbg vol (195bbls) + IA vol (698bb1s) =Total minimum vol (900bbls) 19. Confirm well is dead and RD hardline and LRS. Workover Procedure: 20. Mobilize ASR#1 from Milne Point to Endicott. 21. Verify 0 psi on the annulus and tubing pressure. 22. Set BPV, ND tree, NU 13-5/8" BOP's. a. Function test all prior to arrival of AOGCC inspectors. 23. Spot and rig up ASR#1 and all supporting equipment. 24. PU Casing Jacks via the beaver slide and Tugger winches to rig floor. 25. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. 26. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, re-load and kill the well with 8.5ppg seawater and confirm dead prior to pulling BPV. Set TWC. 27. Test BOPE to 250psi Low/3,000psi 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. ►-Irs'nC-r AOGCC. 1,1.3sPe a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. Fort c. Confirm test pressures per the Sundry Conditions of approval. : CAs�►�c, A CV- 1+4SPEGLop3 d. Test VBR rams on 2-7/8" and 4-1/2"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 28. Contingencyl: (If the tubing hanger won't pressure test due to either a control line leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure • • RWO—Tubing Swap Well: DUI MPI 2-38 PTD: 190-129 Hilwrp Alaska,LI) API: 50-029-22090-00 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 29. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. Asp. Chu,� c +a«.t 30. Casing Jack RU Procedure: *N4Ks1 uSefl Ni EMI< t- pukt.o.kepar it-tows ab¢E'> a. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point as 2,038 psi *Als (equates to—230.4k#or 80%of yield strength). b. Yield strength of 4-1/2", 12.6#, L-80=288k#, and the Mannesmann TDS connections= 288k#. c. String weights during 1990 completion were not recorded. The blocks on Doyon 15 were approximately 35k#. d. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 31. MU 4-1/2" landing joint(or spear) and BOLDS. 32. Attempt to pull tubing without the need of the casing jacks. If successful, move to Step 33. a. 13,040' of 4-1/2"tubing=164.5k#dry/145.5k#buoyed in 8.5ppg to 1500'. 33. Set Casing Jack pressure to 1,415 psi (160,000 lbs). Slowly pressure up on jacks. Hold for 5 min. 34. If hanger does not unseat, increase pressure in 100 psi increments holding for 5 min between pressure increases. Note: do not exceed 2,038 psi (230,400#). If unmoved contact Ops Engineer for further discussion. 35. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. a. Contingencyl: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 36. RU Spoolers and continue to jack 4-1/2"tubing from cut at+/-13,040', and lay down the same in singles. a. From 0—1553'there are two%" control lines(balance and control line)to the HXO landing nipple. b. ASR rig can pull "155k#. The initial^'500' of tubing will need to utilize Casing Jacks to pull the tubing from the well. (12,500' of 4-1/2", 12.6#tubing=^'140k# buoyed weight in 8.5ppg seawater). 37. Once the string weight is comfortably less than 150k#, set tubing in lower slips, retract casing jacks into lowered position and swap to 'Carriage mode'. Resume pulling the completion utilizing upper slips only with rig while laying down the same in singles. a. Visually inspect the outside of the 4-1/2" tubing for signs of corrosion and/or scale. If either are observed, move forward with Contingency—Casing scraper run on 2-7/8" workstring. 38. Use inverted test plug to install wear bushing. 39. RU Slickline and drift w/9-5/8",47#gauge ring to 13,000' md. RD SL unit. a. If unable to reach packer setting depth, move forward with Contingency2—Casing scraper run on 2-7/8" workstring. . RWO—Tubing Swap Well: DUI MPI 2-38 PTD: 190-129 Hilcorp Alaska,LL API: 50-029-22090-00 40. Contingency2—Casing scraper and dress off mill run on 2-7/8" workstring a. PU 2-7/8" workstring and MU 9-5/8",47#dress off mill and casing scraper assembly. RIH and wash to 12,950' and circulate x2 bottoms up or until clean returns are observed. Short trip and scrape casing at packer setting depth at least 4 times(2 short trips). ��t,�F'f 2'1 61' i. Packer setting depth is+/-12,900' md. �RH �S^ficzc) b. Set down and dress off tubing stub at+/-13,031' md. TM-CC� c. POOH w/2-7/8" workstring and lay down. 41. MU 4-1/2", 12.6#, L-80,TCII completion and begin to run. a. Contingency3: (If previous tubing string exceeded ASR lifting capacity once unseated) i. Ensure PXN plug is set in the XN nipple in the tubing tail prior to running. 42. Run 4-1/2"tubing tail and completion, overshot tubing stub and space out. a. Note PU (Pick Up) and SO (Slack Off)weights on tally. b. Packer setting depth is+/- 12,900' and and the overshot depth is+/- 13,030' md. c. Note the Baker packer is a hydraulically set and will only set with a hydrostatic overbalance of pressure from the inside of the tubing string. Risk of setting due to RIH speed is negligible. d. A single SSSV control line will be run from+/- 1600'TVD to surface. 43. Line up to reverse circulate and pump 700bbIs of completion fluid down the backside into well at 4-5 bpm. a. Completion fluid to be seawater w/0.5% Baracor corrosion inhibitor. 44. SO past top of tubing stub and watch for 10k-15k#shear on overshot tattle tails. PU,space out overshot no-go"2' above the stub and land the tubing into the hanger. RILDS. Lay down landing joint.Test tubing hanger to 250psi low/5,000psi High. a. If there are any questions if overshot of tubing stub, begin reverse circulating seawater and ease down with the overshot onto the tubing stub while watching for a definitive pressure increase. 45. Drop ball and rod and complete loading tubing and hydraulically set the packer as per Halliburton's setting procedure. Conduct MIT-T to 3,000psi. Conduct MIT-IA to 2,500psi. 46. Terminate the control line. Pressure test control line to 5000psi and the tubing hanger to 5000psi. 47. Test TRSSSV. 48. RU SL and pull dummy SSSV from +/-1500' md, pull ball & rod and plug body from XN plug @ +/-13,000' md. Drift to 13,400' and w/3-1/8" dummy gun. RD SL. a. If Contingency3 was used,SL to pull XN plug from+/-13,000' md. Drift to 13,400' and w/3-1/8" dummy gun. RD SL. 49. Set BPV. 50. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500bbl returns tank. Post Workover Procedure: 51. RD mud boat. RD BOPE house. 52. RU crane. ND BOPE. Pull BPV.Set TWC. 53. NU 4" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 54. Test tubing hanger void to 500psi low/5,000psi high. 55. Pull TWC. RD crane. 56. Move 500bbI returns tank and rig mats. 57. Spot Slickline unit and RU. . RWO—Tubing Swap • Well: DUI MPI 2-38 PTD: 190-129 API: 50-029-22090-00 Hilcorp Alaska,LI) 58. Pressure test lubricator to 300psi low and 2050psi high. 59. Pull dummy GLV's from all GLM's 60. Set new GL design as per new design sheet(find final design sheet in electronic well folder). 61. RD Slickline. 62. Spot E-Line unit to well and RU unit. 63. Pressure test lubricator to 300psi low and 3500psi high. 64. Perforate the following intervals: a. +/-13,384'—+/-13,388' and (4') b. +/-13,325'—+/-13,354' and (29') c. See final approved perf sheet for final depths from correlation log. 65. RD E-Line and demobilize from island. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • Duck Island Unit HO Well: END 2-38 • SCHEMATIC Last Completed: 11/2/1990 Hilcorp Alaska,LLC PTD: 190-129 SAFETY NOTES TREE&WELLHEAD KB Elev.:54.5'/BF Elev.:15.3' H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree MCEVOY i Well Requires a SSSV Wellhead FMC Leaks @ GLM#7&12,825'per LDL on 3/10/2004 30"411; : 1 .A t„ a OPEN HOLE/CEMENT DETAIL 1 13-3/8" 3,394 cu/ft Permafrost in 17.5"Hole 9-5/8" 3,120 cu/ft Class'G'in a 12-1/4"Hole 13 3/8 7" 400 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 130' N/A 2 13-3/8" Surface 68/NT8OCYHE/Btrs 12.415 Surface 2,541' 0.150 9-5/8" Production 47/NT8OS/NSCC 8.681 Surface 11,083' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 11,083' 13,349' 0.0732 3 7" Liner 29/NT95HS/TKC 6.184 13,087' 13,831' 0.0372 It TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 13,131' 0.0152 ' 4 4-1/2" Tubing 12.6/L-80/TDS 3.958 13,548' 13,565' 0.0152 ll WELL INCLINATION DETAIL 5 Max Hole Angle=56 deg. @ 4,981' Angle at Top Perf=33 Deg.@ 13,393' .1 4 6 JEWELRY DETAIL st it :^ No Depth Item 7 11 i 1 1,553' HES 4.5"HXO SSSV Land Nip-ID=3.813" 4_ Gas Lift Mandrels 8 y°s 2 5,125' STA 7:TVD=4,012',DEV=53,VLV=DMY,Latch=RM,Port=O,5/29/04 3 8,438' STA 6:TVD=6,450',DEV=45,VLV=SO,Latch=RM,Port=32,2/16/04 9 4 10,045' STA 5:TVD=7,611',DEV=42,VLV=DMY,Latch=RA,Port=0,9/26/95 Min ID=2.635" 1, 5 10,980' STA 4:TVD=8,298',DEV=44,VLV=DMY,Latch=RA,Port=0,9/26/95 @ 13,028' 414s410 6 11,798' STA 3:TVD=8,870',DEV=47,VLV=DMY,Latch=RA,Port=O,9/26/95 g1,-1 $ 7 12,536' STA 2:TVD=9,382',DEV=44,VLV=DMY,Latch=RA,Port=0,9/26/95 - a:��e°�11&12 8 12,814' WFD Arrow-PAC Patch,ID=2.372,Btm @ 12,834'-7/18/2004 9 12,999' STA 1:TVD=9,762',DEV=39,VLV=DMY,Latch=RA,Port=0,9/26/95 el 10 13,028' 4-1/2"SWS Nip,ID=3.813';2-7/8"Reducing Nip,ID=2.313"-5/15/04; 2-7/8"XX TTP-9/7/05 11 13,045' Latch and Receptacle ., 't' 12 13,046' 9-5/8"x 4-1/2"TIW Packer&Millout extension,ID of Packer=4.0" s ME 13 13 13,087 9-5/8"x 7"TIW Liner Hanger i 14 0 14 13,097' 4-1/2"SWS Nip,ID=3.813" 15 13,119' 4-1/2"SWS Nip,ID=3.813" 1.. « +15_ ' 16 13 ,130' WLEG,10=3.958"-Bottom @ 13,131' +� 17 13,548' 7"26-32 OTIS Perma-Drill Type WD Packer,ID=3.946 k; ; 16 , 18 13,558' 4-1/2"TDS X Nipple w/plug,10=3.813 �; 19 13,563' 4-1/2"TDS XN Nipple,ID=3.725 9-5/8"420 13,564' 4-1/2"TPS WLEG-Bottom @ 13,565' PERFORATION DETAIL i v Fish:Spinner Cage 7"MarkerJoint . ', x ' 8/13/93 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size @ 13,533' 4,0:1 gk.,, k7,10;17 13,393' 13,454' 10,045' 10,096' 61 1/24/93 Closed 3-3/8" Ivishak ^ 18 13,394' 13,486' 10,046' 10,123' 92 11/7/90 Closed 3-3/8" " Alapah 13,605' 13,628' 10,226' 10,246' 23 6/11/91 Closed 3-3/8" k 19 f` Reference Perf Log:DLL/GR on 10/29/1990 TOF @ 13,630' Tag 6/18/91GENERAL WELL INFO I��� API:50-029-22090-00-00 '' 't'a ; Initial Completion -11/7/1990 7""s i4:,...,, ' See Perf Table for Dates TD=13,831'(MD)/TD=10,426'(TVD) Set WF Patch-7/18/04 PBTD=13,789'(MD)/PBTD=10,157'(TVD) XX TTP Set-9/7/05 Revised By:TDF 5/3/2016 • • Duell:ck IslandEND Unit ,11 W PROPOSED Last Completed: 11/2/1990 Miami)Alaska,LLC PTD: 190-129 SAFETY NOTES TREE&WELLHEAD KB Elev.:54.5'/BF Elev.:15.3' H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree MCEVOY 30, J4 Well Requires a SSSV Wellhead FMC t1 ` '° Leaks @ GLM#7&12,825'per LDL on 3/10/2004 OPEN HOLE/CEMENT DETAIL x 1 v 13-3/8" 3,394 cu/ft Permafrost in 17.5"Hole O.._; 9-5/8" 3,120 cu/ft Class`G'in a 12-1/4"Hole 13-3/8 ,*1 k 7" 400 cu/ft Class"G"in 8-1/2"Hole CASING DETAIL 2 Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 130' N/A 3 13-3/8" Surface 68/NT8OCYHE/Btrs 12.415 Surface 2,541' 0.150 I 9-5/8" Production 47/NT8OS/NSCC 8.681 Surface 11,083' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 11,083' 13,349' 0.0732 7" Liner 29/NT95HS/TKC 6.184 13,087' 13,831' 0.0372 4 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/TDS 3.958 Surface 13,131' 0.0152 5 4-1/2" Tubing 12.6/L-80/TDS 3.958 13,548' 13,565' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=56 deg. @ 4,981' 6 Angle at Top Perf=33 Deg.@ 13,393' JEWELRY DETAIL 7 No Depth Item 1 ±1,500' SSSV w/Single Control Line '+ s Gas Lift Mandrels 4 04 �; 9 5 �,, 2 ±5,266' STA 6:TVD=±4,100' 0 P 3 ±7,675' STA 5:TVD=±5,900' 'sy 10 4 ±8,718' STA 4:TVD=±6,650' 5 ±10,409' STA 3:TVD=±7,885' a=a 11 6 ±11,677' STA 2:TVD=±8,785' 7 ±12,811' STA 1:TVD=±9,585' ti 12 `...����✓✓✓��� 8 ±12,975' X-Nipple 9 ±13,000' 9-5/8"x 4-1/2"Packer 6.,,„;=„„4 ,,13&14 10 ±13,015' X-Nipple 11 ±13,025 X-Nipple 12 ±13,031 Overshot-Btm @±13,040 ' tq 13 13,045' Latch and Receptacle x V14 13,046' 9-5/8"x 4-1/2"TIW Packer&Millout extension,ID of Packer=4.0" MK I 00,415 16 15 13,087 9-5/8"x 7"TIW Liner Hanger ' 16 13,097' 4-1/2"SWS Nip,ID=3.813" . a 17 *+ 17 13,119' 4-1/2"SWS Nip,ID=3.813" ria '7.1 rf V 18 13,130' WLEG,ID=3.958"-Bottom @ 13,131' 'i. 18 '. 19 13,548' 7"26-32 OTIS Perma-Drill Type WD Packer,I0=3.946 <1 . .0 20 13,558' 4-1/2"TDS X Nipple w/plug,I0=3.813 rx tt 9-5/8" a' 21 13,563' 4-1/2"TDS XN Nipple,I0=3.725 4 = 22 13,564' 4-1/2"TPS WLEG-Bottom @ 13,565' " j`Fish:Spinner Cage', PERFORATION DETAIL 7"Markerloint *'_,;* ..1,•,t;8/13/93 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size >. , @13,533' i, ; X19 ±13,325' ±13,354' ±9,988' ±10,012' 29 Future Future 2-7/8" u 20 ±13,384' ±13,388 ±10,037' ±10,040' 4 Future Future 2-7/8" a I 21 Ivishak 13,393' 13,454' 10,045' 10,096' 61 1/24/93 Closed 3-3/8" TOF@13,630 1 6`. 13,394' 13,486' 10,046' 10,123' 92 11/7/90 Closed 3-3/8" 0. Alapah 13,605' 13,628' 10,226' 10,246' 23 6/11/91 Closed 3-3/8" Tag 6/18/91 *# Reference Perf Log:DLL/GR on 10/29/1990 ` GENERAL WELL INFO 7"kiki4 L._*r ' API:50-029-22090-00-00 TD=13,831'(MD)/TD=10,426'(TVD) Initial Completion -11/7/1990 PBTD=13,789'(MD)/PBTD=10,157'(TVD) See Perf Table for Dates Set WF Patch-7/18/04 XX TTP Set-9/7/05 Revised By:TDF 5/4/2016 • i Endicott ASR 13-5/8" BOP w/Jacks 05/05/2016 (t irnrp i4.i,..IJA ii Slips kd.' 'OM 111111k 200 TON JACKING SYSTEM Slips Hydril 13 5/8'15M IN gill litaillak Shaffer �.� :_ - •o j 2 7/8 x 5" VBR Rams 13 5fcgrto 5M Blinds 2 1/16" 5M Kill Valves ")._____ 1 2 1/16" 5M Choke Valves Manual and Manual Manual and HCR lit i i 4 1 .' tr :t I i i r .,,,,,,„ • A N m J to N d m C J J r 0 I l T —�: '—,'— -I- ` I` o • in 0- 1N d L N a e o 0 0 0 0 0 0 0 0 0 0 0 0 0. 0 0 0 0 o 6 0 in 0 in 0 iJ 0 of in c a m m N N r S9l u!83.10j a r Lf U `-I 0 v> E a) a) p In 0 0 0 0 0 0 0 0 U i N (.D 00 ON 1.0 O O a) a) LnO LnO Lc) ,-1 tD r-, O tD o "aN tD Mai L.6 NiiT tf) N 0 u1 II 8 C m u1 c-i to N 00 M C Lf) ,---I Ql O J i rri N N M M tD tD 0 u_ Ar i a--1 t.0O U Ln4- 01 Cr) 0 0 0 0 0 0 0 0 to • -0 M lD Ql N to 00 ri [F vii C r-1 N M ul tD IN 01 O T N 00 (NI" tD O d' 00 M O d U m s-i N Kt tf) N 00 01 s-I XI , 0 Y a) J `"1 r-1 Lr) Uas txA I C * MO (/) O 00000000 0 Co 0 0 0 0 0 0 0 0 0 ul O Ln O Lf) O Ln O U N r-1 t-i N N M M [t LI) v, a ri m 4-. II Q X • 14 RECEIVED Post Office Box 244027 JUL n1 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC J U L 3 0 2015 3800 Centerpoint Drive Suite 100 //�1V�14••i:a ^^CC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 1 AQ '9Y' Anchorage,Anchorage, AK 99501 ` / J -38 Re: Duck Island Unit Well Renaming Request SCANNED AUG 2 3 2016 Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD14 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig • New API_WeilNo l PermitNumberl WellName WellNumber l l WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 500292166200001861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 e50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-468 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/017 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 150029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 150029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 j1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 12022470 DUCK IS UNIT SDI 3-17E/K30 3-17E XHVZE :; Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs-of vadous kinds . Other COMMENTS: Scanned by:, Dianna Vincent Nathan Lowell _ ., Date: 5,,2, 0~_- ,s/~ [] TO RE-SCAN Notes: - Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 F r May 22, 2012 ! SEP 2 4I11w Mr. Jim Regg Alaska Oil and Gas Conservation Commission o f S N -- 333 West 7 Avenue � Anchorage, Alaska 99501 t.09 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, r 0--- 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) Endicott Row 2 Date: 03/28/2012 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 dal END2 -02 / P -18 1860630 50029215680000 15.0 _ 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / Q -16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0 -16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / Q -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2-66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S-17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 e bp ~~. ~,,= ..At ,QO-J2..4 e o , BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 Confidential May 8, 2006 Mr. William Van Dyke Acting Director, Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information April, 2006 Dear Sir or Madam, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for April, 2006. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. ~\) ~n Denis ACT East Subsurface Team Lead JRD/MSB sCANNED JUL 2 5 2007 . ,-.-. . .~. .-..,- .-*" . xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Endicott File e e April, 2006 Production Summary Well Oil NGL Gas GOR Water Cut STB STB MMSCF SCF/STB % 2-38/SN-1 0 0 .000 2-32/SN-3 5530 30 3.778 683 90 Total/ Avg. 5,530 30 3.778 683 90 Sag Delta North Production Summary for April, 2006 April Accepted Well Tests Well Number of Tests 2-38/SN-01 0 2-32/SN-03 2 Operations Summary 2-38/SN-1 shut in pending well intervention. 1-17/SN-2 Plugged and abandon, 1/24/97 JRD/CLP ec: M. S. Sroacha (w/o attachments) C. Ploegstra (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) ~ e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-321SAG DELTA #3 April, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 201 1 134 2,085 0 24.00 309 153 2 187 1 124 2,003 0 23.00 309 154 3 189 1 124 2,095 0 24.00 307 154 4 184 1 119 2,100 0 24.00 296 152 5 178 1 114 2,105 0 24.00 307 153 6 172 1 109 2,111 0 24.00 307 151 7 167 1 104 2,116 0 24.00 312 151 8 169 1 107 2,050 0 24.00 306 151 9 171 1 110 1,984 0 24.00 307 152 10 173 1 112 1,918 0 24.00 308 151 11 175 1 115 1,852 0 24.00 307 151 12 177 1 118 1,787 0 24.00 311 152 13 179 1 121 1,721 0 24.00 307 152 14 181 1 124 1,655 0 24.00 303 152 15 183 1 127 1,589 0 24.00 290 151 16 186 1 129 1,523 0 24.00 289 152 17 188 1 132 1,458 0 24.00 310 153 18 190 1 135 1,392 0 24.00 309 153 19 190 1 135 1,392 0 24.00 308 152 20 190 1 135 1,392 0 24.00 307 152 21 190 1 135 1,392 0 24.00 308 152 22 190 1 135 1,392 0 24.00 306 154 23 190 1 135 1,392 0 24.00 305 153 24 190 1 135 1,392 0 24.00 307 154 25 190 1 135 1,392 0 24.00 309 154 26 190 1 135 1,392 0 24.00 306 155 27 190 1 135 1,392 0 24.00 307 154 28 190 1 135 1,392 0 24.00 305 155 29 190 1 135 1,392 0 24.00 307 154 30 190 1 135 1,392 0 24.00 308 154 31 0 0 0 0 0 0.00 0 0 ~ e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION April,2006 DAY OIL NGL's GAS (mcf) WTR 1 201 1 134 2,085 2 187 1 124 2,003 3 189 1 124 2,095 4 184 1 119 2,100 5 178 1 114 2,105 6 172 1 109 2,111 7 167 1 104 2,116 8 169 1 107 2,050 9 171 1 110 1,984 10 173 1 112 1,918 11 175 1 115 1,852 12 177 1 118 1,787 13 179 1 121 1,721 14 181 1 124 1,655 15 183 1 127 1,589 16 186 1 129 1,523 17 188 1 132 1 ,458 18 190 1 135 1,392 19 190 1 135 1,392 20 190 1 135 1,392 21 190 1 135 1,392 22 190 1 135 1,392 23 190 1 135 1,392 24 190 1 135 1,392 25 190 1 135 1,392 26 190 1 135 1,392 27 190 1 135 1,392 28 190 1 135 1,392 29 190 1 135 1,392 30 190 1 135 1,392 31 0 0 0 0 e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 April, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 0 0 0 0 0 0.00 0 0 2 0 0 0 0 0 0.00 0 0 3 0 0 0 0 0 0.00 0 0 4 0 0 0 0 0 0.00 0 0 5 0 0 0 0 0 0.00 0 0 6 0 0 0 0 0 0.00 0 0 7 0 0 0 0 0 0.00 0 0 8 0 0 0 0 0 0.00 0 0 9 0 0 0 0 0 0.00 0 0 10 0 0 0 0 0 0.00 0 0 11 0 0 0 0 0 0.00 0 0 12 0 0 0 0 0 0.00 0 0 13 0 0 0 0 0 0.00 0 0 14 0 0 0 0 0 0.00 0 0 15 0 0 0 0 0 0.00 0 0 16 0 0 0 0 0 0.00 0 0 17 0 0 0 0 0 0.00 0 0 18 0 0 0 0 0 0.00 0 0 19 0 0 0 0 0 0.00 0 0 20 0 0 0 0 0 0.00 0 0 21 0 0 0 0 0 0.00 0 0 22 0 0 0 0 0 0.00 0 0 23 0 0 0 0 0 0.00 0 0 24 0 0 0 0 0 0.00 0 0 25 0 0 0 0 0 0.00 0 0 26 0 0 0 0 0 0.00 0 0 27 0 0 0 0 0 0.00 0 0 28 0 0 0 0 0 0.00 0 0 29 0 0 0 0 0 0.00 0 0 30 0 0 0 0 0 0.00 0 0 31 0 0 0 0 1 0.00 0 0 FINAL 1.1 1 1 1 . . . 1 Historical Well Tests Report 4/1/2006 - 4/3012006 1 of 1 Endicott, Alaska e bp e BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 Confidential 4/6/2006 ." 'r', """~:t'~¡¡;;;r, ,";'LtJ"'I.' 'Ci. "'L.. -' ..i. Û 'q ( . 0- (~{1 Mr. William Van Dyke Acting Director, Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information March, 2006 Dear Sir or Madam, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for March, 2006. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, ~ '::-----' \ ,Q~\ .~~ ~~. enis ~ ACT East Subsurface Team Lead JRD/MSB xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Endicott File e e ~ March, 2006 Production Summary Well Oil NGL Gas GOR Water Cut STB STB MMSCF SCF/STB % 2-38/SN-1 0 0 .000 2-321SN-3 6756 31 4.810 712 89 Total I Avg. 6,756 31 4.810 712 89 Sag Delta North Production Summary for March, 2006 March Accepted Well Tests Well Number of Tests 2-381SN-01 0 2-321SN-03 2 Operations Summary 2-38/SN-1 shut in pending well intervention. 1-17/SN-2 Plugged and abandon, 1/24/97 JRD/CLP ec: M. S. Broacha (w/o attachments) C. Ploegstra (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION March, 2006 DAY OIL NGL's GAS (mcf) WTR 1 180 1 131 1,527 2 178 1 129 1,533 3 176 1 127 1,539 4 174 1 125 1,545 5 172 1 122 1,550 6 177 1 126 1,578 7 181 1 129 1,605 8 186 1 132 1,632 9 190 1 135 1,659 10 194 1 138 1,686 11 199 1 141 1,714 12 203 1 145 1,741 13 208 1 148 1,768 14 212 1 151 1,795 15 217 1 154 1,822 16 221 1 157 1,850 17 226 1 160 1,877 18 230 1 163 1,904 19 234 1 167 1,931 20 239 1 170 1,958 21 243 1 173 1,986 22 248 1 176 2,013 23 252 1 179 2,040 24 252 1 179 2,040 25 252 1 179 2,040 26 252 1 179 2,040 27 252 1 179 2,040 28 252 1 179 2,040 29 252 1 179 2,040 30 252 1 179 2,040 31 252 1 179 2,040 e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 March, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 0 0 0 0 0 0.00 0 0 2 0 0 0 0 0 0.00 0 0 3 0 0 0 0 0 0.00 0 0 4 0 0 0 0 0 0.00 0 0 5 0 0 0 0 0 0.00 0 0 6 0 0 0 0 0 0.00 0 0 7 0 0 0 0 0 0.00 0 0 8 0 0 0 0 0 0.00 0 0 9 0 0 0 0 0 0.00 0 0 10 0 0 0 0 0 0.00 0 0 11 0 0 0 0 0 0.00 0 0 12 0 0 0 0 0 0.00 0 0 13 0 0 0 0 0 0.00 0 0 14 0 0 0 0 0 0.00 0 0 15 0 0 0 0 0 0.00 0 0 16 0 0 0 0 0 0.00 0 0 17 0 0 0 0 0 0.00 0 0 18 0 0 0 0 0 0.00 0 0 19 0 0 0 0 0 0.00 0 0 20 0 0 0 0 0 0.00 0 0 21 0 0 0 0 0 0.00 0 0 22 0 0 0 0 0 0.00 0 0 23 0 0 0 0 0 0.00 0 0 24 0 0 0 0 0 0.00 0 0 25 0 0 0 0 0 0.00 0 0 26 0 0 0 0 0 0.00 0 0 27 0 0 0 0 0 0.00 0 0 28 0 0 0 0 0 0.00 0 0 29 0 0 0 0 0 0.00 0 0 30 0 0 0 0 0 0.00 0 0 31 0 0 0 0 0 0.00 0 0 FINAL ENDICOTT OIL ALLOCATION FACTORS March 2006 1.200 1.100 fn ... o ~ 1.000 u. c o ;::; ~ 0.900 . o - - <C 0.800 0.700 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day e l.'.~ ·_'nªeri~~~ 1 e bp Well: Well Location: Report Date/Time: Endicott Historical Well Tests Report 3/1/2006 - 3/31/2006 2-32 MPI 4/3/2006 9:08:37AM ._--.._-.....--,.-~ ,v.,.,'. ~/5/200~ .'1 :3Q:OOAM .,.,.....-,~'~"_..'..'.~.,~. LF 4.0 90.00 ....--.....,.,...- _2Z~? BP Exploration ~_.._,_l(j~_ _.____.1~O'1O'_ ..,_____._1~.~~2.. 4.0 0.0841 1,0710 __,^JI~, __.!_~~~2 _..~_".___~J~"~ 104 151 264 141 4,313 4,155 1,882 1,671 Yes _._..~,.,-,- ~-.-_._---._~ -.---.- 711 104 315 151 273 142 _1.!.!22. ~.~998 2:~] ._...!8~ _.-...~-,....~......,~-", ...,..___<o,,,~""_~' ...._~.__..__~....,~.,._ -....... e Page 1 of 1 Endicott, Alaska r bð' . o BP Exploration (Alaska) Inc. Endicott·Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 Confidential Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 . 't' :\'f:~ii'; , '~'2 :¡¿IJ ''4 . RECEIVED FEe 1 5 2006 , ~:.ka Oil &&83 CfJ~. C~ '., Anchørage ")'í' flY: 11:!. ¡¡.,\,). U ~ /T ¡qO- tdq fqa-Ilq 2/9/2006 Sag Delta North Well Testing Information January, 2006 Dear Sir or Madam, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for January, 2006. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, \';\ ; .~ ~ \---"" .\_ "~' \r,l \ ') ~.,-\ D'\-- .'-.. . \. Æ~ JOh~enis ACT East Subsurface Team Lead JRD/MSB xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Endicott File . . January, 2006 Production Summary Well Oil NGL Gas GOR Water Cut STB STB MMSCF SCFISTB % 2-38/SN-1 0 0 .000 2-321SN-3 5095 31 3.497 686 90 Total/ Avg. 5,095 31 3.497 686 90 Sag Delta North Production Summary for January, 2006 January Accepted Well Tests Well Number of Tests 2-38/SN-01 0 2-321SN-03 2 Operations Summary 2-38/SN-1 shut in pending well intervention. 1-17/SN-2 Plugged and abandon, 1/24/97 JRD/CLP ec: M. S. Broacha (w/o attachments) C. Ploegstra (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) . . BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION January, 2006 DAY OIL NGL's GAS (mcf) WTR 1 134 1 95 1,536 2 136 1 96 1,533 3 137 1 98 1,530 4 139 1 99 1,526 5 141 1 100 1,523 6 142 1 101 1,520 7 144 1 102 1,517 8 145 1 103 1,514 9 147 1 104 1,510 10 149 1 106 1,507 11 150 1 107 1,504 12 152 1 108 1,501 13 154 1 109 1 ,498 14 155 1 110 1 ,494 15 157 1 111 1,491 16 158 1 112 1 ,488 17 160 1 113 1 ,485 18 162 1 115 1 ,482 19 163 1 116 1,478 20 165 1 117 1,475 21 167 1 118 1,472 22 168 1 119 1 ,469 23 170 1 120 1,465 24 172 1 121 1 ,462 25 173 1 123 1,459 26 175 1 124 1 ,456 27 216 1 130 1 ,450 28 216 1 130 1 ,450 29 216 1 130 1 ,450 30 216 1 130 1 ,450 31 216 1 130 1 ,450 :'~;!9T;~;':·.';i:·;~,9.íi,~.i:.:·:.:.. :.:/ '.~ài':;~)::·:1(!:;'::·l;;\;.~;~9l:·:;:;t:-.::..-·:·:;j¡,j:j§;'E?~)::'Y;i, ". . . BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 January, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 0 0 0 0 0 0.00 0 0 2 0 0 0 0 0 0.00 0 0 3 0 0 0 0 0 0.00 0 0 4 0 0 0 0 0 0.00 0 0 5 0 0 0 0 0 0.00 0 0 6 0 0 0 0 0 0.00 0 0 7 0 0 0 0 0 0.00 0 0 8 0 0 0 0 0 0.00 0 0 9 0 0 0 0 0 0.00 0 0 10 0 0 0 0 0 0.00 0 0 11 0 0 0 0 0 0.00 0 0 12 0 0 0 0 0 0.00 0 0 13 0 0 0 0 0 0.00 0 0 14 0 0 0 0 0 0.00 0 0 15 0 0 0 0 0 0.00 0 0 16 0 0 0 0 0 0.00 0 0 17 0 0 0 0 0 0.00 0 0 18 0 0 0 0 0 0.00 0 0 19 0 0 0 0 0 0.00 0 0 20 0 0 0 0 0 0.00 0 0 21 0 0 0 0 0 0.00 0 0 22 0 0 0 0 0 0.00 0 0 23 0 0 0 0 0 0.00 0 0 24 0 0 0 0 0 0.00 0 0 25 0 0 0 0 0 0.00 0 0 26 0 0 0 0 0 0.00 0 0 27 0 0 0 0 0 0.00 0 0 28 0 0 0 0 0 0.00 0 0 29 0 0 0 0 0 0.00 0 0 30 0 0 0 0 0 0.00 0 0 31 0 0 0 0 1 0.00 0 0 . . BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-321SAG DELTA #3 January, 2006 OIL NGL GAS WTR LD HRS PSIG DEGF 1 134 1 95 1,536 0 24.00 308 152 2 136 1 96 1,533 0 24.00 309 153 3 137 1 98 1,530 0 24.00 310 152 4 139 1 99 1,526 0 24.00 311 152 5 141 1 100 1,523 0 24.00 307 152 6 142 1 101 1,520 0 24.00 316 153 7 144 1 102 1,517 0 24.00 310 152 8 145 1 103 1,514 0 24.00 310 152 9 147 1 104 1,510 0 24.00 311 152 10 149 1 106 1,507 0 24.00 306 152 11 150 1 107 1,504 0 24.00 311 152 12 152 1 108 1,501 0 24.00 312 152 13 154 1 109 1 ,498 0 24.00 309 151 14 155 1 110 1 ,494 0 24.00 310 152 15 157 1 111 1,491 0 24.00 308 152 16 158 1 112 1 ,488 0 24.00 312 151 17 160 1 113 1 ,485 0 24.00 304 151 18 162 1 115 1 ,482 0 24.00 311 151 19 163 1 116 1,478 0 24.00 312 151 20 165 1 117 1,475 0 24.00 310 151 21 167 1 118 1,472 0 24.00 311 151 22 168 1 119 1 ,469 0 24.00 313 151 23 170 1 120 1,465 0 24.00 312 151 24 172 1 121 1,462 0 24.00 312 151 25 173 1 123 1,459 0 24.00 311 151 26 175 1 124 1 ,456 0 24.00 314 151 27 216 1 130 1 ,450 0 24.00 314 152 28 216 1 130 1 ,450 0 24.00 304 152 29 216 1 130 1 ,450 0 24.00 312 153 30 216 1 130 1 ,450 0 24.00 308 152 31 216 1 130 1 ,450 0 24.00 314 152 "t()j'I\~;]~'·5~~::.:)-;;~1-;·'::}:.f¡~~1:!"':,:i:;:~¡':I~>:;::;:Ö,-.,~::·~iø~qp 1 1 1 3 5 7 9 11 13 15 17 19 21 õ Endicott Historical Well Tests Report 1/1/2006 - 1/31/2006 Well: 2-32 Well Location: MPI Report Date/T"lllr:Jt 2/9/2006 9:34:49AM ;fJ~¡~~-~;::";::'" ';~~~"~.:~.;:.!,;'":.'~. .:,:,::, ,:.", .....~. .... ,.:."..,,"",'.......;...,,', - ....~:~; ..:~- ~~:: Solution Gas FactOr' :.Oil: ... '. .$h~nicag. . Fac=tor c' . Separator Gross Fluid Rate @60 F (BPD) Water Cut Percent (Lab) (%) True Net Oil Rate @60F (BOPD) True Net Water Rate (BWPD) Corrected Gross Fluid Rate @60 F (BPD) True Formation Gas·Oil Ratio (SCF/STB) Choke Wellhead Wellhead Position Pressure Temp, (Beans) (PSIG) (F) Separator Separator Pressure Temp, (PSIG) (F) Separator Gas Rate (MSCFD) Lift Gas Rate (MSCFD) Total Gas Well Liquid Casinr Ratio PressL (SCF/BBL) (PSIG) 1127t2006 5:30:0oPM HF 4.0 .4.0 0.0841 1,0710 Yes 1,681 87,05 216 1,450 1,666 603 104 314 153 269 144 4,129 4,017 2,479 1,647 . ~ ' '2:00:00PM 1J2612~ HF 4.0 4.0 0.0841 1.0710 Yes 1,643 89,28 175 1,456 1,631 708 104 320 151 268 141 4,093 3,984 2,510 1,650 . BP Exploration Page 1 of 1 Endicott, Alaska b~ e o BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 Confidential 1/12/2006 RE(~EIVED JAN 2 0 2006 Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 /C¡O-llq XlqO-/~~ AJDska Oil ¿~ Gas Com;. Commission Anchorage Sag Delta North Well Testing Information December, 2005 Dear Sir or Madam, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for December, 2005. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, \ .r,,~\~ )~--&~ \:':' L\- CJ~n Denis ACT East Subsurface Team Lead JRD/MSB r , xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Endicott File e e December, 2005 Production Summary Well Oil NGL Gas GOR Water Cut STB STB MMSCF SCF/STB % 2-38/SN-1 0 0 .000 2-32/SN-3 6233 30 4.531 727 87 Total I Avg. 6,233 30 4.531 727 87 Sag Delta North Production Summary for December, 2005 December Acce Jted Well Tests Well Number of Tests 2-38/SN-01 0 2-32/SN-03 2 Operations Summary 2-38/SN-1 shut in pending well intervention. 1-17/SN-2 Plugged and abandon, 1/24/97 JRD/CLP ec: M. S. Broacha (w/o attachments) C. Ploegstra (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION December, 2005 DAY OIL NGL's GAS (mcf) WTR 1 199 1 152 1,319 2 202 1 154 1,322 3 204 1 155 1,325 4 207 1 156 1,328 5 210 1 158 1,330 6 213 1 159 1,333 7 216 1 160 1,336 8 218 1 162 1,339 9 184 1 136 1,118 10 224 1 165 1,344 11 227 1 166 1,347 12 229 1 167 1,350 13 232 1 169 1,352 14 235 1 170 1,355 15 238 1 171 1,358 16 241 1 173 1,361 17 243 1 174 1,363 18 246 1 175 1,366 19 249 1 177 1,369 20 252 1 178 1,372 21 234 1 166 1,397 22 216 1 153 1,423 23 198 1 140 1 ,449 24 180 1 128 1,475 25 162 1 115 1,501 26 144 1 102 1,526 27 126 1 90 1,552 28 126 1 90 1,552 29 126 1 90 1,552 30 126 0 90 1,552 31 126 1 90 1,552 . .' TOT A~;.:' 'Z6i233'<';'·',' 30)'~;·;.::~T:.!1:'4,53f;:~þ ·;;:'r~3~219·';~~ú ." 'J :':-:f-,. 1 e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DEL T A #1 December, 2005 OIL NGL GAS WTR LD HRS PSIG DEGF 1 0 0 0 0 0 0.00 0 0 2 0 0 0 0 0 0.00 0 0 3 0 0 0 0 0 0.00 0 0 4 0 0 0 0 0 0.00 0 0 5 0 0 0 0 0 0.00 0 0 6 0 0 0 0 0 0.00 0 0 7 0 0 0 0 0 0.00 0 0 8 0 0 0 0 0 0.00 0 0 9 0 0 0 0 0 0.00 0 0 10 0 0 0 0 0 0.00 0 0 11 0 0 0 0 0 0.00 0 0 12 0 0 0 0 0 0.00 0 0 13 0 0 0 0 0 0.00 0 0 14 0 0 0 0 0 0.00 0 0 15 0 0 0 0 0 0.00 0 0 16 0 0 0 0 0 0.00 0 0 17 0 0 0 0 0 0.00 0 0 18 0 0 0 0 0 0.00 0 0 19 0 0 0 0 0 0.00 0 0 20 0 0 0 0 0 0.00 0 0 21 0 0 0 0 0 0.00 0 0 22 0 0 0 0 0 0.00 0 0 23 0 0 0 0 0 0.00 0 0 24 0 0 0 0 0 0.00 0 0 25 0 0 0 0 0 0.00 0 0 26 0 0 0 0 0 0.00 0 0 27 0 0 0 0 0 0.00 0 0 28 0 0 0 0 0 0.00 0 0 29 0 0 0 0 0 0.00 0 0 30 0 0 0 0 0 0.00 0 0 31 0 0 0 0 1 0.00 0 0 2 e e BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-32/SAG DEL T A #3 December, 2005 OIL NGL GAS WTR LD HRS PSIG DEGF 1 199 1 152 1,319 0 24.00 312 152 2 202 1 154 1,322 0 24.00 315 151 3 204 1 155 1,325 0 24.00 313 151 4 207 1 156 1,328 0 24.00 312 152 5 210 1 158 1,330 0 24.00 307 152 6 213 1 159 1,333 0 24.00 309 151 7 216 1 160 1,336 0 24.00 311 152 8 218 1 162 1,339 0 24.00 308 152 9 184 1 136 1,118 0 20.00 312 144 10 224 1 165 1,344 0 24.00 312 153 11 227 1 166 1,347 0 24.00 310 152 12 229 1 167 1,350 0 24.00 313 152 13 232 1 169 1,352 0 24.00 310 152 14 235 1 170 1,355 0 24.00 312 151 15 238 1 171 1,358 0 24.00 306 151 16 241 1 173 1,361 0 24.00 312 153 17 243 1 174 1,363 0 24.00 306 152 18 246 1 175 1,366 0 24.00 311 152 19 249 1 177 1,369 0 24.00 314 152 20 252 1 178 1,372 0 24.00 313 151 21 234 1 166 1,397 0 24.00 310 151 22 216 1 153 1,423 0 24.00 310 151 23 198 1 140 1 ,449 0 24.00 313 151 24 180 1 128 1,475 0 24.00 308 152 25 162 1 115 1,501 0 24.00 311 152 26 144 1 102 1,526 0 24.00 309 152 27 126 1 90 1,552 0 24.00 313 152 28 126 1 90 1,552 0 24.00 307 151 29 126 1 90 1,552 0 24.00 309 152 30 126 0 90 1,552 0 24.00 311 152 31 126 1 90 1,552 0 24.00 310 152 TOTALi';':6,2ª3.i:, 130Y; 4531'·. 43219:'/ ,0 :;-;.740:0Q¡ . oJ '" "-""',, ..' 3 1.100 1.000 en ~ o .... U ftS LL S 0.900 +:: ftS u o - <C 0.800 FINAL ENDICOTT OIL ALLOCATION FACTORS December 2005 0.700 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day e 1--.- Series 1 I e bp ..-+~11. .. .. ... .. ... ... ~... Endicott Historical Well Tests Report 12/1/2005·12/31/2005 2-32 MPI 1/12/2006 1: 11 :02PM Test Approved 272 143 4,054 2,463 1.642 12119/2005 10:00:00PM HF 316 152 3.835 2.459 1,645 112/1112005 10:15:ooPM HF I (338) I 104 319 152 4,099 2.395 1.648 e BP Exploration Page 1 of 1 Endicott. Alaska . . STATE OF ALASKA ,-.... Ö 7- S' s J 5/ 4-- ALASKA OIL AND GAS CONSERVATION COMMISSION .k»ECEIVED APPLICATION FOR SUNDRY APPROVAl' 20 AAC 25.280 MAY 0 4 2004 '" -~ 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 ~ Suspend 0 RepairWell 00 / Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.00 KB 8. Property Designation: ADL.312828 StratigraphicD Service D 9. Well Name and Number: 2-38/SN-01 / 10. Field/Pool(s): Endicott Field 1 Sag Delta North Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 10426.1 13745 10294.8 Length Size MD TVD top bottom top 40 111 13087 13831 13550 13563 38 13349 39 2&41 I Tubing Size: 4.5 " 12.6 # Packers and SSSV MD (ft): 11. Total Depth MD (ft): 13831 Casing Conductor 71 20" 91.5# H-40 Liner 744 7" 29# NT95HS Liner 13 4-1/2" 12.6# L-80 Production 13311 9-5/8" 47# NT95HS Suñace 2502 13-3/8" 68# NT80CYHE Perforation Depth MD (ft): Perforation Depth TVD (ft): All below plugs All below plugs Packers and SSSV Type: 4-1/2" Otis WD Packer 4-112" TIW Packer 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program ŒI B/jetch 0 M~2004 Date: Operation Shutdown D Plug Perforations D Perforate New Pool 0 4. Current Well Class: PerforateD Alaska\9tt,&rGas Øøn8lé(Gt~tiii StimulateD Time Extensior(fi]:horage OtherD Re-enter Suspended Well 0 5. Permit to DYiIi Number: 190.1290 / Development ŒJ Exploratory D 6. API Number / 50.029-22090-00-00 Plugs (md): Junk (md): ;ee Attachmen 13524 Burst Collapse 40.0 9795.1 10178.0 38.0 39.0 bottom 111.0 1490 10426.1 9690 10189.2 8430 10007.9 8150 2390.6 5020 I Tubing Grade: ITUbing MD (ft): L-80 36- 13131 470 7820 7500 5080 2270 13550 13046 13. Well Class after proposed work: ExploratoryD DevelopmentŒl Service 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~~~I~ 4 S;goatum y~- 'I "/l' / JØ1 15. Well Status afterproposed work: Oil ŒI / GasD PluggedD AbandonedD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. Contact John McMullen Title Phone Sr Production Engineer 564.4711 5/4/04 Commission Use Only l Sundry Number: V ~;?o¥A/6g-- Conditions of approval: Notify Commission so that a representative may witness Other: cT1 Subseque FOuReq~. e: l {7 Approved' (, V Form 10-403 Revised 12/2003 BOP TestD ~ 404 Mechanciallntegrity Test D Location Clearance D BY ORDER OF -<""' /<"' ;:';1/ THE COMMISSION Date: IjtJr ..... BFL .. 0-6 20ß\ ORIGINAL SUBMIT IN DUPLICATE ... '" r-\ r'\ Doug Cismoski/ John Smart GPB Wells Operations Supervisors To: From: Ross Warner Date: May 3, 2004 Subject: Endicott 2-38/SN-01 TubinQ Patch CostCode:SDFACOPER lOR: 150 bopd Estimated cost: $53M Summary: 1 S 2 0 3 E 4 0 5 E 6 S Well data: Test Data: Max Deviation: BHP: Min.ID: Fish: Last TO tag: Pull XX and PX plugs. Set reducing Nipple. Set PX plug in reducing nipple. Change out GL Valve @ station #7 CMIT T X IA. (verify plug is holding) Set patch over leak at 12,825' MD /" / MIT Tubing wI e-line rigged up. If pass. AD e-line / Fail. Run leak detection log. Pumping down tbg., returns IA Pull PX plug in reducing nipple 3/01/04 Bopd 159, Bwpd 7797, GOR 623, WHP 337 psi WHT 197 F, GLR 4.093 mmcfpd. 56 deg at 5,022 MD -4650 psi @ -10,000' 88 3.813 ID, SSSV landing nipple, SWS nipple 13,028', 13,097', 13,118' MD. Spinner cage @ top of fill 13,533' MD. Set PX plug at SWS nipple @ 13,118' MD 3/2/04 Last DH Ops: 3/21/04 Set 4-1/2" XX plug in X-nipple at 13028' Two plugs as of this date. Latest H2S value: 100 ppm on 3/01/04. Objective: Patch tubing leak and replace GL V at Station #7 / BackClround: This well is a low PI, high water cut, gas-lifted well. During routine operational check for the 2004-drilling season it was noted this well had mechanical integrity problems. It was not possible to obtain combination tubing by inner annulus MIT with a plug set in the lowest tubing nipple. A second plug was set in the upper / nipple, 13,028'MD, and a successful CMIT Tubing X IA was performed. Leak detection logging identified a tubing leak at 12,825' MD and a leak at GLM #7 that is at 5,125' MD. The following procedure will attempt to rectify these problems. Procedure: 1 . Confirm most recent H2S measurement. 2. Rig up slickline and pull 4-1/2" XXX plug from SWS nipple at 13,028' MD. Pull 4-1/2" PX plug from SWS nipple at 13,118' MD 3. Set 4-1/2" X 2-7/8" nipple reducer, with a 2.313" X nipple, in the 4-1/2" SWS nipple at 13,028' MD. Set PX plug in nipple reducer. 4. Change out gas lift valve in Station #7. / 5. Perform CMIT, Tubing X Inner Annulus. This is to verify that plug is holding. / 6. Make drift run with 3.771" 0.0. gauge, provided by Weatherford, to 12,900' MD. Note: Before the next operations commences discussed with Weatherford the need to have a pump truck on location to assist in getting the seal assembly into the lower packer. Circulation could be maintained by pumping down the tubing and taking returns through the leak. I leave this decision to the Field Group. The final product resulting from these operations will be a patch set across the leak at 12,825' MD with the middle of the upper packer element at 12, 834' and the middle of the lower packer element at 12,834', or twenty (20') between the upper and lower packers. Reference log is leak Detect Log dated 3/9/04. , -- ... r--- r'\ Also: This patch equipment is in Vernal, Utah so Weatherford needs to be notified that the equipment is needed. Delivery time will take about two weeks after the order is made. Please ensure Weatherford is informed. Their numbers are: North Slope: 659-2356. Anchorage: 561-1632. 7. Rig up e-line with GR/CCL, setting tool and the lower 4-1/2" Arrow-Pac Dual Bore Packer. A Weatherford Representative will be on site for these operations. Tie into the Leak Detect Log run 3/9/04 and set the packer such that the middle of the /' element is at 12,834' MD. POH. 8. Pick up the Setting Tool, upper packer with spacer pipe and RIH. Follow the recommended Weatherford procedure for stabbing into the lower packer and then setting the upper packer, middle element should be at 12,814' MD. The tubing patch specifications are: Min. 10 = 2.5" Spacer Pipe = 2.414" Max. 00 = 3.771" Upper and lower packers. Differential pressure rating = 7,500 PSI 9. MIT Tubing with e-line still rigged up. If test passes release e-line. If it does not pass run another leak detection log by pumping down tubing and taking returns up the inner annulus. 10. Pull PX plug in reducing nipple after discussing job with John McMullen. 11.lnstall SSSV after putting well on production. If there are any questions please contact: John McMullen: 564-4711 (W), 345-5260 (H), 529-5818 (cell) cc: Well file Ken Farnstrom John Denis Jim Ambrose Programs Endicott Production Coordinator M. Millholland Katie Nitzberg Mark Vandergon G Anc Well Work 3 .. ., .. r---. ~ RT. ELEV = 54.5' B.F. ELEV = 15.3' MAX DEV. = 55:42 5000 M.D. TREE: 4-1/16" 15000 psi IMcEvoy / Baker Actuator WELLHEAD: 13-518" 15000 psi 1 FMC (CCL) SAFETY NOTES: LDL ON 03/10/04ID'D LEAKS @ GLM #7 & 12,825' 0 . SSSV LANDING NIPPLE I 1553' OTIS (3.813" 1.0.) W/SSSV IN MIN. I.D. 2" 13-318", 68#/ft, NT80 CYHE BUTT CSG 12541' . Á . 4-1/2", 12.6#1ft, L-80, TDS . GLM's (Otis), (1-1/2" RA Latch) No. MD-BKB TVD-SS 7 5,125 3,957 6 8,438 6,395 5 10,045 7,556 4 10,980 8,243 3 11,798 8,815 2 12,536 9,327 1 12,999 9,671 9-5/8", 47#1ft NT80S XO to NT95HS ~ I 11041' I . -.... / 4-1/2" "SWS" NIPPLE 113028' (Parker) (3.813" ID) ~ Right hand release 1 13045' k'"" - safety jnt C;::-..... . 9-5/8" PACKER 1 13046' 2S. TIW (4.00" !.D.) ~ 4.1/2", 12.6#1ft L-80, TAILPIPE - -4--- 4-112" "SWS" NIPPLE I ~ (Parker) (3.813" ID) 13097' . 4-1/2" "SWS" NIPPLE I ' (Parker) (3.813" ID) 13118' 4-1/2"WLEG 1 13131' ...~ I 13087' HTTP(03/02/04) TOP OF 7" TIW LINER 113087' I ~ 9-518", 47#/ft, NT95HS, NSCC I 13349' I I' a I PERFORATING SUMMARY Ref. Log: DLL-GR (10/29190) 3 3/8" 3 3/8" 6 6 INTERVAL 13394' - 13486' 13605' - 13628' STATUS OPEN OPEN ~ .-- MARKER I 13533' ~SPINNERCAGE (1- ~.--TOPOFFILL 13525WLMD ~ . 7" OTIS 'WD" I 13550' F""':'i\\! 4-1/2" "X" NIPPLE 1 13557' ""1Þ1' (Otis) (3.813" ID) . 4-1/2" "XN" NIPPLE I 13561' (OtiS) (3.725" ID) I '. 4.1/2" WLEG 13563' SIZE SPF ~ PBTD 7", 29#/ft, NT95HS TKC 113745' 113831' >^^^/\ ) x XX X Date By Comments ENDICOTT WELL: 2.38/ SN-01 10/4190 PGS PROPOSED COMPLETION API NO. 50.029.22090 11/20/90 JLH IN rrlAL COMPLETION DIAGRAM 712191 JLH ADD 3/11104 JLA/TLH TTP SET BP EXPLORATION (ALASKA), INC bp BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-661 11/1/2002 Mr. Ken Boyd, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information Dr. Mr Boyd, October, 2002 In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for October, 2002. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, Mark C. Weggeland Endicott Engineering/Development Team Lead MCW/BJM XC: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission RECEIVED NOV 0 2002 Alaska Oil & GaB ~O[IB, ~ Anchorage Sag Delta North ProductiOn Summary for October, 2002 October, 2002 Production Summary Well Oil NGL Gas GOR Water Cut STB STB MMSCF SCF/STB % 2-38/SN-1 5278 66 3.311 627 96 2-32/SN-3 3607 12 2.257 626 85 Total ! Avg. 8,885 39 5.568 627 95 October Accepted Well Tests Well 2-38/SN-01 2-32/SN~03 Number of Tests operations Summary 2-38/SN-1 Routine production. 1-17/SN-2 Plugged and abandon, 1/24/97 2-32/SN-3 Routine production. IVlCW / JGA ec: J. G. Ambrose (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) BP EXPLORATION (ALASKA)INC. ' WELL PRODUCTION WELL Z-3Z/SAG DELTA #3 October, 2002 OIL 1 125 2 126 3 126 4 127 5 128 6 128 7 42 8 0 9 123 10 131 11 131 12 132 13 133 14 133 15 134 16 134 17 134 18 134 19 134 20 99 21 12 22 134 23 63 24 101 25 134 26 134 27 139 28 134 29 134 30 134 31 134 NGL GAS VVTR LD HRS . 1. 1. 1. 1. 1. O. O. O. 1. 1. 1. 1. 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1. 78 802 0 24.00 79 799 0 24.00 79 796 0 24.00 79 793 0 24.00 80 790 0 24.00 80 786 0 24.00 26 257 0 7.87 0 0 0 0.00 77 737 0 22.75 82 774 0 24.00 82 771 0 24.00 83 768 0 24.00. 83 764 0 24.00 83 761 0 24.00 84 758 0 24.00 84 758 0 24.00 84 758 0 24.00 84 758 0 24.00 84 758 0 24.00 62 561 0 17.77 7 67 0 2.1 3 84 758 0 24.00 39 356 0 11.27 63 572 0 18.12 84 758 0 24.00 84 758 0 24.00 87 790- 0 25.00 84 758 0 24.00 84 758 0 24.00 84 758 0 24,00 84 758 0 24.00 PSIG 283 284 285 284 263 260 260 0 315 260 258 260 262 260 273 259 264 272 279 271 373 295 353 298 306 286 288 290 290 289 289 DEGF 125 125 125 125 124 123 122 0 120 124 124 124 125 124 124 125 126 125 124 125 116 125 120 127 129 126 127 128 128 128 129 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 October, 2002 OIL NGL GAS W-I'R LD HR$ 1 333 2. 209 7,099 0 '24.00 2 328 2. 206 7,1 05 0 24.00 3 324 2. 20.3 7,111 0 24.00 4 319 2. 200 7,117 0 24.00 5 80 1. 50 1,819 0 6.13 6 0 O. 0 0 0 0.00 7 0 0. 0 0 0 0.00 8 0 0. 0 0 - 0 0.00 9 0 0. 0 0 0 0.00 10 0 O. 0 0 0 0.00 11 0 O. 0 0 0 0.00 12 0 O. 0 0 0 0.00 1 3 0 O. 0 0 0 0.00 1 4 0 O. 0 0 0 0.00 1 5 0 O. 0 0 0 0.00 16 237 2. 149 6,418 0 21.43 17 261 2. 164 7,193 0 24.00 18 257 2. 161 7,199 0 24.00 19 252 2. 158 7,205 0 24.00 20 248 2. 155 7,211 0 24.00 21 243 2. 153 7,217 0 24.00 22 239 2. 150 7,223 0 24.00 23 144 1. 90 4,428 0 14.70 24 230 2. 144 7,235 0 24.00 25 226 2. 141 7,241 0 24.00 26 221 2. 139' 7,247 0 24.00 27 226 1. 142 7,555 0 25.00 28 241 1. 151 7,229 0 24.00 29 265 1. 167 7,205 0 24.00 30 290 1. 182 7,182 0 24.00 31 314 1. 197 7,1 58 1 24.00 PSIG 307 308 308 308 289 0 0 0 0 0 0 0 0 0 0 296 289 298 304 299 307 310 394 308 311 311 314 311 310 312 312 DEGF 186 186 186 186 186 0 0 0 0 0 0 0 0 0 0 174 182 183 184 184 185 185 179 184 185 185 186 186 186 186 186 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION October, 2002 DAY OIL NGL's GAS (mCr) WTR 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 458 3. 287 7,901 454 3. 285 7,904 450 3. 282 7,907 .446 3. 279 7,909 208 2. 130 2,609 128 1. 80 786 42 O. 26 257 0 O. 0 0 123 O. 77 737 131 1. 82 774 131 1. 82 771 132 1. 83 768 133 1. 83 764 133 1. 83 761 134 1. 84 758 371 3. 233 7,176 395 3. 248 7,952 391 3. 245 7,958 386 3. 242 7,963 347 3. 217 7,772 255 3. 160 7,284 373 3. 234 7,981 207 2. 129 4,784 331 3. 207 7,807 360 3. 225 7,999 355 3. 223 8,005 365 2. 229 8,344 375 2. 235 7,987 399 2. 251 7,963 424 2. 266 7,940 448 2. 281 7,916 NED OCT 16, 2002 REPORT: 201 4:17 AN MPI 2-32 TEST · 4 TEST FACILITY : NPI LO FLOH ENDICOTT HELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 10/15/ 2 9/28/ 2 3:02 7:02 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 901 85.0 I .07 0.08 86.8 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET HATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 134 758 892 84 626 123 812 935 77 626 CHOKE POSITION NELL-HEAD PRESSURE HELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 104 28O 124 27.30 104 298 125 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8975 90.06 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 265 117 2619 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3482 2936 1025 2494 2749 1051 THU OCT 31, 2002 REPORT: 201 5:32 PM 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS SEPARATOR GROSS FLUID RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 10/31/ 2 10/27/ 2 12:10 4:10 4.0 4.0 7494 95.8 1.07 0.08 97.1 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 314 7158 7472 197 628 217 7253 7469 136 626 CHOKE POSITION NELL-HEAD PRESSURE HELL-HEAD TEMPERATURE OIL API GRAVITY FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE 64THS PSIG DEGF DEG API PBD PERCENT 176 325 186 25.60 8961 16.62 176 322 185 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 280 178 3187 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 299O 427 1277 3064 428 1273 1.2O0 - FINAL ENDICOTT OIL ALLOCATION FACTORS October 2002 1.150 ............................................ .......................................... ......... 1.100 o 1.050 1.000 0 950 ~0 850 0 800 ........... 0.750 0.700 I I , i I , , ... I. , i ..--', , i , .. ~... 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day bp BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P.O. Box 19661Z Anchorage, Alaska 99519-661Z 0 9/$/2002 Mr. Ken Boyd, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information - August, 2002 Dr. Mr Boyd, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for August, 2_002. The attached information includes cumulative produced volumes, a summaQ of the operational activities and a complete set of well test results used for production allocation. Sincerely, Mark C. Weggeland Endicott Engineering/Development Team Lead MCW/BJM XC: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Sag Delta North Production Summary for August, 200Z i August, 2002 Production Summary Weli Oil NGL Gas GOR Water Cut STB STB MMSCF SCFISTB % 2-38/SN-1 9017 66 6.456 716 96 2-32/SN-3 5591 48 4.269 764 80 Total / Avg. 1.4,608 39 10.725 734 94 i August Accepted Well Tests Well Number of Tests. Z-38/SN-01 Z 2-32/SN-03 Z Operations Summary 2-38/SN-1 Routine production. 1-1 7/SN-Z Plugged and abandon, 1/24/97 2-32/SN-3 Routine production. mcw / BJm ec: B. McNerlin (w/o attachments) iNED OCT 0.4 2002 cc: Sag File 35.02 "State Reports" (w/attachments) BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION August, 2002 DAY OIL NGL's GAS (mcf) WTR I 284 1. 190 2 471 1. 308 3 462 1. 304 4 454 1. 300 5 362 1. 237 6 451 1. 304 7 459 1. 313 8 467 1. 321 9 474 1. 330 10 481 1. 338 11 489 1. 346 12 496 1. 355 13 503 1. 363 14 511 1. 372 15 518 1. 380 16 525 2. 388 17 517 2. 385 18 509 2. 382 19 500 2. 378 20 492 2. 375 21 484 2. 371 22 475 2. 368 23 467 2. 365 24 471 1. 370 25 471 1. 370 26 471 1. 370 27 471 1. 370 28 460 1. 362 29 471 1. 370 30 471 1. 370 3,100 7,752 7,787 7,822 7,56O 7,857 7,867 7,872 7,878 7,883 7,888 7,894. 7,899 7,904 7 910 7 915 7 903 7.891 7 880 7 868 7 856 7 844 7 833 7 831 7 831 7,831 7,831 7,593 7,831 7,831 31 471 1. 370 7,831 SCANNED OCT 2002 ,.~ .... ~.. --~ .-..%~::: ~.~*-....-~....,. .~ . -* .~.....~. *.* .~-~ .... ~ ...... BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 August, 2002 OIL NGL GAS WTR LD HRS 1 104 1. 65 2 288 3. 180 3 276 3. 173 4 264 2. 165 5 252 3. 158 6 256 2. 163 7 260 2. 168 8 264 1. 173 9 268 2. 178 10 272 2. 183 11 276 2. 188 12 280 2. 193 13 284 2. 198 14 288 2. 203 15 292 2. 208 16 296 2. 213 17 300 2. 218 18 304 2. 223 19 308 2. 228 20 312 2. 233 21 316 2. 238 22 320 2. 243 23 324 2. 248 24 328 3. 253 25 328 3. 253 26 328 3. 253 27 328 2. 253 28 317 2. 245 29 328 2. 253 30 328 2. 253 31 328 2. 253 2,441 7,086 7,114 7,141 7,169 7,167 7,165 7,163 7,161 7,159 7,157 7,155 7,153 7 151 7 149 7 147 7 145 7 143 7 141 7 140 7 138 7 136 7 134 7 132 7 132 7,132 7,132 6,894 7,132 7,132 7,132 0 8.30 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 24.00 0 23.20 0 24.00 0 24.00 1 24.00 PSIG DEGF 306 166 288 181 287 184 286 185 296 185 287 186 286 186 308 186 310 186 310 186 311 186 311 186 311 186 306 186 304 186 307 186 307 186 306 186 307 186 307 186 308 186 308 186 309 186 316 186 307 186 306 187 308 186 332 186 309 186 306 187 306 187 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-32/SAG DELTA #3 August, 2002 OIL NGL GAS WTR LD HRS PSIG DEGF i I 180 I 125 658 0 24.00 275 122 2 183 I 128 666 0 24.00 269 128 3 186 I 131 673 0 24.00 268 129 4 190 I 135 680 0 24.00 268 129 5 110 2 79 392 0 13.67 270 126 6 195 2 141 691 0 23.85 279 128 7 199 2 145 702 0 24.00 269 128 8 203 2 148 709 0 24.00 291 129 9 206 2 152 717 0 24.00 287 127 10 209 2 155 724 0 24.00 287 126 11 213 2 158 731 0 24.00 288 127 12 216 2 162 739 0 24.00 287 127 13 219 2 165 746 0 24.00 286 127 14 223 2 169 753 0 24.00 281 128 15 226 2 172 760 0 24.00 282 127 16 229 2 175 768 0 24.00 286 127 17 217 2 167 758 0 24.00 283 127 18 205 2 159 748 0 24.00 282 126 19 192 2 150 738 0 24.00 282 127 20 180 2 142 728 0 24.00 282 127 21 168 2 133 719 0 24.00 283 126 22 155 I 125 709 0 24.00 283 126 23 143 I 117 699 0 24.00 287 126 24 143 1 117 699 0 24.00 285 126 25 143 I 117 699 0 24.00 282 126 26 143 I 117 699 0 24.00 281 127 27 143 I 117 699 0 24.00 284 127 28 143 I 117 699 0 24.00 282. 127 29 143 I 117 699 0 24.00 284 127 30 143 I 117 699 0 24.00 281 126 31 143 I 117 699 0 24.00 281 126 CANNED OCT 0 FRI AUG 16, 2002 REPORT: 201 9:31 PM NPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLOW ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 8/16/ 2 7/22/ 2 I :25 5:25 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD MATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 1013 77.0 I .07 0.08 80.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 229 767 997 176 766 146 585 732 91 621 CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 104 296 127 27.30 104 297 130 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8971 88.89 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 275 114 3241 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3065 3252 1032 3669_ 5138 1077 SAT AUG 24, 2002 3'49 AM REPORT: 201 MPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLOW ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 8/23/ 2 8/16/ 2 9:47 I :47 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD WATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 852 83.0 1.07 0.08 77.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET NATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 143 699 842 117 815 229 767 997 176 766 CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEC API 104 291 127 27..30 104 296 127 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8972 90.62 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 276 117 3291 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3174 3065 3908 3252-. 1042 1032 SCANNED OCT 2001 NON AUG 5, 2002 REPORT: 201 9:10 PM MPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 8/ 5/ 2 7/25/ 2 11:45 3:45 4,0 4,0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 7438 96.6 1.07 0.08 94.7 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET HATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 252 7168 7421 158 626 384 6866 7251 241 627 CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 176 315 185 25.60 176 317 187 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8965 17,23 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 271 172 2936 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 2778 396 1269 3096 460- 1271 SAT AUG 24, 2002 REPORT: 201 6:53 PM MPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLOW ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 8/24/ 2 8/10/ 2 7:16 11:16 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD WATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 7483 95.6 1.07 0.08 83.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET WATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 328 7132 7460 253 772 95 463 558 2378 25050 CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 176 320 186 25.60 176 311 186 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE PBD PERCENT PSIG DEGF MSCFD MSCFD SCF/BBL PSIG 8963 16.76 273 174 3325 0.000 3O72 446 1276 3309 10185- 1271 1.200 FINAL ENDICOTT OIL ALLOCATION FACTORS August 2002 1.150 1.100 1.050 .ooo 0.950 0.900  0.850 0.800 0.750 ............... 0.700 , I I I I I I I I , I I I , 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day bp BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East 8enson Boulevard P.O. Box 19661Z Anchorage, Alaska 99519-661 6/4/2002 Mr. Ken Boyd, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information - May, 2002 Dr. Mr Boyd, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for May, 2002. The attached information includes cumulative produced volumes, a summaQ of the operational activities and a complete set of well test results used for production allocation. Sincerely, Mark C. W eggeland Endicott Engineering/Development Team Lead MCW/JGA XC: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission RECEIVFD JUH 1 2 2002 SCANNED JUN 2,:~ 2001 ' Sag Delta North Production Summary for May, 2002 " May, 20~2 ~'rodUc{ion Summary " Well "'Oil NGL' ' Gas" GOI~ wate~Cut STB STB MMSCF SCF/STB % 2-38/SN '-'1 9807 63 6.98~' ' 713 ....95 2-32/SN-3 2036 0 1.282 630 92 Total / Avg. .11,843 63 8.270 698 95 i ii i i! iii i i i ii i I i · i May Accepted Well Tests " ..... Well i NumberTests of 2'38/SN,01 i ' 3 ' .2.-32/SN-03 , 2 .., Operations Summary 2-38/SN-1 Routine production. 1-17/SN-2 Plugged and abandon, 1/24/97 2-32/SN-3 Routine production. MCW / JGA ec: J. Ambrose (w/o attachments) Cc: Sag File 35.02 "State Reports" (w/attachments) 2-32/SN-03 05/14/02 930 70 861 628 92.5 299 133 104 3,791 2-32/SN-03 05/20/02 814 73 741 626 91.0 304 135 104 3,728 2'-38/SN-01 05/16/02 7,384 347 7,037 770 95.3 322 "'187 '176 ' 3,06:1 2-38/SN-01 05/20/02 7,388 310 7,078 626 95.8 314 187 176 3,178 2-38/SN-01 05/25/02 7,446 320 7,126 624 95.7 324 186 176 3,123 BP EXPLORATION (ALASKA)INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION May, 2002 DAY OIL NGL's GAS (mcf) WTR 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 22 23. 24 25 26 27 28 29 3O 31 411 3 3O8 7,669 412 3 308 7,685 412 3 308 7,701 413 3 308 7,717 413 3 309 7,734 323 2 240 5,939 414 3 309 7,766 414 3 309 7,783 415 3 310 7,799 397 3 299 7,595 347 3 267 6,995 361 3 275 7,124 385 3 287 7,247 417 3 311 7,880 417 3 311 7,869 418 3 312- 7,857 410 3 294 7,848 399 3 274 7,790 392 2 257 7,828 383 2 240 7,818 385 2 241 7,828 387 2 242 7,838 389 2 243 7,847 271 0 170 5,174 393. 0 246 7,867 393 0 246 7,867 393 0 246 7,867 203 0 127 3,636 290 0 181 5,560 393 0 246 7,867 393 0 246 7,867 CANNE JUN BP EXPLORATION (ALASKA)INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 May, 2002 OIL NGL GAS WTR LD HRS i ii ii 1 347 3 267 6,911 0 24.00 2 347 3 267 6,919 0 24.00 3 347 3 267 6,928 0 24.00 4 347 3 267 6,936 0 24.00 5 347' 3 267 6,945 0 24.00 6 257 2 198 5,142 0 17.75 7 347 3 267 6,961 0 24.00 8 347 3 267 6,970 0 24.00 9 347 3 267 6,978 0 24.00 10 347 3 267 6,987 0 24.00 11 347 3 267 6,995 0 24.00 12 340 3 262 6,863 0 23.52 13 318 3 245 6,427 0 22.00 14 347 3 267 7,020 0 24.00 15 347 3 267 7,029 0 24.00 16 347 3 267 7,037 0 24.00 17 338 3 249 7,047 0 24.00 18 327 3 229 7,013 0 23.85 19 319 2 212 7,068 0 24.00 20 310 2 194 7,078 0 24.00 21 312 2 195 7,087 0 24.00 22 314 2 196 7,097 0 24.00 23 316 2 197 7,107 0 24.00 24 198 0 124 4,433 0 14.95 25 320 0 200 7,126- 0 24.00 26 320 0 200 7,126 0 24.00 27 320 0 200 7,126 0 24.00 28 130 0 81 2,895 0 9.75 29 217 0 135 4,819 0 16.23 30 320 0 200 7,126 0 24.00 31 320 0 200 7,126 I 24.00 PSIG DEGF 310 309 3O9 310 310 361 308 308 307 308 3O8 3O8 321 3O8 311 315 3O6 307 3O7 3O9 3O8 3O8 307 375 312 306 3O5 306 356 3O6 307 187 187 187 187 187 183 186 187 187 187 187 187 186 187 187 187 187 187 187 187 187 187 187 180 187 187 187 187 178 186 187 JUN 2D02 BP EXPLORATION (ALASKA)INC. WELL PRODUCTION WELL 2-32/SAG DELTA #3 May, 2002 OIL NGL GAS WTR LD HRS i i ii i i PSIG DEGF I 64 0 41 758 0 24,00 2 65 0 41 766 0 24,00 3 65 0 41 773 0 24,00 4 66 0 41 781 0 24,00 5 '66 0 42 789 0 24,00 6 66 0 42 797 0 24,00 7 67 0 42 805 0 24,00 8 67 0 42 813 0 9 68 0 43 821 0 24.00 10 50 0 32 608 0 17,62 11 0 0 0 0 0 0,00 12 21 0 13 261 0 7,42 13 67 0 42 820 0 23,08 14 .70 0 44 860 0 24,00 15 70 0 44 840 0 24,00 16 71 0 45 820 0 24,00 17 72 0 45 800 0 24.00 18 72 0 45 777 0 23.88 19 73 0 45 761 0 24.00 20 73 0 46 741 0 24.00 21 73 0 46 741 0 24.00 22 73 0 46 741 0 24.00 23 73 0 46 741 0 24,00 24 73 0 46 741 0 24,00 · 25 73 0 46 741 0 24.00 26 73 0 46 741 0 24.00 27 73 0 46 741 0 24,00 28 73 0 46 741 0 24,00 29 73 0 46 741 0 24.00 30 73 0 46 741 0 24.00 31 73 0 46 741 0 24,00 298 136 298 136 297 136 298 135 298 136 297 136 294 136 136 294 136 296 135 0 0 440 124 302 133 296 134 295 134 294 135 291 135 293 135 294 135 297 135 295 136 295 136 295 136 294 138 295 137 291 135 291 135 291 134 291 134 290 133 290 133 24.00 '295 1 200 1.150 - 1.100 - 1 .O5O - o 1.000 - ~ 0.950 - 1 0.900 O.85O - 0.800 ,. FINAL ENDICOTT .OIL ALLOCATION FACTORS May 2002 1 3 5 7 9 tl 13 15 17 19 21 23 25 27 29 Day 3t TUE MAY 14~ 2002 9'20 AM REPORT: 201 MPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLOW ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS DATE OF START OF TEST TIME OF START OF 'TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS SEPARATOR GROSS FLUID RATE (60 DEGF) BPD WATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR TRUE NET O~L RATE (AT 60 DEGF) BPD TRUE NET NATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE HSCFD TRUE FORHATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL- HEAD TEMPERATURE OIL AP I GRAVITY 64THS PSIG DEGF DEG API FLUID RATE FROM CORRELATION PEROENT ERROR FROM MEASURED RATE .. SEPARATOR PRESSURE SEPARATOR TEHPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PBD PERCENT PSIG DEGF MSCFD LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG CURRENT PREVIOUS 5/14/ 2 4/25/ 2 12:01 4:00 4.0 4.0 935 92.5 1.07 0.08 92.0 7O 861 93O 44 628 62 711 772 39 631 104 299 133 27.30 104 295 138 8970 89.63 267 123 3835 0.000 3791 4122 1119 3811 4985 1130 6ANNE ; JUN 22002 TUE NAY .21~ 2002 4' 07 AH REPORT: 201 MPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF' TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS SEPARATOR GROSS FLUTD RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR TRUE NET OIL RATE' (AT 60 DEGF) BPD TRUE NET HATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE- MSCFD TRUE FORHATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL AP I GRAVITY 64THS PSIG DEGF ~ DEG API FLUID RATE FROM CORRELATION PERCENT ERROR FROH HEASURED RATE PBD PERCENT SEPARATOR PRESSURE SEPARATOR TENPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 5/20/ 2 5/14/ 2 12:28 4:28 4.O 4,O 819 91.0 1.07 0.08 92.5 73 741 814 46 626 7O 861 93O 44 628 104 3O4 135 27.30 104 299 133 8968 90.93 275 124 3774 0.000 4176 4637 1122 3791 4122 1119 CANNED JUN % 2002 THU NAY 16, REPORT: 201 2002 2:56 PH HPI 2-38 TEST : 4 TEST FACILITY · MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF' TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START SEPARATOR GROSS FLUID RATE NATER CUT PERCENTAGE OTL SHRINKAGE FACTOR SOLUTION GAS FACTOR (60 DEGF) TRUE NET OIL RATE (AT 60 DEGF) TRUE NET NATER RATE CORRECTED GROSS FLUID RATE (60 DEGF) TRUE FORMATION GAS RATE TRUE FORMATION GAS-OIL RATIO CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEHPERATURE OT L AP I GRAVITY FLUID RATE FROH CORRELATION PERCENT ERROR FROH HEASURED RATE SEPARATOR PRESSURE SEPARATOR TEHPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE HOURS BPD PERCENT 5/16/ 2 4/28/ 2 1:22 5:22 4,O 4,0 74O9 95.3 95.2 1 .O7 0.08 BPD 347 347 BPD 7037 6886 BPD 7384 7233 MSCFD 267 267 SCF/STB 770 770 64'THS 176 176 PSIG 322 315 DEGF 187 187 DEG API 25.60 PBD PERCENT PSIG DEGF MSCFD 8962 17.61 275 176 3328 0.000 MSCFD 3061 3107 SCF/BBL 451 467 PSIG 1282 1281 JUN :& 2002 TUE .MAY 21, 2002 3:59 AN REPORT: 20.1 HPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF' TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS SEPARATOR GROSS FLUTD RATE (60 DEGF) BPD MATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORHATION GAS RATE HSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE 01 L AP I GRAVITY 64THS PSIG DEGF DEG AP I FLUID RATE FROM CORRELATION PERCENT' ERROR FROM MEASURED RATE SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PBD PERCENT PSIG DEGF MSCFD LIFT .GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF / BBL PSIG 5/20/ 2 5/16/ 2 12:14 4:14 4.0 4.0 7410 95.8 1.07 0.08 95.3 310 7078 7388 239 771 347 7037 7384 267 770 176 314 187 25.60 176 322 187 8965 17.59 265 176 3372 0.000 3133 456 1275 3061 451 1282 $CANNEP JUN %'& 2002 SUN MAY 26~ 2002 4:25 AN REPORT: 201 HPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS DATE OF START OF-TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS SEPARATOR GROSS FLUID RATE (60 DEGF) BPD MATER CUT PEROENTAGE PERCENT O~L SHRINKAGE FACTOR SOLUTION GAS FACTOR TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORHATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL~HEAD PRESSURE NELL - HEAD TEHPERATURE OIL AP I GRAVITY 64THS PSIG DEGF DEG API FLUID RATE FROH CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD 8CF / BBL PSIG CURRENT PREVIOUS 5/25/ 2 5/20/ 2 8:54 12:53 4,0 4.O 7469 95,7 1.07 0.08 95.8 32O 7126 7446 2O0 624 310 7078 7388 194 626 176 324 186 25.60 176 314 187 8962 16.91 276 175 3323 0.000 3123 446 1284 3178 456 1275 bp BP Exploration (Alaska) Inc. Endicott-Prudhoe Bay 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 512/2002 Mr. Ken Boyd, Director Division of Oil and Gas Alaska Department of Natural Resources 550 West 7th Avenue Suite 800 Anchorage, Alaska 99501-3510 Sag Delta North Well Testing Information - April, 2002 Dr. Mr Boyd, In compliance with the Lease Plan of Operations agreement we respectfully submit the following production and well test information for Apdl, 2002. The attached information includes cumulative produced volumes, a summary of the operational activities and a complete set of well test results used for production allocation. Sincerely, Mark C. Weggeland Endicott Engineering/Development Team Lead MCW/BJM ~lv~ xc: Endicott Owners Committee Members Alaska Oil and Gas Conservation Commission Gas Cons · .... :.--'~--' Anchor~.,.'? Sag Delta North Production Summary for April, 2002 [2,.;], APril, 2002 Production Summary Well Oil NGL Gas GOR Water CUt STB STB MMSCF SCF/STB % , 2-38/SN-1 8234 74 7.000 850 96 ,.~. -32/SN-3. 3139 2_~4 1.967 627 9._~0 Total / Avg. 11,373 98 8.967 788 95 April Accepted Well Tests Well 2-38/SN-01 2-32/SN-03 Number of Tests Operations Summary 2-38/SN-1 Routine production. 1-17/SN-2 Plugged and abandon, 1/24/97 2-32/SN-3 Routine production. MCW / BJM ~)~/~ ec: B. McNerlin (w/o attachments) cc: Sag File 35.02 "State Reports" (w/attachments) Well 2-32/SN-03 2-32/SN-03 2-38/SN-01 2-38/SN-01 2-38/SN-01 Sag. Delta North, April 2002 Well Tests Date I' GFR ! .OR I "WE~.'/ ~OR I WC %1 W'. I WHT I CHK I ~as LR 04/17/02 1,036 93 943 626 91.0 305 139 104 3,752 04/25/02 772 62 711 631 92.0 295 138 104 3,811 04/10/02 7,441 298 7,143 626 96.0 324 188 176 3,127 04/26/02 7,418 260 7,158 1,399 96.5 316 187 176 3,020 04/28/02 7,233 347 6,886 770 95.2 315 187 176 3,107 ! BP EXPLORATION (ALASKA) INC. WELL PRODUCTION TOTAL SAG DELTA NORTH PRODUCTION April, 2002 DAY OIL- NGL's GAS (mcf) WTR 1 503 3 316 2 495 3 310 3 487 3 305 4 479 3 299 5 470 3 294 6 462 3 290 7 434 3 272 8 445 3 279 9 438 3 273 10 429 3 269 11 421 3 277 12 4O2 3 276 13 406 3 292 14 240 2 173 15 79 I 49 16 142 I 118 17 374 4 322 18 368 4 331 19 361 4 339 20 355 4 348 21 350 4 357 22 343 4 365 23 337 5 375 24 330 5. 384 25 324 5 392 26 322 4 4O3 27 350 3 341 28 409 3 306 29 409 3 306 30 409 3 306 31 0 0 0 8,453 8,431 8,409 8,387 8,366 8 344 7 969 8 301 8 279 8 257 8 234 7 951 8 187 4 256 751 3,032 8,093 8,065 8 036 8 008 7 980 7 952 7 924 7 896 7 868 7,869 7 427 7 596 7 596 7 596 0 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-38/SAG DELTA #1 April, 2002 OIL NGL GAS WTR LD HRS 1 323 2 203 7,118 0 24.00 2 321 2 201 7,121 0 24.00 3 318 2 199 7,124 0 24.00 4 315 2 197 7,127 0 24.00 5 312 2 195 7,129 0 24.00 6 309 2 194 7,132 0 24.00 7 293 2 184 6,832 0 22.98 8 303 2 190 7,138 0 24.00 9 301 2 188 7,141 0 24.00 10 298 2 187 7,143 0 24.00 11 295 2 198 7,144 0 24.00 12 282 2 201 6,886 0 23.13 13 291 2 220 7,146 0 24.00 14 131 1 105 3,240 0 10.88 15 0 0 0 0 0 0.00 16 106 1 95 2,675 0 8.98 17 281 3 264 7,150 0 24.00 18 279 3 275 7,151 0 24.00 19 276 3 286 7,152 0 24.00 20 274 3 297 7,153 0 24.00 21 272 3 308 7,154 0 24.00 22 269 3 319 7,155 0 24.00 23 267 4 331 7,156 0 24.00 24 264 4 342 7,156 0 24.00 25 262 4 353 7,157 0 24.00 26 260 4 364 7,158 0 24.00 27 291 3 303 6,744 0 23.05 28 347 3 267 6,886 0 24.00 29 347 3 267 6,886 0 24.00 30 347 3 267 6,886 0 24.00 31 0 0 0 0 1 0.00 PSIG 3O9 310 310 310 3O9 3O9 310 312 314 319 311 311 288 297 0 352 312 312 312 311 311 312 312 311 311 311 309 310 308 310 0 DEGF 188 188 188 188 188 188 188 188 188 188 188 187 188 184 0 173 184 186 186 186 187 187 187 187 187 187 185 187 187 187 0 BP EXPLORATION (ALASKA) INC. WELL PRODUCTION WELL 2-32/SAG DELTA #3 April, 2002 OIL NGL GAS WTR LD HRS PSIG DEGF I 180 I 113 2 174 I 109 3 169 I 106 4 164 I 102 5 158 I 99 6 153 I 96 7 141 I 88 8 142 I 89 9 137 I 85 10 131 I 82 11 126 1 79 12 120 1 75 13 115 I 72 14 109 1 68 15 79 I 49 16 36 0 23 17 93 1 58 18 89 1 56 19 85 I 53 20 81 I 51 21 78 1 49 22 74 1 46 23 70 1 44 24 66 I 42 25 62 I 39 26 62 0 39 27 59 0 38 28 62 0 39 29 62 0 39 30 62 0 39 31 0 0 0 ,334 ,310 ,285 ,261 236 212 137 ,163 :139 114 090 065 041 016 751 357 943 914 885 856 827 797 768 739 710 710 683 710 710 710 0 0 24.00 307 149 0 24.00 307 150 0 24.00 310 149 0 24.00 310 150 0 24.00 309 150 0 24.00 311 150 0 22.98 310 150 0 24.00 314 150 0 24.00 314 150 0 24.00 312 151 0 24.00 309 148 0 24.00 304 146 0 24.00 285 143 0 24.00 280 143 0 18.18 294 142 0 8.85 356 134 0 24.00 303 139 0 24.00 302 139 0 24.00 301 139 0 24.00 299 138 0 24.00 299 138 0 24.00 299 138 0 24.00 299 138 0 24.00 298 137 0 24.00 297 137 0 24.00 293 137 0 23.07 313 137 0 24.00 298 137 0 24.00 296 136 0 24.00 299 136 0 0.00 0 0 1.200 FINAL ENDICOTT OIL ALLOCATION FACTORS April 2002 1.150 1.100 - 1.050 - 1.000 - 0 950 - 01900 0.850 1 0.800 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 Day THU APR 25, 2002 11'51 PM REPORT: 201 MPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 4/25/ 2 4/17/ 2 5:14 9:13 4.O 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD NATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 777 92.0 1.07 0.08 91.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 62 711 772 39 631 104 295 138 27.3O 93 943 1036 58 626 104 305 139 FLUID RATE FROH CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8971. 91.39 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 265 126 3850 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3811 4985 1130 3752 3678 1139 NED APR 17~ 2002 10'33 PM REPORT: 201 MPI 2-32 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 4/17/ 2 3/31/ 2 2:18 6:18 4,0 4,0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 1043 91.0 I .07 0.08 88.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET HATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB 93 943 1036 58 626 185 1359 1544 116 627 CHOKE POSITION HELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 104 305 139 27.30 104 306 150 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8968 88.45 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 27O 129 3810 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3752 3678 1139 3597 2405 1173 SUN APR 28, 2002 11'28 PM REPORT: 201 MPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 4/28/ 2 4/26/ 2 1:02 5:02 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD NATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 7257 95.2 1.07 0.08 96.5 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET NATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 347 6886 7233 267 770 176 315 187 25.60 260 7158 7418 363 1399 176 316 187 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8965 19.32 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 266 175 3374 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3107 467 1281 3O2O 456 1281 FRI APR 26, 2002 REPORT: 201 7:13 PM MPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLOH ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 4/26/ 2 4/10/ 2 3:42 7:41 4,0 4,0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD HATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 7436 96.5 1.07 0.08 96.0 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET HATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION HELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 260 7158 7418 363 1399 176 316 187 25.60 298 7143 7441 186 626 176 324 188 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8964 17.25 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 270 175 3383 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3020 456 1281 3127 445 1288 NED APR 10, 2002 REPORT: 201 8:03 PM MPI 2-38 TEST : 4 TEST FACILITY : MPI HI FLON ENDICOTT NELL TEST REPORT *** FINAL *** GLT FIXD ITEM DESCRIPTION UNITS CURRENT PREVIOUS DATE OF START OF TEST TIME OF START OF TEST TIME OF END OF TEST ELAPSED TIME SINCE TEST START HOURS 4/10/ 2 3/28/ 2 6:57 10:57 4.0 4.0 SEPARATOR GROSS FLUID RATE (60 DEGF) BPD MATER CUT PERCENTAGE PERCENT OIL SHRINKAGE FACTOR SOLUTION GAS FACTOR 7462 96.0 1.07 0.08 95.5 TRUE NET OIL RATE (AT 60 DEGF) BPD TRUE NET MATER RATE BPD CORRECTED GROSS FLUID RATE (60 DEGF) BPD TRUE FORMATION GAS RATE MSCFD TRUE FORMATION GAS-OIL RATIO SCF/STB CHOKE POSITION NELL-HEAD PRESSURE NELL-HEAD TEMPERATURE OIL API GRAVITY 64THS PSIG DEGF DEG API 298 7143 7441 186 626 176 324 188 25.60 335 7107 7442 210 626 176 320 188 FLUID RATE FROM CORRELATION PERCENT ERROR FROM MEASURED RATE PBD PERCENT 8962 16.97 SEPARATOR PRESSURE SEPARATOR TEMPERATURE SEPARATOR GAS RATE SEPARATOR GAS GRAVITY PSIG DEGF MSCFD 276 177 3313 0.000 LIFT GAS RATE TOTAL GAS-LIQUID RATIO CASING PRESSURE MSCFD SCF/BBL PSIG 3127 445 1288 2987 430 1280 LARRY GRANT - Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Date: 24 August 1995 ._~-~-z._- .... RE: Transmittal of Data Sent by: ANCH.EXPRESS · Enclosed, please find the data as described below: ~, k~ 2-32/SN-03 ~7~Z~iT;es~ _ . '.L--~I PLS FIN~ BL+~ . ~-_ .... ii-:Run ~ . I . __ .i;::'/ 6471.00 .~~ ~ Please sign and return to: Attn. Rodney' D. Paulson .... --.. :-.~' ..... - - . ............. '. Atlas' Wireline Services · .. ~ c': ' :.~'-:--:.'-... '-. :_ _-'":'~%~::~--..-_. .... RECEIVED - -- .~ -T3_.. : _ ~u~o 201 ........... : ..... -. .- - : - ,> s~-,~o~ 8EP 1 4..1905 ... .. . ._ Received by: ~~ Oil & Gas C~s. Commission STATE OF ALASKA AI_~S,,:~ OIL AND GAS CONSERVATION COMMISSIL.,~ ". REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development X Exploratory 3. Address Strafigraphic 7. P. 0. Box 196612, Anchorage, Alaska 99519-6612 ser~ce 4. Location of well at surface 8. 2011' SNL, 2284' WEL, Sec. 36, T12N, R16E At top of productive interval 5253' SNL, 3451' WEL, Sec. 19, T12N, R17E At effective depth 5143'SNL, 3358'WEL, Sec. 19, T12N, R17E At total depth 5066' SNL, 3290' WEL, Sec. 19, T12N, R17E R£C£1V£D AUG - 1 1994 Alaska 0it & Gas Cons. Commission Anch0ra~je Datum elevation (DF or KB) KBE = 54.5 feet Unit or Property name Duck Island Unit Well number 2-38/SN-01 9. Permit numbedapproval number 90-12g/Not required 10. APl number 5O- O29-22O9O 11. Field/Pool Sag Delta North/Ivishak 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13700' feet Plugs (measured) 10405' feet BKB 13610' feet Junk (measured) 10335' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~.~l depth BKB 71' 30" Driven 110' 11 O' 2501' 13-3/8" 3748 cu fl. permafrost 2540' 2390' 13310' 9-5/8" 3014 cu ft. Class G 13349' 10008' 744' 7" 504 cu ft. Class G 13087'- 13831' 9795'- 10426' measured 13394'- 13486' 13605'- 13628' true vertical (subsea) 9991'- 10068' 10170'- 10191' Tubing (size, grade, and measured depth) 4-1/2" 12.6~ L-80 tubing with 4-1/2" tailpipe to 13131' Packers and SSSV (type and measured depth) 9-5/8" packer at 13046? 7" WDpackerat 13550'. 4-1/2" SSSV at 1553'. 13. Stimulation or cement squeeze summary Scale inhibitor treatment (7/2/94) Intervals treated (measured) 13394'- 13486', 13605'- 13628' Treatment description including volumes used and final pressure $ Bbls seawater, 62 Bbls diesel/mutual solvent mix, 94 Bbls. seawater/scale inhibitor mix, 211 Bbls. seawater/2% surfactant mix, 190 Bbls seawater tubing volume. FSIWHP = 100 psla 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 134 299 4331 0 107.? 493 5246 0 Tubing Pressure 300 299 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17.1 hereby certify that the foregoingc~'~ue~an~d c~rrect to the best of my knowledge. Signed .~~,.../'-Z~JZ.._~ (:~. ~ Title Senior Technical Assistant !1 Form 1 ~t~0'4 Rev 06/15/88 SUBMIT IN D'UPL/ICA:I-E ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: RE: ECC #: Sent by: Data: 26 April 1994 Transmittal of Data 5874.01 PL Dear Sir/Madam, Reference: BP 2-38/SN-01 MPI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PLS GASLFT. FINAL BL Run # 1 1 /PLS GASLFT. RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA ALAo,,A OIL AND GAS CONSERVATION COMMISSI~,,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdOWnpull tubing Alter casingStimulate X Repair Pluggingwell Perforate f~,,~,~~,,~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2011' SNL, 2284' WEL, Sec. 36, T12N, R 16E At top of productive interval 5253' SNL, 3451' WEL, Sec. 19, T12N, R17E At effective depth 5143' SNL, 3358' WEL, Sec. 19, T12N, R17E At total depth 5066'SNL, 3290' WEL, Sec. 19, T12N, R17E 5. Type of Well: Development ., Exploratory StralJgraphic Service Other 6. Datum elevation (DFKBEOr KB)~t/__ 54.5~et I 7. Unit or Property name Duck Island Unit 8. Well number 2-38/SN-01 9. Permit number/approval number 90-129INet required 10. APl number 50- O29-22O9O 11. Field/Pool Sag Delta North/ivishak 12. Present well condition summary Total depth: measured true vertical 13700'feet Plugs (measured) 10405'feet BKB Effective depth: measured true vertical 13610'feet Junk (measured) 103351eat BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 30" Driven 13-3/8" 3748 cu ft. permafrost 9-5/8" 3014 cu ft. Class G 71' 2501' 1331O' measured 13394'- 13486' 13605'- 13628' Measured depth True ve~.a~ depth BKB 110' 110' 2540' 2390' 13349' 10008' 7" 504 cu ft. Class G 13087'- 13831' 9795'-10426' true vertical ~ubsea)9991'-10068' 10170'-10191' Tubing (size, grade, and measured depth) 4-1/2" 12.6~ L-80 tubing with 4-1/2"taiipipe to 13131' Packers and SSSV (type and measured depth) 9-5/8" packer at 13046'; 7" WDpackerat 13550'. APR 4-1/2"sssv at 1553'. ~i~[,'~ r~;~ ~. r'_.Jo ~',~ ('t,,rnrn~SSi0B * ,'.~,~,~,~.,,,..~. ,.,~1 .,-.~ .*.~ ~ ........ 13. Stimulation or cement squeeze summary Scale inhibitor treatment ~,nch0rage Intervals treated (measured) 13394'- 13486', 13605'- 13628' , ,_,=inclu~inn volumes used and final pressure $ Bbls seawater wINE-18, 57 Barrels diesel, 143 Bbls seawater/S-289 Treatment description mixture and 703 Bbls seawater overflush wINE-18 SIWHP = 500 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 3017 1933 4526 0 538 2882//'' 1830 4322 0 409 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing~.u~a~./d c rect to the best of my knowledge. Si~ned(~_..~/~./~_- ~· ~c'~r Title Senior Technical Assistant II Form ~4 Rev 06/15/88 SUBMIT IN DUPLICATE BP EXPLORATION April 14, 1993 Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Grant: Enclosed are the materials that the AOGCC requested in your letter dated January 7, 1993. WELL ~,"~IU 1-17/SN-02 v'~DIU 2-64/U-10 ~ DIU 2-38/SN-01 DIU 2-32/SN-03 ~ DIU 4-20/M-35 PERMIT NO. LOGS/TAPES/LISTINGS COMPANY 90- 1 50 /~DIFL-AC/ZDL-CN-SL~~5~'1 ATLAS/4709 ,~~T(N& RFT~J~~for '%.~:~13 SCH/74265 o this well) ~ ........ (folded sepi~blue line Icg) 90-0 77 ~WD DUAL PROP. RGD~~~ ~ TELECO/774TAK ~~~~ SCH/74067 ~MSFMSLD/CNT~ ~ ~Oo~ HAL/L4921 5-1 (FILES 1-46) 90-129 ~~~~~~ SCH/74182 ~~ ~ CTE/BHC/LDT/CNUNGT/DLUMSL~CH/74161 ~~~T FIELD FILES .018-.046~ SCH/74161 90-1 1 9 ~~~~ SCH/74088 UMSFL-D L/BCS-SLB/ . CNT-HRI/CSNG/MUSDUDSN2~ HAL/L49180-X 8 6- 1 73 ¢~OD-F/CAMCO ........ (folded sepi~blue line Icg) (completes transmittal 83998) v/ PBU P-13 ',~90'-1 1 ~,,FMT (No RFT for this well) (folded sepia/blue line Icg) Sorry about the delay - many of these tapes BPXA didn't have in their files and had to be acquired from the service companies archives. Please sign and return a copy of this transmittal to the BP Petrotechnical Data Center. If you havecj'~,~ueetio~ ~. ¢4;~ed more information please contact the data center. K ~ (~,~ ~" ~V IJ Sincerely J(~/,es R. Weise '~ . , WELL PBU DS P-13 iPBU Ds P-~.o tDIU 2-78/SNOI Did 2-32/SNO3 i'DIU M-3S PBU S-03 PEILMYr 90-150 I 90-111 i_'Y~.~J ! ! ,, 90-129 ! 90--119 ,, 8~173 $1-090 REQUIRED DATA DIGITAL DATA +"LIS X, rE. P,~.~CATION LISTLNC RFT SEPL4, & BLUELLNE " RFT. DRY DITCH. g'~"~ · .,- *, ,... DESCRIPTION (PST SEPr~'' & BLL~L~m!E,~' DiGiT2G_~ DATA + LIS ~T,R_t~iCATiON LISTING DIGITAL DATA + LIS '~RZFICATION LISTLNG DIGITAL DATA + LIS ¥~RiFICATION LISTING SEE TR~NSM-ITTAL 83998, GAS LIFT SEPL4. Alaska Oil & Gas Cons. CommissiOn; Anchorage WALTER J. HICKEL, GOVERNOR ALASKA OIL A~D GAS CONSERVATION COMMISSION January 7, 1993 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 James Weise Geo-Science Information Specialist BP Exploration(Alaska) Inc. P O Box 196612 Anchorage, AK 99519-661'2 Dear Mr. Weise, Per our conversation with on January 06, 1993, enclosed is a list of data that the Commission has yet not received. These wells are either released or scheduled for release. This requirement of well data should be handled as a priority. Please submit the data as soon as Possible. We will be conducting inventories of all well files to assure all data is submitted in accordance with AOGCC regulations. Please keeP in mind that we will be contacting your office periodically in regards to these compliance issues. I appreciate your cooperation and attention to these matters. questions please feel free to call me. If you have any Sincerely,' Larry Grant MEO II BP EXPLORATION Alaska, Inc. February 10, 1993 Mr. George Wilson Alaska Department of Environmental Conservation Pipeline Coordinator Regional Office 411 W. 4th Ave - Suite 2C Anchorage, Alaska 99501 AnnUlar. Injection. Permit Permit no. 9240-DB002 -TH ..... ' Request for Annular Injection · .- . - Dear Mr. Wilson: Effective this date, prudhoe Bay Drilling would like to add the following Endicott wells to the list of those approved for annular injection in 1993' MPI 2-16/M-16 MPI 1-63/T-22 ~sct- MpI 2-38/SN-01 c/t:>- MPI 1-17/SN-02 qc)-tszD MP, I 2-32/SN-03 MP'~i 1-11/SN-04 Enclosed is an updated injection table showing previous injection volumes in these well. Thank you for you consideration in this matter. Please call Karen Thomas as 564-4305 if you have any questions concerning this report. Sincerely, R£ EI -, I/ED ./Z./')'~ ;'~'fi ' , ~ ...... ~iaska oil & ~as Cons.~99~commission '~a' A. Denman ' HSE Coordinator, Pmdhoe Bay Drilling ~0mg, BP Exploration (Alaska)Inc. Post Office Box 196612 Anchorage, Alaska 99519-6612 Telephone (907) 561-5111 Co-Operators, Prudhoe Bay Unit ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 199~ Ann~ Page 2 'nj~ction KMT/EAD Attachments cc; Leigh Griffin, AOGCC REEEIVED MAR 0 1 19g~ Alask~ Oil & Gas Oons, Oommtss,or~ Anchorage BP EXPLORATION February 16, 1993 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Sag Delta North Field. Please contact me at 564- 5225 if you have any questions. Sincerely, Senior Technical Assistant II JLH Enclosures xc' File 06.10 RECEIVED F£B /V~199~ gJaska 0il & Gas Cons. Commission Anchorage SAG DELTA NORTH FIELD WELL NAME DATE INTERVALS LOG NAM[:. RUN NO COMPANY NAME 4,~..~, ?..C~ 2-38/SN-01 1/24/93 13300'-1361 O' Collar log (Perforating-Record) Atlas Wireline BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 15, 1992 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run on the following Sag North wells: WELL2-32/SN-03 12900-13500' PRODUCTION PROFILE SCHLUMBERGER 5/4/92 RUN 1 ? o-~"~ WELL2-38/SN-01 13000-13610' PRODUCTION PROFILE SCHLUMBERGER 12950-1365.4' JEWELRY.,,"' CAMCO Sincerely, ~_~.-Haa~ JLH/clt xc: File 6.10 5/3/92 RUN 1 3/27/92 RUN 1 , RF.C IV£D MAY 1 9 1992. Alaska Oil & Gas Cons, Commission Anchorage 2597/JLH/clt BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 10,1991 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run on the following Sag North wells' WELL2-38/SN-01 13605'-13628' CASING COLLAR lOG ATLAS WIRELINE 6/1 1/91 RUNONE Sincerely, JLH/clt xc: File 6.10 ,IUIL_ 2064/JLH/clt STATE OF ALASKA ALA~r,,A OIL AND GAS CONSERVATION COMMISSh.,.~ 0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown ~ Re-enter suspended well __ Alter casing ~ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program~ Pull tubing __ Variance__ Perforate X Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exp/oration ~A/aska) /nc. Development x KBE = 54.5 feet Exploratory 3. Address Stratigraphic~ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 ser~ce~ Duck/s/and Unit 4. Location of well at surface 8. Well number 2011' SNL, 2284' WEL, Sec. 36, T12N, R16E 2-38/SN - 01 At top of productive interval 9. Permit number 5253' SNL, 3451' WEL, Sec. 19, T12N, R17E 90-129 At effective depth 10. APl number 5143'SNL, 3358' WEL, Sec. 19, T12N, R17E 50- 029-22090 At total depth 11. Field/Pool 5066' SNL, 3290' WEL, Sec. 19, T12N, R17E Sag Delta North/ivishak 12. Present well condition summary Total depth: measured 13700' feet Plugs (measured) true vertical 10405' feet BKB Effective depth: measured 13610' feet Junk (measured) true vertical 10335' feet BKB Casing Length Size Cemented Measured depth True vertical depth StructuralBKB BKB Co nductor 71' 30" Driven 110' 11 O' Surface 2501' 13-3/8" 3748 cu ft. permafrost 2540' 2390' Intermediate 13310' 9-5/8" 3014 cu ft. Class G 13349' 10008' Production Liner 744' 7" 504 cu ft. Class G 13087'- 13831' 9795'- 10426' Perforation depth: measured 13394'- 13486' 13605'- 13628' true vertical (subsea) 9991'- 10068' . Tubing (size, grade, and measured depth) 4-1/2" 12.6//L-80 tubing with 4-1/2" tailpipe to 13131' JUl._ - Packers and SSSV (type and measured depth) 9-5/8" packer at 13046'; 7" WDpacker at 13.~{~§k~ OJJ & Gas Cons. C0mmJssJ0,q 4-1/2" SSSV at 1553: 13. Attachments Description summary of proposal X Detailed operations program 14. Estimated date for commencing operation 15. Status of well classification as: June 1, 1991 16. If proposal was verbally approved Oil x Gas Name of approver Lonnie Smith 5/13/91 Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~-/~- '~'~---~-'~..__ Title Endicott Operations & Production Lead Engr. Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approva, No. ~/_/~,~ Plug integrity __ BOP Test__ Location clearance __ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission Commissioner Date'-] Form 10-403 Rev 06/15/88 Approved Copy SUBMIT IN -rRIPLICATE ~etumed ORI61NAL S'6NED BY ~ '"J J~:::[./~I LONNIE C. SMITH SAG DELTA NORTH Well 2-38/SN-01 In order to benefit natural lift from Alapah gas production, we plan to perforate twenty-three feet of the Alapah formation. The interval to be perforated is: 13605' - 13628' BKB (Ref. DLL, 10/29/90) This interval will be perforated using 3 3/8" carrier guns at 6 shots per foot at 60 degree phasing. A lubricator will be installed and tested to 3000 psi for all well work. The SSSV will be reinstalled and tested after the perforated interval is added. RE £iV£D .Oil.& ~as COns. Cornrnissio~ 'Anchorage STATE OF ALASKA AL~o~A OIL AND GAS CONSERVATION COMMISSIL,,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate - Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2011' SNL, 2284'WEL, Sec. 36, T12N, R16E At top of productive interval 5253' SNL, 3451' WEL, Sec. 19, T12N, R 17E At effective depth 5143'SNL, 3358'WEL, Sec. 19, T12N, R17E At total depth 5066' SNL, 3290'WEL, Sec. 19, T12N, R17E 5. Type of Well: Development Exploratory Stratigraphic 6. Datum elevation (DF or KB) KBE = 54.5 feet 7. Unit or Property name Duck Island Unit 8. Well number 2-38/SN - 01 9. Permit number/approval number 9O- 129 10. APl number 5 O- O29-22O 90 11. Field/Pool Sag Delta North/Ivishak 12. Present well condition summary Total depth: measured true vertical 13700' feet Plugs (measured) 10405' feet BKB Effective depth: measured true vertical 13610' feet Junk (measured) 10335' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 30" Driven 13-3/8" 3748 cu ft. permafrost 9-5/8" 3014 cu ft. Class G 71' 2501' 13310' measured 13394'- 13486' 13605'- 13628' Measured depth True vertical depth BKB BKB 110' 110' 2540' 2390' 13349' 10008' 7" 504 cu ft. C/ass G 13087'- 13831' 9795'- 10426' true vertical (subsea) 9991'- 10068' 10170'- 10191' Tubing (size, grade, and measured depth) 4-1/2" 12.6#L-80 tubing with 4-1/2" taiip/pe to 13131' RECEIVED Packers and SSSV (type and measured depth) 9-5/8" packer at 13046'; 7" WDpackerat 13550'. ' 4-1/2" SSSV at 1553'. 13. Stimulation or cement squeeze summary d U L. ~. 0 ~;~ ~ Intervals treated (measured) Treatment description including volumes used and final pressure Alaska .Oil & Gas Cons, Corem[ss~'°~ Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 1430 836 1035 0 601 Subsequent to operation 2908 1747 2685 0 286 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. Si~ned ~~' /' /~~"--"~~ ~tleEndicott Operations & Prod. Load Enqr. Date ~ ~/ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department Additional DATE: 10-11 June 1991 WELL N~: 2-38/SN-01 BP EXPLORATION REP: Luedke-Chan SERVICE COMPANY: AWS Perforations INOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODUCTION TREEI ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH. CLEAN UP ANY~ CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE. I DATE/TIME [ OPERATIONS SUMMARY 1230 MIRU AWS. Post radio silence signs at the entrance to island and next to well site. Install SSV fusible cap. . SIWHP = 1084 psig. IAP = 0 psig. OAP = 0 psig. Choke = 26 Beans. Well SI due to bailing. Pressure test lubricator to wellhead pressure. ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). Otis depth showed only 19 feet of interval above fill. 1415 RIH with Gun gl (19 feet). SIWHP = 1084 psig. 1500 Couldn't get below 5278' MDBKB. This was strange because initial perfs had no problems with 20' guns. Look at GCT - 7.53 deg/100' dogleg! 1530 POH 1715 RIH with Gun g 1 (10'). 1825 Tie in to CBL dated 11-01-90. All of the depths listed below are from the open hole reference log. Flag line for next run. 1905 Find that all 23 feet of interval is there after all. Tag TD ~ 13630' MDBKB. SIWHP = 1050 psi#. 1915 Open wing valve and set choke to 26 beans. FWHP = 595 psi#. 1920 Hang gun gl Top Shot at 13618' MDBKB. 1920 Shoot gun gl from 13618'-13628" MDBKB and flow well for 15- 20 minutes. FWHP = 599 psi#. No indication that gun fired! 1927 SI well and log collars through sliding sleeve while POH. 2030 Gun did not fire. 2100 RIH with Gun gl (10 feet). SIWHP = 834 psi#. 2230 Tie in to CBT logging up. Open wing valve. FWHP = 716 psi#. 2240 Shoot gun g 1 from 13618'-13628' MDBKB. FWIlP = 742 g~il~ 2255 SI well and POH. 2315 RIH with Gun #2 (13 feet). 6/11/91 0100 Can't get by dogleg with an extra 4' of length. POOH 0200 Swab leaks. Decide to shut down and try again later today, dUE 1300 Still waiting for grease truck, a~,,,,r ....... 1410 RIH with Gun g2 (10 feet). SIWHP = 954 psi#. 1530 Tie in to CBT logging up. 1540 Open wing valve. FWHP = 406 psi#. 1547 Shoot gun # 2 from 13608'-13618' MDBKB. FWHP = 502 psi#. 1600 SI well and POH. 1730 RIH with Gun g3 (3 feet). SIWHP = 725 psi#. 1845 Tie in to CBT logging up. 1915 Open wing valve. FWHP = 664 psi#. 1920 Shoot gun # 3 from 13605'-13608' MDBKB. FWHP = 668 psi#. 1925 SI well and POH. SIWHP = 743 psi#. Confirm all shots fired. 2100 End radio silence. s Cons. Commission :borage DATE: 10-11 June 1991 WELL N°: 2-38/SN-01 TYPE OF OPERATION: Additional Perforations PERFORATION SUMMARY: GUN INTERVAL(DLL) CBL DEPTH FEET ~ 1 - 3 13605'.13628' 13605'-13628' 2 3 Aiapah All intervals were shot using 3 3/8" guns at 6 spf, 60 degree phasing and random orientation. ~ ~ ' STATE OF ALASKA 0 ~ '~ ! ~ ~ [ ALASKA OIL AND GAS CONSERVATION CL~,vlMISSION _.;~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 90-129 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 $0- 50-029-22090 4. Location of well at surface !~ - ' - · ~ - 9. Unit or Lease Name 2011' SNL, 2284' WEL, SEC. 36, T12N, R16E ,~ .' ~!/L !;~¥~ : .~.~:_~;.~.:_;~::. ,;..~ Duck Island Unit At Top Producing Interval 1 ~, ;:;....~.,..;~, 10. Well Number .~__ 11. Field and Pool At Total Depth i[_~, H Sag Delta North ~ 5066' SNL, 3290' WEL, SEC. 19, T12N, R17E ='------'--~ ' 5. Elevation in feet {indicate KB, DF, etc.) ~. Lease Designation and Serial No. 54.5 ' KBE I ADI. 312828 12. Date Spudded 1~. Date T.D. Reached ~4. Date Comp., Susp. or ^band. iiff. Water Depth, if offshore 116. No. o! Completions 10-4-90 10-28-90 11-7-90I 6-12' MSL foot MSL I One 17. Total Depth {MD+TVD) ~8. Plug Back Depth {MD+'I'VD>IO. Directional Survey [20. Depth where SSSV set 121. Thickness of Permalrost 13831'MD/10426'TVD 1374~' TD/lO349'TVD '~S [] NO [] 1553'foot MD I 1466' 22. Type [Ioctric or Other Lo~s Run LD T/CNI._/G~, RFT, DIL/GF~H$C, MSFL/D1.L/~R 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER Fr. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30 Struct. Drive Surface 13-3/8 68# NT8OC YHE Surface 2540 17-1/2 3394 cu fl Permafrost 9-5/8 47# NTSOS Surface 11041 12-1/4 9-5/8 47# NT95HS 11041' 13349 12-1/4 3120 cu ft Class G * 7" 29# NT95HS 13087' 13831' 8-1/2!' 400 cu fl Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET {MDI PACKER SET (MDI Atlas 3-1/8"@ 6 spf 4-1/2" 12.6# 13131' 13046' MD TVDSS L-80 13394' - 13486' 9991'- 10068' 26. ACID, FRACTURE, CEMENTSQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" X 9-5/8" Downsgueeze annulus with 120 bbls annulus Dry Crude. 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11-8-90. I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL :~SIZE IGAS~OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "Ir . I Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core i FEB - § t991 Alaska 0il & Gas Cons. Commission Form 10-407 Submit in duplicate Rev. 7-1-80 C,(:h"~INUED ON REVERSE SIDE 29. - : : 30. GEOLOGIC MARKERS , ,.,RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 13336 9997 Top Ka vik 13494 10130 Top Lisburne 13601 10222 31. LIST OF ATTACHMENTS I hereby cedify that e foregoing i true and correct to the best of my knowledge Title Endicott Lead Engineer Date Signed / L INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Thursday. OctQber 4. 1990 WELL: 2-38/SN-01 AP! No. 50-029-22090 Day: 1 Depth at 0600 Hrs. = 24 Hour Footage = OFt. .O. Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation: Preparing to move rig Summary_ of Last 24 Hours:. Moved mud pits away from rig. Prepared rig and location for move. Plugged well for drill-by. MudTv.De .. , Mud Weight Viscositv P V yp Fluid Loss Solids Temo #/gal Sec. cc °F Survey Depth Angle Direction TVD ~ E(+)RV(;) Dog Leg Section Coordinate Coordinate °/100' Reviewed By:?/lt ~3~'v BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG,DELTA NORTH As of 0600 Hrs. Friday. October 5. 1990 WELL: 2-38/SN-0t APl No. 50-029-22090 Day' 2 Depth at 0600 Hrs. = 24 Hour Footage = 590 Ft. 590 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 .176162 Current Ooeration: Tripping for BHA change Summary_ of Last 24 Hours: Plugged wells for drill-by. Accepted rig at 1900 hrs on 10-4-90. Moved dg on to location. Spudded at 2230 hrs on 10-4-90. Drilled from 0' to 590'. POH. NU riser. Mud Tyoe M~Icl Weight Viscosity Spud 9.5 #/gal 200 Sec. · ~ J~ Angle Direction TVD PV yp ~ Solids 20 45 11.5 cc 4% N (+liS (-~ Ef+I/W(-) Section Coordinate Coordinate Temo 46 OF DQg Leg °/100' Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Monday. October $, 1990 WELL: 2-3,8/SN-01 AP! No. 50-02.9-22090 Day: 4_ Depth at 0600 Hrs. = 72 Hour Footage = 2.550 Ft. 1.960 Ft. , Current Operation' ND riser ,,Summary 9f Last 72 Hours' Drilled 17-1/2" hole from 590' to 2550'. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = D. OYON RIG # 13 1.76162 Ran and cemented 13-3/8" casing. ND riser. Mud Tvoe Mud Weiaht - . -- Spud 9.6 #/gal ¥i~cosity p V YP 1EJ.u_L~[_La.,~ Solids 68 Sec. 9 40 19.0 cc 8% Tomb 72 OF ~ EEP. tJZ Angle J~C_C&L¢~ 5 927 7.25 N32W 10 1,318 11.30 N16E 15 1,784 23.80 N19E 19 2,157 32.50 N23E 20 2,487 40.20 N22E N (+)/S (-) E(+)/W(-) TVD Section Coordinate Coordinate 926 8 17 -14 1,312 57 76 -23 1,753 200 215 21 2,083 373 379 80 2,348 Dog Leg o/109' 0.90 1.80 1.10 Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ~,AG DELTA NORTH As of 0600 Hrs. '['uesday, October 9, 1990 WELL: 2-38/$N-01 APl No. ~0-029-22090 Day: 5 Depth at 0600 Hrs. = 24 Hour Footage = 3.950 Ft. 1.400 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 !.76162 Current Ooeration' Drilling 12-1/4" hole Summary of Last 2_&4 Hours: NU speedhead and BOPE. Tested BOPE. RIH. Tested casing to 3000 psi, ok. FIT = 12.9 ppg. Ddlled 12-1/4"hole to 3950'. Mud Type Mud Weiaht Viscosity P V - . -- Lignosulfonate 9.2 #/gal 40 Sec. 5 Survey Depth Anale D. LEe,..EE¢~TVD -- 25 2,724 44.00 N22.1E 2,524 29 3,098 48.30 N23.6E 2,784 31 3,291 50.60 N24.4E 2,910 ~ Solids 23.0 cc 5% .N (,+)/s (4 E(+)/vv(-) Section Coordinate Coordinate 724 705 215 __ 992 952 321 1,140' 1,088 382 Temo .: "70 OF Doa Lea -- °/100' 1.50 1.30 1.20 Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Thursday, October 11, 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day' Z Depth at 0600 Hrs. = 24 Hour Footage = 6,450 Ft. 1,392 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 1.76162 Current Operation: Drilling Ahead Summary of Last 24 Hours: Ddiled 12-1/4" hole from 5058' to 6450'. Mud Tvoe Mud Weiaht Viscosity Lignosuifonate 9.3 #/gal 40 Sec. PV YP Fluid Loss Solids 8 10 10.0 cc 6% Temo 70 OF Survey Deoth Angle .{~Le. flJ.LQ~ TVD 50 5,034 56.10 N34.9E 3,954 62 6,174 41.50 N26.2E 4,763 N (+)/S (-) E(+)/W(-) Section Coordinate Coordinate 2,532 2,307 1,053 3,334 3,017 1,424 Dog Leg ?/100' 0.83 0.38 Reviewed By' BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Wednesday. October 10.1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: 6 Depth at 0600 Hrs. -- 24 Hour Footage = 5,058 Ft. 1.108 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG tf 15 ,176162 Current Operation: RIH Summary of. Last 24 Hours' Drilled 12-1/4" hole from 3950' to 5058'. Mud Type Mud Weight Viscosity Lignosulfonate 9.4 #/gal 45 Sec. P V YP. Fluid Loss Solids 9 1 4 11.5 cc 7% TemD 72 OF Survey Deoth Angle Direction TV[;) 43 4,400 53.40 N30E 3,580 N (+)/S (-) E(+)/W(-) Section Coordinate Coordinate 2,023 1,875 780 Dog Leg o/100' 1.20 Reviewed By' ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Friday, October 12.1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day' 8 Depth at 0600 Hrs. = 24 Hour Footage = 7,775 Ft. 1,325 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation' Drilling Ahead Summary of Last 24 Hours' Drilled 12-1/4" hole from 6450' to 7775'. M~ Ty.oe . Mud Weight Lignosulfonate 9.6 It/gal )/iscosity 38 Sec. PV YP. F. luid Loss Solids 9 1 3 9.0 cc 8% Temo 72 OF Survey Depth Angle Direction TVD 64 6,362 41.00 N26.5E 4,904 76 7,495 41.80 N24.4E 5,764 N (+)/S (-) E(+)/W(-) Section Coordinate Coordinate 3,458 3,128 1,479 4,195 3,796 1,793 Dog Leg o/100' 0.22 0.48 Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Monday. October 15. 1990 WELL: 2-38/SN-01 AP! No. 50-029-22090 Day: 1 1, Depth at 0600 Hrs. = 72 Hour Footage = ! 0,380 Ft. 2,6O5 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation: Drilling Ahead Summary of Last 72 Hours: Drilled 12-1/4" hole from 7775' to10380'. Mud. Type. Mud Weight Viscosity Lignosulfonate 9.9 #/gal 38 Sec. PV YP Fluid Loss Solids Temo 10 12 7.0 cc 11% 71 °F Survey Deoth Anale Direction TVD 78 7,691 42.30 N24E 5,909 86 8,435 45.30 N22.8E 6,441 92 9,008 44.80 N23.5E 6,846 105 10,220 41.20 N21.2E 7,733 N (+)/S (-) E(+)/W(-) Dog Leg Section Coordinate Coordinate °/100' 4,326 3,916 1,847 0.78 4,845 4,393 2,054 0.69 5,249 4,765 2,215 0.23 6,071 5,529 2,527 0.48 Reviewed By: '~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Tuesday. October 16. !990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: 1 2 Depth at 0600 Hrs. = 10.770 Ft. 24 Hour Footage = 390 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation: Drilling Ahead Summary_ of Last 24 Hours: Drilled 12-1/4" hole from 10380' to 10770'. Mud 'l'_vp¢ Mud Weight Viscositv Lignosuifonate 9.8 #/gal 36 Sec. PV YP 1 i~ Solids 10 10 6.8 cc 11% Temp 80 °F Survey Depth Angle Direction 107 10,408 42.40 N21.6E 110 10,696 43.90 N22.4E N (+)/S (-) E(+)/W(-) ~ Section Ooordinate Coordinate 7,873 6,195 5,646 2,572 8,082 6,390 5,829 2,643 Dog Leg .o/100' 0.76 0.65 Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Wednesday. October 17, 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: 1 3. Depth at 0600 Hrs. = 11,000 Ft. 24 Hour Footage = 230 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DQYON RIG Cf 15 176162 Current Operation' Drilling Ahead Summary of Last 2,4 Hours: Drilled 12-1/4" hole from 10770' to 11000'. Mud Type Mud Weight Viscosity Lignosuifonate 9.9 Cf/gal 35 Sec. P V yP Fluid Loss Solids Temp 10 10 6.4 cc 11% 78 °F Survey Depth Angle Direction 111 10,815 44.50 N27.3E 8,167 N (+)/S (-) E!+)/W(r) Dog Leg Sectiorl Coordinate Coor~linate °/100' 6,472 5,904 2,677 2.90 Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Thursday. October 18.199(;;) WELL: 2-38/SN-01 APl No. 50-029-22090 Day' 14 Depth at 0600 Hrs. = 11.365 Ft. 24 Hour Footage = 365 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYEN RIG # 15 176162 Current Operation' Tripping for bit Summary of Last 24 Hours: Drilled 12-1/4" hole from 11000' to 11365'. Mud Tyoe Mud Weight .Viscosity Lignosulfonate 9.9 #/gal 38 Sec. P V YP .F. luid Lgss Solids 1 0 1 6 5.8 cc 1 0% Temp _-86 OF Survey Depth Angle Direction 112 10,964 44.50 N31.3E 115 11,246 45.70 N 32.21= N (+)/S (-) E(+)/VV(-) TVD Sectioq Coordinate Coordinate 8,273 6,577 5,995 2,728 8,473 6,775 6,165 2,831 Dog .Leg °/,100' 1.80 1.10 Reviewed By: Z~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Friday, October 19. 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day' 1 ~. Depth at 0600 Hrs. = 24 Hour Footage = 11,900 Ft. 535 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYEN RIG # 15 176162 Current Operation: Drilling Ahead Summary_ of Last 24 Hours' Drilled 12-1/4" hole from 11365' to 11900'. Mucl Type Mud Weight Viscosity Lignosuifonate 10.0 #/gal 38 Sec. pv YP. Fluid Loss Solids 11 11 4.8cc 11% Temp 86 OF Survey Depth Angle ~ 116 11,341 46.10 N30.8E 11 9 11,625 46.40 N33E N (+)/S (-) E(+)/W(-) TVD Section Coordinate Coordinate 8,539 6,843 6,223 2,867 8,736 7,048 6,397 2,976 Dog Leg o/100' 1.10 0.86 Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Monday, October 22. 1990 WELL: 2-~8/$N-01 APl No. ~0-029-22090 Day: 1 7 Depth at 0600 Hrs. = 72 Hour Footage = 12,671 Ft. 771 Ft. Rig: AFE Number: AFE Amount = Current Costs --- Estimated Final Cost -- DOYQN RIG # 15 176162 Current Operation: Drilling. Summa_ry of Last 7,2. Hours: Drilling ahead in 12-1/4" hole at 12671'. Mud.Type, Mud Weight Ligno 10.2 #/gal Viscosity 37 Sec. .P V. YP Eluid Loss Solids 1 0 1 0 4.8 cc 13% Temp oF Survey ~ Angle .~ 128 12,559 43.60 N35.8E '['VD 9,384 N (+)/S (-) E(+)RV(-) Section Coordinate Coordinate 7,715 6,947 3,363 Dog Leg o/100' 0.49 Reviewed By' BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH. As of 0600 Hrs. Tuesday. October 23. 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: Depth at 0600 Hrs. = 24 Hour Footage = 13,270 Ft. 599 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = .DOYON RIG # 15 176162 Current Operation' Drilling Ahead Summary_ of Last .24, Hours: Drilled 12-1/4" hole from 12671' to 13270'. Mud Tvoe Mud Weioht Viscosity Lignosuifonate 10.2 #/gal 37 Sec. PV yP. Fluid Loss Solids Temo 9 8 4.9 cc 1 2% 88 °F Survey Death Ag¢.¢. .~.LE.c,..c.,.ti.~ 'D/D 129 12,698 43.10 N35.5E 9,485 134 13,162 36.40 N38.9E 9,841 N (+)/S (-) E(+)/W(-). Dog Leg Section Cogrdinate Coordinate °/100' 7,809 7,025 3,418 0.39 8,102 7,260 3,600 1.50 Reviewed By: 1~¢~- BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ,SAG DELTA NORTH As of 0600 Hrs. Wednesday, October 24. 1990 WELL: 2-38/SN-01 AP! No. 50-029-22090 Day: 20 Depth at 0600 Hrs. = 13,361 Ft. 24 Hour Footage = ~ 1 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG Cf 15 176162 Current Operation' Tripping Summary of La. st 24 Hours' Drilled 12-1/4" hole to 13328'. POH for washout. Drilled to 13361', 12-1/4" TD. LD MWD. RIH with bit w/o jets. POH for washout. MudType Mud Weight .Viscosity P V YP Fluid Loss Solids .Temp Ligno 10.2 #/gal 37 Sec. 9 8 4.8 cc 12% 96 °F Survey Deoth Anole .~LEg..c,,.tL~ .TVD N (+)/S (-) E(+)/VV(-) Dog Leg SectiQrl Coordinate Coordinate °/100' Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Thursday. October 25, 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day' 21 Depth at 0600 Hrs. = 24 Hour Footage = 13,361 Ft. 0 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation' Running 9-5/8" casing Summary of Last 24 Hours' RIH. Condition hole. Ran 9-5/8" casing. Mud Ty.oe Mud Weight Ligno 10.3 #/gal Viscosity 37 Sec. pv ..YE Fluid Loss Solids 9 7 5.0 cc TemF oF Survey Depth Angle ~)irection Tvo N (+)/S (-) E(+)/VV(-) Section C;oordinate Ooordinate _.Dog Le(_ °/100 Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Friday. October 26. 1990 WELL: 2-38/SN-01 APl No. ~;0-029-22090 Day' 22. Depth at 0600 Hrs. = 24 Hour Footage = 13.361 Ft. O Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 176162 Current Operation: Repairing rotary table Summary_ of Last 24 Hours: Ran and cemented 9-5/8" casing. Tested BOPE, ok. Installed new rotary table and chain. Mud Tvoe Mud Weiaht Viscosity Ligno 10.5 #/gal 37 Sec. PV Y.P Fluid Loss Solids 9 6 6.4 cc 14% Temp oF Survey De.oth Angle Direction TVD N (+)/S (-) E(+)/VV(-) Section Coordinate CoorC. inate Dog Leg °/100! Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Monday, Octol~er 29. 1990 WELL: 2-38/SN-01 APl No. 5O-O29-22O9O Day: 25 Depth at 0600 Hrs. = 72 Hour Footage = 13,831 Ft. 47O Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG Cf 15 176162 Current Operation: Logging 8-1/2" hole Summary of Last 72 Hours: . RIH to float collar. Tested 9-5/8" casing to 3000 psi, ok. Drilled float equipment. Drilled 8-1/2" hole to TD at 13831'. MAD pass with Teleco tool. Circulate and condition hole for logs. POH. Ran open-hole logs. MudType Mud Weight 'Viscosity P V YP Fluid Loss Solids Temo Ligno 9.8 #/gal 38 Sec. 9 7 5.4 cc 11% °F Survey Depth Angle. Direction TVD _N (+)IS (-) E(+)/W(-) Dog Leg Section Coordinate Coordinate °/100' Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Tuesday. October 30. 1990 WELL: 2-38/SN-,01 AP! No. 50-029-22090. Day: 26 Depth at 0600 Hrs. = 13,831 Ft. 24 Hour Footage = 0 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = D(;)YON RIG # 15. 176162 Current Operation' Running 7" liner. Summary of Last 24 Hours: Made conditioning trip. POOH. Mud Type Mud Weight Viscosity Ligno 9.8 CC/gal 37 Sec. P ¥ YP Eluid Loss Solids 9 6 6.0 cc 11% Temp 97 OF Survey Depth Angle Direction TVO. N (+)/S (-) E(+)RV(-) Section Coordinate Coordinate Dog Leg o/100' Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Wednesday, October 31. 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: 27 Depth at 0600 Hrs. = 13,831 Ft. 24 Hour Footage = .0_ Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = .DOYON RIG Cf 15 176162 Current Operation: L/D 8-1/2" BHA. Summary of Last 24. Hours: Ran and cemented 7" liner. Cleaned cement out of 9-5/8" to top of 7" liner. POOH. Mud Type Mud Weight Viscosity P V YP Fluid Los~ Solids Ligno 9.8 Cf/gal 37 Sec. 9 7 6.0 cc 11% Temp OF Survey Death Angle .BLEe,,_e,.t Lo~ TVD N (+)/S (-) E(+)/VV(-) Section Coordinate Coordinate Dog Leg °/100! Reviewed By: ~."' BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Thurs~a,y. November 1. 1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day' 28, Depth at 0600 Hrs. = 24 Hour Footage = 13,745 Ft. 0 Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG # 15 176162 Current Operation: POH Summary.of Last 2--4 H0urs:. P©H. LD BHA. RIH and tested casing to 3000 psi, ok. Cleaned out to landing collar. CBU. DisPlaced to 9.4 ppg brine. Filtered brine. Tested casing to 3000 psi, ok. POH and LD drillpipe. MudType Mud Weight Viscosity p V YP Fluid Loss Solids Brine 9.4 #/gal Sec. cc Temp OF Survey Deoth Angle Direction TVI~ N (+)/S (-) E(+)/W(-) Section Coordinate Coordinate Dog Leg o/100' Reviewed By:~/~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: SAG DELTA NORTH As of 0600 Hrs. Friday, November 2.1990 WELL: 2-38/SN-01 APl No. 50-029-22090 Day: 29 Depth at 0600 Hrs. = 13,745 Ft. 24 Hour Footage = Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DO.YON RIG tf 15 176162 Current Operation: Running 4-1/2" tubing Summary of Last 24 Hours: POH and LD driilpipe. Ran CBT/CET/GR/CCL, GCT/Gyro, and gauge ring and junk basket. Ran Otis WD packer, set at 13550'. Rigged up to run 4-1/2" tubing. MudType Mud Weight Viscosity PV YP Fluid Loss Solids Temp Brine 9.4 #/gal Sec. cc °F Survey Deoth Anale Direction TVD N (+)IS (-) E(+)/W(-)_ Dog Leg Section Coordinate Coordinate °/100' Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY DRILLING REPORT: ~AG DELTA NORTH As of 0600 Hrs. Monday, November 5. 1990 WELL: 2-38/SN-01 AP! No. 50-029-22090 Day' 30 Depth at 0600 Hrs. = 13,745 Ft. 72 Hour Footage = O Ft. Rig: AFE Number: AFE Amount = Current Costs = Estimated Final Cost = DOYON RIG Cf 15 176162 Current Operation' Release rig Summary of Last 72 Hours: Ran and landed 4-1/2" tubing. ND BOPE. NU tree. Tested tree to 5000 psi, ok. Displaced tubing to diesel. Set 9-5/8" packer. Tested annulus to 2500 psi, ok. Cleaned mud tanks. Released rig at 2000 hrs on 11/02/90. MudTy. pe Mud Weight Viscosity P V YP Fluid Loss Solids Temp Brine 9.4 #/gal Sec. cc °F Survey Depth Angle Direction N (+)IS (-) I~(+)/w(-) Dog Leg TVD Section C, oQrdinate Coordinate °/100' Reviewed By: ~ OttfGIti~t SUB - S URFA CE DIRECTIONAL SURVEY UIDANCE ~ ONTINUOUS !-~ OOL RECEIVED Alaska 011 & Gas Cons. Commission Anchorage Company BP EXPLORATION Well Name 2-38(SN01)(2011' SNL~2284' WEL~SEC 36~T12N~R16E Field/Location SAG NORTH, NORTH SLOPEr ALASKA Job Reference No. 74182 Loclcled By: MCBRIDE Date ~ 01-Nov-90 Computed KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR BP EXPLORATION 2-38(SN01) SAG NORTH NORTH SLOPEr ALASKA SURVEY DATE: 01-NOV-1990 ENGINEER: MCBRIDE METHODS OF COMPUTATION TOOL LOCATZON: TANGENTIAL- aVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HDRIZ. DIST. P~OJECTED ONTO A TARGET AZIMUTH OF NORTH 26 DEG 54 MIN EAST COMPUTATION DATE: 15-NOV-90 PAGE BP EXPLORATION Z-38(SN01) S AG NORTH NORTH SLOPE, ALASKA DATE OF SURVEY: 01,-NOV-'1990 KELLY BUSHING ELEVATION: 5,~.50 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATZON AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -54,50 0 0 N 0 0 100.00 100.00 45°50 0 30 S 61 55 E ZO0.O0 200.00 145.50 0 28 S 65 35 E 300°00 299.99 ~45o49 0 31 S 85 35 E 400.00 399.99 345,.49 0 29 N 96 4 E SO0.O0 499°99 445,.49 0 22 N 82 17 E 600.00 599.98 545°48 0 31 N 18 59 700.00 699.93 645.43 2 58 N 44 26 W 800,.00 799.65 745.15 5 24 N 39 I W 900.00 899.03 844.53 7 10 N 32 0 WI 1000.00 998.15 943.65 7 53 1100.00 1097.17 1042.67 8 12 120,0.. O0 1196.03 1141.53 9 14 1300.00 1294.54 1240.04 10 47 1400.00 1392.32 1337o82 13 25 1500.00 1488.81 1434.31 17 6 1600.00 1583.45 1528.95 20 23 1700o00 1676.52 1622.02 22 22 1800.00 1768.52 1714.02 24 2 1900o00 1859.35 1804.85 25 41 2000°00 1948.25 1893.75 28 42 2100o00 2034.97 1980.47 31 8 2200.00 2119.50 2065.00 33 25 2300.00 2202.13 2147.63 35 20 2400.00 2282.27 2227.77 38 7 2500.00 2359.62 2305.12 40 36 2600.00 2434.54 2380°04 42 11 2700.00 2507.84 2453.34 43 30 2800.00 2579.76 2525.26 44 31 2900.00 2650.42 2595.92 45 38 3000.00 2719.54 2665.04 46 55 3100.00 2786.87 2732.37 48 20 3200.00 2852.65 2798.15 49 25 3300.00 2916.82 2862.32 50 42 3400.00 2979.72 2925.22 50 58 3500.00 3042°65 2988.15 51 3 3600.00 3105.37 3050.87 51 19 3700.00 3167.63 3113.13 51 47 3800°00 3229.28 3174.78 52 15 3900.00 3290.34 3235.84 52 41 VERTICAL DOGLEG RECTANGULAR COOROINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG N 21 45 W N 10 51 W N 2 33 W N 3 19 E N 11 46 E N 18 45 E N 20 58 E N 20 38 E N 19 10 ~ N 17 5~ E 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.03 S 0.06 E -0.04 0.05 0.45 $ 0.80 E 0.17 0.17 0.66 S 1.67 E 0.56 0.00 0.66 S 2.55 E 0.98 0.38 0.59 S 3.34 E 1.35 2.39 0.42 S 3.80 E 2.82 2.35 2.11 N 2.05 E 5.45 2.31 7.52 N 2.77 W 10.58 1.66 16.56 N 9.26 W 18.41 1.48 28.36 N 28.59 1.41 41.73 N 41.15 1.53 56.68 N 56.51 2.82 73.86 N 76.23 3.85 94.55 N 101.88 4.15 119.73 N 133.93 2 ~0 149.99 N 170.29 1:~5 184.13 N 209.18 1.61 220.97 N 250.57 2.50 260.59 N N 20 0 E 295.87 N 21 55 E 345.39 N 22 54 E 398.64 N 22 50 E 454.81 N 22 52 E 514.46 N Zg 24 E 577.67 N 22 Z E 643.66 N 22 14 E 711.4.4 N ZZ 14. E 780.70 N 22 49 E 851.24 N 23 38 E 923.35 N 24, 24. E 997.20 N 24 46 E 1072.45 N :~5 17 E 1149.10 N 25 46 E 1226.82 N 25 51 E 1304..52 IV 26 10 E 1382.40 N 26 10 E 1460.64 N 26 15 E 1539.3T N 26 46 E 1618.57 0.00 N 0 0 E 0.07 S 61 54 E 0.92 S 60 30 E 1.79 S 68 30 E 2.63 S 75 30 E 3.40 S 79 57 E 3.83 S 83 45 E 2.96 N 44 18 E 8.01 N 20 14 W 18.97 N 29 13 W 15.21 W 32.18 N 28 12 W 19.07 W 45.89 N 24 34 W 20.78 W 60.37 N 20 8 W Z0.69 W 76.71 N 15 39 W 17.89 W 96.23 N 10 43 W 10.82 W 1ZO.2Z N 5 10 W 0.37 E 149.99 N 0 8 E 13.4.5 E 184.62 N 4. 11 E 26.80 E 222.59 N 6 55 E 40.17 E 263.67 N 8 46 E 2.12 1.99 1.70 2.76 2.38 2.59 1.36 I .05 0.99 1.54 303.90 N 54.93 E 308.82 N 10 15 E 350.36 N 72.80 E 357.85 N 11 44 E 399.71 N 93.21 E 410.44. N 13 8 E 451.60 N 115.09 E 466.04 N 14 18 E 506.69 N 138.35 E 525.24 N 15 16 E 565.13 N 162.85 E 588.13 N 16 5 E 626.47 N 187.82 E 654.02 N 16 41 E 689.48 N 213.43 E 721.76 N 17 12 E ,, 753.80 N 239.73 E 791.00 N 17 39 E 819.20 N 266.73 E 861.53 N 18 2 E 1.53 1.37 1.42 1.11 0.98 0 0.08 0.40 0.61 1.87 885.60 N 295.24 E 933.52 N 18 26 E 95~.13 N 325.35 E 1007.13 N 18 51 E 1021.60 N 356.71 E 1082.09 N 1g 15 E 1091.12 N 399.11 E 1158.43 N 19 38 E 1161.25 N 422.64. E 1235.77 N 20 0 E 1231.22 N 4.56.46 E 1313.11 N 20 ZO E 1301.21N 490.65 E 1390.64 N 20 ,0 E 1371.43 N 525.17 E 14.68.54 N 20 57 E 1442.07 N 559.94. E 1546.97 N 21 13 E 1513.01 M 595.15 E 1625.85 N 21 28 E COMPUTATION DATE: 15-NOV-90 PAGE BP EXPLORATION 2-38¢SN01) SAG NORTH NORTH SLOPEp ALASKA DATE OF SURVEY: 01-NOV-~g90 KELLY BUSHING ELEVATION: 54.50 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MERSURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH OEO HIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET 9EG/IO0 FEET FEET FEET DEG 4000.00 3350.29 3295.79 53 ,0 ,100.00 3408.59 335,.09 54 50 ,200.00 3466.19 3,11.69 54 53 4300.00 3524.04 3469.54 54 25 · ,oo.oo , oo.oo , 5000.00 3939.64 3885.1, 55 42 5100.00 3996.74 3942.24 53 54 5200.00 4057.62 4003.12 51 8 5300.00 4122.91 4068.41 46 44 5400.00 4194.26 4139.76 43 9 5500.00 4267.35 4*212.85 43 14. 5600°00 434,0.01 4285.51 43 5 5700.00 4.413.4,4. 4*358.94 42 34* 5800.00 4*4*87.4*7 44*32.97 41 53 5900.00 4561.65 4501.15 42 22 6000.00 4,635.66 4581.16 41 53 6100.00 4710.25 4,655.75 41 4,1 6200.00 ¢785.16 4.730.66 41 22 6300.00 4860.42 4.805.92 4*0 58 6400.00 4935.93 4881.4,3 40 51 6500.00 5011.69 4957.19 40 36 6600.00 5087.58 5033.08 40 40 6700.00 5163.63 5109.13 40 25 6800.00 5239.77 5185.27 40 18 6900.00 5316.06 5261.56 40 15 7000.00 5392.54 5338.04 39 56 7100.00 54*69.4*Z 5414.92 39 4*2 7200.00 554*5.97 5491.47 40 20 7300.00 5622.05 5567.55 40 39 74.00.00 5697.4*9 564.2.99 41 22 7500.00 5772.33 5717.83 41 43 7600.00 5846.85 5792.35 41 54 7700.00 5921.10 5B66.60 42 7 7800.00 5994.93 5940.43 42 42 7900.00 6068.19 6013.69 43 12 N 27 58 E 1698.60 N 28 23 E 1779.82 N 28 37 E 1861.53 N 28 46 E 1943.06 N 29 I E 2023.77 N 29 16 E 2103.46 N 29 54 E 2182.64 N 30 38 E 2262.00 N 32 5 E 234*Z.31 N 34 6 E 2423.04 N 35 49 E 2504.31 N 35 17 E 2585.4*0 N 32 50 E 2664.08 N 29 39 E 2739..55 N 26 Z8 E 2809.56 N 25 4*3 E 2877.81 N 25 26 E 294,6.50 N 25 ZO c. 3014,.35 N 25 26 E 3081.55 N 25 28 E 31,8.59 N 25 27 E 3215.82 N 25 24 ~ 3282.40 N 25 35 E 334.8.63 N 25 34 E 34,14.45 N 25 50 ~ 3480.00 N 26 7 E 3545.26 N 25 59 ~ 3610.38 N 25 48 ~ 3675.30 N Z5 40 ~ 374,0.12 N 25 30 E 3804.76 N 25 21 E 3869.15 N 25 42 E 3933.08 N 25 30 E 3997.42 N 24* 55 E 4062.29 N 24 33 E 4127.$7 N 24 13 E 4194.14 N 23 48 E 4260.74 N 23 36 E 4327.62 N 23 32 E 4394.95 N 23 26 E 4462.~9 1.88 0.38 0.21 0 1.68 1.28 0.30 1.82 1.39 2.09 1584.13 N 631.87 E 1705.50 N 21 45 E 1655.71 N 670.29 E 1786.25 N 22 2 E 1727.54 N 709.31 E 1867.69 N 22 19 E 1799.08 N 748.50 E 194.8.57 N 22 35 E 1869.80 N 787.49 E 2028.86 N 22 50 E 1939.43 N 826.38 E 2108.15 N 23 5 E 2008.36 N 865.51 E 2186.92 N 23 19 E 2077.05 N 905.53 E 2265.86 N 23 33 E 2145.80 N 947.52 E 2345.68 N 23 49 E 2213.87 N 991.79 E 24,25.87 N 2, 8 E 1.44 '2281.03 N 1039.04 E 2506.53 N 2, 29 E 2.12 234*7.55 N 10~7.13 E 2587.06 N 24 51 E 2.93 7.53 2.36 0.5' 1.68 0.22 0.92 0 2413.22 N 1131.59 E Z665.36 N 25 7 E Z4.77.85 N lI71.OZ E 274*0.62 N 25 18 E 2539.79 N 1203.68 E 2810.58 N 25 21 E 2601.22 N 1233.4.3 E 2878.84 N 25 22 E 2663.16 N 1243.15 E 294*7.5, N 25 23 E 2724..50 N 1292.23 E 3015.4,2 N 25 22 E 2785.25 N 1321.02 E 3082.65 N 25 22 E 2845.81 N 1349.83 E 31'9.71 N 25 23 E 0.29 0.29 O.OB 0.79 0.92 0.53 0.38 0.00 0.31 2906.53 N 1378.73 E 3216.96 N 25 23 E 2966.68 N 1407.33 E 3283.56 N 25 23 E 3026.48 N 1435.85 E 3349.81 N 25 23 E 3085.87 N 14,~4.27 E 3415.65 N 25 23 E 3144.96 N 14,92.67 ~ 3481.21 N 25 23 E 3203.59 N 1521.34 6 3546.48 N 25 24* E 3262.09 N 1549.97 E 3611.6~ N 25 25 E 3320.51 N 1578.32 E 3676.53 N 25 25 E 3378.90 N 1606.46 E 374.1,,35 N 25 26 E 3¢37.20 N 1634.43 E 3806.01 N 25 26 E 0 0.56 0.34. 0.62 0.52 0 0.38 0.13 0.28 0.77 3495.41 N 1662.03 £ 3870.43 N 25 26 E 3553.13 N 1689.56 E 3934..38 N 25 26 E 3611.14 N 1717.42 E 3998.73 N 25 26 E 3669.86 N 1745.05 E 4063.63 N 25 26 E 3729.4.8 N 1772.49 E 4129.25 N 25 25 E 3789.90 N 1799.85 ~ 4195.57 N 25 24 E 3850.80 N 1827.02 E 4252.23 N 25 23 E 391Z.14 N 1853.9Z E ~32~.19 N 25 21 E 3973.97 N 18~0.88 E ¢396.60 N 25 20 E 4036.40 N 1907.99 E 4464.63 N 25 18 E COMPUTATION DATE: 15-N0¥-90 PAGE BP EXPLORATION DATE OF SURVEY: OI~NOV-ZO90 2-38¢SN01) KELLY BUSHING ELEVATION' S4 50 FT SAG NORTH ' NORTH SLOPE, ALASKA ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN FEET BEG/lO0 FEET FEET FEET DEG MIN 8000.00 6140.65 6086.15 43 51 8100.00 6212.32 6157.82 8200.00 6282.91 6228.4! 45~5 8300.00 6352.84 6298.34 45 32 8400.00 6423.16 6368.66 8500.00 6493.64 6439.14 45 7 8600.00 6564.55 6510o05 8700.00 S635.42 6580.91 44 53 8800.00 6706.45 6651.95 '44 50 8900.00 6777.62 6723.[2 44 41 9000.00 6848.66 6794.16 44 40 9100.00 6919.83 6865.33 44 29 9100~00 6991.36 6936.84 44 28 9300.00 7063.03 7008.53 43 54 9400°00 7135.27 7080.77 43 38 9500.00 7207.71 7153.2! 43 20 9600.00 7280.73 7126o23 42 45 9700°00 7354.55 7300.05 42 10 9800.00 7428.57 7374.07 42 30 9900.00 7502.74 7448.24 61 49 10000.00 7577.32 7522.82 41 41 10100.00 7652.22 7597.72 40 54 10200.00 7728.21 7673.71 40 47 10300.00 7803.51 7749.01 41 27 10400.00 7878.07 7823.57 42 9 10500.00 7951.87 7897.37 42 41 10600.00 8025.09 7970.59 43 10 10700.00 8097.69 8043.19 43 47 t0800.O0 8169.45 8114.95 44 18 10900.00 8241.23 8186.73 44 7 q11000.00 8312.79 8258.29 64 26 11100.00 838,.10 8329.60 44 31 11200.00 8455.04 8400.54 44 55 11300.00 8525.28 8470.78 45 46 11400°00 8594.82 8540.32 46 4 11500.00 8664.18 8609.68 46 6 11600.00 8733.42 8678.92 46 12 11700.00 8802.54 8748.04 46 17 11800.00 8871.51 8817.01 46 32 11900.00 8940.25 8885.75 66 34 N 23 31 E 4531.68 N 23 30 E 4601.:30 N 23 37 E 4672.01 N 2.3 26 E 4743.37 N 23 13 E 4814.32 N 23 0 E 4885.12 N 22 51 E 4955.46 N 22 58 E 5025.84 N 23 5 E 5096.06 N 23 12 E 5166.16 N 23 8 E 5Z36.40 N 22 54 E 5306.48 N 22 45 E 5376.21 N 22 33 E 5445.72 N 22 39 E 5514.68 N 22 33 E 5583.43 N 22 42 E 5651.55 N 22 50 E 5718.84 N 22 53 E 5785.91 N 21 59 E 5852.78 N 21 16 E 5919.12 N 20 28 E 5985.01 N 20 27 E 6049.60 N 20 40 E 6115.00 N ZO 49 E 6181.Z5 N 21 4 E 6148.35 N 21 33 E 6316.14. N Z2 12 E 6384.65 N 25 31 E 6454.15 N 31 3 E 6523.71 N 31 54. E 6593.32 N 31 58 E 6663.16 N 31 48 E 6733.37 N 32 3 E 6804.28 N 32 10 E 6875.84 N 32 38 E 6947.55 N 32 56 E 7019.31 N 33 37 E 7091.14 N 34 19 E 7162.99 N 34 56 E 7234.96 0.50 0.69 0.39 0.53 0.29 0.63 0.67 0.74 0.50 0.68 0.1) 0.38 0.41 0.34 0.16 1.14 0.78 0.69 0.80 0.74 0.35 3.52 0.93 4099.61 N 1935.4.5 E 4533.51 N 25 16 E 4.163.55 N 1963.27 E 4603.22 N 25 15 E 4128.48 N 1991.58 E 6674.01 N 25 13 E 4294.00 N 2020.15 E 47¢5.47 N 25 12 E 4359.32 N 20¢8.24 E 4.816.53 N 25 10 E 4424.55 N 2076.14 E 4887.43 N 25 8 E 4489.50 N 2103.58 E 4957.89 N 25 6 E 4554.48 N 2131.06 E 5028.39 N 25 5 E 4619.25 N 2158.60 E 5098.73 N 25 3 E 6683.85 N 2186.21 E 5168.94 N 25 I E 474.8.56 N 2213.90 E 5239.29 N 25 0 E 4813.21 N 2241.36 E 5309.49 N 24 58 E 4877.64 N 2268.48 E 5379.35 N 24 57 E 4941.98 N 2295.31 E 5449.00 N 24 55 E 5005.83 N 2321.87 E 5518.10 N 26 53 E 5069.45 N 2348.43 E 5586.98 N 24. 51 E 5132.56 N 2374.62 E 5655.25 N 26 50 E 5194.74 N 2400.76 E 5722.67 N 26 48 E 5256.69 N 1426.89 E 5789.87 N 26 47 E 5318.66 N 2452.53 E 5856.88 N 24 45 E 5380.61 N 24.77.05 E 5923.41 N 24 43 E 544.2.51 N 2500.67 E 5989.52 N 24 41 E 5503.43 N 2523.38 i 6054.35 N 2~ 38 E 0.5~ 5565.04 N 2546.46 E 6119.98 N 24 35 E 0.82 5627.35 N 2570.07 E 6186.47 N 24 33 E 0.49 5690.39 N 2594.15 E 6253.81 N 24 30 E 0.67 5753.85 N 2618.88 E 6321.81 N 24 28 E 1.01 5817.67 N 2646.49 E 6390.5! N 24 27 E '/: 4.27 5881.56 N 2672.17 E 6460.13 N 24 26 E 2.18 5962.74 N 2705.34 E 6529.55 N 24 29 E 0.60 0.77 0.66 0.39 0.29 0.47 0.13 0.62 0.46 0.79 6002.19 N 2742.02 E 6598.86 N 24. 33 E 6061.66 N 1779.16 E 6668.39 N 24 38 E 6121.49 N 2816.41 E 6738.30 N 24 42 E 6181.93 N 2854.00 E 6808.93 N 24 47 E 6242.81 N 2892.19 E 6880.22 N 24 51 E 6303.63 N 2930.78 E 6951.66 N 24 56 E 6364.26 N 2969.89 E 7023.11 N 25 1 E 6424.71 N 3009.48 E 7094..64 N 25 6 E 6484.76 N 3049.95 E 7166.19 N 25 11 E 6546.53 N 3091.20 E 7237.85 N 25 17 E COMPUTATIQN DATE: 15-NOV-90 PAGE BP EXPLORATION DATE OF SURVEY: 01-NOV-Z990 2-38(SN01) KELLY BUSHING ELEVATION: 54 50 FT SAG NORTH. NORTH SLOPE~ ALASKA ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE MEASURED'VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH OEG 12000.00 9008.85 8954.35 46 44 12100.00 9077.21 9022071 46 58 12200.00 9145o29 9090079 47 15 12300.00 9213.79 9159029 45 48 12400.00 9284.53 9230.03 44 20 12500.00 9356.41 9301.91 43 51 12600.00 9428.72 9374.22 43.29 12700.00 9501.39 9446.88 43 10 12800.00 9575.04 9520.54 41 54 12900°00 9650.30 9595080 40 31 13000°00 9727.07 9672.57 39 13 1~100o00 9805.37 9750.87 37 50 13200000 9885.37 9830.87 35 58 13300000 9967.20 9912.70 34 16 13400.00 10050°57 9996007 32 44 13500.00 10135.19 10080069 31 42 13600000 10221.48 10166°98 28 45 13700000 10309.92 10255°42 27 31 13800000 10398.61 10344.11 27 31 13831000 10426.11 10371.61 27 31 N 35 41 E 7306.94 N 36 14 E 7379°02 N 36 11 E 7451o29 N 35 50 E 7523.21 N 35 15 ~ 7593.09 N 35 27 E 7661.88 N 36 35 E 7730.07 N 36 58 E 7797.76 N 37 15 E 7864.32 N 37 28 E 7929.08 N 37 48 E 7992°02 N 38 19 E 8053.06 N 38 50 E 8111.81 N 39 41 ~ 8167.96 N 40 31 E 8221.70 N 39 40 E 8273.60 N 40 52 E 8322.79 N 41 14 E 8367.97 N 41 14 E 8412.73 N 41 14 E 8426.61 0°40 0.39 0.07 2.66 0.68 0.65 0.54 1.04 1o22 1.31 1.37 2.97 2.26 I .86 1.78 2.14 3.49 0.00 0.00 0.00 6603.90 N 3133.27 E 7309.51 N 25 23 E 5662.98 N 3176.13 E 7381.26 N 25 29 E 6722.05 N 3219.43 ~ 7453.24 N 25 35 E 6780.94 N 3262.31 E 7524.88 N 25 42 E 6838.48 N 3303.34 E 7594.53 N 25 47 E 6895.26 N 33~3.48 E 7663.12 N 25 52 E 6951.11 N 33!34.11 E 7731.11 N 25 58 E 7006013 N 3425.27 E 7798.61 N 26 3 E 7060.06 N 3466.08 5 7864.99 N 26 9 E 7112.43 N 3505.99 E 7929.60 N 26 14 E 7163.15 N 35~5.13 E 7992.41 N 26 ZO E 7212.19 N 3583.39 E 8053.35 N 26 25 E 7259.08 N 3620.82 E 8112.00 N 26 31 E 7303.60 N 3657.17 E 8168o07 N 26 36 E 7345.79 N 3692.79 E a221.76 N 26 41 E 7386.60 N 3727.06 E 8273.62 N 26 46 E 7425.25 N 3759.5,8 E 8322.79 N 26 51 E 7460.18 N 3790.60 E 8367,,97 N 26 56 E 7494°92 N 3821o06 E 8412o75 N 27 I E 7505.69 N 3830.50 E 8426.63 N 27 2 E COMPUTATION DATE: 15-NOV-90 PAGE BP EXPLORATION 2-38(SN01) SAG NORTH NORTH SLOPEr ALASKA DATE OF SURVEY: 01-NOV-1990 KELLY BUSHING ELEVATION: 54.50 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION aZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDR[Z. DEPARTURE SECTZON SEVERITY NORTH/SOUTH EAST/WEST OISTo AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG M[H 0.00 0.00 -54.50 0 0 1000.00 998.15 943.65 7 53 ZO00oO0 1948.25 1893o75. 28 42 3000.00 2719.54 2665.04 46 55 4000°00 3350.29 3295.79 53 40 5000.00 3939.64 3885.14 55 42 6000.00 ~635.66 4581.16 41 53 7000.00 53'32.54 5338.04 39 56 8000.00 5140.65 6086o15 43 51 9000.00 6848.66 6794.16 64 ¢0 N 0 0 ~ 0.00 N 21 45 W 18.41 N 20 0 E 295.87 N 23 38 E 923.35 N 27 58 E 1698.60 N 35 49 E 2504.31 N 25 27 5 3215o82 N 25 21 E 3869o15 N 23 31 E 4531.68 N 23 8 ~ 5236.40 0.00 1 2.12 1.53 1.88 1 0.29 0.42 0.50 0.13 0.00 N 0o00 E, 0.00 N 0 0 E 28.36 N 15.21 W 32,18 N 28 12 W 303.90 N 56.93 E 308.82 N 10 15 E 885.60 N 295.2~ E 933.52 N 18 26 E 1586.13 N 631.87 E 1705o50 N 21 45 E 2281.03 N 1039.0~ E 1506.53 N 24 29 E 2906.53 N 1378.73 E 3216.96 N 25 23 E 3495.41 N 1662.03 5 3870.63 N 25 26 E 6099.61 N 1935.45 E 4533.51 N 25 16 E 4748.56 N 2213o90 E 5239.29 N 25 0 E 10000.00 7577.32 7522.82 41 41 11000.00 8312.79 8258.29 44 24 12000°00 9008.85 8956.35 46 44 13000°00 9727.07 9672.57 39 13 13831.00 10426.11 10371.61 27 31 N 21 16 5 5919.12 N 31 56 E 6593.32 N 35 41 E 7306.9~, N 37 48 ~ 7992,,02 N 41 14 E 8426.61 0.35 0.60 0 .&O 1.37 0.00 5380.61 N 2477.05 E 5923.41 N 24 63 E 6002.19 N 27~2.01 E 6598.86 N 24 33 E 6603.90 N 3133.27 c~ 7309.'51 N 25 23 E 7163.15 N 35~5.13 E 7992.41 N 26 ZO E 7505.69 N 3830.50 E 8426.63 N 27 2 E COMPUTATION DATE: 15-NOV-90 PAGE BP EXPLORATION 2-38(SN01) SAG NORTH NORTH SLOPE9 ALASKA DATE DF SURVEY: 01-NOV-1.990 KELLY BUSHING ELEVATION: 5~.50 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ENGINEER: MCBRIDE TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0.00 0.00 -54.50 0 0 N 0 0 E 54,,50 54.50 0.00 0 17 N 69 19 E 154.50 154.50 100.00 0 28 S 58 57 E 254.51 254.50 ZO0. O0 0 32 S 78 10 E 354.51 354.50 300.00 0 31 N ~9 13 E 454.51 454.50 400.00 0 28 N 85 30 E 554.52 554.50 500.00 0 17 N 88 24 E 654.53 654.50 600.00 2 0 N 35 3 ~ 754°68 754.50 700.00 4 16 N 41 53 ~ 855.15 854.50 800.00 6 33 N 35 43 ~ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EaST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG 955.95 954.50 900°00 7 42 1056.90 1054.50 1000o00 8 1 1157.96 1.154.50 1100.00 8 43 1259o30 1254.50 1200.00 9 58 1361.20 !354.50 1300o00 12 22 1464.23 1454.50 1400.00 15 40 1569.21 1554.50 1500.00 19 30 1676.22 1654.50 1600. O0 21 59 1784.67 1754.50 1700.00 23 44 1894.62 1854.50 1800.00 25 33 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E -0.03 0.00 0.28 S 0.47 E 0.03 0.06 0.60 S 1.26 E 0.37 0.30 0.60 S 2.15 E 0.$0 0.00 0.63 S 3.00 E 1.14 0.53 0.56 S 3.63 E Z.lO 2.73 0.64 N 3.38 E ,3.95 2.62 4.59 N 0.31 ~ 7.95 1.86 12.10 N 6.27 W N 26 4 I,I N 15 22 ~1 N 5541,1 N 0 36 E N 8 35 E N 16 40 E N 20 49 E N 20 57 E N 19 19 E N 17 54 E 2007.14 1954.50 1900.00 28 51 2122.88 2054.50 2000.00 31 36 2242.08 2154.50 2100.00 34 4 2364°94 2254.50 2200.00 37 11 2493.27 2354.50 2300.00 ~0 25 2627.01 2454.50 2400.00 42 33 2764.68 2554.50 2500.00 44 10 2905.85 2654.50 2600.00 45 43 3051.59 2754.50 2700.00 47 44 3202.85 2854.50 2800.00 49 27 14.64 1.28 22.90 N 23.93 1.56 35.82 H 35.52 1.82 50.14 N 49.89 1.78 66.56 N 67.94 3.16 86.04 N 91.92 '4.46 110.13 N 123.49 3.17 140.19 N 161.36 2.20 175.73 N 203.03 2.34 215.11 N 248.26 2.39 258.37 N 3359.85 2954.50 2900.00 51 14 3518.84 3054.50 3000.00 51 2 3678.80 3154.50 3100.00 51 39 3841.24 3254.50 3200.00 52 20 4007.14 3354.50 3300.00 53 46 4179.68 3454.50 3400.00 54 52 4351.98 3554.50 3500.00 53 48 4518.35 3654.50 3600.00 52 29 4682.59 3754.50 3700.00 52 55 4851.71 3854.50 3800.00 54 16 N 20 9 E 299.30 N 22 9 E 357.27 N 22 53 E 421.95 N ~2 54 ~ 493.12 N~2 29 ~ 573.31 N g2 3 5 661.80 N 22 14 ~ 756.10 N 22 53 E 855.42 N 24 3 E 961.24 N 24 46 E 1074.61 N 25 35 5 1195.58 N 25 57 E 1319.16 N 26 10 E 1444o00 N 26 20 E 1572.01 N 28 3 5 1704.36 N 2.8 36 E 1844.92 N 28 52 E 1985.16 N 29 22 E 2118.02 N 30 25 E 2248.12 N 33 4 E 2384.02 0.00 N 0 0 E 0.00 N 0 0 E 0.54 S 59 32 E 1.39 S 64 28 E 2.26 S 72 36 E 3.07 S 78 14 E 3.67 S 81 1.0 E 3.44 N 79 19 E 4.60 N 3 49 13.63 N 27 24 ti 12.79 I,t 26.23 N 29 11 17.70 I,I 39.96 N 26 18 ti Z0.32 ti 54.10 N 22 3 ti 20.94~ ~1 69.77 N 17 28 19.43 ~ 88.21 N 12 44 ti 13.90 W 111.00 N ~ 7 12 ti 3.38 ~ 140.23 N I 23 ti 10.27 E 176.03 N 3 21 E 24.75 E 216.53 N 6 34 E 39.45 E 261.36 N 8 41 E 2.15 2.26 1.60 2.84 2.71 1.36 1.00 1.54 1.38 1.41 307.14 N 56.13 E 312.22 N 10 21 E 361.41 N 77.28 E 369.58 N 12 4 E 421.25 M 102.31 E 433.49 N 13 39 E 486.99 N 130.03 E 504.05 N 14 57 E 561.09 N 161.18 E 583.79 N 16 2 E 643.35 N 194.65 E 672.15 N 16 50 E 730.95 N 230.39 E 766.40 N 17 30 E 823.06 N 268.36 E 865.71 N 18 4 E 920.30 N 310.58 E 971.30 N 1~ 39 E 1023.57 N 357.62 E 1084.24 N 19 16 E 0.67 0.64 0.95 0.21 1.75 0.34 1.37 0.65 1.26 1.81 1133.10 N 409.09 E 1204.69 N 19 51 E 1244.40 N 462.85 E 1327.69 N 20 24 E 1356.49 N 517.8¢ E 1451.97 N 20 54 E 1¢71.33 N 574.40 5 1579.~8 N 21 ZO E 1589.21 N 634.58 E 1711.22 N 21 46 E 1712.95 N 701.35 E 1850.97 N 22 16 E 1835.99 N 768.79 E 1990.45 N 22 43 E 1952.13 N 833.51 E 2122.63 N 23 7 E 2065.07 N 898.47 E 2252°05 N 23 31 E 2181.13 N 970.07 E 2387.13 N 23 59 E COMPUTATZON DATE: 15-NOV-90 PAGE BP EXPLORATZON 2-38(SN01) SAG NORTH NORTH SLOPEr ALASKA DATE OF SURVEY: 01-NOV-1990 KELLY BUSHING ELEVATION: 54.50 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG #IN DEG HZN 5026.40 3954.50 3900.00 55 46 5195.01 4054.50 4000.00 5! 15 5345.02 4154.50 4100.00 44, 1,9 5482.39 4,254.50 4200.00. 4,3 8 5619.81 4354.50 4300. O0 42 52 5755.63 4454.50 4400.00 42 13 5890.32 4554.50 4500.00 42 20 6025030 4654.50 4600,,00 41 50 6159.14 4754.50 4700.00 41 25 6292.16 4854.50 4800.00 40 59 6626.53 4954.50 4900.,00 40 46 6556.37 5054.50 5000.00 40 40 6688.01 5154.50 5100.00 40 24 6819.31 5254.50 5200.00 40 18 6950.31 5354.50 5300.00 40 7 7080.61 5454050 5400.00 39 38 7211.20 5554.50 5500.00 40 21 7342'88 5654.50 5600.00 40 58 7476.12 5754.50 5700.00 41 39 7610.28 5854.50 5800.00 41 57 7745.11 5954.50 5900.00 42 22 7881.24 6054.50 6000.00 43 3 8019.22 6154.50 6100.00 43 59 8159.52 6254.50 6200.00 45 15 8302.36 6354.50 6300.00 45 31 8444.48 6454.50 6400.00 45 8585.87 6554.50 6500.00 44 41 8726,89 6654.50 6600.,00 44 42 8867.53 6754.50 6700.00 44 31 9008021 6854.50 6800.00 44 40 9148.49 6954.50 6900.00 44 16 9288.16 7054.50 TO00.O0 43 57 9426.57 7154.50 7100.00 43 37 9564016 7254.50 7200.00 43 4 9699.93 7354.50 7300.00 42 10 9835.12 7454.50 7400.00 42 14 9969,44 7554.50 7500.00 41 45 10103.01 7654.50 7600.00 40 50 10234.80 7754.50 7700.00 41 4 10368.27 7854.50 7aO0.O0 41 55 VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG #IN N 36 0 E 2525.87 N 32 56 E 2660.21 N 27 42 E 2771.59 N 25 40 E 2865.76 N 25 23 E 2959.99 N 25 20 E 3051.87 N 25 27 E 3142.08 N 25 29 E 3232.70 N 25 30 E 3321.63 N 25 33 E 3409.31 0.82 2.78 3.42 O. 71 0.74 1 0.56 0.32 0.64 0.50 2298.71 N 1051.84 E 2527.93 N 24 35 E 2409.96 N 1129.48 E 2661.51 N 25 7 E 2505.98 N 1186.39 E 2772.63 N 25 20 E 2590.36 N 1228.21 E 2866.79 N 25 22 E 2675.36 N 1268.94 E 2961.04 N 25 23 E 2758.42 N 1308.29 E 3052.96 N 25 22 E 2839.92 N 1347.03 E 3143.19 N 25 23 E 2921.77 N 1385.99 E 3233.84 N 25 23 E 3002.11 N 1424.20 E 3322.80 N 25 23 E 3081.23 N 1462o05 E 3410.51 N 25 23 E N 26 I E 3496.03 N 26 6 E 3581.94 N 25 49 E 3667.53 N 25 41 E 3752.60 N 25 20 E 3837.21 N 25 38 E 3920.71 N 25 26 E 4004.67 N 24 44 ~ 4090.30 N 24 16 E 4178.27 N 23 46 E 4267.60 0.46 0.54 0.33 0.00 0.18 0.43 0044 0.79 0.43 0.50 ,3159.38 N 1499.6~ E 3497.24 N 25 24 E 3236.53 N 1537.48 E 3583.15 N 25 25 E 3313.50 N 15~4.93 E 3668.75 N 25 25 E 3390.16 N 1611.87 E 3753.84 N 25 26 E 3466.52 N 1648.35 E 3838.47 N 25 26 E 3541.97 N 1684.20 E 3921.99 N 25 26 E 3617.68 N 1720o53 E 4005.98 N 25 26 E 3695.30 N 1756.81 E 4091.65 N 25 26 E 3775.42 N 1793.33 E 4179.69 N 25 24 E 3857.09 N 1829.79 E 4269.11 N 25 23 E N 23 33 E 4357.88 N 23 26 E 4450.09 N 23 31 5 4544.98 N 23 34 E 4643.22 N 23 23 E 4745.05 N 23 12 E 4845.83 N 22 51 E 4945.55 N 23 0 E 5044.74 N 23 11 E 5143.42 N 23 7 E 5242.16 1.05 0.76 0.87 1.22 0.50 0.44 0.63 0.67 0.68 0.14 3939.93 N 1866.05 E 4359.49 N 25 21 E 4024.64 N 1902.89 E 4451.82 N 25 18 E 4111.82 N 1940.76 5 4546.83 N 25 16 E 4202.06 N 1980.03 E 4645.19 N 25 14 E 4295.55 N 2020.83 E 4747.15 N 25 12 E 4388.33 N 2060.68 E 4848.08 N 25 9 E 4480.35 N 2099.72 E 4947.96 N 25 T E 4571.92 N 2138.45 E 5047.32 N 25 4 E 4662.90 N 2177.23 e 5146.16 N 25 2 E 4753.87 N 2216.17 E 5245.06 N 25 0 E N 2.2 50 E 5340.30 N 22 34 E 5437.54 N 22 41 E 5532.96 N 22 33 E 5627.21 N 22 50 E 5718.79 N 22 39 E 5809.54 N 21 26 E 5898.88 N ZO 27 E 5986.96 N 20 29 E 6072.26 N 20 47 E 6160.12 0.23 0.16 0.47 0.94 0.68 1.56 0.'/2 3.18 0.72 0.58 4844.45 N 2254.54 E 5343.37 N 24 57 E 4934.39 N 2292.16 E 5440.80 N 24 55 E 5022.74 N 2328.93 E 5536.41 N 24 53 E 5110.01 N 23~5.24 E 5630.85 N 24 50 E 5194.69 N 2400.74 E 5722.62: N 24 48 E 5278.52 N 2436.07 E 5813.54 N 24 46 E 5361.67 N 2469.64 E 5903.11 N 24 44 E 5444.35 N 2501.35 E 5991.47 N 24 41 E 5524.78 N 2531.35 E 6077.05 N 24 37 E 5607.49 N 2562.52 E 6165.27 N 24 34 E COHPUTATIgN OAT£: 15-NOV-90 ". PAGE 8 BP EXPLORATZON 2-38CSN01) SAG NORTH NORTH SLOPE. ALASKA DATE DF SURVEY: 01-NOV-1990 KELLY BUSHING ELEVATION: 56050 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH OEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 10503058 7956.50 7900000 42 4Z 10660.39 8054.50 8000000 63 22 10779.11 8156.50 8100000 44 19 10918.69 8254.50 8200.00 44 14 11058.52 8356.50 8300000 44 33 11199.26 8456.50 8600000 64 55 11341094 8556.50 8500000 45 55 11686.05 8656.50 8600000 46 6 11630.68 8754.50 8700000 66 16 11775.28 8854.50 8800.00 66 29 N 21 5 E 6250.77 N 21 48 E 6343.71 N 24 21 E 6439.57 N 31 30 E 6536.56 N 32 I E 6634.20 N 31 68 E 6732.83 N 32 5 E 6836.26 N 32 36 E 6937.56 N 33 3 E 7041.Z0 N 36 10 E 7165.21 11920074 8954.50 8900.00 46 39 12066.72 9054050 9000.00 66 58 12213.57 915¢. 50 9100000 47 13 12357083 9254.50 9200000 44 50 12697.35 9354.50 9300000 43 51 12635051 9456.50 9400.00 43 28 12772.33 9554.50 9500000 62 15 12905053 9654.50 9600000 ¢0 27 13035.27 9754.50 9700000 38 38 13161067 9854.50 9800.00 36 42 N 35 6 E 7269.~8 N 36 4 E 7355.00 N 36 10 E 7461.12 N 35 25 E 7563.81 N 35 25 E 7660.06 N 36 46 E 7754.15 N 37 12 E 7846.07 N 37 30 E 7932.61 N 37 53 E 8013.80 N 38 39 E 8089.59 13286.62 9956.50 9900.00 36 33 13604067 10054050 10000.00 32 60 13522064 10154.50 10100.00 31 11 13637068 10256050 10200.00 27 46 13750026 10354.50 10300.00 27 31 13831.00 10626.11 10371.61 27 31 N 39 33 E 8159.50 N 40 29 E 8224.15 N 39 43 E 8285.12 N 41 12 E 8339.96 N 61 14 E 8390.67 N 41 16 E 8626.61 0.51 0.72 3.66 I °32 1.01 0.63 0 0.41 0.54 0.62 5692.65 N 2595.02 E 6256.23 N 24 30 E 5779.58 N 2629.10 E 6369.47 N 24 28 E 5868.36 N 2666.02 E ~S445.56 N 24 26 E 5953.76 N 2712.03 E 6562.35 N 24 29 E 6037.00 N 2763.75 E 6639.56 N 24 36 E 6121.03 N 2816.12 E 6737.77 N 26 42 E 6207.41 N 2869.98 E 6838.77 N 26 69 E 6295.16 N 2925.36 E 694,1.67 N 26 55 E 6382.72 N 2981.87 E 7044.90 N 25 Z E 6469.93 N 3039.86 5 7148.48 N 25 10 E 0.84 ;6556.87 N 3099.85 E 7252.70 N 25 18 E 0.43 6643.3.3 N 3161.78 E 7357.35 N 25 27 E 0.43 1.34 0.66 0.30 1.36 1.39 1.63 1 6730.09 N 3225.31 E 7663.03 N 25 36 E 6814.33 N 3286.23 E 7565.35 N 25 65 E 6893.76 N 3342.41 E 7661.31 N 25 52 E 6970.71 N 3398.70 E 7755.12 N 26 0 E 7065.29 N 3454.86 E 7846.79 N 26 7 E 7115.28 N 3508.18 E 7933.13 N 26 15 E 7180.66 N 3558.74 E 8014.15 N 26 22 E 7241.37 N 3606.61 E 8089.81 N 26 29 E 1.95 1.77 2.53 2.87 0.00 0.00 7296.92 N 3651.63 ~ 8159.62 N 2~ 35 E 7347.71 N 3694.62 E 8226.21 N 26 42 E 7395.69 N 3734.60 E 8285.13 N 26 48 E 7438.61 N 3771.21 E 8339.96 N 26 53 E 7477.64 N 3805o91 E 8390.47 N 26 58 E 7505.69 N 3830.50 E 8426.63 N 27 2 E BP EXPLORATION 2-38(SN01) SAG NORTH NORTH SLOPEr ALASKA HARKER GCT LAST READING PELTO DRILLER'S DEPTH COMPUTATION DATE= 15-NOV-90 PAGE 9 DATE OF SURVEY: 01-NOV-1990 KELLY EIUSH[NG ELEVATION.' 54.50 FT ENGINEER: MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LocATION = Z011t SNL g Z28~' WELt SEC36 TIZN RI6E MEASURED DEPTH TVD RECTANGULAR COORDINATES 8ELOg KB FROM KB SUB-SEA NORTH/SOUTH EASTtgEST 13652.10 10267.44 10212.94 7¢¢3.54 N 3776°02 E 13745.00 10349.83 10295.33 7¢75.8t N 3804o31 E 13831.00 10426.11 10371.61 7505.69 N 3830.50 E COMPUTATION DATE: 15-NOV-90 PAGE '10 BP EXPLORATION 2-38¢SN01) SAG NORTH NORTH SLOPEr ALASKA KELLY ff~f~,~, STRATZGRAPHIC SUMMARY SURFACE LOCATION : Z011e SNL E MARKER MEASURED DEPTH BELOW KB TVO FROM KB SUB-SEA PBTD DRZLLEReS DEPTH 13745.00 10349°63 10295°33 13831.00 10426oll 10371o61 FINAL NELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIHUTH FEET DEG 13831.00 104,?.6.11 10371o61 8426°63 N 27 Z E' DATE OF SURVEY: 01-Nov-'1990 9USHTNG ELEVATION: 54.50 FT ENGINEER: MCBRIDE 2284e WELt SEC36 T12N R16E RECTANGULAR COOROZNATES NORTH/SOUTH EAST/~EST 7~75o31 N 3804.31E 7505.69 N 3830°50 E SCHLUMBERGER O I REC T I ONAL SURV E Y COMPANY BP EXPLORATION WELL 2-38 ( SNO i ) FIELD SRO NORTH COUNTRY USA RUN ONE DATE LOOOED O i - NOV - 90 REFERENCE 74182 HORIZONTAL PROJECTION WELL: 2-38 (SN01) (2011' SNL, 2284'WEL, SEC 3f' .... 12N, R12E) NI3RTH ! 2__noo REF '74 !82 SCALE = I/;ZO00 IN/FT 60OO 400O SOUTH -4000 -61:X30 -400O -2000 0 14EST 20O0 400O 6OO0 8013O lO00O EA6T WELL: 2-38 (SN01) (2011' SNL, 2284' WEL, SEC 36, T~I, R12E) VI:K I IL/RL I"RUJrL I -4__000 -2000 0 0 2000 41300 BO00 EIO00 1000O PROJECTION ON VERTICAL. PLANE ~'7. - ~0'7. FaCRLEO IN YERTICRL 0F..PTH~ HORIZ SCALE -- 1/20OO IN/FT ORIGINAL GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY BP'EXPLORTION COMPANY MPI 2-38/SN-01 WELL NAME ENDICOTT, ALASKA LOCATION AL1090D33 JOB NUMBER KEVIN DESORMEAUX NAME MWD 10/23/90 TYPE SURVEY DATE SUPERVISOR TITLE SIGNATURE DEPTH INTERVAL 485 FT. 13365 FT. FROM TO 10/02/90 10/23/90 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. RECEIVED FEB - ,5 t99! Alaska Oil & Gas Cons. Commission Anchorage GREAT LAND Client .... : Field ..... : Well ...... : Section at: Engineer..: DIRECTIONAL DRILLING, BP EXPLORATION ENDICOTT MPI 2-38/SN-01 N,27.65,E LEJEUNE/DESORMEAUX INC. 3 3 3 3 3 MEAS INCLN DEPTH ANGLE 485 0.25 564 0.25 655 2.00 745 4.00 835 5.50 3 927 7.25 3 1017 8.00 3 1106 8.25 3 1227 9.90 3 1318 11.30 3 1412 13.80 3 1506 17.30 3 1597 20.60 3 1691 22.80 3 1784 23.80 3 1878 25.10 3 1971 27.90 3 2063 30.30 3 2157 32.50 3 2258 34.40 VERTICAL-DEPTHS BKB SUB-SEA 485.0 430.5 564.0 509.5 655.0 600.5 744.8 690.3 834.5 780.0 926.0 871.5 1015.2 960.7 1103.3 1048.8 1222.8 1168.3 1312.2 1257.7 SECTION DISTNCE 0.5 0.6 1..8 2.7 5.1 RECORD OF SURVEY DIRECTION BEARING S 22.00 E N 21.00 E N 54.00 W N 48.00 W N 39.00 W 9.7 N 32.00 W 17.1 N 16.00 W 27.0 N 5.00 W 43.2 N 3.00 W 58.0 N 1.60 E 1403.9 1349.4 77.1 1494.5 1440.0 101.7 1580.5 1526.0 131.0 1667.9 1613.4 165.5 1753.3 1698.8 201.9 1838.9 1784.4 240.3 1922.1 1867.6 281.3 2002.5 1948.0 325.7 2082.7 2028.2 374.4 2167.0 2112.5 429.9 3 2351 36.90 2242.5 2188.0 484.0 10/31/90 'Survey Codes: Computation...: RADIUS OF CURVATURE Survey Date...: 10/23/90 RKB Elevation.: 54.50 ft Reference ..... : AL1090D33 Magnetic Dcln.: 30.30 E (MSN01D) 3/MWD RELATIVE,COORDINATES FROM-WELL-HEAD 0.1N 0.TE O.1N 1.0E 1.7N 0.5E 4.7N 3.1W 10.iN 8.2W 18.4 N 14.2 W 29.3 N 19.0 W 41.6 N 21.3 W 60.7 N 22.6 W 77.4 N 22.8 W N 13.00 E 97.6 N 20.3 W N 18.60 E 121.9 N 13.4 W N 21.10 E 149.7 N 3.4 W N 20.00 E 182.2 N 8.8 E N 19.10 E 216.9 N 21.1 E N 18.10 E 253.7 N 33.6 E N 19.20 E 293.0 N 46.8 E N 21.10 E 335.0 N 62.2 E N 22.80 E 380.5 N 80.5 E N 24.30 E 431.5 N 102.8 E N22.40E 481.3 N 124.3 E CLOSURE DISTNCE BEARING 0.8 N 79.00 E 1.0 N 81.75 E 1.8 N 17.12 E 5.6 N 33.59 W 13.0 N 39.23 W 23.2 N 37.59 W 34.9 N 33.00 W 46.8 N 27.10 W 64.8 N 20.46 W 80.7 N 16.44 W 99.7 N 11.72 W 122.6 N 6.27 W 149.7 N 1.29 W 182.4 N 2.78 E 217.9 N 5.57 E 255.9 N 7.53 E 296.8 N 9.08 E 340.8 N 10.52 E 388.9 N 11.95 E 443.6 N 13.40 E 497.0 N 14.48 E DL /lOO 0.05 0.00 1.93 2.22 1.67 1.91 0.90 0.38 1.36 1.55 2.75 3.76 3.64 2.35 1.09 1.40 3.02 2.66 2.40 1.94 2.79 MPI 2-38/SN01 MEAS INCLN DEPTH ANGLE 2445 39.10 2487 40.20 2631 42.60 2724 44.00 2817 44.50 3 2909 45.90 3 3004 47.10 3 3098 48.30 3 3191 49.40 3 3291 50.60 3 3378 51.30 3 3469 50.90 3 3562 51.20 3 3653 51.60 3 3747 51.90 3 3839 52.50 3 3933 53.30 3 4025 54.30 3 4119 54.50 3 4212 55.10 3 4306 54.60 3 4400 53.40 3 4492 52.70 3 4585 52.60 3 4677 52.70 3 4770 54.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2316.6 2262.1 541.6 2348.9 2294.4 568.3 2456.9 2402.4 663.0 2524.6 2470.1 726.4 2591.2 2536.7 791.1 2656.1 2601.6 856.2 2721.5 2667.0 924.9 2784.7 2730.2 994.3 2845.9 2791.4 1064.1 2910.2 2855.7 1140.6 2965.0 2910.5 1208.1 3022.1 2967.6 1278.9 3080.6 3026.1 1351.2 3137.4 3082.9 1422.2 3195.6 3141.1 1496.0 3252.0 3197.5 1568.6 3308.7 3254.2 1643.6 3363.0 3308.5 1717.8 3417.7 3363.2 1794.3 3471.3 3416.8 1870.3 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 22.60 E 534.7 N 146.4 E N 21.60 E 559.6 N 156.5 E N 21.70 E 648.1 N 191.6 E N 22.10 E 707.2 N 215.4 E N 23.20 E 767.1 N 240.4 E N 23.90 E N 23.20 E N 23.60 E N 24.6~ E N 24.40 E 827.0 N 266.5 E 890.1 N 294.0 E 953.9 N 321.6 E 1017.9 N 350.2 E 1087.6 N 382.0 E N 26.10 E 1148.7 N 410.8 E N 25.20 E 1212.5 N 441.5 E N 25.60 E 1277.8 N 472.5 E N 25.40 E 1342.0 N 503.1 E N 25.00 E 1408.8 N 534.5 E N 25.80 E N 28.00 E N 27.20 E N 27.80 E N 28.00 E 3525.4 3470.9 1947.1 N 29.90 E 3580.7 3526.2 2023.1 N 30.00 E 3636.0 3581.5 2096.5 N 29.90 E 3692.4 3637.9 2170.4 N 31.70 E 3748.2 3693.7 2243.4 N 30.70 E 3803.7 3749.2 2317.8 1474.5 N 565.7 E 1541.4 N 599.6 E 1607.1 N 634.0 E 1674.9 N 669.3 E 1742.1 N 704.9 E 1809.4 N 742.1 E 1875.2 N 780.0 E 1938.9 N 816.8 E 2002.4 N 854.6 E 2065.0 N 892.5 E N 32.20 E 2128.7 N 931.4 E Page 2 10/31/90 CLOSURE DISTNCE BEARING 554.4 N 15.31 E 581.0 N 15.62 E 675.8 N 16.47 E 739.3 N 16.94 E 803.9 N 17.40 E 868.8 N 17.86 E 937.4 N 18.28 E 1006.7 N 18.63 E 1076.4 N 18.99 E 1152.7 N 19.35 E 1219.9 N 19.68 E 1290.4 N 20.01 E 1362.4 N 20.29 E 1433.2 N 20.55 E 1506.8 N 20,78 E 1579.3 N 20.99 E 1653.9 N 21.26 E 1727.7 N 21.53 E 1803.7 N 21.78 E 1879.3 N 22.03 E DL /lOO 2.34 2.80 1.67 1.52 0.79 1.57 1.32 1.30 1.34 1.21 1.44 0.74 0.42 0.46 0.41 0.85 1.73 1.23 0.47 0.66 1955.6 N 22.30 E 1.44 2031.0 N 22.59 E 1.28 2103.9 N 22.84 E 0.76 2177.2 N 23.11 E 1.23 2249.6 N 23.37 E 0.70 2323.5 N 23.63 E 1.75 'Survey Codes: 3/MWD MPI 2-38/SN01 S MEAS C DEPTH 3 4870 3 4962 3 5034 3 5128 3 5220 INCLN ANGLE VERTICAL-DEPTHS BKB SUB-SEA 54.50 3862.2 3807.7 55.60 3914.9 3860.4 56.10 3955.3 3900.8 53.30 4009.6 3955.1 50.10 4066.6 4012.1 3 5313 45.90 4128.8 4074.3 3 5424 43.20 4207.9 4153.4 3 5519 43.30 4277.1 4222.6 3 5613 43.00 4345.7 4291.2 3 5706 42.60 4413.9 4359.4 3 5798 42.40 4481.8 4427.3 3 5891 42.30 4550.5 4496.0 3 5987 42.00 4621.7 4567.2 3 6082 41.80 4692.4 4637.9 3 6174 41.50 4761.1 4706.6 6269 41.20 4832.4 4777.9 6362 41.00 4902.5 4848.0, 6454 40.90 4972.0 4917.5 6555 40.70 5048.5 4994.0 6649 40.50 5119.8 5065.3 3 6742 40.60 5190.5 5136.0 3 6835 40.40 5261.2 5206.7 3 6927 40.30 5331.3 5276.8 3 7022 40.00 5403.9 5349.4 3 7110 39.90 5471.4 5416.9 3 7205 40.60 5543.9 5489.4 'Survey Codes: 3/MWD RECORD OF SURVEY SECTION DISTNCE 2398.6 '2473.4 2532.5 2608.7 2680.5 2749.6 2827.4 2892.5 2956.8 3019.9 3082.0 3144.6 3209.0 3272.3 3333.5 3396.'2 3457.3 3517.6 3583.6 3644.7 3705.1 3765.4 3824.9 3886.1 3942.5 4003.8 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 CLOSURE DISTNCE BEARING N 34.20 E 2196.6 N 975.9 E 2403.6 N 23.95 E N 35.30 E 2258.5 N 1018.8 E 2477.7 N 24.28 E N 34.90"E 2307.3 N 1053.1 E 2536.2 N 24.53 E N 34.00 E 2370.5 N 1096.5 E 2611.8 N 24.82 E N 31.50 E 2431.2 N 1135.5 E 2683.3 N 25.04 E N 28.50 E 2491.1 N 1170.1 E N 25.20 E 2560.5 N 1205.2 E N 26.10 E 2619.2 N 1233.4 E N 27.00 E 2676.7 N 1262.2 E N 25.00 E 2733.5 N 1289.9 E N 25.20 E N 25.10 E N 25.30 E N 25.20 E N 26.20 E 2789.8 N 1316.2 E 2846.5 N 1342.8 E 2904.8 N 1370.3 E 2962.2 N 1397.3 E 3017.3 N 1423.9 E 2752.2 N 25.16 E 2830.0 N 25.21 E 2895.1 N 25.22 E 2959.4 N 25.25 E 3022.5 N 25.26 E 10/31/90 DL /lOO 1.42 1.45 0.79 3 .O4 3.83 4.81 2.80 0.46 0.55 1.08 3084.7 N 25.26 E 0.24 3147.3 N 25.26 E 0.12 3211.8 N 25.25 E 0.33 3275.2 N 25.25 E 0.22 3336.3 N 25.26 E 0.58 N 26.50 E 3073.5 N 1451.7 E 3399.1 N 25.28 E N 26.50 E 3128.2 N 1479.0 E 3460.2 N 25.30 E N 26.50 E 3182.2 N 1505.9 E 3520.5 N 25.32 E N 26.10 E 3241.3 N 1535.1 E 3586.5 N 25.34 E N 25.00 E 3296.5 N 1561.5 E 3647.7 N 25.35 E 3351.3 N 1587.0 E 3406.i N 1612.5 E 3460.3 N 1637.3 E 3516.2 N 1662.3 E 3567.7 N 1685.4 E 3708.1 N 25.34 E 3768.5 N 25.33 E 3828.1 N 25.32 E 3889.3 N 25.30 E 3945.8 N 25.29 E 0.34 0.22 0.11 0.26 0.54 N 24.90 E N 25.10 E N 24.00 E N 24.10 E N 24.30 E N 25.20 E 3623.5 N 1711.1 E 0.12 0.23 0.51 0.32 0.15 4007.2 N 25.28 E 0.84 MPI 2-38/SN01 S MEAS INCLN C DEPTH ANGLE 3 7299 41.10 3 7401 41.50 3 7495 41.80 3 7590 42.10 3 7691 42.30 3 7784 42.70 3 7878 43.30 3 7973 44.00 3 8076 44.50 3 8153 45.10 3 8246 45.70 3 8341 45.60 3 8435 45.30 3 8531 45.10 3 8624 44.80 3 8717 45.00 3 8811 44.80 3 8907 44.90 3 9008 44.80 3 9102 44.60 3 9195 44.40 3 9287 44.20 3 9389 43.90 3 9482 43.50 3 9557 43.30 3 9655 42.70 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5615.0 5560.5 4065.2 5691.6 5637.1 4132.4 5761.9 5707.4 4194.8 5832.5 5778.0 4258.2 5907.4 5852.9 4325.9 5975.9 5921.4 4388.5 6044.7 5990.2 4452.5 6113.4 6058.9 4517.9 6187.2 6132.7 4589.5 6241.8 6187.3 4643.6 6307.1 6252.6 4709.7 6373.5 6319.0 4777.5 6439;5 6385.0 4844.2 6507.1 6452.6 4912~2 6572.9 6518.4 4977.7 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 4 10/31/90 CLOSURE DISTNCE BEARING DL /lOO N 25.30 E 3679.1 N 1737.3 E 4068.7 N 25.28 E 0.53 N 24.10 E 3740.3 N 1765.5 E 4136.0 N 25.27 E 0.65 N 24.40 E 3797.2 N 1791.1 E 4198.5 N 25.25 E 0.35 N 24.30 E 3855.1 N 1817.3 E 4261.9 N 25.24 E 0.32 N 24.00 E 3917.0 N 1845.1 E 4329.8 N 25.22 E 0.24 N 22.70 E N 23.80 E N 23.60 E N 22.10 E N 24.50 E N 23.70 E N 23.60 E N 22.80 E N 23.60 E N 24.30 E 6638.8 6584.3 5043.2 N 23.20 E 6705.4 6650.9 5109.4 N 22.90 E 6773.5 6719.0 5176.8 N 23.20 E 6845.1 6790.6 5247.9 N 23.50 E 6911.9 6857.4 5313.8 N 22.20 E 3974.7 N 4033.6 N 4093.6 N 4159.8 N 4209.7 N 1870.0 E 1895.3 E 1921.6 E 1949.6 E 1971.0 E 4270.1 N 4332.3 N 4393.9 N 4456.5 N 4516.6 N 4392.6 N 25.20 E 4456.6 N 25.17 E 4522.2 N 25.15 E 4594.0 N 25.11 E 4648.2 N 25.09 E 0.77 0.84 0.74 0.86 1.75 1998.0 E 4714.4 N 25.08 E 0.78 2025.3 E 4782.4 N 25.06 E 0.12 2051.7 E 4849.3 N 25.03 E 0.54 2078.5 E 4917.4 N 25.00 E 0.47 2105.2 E 4983.1 N 24.99 E 0.49 4576.6 N 2131.6 E 5048.7 N 24.97 E 4637.7 N 2157.6 E 5115.0 N 24.95 E 4700.0 N 2184.1 E 5182.7 N 24.92 E 4765.4 N 2212.4 E 5253.9 N 24.90 E 4826.3 N 2238.0 E 5320.0 N 24.88 E 4886.7 N 4946.1 N 5011.5 N . 5070.8 N 5118.3 N 6978.2 6923.7 5378.6 7044.1 6989.6 5442.6 7117.4 7062.9 5513.3 7184.6 7130.1 5577.3 7239.1 7184.6 5628.6 N 22.00 E N 22.90 E N 22.60 E N 22.50 E N 23.10 E N 23.20 "E 0.63 0.27 0.19 0.18 0.71 2262.6 E 2287.1 E 2314.5 E 2339.2 E 2359.1 E 7310.8 7256.3 5695.3 5385.1 N 24.84 E 0.24 5449.3 N 24.82 E 0.52 5520.2 N 24.79 E 0.33 5584.4 N 24.76 E 0.43 5635.9 N 24.75 E 0.46 5179.8 N' 2385.4 E 5702.7 N 24.73 E 0.61 'Survey Codes: 3/MWD MPI 2-38/SN01 Page 5 10/31/90 S MEAS INCLN C DEPTH ANGLE 3 9749 42.30 3. 9843 42.10 3 9938 41.90 3 10040 41.70 3 10127 40.80 VERTICAL-DEPTHS SECTION BKB SUB-SEA. DISTNCE 7380.1 7325.6 5758.5 7449.7 7395.2 5821.4 7520.3 7465.8 5884.6 7596.3 7541.8 5952.2 7661.8 7607.3 6009.2 3 10220 41.20 7731.9 7677.4 6069.8 3 10314 41.70 7802.4 7747.9 6131.6 3 10408 42.40 7872.2 7817.7 6194.1 3 10504 43.00 7942.8 7888.3 6258.8 3 10602 43.30 8014.3 7959,8 6325.5 3 10696 43.90 8082.3 8027.8 6390.1 3 10815 44.50 8167.6 8113.1 6472.9 3 10964 44.50 8273.9 8219.4 6577.3 3 11061 44.40 8343.2 8288,7 6645.1 3 11153 45.10 8408.5 8354.0 6709.8 3 11246 45.70 8473.8 8419.3 6775.8 3 11341 46.00 8540.0 8485.5 6843.8 3 11437 46'.20 8606.5 8552.0 6912.8 3 11532 46.30 8672.2 8617.7 6981.3 3 11625 46.10 8736.6 8682.1 7048.2 RECORD OF SURVEY 3 11718 46.40 8800.9 8746.4 7115.0 3 11820 46.60 8871.1 8816.6 7188.5 3 11913 46.80 8934.9 8880.4 7255.7 3 12007 46.90 8999.2 8944.7 7323.6 3 12101 47.10 9063.3 9008.8 7391.6 3 12189 47.30 9123.1 9068.6 7%55.5 DIRECTION BEARING N 22.40 E N 22.3O E N 21.50 E N 21.20 E N 20.90 E RELATIVE-COORDINATES FROM-WELL-HEAD 5238.3 N 2410.0 E 5296.7 N 2434.0 E 5355.7 N 2457.7 E 5419.0 N 2482.5 E 5472.6 N 2503.1 E N 21.20 E 5529.5 N 2525.0 E N 20.80 E 5587.6 N 2547.3 E N 21.00 E 5646.4 N 2569.8 E N 21.60 E 5707.1 N 2593.4 E N 22.20 E 5769.3 N 2618.4 E N 22.40 E 5829.2 N 2643.0 E N 27.30 E 5904.5 N 2677.9 E N 31.30 E 5995.6 N 2729.0 E N 30.90 E 6053.7 N 2764.0 E N 30.90 E 6109.3 N 2797.3 E N 32.20 E N 30.80 E N 32.20 E N 31.80 E N 32.90 E 6165.7 N 2832.0 E 6223.8 N 2867.6 E 6282.8 N 2903.7 E 6341.0 N 2940.1 E 6397.7 N 2976.0 E CLOSURE DISTNCE BEARING 5766.1 N 24.71 E 5829.2 N 24.68 E 5892.7 N 24.65 E 5960.6 N 24.61 E 6017.9 N 24.58 E DL /lOO 0.57 0.22 0.43 0.24 1.04 6078.8 N 24.54 E 0.45 6140.9 N 24.51 E 0.56 6203.7 N 24.47 E 0.75 6268.7 N 24.44 E 0.69 6335.7 N 24.41 E 0.42 6400.4 N 24.39 E 6483.4 N 24.40 E 6587.4 N 24.47 E 6654.9 N 24.54 E 6719.3 N 24.60 E 6785.0 N 24.67 E 6852.7 N 24.74 E 6921.4 N 24.80 E 6989.5 N 24.88 E 7056.0 N 24.95 E N 34.10 E 6453.7 N 3013.1 E 7122.5 N 25.03 E N 34.00 E 6515.0 N 3054.5 E 7195.5 N 25.12 E N 35.70 E 6570.6 N 3093.2 E 7262.3 N 25.21 E N 35.20 E 6626.5 N 3132.9 E 7329.8 N 25.30 E N 36.70 E 6682.1 N 3173.3 E 7397.3 N 25.40 E N 36.10 E 6734.1 N 3211.6 E 7460.7 N 25.50 E 0.65 2.08 1.32 0.23 0.76 0.96 0.83 0.79 0.24 0.65 0.75 0.20 0.99 0.30 0.88 0.43 'Survey Codes: 3/MWD MPI 2-38/SN01 Page 6 10/31/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 3 12283 46.10 3 12377 44.40 3 12459 44.00 3 12559 43.20 3 12698 43.10 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 9187.5 9133.0 7523.2 N 35.20 E 6789.7 N 3251.5 E 7528.1 N 25.59 E 1.37 9253.7 9199.2 7589.4 N 34.80 E 6844.3 N 3289.8 E 7593.9 N 25.67 E 1.82 9312.5 9258.0 7646.1 N 35.40 E 6891.1 N 3322.7 E 7650.3 N 25.74 E 0.60 9384.9 9330.4 7714.4 N 35.80 E 6947.2 N 3362.8 E 7718.3 N 25.83 E 0.82 9486.3 9431.8 7808.5 N 35.50 E 7024.4 N 3418.2 E 7812.0 N 25.95 E 0.12 3 12787 41.80 9552.0 9497.5 7867.9 N 37.60 E 7072.7 N 3454.0 E 7871.0 N 26.03 E 1.80 3 12877 40.60 9619.7 9565.2 7926.2 N 37.90 E 7119.6 N 3490.3 E 7929.1 N 26.12 E 1.34 3 12969 39.40 9690.2 9635.7 17984.5 N 36.90 E 7166.5 N 35~6.2 E 7987.1 N 26.20 E 1.38 3 13061 38.00 9762.0 9707.5 8041.1 N 38.80~.E 7212.0 N 3561.5 E 8043.4 N 26.28 E 1.71 3 13162 36.40 9842.4 9787.9 '8101.0 N 38.90 E 7259.5 N 3599.8 E 8103.0 N 26.38 E 1.58 PROJECTED T.D. AT 13365 MD 13365 34.00 10008.3 9953.8 8215.8 N 38.90 E 7350.6 N 3673.3 E 8217.3 N 26.55 E 1.18 ~Survey Codes: 3/MWD' MPI 2-38/SN01 ~ Page 7 10/31/90 SUBSEA MEAS DEPTH DEPTH 500 555 600 655 700 755 800 855 900 956 1000 1057 1100 1158 1200 1259 1300 1361 1400 1464 1500 1569 1600 1677 1700 1785 1800 1895 1900 2008 2000 2124 2100 2243 2200 2366 2300 2494 2400 2628 2500 2766 2600 2907 2700 3053 2800 3204 2900 3361 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL INCLN TVD MD-TVD VERT DIRECTION ANGLE BKB DIFF CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 0.25 555 0 0 S 5.81 E 0.15 $ 0.81 E 1.99 655 0 0 N 53.61 W 1.73 N 0.55 E 4.16 755 0 0 N 47.03 W 5.17 N 3.63 W 5.88 855 1 0 N 37.47 W 11.66 N 9.48 W 7.49 955 1 1 N 26.88 W 21.63 N 15.99 W 8.11 1055 2 1 N 11.09 W 34.70 N 20.32 W 8.96 1155 3 1 N 4.14 W 49.36 N 21.92 W 10.40 1255 5 1 N 1.37 W 66.35 N 22.85 W 12.45 1355 7 2 N 6.84 E 86.27 N 22.19 W 15.75 1455 10 3 N 16.11 E 110.53 N 16.90 W 19.59 1555 15 5 N 20.34 E 140.74 N 6.72 W 22.46 1655 22 7 N 20.17 E 176.96 N 6.92 E 23.82 1755 31 9 N 19.09 E 217.36 N 21.32 E 25.62 1855 41 10 N 18.30 E 260.77 N 35.87 E 28.86 1955 53 13 N .19.96 E 309.55 N 52.69 E 31.72 2055 69 16 N 22.20 E 364.12 N 73.78 E 34.12 2155 88 19 N 24.08 E 423.75 N 99.31 E 37.25 2255 112 23 N 22.43 E 489.62 N 127.71 E 40.32 2355 140 28 N 21.61 E 563.93 N 158.23 E 42.54 2455 173 33 N 21.70 E 645.97 N 190.79 E 44.22 2555 211 38 N 22.59 E 734.02 N 226.42 E 45.87 2655 252 41 N 23.88 E 825.49 N 265.83 E 47.72 2755 298 46 N 23.41 E 923.15 N 308.24 E 49.56 2855 350 51 N 24.57 E 1026.99 N 354.40 E 51.17 2955 407 57 N 25.77 E 1136.91 N 405.09 E 3000 3520 51.07 3055 466 59 N 25.42 E 1248.61 N 458.53 E MPI 2-38/SN01 Page 8 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 10/31/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 3100 3681 51.69 3155 3200 3843 52.54 3255 3300 4010 54,14 3355 3400 4183 54,91 3455 3500 4356 53,96 3555 3600 4523 52.67 3655 .3700 4687 52,84 3755 '3800 4857 54.43 3855' 3900 5033 56,09 3955 4000 5201 50,76 4055 4100 5350 45.01 4155 4200 5488 43.27 4255 4300 5625 42.95 4355 4400 5761 42,48 4455 4500 5896 42,28 4555 4600 6031 41.91 4655 4700 6165 41,53 4755 4800 6298 41,14 4855 4900 6431 40.93 4955 5000 6563 40.68 5055 5100 6695 40.55 5155 5200 6826 40.42 5255 5300 6957. 40,20 5355 5400 7088 39,93 5455 5500 7219 40,67 5555 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 526 60 N 25,28 E 1361,58 N 512,36 E 589 63 N 25,90 E 1477,47 N 567,16 E 656 67 N 27,33 E 1596,66 N 628,62 E 728 72 N 27,94 E 1720,87 N 693.61 E 801 73 N 29.95 E 1844,37 N 762,24 E 868 67 N 30,49 E 1959.92 N 828,96 E 933 65 N 30.87 E 2072.09 N 896.71 E 1002 69 N 33,94 E 2187,66 N 969.84 E 1078 76 N 34,91 E 2306,30 N 1052.42 E 1146 68 N 32.02 E 2418.76 N 1127.83 E 1195 49 N 27,41 E 2514,10 N 1182.31 E 1233 38 N 25,81 E 2600,04 N 1224.10 E 1271 37 N 26.74 E 2684.02 N 1265.86 E 1307 36 N 25,12 E 2767.21 N 1305.62 E 1342 35 N 25,11 E 2849,79 N 1344.39 E 1377 35 N 25,25 E 2931,47 N 1382,88 E 1411 34 N 26,10.E 3011.99 N 1421.27 E 1444 33 N 26,50 E 3090.76 N 1460.32 E 1476 33 N 26,50 E 3168,59 N 1499.13 E 1508 32 N 26,01 E 3246.00 N 1537.42 E 1540 32 N 24,95 E 3323.39 N 1574,03 E 1572 32 N 25,08 E 3400.90 N 1610,12 E 1603 31 N 24,03 E 3478.18 N 1645,28 E 1633 31 N 24,25 E 3554.85 N 1679.61 E 1664 31 N 25,21 E 3631,70 N 1714,99 E 5600 7351 41,31 5655 1697 33 N 24,68 E 3710.42 N 1751.95 E MPI 2-38/SN01 Page 9 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 10/31/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5700 7485 41.77 5755 5800 7620 42.16 5855 5900 7755 42.57 5955 6000 7892 43.40 6055 6100 8030 44.28 6155 6200 8171 45.22 6255 6300 8314 45.63 6355 6400 8456 45.26 6455 6500 8598 44.88 6555 6600 8739 44.95 6655 6700 8880 44.87 6755 6800 9021 44.77 6855 6900 9162 44.47 6955 7000 9302 44.16 7055 7100 9440 43.68 7155 7200 9578 43.17 7255 7300 9714 42.45 7355 7400 9849 42.09 7455 7500 9984 41.81 7555 7600 10117 40.90 7655 7700 10250 41.36 7755 7800 10384 42.22 7855 7900 10520 43.05 7955 8000 10657 43.65 8055 8100 10797 44.41 8155 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1731 34 N 24.37 E 3791.20 N 1788.41 E 1765 35 N 24.21 E 3873.18 N 1825.48 E 1800 35 N 23.11 E 3956.48 N 1862.30 E 1837 37 N 23.77 E 4042.04 N 1899.03 E 1876 39 N 22.77 E 4130.25 N 1937.34 E 1916 41 N '24.35 E 4221.26 N 1976.28 E 1959 43 N 23.63 E 4314.51 N 2017.51 E 2002 43 N 22.98 E 4407.87 N 2057.59 E 2043 42 N 24.10 E 4499.83 N 2097.68 E 2085 41 N 23.13 E 4591.05 N 2137.80 E 2126 41 N 23.12 E 4682.63 N 2176.69 E 2167' 41 N 23.32 E 4773.98 N 2216.07 E 2207 40 N 22.07 E 4865.16 N 2253.83 E 2247 40 N 22.86 E 4955.45 N 2291.03 E 2286 39 N 22.54 E 5044.37 N 2328.18 E 2324 38 N 23.12 E 5131.66 N 2364.81 E 2360 36 N 22.69 E 5216.79 N 2401.06 E 2395 35 N 22.25 E 5300.75 N 2435.66 E 2429 34 N 21.36 E 5384.23 N 2468.92 E 2463 34 N 20.93 E 5466.71 N 2500.84 E 2496 33 N 21.07 E 5547.99 N 2532.14 E 2530 34 N 20.95 E 5631.38 N 2563.99 E 2566 36 N 21,70 E 5717.27 N 2597.45 E 2603 37 N 22.32 E 5804.59 N 2632.86 E 2642 39 N 26.54 E 5893.01 N 2672.02 E 8200 10937 44.50 8255 2682 40 N 30.57 E 5979.20 N 2719.15 E MPI 2-38/SN01 Page 10 10/31/90 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 8300 11077 44.52 8355 8400 11218 45.52 8455 8500 11362 46.04 8555 8600 11506 46.27 8655 8700 11651 46.18 8755 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 2722 40 N 30.90 E 6063.28 N 2769.76 E 2764 42 N 31.81 E 6149.02 N 2821.51 E 2807 44 N 31.11 E 6236.77 N 2875.31 E 2852 44 N 31.91 E 6325.28 N 2930.29 E 2896 44 N 33.23 E 6413.34 N 2986.16 E 8800 11796 46.55 8855 8900 11942 46.83 8955 9000 12088 47.07 9055 9100 12235 46.71 9155 9200 12378 44.39 9255 2941 45 N 34.02 E 6500.50 N 3044.68 E 2987 46 N 35.55 E 6587.57 N 3105.34 E 3034 46 N 36.49 E 6674.52 N 3167.67 E 3081 47 N 35.66 E 6761.38 N 3231.37 E 3124 43 N 34.81 E 6844.97 N 3290.21 E 9300 12517 43.53 9355 9400 12654 43.13 9455 9500 12790 41.76 9555 9600 12923 40.01 9655 9700 13051 38.14 9755 3163 39 N 35.63 E 6923.86 N 3346.02 E 3200 37 N 35.59 E 7000.19 N 3400.87 E 3236 36 N 37.61 E 7074.46 N 3455.33 E 3268 32 N 37.40 E 7142.92 N 3508.28 E 3297 29 N 38.60 E 7207.38 N 3557.80 E 9800 13177 36.22 9'855 9900 13300 34.77 9955 3322 25 N 38.90 E 7266.41 N 3605.34 E 3345 23 N 38.90 E 7321.92 N 3650.13 E MPI 2-38/SN01 ~ Page 11 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 10/31/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 1000 7.86 998 944 15 N 19.02 W 27 2000 28.66 1948 1893 295 N 19.80 E 306 3000 47.05 2719 2664 922 N 23.23 E 887 4000 54.03 3348 3294 1698 N 27.42 E 1589 5000 55.86 3936 3882 2505 N 35.09 E 2284 DL/ 100 18 W 33 N 34.07 W 0.9 51 E 310 N 9.54 E 2.7 293 E 935 N 18.26 E 1.3 625 E 1708 N 21.46 E 1.2 1037 E 2509 N 24.42 E 0.8 6000 41.97 4631 4577 3218 N 25.29 E 2913 N 1374 E 3220 N 25.25 E 0.2 7000 40.07 5387 5333 3872 N 24.08 E 3503 N 1656 E 3875 N 25.31 E 0.3 8000 44.13 6133 6078 4537 N 23.21 E 4111 N 1929 E 4541 N 25.14 E 0.9 9000 44.81 6839 6785 5242 N 23.48 E 4760 N 2210 E 5248 N 24.90 E 0.2 10000 41.78 7567 7512 5926 N 21.32 E 5394 N 2473 E 5934 N 24.63 E '0.2 11000 44.46 8300 8245 6602 N 31.15 E 6017 N 12000 46.89 8994 8940 7319 N 35.24 E 6622 N 13000 38.93 9714 9660 8004 N 37.54 E 7182 N 2742 E 6612 N 24.50 E 0.2 3130 E 7325 N 25.30 E 0.3 3538 E 8006 N 26.23 E 1.7 <KE>o ! i - 750 3000 375o 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 i3500 75O VERTICAL.~_c--r-TnFl._,.. _ //]]':,lc, EF EXPLORATION HF~ 2-38/SN-01 Section at: N 27.65 E TVD Scale.: 1 inch = 1500 feet Oep Scale.: 1 inch = 1500 feet Drawn ..... Harker Identification MD TVD SECTN INCLN A] KB 0 0 0 0.00 BI PROJECTED TD 13365 10008 82t6 34.00 750 1500 2250 3000 3750 4EO0 Section Departure 5250 6000 6750 7500 Marker Identification MO N/S E/H 8] PROJECTEO TO 13365 735! N 36?3 5P EX?LORATION NFl 2-38/'SN-01 CLOSURE ..... : 8217 ft N 26.55 E DECLINATION.: 30.30 E SCALE · I inch = 1200 feet 0RAWN ....... : ~0/3t/90 A I 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 t800 t200 6OO 60O 6O0 0 600 1200 t800 2400 3000 3600 4200 4800 5400 6000 6600 <- WEST' EAST -> AUbL, I~ L~I-ULUL'UI.~,L MAI _I-[IP~Lb iNVENTORY LiST PERMIT ~ ~ ~ - / ~ ~ WELL NAME D/~ ~ - 3~ ~~ COMPLE~ON DA~ W ! ~ I ~ CO. CONTACT ~~~ check off or list data as it is receivedTlist received date for 407. if 407 j*,~//,.¢'//~/ drillina histo,-v' I,.-'~ survev I .~-.I well tests cored intervals core analysis I~v,~ dry ditch intervals ,. not required list as NR digital data BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 20, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Sag Delta North wells' WELL 2-32/SN-03 PROD-R 12700'-13475' SCHLUMBERGER TEMP 12800'-13599' HRS PERF 12750'-13330' SCHLUMBERGER WELL 2-;~8/$N-01 hGRS 12900'-13779' SCHLUMBERGER LDT/CNL PORO 12900'-13812' SCHLUMBERGER LDT/CN L RAW 12900'-13812' SCHLUMBERGER PROFILE CALIPER 1 0/1 4~90 RUN ONE 1 0/20~9O RUN ONE 1 1/4/90 RUN TWO 10/27~90 RUN ONE 1 0/27~90 RUN ONE 1 0/27~90 RUN ONE 10/28/90 12900'-13812~ SCHLUMBERGER RFT 13406'-13690' SCHLUMBERGER BHCS 13327'-13765' SCHLUMBERGER SSTVD 13300'-13812' SCHLUMBERGER DIL/SFL 13327'-13603' SCHLUMBERGER DLL/MICRO SFL 13327'-13795' SCHLUMBERGER CET 12995'-13676' SCHLUMBERGER CBT 12995'-13658' SCHLUMBERGER PACKER RECORD 12464'-13565' SCHLUMBERGER CCL/PERF 13090'-13600' SCHLUMBERGER Sincerely, L. Haas JLH/Ims cc: File 06.10 RUN ONE 1 0/28/90 RUN ONE 10/29/90 RUN ONE 1 0/29/90 RUN ONE 1 0/29/9O RUN ONE 1 0/29/9 0 RUN ONE 11/1/90 RUN ONE 11/1/90 RUN ONE 11/1/90 RUN ONE 11/7/90 RUN ONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE APPLICATION OF BP ) Exploration (Alaska) Inc.) for an order granting ) an exception to spacing ) requirements of Title ) 20 AAC 25.055 to provide ) for the drilling of the ) Sag Delta North #1 well. ) Conservation Order No. 260 Sag Delta North #1 Well Section 19, T12N, R17E, Umiat Meridian September 20, 1990 IT APPEARING THAT: · BP Exploration (Alaska) Inc. (BPX) submitted an application on August 29, 1990 requesting an exception to 20 AAC 25.055(a)(3) to permit the drilling of Sag Delta North #1 well closer than 500' from a drilling unit boundary. · Notice of hearing on this request was published in the Anchorage Daily News on August 30, 1990 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: · BPX proposes to drill Sag Delta North #1 from a surface location 2011' from the north line (FNL) and 2284' from the east line (FEL) of Section 36, T12N, R16E, Umiat Meridian, to a bottomhole location 4911'FNL, 3212'FEL, Section 19, T12N, R17E, Umiat Meridian. · Top of the productive interval is expected to be 5240'FNL, 3380'FEL, Section 19, T12N, R17E, Umiat Meridian. · An exception is necessary to achieve compliance with 20 AAC 25.055(a)(3). · Offset operator/owners have been duly notified and have filed no objection. Conservation Orde~ No. 260 September 20, 1990 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the BPX Sag Delta North #1 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: BPX Exploration (Alaska) Inc.'s application for an exception to 20 AAC 25.055 for the purpose of drilling the Sag Delta North #1 well is approved as proposed. DONE at Anchorage, Alaska and dated September 20, 1990. ~ ~~~-~onnie C. Sm~th-7-~Commissioner ~o~~~~~~,~~~~~laska Oil and Gas Conservation Commission DAv~i-d W]7-J~0n, Commissioner Alaska Oil. and/Gas Conservation Commission September 21, 1990 Telecopy: (907)276-7542 Endicott Lead Engineer BP Exploration (Alaska) !nc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Duck Island Unit S-38/SN01(MPI) BP Exploration (Alaska) Inc. Permit No. 90-129 Sur. Loc. 20!!'SNL, 2284'%~L, Sec. 36, T!2N, R16E, ~,~ Btmhole Loc. 4911'SI~, 3~12'!~ Sec 19 T]2N R17E UM Dear Mr. Miller Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission BY OP. DER OF THE CO!®IISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratory l-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-iI Service [] Development Gas [] SingleZone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) '10. Field and Pool BP Exploration BKB=56 feet Sag Delta North 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s~, 20 ^AC 25.025) 2011'SNL, 2284' WEL, SEC. 36, T12N, R16E Duck Island Unit At top of productive interval 8. Well number Number 5240' SNL, 3380' WEL, SEC. 19, T12N, R17E 2-38/SNO1(MPI) 2S100302630-277 At total depth 9. Approximate spud date Amount 4911' SNL, 3212' WEL, SEC. 19, T12N, R17E October02, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(Moar~TVD) property line ADL 312828 ~ 367' feet 2-36/014 @ 1416'/3.2'feet 4299 14005'MD/10381'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickott depth 1200 feet Maximum hole angle 47.30 Maximum surface 3835 pslg At total depth (TVD) 10000'/4825 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe Surface Drive 17-1/2" 13-3/8" 68# ~.C~'HE Butt 2493' Surface 2549': 2500 2700 cuft Permafrost 12-1/4" 9-5/8" 47# NTSOS NSCC 11175' Surface~ 11231' 8500' 12-1/4" 9-5/8" 47# ~w'gsHs NSCC 2156 11231 8500' 13387' 9961' 3119 cuft Class G 8-1/2" 7" 29# Nr95Hs TKC 868 13137 9792' 14005' 10381' 312 cuft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural :":'~ i!! ~i.~ ~ ~'~'~ .... Conductor ~ :~ .~: Surface Intermediate -'-:- .... ~'~~,.1 ?~._~ Production Liner ~ ~'-~'~.- ~',i~ O0ii~ Perforation depth: measured . ~-:;i~O~'~.~.;~ true vertical 20, Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program~ Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAO 25.050 requirements[] 21, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ,~~_ Title Endicott Lead Engineer Date ¢~'~ Commission Use Only Permit Number IAPI number IApproval .dAte. ISee cover letter ~'0 "/~ ~' 150- o.2.~-- .2. 2.-0 ~'(_) I 09/2:1/90 Ifor other requirements Oonditions of approval Samples requi.~red [] Yes :E~'NO Mud Icg requir, ed [] Yes ~ No Hydrogen sulfide measures [] Y.es ~ No Directiorkal' survey required ~ Yes [] No Required working pressure fo,_.r,,/B~PE 1-12,~ ,R,~'M:;..-~;[5M; r-I10M; I-I15M; Other: ~--~" / ~./"'/%- . by order of by ~ (,, .//~'~.._...~---~ Commissioner Approved ..../~ ..: .: . the comm,ssion_ . Da,!e. :orm 10-401 Rev. 12~1_,,,-~5 Submit in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 2-38/SN-01 (MPI) Objective Well 2-38/SN-01 will be drilled as an oil production well. The Ivishak is the primary objective. The completion will be run at the time of drilling and will consist of a packer tailpipe assembly. Operation Execute a rig move to slot 2-38 and rig-up. Vertically drill 17-1/2" hole to 1200 ft. then directionally drill to 2549 ft. Run and cement 13-3/8" 68#/ft., NT-8OCYHE Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4825 psi at 10,000 ft. TVDss. Maximum possible surface pressure is 3835 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Drill 12-1/4" hole to the intermed, iate casing point above the Ivishak formation. Run and cement 9-5/8' 47#/ft., NT80S and NT95HS, NSCC casing.. No abnormal.pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, NT95HS buttress (TKC) liner to TD with apDroximately 250 ft. of lap in the 9- 5/8" casing. Clean out to landing collar. I-est casing and lap to 3000 psi. Change over to NaCI packer fluid.Run CET/CBT/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Perforate well underbalanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with a packer tailpipe completion. A sub surface safety valve will be installed below base of permafrost. Nipple down BOPE. Install tree on wellhead and release rig. Fluids incidental to the drilling of a well will be pumped down the 13-3/8" by 9-5/8" annulus of the well. The 13-3/8" x 9-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. PC 9/5/90 SAG DELTA NORTH PROPOSED DIAGRAM ,WELL 2-38/SN-01 (MPI) NON-FREEZING FLUID TVD (BKB) MD (BKB) 30" DRIVE PIPE KOP ( DIR: N 27.1° E; ANGLE: 47.3 DEG ) BASE PERMAFROST SSSV 13-3/8" 68#/FT NT~80CYHE BTC BOTTOM OF FREEZE PROTECTION TOP OF 9-5/8" CEMENT 3-1/2", 9.2#/FT L-80 TDS TUBING W/3-1/2" TAILPIPE 9-5/8" 47#/FT NT80S NSCC 3-1/2" SLIDING SLEEVE 9-5/8" PACKER 7" LINER TOP 9-5/8" 47#/FT NT95HS NSCC 7"PACKER PLUG BACK TD 7" 29#/FT NT95HS TKC LINER 131FT 131FT 1200FT 1466 FT 1466 FT 1549 FT 1550 FT 2500 FT 2549 FT (ESTIMATED) 3000 FT (ESTIMATED) 3600 FT 8500 FT 11231 FT 9758 FT 13087 FT 9792 FT 13137 FT 9961 FT 13387 FT 1O381FT 13925 FT 14OO5 FT SAG DELTA NORTH DEVELOPMENT WELL 2-38/SN-01 {MPI) DEPARTURE TO BHL: 8599 FT 14005 Fi- M D 10381 FT TVD BKB DEPARTURE TO TARGET: 8231 FT 135O4 FT MD 10041 FT TVD BKB 'TRUE NORTH GRID N 27° 4'E SLOT 2-38 SURFACE LOCATION X = 258,921 FT; Y = 5,982,408 FT 2011 FT SNL; 2284 FT WEL SEC 36 , T12N , R16E NOTE: THE NEAREST WELL TO 2-38/SN-01 IS 2-36/O-14'LOCATED 10 FT NORTHEAST AT SLOT 2-36. PC/9-5-90 ~ BOP STACK CONFIGURATION 13 5/8", 500'0 PSI WP TRIPLE RAM ST ACK DRILLING I RISER ANNULAR I PREVENTER I I I I BLIND RAMS I 2" KILL LINE MANUAL HYDRAULIC GATE GATE DRILLING SPOOL I PI PE RAMS I I 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE $1 36 22 0 4;>400 0 44 0 O. C_ERTI FI CATE OF SURVEYOR I Nearby certify thatl am properly registered and licensed to practice land eurveying In the State of Alaska end that this ~lat represent= en ~ropoaed i~alion let the-Well num~r~ ~ho~n abo~e. All surveying wa~ dane byme or under my ~upervi~n, and that ell dimen,ions end det~il~ are correct. DRW. 116-85 SHEET Z ef I0 _ REV. O NO TES' 36 0 Indicates well  Indicates Calc[~lated Sectioa Corner I~omitioa Indicatee Perl)e~dicular Offset Distance Indicates I~r~endicular Offeet Dimte~ce [ per?endic,ular~istance, vqries fQr each ?1!1 ) PLAT OF MPI PROPOSED WELL LOCATIONS LOCATED IN IIEC.~,&,T..I:~ N.,R. I& E. UMIAT Id. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPARED F.R. BELL ~t ASSOC. ' PRUDHOE BAY OFFICE PRUDHOE BAY, ALASKA I I I DATE' NOV-I$, ISIS $C4LE, I ". DRAWN I¥: R,~.T. CHECKED BY' I.E. i I! ii IIELL All). ;ZOt~ $ U,.. JNE & LJ~TZTU~E L lull IIIT(~) tilT(I) ~ Y. ~tl2412.37 #. 7io5324.$1 7~2~'~0.0170' J4~l?'ze.~l" lt21;~l' Zez~.~4 2 Y- 5982579.88 H- 7805353.52 70°21'10.9814 X- 25904[.49 E- 464094.45 ~ Y' 5982474,IB 1H' 7805321.~B 70~21'09,~846' 147~57'20,625B' 1~36.77 ~ 2032,11 . ~X= 25~175.01 ~ E= 4~4155 65 4 Y= 5~82571.6~ ~ N= 7805550.~ '~0°21'10.8~1' 147c57'24.785~' 1845,80' 2174,41 x- 2~9035 7~ E- 4~40~2 74 5 Y= 5~824~5.~ N= 780551~.4~ 70°21'0~,~025 X= 25~169,27 E= 464155.~5 . 6 Y- 5982565,50 K- 780554B.47 70~21'10,8168' 147°57'24,q454' 1852,17 2179,88 X- 2~0~0,02 E- 464091,04 7 Y- ~824~7,80 ~= 7B055'16,94 70°21'09,B200 X= 259165,54 E= 464152,24 8 Y- 5982555,~0 ~= 7805545,94 70°2i'10,7544" 147°57'25,1055' ~"18~0,54 21B5,5~ X- 259024.29 ~- 4640B9,~ ~.. 9 Y' 59B244V.61 N' 7805514.41 70°21'09.7376' 147°~7'21.1054' 19&i.19 204B.5~ X' 259157.B0 E' 464130.53 10 Y' 5982547.11 N' 7905343.42 70~21'10.6521' 147~ 57 ' 25. 2651' 1BBB.91 2190.B3 X' 259018.~5 E' 464.087.62 ' 11 Y- 5992441.42 N'.7805311.B9 70~21'09.655~' 147°57'21.2653' ~970.26 2054.00 X' 259~52.07 E' 464128.93 12 Y' 59B2538.92 N' 7905~40.90 70~21'10.5697' 147°57'25.4250' IB77.21 2196.30 X- 259012.82 E- 464085.92 I ~ Y- 5982433.23 N- 7~0~309.~b 70c21'09.57~0' 147°~7'21.4251' 1978.63.~ 20~9.47 X- 259146.33 E- 464127.[2 14 Y- 5982530.73 N, 780~B.37 70~ 21'10. 4874' 147~57'2~.~B49' ~B8~.66~ 2201.77 X- 2~9007,0~ E- 1~ Y- 598242~.0~ N- 780~306.84 70c21'09.4906' 147~57'2~.5B~0' 19B7.00 2064.94 X- 2~9140,60 E- 464125.42 '~6 Y- 5982522.54 N- 7B05335.85 70°21'~0.4051' ]47°57'25.7447' ~194.03 2207.24 X= 259001.35 E- 4640B2.50 17 Y- 5982416.B4 N- 7B05304.31 70°21'09.40B3' 147~57'21.7449' 1995.3B 2070.41 X- 2~9134.16 E" 464123.71 lB Y- 5982~14.3~ N. 7B0~333.32 70°21'10.3227" ~47o57'25.T04&" 1902.40 22~2.71 X- 2~899~.61 E- 464080.80 19 Y- ~982408.6~ N- 7B0~301.79 70c21'09.3260" 147°57'21.9047" 2003.75 207~.B9 X. 2~9~29.~ E- 464122.00 J 20 Y- ~9B2506.16 'N= 780~3~0.B0 ~0c21'10.24~4" 147~7'26.0&44" 1910.77 2218.18 X- 2~egBg.g7 E- 464079.09 21 Y= 59B2400.46 N- 780~299.27 70~22'09.24~6" 147°57'22.0&4&' ' '2012.12 2081.36 X- 2~9123.39 E- 464[20.30 i i ii i i i i PRO SED WELL L ATION LiST ~ ~D~~~~.~ SOHIO ALASKA PETROLEUM CO. BELL SSOC ~~ss~~ SHEET ~ of I0 ' · SCALE: ~/~ -~~~ - PRUDHOE BAY OFFICE 'DRAWN BY: RG.T ~[v. o PRUDHOE BAY, ALASKA CHECKED BY= B.E. i i i i ii ii ', 23 Y" ~982392.27 N' 7B052~&,74 70°21 '09, X- 2~9117,65 E- 46411B,~ 24 ,Y- 5~8248~.77 N- 7805~25.75 ,70c21'I0.0757· 147c57'26.3842· 1927.5~ ' 222~.15 x= 258~78.40 ~ E= 4~4075.~8 . 2~ ~Y- 5982481,58 :~N- 7805~23,2~ '70~21'09.99~4" 147~7'2~,5440" ~i 19~.90 ' 22~4,~0 27 iX= 258972:67 j E= 464073:97 l" 2~106, t8 E" 4641{~,lB 28 Y' )~2473,3q N" 7~05320,70 70~2t'0~,~{11" 147c~7'24,703~" 1{44,27 2240,07 X- 2~8~64.~3 E" 444072.27 ~ 2~ Y" ~82367,70 N' 7B0528~,{7 7002~'0~.{143" 1470 ~7 ' 22, 7040" 2045,1l 2t03,24 _ . .... X" 2)~{00,4~ E- 4~4{13,47 30 Y- ~8244~,20 N- 7,0~3{N,l~ 7002l'0{,12~7" 147o57'24,~437" 1{~2,14 224~,54 X- 2~8}41,20 [- 444070,~4 { 3~ Y- ~{823~,~0 N- 7{0)2~ i~ {70°21'0~,1320' {47c~7'22,{43{" 20)3,{{ 2~01.72 X- 2~9094,71 [- 46411i:7~ 32 Y- 59B2457.01 Nm 7805315~&5 ~70c21'Oq,74&4" 147°~7'27,0236" 19&1.01 ~2251.01 X' 25B955.46 E" 46404B 8~ ~ 147°~7'23.0237" 2062.35 2114.19 3~ Y' 5~82351.~1 W' 7B05284.12 {70o21'OB.749b" X' 25~08B.98 E' 464110,06~ 34 Y- 5962448.62 N- 780531~.13 70c21'09.~641" 147057'27.1634· 1959.38 2256.49 X- 256949.73 E- 464067.15 35 Y' 5962316.55 N' 7605274.02 70o21'06.4203" 147°57'23,6432" ~ 2095.64 2'136.07 X' 259066.03 E' 464103.23 36 Y' 5982416.05 N' 7805303.03 70021'09.3347" 147c57'27.8229" 2002.B7 227B.37 X' 2~8926.78 E' 464060.32 ~ ~7 Y= 5982310.36 N' 7805271.50 {70°21~08.3379' 147°57'23.8230' 2104.21 2141.55 X' 2~9060.30 E' 464101'53 38 Y' ~982407.~6 N' 7805300.~1 70021'09.2524" 147°57'27.9127" 2011.24 2283.B4 X' 2~892~.0~ E' 4640~8.61 39 Y' ~9B2302.17 N' 7B0~268.98 70o21'08.25~&" 147c57'23.9~29" 2112.5B 2147.02 X' 2~9054.~6 E' 464099.82 { ' 40 Y' ~982399.67 N' 7805297.q8 {70°21'09.1700" 147°.57'28.1426" 2019.&2 2289.31 X= 258915.31 E' 464056.91l. 41 Y' ~982293.97 N' 7B05266.45 {70°21'08.1733' 147~57'24.1~27' 2120.95 2152.49 X- 259048.83 i E' 464098'11~ 42 Y' ~9B2391.48 i' N' 780~29~46~ 70°21'09 .... 0877" 147°~7'28 3024" 2027 99 2294 79 X'. 258909.~8 ~ E' 4640~5 20 . MPi PR SED WELL L ATION LIST ~c OF Ac~t, LOCATED IN SEC. ~6 T. 12N R. 16E. UMI&TM. ~%~~,-,,: ~.e ,~ ' ., t SOHIO ALASKA PETROLEUMCO · Daw..o. ,,E A,ED ~ ~~'~'~ -- F.R BELL · ASS'OC '~~SS~A~.' SHEET 4 Of I0 ' ' SCALE: N/A ~~~~ PRUOHOE BAY O~CE -' REv O PRUDHOE BAY, ~ASKA DR~WN mY: e.a.~ CHECKED BY: B,E i i IELL AlP ZO~ 3 UTh .ONE & LATZTU~E L~ Tgi! lilt 43' y.'"S~12215.7i N. 710S2&3.~3~ 70~2;'0i.0~09' i4~S7'24.30~&' X- '25904~.09 E- 46409&.4~ 44 "Y'- 5982383.29 N-'7~0~292.'9~" 70c21"09.00~4· '1~'7°~7'28.4&23· 203&.3& 2300.26 4~ ~:-~-~~.~-~ ~e~'S~2-.~O='~o-~,~.oO~ ~X- 2~9037.3~ E- 464094.70 48 Y- 5982366,91 ',, 7B05287,89 ~70o21'0B.8407' 147°57'28,7B~0~ : 2055. t0j 23il,20 X- 258a~2.37 E- 464050,08 49- Y- 5982261,21 N- 7805256.35 70o21'07.84~9" 147o57'24,7122. 2t54.44~ 2174,38 X- 2~9025.B9 E- 464091,29 50 Y- 5982358,71' ~- 780528~,36 70o21'08,7584" 147°57'28.94tB· 2061,47 2316,67 X- 2588B6.6~ E- 464048.38 51 Y- 5982253.02 N- 7805253,8~ 70o21.'0~7616· t47o57'24,9420' 2162',1t 2179,B6 X- 259020.15 E- 464089,58 52 Y- 5982350.52 N- 7805282,84 70c21'08.6760" 147°57'29,1617" ' ~069.B5 2322,14 X- 258880.~0 E- ~640~6.67 53 Y- 5~82244.83 N~ 7805251.31 70~2i'07.~7~3' 147°57'25.101~~ 2171.1~ ~ 21~5'33 X- 259014.41 E- 4640G7.89 ~4 Y- ~982~42.~3 N- 780~2B0.31' ~'0~21'0~.5937' 147~7'29.2&~' 2078.22 J 2327.&2 X- 2~G7~.16 EB 464044.96 55 Y= 59B2236.64 N= 7B0524B.7B 70c21'07,5969' 147o57'2'5.'2617' ' 217q,56 2190,~0 X= 25900B.6B E= 4640B6.17 56 Y= 59B2334.14 N= 7805277.79 70c21'0B.5113" 1'47o57'29.4214~ " 2086.59' 2333.09 X- 25B~69.43 E- 464043.26 57 Y- 598222B,44 N- 7805246,26 70o21'07,5146' 147°57'25,4216' 2t87,93 2196,27 X= 259002,94 E= 464084,46 58 Y= 5982325.95 N- 7B05275,27 70°21'0B.4'290'" [47c57'29,5Bt2" 2094,96 2338.56 X= 259863.&9 E= 464041,55 59 Y= ~982220,25 N= Y~05243,73 70~2t;'07,4323· 147o57'25;5B14· '219&,30 2201.74 X= 258~97,2t E= 464092,76 60 y-' 59823]'7,76 N= 7805272,74 70021'OB,3467' 147o57'29,74t't~ 2103,33 2344,03 X- 258957,96 E~ 464039.85 [ . . .~ . , . 61' Y- 59822~2.06 N, 780~241.2t 70o21'07.~4'99' 147~57'25.7'413' 2204.&7 2207.2t x- 2se~1.47 E- 4640~[,0S 62 *'Y- s~Og.'sT. ~- 7~0~270.22"'70c2t'0~,2~4~' t47os7'29.900~· ~ttt.7t" ~4~.~0 x- 2sess2.22 E- 46~0~.~4 63 Y- 59~2203.~7 N- 78052~8.69 70~2t'07.2676' t47o57'25.90[t· 2213.05 221'2.&9 x- 2~8s.74 E- 46~07~.~4 i I ii ~ ....... ~ i i i i i . .~~~_~ -~ -~ MPi PRO~SED WELL L~TION LIST ~~~.~4.n ~ ~'LOCATEO IN ~C. 36,T. IZN.,R. 16E. UMIAT ~~~~~.~ SOHIO ALASKA PETROLEUM CO. . i.~,~//_Z~/;~.~.. -- / ~~~ DRW. NO-116- 85 PREPARED BY ~DATE:NOV'I3'I~I5 'I;~ ~-~~ -- ,.' qk;.u,ESS~__~ F.R. BELL S ASSOC. SCALE' N/A ~~~~ SH[ET 5of ~ pRUDHOE BAY OFFICE , 'D~WN BY : ~EV. O P~UDHO E ~Y~ II .... ~ il i i i iii i i i ~' ....... I I IplII!IlI I1111 I . I I I II II I II I WI, ELL ,tSP :ZONE:' I UT,/'~NE 6 I, iTItUlE L(~,TUll '" . 64 "y, S91230~31 N- 7105267,"69 7~21~0'1,1120' J47087'10.0601· X~ 251146.41 E~ 4&4036.43 65 Y~ 5982~9S.68 N' 7g05236,~6 70~2~,07.~B'52, J47~S7'26,0620' ~2~.43 X~ 2~8980.00 E~ 464077.64 66 ~Y- 5~B22~3.1B ~ N- 7B05~65.17'" 70-21,0G.0~97, ' 147~7'~'0.2206' : 212~'~4~ !2360.45~ 67 ~Y-,~621~.49 N-~80'~':~--~-~;~-:-~029' , 14~'7'26.2208' ' 222"80 ~~'2'~'6~ x. 2~4.16~ E- 4640~.9~ / ' x- ~~.oi, E- 4640~.0~ &9 'Y- ~982179 30 [ N- 7B0~211,11 70c21'07.0206· 147c57'2,;3B07' 2211,17 2229,10 X- 2~8968:51~ E" 464074,23 70 Y- 5982276.80~ N- 7B05260.12 70o~X'07.9350. ,. ~47o57'30.5403" 2~45.J9 237~.39 X- 2~B829,28 E- 464031.3Z . MPI PRO~SED ~E~ L~ATION LIST ~ ~ LOCATED IN SEC 36 T. 12 ~ OF ~ ~ ' ' ' ~-~'--~ sOHIO ALASKA ~ETROLEUM ~~,.~ ~.6919~ .~ ~ DRW. NO. 116-85 PREPARED BY ~TE: NOV. 13. 1~85 ~'~/*;~~'; ;.R Bgcc s Assoc. · k~'~s~c~ - - PRUDHOE B&Y OFFICE ~~~ R.G.T. R~. O PRUDHOE BAY,&L&SKA D~&WN CHECKED BY: B.E. , ii i iii i ii ii i i i II J I Search Radius= 200 COURSE LiNE ---FO-~~eZne-d w e i i.' Location = W-E S-N TVD (Si~S) · Bottom 263074. 17 598~38 04 1n°*~ O0 ' ~: Ali depths in ~e-e-~Beiow ~seiig Bushing ;~ Clos-~-st ~pproach WELL IDENT /PROPOSED\ /NEARBY\ CLOSEST ~17~ :~, TVD DEPART TVD DEPART D I STANCE /PROPOSED\ /NEARBY\ DEPART TVD DEPART VERTICAL DISTANCE NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW ' !!,~i AO00-O000051 MI--! AOOO-OOOC¢083 ,:=: MI-33 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW AOOO-OOOOOS& .i Mi-3~ NO--COORD-I-NA-TE--PI~I-NTS WiTHiN SPECiFiED ~-l!~RCH WiNDOt~ ;~ AO00-O000120 .',r MI-70 NO COORDINATE POINT8 WITHIN SPECIFIED SEARCH WINDOW _,~ MI-SD7 4~57. ~ lC~54. 8 4407. 0 682. 8 260. ~ A0~9-20~3~00 i:~: Mi-SD~ 381~-~_~ i~. 3 3~5~. 8 ~2. 3 838. ;:! MISDIO 3918. 4 1587. I 410~. 2 368. 4 455. :~, A02~-2i D~800 4198.7 1891.3 4~=~.~ 851.7 431.~ 365~. 1 1305.8 4533.8 748.5 882.0 :~i MI-P18 2281. 4 212. 1 2280. 6 4. 3 24. 7 ..¢: A02~-2158500 :?~ ~ k-~-4-8. 4 i~9 i 2~-7. i ~. i 27. 6 A02~-21 i~ i .-'.~:..~.Mi=020 ' ""::":""'":"'""-2136. 0 .... 157. 7 :":" ............ :' ~1'362:3 ..... :.is::.:. ........ i'&' 0'- ..... :.: s:.: ~=.~ ~ ...~= ._ ~ ~i~O0 MI-iai 0.~ 0.0 0.0 0.0 177.9 AO~?-21~J?O0 Ni-OIG ~vo ..... ~ 144-~..= =~?~ .... 9 o' i ~.v-- - 911 , AO:~-~ 164800 :.,~ Mi QI7 lO0. 9 O. 0 100. 0 O. 2 120. J · · AO2~-~186200 ' M I-P 1 ~ 1728. 5 4~. 8 ~ 728. 5 2. 3 7. 0 :so~ 'MI-Ma~ 17~9. 6 ~1. 7 17~9.3 ;.-. ~. 1 181.2 'i, Aoa9-a 167a00 ;sz ,,~-~ 1. 0 O. 0 O. 0 O. 0 i ~ ,s~ AOag-a 1 MI-P20 1685. ~ 41. 8 1~84. 8 17. 4 174. 0 ;~li ;:~ MI-~22 2251. 5 200. 3 2244.7 79.'5 117. 3 ~n AOag-a171300 ...... ~%l-O2~ O. 8 O. 0 O. 0 O. 0 1~'. Aoag-a172200 MI-N22 1000. 7 O. 0 1000. 0 1. 8 190. 7 A029--2174300 ~ HZ-d18 ~ ~. 0 ~ 88. 4 18~. i A029--~174800 M I-Pa4 1398. ~ ~. 9 1399. 3 32. 7 138. 5 ~AO29-2175000 2232.6 I93..0 60~3.7 143.7 38~i. 1 2-i _$45DUA124'[DRANO35]MISNt_CLOSAP_SHORT. LiS;4 5-SEP-195'0 12:46 P.~ge 2 MI-S14 I001. 0 O. 0 1000. 0 A029-217~,700 2.4 ~8.1 ~,1 ~z~+ 1UU1. U ~. 0 1000. A029-2 ! 76700 M'I--~I-2 400c9 070 -- ~0070 A029-2177100 MI-~16 2260. 5 203. 8 2~9. , ~0~~78800 077 Z4 6 MI-P17 1556. 5 22. 7 1562. A029-2184100 Hi-P2i i200r. 0 0~0 i i~. A02~-2184700 · :: MI-S17 201. 5 O. 0 200. A029-2186400 ...~ 1. I 0.0 0.'0 .~: A029-~187300 MI-R~3 1300. 0 1. 7 1304. MI-M16 2381. 9 255. 4 2378. 8 A029-~ 189200 ,:s M~i PI3 l~-O (}r~ 1 i~9. '5 AO~9-~i 89900 MI-U15 1200. 0 O. 0 1200. 4 AO~9-~193100 ~s Mi--~' i~00. 'O O. 0 i i~9. 5 AO~O .:si MI-K~5 1910. 8 89. 8 1910. 6 ~ A029-220i 400 =~ AO29-2~O3RO0 ::, MI-LI~ 2066. ~ 134. 5 2065. 6 ;.,,~04 i O0 ' M I-809 O. '~ O. 0 O. 0 A029-2204800 :-: · Mi-Li D ~3i--~ i30. 5 ~ A029-2201400 Mi-O14 Closest approach distance = 2.2 ~eet 35. 9 26. 0 55.3 0.0 54. 0 °~ 3 9.3 145.4 5.0 143. 1 i71. 7 33. 3 1!2. 7 465.--'. 3 0.0 150. 153. 800. 24. 8 ESDT. 9 28. 1 -1347. i.O 3.6 i.3 5.9 0.0 i~-8 64. 9 20.1 158. 8 40. 2 'I1. ,~-- 173. 6 181. 8 16.8 99. 9 17.5 2058T-. 6- --- - i ~0370 2338. 6 T327i 28. 236. 36'60':. -. I'47. 5237. 108. 3 3~. 9 3099. OFF ~or this run "~ = 1200.0 ~eet '--- .-' Se,nrch' Radius= 200 7 DEGREE LEAD LINE Foi- p,-uposed u~e-l-l: Location = W-E S-N TVD(SBS) Bottom 262125.53 5790388.06 10325.00 ., .... . '.-II d~p~h~ i,, ~ ~eiuu~-K~ilg Bu~him Olose~t App~0sch WELL IDENT /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A000-0000051 MI-1 AOGO-OGO008~ MI-33 A000-0000086 AO00-O000120 MI -70 ,.::. ~7 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COOR~NA~E~iTHiN S-- - ' _ NO COORDINATE POINTS WITHIN SPECIFIED SEARCH wINDow 4101.3 1785.6 4~0,.= 603.9 3709.0 135~.9 4361.6 577.0 aO:PS. 5 i44.8 &095.3 J4.3 3~7,7 3401.1 1025.8 9~22.0 .881.~ ~121.8 2259.1 203.2 al~4.~ 155.1 3935.8 MI-SD7 4138. 8 18a6. 3 4a07. 4 524. 1 la7. 2~ A029-2063900 · ::.. A0~-~064000 MISDiO 38~8. ? 1566. 0 400~. 3 30~. 6 ~5. MI-PI8 2a70. 6 207. 6 a270. 0 4. 3 50. ' A0~9-21 58500 ~ P~i-~i~ ~o~. ~ i74. i 2~'. ~. ~ ;:~ AO~-~ 1 ~0 ~00 ' MI-O~O ~065. 4 134. 1 ~0~5. 8 1~. 2 204. ~, MI-O~I O. ~ ..0. 0 O. 0 O. 0 177. .~, 'AO2~-~l&3~O0 ~i uio ~uo~ ~ i40. 4 2084. ~ 6. i ~.3 AO~-~i ~4800 ~,,. ~ii-Oi7 i~ ~ 100. O O. = i~. ' ' MI-PI4 ' 1721.2 48. 1 1721.2 2. 2 12. ;'~ MI-Ma5 O. 9 O. 0 O. 0 ~. 0 183. i:' ~i 0~5 1. 0 O. O O. O O. O 170. -~2. A029-21 ~300 MI-P20 1546. 2 R1. 4 1545. 6 17. 3 177. 'i~ AG~9-~'~'&9800 '~ MI-O~ aa03. 3 181.8 2190.5 c?&. c/ 140. 4 .:~ AOa~-~- 171300 ?ii-0~3 O. 8 O. 0 O. O O. O 171:3 AOF:~-a172~00 MI-Naa 1000.7 O. 0 1000. 0 1. 8 1 ?0. 7 AOaD-a174300 . .~ ~ii-di8 ~230~-. 9 i9~. 4 -~';~30. ~ ~4. ~ 18/. ~ AOaD-2174800 · MI-P24 1300. 0 1. 7 1300. 7 3i. 8 138. 8 .'-AOaD-2175000 · · ' _~4SDUAI~4: [DRANO35]MISNI_CLOSAP_SHORT7. LiS; 4 5-SEP-I?90 12:47 P.=ge " Pii-Oi8 P230. v 19;~. 4 :-'-'~0. 8 A02~-2174800 MI-P24 1300. 0 1. 7 1300. 7 A029-2175000 _$4$DUA 124: [ DRANO35 ] MI SNI_CLOSAP_SHORT7. L i S; 4 04. 8 31.8 138. 8 5-SEP-1990 i2247 Page MI-514 1001.0 0.0 1000.0 A02~-2176700 Mi-Ri2 400.9 0."0 ~O0. u A02~-2177100 MI-Ki& 2237.8 195.0 2236.4 A0~-~i78800 2.4 68. 1 u. '2 2V. ~ 44. 4 7c). 7 238&. 3 257. 5 5172. MI-RR5 1.0 0.0 0.0 AO2g-2180100 Hi-di9 1899.~= 66.7 18gg. 8 A029-2181500 Mi-N14 1902.6 87.7 1901.7 A0~-2i8~700 o. o 1,2. 3 :: 8. 6 234. 3 O. 8 20. 1 2043. 9 127. 6 4*85. 7 44. 6 2¢42. 6 MI-P17 ' 1499.5 15.7 1505.4 A0~9-2184100 ' i-ii-Fi1 i200.0 0.0 119~. 1 A029-~184700 MI-PI9 1870.2 7~.8 1868.2 ~0~-~i85800 33. 0 145. i~. I 171. 25. 5 43. ...._M!-. S! 7==:=== ............ ~01. 5 =: O. 0 RO0. 0 A029-2186400 i-ii-F2~ 1. 1 O. 0 O. 0 A029-2187300 MI-R23 1300. 0 1. 7 1304. 5 ' A0;29-~i88500 54. 0 153. 6 MI-M1& 2403.1 ~65.3 2401.3 Hi-Pi3 i~O0. O 0.0' i19~.5 MI-U15 1200.0 0.0 1~00.4 Ao~9-2i9~ioo 146. 6 33. 1 2243. 2 197. 1 1308. 2 -6~. 2 -934. =. ~'~J. 1 5. 0 158. 8 MI-015 0.~ 0.0 0.0 AO2V-219.3100 ~ii~14 1961.6 103.4 iV6i. i MI-~26 1200.0 0.0 11~.5 O. 0 40. 2 $:'7 -'~'+' i 2i-3 i. 8 i 5~. 2 3796. 1. 0 173. 6 MI-K2D 1810.1 65.~ 1809.8 A02~--2201400 J',i ui~ 1416.1 MI-L16 205~.4 131.4 2055.6 A029-~204i00 MI-SOY 0.9 0.0 0.0 'SUI"11'~R Y 0.0 5'g.g The meii---u~h-ich ¢omes--c-t'o~e~_~--t~he--p~oposerf--arell i~. A029-2201400 MI-Of4 SAG DELTA NORTH MUD .PROGRAM MAIN PRODUCTION ISLAND ,,WELL 2-38/SN-01 Interval Mud Weight Viscosity Fluid Loss (sec/at) (ml/30min) . . 0 - 2500' 8.8-9.8 100-200 20-15 Set 13-3/8" casing 9.0-9.5 Mud Type/ ComDonents ..Generic Mud #5 Seawater Fresh water Gel Soda Ash 2,500- 13,387' 9.2-10.5 40-45 15-16 Set 9-5/8" casing 9.0-10.5 ..Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill 13,387 - 14,005' 9.2-10.5 40-45 6-8 Hang 7" Liner 9.0-11.0 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite Newdrill /~'"'%' II U J_ I I fill ! i - i ,' ..L ,~'4, ooo ~, FuE. L. o, I I II - I I I I .... I/"~! I __ J IF IN DOUBT-.* ASKI! I ___1 __ I .__ Ill l_ ,- . ~] ,., -t- ~ LO' ~/7 :o° DOYON DRILLING, INC. RI G NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Nominal Model Capaci t~ Shaker Desander Mudcleaners Centrifuse Brandt Dual Double Demco 2-12" cones Tri Flow 1000 gpm 700 9Pm ( e ach ) Double 400 9pm 8 each - 4" (each) cones Pioneer Hark II, 150 9Pm Decant i n 9 Desasser Drilco Asi tarots Brandt Hoppers Geosource Vacuum 1000 9pm 8 each - 25 h.p. Dual Sidewinders 1000 9pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drillin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. TEST PLUG --PACKING PORT TEST .PORT -- LOCKSCREW CASING HANGER SPLIT SPEEOHEAD · 13-3/8 II. 3. 9-5/8" CASING AND 14ELLHEAD EQUIPHENT 3.1 TESTING B.O.P. STACK I. Af.ter B.O.P.'s are nippled up to split speedhead, make up 13" x 4-I/2 Internal Flush B.O. I'. test plug, ACcessories Item 7, Part No. 538116. 2. Lower plug into head (it will land on lower Step). Tighten 4 lockscrews .90° apart. 3. After B.O.P. test, back out lockscrews and retrieve test plug. CAUTION: It is very tmporrnnt not to have the lockscrews protruding into the bore of the head whtle either running or pulling the B.O.P. test plug. Always check them if in doubt. (29) I. ] 13-5/8" API-5000~ 13-'5/8" APl-BO00, CONTROL LINE-- 1 3 - 3/8" -- 9 - 5/8" --CONTROL LINE 4 - l/2:' lC, lIRE i WELLHEAD ASSEMBLY,ENDICOTT SKSI 13-3/8"x 9-5/8"× 4-1/2" SOHIO ALASKA PETROLEUM COMPANY (3) -- SPL I T SPEEDHEAO (30) TEST PLUG '13-3/8" 0.D. CASING 13~.? ACCESSORI. ES I~TEH 6 II Ii II II II II II ! BOP TEST PLL,~ FO~ UPPER BOWL . -- , /-/.-~/2 IF FEHALE THO / · 11 II II II It / ACCESSORIES ZTEH 7 210 (19) II. 4. 4-1/2 TUBING AND U~ELLHEAD EQUIPMENT 4.1 TESTING B.O.P.'s 1. After 9-5/8" has been set and tested run in B.O.P. test .plu~, Accessory Item 6, Part Number 5381.17, which lands in upper bowl of the split speedhead. Run in 4 lockscrews lightly, 90° apart to keep plug from movtn~. 2. After test, retract lockscrews and pull plug. 3. Run in short bowl protector, Accessory Item 8, Part Number 538114, using the same running tool, Accessory Item 5, Part Number 538115, that was used for the long protector. 4. After bowl protector, is in place, run in 4 lockscrews lightly to hold protector in place. CAUTION: Upper lockscrews must be retracted when the bowl protector or B.O.P. test plug is either run or pulled. CHE~ LIST FOR NE~ APPROVE DATE · IT_~d (1) Fee (2) Loc i,i i (8) (9 thru 13) ~!0 and i3) (4) Cass ,, i, (14 thru 22) (23 :hr: 28) (6) rev: 01/30/89 6.011. · NO L='MAAKS YES 2. Is well no' be located /m a daf/~=ed pool ............................. __. 3. Is well located proper distance from property line .................. ___ 4. Is well located proper distance from other wells ........ 5. Is sufficient tu:dedicated acreage available in :his pool ............ 6. Is we!! uo be deviated and is we!!bore plat included ................ 7. Is operator the only affected party. ................................. _ . 8. C~: permit be approved before fifteen-day wai= ...................... Does operator have a bond in force .................................. is a co:sarma=ion order needed ...................................... Is aa~surauive approval needed ................................... A' 7~ Is :he le~e :%unbar appropriate ..................................... Does :he well have a unique n~e and nmnber ......................... 1. Is the permit fee attached .......................................... 10. il. I3. 14. 15. 16. I7. 18. 19. 20. 21. 22. - IS cdnducuor s==~ug provided ........................................ Will surface casing protect all zones reasonably expected to serve as an u~derground source of drinking wa:ar ..................... ,, , is enough came:: used ~o circuia=a on co:duc:or and surface ......... W'~!! cement =ia in surface and intarmedia=a or produc=ion s=rings ...' Will cement cover ~ known produc=ive horizons ..................... ~ii! all casing give adequate safety in collapse, :ansion and burs:.. Is this well to be kicked off from an ~.isuing we!lbora ............. Is old wel!bore abandonment procedure included on 10-&03 ............ Is adequate weilbore separation proposed ..................... ...... ___ Is a diver=er system required ....................................... ___ is :he dril!iug fluid program schema:ic and list of equipment adequa=e~ Are necessary diagr~ and descriptions of~m~r-am~ BOPE a==ached. Does BOPE have sufficient pressure rating - Test to ooo~_.oo~F~psi~ .. Does :he choke ma~ifoid comply w/AP! RP-53 (Nay 84) ..... ~ ............. , Is the presence of H2S gas prob~oie ............................. ;--- , explore=Dry and Stra~igraphic wells: Are da:a presen=ed on po:am=ia! overpressure zones? ................. ---- Are seismic analysis da:a presen:ed on shallow gas zones ............ .,. . If an offshore loc., ~e su~-~ey results of seabed condluions prese~=ued , 23. 24. 23. 26. 27 28. ~or 29. 30. 31. 3Z. Additional recuireme~us ............................................. 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 APPENDIXi ., No special 'effort has been made to chronologically organize this category of information, .o ****************************** ~mmmmmmmmmmmmmmmmm~mmm~mm~mmm~ C~p~N~ NAME : BP EXPLORATION wELL"N ~E : 2-38(8N0t) FIELD NAME : SAG NORT~ BOROUGH : NORTH SLOPE SThTE : ALhSKA API NUMBER : 50-0~9'~090 REFEREWCE NO : Oate ~ ~IS TaRe Veriflcat~,on Li. st~no ;chlu~berqer A.la$~a ComD~,~tin6 Cer~ter 29-MAR-1993 10:17 D~T~ : 90t1!/~.5 OPIGiN ~ FLIC P~EVIOUS REEL ~ C~EMT : GCT, BP EXPLOR~TI[i)N, 2 38(SN01), SAG ~m'' t'~ APl #50 02g-2~090 ..... ........ - ~ RT,~, - , **** TAPE HEADER **** 8MRVIC~ NAME ~ ~CT DATE : O~!CiM ~ Fb%C CONTINUA. TIOM P~EV!OUS TAPE : CO~EMT : ~CT, BP MX~LORATIOM, 2-38{SMO1), SAG NORTH, APl #50-029-~090 PAGE: HE, ADE **** FTL~ Na~E ! ~CT .001 SE~V!CE : FbIC VERgiOM : 001A06 DATE : 90/1!/15 ~aX REC FILE TYPE LAST FILE ******************************************************************************* ******************************************************************************* ** SCHL[IMBE~GER ~EbL SERVICES ** ** *$ ******************************************************************************* ******************************************************************************* F~EbD: SAG NO~TH BORO~;GH: NORT~ SLOPE APl NttMBE~: 50-029-220~0 [,mCaTION: 20!~.' .~'I, & 2284' RANGM: !6E P~RMAME~',~T DATUms: ~SL MLEVATIOM: 0 'IS Ta~e verif~.cation ~chl~mberoerA !as~a Com~ut~,n~ Center PAGE: ELEVATIONS KB: 54.5 DF: 5~.5 GL: 14.5 ~TE LOCG~D: 01-NOV-1990 TD DR!LLE~: ~]745 CASING: 5/~" 47 LB ~ DRILLER DEPTH OF 0 TO 13349 7" ~9 LB ~ DRILLER D~'i~PT~,q OF 130~! TO TD TYPE FL!,!ID IN }{OHM: BRINE T~E LOGGER OM BOTTO~ ~6:00 Of-NOV LOGGING QISTRICT: PRU~MOE aAY ToOL ~U~BERS: CEoS A 733 GCPC B 727 GCID A 37 ~CB~IOE CEEC C 956 CBC DB ~0 TCC B 839 gCEC A 726 ~CAD ~.701 TCC B 276 D~TE JOB STARTED: 15-NOV-90 JOB REFERENCE N~: 74182 bDP/AM~: KOHR!MG COMPUTING CENTER REMARKS: SWS MEAN wELL ~ZI~UTH OF 26,9 USED IN COMPUTATION. THIS LIBRARY TAPE ALSO INCLUDES EXTRAPOLATED VALUES OF GCT DATA ERO~ GCT LAST READING (1365~,1') TO DRILLER'S DEPT~ TABLE TYPE : CONS TuNI VALU DEFY A.T! Commmnv Name F~ S~G NORTH F~eld Name wN 2-38(S~01) Well Name NaTI USA Nation SWAT ~,LASKA State or Province COUN NORTH SLOPE County TOWS 1~ Towns~iD FL 2n~1' 6NL & 2284' WEL Field Location SON 404459 Service Order Number Tape Verification bistin~ ~CblUmberqer ~lasKa Comm,Jt~.~ Center 29-aAR-!993 !0:17 TUN! VALU DEFI g, PI~ 50-0~g-22090 AP~gerla! ~t!mber TaBL~ TYPE : CURV ~EF! D~pT Den/h Chan~el Name GDED ~Y~O Depth VDEm True ¥~rtical D~th as cban~el <TvTC~I> DMV? Deviation MLAZ Deviation tzimutb NSD? ~otth South Drift MWD~ East west Drift ComPonent ~CWM!, CURVATUR~ OF THE WELL DATA FOPM~T SPEC!FIC4TIO~ ~ECfl~D ** ** SET "YPE 64EB ** ?YPE R~PR CODE AbU I 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 9 65 1! 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE mm ...... '" ............................. g .... ~ ........ T ................. ' ........ ~'~'~'" DPpT FT 404459 00 000O - I 1 4 6~ 000 0 0 0O GDEP GCT rT 4044~q O0 000 00 0 1 1 ! 4 68 0000000000 VDE~ ~CT FT aOa459 O0 000 O0 0 ! 1 1 4 68 0000000000 5tS Taoe Verification Listtno ~chlumberoer Alaska Comput~nd Center 29-~AR-!993 I0:17 PAGE: ID ORDE~ # bOG TYPE C[,ASS ~OD NUmB S~.~P ELEM CODE ~/..lZ GCT OEG 404459 O0 000 O0 0 ~ ! ~ ~ 68 0000000000 NSD~ GCr FT 40a459 00 000 O0 0 ~ ~ ~ ~ 68 0000000000 Ewg~ GC~ FT 404459 00 000 00 O ~ ~ ~ 4 68 0000000900 D~P~ 65535'500 ~D~P,GCT 9 000 VDED.GCT 9 OO0 DEVI.GCT }{LA~:GCT 1~7.004 ~$DR.GCT ~:O00 EWDR,GCT ~:000 CWEL'GCT D~PT. 65500,000 GOEP,GCT !359.849 VOFP.GCT 1353.~78 DEVI,GCT ~LAZ,GCT 8,475 NSDR,GCT 85,751 ~WDR.GCT -19.479 CWEL.GCT D~PT. 65400.000 GD~P~GCT 6~29 997 VDEP.GCT 4732 669 ~VI.GCT ~bAZ.GCT ~5,44] ~SDR'GCT ~984:679 EWDR,GCT ~415~89~ CWEL.GCT DEPT. 65300.000 GDEP'GCT 1~3~,795 VDKP.GCT 859~ 898 DEVI,GCT HLAZ.GCT 32,147 NSDR,GC'T 62 .,2~3 EWDR,GCT 2890:574 CWEL,GCT D~P? 65251 50.0 GDEP,~CT 13831,000 V[)EP,GCT 10426 105 DEVI,GCT ~{LAZ~GCT 41.:23~ NSDR.GCT 7505,69~ EWDR,GCT 3830:498 CWEL:~CT END OF DAT~ ** 0 4 ~2.3~9 S.t75 41.577 0.490 46,065 0.272 27.516 0.000 FILF NAME : GCT ,00! SERVICE : wLTC VERSION : 001~06 DAT~ : 90/11/15 ~X REC S!Z~ : ~024 FIL~ TYPE ~ LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E DSTM : 00/11/!5 O~IGIN : ~bTC T~PF NAME : 74~82 CONTIWUAT!OM ~ : P~EVIO[!S TAPE CO~EMT ~ GCT, BP EXPLORATION, #50-029-22090 ,~I$ ?a~e Verlficat~,om Listing ;cblumber~er Alaska Computing Center 10:t7 PAGE: **** REEL TRAILER **** DATF : 90/!!/~5 ORIGIN : FblC R~E5 WA~E ~ 74~,82 CQ~EMT : GCT, 5P EXPLORATION, 2-38(SN01), SAG NORTH, API #50-029-22090 ******************************* ~mmm~mmmm~m~m~mmmmmmm~m~ cOMpANY NAME : BP EXPLORATION WELl, NAME ~ 2-3~/SN-OI MPI FIELD NAME : SAG BOROUGH : ~iO~TM SLOPE STATE : APT NUMBER : 50-029-22090 ~chIumberQerAlasKa <omDutt~g Ce~te~ 29~AR-1993 10:23 S~RVICE NA4~ : EDiT DATE : 90/11/ t O~I~IN ~ ~S!C CONTINUATYON # : P~EV!OU$ REEh C~M~E~ : BP EXPLORATION, SAG NORTH, 2-38/SN-0! MPI, API #50-0~g-2~090 **** TAPE HEADER **** SFRVICE NA~M { MD!T ORIGIN ~ FLOC TAP~ NA~E ~ 74~6~ CONTINUATIO~ # : ~ PREVIOUS T~DE : CO~ENT { BP ~YPLO~ATtO~, SAG NORTh, 2-38/SN-01N'PI, AP! #50-029-2}090 PAGE: ****~ FIbE HEADER **** FIL~ NAME : ~DIT ,00! SERVICE : ?L!C V~RSION : 001~06 DAT~ ~X REC SIZ~ FILF TYPE : bO LIST ******************************************************************************* ******************************************************************************* ** ** ** ** SCMbUMBE~GER WELL SERVICES ** ******************************************************************************* ******************************************************************************* CDMDANY N~F: ~P EXPLORATION W~!,L: 2-~B/SN-O! MPI FIELD: SAG N~RTN ~DROUGH; NORTH SLOPE S~TE: ~LASKA AP/ NII~BER: 50-0~9-27090 ?Oil' SNL & 2284' WE!, 36 TOWNSHIP: 12M RANGE: PFR~-~ANE~T DATUM: ~SI, EbEVATION: 0 ,!IS Ta~e Verification L~stlna ;chlumberger A],.aska Comoutfng Center 29-~AR-1993 I0~3 PAGE: ~8'0CT'!990 ONE 13~3~ 13816 D~TE LOGGED~ T9 LOGGER: DF: 56 GL: t4.5 LOGGING ENGINEER: SARBE~ WITNESS: ~C~ULLEN TOO[, NUMBERS (LDT/CNL/MGT PASS): AMS-AA-724 NGD-O 7~9 NSC-E GPIC-B 934 TOOL NUMBERS (DTE/BMC S~C-Sa-50 SLS-WA-1639 D!S-MC-~76 T~OL NUMBERS (DLL/~SFL PASR): AM~-AA-724 SGC-$A-50 DRS-C-484~ DLS-F-975 SDAa-509 TCC-B-281 C,C=H 327 DRS-C 4908 TC~-509 TCC=B-281 SDC=CA-32 DIC-~:B-271 TC~-AB-$09 TCC-B-281 SRE=D-797 DLC-D-761 DLE-E-7~9 TCM-~B-50g FIELD REMARKS (LDT/C~L/NGT PASS): TOOT, 8T~ING (~OT-TOP) : GPIT-LDT=C~L-NGT-TCC-A~S. THE CML BOWSP~iMG WAS USED ALONG WIT~ 2 ROLL OVER D~VICES. T~E bOGS WEPE O~IGI~AI.,LY GENERATED I.{SI~G SANDSTONE ~ATRIX ~T S~ZE: B t/~" TYPE FLUID ' DENSITY: 9.7 VISCOSITY: 35 P~: 10.5 FLUID LOSS: 5,6 ~UD RES!STIVITY~ 1. 0 0 73 FTLT~ATE'RESiST!V!TY: 1.: 0 ~ 73 Ti'ME LOGGER "ON BOTTOM (LDT/C~;{L/NGT PISS): 16132 0CT-28 T!M'F LOGGER DM BOTTOM (DTM/BHC PR, SS): 01~40 0CT-29 TIMK~ LOGGER ON BOTTOM (Dbb/~Srb PASS): 04111 OCT-29 MAXI~U~ TMMP ~ECORDED (LDT/CNL/MGT PASS): 194 MAXI~},)~ TE~4P ~ECOPDED (DTE/BHC P~SS): 203 ~aXIMUM T~MP RECORDED (DLL/uS~'L PASS): 203 LOGGING DISTRICT: PRUDHOE BAY ,IS T~-Ue Verification ;c~l, umberq~r Alaska ¢omt~utlnO Center 29-~AR-199~ !0:?~ MI×ED L'IT~OLOGY "H THIo , USING A Cb{'L ~TRI'% OW LI~E, A~!D 2,71 G/CC FOR TNE LOT, CML HOLE CORRECTIO{~ C~.~NGFD OH '~I~ P~SS AT 13325' TO ~S, BS C~.a.~GED TO {~.~5" NObE STATUS CHANGED TO CASED, TOOL STRING (BOT'-TOP) = DITE'S~T-G~-TCC'A~$, TOOL CENTraLIZED WITH 9 1/2" RUBBER FINNED STANDOFFS, A 2 1/~" ~UBBER ~OLE FI~DE~ WAS ~bS© [)SED O~ THE DIL, TEE FIRST LOGGING AT 40 KMZ, BOTH PASSES $}40ULD BE INCLUDED OM THE FINAL D'ATA TAPE, ~QW~V~R, ONLY SUBTLE IJI~F~RFNCES WErE SEEM ~ETWEEN THE bOGS, RE~ARKS CDLL/~SFL PASS3: TOOL STRING CBOT'~OP) = DLL-MSFLCSRTC)-~R-TCC-AMS-BRIDbE. THERE WERE TWO SEVERE PULLS OM T}~F FIRST LOGGI~ PASS. FOR THIS RE~SON IT WAS DECIDED NOT TO RETURN TO TD FOR A COMPLETE REPEAT SECTION. THE REPEAT WAS A SMALL SECTION ABOVE TF~E LAST ~UL[,. TNM LO~ D~TA FLAT-{~INES IN PLACES DUE TO TEE PULLS. TRE 40 KHZ PHA$OR IMOUCTIO~ REPEAT IS INCLUDED OM THE ]RD FILE OM TMIS T,~E !~ ORDE~ TO KEEP TEE NI{~BE~ OF CHANNELS IN THE 1ST rILE .At, b DAT.~ ON T~IS LIBRARY TaPE ~TC'HES FIELD '~LUEbINES' ENVIRONMENTAL CORRECTED POROSITIES ARE ALSO I~CLUDED O~ THIS TAPE, THE PROGRA~ NA~ES, P~A~ETERS USED, AND C~AMMEL ~,A~ES ARE: PRECNA vERSION 001HO9+18 1 BHPS= 0 (MOREHOLE PANEL ~ETTIMG) !DSm CR (CALC, FROM CO!.I~T RATES) RaTCAL= 2.~35 (SHOP TANK RATIO) SOCNL: 0,5 (STANDOFF ~FFSET) TCNT= CMTM (TOOL TYPE) HOLE SIZE CORreCTION STANDOFF CORRECTION NPHI,S~N NDHI.LIH MP~I,DOb PRELDT VERSION 005H06+1~ 2 DBNC: CALl (CALl USED FO~ CORR,} I$$.CR: 0 (CALC. FRO~ RHOB) TLDTm LgTD (TOOL TYPE} ISS.~RO= 0 (STANDARD CO~P[!TE) PHO~AT= 2.65 (MATRI×} BOREHOLE CORRECTION PFDC,$AM uFDC,bIM PWDC.DOL DATE JOB STARTED: ]l-OCT-90 JOB REFERENCE NO: 74161. LDP/A~A: KONRING PAGE: ****************************************************************************** , * FILE - ED!T.O01 ichlumberger Alaska Comput{ng Center 29-~R-1993 10:2~ SAG NORTH 2-38/$N-0! ~PI 50-029-g2090 DTE 20 KHZ MAIN. PASS LOG DATA FRO~ FIELD FILE ,O56 BHC MAIN PASS LOG DATA FROt4 FIELD F!hE ,056 LDT/CNL/N~T MAiN'PASS LO~.iD~TA FR~:M'FIELD'FILE ,O1! DATA SAMPLED EVERY -,5000 F~E? DATA INCLUDED TOOL EXTENSION TYPE USED DIT-E ,DTE B~C .gHC bDT .LDT CNT-A/D/H 'CNL NGT ,NGT DLL ,DLL PHA$OR [)UAL INDUCTION SFL BORE}{OLE COMPENSATED SONIC LITHO DENSITY CC]MPENSAT~D NEUTRON , ~ATURAL ~.~MA SPECTROSCOPY DUAL LATEROLOG (6" SAMPLED) 13792' TO 13327' 13783' TO 13327' 13797' TO 13327' 137R4' TO ~3327' ~3780' TO ~3327' 13771' TO !33~7' ****************************************************************************** PAGE: 4 TUNI VALU DEFI C~ Bp F~ SAG NORTH WN 2-3~/$~-01 ~PI APIN 50-02g-2~OgO FL 201!' SNL & 9284' WEL S~CT 36 COI!N NORTH SLOPE STAT ALASK~ NATI USA WITN ~CMULL~N/~OoRE SON 549188 APO ~T 56, E~B FT '999,25 EnF FT 56, EGL FT J4,5 TB~ FT 13832, Tnb FT 13816, BLI ~T 13~12, Company ~ame ~ield Name Well Name ~PI Serial Number Field Location Sect~on~ Township Ra~oe County State or Province Nation Witness' Name Service Order ~umber Permanent datum ~tevat~oD of Perm, Datum Log ueasured From ~OOV~ PERMANENT DATU~ Elevation of Kelly BushiDo Elevation of Derric~ Floor Elevation of Ground Leue! Total Depth - Driller Total Depth - Log~er Bottom Log Interval ;~IS Taoe verification Listtnq ~e~lu~berqer Alaska ComPutt~q Center 29-~AR-!993 ),0:23 PAGE: 5 TUfT YABU DEFI '"' .......................... "'"'"'""'";; .............. T~,! ~T ~2~00. Too D~T I, IGNOSL!LFO A E Dril[I6 UId DFD G/C3 9.700001 Dr'~lt~nQ Fluld Densit~ D~PH 10,5 Drill~nQ Fluid Pb ' D~V S 35, Dr~ll~n~ Fluid V~scosit¥ D~L F3 5.6 Dr~ll~no Fluid LOBS ~S OH.M ! 5 Resistivity of ~ud SamPle ~ST DEGF i 7~ ~'ud...Sample Temperature~ ~ ~FS OM~ Re$1$tiv~..t¥ of"mud filtrates gFST DEaF 9~' ~ud Wiltrate Sample Temperatu R~CS oHM~ I 71 gesistlv~t¥ of MUd Cake Sampl ~CST DEGF 7~. Mud Cake Sample Temperature TCS 07:00 OCT-~8 Time Circulation Stopped TLAB 16:32 0CT-~8 Time l, oqaer at ~ottom ~MT DKGF ~03, Bottom ~ole Temperature SFL~) SP IDP~ IFRW C!~P ~T~ D? TT~ TT4 G~ T~NS ~ES DEF! ~eoth Channe~ ~edium Induction standard ProceSsed Res~stivl. ty Deep Induction. Standard Processeu Reslstivitv Spontaneous ~otentlal INDUCTION DEeP PHASOR RESISTIVITY INDUCTION MEDI'IJ~ PHASOR RESISTIVITY Induction Calibrated Frequencv_ _ IOOF DEEP IMDUCTIOM OUALITY FACTOR I~QF MED INDUCTION OUALITY FACTOR %NDUCTIOM DEEP PHASO~ CONDUCTIVITY INDUCTION ~EDIU~ PHA$O~ CONDUCTIVITY Deem Inductlom Real Intermediate Conductivity Deed Induction Ouad Intermediate Conduet~vit¥ ~edlum Induction Peal Intermediate Conductlv~tv ~amma Ray Tenslon Mud Temperature ~UD Reslstlv~tv Head Tension TRANSIT TI~E TRANSIT T!~E 2 TRAN~I· T!~E Tg~$IT TI~E 4 S~ontaneous Potential Gamma ~av Tension gud Temperature ~[.)D Res!st~v~ty gead Tension Schlumberger PAGE: ~0~ OLS LU LL LITH 8~HV L~RH C~5! D~V~ PI~Z T~NS ~TEN P~Df TNPH NPO~ ~CNT RCFT C.TC CFTC TENS HTE~ POTA U~ ~ensitv Porosity Bulk Density ~hotoeleCtric Factor Ou~tItV control of 1oho sPaclPq OU~l t~ eontro! on ~hort t.,DT [,on~ Svaeinq Comvute~ Count ~ate (LL+LU/2) Lo~ UnDer !~2 W~ndow Count ~ate 5one Lower. Window Count Rate Short SPacin~ 1 Window Count Rate $hort SLating 2 window Count Rate Short SDactn~ IDensitV Long SDacino RHOB (Uncorrected) CaliDer Relative Azimuth of gole'"Drift Uranium, Potassiu~ Hole A~imutn Devietion Pad ! Azimuth SDectroscoDy. Gamma~a¥ Co~Duted GP from ThOriUm, Ten,ion ~ud Temperature ~UD ~esistlvit¥ ~ead Tension Porosttv From tlc FDC Tool POrOSity From the FDC Tool ~OroStt9 From. t~e FDC Tool Neutron PorositV Thermal Neutron Calibrated Ther~a! Neutron Ratio ~eutron Porosity Outnut From an AP~!lcatlon ~C~T ~CFT CFTC Spectroscopy Gamma-Ray ~ead Tension Neutron Porosity ~eutro~ Porosity ~eutro~ ~oros~tv S~eetrosco~y Gamma-Rev Computed GR from ThoTtum, ?hOriUm Potassium Uraniu~ Window 2 (,5 - ~,! Uranium, Proaram Potassiu~ ,IS Taoe Yerificatton Listing ;chlumberq'er Alaska Comp~&t~n~ Center 29-~AR-~993 !0~3 PA ~E: W~N~ Window WSN~ Window 5 T~N8 Tension CS Cable Smeed ~TE~ Head Tension LbS Latero-Lo~ Shallow (Resistivity) LtD Latero-Lo~ Deed (~esistivitv) Cabs Sonic Caliper SP SDontaneou~ Potential G~ Gamma T~NS Tension MTE~ ~U~ Temperature ~ES ~UD Resistiv~tv HTEN Head Tension ~m~m~mmmmmmmm~m~,m~m~mmmm~m~m~mmmm~m~mmmmmm~mmmmm~m~m~N~m ** DATA FORMAT $P$C'IFIC~TION RECORD ** SET TYPE - 64EB ~* TYPE !,~,P~ CSDE VALUE 1 66 2 66 0 3 73 396 4 66 5 66 6 73 7 65 9 65 Ii 66 !3 66 0 14 65 FT 15 66 68 16 66 1 O 66 0 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ** SET ?YPY' - CHAN -~........... ......... ........................,,,, ..... :::: ~[; ........... . .............. ID ORDER ~ 50G TYPE CLASS MOD NUM~ ...... ...... .. .... ~- ..... .......... .... ... ......... ~ ..... T ..... ~.....-.. .............. DFDT FT .0188 O0 000 O0 0 ~ 68 0000000000 SFLU DTE OHM~ 5491g~ O0 000 O0 0 ~ ~ 1 4 6g 0000000000 II~U DT~ OMMM 540188 O0 000 O0 0 1 1 I 4 6~ 0000000000 ILO DT~ O~{Wu 549198 90 00~ 09 0 ! 1 ! a 69 0000000000 Tape Verification Listino Schlumberger AlasKa Compt3. t].nO Center 29-MAR-t993 t0:23 PAGE: SP OT~ ~ 549188 IDPN DTE OH~ 549~88 I~Pg DTE OU~ 54~18~ !FR~ DT~ HZ 549188 I~QF DT~ 5491~8 C~DD DTE MMHO 549188 C!~P DTE ~HO ~4~!88 ]I~D DT~ M~gO 5491~8 I!XD ~T~ MMNO 549188 I!R~ DT~ M~HO 5~9188 TENS DTE LB 5491~8 MTE~ DTE DEGF 549198 ~E~ DT~ ONMM 549188 HTEN DTE LB 549188 DT BHC US/F 5491.88 TT1 BHC US 549188 TT] BHC US 549188 TT3 BMC US 549188 TT4 BHC US 549188 BP BHC ~V 549188 G~ BHC GAP! 5491~8 TENS BHC LB 549188 MTK~ BHC DEGF 549188 M~ES BHC O~M~ 549188 RwOB LD? G/C3 549188 D~O bDT G/C3 549188 PEF LDT 5&9188 QSS LDT 549188 LS LDT CPS 54~188 LU LOT CPS 549188 LL bDT CPS 549188 LITN LOT CPS 549188 SS1 LOT CPS 549188 SS2 bDT CPS 549188 LSHV LDT V 549198 S~M LDT G/C] 5491~8 LSRw LDT G/C~ 549188 LUW~ LDT G/C~ 5491~8 CALI LDT IN 549188 ~B LOT DEG 549~88 AZI" LDT DFG 549188 NAZI LDT DEG ~49188 DFV! LDT DEG 549188 P~AZ LDT DEG 549188 SCR LDT GAPI 5491~8 LOG TYPE O0 o00 OO 0 1 O0 00o oo 0 1 oo o00 O0 0 O0 000 oo 0 ! O0 000 O0 0 O0 000 O0 0 1 O0 000 O0 0 o0 000 oO 0 O0 000 O0 0 !. O0 000 O0 0 O0 000 O0 0 O0 o00 OO 0 OO o00 O0 0 I O0 oo0 oo 0 ! O0 000 O0 0 O0 000 O0 o O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 O0 000 OO 0 O0 o00 O0 O0 000 O0 0 O0 000 O0 0 1 O0 000 O0 0 1 O0 000 O0 0 1 O0 000 OO o 1 O0 000 O0 0 O0 o00 O0 0 O0 o00 oo o 1 O0 000 OO 0 O0 000 O0 0 1 O0 0o0 oo 0 1 O0 000 O0 0 O0 000 OO 0 oO 00o O0 0 1 O0 000 O0 0 O0 000 O0 0 1 00 000 00 0 1 O0 000 O0 0 00 000 O0 0 1 On 000 oo 0 O0 000 O0 0 t oo gO0 O0 0 1 O0 000 O0 0 1 OO 000 O0 0 1 O0 000 O0 0 1 O0 000 O0 0 00 000 00 0 1 oo 000 O0 0 1 OO 00o OO 0 t O0 000 oo 0 ! ! i 4 68 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 ! I 4 68 0000000000 ! ! 4 68 0000000000 ~ I 4 6~ 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 ! ! 4 68 0000000000 I I 4 68 0000000000 I 1 4 68 0000000000 ! 1 4 68 0000000000 ! I. 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 I ~. 4 6~ 0000000000 1 I 4 68 0000000000 ~ I 4 68 0000000000 1 ! 4 68 0000000000 ! I 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000000000 1 I 4 68 0000000000 ! 1 4 68 0000000000 1 ! 4 6~ 0000000000 1 ~, 4 68 0000000000 I ! 4 68 0000000000 ! I 4 68 0000000000 ! 1 4 68 0000000000 1 1 4. 68 0000000000 ! I 4 68 0000000000 ~ 1 ~ 68 OOOO000000 ! I 4 68 0000000000 ! I 4 68 0000000000 1 ! 4 68 0000000000 1 ! 4 68 0000000000 1 1 ~ 68 0000000000 1 1 ~ 68 0000000000 ! ! 4 68 0000000900 I I 4 68 0000000000 1 1 4 68 0000000000 ~ 1 4 68 O000000000 ! I 4 68 0000000000 ! I a 68 0000000000 1 1 4 68 0000000000 ! 1 4 68 OOOO000000 ! I 4 68 0000000000 1 1 4 68 0000000000 ! ! 4 68 0000000000 1 1 4 6~ OO00000000 ;chlumberger~"~lesKa,'Computin~ Center 29-MAP-!993 10:23 PAGE: , . N~ S~RV UNIT SE~vic~ API ~P! ~P! ~P ID ORDER ~ bOG TYPE Cb~88 ~0 C~ bDT GADI 549188 O0 000 O0 0 T~NS bDT bM 5491~8 O0 000 O0 0 MTE~ bDT DEGF 549188 O0 000 O0 0 M~ES bDT OMM~ 549~88 O0 000 O0 0 HTEN DDT LB 549188 O0 000 O0 0 PFDC S~ PU 549188 O0 000 O0 0 PFDC bi~ PU 549188 O0 000 O0 0 PFDC DOb DU 549~8 O0 000 O0 0 NPHI CML PU 549~8 O0 000 O0 0 T~PH CML PU 549188 OD 000 O0 0 TNR~ CNL 549188 O0 000 O0 O NPO~ CNL PU 54918~ O0 000 O0 0 RCNT CNL CPS ~49~88 O0 000 OC 0 ~CFT CNL CPS 549I~8 O0 000 O0 0 C~TC CNL CPS 549188 O0 000 O0 0 CFTC CNL CPS 549188 O0 fi00 rio 0 $~R CNL GAP! 549188 O0 000 O0 0 T~N~ CML LB 549188 O0 000 O0 0 HT~N CNL [,B 5491~8 00 O00 00 0 ~PHI SAM DU 54918~ O0 000 O0 0 NPM! [,IM PU 549188 O0 000 O0 O NPH! DOL PU 549188 O0 000 O0 0 $~ NGT c~pI 549188 O0 000 O0 0 CGR- NGT ~API 549188 O0 000 OO 0 TMO~ NGT PPM 54918~ O0 000 O0 0 POT~ ~GT PU 5491~ O0 000 O0 0 U~N NGT PDM 549188 O0 000 O0 0 WIN~ NGT CPS 549188 O0 000 O0 0 W~NG NGT CPS 549188 O0 000 O0 0 W~NG NGT CPS 5491~8 O0 000 O0 0 W4N~ NG? CPS 5401~8 O0 GO0 O0 0 WS~G NGT CPS 54918~ O0 000 O0 0 T~Ng NGT LB 549188 O0 000 O0 0 C~ NGT F/M~ 54918~ O0 000 O0 0 MTEN NGT LB 540188 00 000 00 0 LLS DLL OH~. 549108 O0 000 O0 0 L[,D DLL OH~M 549!88 O0 000 O0 0 CILS DLL IN 549~98 O0 000 O0 0 SD DLL ~%t ~491~8 O0 000 O0 0 ~ DLL GAPI ~401~8 O0 000 O0 0 T~NS DLL LB 540188 O0 000 O0 0 MTE~ DLL DEGF 549188 O0 000 O0 0 ~Eg DLL OH~ R49188 O0 000 O0 0 HTr? DLL LB 549188 00 00o O0 o 1 't ! 4 1 ! I ! 1. 1 ! ! 1 4 1 1 1 4 t 1 I 4 I I I 4 I 1 I 4 1 I 1 4 I ! ! 4 I 1 1 4 I ! I 4 1 1 t 4 I .! I 4 i I I 4 ~. 1 4 I I I, 4 1 1 1. 4 I ! 1 4 1 1 1 4 I 1 I 4 1 1 1 4 1 ! ! 4 1 ~, I 4 ! 1. 1 4 I ! 1 4 I .! I 4 ! 1 1 4 1 ! 1 4 1 1 ! 4 I I I 4 ! 1 I 4 ! 1 1 4 1 ~. 1 4 1 ! 1 4 1 I ! CODE {HEX) 68 O00000OO00 68 O000CO0000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 000o000000 68 OOnO000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O00OO00000 68 0000000000 68 OOOO000000 0000000000 68 0000000000 68 O00000OO00 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 #mmmmmmmmmmmmmmm#mmmmmmmmmmmmMm ** DATA ** Tape Verl~.tcatton List~.ng ~cblumber~er ~laska ComPUtir~o Center DEPT.:~ 13BV4,000 SP.DmE -40,3!3 TDP~.DTE lPQF,DTE 3,000 IMQF.DTE TEN$,DTE 3490,000 DT.BHC 64,50Q TTI,~HC TT4 BUC 342,000 SP,BWC ~HO~,.LDT -999.250 DRMO, LDT OS$,LDT -999.250 LS,LDT L~TN,LDT -999,250 S$1.LDT $SHV'LDT -999,~250 SIRH.LDT C~L!,LDT -999,250 DEVT,LDT -999.,2:50 PIAZ.LD~ T~N~,LDT -999,250 MTEM,LDT ~DC'SAN -999,250 PFDC,LIM TNPN.CN[, -999 250 TNR~ .CNL RCrT,CNb -999:250 CNTC:CNb -99 250 POT,,NGT -999,250 ~3NG.:NGT -999.250 W4, G,NGT C$,NGT -999,250 ~TM~.NGT CALS,DLL -999,250 SP,DLL MTE~,DLL -999,250 ~R~S,DLL · DEPT, 13800.000 SVLU,DTE SP,DTE -~3.141 TDPH,DTE IDOW.DTE 0'000 I~F.DTE I!~,DTM 18,9~4 IIXD,DTE TE~$ DTE 7270,000 ~TEM,.DTE DT:~HC 64,500 TTI,BH~ TT4.,B~C 34~ OOO SP,BHC ~HOR,LDT 2,624 DR~,LDT OS$,LDT 0,0!~ L$,LDT L!TW,LDT 54.1~5 $SI.LDT SSHV,bDT 13~6,000 SlRH,LDT CALI,LDT 8,922 RB,LDT DEV?,LDT 25,2~9 PI~Z,LDT TENS.bDT 7315.000 "TEM,LDT PFDC,SAN 1,409 PFDC.LIM TN~g,CNb 4,741 TN~A,CNL RCWT,CN5 7579,807 CMTC,CNL TENS,CML 7~5,000 ~TEN,CML NPHI.DOL -0.~98 SGR,NGT POTa.MGT ~,54! URAM,NGT w3~C.MGT 39.~00 w4~!G,NGT CS.NG~ 8d~,O00 ~TE~,NGT C~LS.DLL 3,1~9 SP,DbL ~TE".DLL 197,150 29'MAR-!993 4'5~ ~96.750 ~40,3!3 0'35~ -999 250 -999 ~50 -999 ~50 -999 50 999,250 -999, -990,~5050 -999.~50 999'~5~ -999,~50 -999,~50 -999, 50 -999,~50 29 594 0,000 -1,780 196,750 470,800 -23.141 0,354 0,024 20~ 75O 2,523 173 956 211:967 195,750 4,869 ~..017 7532.067 615.000 74.844 5,!60 8.~94 15 000 0.360 !bM,DTE !~P~,DTE CIDP,OTE IIR~,DTE ~RES,DTE TT~,BHC GR,B~C HTEN,B~C PEF,bDT L:U.hDT SS2,LDT LSR~,LDT ~ZI~,LDT SGR,bDT MRES,LDT PFDC,DOL NPOR.CNL C~TC,CNb ~PHT,SAM CGR,NGT W1NG.NGT W5MG,NGT LLS,DLL GR,DbL HTE~,DLL IL~,DTE I~PH,DTE CIDP,DTE IIR~,DTE TT2,BMC GR"BMC HTEN.BHC PEF.SDT LU.LDT LSR~,LDT AZI~,LDT SGR,bDT PFDC,DOL NPO~,CNb CFTC,CML NPHI,S~N CGR,NGT WlNG.NCT WbNG,MG? bLS.DLL GR,DbL HTE~,DLL !9,063 t0.578 49 81 0~354 ~42,~00 ,753,094 10'500 -999;~50 -999:250 -999,250 -999.250 g 250 -999.250 -099.250 ;99.250 -999'250 2999.250 999.~50 -999.~50 -g99'~50 1 922 20..2~9 5~.469 0 354 5 094 246,500 3 297 267.750 2,600 38,643 74,844 0,356 4,676 7686.549 3.243 37.543 ~5~.~@5 ~.739 595.021 69.625 -296,500 IbD,DTE C!MP,DTE ~R,DTE HTEN.D~ 'TENS,~HC DPHI'tDT OLS,LDT LL,LDT LSMV,LDT LU~M.bDT NAZI.bDT CGR,LDT HTEN,LDT MPPm.CML RCNT,CNL SGR,CNL NPHI.,LI~ TMOR,MGT W?~G,NGT TENS.MGT LLO,DLL TENS.Dbl., It.,D,DTE CI~P,DTE GR,DTE HTEN,DTE TT3,BHC TENS,FMC DP~I.LDT OL$,LDT Lb,bDT LSHV,LDT GURH.LDT H~ZILDT CGR:LDT MT~N,LDT NPHI.CNb RC~T,C~L S~R,CMb THOP.NGT w~G.NGT T£~S.MGT LLD.DbL TENS.DUb 51.,7i9 20.000 53.094 -7!0.500 471.600 3490,000 -999,~50 -999,250 -999,250 -999,~50 -999,~50 -999,~50 -999. 50 -999,~50 '999.,~50 '999,~50 '999,~50 -999,~50 '999,~50 '999~50 '999,250 '999,250 47 25 o: oo 52.7~1 53,094 246,500 471,600 7270,000 1,603 0.023 ~464,000 2,615 ]8,643 37,543 615,000 ~,645 7930,788 74,844 0,4~7 3,721 116,114 7315.000 624.3~! 6460.000 bis TaPe verif!catlo~ List~no ~chlumber~er Alaska Comput~no Center D~PT 13Z00.000 SFLU DTE !DOF DTE 0.000 !~OF DTE IT~'DT~ Ia3.1~¢ IIXD"D~ TE~,DT~ 7090,000 DW.BHC 78.700 TTI'MMC TT4.~HC 380.400 SP'BHC ~TE~.B~C 199.375 ~OB.LDT 2.444 DR~O.LDT DSS.bDT 0'005 L$'LDT L?Tg LQT ~3.750 SSi.bDT SSF{V:LDT t337.000 SIRH'LDT CALT.LDT 9.586 RB.LDT DEVI.LDT ~6.668 PlAZ:.LDT TNP~.C~L 25.2!.9 TNP~ CHh RCFT.CNL 1372.444 C~TC CNL TFNS.CNL 7265.000 HTEg CNL NPH~.OOL 15.847 SGR NGT POTa.NGT 0.5~6 URAN,NGT W]~G.NGT 22.556 W4NG.MGT CS.~GT 860.000 ~TEN.~GT CALS.DLL 9.4~4 SP,DLL MTE~.DLL i97.375 ~RES.DL5 DEPT.. 13600.O00 SFLU~DTE SP.DTE !6.000 IDPH,DTE IDQF.DT~ 0.000 I~OF.DTE IIRD.DTE 1~0.938 IiXD.DTE TEN$.DTE 6980,000 ~TE~,DTE DT.~HC 72.500 TT1.BHC TT~.BHC 356.400 SP.B~C MTE~.BHC 199.750 MRE$.B~C RHOR.LDT 2,54] DRMO.LDT DSS.bDT 0.017 LS.LDT LITH.LDT 65.]~] SSI.bDT $SHV.LDT 1338.000 SI~H.LDT C~I..T.LDT 9.4~4 RB.LDT D_VI,L~T ~7,821 P!~Z,LDT TEN~.LD? 7710.000 ~TEg. LDT p~D ..S,AN 6.207 PFDC.LI~ T~P~.C~L ~3.345 TN~AoCNL ~CFT.CNL 1309.675 CNTc. CNL TEN$.CNL 7710.000 ~T~.CNL NDH~.DOL 14.2o3 SGP.N~T POTa.MGT ~.572 URA~.NGT W3N~.NGT 62.375 W4~G.NCT C~.NGT 887.500 ~TEN.NGT CA[.~..DLL 10.500 SP.DLL ~TE~.DLL lO8,950 ~R~$,DLL 29-~AR-1.993 10:23 6.75~ I:L~.DTE 6,156 I~P~.OTE 0.000 CIDP.OTE 7.875 IIR~.~°DTE !9B.~75 53~.000 TT2'BHC -22,125 GR,BHC 0,357 -0.009 PEF.L~T ~641750 187.750 2,490 1~1 171 AZ!~.LDT ~.95.i75 ~RES.~DT !5. 04 PFDC.DO5 44.6]6 3.969 WlNG.N~T .7'049 WbNG.NGT 621.500 LI,,S.DLL 0,364 HTE~,DL~ 8.297 IL~.DTE 8,086 0.000 CIDP.DTE 6,387 199.750 ~RES'DTE 49~.400 TT~.B~C 16.O00 GR.O~C 0.360 HTEN,BHC 0 024 ~.UUT 237[00o ~U.LDT 198.500 SS2.LDT 2,44! LSRH,LDT 181 437 219:458 SGR,bDT 194,000 9,498 PFDC,DOD ~8~.000 NPHI.SaN 10~.875 CGR.~GT 9.48~ W5NG.NGT 8~.000 LL$.DLL 38.406 GR.DLL 0.361 ~TEN.DLL 5.949 6.023 !6~375 !5 1 5o 0.357 375.200 48.094 196.~50 ~53.500 ~71.500 ~.451 37~28 441636 21.,756 25 1409 ~=20 23 O45 15 95O !50 846 6.91~ 44.000 376.750 3.5G3 0.360 360.800 9m,625 ~53.!25 3.~87 ~29.000 27~:000 5~8 104,875 0,376 16,392 22.99~ 1342.893 ..~?0 357.285 ~.475 7.117 ~04. 75 ~77.750 ILD. CI~P. TT3. T~NS. bSHV. HTEN~ RCNT. NPHI, W~NG. TmNS. LLD. ILD. GR. HT~N TENS. DPHI, ObS, LL, H~Z!., CGm. HTEN. NPHI. RCNT. SGR. NPHI. THOR. W2N~. T~NS. LLD. T~NS. DTE DTE DTE DTE DTE BHC I.,DT LDT bDT LDT bDT LDT bDT C N L CNI., CNL bI~ NGT NOT NOT Dt.L DLL DTE DTE BHC LDT bDT bDT LDT bDT LDT LDT bDT CNL CNL CNL I~I~ NGT NGT DLL PAGE{ 11 6,078 20,000 165875 4 :o9 196 250 7090.000 !2.507 0:.004 37,828 15.990 621,500 24.205 35670 :069 62.500 0 ? 977 o:ooo I~ 625 253 125 500 000 69~0.000 6.496 0,008 122,43B 1469,000 2.5~7 37.833 77.270 882 000 22~B30 3271.142 104~875 16,051 10,117 152.196 7710.000 7.950 7795.000 ,IS ?~De Verlfic~t~on List~n~ ;chlumberger Alaska Compute, hq Center SP, TE 79,500 IDPH'DTE !DQF,DTE 0,000 I~0F,DTE. i!RD.DTE 132,875 ~IXD-DTE TENS,DTE 6460,000 MTEM.DTE DT,R}{C 77.i00 TT1,BHC TT4 B~C 3~2 800 SP, BHC R~O~,LDT 2 5~7 D~H~,LDT 5!T,.5DT 64 625 SS~ ~DT CALI.LDT 1!,367 RB.LOT DEVI',.LDT ~0,934 PJ.~Z.LDT T~NS,LDT 6875,000 ~TES.LDT PFDC.SAN 6,303 PFDC.LI~ T~PN,CNL ~g.~966 TN~.CNL RCFT,CNL {0~5.609 CNTC,CNL T~N$,CNb 6875,000 ~TENoCNL NDH~DO5 19.123 S~R,NGT POTA.NGT 2,715 URAN,NGT W3N~.N~T 62,325 W4NG,NGT CS.NGT 885.500 HTEN.NGT CAL~,DLL ~1,383 SP.DLL ~TE~.DL5 198.388 ~RE$.DLL DEPT 1, 340o. 000 SFt, U DTE I~F,DTE o,000 I~OF.PTE II~D,DTE 35,813 TE~S,DTE 6390,000 HTE~.DTE DT,B}{C 91.200 TTI,BHC TT4,BHC 397,200 ~T~.,BHc 196.750 gR~$.BHC ~HOB.LDT 2,348 DR~O.LDT OS$.SDT 0.008 ~S.LDT L?TH.,LDT 100.185 $S1.LDT 8SHV.LDT 1338.000 C~.LDT 8 922 ~B.LDT DE .bY? 32:2o7 PlAZ.LD TENS.LDT 6920.000 ~TE~.LnT PFDC.$AN {$.1~4 ~FDC.LYg TNP,.CNb ~2.9~7 ~CFT.CgL 16~2.583 C~TC.C~b TENS.CNL 6920.000 NP~T.DOL ~4.023 SGR.NGT POTA.NGT 0.5~3 URAg.i~G? W~NG.NGT 13.000 w4~G.NGT C$.NGT ~9,000 CALS.DLL 8,844 $P.DLL MTEW.DLL 198,050 ~RE$.DLL 29-~A~-1993 I0:23 5.863 ILM.DTE 6,555 IMPH..DTE 0,000 CiDP,DTE ~981000 M'~E$.DTE 544,.~00 79'= 00 GR,B~C O. 58 262.}50 LU'LDT 21~.125 SS2 SD? 180,444 216~666 ~9~ 375 9:590 PFDC'DOL 2,698 NPOR.,CNh 2733.~97 CFTC,C~L ~ 500 469 GR,DL5 0.358 HTEN.DLL 22 438 27[92~ IB~PH,DTE -0!6!5 !!~,OTE 196 750 ~{RES gTE 584.000 TT2:BHC 20.953 GR.BHC 0o36B H~EN.~HC -0 0~0 309~75o GU.DDt ~92.625 S$2,hDT 2.396 LSRH,LDT ~8~.933 A~I~.LDT 225.206 SGR,bDT 90 ~25 ~RES.bDT 20[996 PFDC.DOL ~.240 ~POR.CNL 3795.856 CFTC.CN5 5~9,500 NPHI,SIN 24.5~2 CGR.NGT 2.500 W5NG.NG? 589.500 LLS.DLL 1.935 5988 62~19 0 5O 0358 3951600 78.31 ~.947 2196 0 49 36.149 I14.67~ 0.376 16.477 ~5.458 994.}76 26.82! ~5.'.111 389.~2! 9-481 ! 89.063 19188 202156 35 49:1 69 0,365 396.800 20969 568 282 0 57 37.028 24.562 0.383 ~7.0!5 ~2.335 1692.717 82.500 1.000 22.606 24,094 302.750 ILD.DTE IFRE.DTE C!~D.DTE HTEN TENS.B~C DPM!.LDT OLS.LDT bL.LDT LSMV.LDT LURM.LDT ~ZI.LDT CGR.LDT HTE~LDT ~PHT:CNL RCNT.CNL SGR.C~5 NPHIoLI~ THOR.NGT W2NG.NGT TEN$.NGT 5LD.DLL TENS.DbL CIMP.DT~ H~EN.D~E TT3.BHC TEN$.BHC DP~I..LDT O~S.LDT LL'LDT LSHV.LDT 5URH.LDT H~ZI.LDT CGR.LDT HTEN,L~T NPH/.CNL RCNT.CNb SGR.CNb THOR.MGT WSNG,NGT TENS.NGT LLD.DLL TE~S.QLL PAGE: !2 6570 202000 I60 5 78,3!3 551.200 6460.000 6'837 0,006 136,875 ~469,000 2,465 36 14:9 85:111 537.500 26,421 3165,740 1!4,673 21.660 11.628 179.64! 6875-000 6.5 25.1~8 ~.000 ,594 20.969 152.000 574.000 63~0000 18:280 0.004 163.750 1469.000 2,365 37.0?8 ~6.022 589.500 21,987 4055,267 24.562 15.948 1.895 39.500 6920.0O0 32.929 75~5.000 -;chlumberoer AlasKa Computina' Center TE:N~,DT~ 6575.000 DT,~HC 52,~00 TTI.BHC 600 s .B c O$S.L~T: -0.O~5 LS.LDT L~T~,LD? !3.1!7 $SHV*bDT !3~9.000 SI~H,LDT CAL~,LDT 9,06] RB.LDT DEVI.LDT ]!.285 PiAZ.LDT TE~{S,LDT 6720,000 ~TE~.LDT PFDC,SA~ ~5,907 PFDC,LI'~ TNP~.CN[, -999,250 TN~A.CNb RCFT,CN[, 3~8,'235 CgTC,CNL T~NR.CNL 67~0,000 HTEN'CNL ~PH~.QO5 42,815 SGR.N~T PgT,~.NGT ~.997 URAN.NGT W3NG.NGT 72,000 CS.NGT 1797,000 HTEN.NGT CR:L$,DLL 8.961 ~TE~.DLL 195,462 ~R~g. DLb D~PT' 13200.000 SFLU.DTE sp. DTE -999,~50 tDPH.DTE IDOF.DTE -999 250 I~OF,DTE IIRD,~TE -9992250 IIXD,DTE T~NS,DTE -999.250 ~TE~.DTE DT,BHC -999,250 TTIoBHC TT4 BNC -999.250 SP,BHC MTE~BHC -099,250 MR~S.B~C R~OB,LDT 2.040 DRNO.,LDT O$S.LD? -0.1~5 LS.LDT LITM.[,DT 14.617 $S1.LDT SSHV,.L~T ~3]~.000 SI~H.LDT CAL~ [,,DT 9.063 6EV..:LD?- 12.601 PIAZ,LDT T~NS.LD? 64]5,000 PrDC.SA~ 36.841 PFDC,LI~ T~P~.C~iL -999 250 TNRh.CNL RCFT.C~L 356:588 CNTC.CN5 TFgS,CNL 6435,000 NTEN,CNL NP~T,DO[, 42,759 SGR,NGT POT~.qGT 1,852 URAN.NGT W3~,gGT 60,078 W4~'G.N~T C$,~GT 1798,000 HTEN,~GT CAL$.D[.L -9o9,250 ~T~.OLL -999.250 29-~A~-]993 10:2'] 9696,000 IL)~:.DTE 0 000 C!DP,DTE 191,250 ~RES,DTE 45~.000 TT~,B~C 46:2!9 GR.BHC -0,~45 PEF,LDT 111.688 LU,LDT 57,06] SS2.LDT 4.789 LSRH.LDT 21~.217 AZI~,LDT 32 ,785 SG~.LDT 2~506 PFDC.bOL !4~6. 90 CFTC, ~ C~.L 54:~.500 ~PHI.:SAN 150,~{7 CGR,NGT 12.~39 Wl~G.NGT 20.500 WS~G.~GT -I .,95 0.372 HT~N.DLL -999.250 CiDP,DTE -999,250 -999.250 TT2.~HC -999] ,O HT~N,BHC -0,821 PEF.SDT 139,000 LU,LDT o.156 SS2.U T 4.594 LSRM.LDT 145.460 AZI~.LQT 4.642 SGR,bDT 18~.875 gRES.LDT 39.057 P~DC.DOL 4.06~ NPOR.CNb ~474.505 CFTC,CNL 500,000 NPHI,SAN ~6.195 CGR,N~T 9.44! 10.659 w5NG.~GT 500.000 LLS,~LL -999,~50 GR,D[,L -99q.~50 HTEN,~)L5 950000 i95o2ooo 67 -771 0.385 322.400 .6,S75 21.938 t!9.688 84 75 109.38t 150.217 0 40I 332952 -999.250 364.559 52 52 :soo 0.148 !40.875 262.000 -999.250 -999.250 -999.250 -999.250 -999.~50 -999'250 -999 250 28 469 145 500 98.43~ 2.85 219.837 126.~95 0.414 4~.699 -999.250 360.114 52.295 57.944 429.264 11.628 -999.250 -999,250 -999.~50 ILD.DTE IFRE2DTE CIMP.DTE TE~S.B~C DP~I.LDT LL.LDT bSH'V:.L~T ~UPH.LDT CGR.LDT HTEN'LDT NPMI.CWL RCNT.CNL $GR,CNL NPHI'Lt~ T~OR.MGT TENS.NGT LLD.DbL TENS.DLL ILD'DTE CIMP.DTE GR.DTE HT~:~ DTE TT 3: TEN$.B~C OLS.LDT LL.LDT L$gV.LDT LURH.LDT NAZI.LDT CGP.LDT gT~N.LDT NPHI.CNL RC~T,CN5 SGR.CNL NPHI,LI~ T~OP.NGT W?NGoNGT TEM$.MGT LLD,DLL TENS.DLL PAGE: 13 i~ 531 000 -76 000 128 625 ol:i oo 6575,000 26,066 0,068 51.875 1467,000 3.1~9 109.381 6~,730 542.500 55.425 1619.816 49,895 8'319 250.~000 6720,000 0,367 U290o000 -999 250 -9992250 -999250 -999:250 -999.250 -999,250 -999,250 36,972 0.017 66.250 1467.000 2.900 210 837 5~:944 500.on0 48,515 1509,697 126,195 49,8~9 7,901 210,271 6435,000 999,250 '-.,.IS TaPe v~r~:tcst!on ~.chlumherqer Alaska COmputino Center DEPT !31.00 000 SFLtJ,DTE IQQV.DTE -999.250 IT~D.DTE -999,250 TENS.DTE -999,250 ~TE~,DTE DToBHC -999.250 TTi,BHC TT4.B~C -999 250 SP,BHC ~E" ~HC -999"250 g~OB. bDT 1 .~79~ DRH~.LDT OSS.LD? -0.-173 L~., bDT L!T~.LDT ! 8,703 SS1,LDT SSHV.LDT t339'000 SlRHi. LDT ~ALI,LDT 8 938 D~gI.LDT 5:857 PI~Z,LI)T T~NS.[.:,DT 6280,000 ~TEM,LDT PFDC.SAN · 51,510 PFDC,LIM TNPg.CN5 -999,~50 TN,A.,CNL ~CFT.CN5 357,814 C~TC.C~b T~NS,CNL 6280.000 ~TEN,CN5 ~PHI.O05 38.188 POTB,NGT 2 198 ~RAN.NGT w~NC.NGT 59:671. -4NG,NGT C$,NGT ~795,000 C~L$,DLL -999,~50 SP.DLL ~TE~.Db5 -999,250 DRVT. 13000,000 SFLU'DTE SP.DTE -999,250 IDOW.DTE -999.250 YgOF,DTE IIRU..DT~ -999,~50 IIXD'DTE TE~K.DTE -999,250 ){TEM.DTE DT.BHC -999,250 TTI,BHC TT4,BMC '999,250 8P,BHC MTE~.BHC -999,'290 MRE$.BMC HOP.bDT 2,26~ D~HO.I,DT .... UIT!{ LDT 12.164 SSI*LDT 8SHV:LDT !338.000 SI~H.LDT CALT.LDT 8,961 RB.LDT DEVI,LDT 29.4~8 TFNS.LDT 6200.000 ~TE~.LDT PFDC.SAN 73.4!0 PFDC,LI~.~ T~PU,CNL -999.250 TN~A.C~L ~CFT'CN[, 457.600 C~TC,C~L TF~,C~L 6200.000 ~TEN,CNL NPH!.DOL 35,574 POTA,MGT 1.881. U~.~g,NGT W3NC.NGT 44,4~! W4NG,NGT C~.~GT ~792.0OO ~TEg,NGT CaLS.DLL -999,250 SP,DLL ~T~.~LL -999.250 ~REg. DLL 29-MAR-~.993 ~0:~3 "999,2~0 '999.~50 "999'~50 '999.~50 999 50 !~0 925 6~750 54,969 4,703 2 ~ 27 180 25 1368,65~ 8 314 12 346 482 ~50 -~99 5O -999,250 -999 - 9:50 -99~,250 -99 -999,250 -999.250 0,792 59,969 4,68R 179,500 26.098 3.79? 1715.830 483,500 98,444 5.153 13.430 483.500 -~99.250 -999.?50 I~La-D~E CIDPoDTE ~RES.DTE TT~.B~C PgF.LQT LU.bOT S$2.LDT LSR~{.LDT AZI~.L~T SGR'LDT MR~S.LDT PFDC.DOL gPOR.CNL CVTC, CNL gP~I,SAN CGR.NGT ~NG,NGT W:SNG,NGT LLS.DLL HTE~,DLL IL~.DTE I~PH.DTE CIDP.DTE I!RM.QTE ~RES.DTE GR.BUC MTEN.BgC PEF.LDT LU,bDT SS2.LDT LS~H.bDT AZI~.bDT SGR,LOT ~mES,DDT PFDC,DOb MPOR,CNL CFTC,C~b CGR.MGT W!NG.MGT W5NG.MGT !,L$.DI.L GR.gLL HT~.DLL :999 250 999:~50 :999- so 990.~50 -999~50 -9991: so 2~ !72 170!150 98 75 60.24 ~19-~i0 0,426 56.793 -999.~50 359.6i4 47.570 59.705 407 407 -99250 -999'250 -999.250 -999250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 22 281 121.:375 89.6~5 3.053 8~.306 98.444 0.429 31.727 -999.250 468.32~ 44.829 61.189 322.314 8.~64 999 250 -999.~50 DILD, TE IFRE,DTE CI~.P.~TE MTEM DTE TENS.BMC DPMI.LDT OL$.LDT LL.LDT I.SHVPDT HAZILDT HTEN.LDT NPNI.CNL RCMT,CNL SGR,CNb T~OR,NGT WgNG.NGT TE~$.NGT 5LDDI. L iLD.DTE tFRM,DTE CIMP DTE HTMN.DTE TT3.BHC TENS.BHC DPHI.LDT ~LS.LDT LL.LDT LSHV.LDT bURN.bDT NAZI.bDT CGR,LDT HT~N.LDT NPHI.C~L RCNT.CNL SGR.C~b NPHI.LIM T~O~.NGT W~,G.WGT TENS.NGT LLD.DLL TENS.DLL PAGE~ t4 999,250 999,250 999,250 -999,250 '999,250 ~999,250 -999,250 51,611 0,045 8i,3'75 1467,000 2..754 60.247 59~705 482"250 49,947 1396,744 119,81.0 44.~73 6,955 182,099 6280,000 -999.250 -999~250 -999 250 -999 250 -999250 -9992250 99,250 '923,560 0,037 51.688 1467.000 3.100 88,306 61,189 483,500 43,552 1770.351 98,444 41.104 8,648 161.157 6200,000 -999,250 -999,250 5~S. Ta~e veriftcat ion bistin~ ~ch!umber~er AlasKa ComPutlnq Center D~PT 1.2900 o00 SFL!I'o DTE iDOF.DT~ -999,2:50 ~MO~,DTE IIRD. DTE -999, ~250 IXD,DTE T~NS.. DT~. -gqq 250 MTEM,D.. E DT. ~ -999: 250 TTI*BHC TT4.BNC -999,250 SP:. BHC MTE~' BHC -999.2~0 ~R~S~ BHC R~OB,~DT 2,473 DRHO,LDT OSS* [,DT -0.0 ~ 8 LS. SS}~V.LDT 1.3~7.000 S1RH,LDT C~LT,LDT 8 ~..22 ~B,LDT D~VT,LDT 35.984 P1AZ*LDT T~]NS*LDT 6150.000 ~.TE~. LDT PFDC.S~N 10,57~ DFDC,LI~! RfFT..CML 448.20! CNTC*CML TENS,CNL 6~50.000 HTEN C~L NPH~.DO5 35,396 POT~. NGT I ,888 ~.,~,~ N~ 42 471 ~4NG,NGT C~,NGT 1~33,000 HT~N. ~G'T CA.L~ .. DUb -999 * 250 SD'. DLL MTE~,DLL -999,~50 ~RE.5, DLL DEpT' 17591 500 SFLU.DTE IDOF,DTE -999,250 I~OF*DTE I'T~D,DTE -9991250 IIXD,DTE TENS,DT~ -999,250 MT~,DTE DT,BHC -999,250 TTi,BHC TT4.BHC -999,250 ~TK~,BHC -999,250 ~R~S,BHC RHOF.LDT ~,~97 DRHD,LDT Oo~ I, DT -0 113 b$..bDT [,ITP,LDT 13,594 SSl,LDT SSHV.LD? 1338.000 SI~H,LDT C~LI,LD~ ~ 922 RB,LDT D~VT.LD~ 29:940 TENS.SDT 6210,000 ~TEM L~T PFDC.SAU 27,29B T~PM.CNL -999 250 Tg~A,C~L RCFT.C~L 3~1:558 CNTC,CNb T~WS.CNb 62{0.000 H?EN.CNL ~PHT,DOL 40,50B SGR,N~T POTA.NGT ~.605 w]N~.NGT 4~.3~ W4NG:NGT CS.NGT 1~4.000 HTgN.N~T C~Lg.DLL -999.250 SP.DL5 ~T~.Db!., -909.250 ~RES.DLL END OF DATA -999.250 !LN,DT~ -999.250 I~PH.DTB -999,~50 Ct. DP,~Tg -999,~50 IIR~:.DTE -990,250 ~PES,DTE -999'250 TT2,BHC '999,250 o99~DSO .~..~C '0.935 PEF,LDT ~3.43~ LU.LDT 49.D50 $S2.LDT 5.238 LS~H..bDT 166.~20 ~ZI~obDT t!4,9~5 178.~ 5 ~3, 09 PFDC,DOL 3,63~ NPOR,CNG ~638.~40 CFTC.CMb 493,250 NP[{I,SAN 7~,065 CGR.NGT 3 4'37 Wi!~ING~ .N'GT 0~ 965 WSNG,NGT 493 ~50 I, LS,DLL '999~.50 G~.DbL -999..~50 HTEN.DLL -999 ~50 -q99! 50 INPH.DTE -999 ~50 CiDP-DTE -999.250 IIR~,DTE -99 ... -99~ ~50 GR.~HC -999~50 HTEN:,BHC 120.688 LU.LDT 60,28! S$2,LDT 4.648 5SRN,LDT 1~7.73] A.Z!~.LDT 103.048 !78.125 2RES,LOT 29.~49 PFDC.DOL 3 899 1522~757 CFTC,CNL 481.750 68.597 CG~.NGT 2.971 ~,964 WS~G.NGT 4~,750 -999.~50 GR,DLL -999.950 -999'250 -~99.250 99~ ~50 :999.250 -999.~50 9?.375 63 !~5 3 406 3~_.I. 35 .2.065 0.437 20.~82 '999 250 44.64~ 47,:~17 24t.313 ~-896 -999.~50 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -~99 250 -999,250 -99~,250 18.625 130.625 94.500 2.986 27~ 142 0.437 35.192 -999.250 394.121 49.979 47.117 245.868 6.~98 -999.250 -999.250 -99o.~50 ILDDTE CI{P .DTE MTEN.DTE TT3.BHC TENS,BHC DPHI.LDT Qb$.LDT Lb.LDT bSHV.LDT LU~M.LDT M~ZI.LDT CGR.LDT HTE~.LDT NPHI.CNb ~CNT,CNL SG~.C~L NPMI,LI~ TROR.NGT W2NG.NGT TENS.NGT LLD.DbL TEN$'DLL Z~D'DTE IFRB.DTE CI~P },{TEN DTE TT~:~C TE~S.BHC DPHI.bDT QL$.LDT Lb. LDT LSMV.LDT LURH.LDT H.~ZI.LOT CG~,LDT HTEN.SDT ~PHI.CML RCwT.CNL SGR.CNL THOR.MGT ~2~G.WGT TEMS.WGT TEMS.DLL PAGE: t5 999,250 999,~50 999.2'50 999.250 -999,250 -999 ~50 719 000 493.~50 40~649 !754,770 72,065 40°888 4,886 ~,969 6150,000 -999,250 -999250 -999,250 -999,250 -999 250 -999,~50 27°434 -0.015 55.313 1466.000 3,0t4 274.142 47,~7 481,750 45.375 ~634,220 68,597 47.~0! 6.018 97.107 6210.000 -999.250 -999.250 ~chlt.-,mberq~r Alasl~a Co~PutJ. nO Center 29-MA.R-!gg3 t~0:23 **** FILE TRAILEP **** FILE MAgE : EDIT .00~ VERSION ! 00~A06 ~AX. REC SIZE : ~0~4 FILF TYPE : LO **** FILE MEADER **** FIL~ MAME : EDIT .002 SERVICE ~ FbIC VERSION ~AX REC $!ZE : 1024 FILF TYPE : LO ********************************************************************************* '~ 002 FIL .....' EDIT, BP ~XPb~RATIt]M SAG NORTN ~-~8/SN-0~. , , * * , , * MAIM PASS Dbb DATA FROM FIELD FILE ,066 DATA SAMPLED EVERY -.1667 FEET DATA INCLI!DMO - TO0!, EXTENSION TYPE USED D[,b TOOL NA~E DUAL hATEPO[,OG ~.3771' TO 13327' ****************************************************************************** TABLE TYPF., : Co~s Tt!NI VALU DEFI CN BP EXPLORATION Company Name FN S~G NORTh{ Wield Name 5IS Tape veriflcation bist~no ~chlumberger A].aska Computing Center 29-MAR-1993 10:23 PAGE~ 17 APIN FL S~CT TOWN COUN STAT SON 549189 ~PD FT O. APD FT 56 E~B FT '9~9.~5 EDF FT 56. TD5 FT 38 DFPH !6. D~V $ 35. DFL F3 5.,6 a cs ~CST DEGF 7~, TCS 07:00 v~bu 50'029m~2090 201~.' SNL & 2284' ALASKA USA ~C~ULLEN/~OO~E 5 0CT-28 DEFI Well Nam~ APl:Serial ~umber Field Location Section~ Township Range County State or Prov~nce Nation Wttness'..Name Se~vtce Or~e~ Number Permanent ~atum EleVation of Perm, Datum ~o~ ~easured From ABOVE PErMAnENT DATUM Elevation of Kelly Bushing Elevation of Derrie~ Elevatiom of Ground tevelrO Total Depth - Driller Total Demth - Logger Bottom Log Interva! Tom bog ~nterval na F1 Id Density u D~ll!lno Fluid Ph Drillina FlUid viscosity Drillina.,.Fluld Loss ResistiVity of MUd Sample ~ud Sample Temperature Resistivity of mud filtrate s ~ud,~Flltrate Sample Temperatu Resist!v~tv of Mud Ca~e SamDl .ud CaMe Sample Temperature Time Circulation Sto~ped 16:32 0CT-28 Time Lo~qer At Bottom BHT .DEC, F. 203, . ~ottom Hole Temperature mmmmmmm mm mmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmm~ mmmmmmmmmmmmm~mmmmmmmm~m~mmmm~mmmmmmmmmmmmmmmmmmmm T~BI, E TYPE OEF! ~Ep~ e t Ch n el-Nam~ p h a n e ~$FL ~S~[, Res~ stivitv $~!~ Synthetic ~icro-Inverse Resistivity S~Nn Synthetic ~icro-Normal ~esisttvity ~cblusberqer Alaska Computima' Center PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR,CODE VALUE 2 66 3 73 5 66 7 65 9 65 ~.~ 66 13 66 1~ 65 15 66 ~6 66 0 66 0,166 wT 64 0 FT 68 1 1 mmmmmmm#mmmmmmm#mmmmmmmmm.mmm. ** SET TYPE - CHAN ** -----.--,,,----------------.........--.---,,,-......,...... ......... -.......-;~.....--. ORDER ~ LOG TYPE CLASS ~OD NUMB SA~P ELEM CODE (HEX) D~pT FT 5491~8 0O 000 O0 0 2 I t 4 6~ 0000000000 ~FL DLL GHEE 549188 OO 000 OD 0 2 ! 1 4 68 0000000000 $~IN DLb OMM~ 540188 00 000 O0 0 2 I I 4 6~ 0000000000 $~NO DLL O~M~ 5491~8 O0 000 00 0 2 ! I 4 65 0000000000 DEPT. 13815.834 MSFL.DLh 1.588 S~IN.DbL 0.378 SMNO.DLL DEPT. 13800.000 ~SFU.DLL 1.588 S~IN.OLL 0.378 SMNO.DLL DEPT. 13700.000 ~SFL.~LL 13.453 S~I~.DLL 7.?15 $~NO.DLL DEPT. 13600.000 ~$FL.DLb 4.344 SMIN.DLL 0.629 S~NO.DLL D~PT. 13500.000 MSFL.DLL 8.414 SgIN.Db~ 1.225 SmNO.DLL D~PT. 13400.000 ~SFD.DLL i6.313 S~!N.OLL 1.905 S~NO.DbL DFPT. 13292.500 "SFL.DLL 0.~29 S~I~.DLL 0.420 S~NO.DLL 0.264 0.264 6.7~7 0.885 1.979 3.293 -0.205 ** END OF DATA ** ~,i!$ Ta~,e YerffJ. cot~on List~n~ ~chlumberqer Alaska Co~putin~ Center **** FILE TRAILER F!L~ NA~E : EDIT .002 SERVICE ~ FL!C DATE 90/~I/ 1 !0~4 FILE TYPE : LO **** FILM HEADER **** FILE ~AME ~ EDIT .00t SERVICE ~ FLTC V~RMtO~! : 00IA06 DATE i 90/11/ I MAX REC S:!ZE :' !0~4 FILE TYPE : LO LAST F~LE ~ 29-~AR-1993 ],0:23 PAGE: 19 ******************************************************************************* , , , , , , , , , , FILM - EDIT.003 EXPLORATION DTE 40 ~HZ REPEAT PASS DATA FRO~ FIELD FILE .059 D~TA SA"' * ,. - .. · PLE, D EVERY .5 FEET DATA INCb!!DED - TOO[, EXTENSION TYP~ USeD DTE .DTR TOOL PHASOR INDUCTION 13792' TO 13327' ****************************************************************************** T~LE TYPF ~ C~MS ~chlumberqer Alaska CornrJutlnq Center 29-~AP.-).993 i0{23 PAGE,,"' 20 SECT TOteM COUP! STAT MATI WiTN SON ~L ~FT DFL ~ST ~MC'S TCS B~T T!)~! VALU ', DgFI 2-3~/SN-01 ~P! Well Name 50-029-~2090 E A~I Serial Number 20~1' SNL & ~284' w:L F1e!d Location 36 Section t2N Township t6E Range  iORTH S~OPE County LAS~A ..... State or ~rovince USA Nation , ~C~ULLEN/MOORE witness ~a. me 54 188 " Service or,er Number ~$b Permanent datum FT 0 ~levation Of Perm. Datu~ " D~ boo geasured From: FT 56, ABOVE PER~ANE~T DATU~ PT -999.~5 ~levat~on of Kelly Bushino FT 56. Elevation of Derrick Floor FT 14,5 Blevatlon.of G~ound LeVel ~T ']8~2' Total De~th ' Driller PT '13816~ TotalDePth - bo~ger Bottom bo ~terva! ~T 12900. TOp bO~ X~t rV~le LIGNOSUL~ONATK Drill: n~ Fluid Type ~/C3 967000o~' Drill n~ FlUid Density ~ ,5 D~.iXI~Q Fluid Ph S ~5, Drilling Fluid VisCos~ty F3 5 6 Drllllno..Fluld Loss OH~ 1:5 ResistiVity of ~ud SamPle DEGF ~ Mud.,.Samp~e T mperature ~H.~ ?-..§ Res~st~v~t~. ~f mud ~lttrate , DEGF 73, M~d filtrate Sample Temperatu OH~ 1 71 Res[st!vitF of Mud Ca~e Samsl -. ~u~ Cake Semele Temperature 07:0o OCT-28 Time'c~rculation Stopped ~6:32 0CT-~8 Time Logger At Bottom TYPE : CURV SFL!? ILM SP I~PH IW~F IDQF I~OF SFL ~eslstivttv (unaveraqed) ,ediu~ Induction StaDdar~ Processed Resistiuity Deed Induction Standard Processed Resistivity Spontaneous Potential TNDUCTIO~{ DEeP PHA$O~ RESISTIVITY INDUCTION ~EDI!I~ DHASOR RESISTIVITy %nduction Calibrated Frequency IDOF DE~P INDUCTIO~? QUALITY FACTOR ~OF ~ED INDUCTIO~ OtT~LITY FACTO~ LIS Ta~e verification Listinq ~cb).u~berg..r Alaska ComDutIn~ Center 29-MAR-1993 10:~3 - . C!DP IIXD I!R~ TENS ~TE~ Dee~ Imductlon Real IDtermedlate Conductivity Dee~ Indtlctton Ouad Intermediate ConduCtiVity ~edlum Induction ~ea! I~termedlate Conduct~~~ty Ga~sa Ray Tens~oD .ud Temperature gUD Resistiv~tv Head Tension ** DATA FnR~AT SPMCIFIC~TIi)N RECORD ** SET TYPE - 64EB.'** TYPE ~EP~ CODE 1 66 0 2 66 0 3 73 5 66 6 7 65 9 65 F II 66 12 12 68 !] 66 0 14 65 FI ~5 66 68 !6 66 0 ~6 DFPT FT SFLI! DTR ILD DTR SP DTR IDPM DTR OgMM IFR~ DT~ HZ IOOr DTR YPE - CHAN ** mmmmmmmmmmmmmmmmmmmmmmmm m mm mm mmmmmmmmmmmmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 49188 O0 000 O0 0 3 1 i 4 68 O000000OO0 49188 O0 000 O0 0 3 1 I 4 68 0000000000 491~8 O0 000 O0 0 3 1 1 4 68 0000000000 49188 O0 000 CO 0 3 I 1 4 68 0000000000 49!~ O0 000 O0 0 3 1 1 4 68 0000000000 491~8 O0 000 O0 0 ] 1 1 4 68 0000000000 4918~ O0 000 O0 0 3 I 1 4 68 0000000000 49188 O0 000 O0 0 3 1 1 4 68 0000000000 49188 O0 000 O0 0 3 ! I 4 68 000O0O0000 ~I,q Taoe verification List!no ~c .... lumberqev Alaska ComputtnO Center 29-~A~-1993 10:23 PAGE 22 ~ SEPV ~T SE~V~C~ API ID ORDER a LOG TYPE %~OW DT~ 549188 O0 000 CIDP DTR M~HO 5491~8 O0 000 00 CI~D OTP M~HO 549188 00 000 O0 IIRD DTR M~HQ 549188 O0 000 O0 I!XO DTR M"MO 549188 00 000 00 IIRv DTR ~NO 5491~8 0O 000 00 GR DTR GAPI 549188 00 000 O0 TEN~ DTR LB 54~188 O0 000 O0 MTEM DTR OEGF 54Q18~ 00 OD0 00 ~RE$ DTR ON~M 549188 00 000 00 HTEw DTR LB 549108 00 000 00 ~OD N 0 0 3 0 3 0 3 O 0 3 ELE~ CODE (HEX) 1 I .4 68 0000000000 1 I 4 68 0000000090 ! I 4 68 0000000000 I I 4 68 0000000000 J ~ 4 68 0000000000 ! I 4 68 0000000000 ! I 4 68 0000000000 ! I ~ 68 0000000000 I I 4 68 000fi000000 1 ! 4 68 0000000000 I 1 4 68 0000000000 DATA DEPT, 8P.DTR iD~F,DTR IIRg. DTW TENS.DTn D~PT.. ID~W.DTR II~D.DT~ DEPT, ~P.DTR !D~W.DTm IIRD,DTR DEPT, S~,DTR IDOW,DTR II~D,DTR TFNS.DT~ DEPT. SP,DTR IDO~,DTR I!RD,DTR TENS.DT~ SP.DT~ IDO~.DT~ TEN$.DTR 13860,000 SFLU,DTR 30 16.891 IDP~.DTR 57 3 OOO IMOF,[TR) ' 2 !6;375 IIXD.DTR 1 5605.000 MTE'~. D~R 19q 13~,000 SFL'U DTt~ ' .859 0 ~0 I~OF.DTR 1.6: 6 7365.000 13Z00.000 SFLU DTP ~8,078 IDPH:DTR o ooo !42:000 I!×D.DTR 6850,000 ~TF~.DTR o.ooo 13!.375 II~O.DT~ o.ooo , 4oo.ooo -19.797 IDPH.DTR 0.000 7~O~.DTR 40.500 6400.009 ~TE~.DTR 30 57 0 199 6 5 0 17 199 8 6 15 200 ! I~PH O'.~ .047 DTR , 047 IFRE,DTR ,000 CIDP,D~ 17 297 CI~P,DTR .481 IIRM,DTR 45~844 GR,DT~ .375 MRE$,DTR 0.351 HTEM,DT~ :031 IL~ DTR 21 .547 ILD,DTR 344 I~PH;DTR 21:484 IFRE.PT~ .000 CIDP.DTm 147.422 CIMP,DTR .5~7 II~!,DTR 4 .813 GR,DTR ,3 5 MgES,DTR 0. 351 MTE~-~.DTR ,000 .266 ,375 ILY,DTR 5 859 ILD.DT~ IMPH.:DTP 5~855 IFRE.DTR CIDP.DTR ~68.000 CI~P.DTR IPu.DTR ~59,500 GR.DT~ ~RES,DTR 0 356 HTEN DTR .070 ILM,DTR 7.156 ILD,OT~ .438 IP~P~.DTR 7.227 IFRE.DTR .000 C!DP.DTR ].55.250 CI~P.DTR .703 TI~.DT~ 131,500 GP.DTR .125 ~RES.DTR 0·358 HTEN.DTP 8·500 ILM.UTR 6.629 IbD.DTR 6,51~ !~PH.DT~ 7.258 IFRE.DTR 0.000 CIDP.DTR 15~.500 CIMP.DT~ 16,984 %!R~,DTR ~41.625 GR.DTP 198,250 MRES.DTR 0.354 HTE~.DT~ . ~91 I!.,~.DT~ 19,594 IbD.DT~ .750 INP' N,DTR 1g.813 IFRK...,DTW. 0,000 CIDP,DTR 42.063 C!YP.DTR 3.307 IIR~.D~R 49.219 GR,DTP 7 000 ES 0 359 HTE~ DT~ · . ~ .DTP .... 2 2 !9 57,656 40.000 47.469 49.438 -569,500 56.875 40,000 46 500 49!43~ 232 625 855 4 :ooo 170.625 41,188 236.000 6.336 40.000 138.250 105.063 283.500 6.527 40.000 137 625 106:6~5 119.688 23,313 40.000 50,438 22.641 142,250 LIS Tape Yer!,fication Listino SchlUmberger AlasKa Computin~ center 29-gAR-1993 10:23 23 DEPT. 13~00 000 SFLU!DTR SP.DTR 24:469 IDPH DTR IDQV.DTR O.00O !~OF DTR TENS'DT~ 6405 000 ~TE~ DT~ DEPT., 13~9 500 ~FLU.DT~ SP..DTR -~7~375 IDPM.DTR IDOF.DT~ 0.OO0 !~OF.DTR I!RD.DT~ 19.64.~ XIXD.DTR TEN$.DTR 6400.000 MTE~.DT~ ** END OF DATA ** 9696.000 ILg. DTR 38.625 I~{PH.DT~ 0.000 CtDP.DTR -!34.~25 II~,DTR ~9~.O00 ~PES.DTR 9696.000 ILiq.DTR 51.063 IMPH.[)TR 0.000 CIDP.DT~ -87.~25 IIR~..DTR 19~...56 M'RE$'DTR t950.O00 ILD.DTR t950.000 IFRE.DTR 25.875 CIMP.DT~ '40,53~. GR.DTR 1950.000 ILD.DTR !.950.000 IFRE.DTR 19.56] CI~P.DT~ -1§.430 GR.DT~ 0.382 HTEN.DT~ 38 7~I 40~000 -39.563 i34.000 i69.625 48.844 40.000 -23.~34 8.~ ..~75 !57.6~5 **** FILM TRAILER **** FILM NAME ~ EDIT SERVICE : FLIC VERSION ~ O0~A06 ~X REC SIZE : 1024 FILM TYPE ! [~0 LAST FILE **** TAPE TRAILER **** SERVICE NAME : EDIT DATE. ~ ~0/1!/ ~ O~!GIN ~ FLIC TaPF NA~E : 74~6! COMTXNUAT!O~ # : ~ P~EVIOUS TAPE : CO~ENT : BP EXPLORATION, **** REEL TRAII.,E~ **** SERVICE NAME : EDIT DATF REEL NA~E ~ 74~6~ CON?IN[JAT!OM # PREVIOUS REEL CO~E~T : BP EXPLORATION, SAG NORTH, SAG NORTH, 2=38/SN'0~ MPI, 2'3~/SN'0! ~PI, AP1 AP1 #50=02g-22090 #50=029-22090 A~CHORAGE, ~$KA 99518 907/56~-~654 ! TAPE VErifICATION LISTING LIS FORMAT LIS TAPE VErIFICaTION FOR RFT FIELD TAPE RECEIVED APR 1 5 199~ ~Jaska Oil & Gas Cons. Commisslor~ ~chorage JobNumber Company Name Well Name F~eld Name Countv State Date ACquired Run Number Oate Processed Files Include4 RP EXPLOPAT!ON S~G NO~TH ~!ORTN SLOPE ALASK~ 28-OCT-90 29-~A~-g3 RFT FILES .018 THPU .046 SChlumberger Page 500 WEST INTERNATI[)WAL ~tRPORT ~OAD A~!CMO~AGE, ALaSkA 995~'8 907/562-265~ TAPE VERIFICATION L~STING bis FORe, AT LIS TAPE VEPIFIC~.~ri[]N FOR RFT FIELD T~PM Job Number Companv ~ame Well ~a~ Fte]d ~ame Countv State Date ~c~ulred Run Number Date Processed Files I~cluded 74161 BP EXPLOPATION NORTH SLOPE ALASKA 28'0CT-90 29'~A~-g3 RFT FILES ,018 THRU .046 RECEIVED Oil & Gas Cons. Commission Anchorage ~cblumber~er Page 3 ! LIST Command List{nE K~Y ! LIST SUmmArY MNEMONICS tteD for Logical LIS stru s: FILE CAbbrev: F) LIS logical file info TAP~ (Abbrev: T) LIS logical tape ln~o R~EL (Abbrev: R) LIS logical reel info and for the entire LIS/A input lOgical l~mlt: LU (Abbrev: L) LIS/A logical unit info The field ],ab:els_appear on some or al! of these summaries, as i~icate~ by the abbrev, en right, Su~mary F{e].d Labels{ REELS ~tlmber o~ logical reels on (L ) TAPES Number o( Io~Ical ~9~es on CL~ ) FILES Number of logical~!~es on (LRT) #PR 9umber of physical records (LRTF) ~[,R ~umber o~ logical records (LPTF) ~DR ~umber of data records ( F) #FMC ~umber of encrypted records ( F) ~F~ Number of data frames f F) PI Primary index channel name... ( ~) PI_UNITS Pr!mary index units mnemonic ( F) MAXPI ~aximum primary index value ( F) ~IMPI M~n~mum primary index value ( F) NOTE - DEPTH OF PRESSURE TEST IS RECORDED ~S CHANNEL FDEP, FQEP IS ALSO LISTED IN "CONS" TABLE ON'TESTS ~HE~E THE CS[] T~BLES W~R~ DUmPeD TO TAPE. FOR FORMATION TEST FILE$. "DEPT" INCLUDED IN THESE LISTINGS DOES ~OT REFER Ti] DEPTH OF MEASUREmeNT BUT IS !NTER!~ab CCU~TER []SMD WHFM ~EASI~I~G IN TI~E. IN AM ~TT~PT TO KEFP THIS I.!ISTIMG TO A ~EA$OMABLE LRNGTH, ONLY SPECIFIC CHA~NELS ~ND CONSTANTS ARE LISTED' THIS LISTING DOES NOT INC!.UDE g~NY OF THE CHANNELS AND CONSTANTS INCLUDED ON THE FIELD TAP~. Schlumberqer LIST ~'~U~O:[]L!SA.DAT; ~9-MAR-93 II:!7:01 Page 4 ~eel beeder 5491S8 COMTI~UAT!OM ~: O0 PREVIOUS CO~E~T : SCMLD~BERGE~ WELL SERVICES CSU TAPE TaPe header 549188 ** TAPE HEADEP ** SERvIcE N~E : D~TM : 90/t0/29 O~I~IN : CSU T~P~ ~A~E : 549188 CO~TINUATION #: CO~E~T : SCHI~!JMHERGER WELL SERVICES CSU TAPE header G~FT .0~8 ** FILE ~MA~ER ** FILE DATE : 90/10/28 ~AX, RMC,i LEN,: 8192 WILE TYPE ~ PR DREVTOUS FI~E : Table type CON'S L~$tt~Q Of set. 7 type CONS ~BJNA~ STa? PI)MT TUNI FDEP !!NAL F w 13425,2 ~nd Of set Table tYPe CONS L~stin~ of set 8 tYPe OBJ~A~ S~AT PUU! TI)~! VAL{~ ~nd of ~t, ~ch~umberqer L~ST ~!J~O:[]LISA,D~T: ~9-~A~-93 !1:17:0I Page 5 Data fora~at sveci~cat,1~on record. ENTRY V~LUE REPCODE SIZE ~ 0 66 4 ~ 5 ! 66 6 0 73 4 7 INCH 65 9 .!IN 65 4 tl 57 66 1~ 1 66 14 .lin 65 16 I 66 0 0 66 object 0 Llsttnc{ of set 0 tvue C~ . ID ~DER ~ LOG TYP C[,S MOD NUmB Ebb. SA~P COD (~X). , · mmmmmmmmmmmmmmm#mmmmmmmmmmmmmmm~mmmmmmmm~mmm~mmmmmmmmmmm~mmmmmmmmwmm~m~#~m~! .~OD ~R~? S 97 onn o0 0 lB I I 4 ~3 ~00000000 E?IM GRFT S 97 6)6 21 0 18 1 1 4 68 8000000000 SGP GRFT PSIG 97 000 O0 0 1~ 1 ! 4 68 8905000000 PONE GRFT 97 000 O0 0 18 I ! 2 49 8205000000 p?~N ~RFT 97 000 OO 0 1~ 1 ! 2 49 8205000000 PMUN ~RFT 97 000 00 0 ~8 ~ ~ 2 49 ~05090000 GR CRFT GAPX 97 310 01 0 18 t 1 2 49 8400000000 End of Bet r)at.a record type 0 r)EPT 1621200 ,lIN 13510, FT 4117,848 M ........... .... .............................. .... .. .... ............. Ttln 34161~779. ETIM 8.43 SGP 5310'6 96 PONF, 0. PT~N 1 . PHIIN 3. PTHO 5, O~ 35,19 Data record type 0 DEPT 1615200 ,lIN 13460. FT 4102.608 M Tfln 34161~B70 ETI~ 106.40~ SGO 5~70.9~9 PON~ 1. PTEN 7, PHUW 2. PIHO 5, G~ 36,34 ;cblumberoer LIST MUB0i[]LISA,DAT; 29-MAR-g] 1I{!7:0t Page Data record tvDe 0 DgPT 1609200 .lin !34~..0, FT 4087,368 ~ · TflD 341612963 ETIM !99,314 ~GP 5'~43.827 PON~ 3, PTEN 4, PHUN 2. PTMO 5, 18,41 Data recor~ tvDe 0 DEFT 1603200 .]T~ I3]60.~FT 4072.1~8,~ PTEN 2 PHU~ ~ ..THO 5, ~ata r,cora type 0 D£PT 1597200 PT~N O. P~UN ~ile trailer GPF? .0~8 FILE NA~E ~E~VICE NA~E ! LOG VEtS!ON # : 32,4 DATE : ~AX. REC,~ LEN,~ 81,92 ~ILE TYPE : PR ~}E×T FIL~ . #LR #PR ~ENC ~DR · 9F~ PI PI.UflITS ~AXPI MINPI 44 51 0 8 436 D~PT ,1IN 1621~00 1595100 DEFT F 135i0 1.329] 5 17'g48 4osl File header GRFT ,0lq ** FILE HKADER ** FI!,E N~ME : GRFT .019 ~RVIC~ NA~E : LOG VERSTONDATE # :~ 90/i0/28 "AX. REC. LEN.t ~192 FILE TYP~ ~ PR PREVIOUS FIL~ ~ Schlumberger LIST ~UBO~[]LISA.DAT; Table type Listi, n~ of set 7 type CONS OBJNAM STAT PHN! TUN! VAL[! · FDE ))~aL F F 11406, Table tYPe L~$ttn~ of set 8 tYPe .n~dN~ STAT PU~! T~)N! 'VAbU ~mmmmmmmmmwmmmmmmmmmmmmmmmmm ~nd of set Data format specification record L~st~nQ of set 3 type 64~B obJe¢t 0 ---....-.-..-..-.--,,,,,,-..,-.. ENTry VALUE p . ..... ·$ ZE ! o 66  O 66 · 1. 46 7 9 2 4 1 66 5 0 66 ! 6 -12 73 4 7 INCH 65 4 8 ~2 73 4 9 .JIN 65 4 1.1 ~6 66 13 t 66 14 .J. IN 65 4 ~5 73 66 16 ! 66 0 I 66 1 ~nd of 29-~,AR-03 !1:1'7:01 Page 7 Listtnq of set 0 type CHAN --...,............................ ..... -.------,,,,--,,,--... ..... ............ · ID O~DER # LOG TYP CLS ~OD NUM~ ELEu Sa~P COD (HEX) T~D G~FT S 97 000 00 0 19 1 I 4 73 0200800000 ET]~ GRFT S 97 6]6 9~ 0 19 1 ! 4 68 0000800000 S~P GRFT PSIG 97 000 00 0 19 ~ 1 4 68 0905800000 PONY C~F? 97 000 00 0 i9 1 1 ~ 40 0205809000 ~TK~ GgFT 97 000 00 0 19 ! ! 2 49 0205~00000 P~U~ GRFT 97 000 00 0 t9 ~ ! 2 49 PTPO C9~T 97 000 O0 0 !O ~ ! 9 49 0~0~g00000 G~ GRFT GAPl 97 Ii. 0 Oi 0 19 ~. I ~ 4~ 0400800000 ;chlumberger LIST M:U~O:[]bISa,DAT; 2g-MAR-g3 11:!.7:01 Page F~te tra~ler G~FT ,019 ** FILE TRAILKR ** FILE NA~ : GRFT .O19 YER$ION # ~ 32,4 ibE TYPE "*: PR ~E×T FILE : 'EOF) File header GRFT .0~0 FILE NAME : GRFT ,0~0 , , DATE : 90/!O/28 ~AX. REC, LEN.: 'FILE TYPE ~ ~R Tab!.e tYPe CONS I,~sting of set 7 type CONS ~m~m~m~m~m~~mm~m~ OR,JNA~ STAT PI,INT TIINI FDEP UN~L F F 13406, ~~m~~mm~~mmm~m~ ~nd of set Table tvpe CONS l,~sttno of set ~ ty~e CONS PU I TIJNI VAI~I.I ~chl. u~berrler LIST ~t;BO,'.[3LISA,DhTI Data format specification record 11:!7:01 Page Lls'tlno o~i set 5 type 64E~ object 0 ~NTDY VAI~U~ REPCOD~ 8Ig~ · · , 2 0 66 3 !46 79 5 0 66 6 -12 7] 4 7 INCH 65 4 8 ~2 73 4 9 .lin 65 4 !! 56 66 14 .:lin 65 4 15 73 66 !6 I 66 0 ~ 66 ~ndo~ set bistln~ of set 0 type CHAN : %D ORDER # bOG TYP CbS ~OD NUMB ELE~ S~P COD (MEX) TOD C~FT S 97 000 00 0 20 t ~ 4 73 0~00500000 ETIM ~RFT $ 97 636 21 0 20 ~ I 4 68 0000800000 S~P gRFT PSIG 97 000 00 0 ~0 ~ 1 4 68 0205800000 PON~ GRFT' 97 000 00 0 20 1 ! 2 49 0205800000 PTEM GRFT 97 0O0 00 0 20 I I 2 49 0~05800000 P~UN ~¢FT 97 000 O0 0 20 t 9 2 49 O~05800000 PTMO GCFT 97 O00 00 0 20 ! ! 2 49 0~05800000 G~ ~FT GAPI 97 3~0 01 0 20 1 ~. .2 49 0400800000 End of set Data record tvDe 0 BEPT 7864428 .lin 65536.9 FT 19975,6471~ m~~mmmm~m~mm~mm~m~m~mm~m~m~m~mmmm~~~m~m~~m~mm~ TOD 34!,6!36~5 ETI~ 0.357 SGP 5?54.535 PONY 4. PT~N 5. PHHN ~. PTHO 5. GR 88,38 ~m~~m~~m~m~m~mm~mmm~m~mm~~mm~m~m~m~mmmmm~m~m~~m~m Wile trailer GRKT .n~O cblumber~er L%ST Mt!~O,..[]LISA.D.~T; ~9-MAR-93 1I:17:01 Pa~e 10 ** F~LE TRA~L~R ** RrT .o2o DATE UAX REC. LEN,: '8~92 FIL~ TYPE : PR NEXT FIL~ ~,R' #P~ #RNC ~DR #FM PI P~.UNITS MAXD! MINPI , 39 46 0 3 t21 DKPT ,lin 786442R 7862988 DEPT F 65536,9 65524,9 DEPT M 19975.6471 19971,9895~ File. header G~FT ,021 ** FILE HEADER ** FILE NAME ~ GRFT ,021 VERSION ~ DATE FILE TYPE PREVIOUS FILE Data format spec~f~cat, ion record h~stin~ of $~t 7 type 64EB object ENTRY VA~UE REDCODM SIZE ~ 0 66 ~ 0 66 3 146 79 2 4 1 66 5 0 66 6 -12 73 4 7 INCH 65 4 8 12 73 4 9 .lin 11. 56 66 13 I 66 1 14 .lin 65 4 15 73 66 16 1 66 0 1 66 1 ~chlumberger PIST MUBO:[]S!SA.DAT; 29-~A~-93 !I~!7:01 ~age t. 1 ~AM~ ~E~V UNIT SK~vICR APl APl APl APl F~LK NUmB NU~ SIZE ~R~ P~OC~SS .ID ORDER ~ LOC TYP C[,S MOD Nl.{~8 EL~ S~P COD TOD ~WT $ 97 000 00 0 21 ! ! 4 73 0~00800000 ETI~ ~FT $ 97 6~6 ~1 0 2~ ~ ! 4 68 0000800000  Gp GRFT P$IG 97 000 00 0 2t I ~ 4 68 0905800~00 OM~ ~RFT 97 000 00 0 2~i 1 ~ 2 49 0~05800600 PTEN ~RFT' 97 000 00 0 :21 I ! 2 49 0~05~00000 P~HN ~RF'T 97 O00 00 0 2~ 1 ~ 2 49 0~05800000 'PT~O G~FT 97 000 00 0 21 1 1 2 49 0205800000 GR ~.~RFT GAP! 97 3~0 01 0 2! 1 1 2 49 0400800000 ~nd Of set Data record tYPe 0 DEPT 78644~8 ,!iN 65536,9 FT !9975,647!2 ~ 0~ 341613777 ETIiM 0,328 SGP. 5~4~,904 PO~ E~' , PT~O 5, GR 64,63 T ..... ~ 4 PHUN Data rocord t¥~e 0 DEPT 78584~8 ,~.iN 65~6,9 ~T 19960,40712 ~m~~m~m~mmm~m~m~m~~m~~m~m~m~m~m~mm~~~ TOD 341fit. 39~7 ETI~ 150o3~3 SGP 5~9.46~ P~ 9. PT~N 3, PHUN 2. PTHO 5, G~. I04. nata recor~ type 0 TOD 39!6!4077 ETIM 300.3276 SGP. 5~36.~3 PO~E 6, PT~N 3, PHU~ 2, PTHO 5, CW 99,25 l~m~m~m~l~mm~l~l~l~ml~l~ml~lm~m~~m~~mlm~l~lml~mmml~ File tra~.l,r GRFT .021 ** FILE TRAILER ** FILE NA~E : GRFT ,021 VERSION ~ ~ 32,4 ~ATE : 90/10/~8 vAX, REC, LEN,: WILE TYPE ~ PR ~E×T FILE '~7008644~8 7~4~9 295 D~PT ,11 QEPT F 65~6 0 65407 D~PT ~ 19975[~471 i99~6. 206 (EOF) File header GRFT .022 ** FILE HEADE~ ** FILE NA~M : GRFT ,022 ~RVICE ~A~E : LOG VERSION ~ ~ ~.4 DATE ~~0710/~8 ~AX. REC, LEN.~ ~192 FILE TYPM ~ PR PREVIOUS FILE ~ Table type CONS [.,~stlno of set 7 type CO~S ORJNAM STAT PUNI TUN! VALU P UNAb F F 13424, o~ set Table t L~st End of set 8 tyme CONS. STAT PUNI TUNI V~L[! Data format smeclficat~on record Listlno of set 9 type 64EB object 0 ENTP¥ VALLf~ ~nrJR~ ~PC .. SIZE 2 O 66 4 1 66 5 0 66 6. -12 7~ 4 7 TNCH 65 4 8 !2 7~ 4 9' .1!~ 65 4 1~ 56 66 13 ! 66 ! t4 .lIN 65 4 15 73 66 0 1 66 End of set 2g-MAR-g3 1!:17:01 Page 13 L~stlnq of set 0 type CHAN ID ORDER # LOG TYP CLS MOD NIJ~B ELE~ SAMP COD (HEX) TOD GRFT S q7 000 O0 0 22 1 ! 4 7~ 0200800000 o 97 636 ~ 0 2~ ~ I 4 68 000080000~ I ! 4 68 P?EN CRFT 97 000 O0 0 2~ , ~ 2 49 0~05800000 set Data record type 0 D~PT 7~64428 ,lin 65536,9 FT !99'75,64712 ~ TO~ 341;614299 ETI" 0.328 SGP.. 5248.549 PON~ 8. .PT~N..4, PHilN 2, PTHO 5, G~2~,:77 Data rec m)~mmmmm TOD 341 PT~N 5, Pile tra1~er G ** rIb~ TRAIL ~ILE NAME SERVICE NA~E VERSION ~ ~ATE ,AX. AEC, LEN. FILE TYPE ~E~T FILF ord type 0 DEPT 7858428 ,lIN 65486,9 FT !.9960,40712 mm~mmmmmmmwm~mmmmmmmmmmmmmmm~mmm~m~m~mmmm~m~mm~Mm~mmm~ p.u , T.O 4.. gFm .022 I GRFT ,022 LOG .' g0~10/2~ ! 8192 : PR chlumberger LIST MUBOI[]LISg,DAT; 29-~:~AR-g3 1J~'.17:01 Page 1.4 . .... .. ..... ;~ .... ; ................ ~ ~- '''''~; ..... ;; ..... ; ...... 17' ..... '''''''''''''''"''''''''''''''''''''''''''~5~ D~PT .lin .864428 7~530t6 D~PT ~ ~99 5~6471 ~9946.66064 .m.m.m.mmmmm.m..mmmm.mmmmmmmmmmmmmmmmmmmmmmm.mmmm.m--mmmmam'mmmmmmmmmMmmm''' EOF) File header GRFT .0~3 ** WILE HEADE~ MERV!C~ NAME VERS~O~ # : 32 4 FI[]E TYP~ : PR ~REVZOUS F~b~ Data format s~eci~ication record Listing o~. set 11 type 64EB object ENTRY V~L~tE !~E, PCflD ,, STZR 1 0 66 ~ 0 66 1 3 ~:46 79 4 ~ 66 5 0 66 6 -1~ 73 4 7 INCH 65 4 8 12 73 4 9 .1Y~ 65 4 t~ 56 66 ~3 t 66 14 .lin 65 4 15 73 66 16 1 66 0 t 66 b[$tino o~ set 0 ty~e CHAN . mmma ...'aa..mma-- ~ . .... . ;'' '--' · ~' ;;;~ ;E~v ~;~ ~.~c~ ;.~ ;~ ~;T ~; ~ ;""'"'" ..... "'"'"'"' ......o~ ~.,~' ..... "'"'"'"'"""'",","',",,'","'","'"'s o, oo,) ~ .... '"'"'""'" ETI~ GRFT $ 97 6]6 21 0 2~ I ~, 4 68 0000500000 $~P ~RFT DSIG 97 000 00 0 23 ! ~ 4 6~ 0?05800000 ~ONF GCFT q7 00O 00 0 23 ! 1 ? q9 0205~00000 pTEN ~RFT 97 000 00 O 23 I ~ ? 49 0~05800000 DHUN GRFT 07 000 00 0 23 I ~ 2 49 0205800000 ~.0 ~RF.~ .... P! 97 OeO O0 0 23 I 1 2 49 0?05800000 ~d Of Data record tvDe 0 DEPT 7864428 .!IN 65536,9 FT 19975,64712 M TOD 3.41614702 ETIM 0.32:9 8GP 5~55.'36 P~aE PTEN 5, PHU~ ~, PTHO 5, . GR ~9,.47. Data record tvDe~ 0 DEPT 7858428 .1i~.65486.9 FT 19 TOB 34t614882 ETI~ 150,332~ SGP PTEU 5, P~U~ 3, P'T~O 4, . Data r~cord tV TOD 34161 500? PTEN 4, ~{le t'ra)].,er G~F? VERSION # = 3~ 4 = 9o}1 FILE TYPE = PR. ~E×T FILE ,0~3 0/28 945,16712 PO~E g c,P ' 2i..14, 25 ~5 0 21 1130 OEPT ,I.I~ 7864420 7850880 DEPT F 65536.9 65424, ~mmmmmmmm~mm~mm~~m~m~mm~~m~~~mm~~~m~ ~ Vile header GRFT .024 SE~VIC~ NA~E : [~OG DATE ~ 90110/2g w'II~E TYP~ ~ PR PREVIOUS FILE : Data format SPe¢ificat~on record L~stino o~ .set 1] type 64EB. object 0 E~ITRY VAI.,I.IF P.F, PC~D~ SIZE ~nd O~ set. Listing of set 0 type CHAN - ~I~F SFPV U~tT SEPVICE aP! ~PI AP1 AP! FILE NUUB ~U~B SIZE R~P PROCESS ID · ORDEP ~ LOG TYP CLS ~OD NUNB ELE~ SA~P COD (HEX) TOD CRWT S 9~ 000 00 0 24 I t 4 73 0200800000 ETIM ~RFT S 97 636 ~1 0 2~ 1 ~ 4 68 0000800000 SOP CPFT P$iG 97 O00 00 0 ~4 1 ~ 4 6~ 0205800000 PON~ CRFT 97 000 O0 0 24 ! ~ 2 49 0205800000 9T~ ~RFT 97 000 00 0 24 ! ! 2 49 0~05800000 PHUN CRFT 97 000 O0 0 24 ~ 1 ~ 49 0205800000 ~TWO ~RFT 97 000 O0 0 2~ 1 1 2 49 0~05800000 GP ~RFT GAPI 97 310 01 0 24 ! ~ 2 49 0400800000 End of set · ~D 341615l~5 ETIM 0.3~9 SGP 5~72.866 PO~!F.: 2. PTE~,~ 7. PH[IN ~. PTHO 5. GR 39,$8 ..... . ..... T- 29-.r~ AR,, 93 ~: ~.:7:0~ Page 17 ~c~lumoer~er LIST MU80: [ ] LISA, DA ~.., . ~'ile trailer GP~'? .024 ** ~I.L~ TRAILER FILE ~E ": :GRFT '024 VEtS'ION # : ~AX, REC, LEN,~ 9192 PiLE TYPF : PR ~EXT FILE : #LR {PR #ENC ~DR #F'M PI PI_UNITS MAXPI MINPI 5 5 0 1 20 DEPT .I~ 786442~ 7864200 DEPT F ~ 655~6.9 655~5, D~PT ~ ~.9975.6471 19975,068 (EnF] File header GRFT .o25 ** FIbE HEADER SERVICE NAME vERSION # : ~AX, R~C. FiLE TYPE PREVIOUS FILE : Data format EN R V 2 3 146 5 0 6 -12 7 YNC~ 9 .1I~ ~1 56 13 1 14 .1IN 0 ** GRFT ,025 LOG ~2.4 90/10/~8 8192 PR $oecification recora f set !5 type, 64EB object ~mmmm~m~m,mmmm~mmmmm~ ~LU~ RgPCOD~ $?ZE 66 7] 4 65 4 65 66 1 66 I 65 4 66 66 Sch 1umberoer.. LIST. ........ ~}[JBO; [ ] LI,.Ag' , DAT:. 29-NAR-93 I i: 17: Ol Paae 18 Li~ttnQ of set n .. .... ......... .... N ~i~ 'qF:WV [~NTT S~VICE P P TD GNDE~ ~ LOG TY S~P ORFT PSI~ 97 O0 PON~ ~RFT 97 O0 End of set I AP i FILE NUMB NUMB SIZ . P CbS MOD NU~R EL~ S~MP CO 0 on 0 25 I ~ 4 73 6 21 0 ~5 1 I 4 68 0 O0 02 5 I 1, 4 68 0 O0 0 25 I { 2 49 O O0 0 25 I 1 2 49 D 02OO80OOO0 O000gO0000 0~05~00000 0205500000 0205800000 0205~00000 0205800000 040~800000 Data record type 0 CE~P? 7~64428 lIN 65536 9 FT 19975,64712 Tf'~r) 34~:~i5132 ETI~ 0.329 SGP. 527~.366 PONE 1. PTEN 7. PHUN 2,. PTHO 5,. GR .28,81 Datarecor8 true n DEPTT~5~4~8 .lI~ A54R6.9 FT i9960,4071~ M, TOn 3416152R2 ETIM 150.m303 SOP 5264.062 PO~ 4 TOn 34! PTEN 6, trotl~r G File ** FILE TPA!b ?ILE NA~M ~M~VICE NAME VERSION ~ UAX. REC. LEN. mILE TYPE ~EXT F?LF ~FT .025 ER ~ GRFT ,0~5 : LOG : 32,4 ~ 00/10/28 ! Sc!~lum~ercer LI~T MUrAO-'[]LISA.DAT; 20-NiAR-93 1I:17:01 Page !9 .............#LR ~' .... ';'''''''''''"'''~C ~ ~M .... ''''''''"''~''' ~'''''''''''''''''''PI: PI.,l. ~ A~! ..... ''''''2. ........ 28 ''''''''''''''''''''''''''''''''''''''''''0 ~4 ~2~4, DEP?, .ll~', ~ ~ _ . ...... ?.~"912''''''' D~PT ~ 65536.~ 654~.6 D~PT ~ ,9975.~4~t ,99 Wile heade~ GRFT .0~6 WILE NA.~E ~ GRFT .026 SE~VIC~ NA~E : LOG VE'RSIO~ ~ : 32.4 DATE ~AX. .EC. LEN.: 8'192 Data format snec~fication record t, ist~ng of set ~7 t~pe 64EB object, 0 ~NTRY VALUE ~,,PCOI..E 8IZ~ ~.~.........~.........~....~'---- 0 66 I 0 66 3 i46 79 4 ~ 66 1 5 0 66 7 ?NCN 65 4 8 !2 73 4 9 .1I~ 65 11 56 66 ! 14 .lin 65 4 t. 5 73 66 16 ! 66 1 O ! 66 ~nd of set Llsttn~ of set 0 tYpe CHAN ~;~'~'"~;'~;~"~;i';;;';~ ;~ ~ ~. ~,,~ .... s~z~" ........ .~ ~.oc~ss'"' ...... ID O~DER ~ LOG TYP CLS ~D NUmB ELE~ S~MP COD (HEX) ........... ......... ....... . ............ ..... .... .---,-..-..---..,--,, ........ T~D CRPT S 97 000 00 0 26 ! 4 7 00800000 ETI~ G~FT S 97 636 2~ 0 ~6 I 1 4 68 0000800000 SGP G~VT PSTG 97 000 00 0 26 ~ 1 ~ 68 0205800000 PONF C~FT 97 000 00 0 26 1 ! 2 49 0205800000 DTEM GRFT 07 O00 00 O ~6 1 1 2 49 0205800000 P~U~ G~FT 97 000 00 0 26 ! ! ? 49 0~05800000 PTH0 ~FT 97 000 O0 O 26 !.. t. 2 49 0~05~00000 G~ ~RFT GAPI 97 310 01 0 26 i I 2 49 0400800000 Oata record tvve 0 DEPT 7864428 ,!iN 65536,9 ET !9975'647!7_ ~ TOD 3416156~.0 E~'.IM 0,.3~9 SGP.: 5~72,~27 PON~ 2,~ UTEN 7 PHUN ~ P2HC. 5 GR 26,25. Oatar,cord tvue 0DEPT.78584~$ ,lIN 65~85,g FT 19960,4071~ : TOD 341615760 ETI~ 150,3292 SGo ~6~8.26~ pON~ 8, Data recor~ true 0 DEPT 3'R5~4~8 .:lin 65436.9 FT19945,!67!~.'~ · · . ~OD 341615910 ETIN 300,3285 SGP 4373.586 PON~ 3,.: PTEM 7. PHUN:3.:: PTHO 4, (;R .:30,23 . Flle trailer G.F~ .o~z RAMS : DATE· t 90}10/~8 "aX, REC,, BEN,: 819~ ~IL~ TYPE : PR NEXT FIL~ t riLE SIIM)~ARY ''' ........#LR '''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.PR #ENC P PI'UNITS MAXPI N · D~PT F 65536,9 65411, DEPT ~ 19975,6471 19937,272~ mmmmmmmmmmmmemmmmmemmmmmmmmmmmmmmmmmmmm~m~emmemme~emmmmmmme~e~emmmeeemem~e File header GRFT ,027 Scblumberoer LIST ~UB0:[]LISA.DAT; 29-~AR-9] !!:I7:0! Page 2! FILE Na~E : GRFT .097 DATE FILE TYP~ Data format specification record L~st~n~ of set ~9 tYDe 64EB object 0 1 o 66 1 2 0 66 1 3 146 79 4 ! 66 5 0 66 6 -1~ 73 4 7 INCH 65 8 !2 73 9 .II~ 65 4 1! 56 66 1 1] I 66 1 14 ,.lIN 65 4 15 73 66 16 ~, 66 1 0 ~, 66 Listino of set 0 type CHAN -------,-.--------........,,,...,..............-.................,,,.,,........ ID O~DER # LOG TYP CLS ~D NUMB ELE~ S~MP COD (N~X) S~P ~'T P~!G 9~ 000 O0 0 27 ~ ' 4 68 0205800000 End Of set . ~ . Data record tV~e 0 DEPT 7858428 ,lIN 65486,g WT 19960,4071:2 TOD ]41616348 ET!~ 150.3293 SGP. 5341.439 PTE~ 4. PHUM 3. PTHO 5. GR 105,t · Data record tvve 0 DEPT 7~52428 .lIN 65~36.9 F? 19945,16712 M · TOD 341~16408 E?IM 300.3278 SGP 4810.341 PONE 9 Data recor~ type 0 DEPT 7R46428 .liN 65386.9 ~T 19929.9~7~2 ~ ..;........... .... . ......... ........ ........ File trailer GRFT .027 ** FILE TRAILRR ** FILE.NAME ~ GRFT .027 SERVICE NA~E : bOG VERSION # ~ 32.4 DATE t 90/10/28 ~AX. R~C.: 'LEN : ~Ig2 WILE TYPE " . : PR ~EXT FiLE : 0 ~0 1646 DEPT .1l~ 7 ~ DEPT ~ 65536 9 65372,4 D~PT ~ ~9975~6471 19925.50752 (gnF) wile header GRFT Schlumberqer,,. ......... L.T,,_TA . NUB(); [1LTSA. ..... · DAT: 29-b~R-g] !1:17:01. . PaOe 23 F I'LIC NAM~ ,5ERV~C~ NA~E ~ LOG OAT~ m 00~10/28 ~AX. REC, WIL~ TYPE : PR PR .... V~OUS b : Data ~orm~ sueci~icat, ion Listino oE se~ 2~ type 64~8 objec~ 0 ~M~y .... ........ ....... 0 66 3 146 79 2 4 1 66 1 5 o 66 6 -12 73 4 7 TNCH 65 4 8 12 73 9 .lI~ 65 11 56 56 13 I 66 14 ,:lin 65 4 15 73 66 1, 16 1 66 0 t 66 ! ~nd of set List!nc of set 0 type C)(AN .-...... .... ............ ..... ................,-,......,....................... ,~, o~Z~~ ~..~.o~, 'r..~ c,,~ ~o.~ ~.,~ ~,~ ~ co~ (,.~×~ TOD ~RFT G 97 000 00 0 28 ! ! 4 ETI~ ORFT $ 97 6]6 21 0 28 1 1 4 S~P ~rW PSIG 97 000 00 0 28 1 ! 4 P~NF ~RFT 97 000 00 0 28 1 I 2 PTE~ C~FT 97 000 O0 0 2~ 1 I 2 PH!3~ gRFT 97 000 00 0 28 1 { 2 PT~O GRFT 97 000 O0 0 28 1 1 2 ~ CRFT GAP! 97 3!0 01 0 28 ! 1 2 73 0200800000 68 000OR00000 0205800000 49 0205800000 49 0205800000 49 0205800000 49 0205800000 49 0400800000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ~nd of set Oata record type 0 D~;PT 7864428 .lin 65536.9 FT 19975,647!2 TOD 34161676~ FTI~ 0.327 SGP 5342.340 Pm~E ~. PT~N 4. PHUM 3. PTHO 5. GR 88,38 SchlUZberoer LTS? ~UBO:[]L!SA,DAT; 29-){AR-93 11:17:01 Page 24 , , · . TO~ 341616912 ETY~ 150.3283 SGo~ 4656,628 PC{~E 6. PT~ 5, PHU~ 6, PTHO 4, G~ 102,5 · record true 0 DEPT 7852428 '.lI~ 65436.9 ~T 19945,16712 , 341617062 ETIM 300,3266 SOP, 5330,606 PO~E O, . ..... ~THO 5. GR 95,5 VERSION # : 32.4 ~TE~ : 90/10/~8 FILE TYPE : ~k ~E~T FtL~ : FILE SUmmArY 25 25 0 ~ 1155 D~PT ,lin 78644~8 7850580 DEPT F 65536.9 65421.5 D~PT ~ ~9975.647! 19940,4732 Wile header GR~T .029 ** FII,E HEADER FILE Na~ : SERVICE NAME : VERSION # : DATE ~ UAX. REC. LEN.: FILE TYPE : PREVIOUS FILE : GRFT .0~9 LOG 32.4 90/10/~8 PR Schlumberger LIST MUB0.,t3L!$A.D~T; ~9-MAR-93 !!.:17:0t~ Page 25 Data format specification record L~stino of set ~3 type 64EB object 0 E~TRY 'V~t,U~ ~EPCOD~ $!Z~ i 0 66 2 0 66 4 ! 66 5 0 66 ! 6 -i2 73 7 INC~ 65 4 9 .lin 65 4 1~ 56 66 ~3 I 66 ~ ,lIN 65 4 ~5 73 66 ~6 ! 66 t 0 ~ 66 ~nd of s~t List]no of set 0 ty~,e CHAN · ID OR ~,R ~ LOG TYP CLS MOD NUMB ELMM SAMP COD (HEX) ?mD CRFT $ 97 000 '00 O 29 ~ I 4 ETI~ GRFT S 97 ~6 2~ 0 29 ~, I 4 $~ ~RFT P$iG 97 000 00 0 29 1 ! 4 PON~ GRFT 97 000 00 0 29 ! 1 2 PTEN GRFT 97 000 00 0 29 1 I 2 PHU~ GRFT 97 000 O0 0 29 1 1 2 PTHO ~RFT 97 000 00 0 29 1 ~ 2 GD ~RFT GAP/ 97 310 01 0 29 ! I 2 73 0200800000 68 0OOO8OOO00 68 0205800000 49 0205800000 49 0~05800000 49 0~05800000 49 0~05800090 49 0400800000 End o~ set Data record tYDe 0 DEPT 7864428 .lIN 65536.9 FT 19975,647~2 M TOD 34~6~7].q5 ETTM 0.328 SGP 5354.01~ PONE 4. PTKN 5. PMUN 3. PTHO 5, GR 85.81. IIImmII~ m#me~m~i~mmmmmmmmmmmm,mmmmIm~mmImimmmllmmmmmm mm m ~m ~ mmmmmmmm TOD 34]617345 gTI~ 150,3282 8GP 5346.g7~ PONE 7. PT~N 4, pH{JN 3. PTHO 5, GR 65,56 [~at:a record type 0 DEPT 7852428 .lIN 65436,9 FT 19945,16712 TOD 34~.617495 ETIM 300,32~7 gGP 5340,95 ' F~le tra~ler GRFT .02q **~ FILE TRAILER ** FILE ~ERVICE VERSION # ~ 3~,4 FILE TYPE : ~R '#LR #PR ~E'NC ~r~R #F~ PI PI_UNITS MAXPI ~INPT ~ 940 ~ ~06 DEPT .~!N 7486 42B 785116~ DEPT ~ 19 6471 19.. 96672 File header GRFT .030 ** FILE MMADER ** FILE N~ME : GRFT .o30 SERVICE wA~E : LOG VERSION # ~ ~2 4 DATE ' ~AX RE~ LEN.: Data format specification record bistina of set 25 type.64E F. NTPY VAt, U~ ~EPCO[i)~ SI 0 66 ~ 0 66 1 146 79 ~ ~ 66 1 0 66 ~ -12 73 4 ~NCH 65 4 12 73 4 .1I~ 65 4 56 66 I object 0 Schlumberger LIST ~US0:[3LI~A DAT 14 . ,1 IN 65 4 15 73 66 0 ! ,66 ~nd of set' 11:17:01 Page Listln~ of set, o tyue CHAN ~a~ SE~V UNIT SK~VICE API API AP1 APl FIL~ N!.)~¢ NI, I~B SIZ~ REP PROCESS ID ~RDER ~ BOG TYP C5S ~OD NUmB ELE~ SA~P COD mmmmmmmm~mmmm~mmmmmmmmmmmmmmmmmmm~mmmmmmm~mmmmmmmmmmmm~mmmmmm.mm~m~Nm~MMmm~. ,, , TOD ~RWT S 97 000 O0 0 30 !, ~ 4 73 0200~00000 ET!~ GRFT $ g7 636 21 0 30 ~ I 4 S~P GRFT PSIG 97 000 00 0 30 I 1 4 PON~ GRFT 97 000 00 0 30 1 1 2 PTEN GRFT 97 000 00 0 30 1 ~. 2 P~UN GRFT 97 000 O0 O 30 ! 1 2 PTHO CRFT 97 000 O0 0 30 1 I ~ GR ~RFT GAP! 97 3!.0 01 0 30 I I 2 6B 0000~00000 0205~00000 49 0205800000 0~05800000 4 0~05800000 0205800000 4 0400800000 End of set TDD 341617627 ETIM 0,327 SGP 5341.252 PONE 1 PTEN 4. PH{I~ 3. PTHO 5. GR 4~,44 Data record type 0 DEPT.T85~428 ,lIN 65486.9 FT 19960,40712 ~ TOD 341617777 ETI~ 150.3273 SGP -3 404037 PO~E 3 PTEN O. PHt]N 0. PT~O O, G~ 65,06 Data recor~ ty~e 0 DEPT 7852428 .lIN 65436.9 ?T.Igg45,{6712 mMmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmm~mmmmmmm~mmmmmmmmm~m~mmm~m~mmm~ TOD 345_617927 ETI~ 300.3287 ~GP '2.549807 PONE 2. PTEN O, PUUN O, PTHO O, GR 53,94 rile trailer GnrT .030 chlumberger LIST SUB0., []bISA.DIIT; 29-MAR-93 l! ~17:01 Paq..e 28 ** FILE TRAILER F!L~ NA~E : G~FT .030 SERVICE ~A~E ~ DATE : ~AX. REC. LEM.~ 8192 w!~E TYPE : PR ME×T F!L~ #%,R #PD ~ENC #DR #¥M PI PI.UNITS ~? ~7 0 ~) I~43 DEPT .lin 7~64{2~ 7~495~t DEPT F 65536 9 65412.7 DEPT ~ 19975:6.47! 199)7,79096 F~],e header GRFT ,03~ ** FII~E HEADER ** ~ILE N~ME : G~FT SERVICE NA~E : LOG VERSION # : ~ 4 DATE ~ 90~0/~8 ~REVIOUS FILE ~ Data format L~sttn~ o ENTRY V ~ o ~ 0 3 ~ 4 ~ 5 0 ? T 9 . . mmmmmmmmm ~nd of se .031 f s~t 27 type 64EB object ~LU~ ~EDCODE sTg~ 66 66 66 66 1 NCH 65 4 lin 65 6 66 66 lin 65 4 3 66 66 1 66 mmmmmmmmmmmmmmmmmmmmmmm t, Schlumberger LIST MUB0;[]Ii!$A.DATI 2g-MAR-g3 1.~.:17:01 Page 2g · , L{st~no ~f set 0 type C~ NA~ ~RV UNIT SEPV?C'~ aPI aPI API AP~ FILE M!t~B ~L)~ $1Z~ ~P P~OC~$S ORDER ~ LOG TYP CLS blOD NUMB E. LE~ S~MP COD S~P ~RFT PSIG 9.7 000 00 0 31 ~ ~ 4 68 0~05~00000 pONE ~FT 97 000 O0 O 31 ~ 1 2 49 0~05800000 PTE~ ~RFT 97 000 00 0 31 1 ! ~ 49 0205800000 pMiUM GRFT~ 97 000 O0 0 31 ~ 1 49 0~05800000 PTHO ~gFT 97 000 00 0 3! I ~. ~ 49 0~05800000 G~'. ~RFT GAP! 97 {I0 01 0 3I I 2 49 0400800000 ~nd of set Qata record tvpe 0 DEPT 78644~8 ,lin 65536.9 FT 19975,647~2 ~ ..,,,.,............................-.....--.-.-----.-..-------------- Data record type 0 DEPT 785842~ .~IN65486,9 FT ~9960,407!2 ~ TO~ 3416!~27~ ~TIM i50.]303 BGP 4981.755 pONE l~, PTEN 8, " PHUM 9. PTHO 4, GR 5 22 nata recor~ type 0 D~PT 7852428 .lin 6543~.g FT 19945,!671~ · OD 34~618428 ETIM 300.3209 SGP 5342.876 PT~N 4, PHUN 3, PTHO 5. G~ 58,97 File tra~l~r GPrT .03~ ** FILE T"AIbER ** FILE NAME : GRFT .031 ~AT~ ~ 90/10/28 ~AX. EEC. LEN.: B~92 wIE, E TYP~ ~ P~ NE~T FILE : Schlumherqer LIST MUB0:[]hlSA.DA?; 29-~A~-9] 1i117:0l Paqe 30 wILE SUMMA, RY mmmmmmmmmmmm~m~mm~m~mmmmm.mmmmmm~m~m~mm~mm~mmmm~m'~m~m~mmmm~mmm~mmMmmmm, ,. ~EMC #DR #F~ PI PI_{I~TS NAXPl ~Y~PI DEPT F 65536 9 654]6 9 DEPT ~ 19975:6471 19945:16712 ,n (E File header GRWT ** FILE MEADER ** FILE NAME ~ GR~T ,032 SERVICE NA~E : LOG DAT~ { 90/10/28 ~aX. REC. LE~.: 8192 FILE TYPM~ : PR PREVIOUS FILE Data format speCial, cat'on record b~stin~ o~ set 29 tYDe 6.4EB ObjeCt 0 E~TPY VALUE ~, 0 66 1 2 0 66 3 146 79 5 0 66 6 -1~ 73 4 7 TNCH 65 4 ~ 12 73 4 9 .lin 65 4 !! 56 66 1 13 I 66 1 14 .1I~ 65 4 !5 73 66 16 ! 66 1 O 1 66 1 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm En~ ~ bistlnq o~ set o type CH~N TD ORDER # LOG TYP CbS MOD NUMB ELEM SA~P COD CHEX) TmD ~RFT S 97 000 O0 n 3 1 ~. 2 4 73 0~00800000 ETI~ GRFT S 97 636 21 0 32 1 1 4 68 0000800000 SOP ~RFT PSIG 97 000 O0 0 39 ! ! 4 68 0~05~00~00 PONE GRWT 97 000 00 0 39 ! ! ~ 49 0~05800000 PTEN GgFT 97 000 00 0 32 l ! 2 49 0905800000 DH[;~ CRFT 97 000 00 0 3~ ! 1 2 49 0~05800000 29-~AR-g3 1~:17~01 Page ~?t,!O ~RF~ 97 o00 00 0 ~2 I. 1 2 4g 0~05800000 GA I 97 310 O1 O 32 1 1 2 ~g 0400~00000 ~:nd of set Data record type 0 DEPT 7~64428 .1~N 6553~ ~ ~T 19975.64712 ]41618564 ETI~ 0.329 SGP,. 5352.172 Date record tvoe 0 DF, PT 7858428 .llN 65486.9 FT i9960.40712 ~ ............. ..... .............................,,.... .... ;.-----.....- Data record type 0 DE~T 78464~8 .lin 6518~'.9 FT 1,~929.9~7~ ...... ,,,,..................................., ...... ................ TOD. 3 .90t3 ETI~. , . 450.3307 SGP, .... 5026.8, PON~ 6. PTEN 2. PHU~ Od PTHO 5. GR 46,03 ecor~ type 0 DEPT 7~404}8 .~IN,65336,9 FT 199!4.6R7t2 ~ m~mmmmmmmmmm~m~mm~m~mmmmmmmmmmi{~{m~m~m~m{mm~mmm~{~m~~m{{ 3.... ....... . '...o 5;" C~ 5~.38 FILE NAME ~ GRFT .032 VEPSION # : 3~.4 DATE ~ 90/~.0/28 ~AX, REC. LEN.~ 8192 FIbE TYPE : PR WEXT FILM ~ File trailer GRFT .03~ ;r SchlumberGer LIST ~IUBO:[II.,ISA.DAT~ 2o-~4gR-93 1.!:17:01 Page 32 DEPT F 65~36 '9 65317 DEPT ~ 19. 75:6~71 ~.9908:~9592 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmm~mmmmmmmmmmm. ' , (EOF) File header GRFT .033 ** FILE HEADER Fl'bE NAME : GRFT .033 SERVICE NA~E : LOG VE~$IO~ # ~ 32,4 DATE : 90/~.0/2~ "AX,~MC& bEN.: 8!92 rILE TYP.,~ : PR PRFVI'OUS F%bE : Data format smec~fieation recoro L~.st~no of set 3l type 64~B object 0 , 66 3 146 79 2 ~ ! 66 ! 5 0 66 6 -12 73 4 7 TNCH 65 8 !2 73 4 9 .1I~ 65 4 11 56 66 1 13 I 66 ~4 .lI~ 65 4 t5 73 66 16 ! 66 0 ! 66 End of set tistlno of set 0 tyoe CHAN """"'"' ...... '"" ....... ' ......... ' ........ '"'T'"' ...... ............ TOD CP~T S 97 000 O0 0 33 1 4 020OPO0000 ETIg GRFT S 97 636 2~ 0 33 1 ~ 4 68 0000800000 S~P GRFT PSIG 97 000 00 0 33 1 ! 4 6g 0~O5800000 PON~ ~PFT 97 000 00 0 33 ! 1 2 49 0205800000 PTE~ GRFT q7 000 O0 0 33 I 1 2 49 0~05800000 PHUN GRFT 97 000 OO 0 33 ! ~ 2 49 0205800000 Schlumberoer bIa',, Pg-MAR-93 !1~17~01 Pa~e 33 'T ~ ., P"HO ~RFT 97 000 00 0 3 l, t 2 49 0205800000 GR . .~RFT. GAP! 97 31,0.01 0 3 1 ! :2 49 04OO~00000 R~d ~ ~et Data record type 0 DEPT 7864428 .lIN 65536.9' FT 19975.647!,2 T~B 341~1q2~2 ETIM 0.32~ SGP 5364.260 P~N~ 4 Data record type o DEPT 7R58428 .lin '65486.9 FT 19960.40712 M Ta~ 34161,9432 ET!Mt50 32a3 SGP- 5357'335 pOS . . · 7. PT ....... i~! 5. . File trailer GRFT .033 · ~ FILE T~AILER FILE NAPE SERVICE NAPE { LOG D~TE ~ 90}10/28 ~'AX. REC. LEN.: 9192 ~II,~ TYPE ~EXT FILE PII,,,E S{.!~MARY #~NC ~'DR #'F~ ~ PI: PT--UNITS ~AXPI ~l~PI mm~mmmmmmm~mmmmmmm~mmmmmmmmmmmmmmmmm~mm~mmmmmmmmmm~mmmmmmmmmmmmm~mm~m~mmm, 16 !6 0 1~ 663 OEPT ,lin 7864428 7856484 DEPT F 6553i. 9 65470 $' DEPT ~ 1997~:6471 1,9055:46936 File header GRFT ,034 ** FI!,E HEADE~ ** VERSION # ~ 32.4 DATE .aX. REC. LEN.: FILE TYPE ~ PR PREVIOII~ FYBE ,, ,.'.hlum. herqer LIST ~[tBO'~[]L!SA.DAT; 29-MAR-93 1.1:'17:01 Page: 34 Data format specification record L~s't!n~ o~ set 0 type CHA-~'.' N '~a~Y SERV UNIT SERVtCM AP! APl APi APl FIhE NU~F NUmB SIZE REP PROCg$8 ID O~DE ~ LOG TYP CbS MOD NUmB ELEM SAMP COD (HEX) ~. ~"rT~ 9~ ~ ~ o ~4 ~ ~ ~ ~8 oooo~o°°°° 0 0000 SGP GRFT PSI¢ 97 000 O0 0 34 I ! 4 68 0~05800000 PONE ~R~T' 97 000 O0 0 34 ~ ~ ~ 49 0205800000 PTE. ~RFT 97 000 O0 0 34 ! ! 2 49 0205800000 vHU~ ~RFT 97 000 O0 0 34 I ! ~ 49 0205800000 mmmmmmm~mmmmmmmmmmm~mmm~mmmm~mmmmmmmmmmmmmmm~mmm~mmmmmmmmm~mmmmmm~mm#mmm~mmmm End Of set Data record type 0 DEPT 7864428 .lin 65536.9 FT 19975,647X2 M m~m~m~mm~m~mm~m~m~m~mmmm~m~m~m~mm~m~mm~m~mm~~m~~~ TOD 3416195~9 ETTM 0,3~7 SGP 5356,215 PONF 6. PTFN 5. PHUN 3. PTgO 5. GR 36,84 Data rAcord tvoe 0 DEPT 7858428 .l!N 65486.9 FT 19960,40712 m~mm~m~m~m~m~~m~m~m~m~m~~mmmm~m~m~mm~m~mm~m~mm~ T~D 341619679 ETIM 150.32~4 ~GP. 5354.932 PON~ 4. PTEN 5. PHUN 3. PTHO 5. GR ~8,94 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm'mmmm File trailer GmF? .034 Schlumberger LIST PUBO:[]!,!SA,DAT: 2g-~A.R-g3 11:17:0! Page 35 DATE ~X. REC, LEN,: wEXT FILE . D PT 'lI 7 57936~ 7864428 14 14 0 I0 42 E :'~ ! 8 ~PT r 65536,9 65482,~ .PT M 19975,6471 19959, 5744 rile header GRFT °035 *~ FILE HEADE~ ** rILE NA~ ~ GRFT .035 SERVICE ~A~E : LOG D~TE ~ ~0~10/28 "AX. REC. LEN..* 8192 FILE TYPE ~ PR OREVIOUS FILE ~ Data format specification record Listing of set 35 t~pe 64EB object 0 ENTRY VALUE REPCOD~ STZ~ I 0 66 2 0 66 3 146 79 2 4 I 66 1 5 0 66 6 -12 73 4 7 INCH 65 R 12 7t 4 9 .!IN 65 4 11 56 66 1 !3 1 66 1! .lin 65 4 15 73 66 16 ! 66 I 0 ~ 66 ~nd of set Schlumberger LIST MUB0:[]LIS~.DAT; 29-~AR-03 1)~:17:01 Page 36 Listln~ of set 0 type CHAN A~E ~ V UNI. SER I ~PI API API FILE ~U~P~ ~ ~B $!g~ ~EP P~OCESS TOD C~FT ~ 97 000 00 0 35 1 ! 4 ETI~ ~RF? $ 97 636 21 0 35 ~ i. 4 S~P ~RWT PSlG 97 000 00 0 35 t I 4 PON~ ~FT 97 000 00 0 35 ! ! 2 PTEN GRFT 97 000 00 0 35 ~ I 2 P~UN ~RFT 97 000 O0 0 35 I I ~ pTPO C~FT 97 000 00 0 35 1 1 ~ G~ GRFT GAP! 97 310 O! 0 35 1 ~ 2 73 O200800000 68 0000800000 0205~00000 49 0205800000 49 0~05800000 49 0~05800000 49 0205200000 49 0400200000 ~nd of set Data record type 0 DEPT 7864428 .1I~ 65536.9 FT 19975,6471.2 ~ TOD 34~.61974~ ETI~ 0.336 SGm 5357.256 pDNE 7. PTEN 5. PHU~ 3, PTMO 5. GR 39,28 Data record type 0 DEPT 785~428 .!IN 65486,9 FT 19960,4071~ TOD 341.6198q~ g?I'~ 150,3363 SGP 5356,659 POg~ 6, PTEN 5. PHUN 3. PTHO 5. GR 35,44 Patarecord tYPe 0 DEPT 7852428 ,tIN 6543A.9 FT ~g945,16712 M TOD 34~620042 KTI~ 300.3357 SGP 5355.45" PON~i 6. PT~N 5. PHUN 3. PTHO 5. GR 29,2~ ~ile 'tre~.ler G~F? .0~ ** FILE TRAILER FILE NAME = GRFT ,035 SERVICE NAME ) tO~ VERSION # : ~2,4 D~TE ~ 90/10/28 uAX. REC, LEN.: 8192 wILE TYP~ ~EXT FILE Schlumberger L~ST ~UBO:[]LISA.DAT~ 29-~',~AR,,9] I1;17;0! Paqe ~7 ?ile header GRFT .036 ~* FILE HEADER ~ILE MA~E ~ GRFT ,036 SERVICM NAME ~ LOG VERSION ~ ~ )2,4 DATE = 90/10/~8 MAX, ~C, L.EN,: 8192 FILE TYPE ~ PR PREVIOUS FILE g Data format specification record b~stino of set 37 tyoe 64ES object ~MTRY VA[,UE REPCODE ! 0 66 2 0 66 3 146 79 4 ! 66 5 0 66 6 -1~ 7~ 4 7 INCH 65 4 8 12 73 4 o .IIM 65 4 lJ. 56 66 13 1 66 14 .llq 65 4 15 73 66 16 ! 66 0 1 66 of set bistino of set 0 type CHAN mmmmmmmmmmm m ma ~,~ ~,~ '~,;; ,,,,,,"'""------------'---------- .. ~ ~~ . ~o~ ~ c~s ~ ~u~ E~ s~_~ coo TOD CEFT S 97 000 O0 0 36 1 1 4 73 0200800000 ETI" GRFT S 97 636 21 0 36 1 ! 4 68 0000800000 SGP GRFT PStG 97 000 00 0 36 1 ! 4 68 0905800000 PCNF GRFT 97 000 00 0 36 I ~ ~ 49 0~05800000 PTEN GEFT 97 000 0O 0 36 t ! 9 49 0~05800000 DHUN ~RFT 97 000 00 0 36 1 1 2 49 0205800000 $chlumberoer LIST ~UB0:[]L!SA,DA?; 29-MAR-93 1!~1710! Page 38 PTH0 GRFT 97 000 O0 0 36 I 1 2 49 0~05800000 G~ GRFT GAPI 97 3!0 Ol 0 36 i, 1 2 49 0400800000 · Data record type 0 DEPT 7864428 .lin 65536,9 FT 19975,64712 TSD 341620113 ETI~ 0.329 SGP 5363.964 PONE ~ PTEN 6, PHUN 3. PTHO 5. G~ .53 Data record tvpe 0 DEPT 7858428 .!IN 65486,9 FT 19960.40712 TOD 341620263 ETI~ 150.3292 SGP~ 5360,035 POME O. PTEM 6. PHON 3, PTHO 5. GR 78,19 File, trailer GRFT ,036 ** FILE T~A!bER ** FILE NAME : GRFT ,036 SERVICE NA~E ~ bOG VERSIO~D~TE # :: 9032/I0/28 ~AX, REC, bEN: 81° riLE, ~ TYP~ '~ PR ~EXT FILE rILE SIIMM.~RY #LR ~PP #ENC #DR #FM PI PI,UNITS MAXPI ~INPI mmmm~mmmm~m~mmmm~mmmmm~mmm~m~m~m~m·mmm~m~m~mmmmmmmm~mmmmmm~mm~'~~ 15 15 0 J. 1 59! DEPT ,lin 7864428 7857348 DFPT F 65536.9 65477,9 ~EP? M 19975,6471 1'9957.66392 ~m~~m.~mmm~m~m~m~~~m~m~m~m~mm~m~~m~mm~m~m~m~m~m rile header GRFT .037 ** FILE HFADEn ** FILE NAME : GRFT ,037 SERVICE ~A~E : LOG VERSION # ~ 32,4 ~TE ~ 90/10/28 ~AX, REC. LEN.: rILE TYPE : PR PREVIOUS FILE Schlumberger LTST MUBO:[]L!$A,DAT; 29-~AR-93 t1:17:01 Page 39 L~stino of set ]g tYPe 64EB object 0 . 2 0 66 i46 79 5 0 66 6 -12 73 4 7 rNCH 65 8 ~2 73 4 9 ~ 65 13 ~ 66 14 .1I~ 65 4 l~ 73 66 1 16 I 66 0 ~ 66 End of set b~sttno o~ set 0 type CH.~,~ ID ORDER ~ LOG TYP C!,S ~mD NUgB ELaM SAMP COD (HEX) TOD gRFT $ 97 000 00 0 37 I 1 4 ETI~ ~RFT S 97 636 2! 0 37 1 ! 4 SOp GRFT P$IO 97 000 00 0 37 t ! 4 P~NE GRFT 97 000 O0 0 37 ! ! 2 PTE~ CRFT 97 000 00 0 37 I ! 2 PHUN GRFT 97 00O 00 0 37 ! 1 2 PTHO ~R~T 97 000 O0 0 37 ~, ! 2 ~ ~FT GAP! 97 310 O1 0 37 1 1 2 73 0~00800000 68 000O8O00O0 68 0205800000 49 0205800000 49 0205800000 49 0205800000 49 0205800000 49 0400800000 m~mm~#m~m~m~mm~mmmmmmmmmmmmmmmmmmmm#mmmmmm~mmmmmmmmmmm~mmmmmmmmmmmmmMmmmmmmmm Rnd o~ ~et Data record type 0 DEPT 7864428 .lin 65536.9 FT 19975.64712 M T0''~''~'~''~'''~''';~''''''';~;''~i;~~6 04.. ,M ..... pO~''['~''~''''''''. PTEN 2. PHUN 3. PTHO 5. G~ l~0 I Data record tvoe 0 OEP1/ 7858428 .lin 65486.9 FT 19960.40712 mmmmmmmmmmmmmmmmmmmmmm mmmmm m m mw PT~N O, PHiIN 0. PTHO O, GR 111.5 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm Schlumberger LIST ~UBO -' [] LISA . ... ATiD 29-MAR-.g] 11;I7:01 Page 40 Data record type 0 DEPT 7852428 .lIN 65436.9 FT i9945.16712 g TOB 34~07~7 ETI~ 30 ~ 4RaT.Off5 ~0~ · . ~ File trailer G~FT ,037 **' FILE TRAILER VERSION # : 32,4 DATE ! 90/~0/28 gAX. REC. LEN.: 8192 ~ILE TYPE : PR ~E%T FXLE ~):LE SUMMARY 2R ~8 0 24 1313 DFPT ~ ~ ~ ~64428 4 84 mllmmmlmmlmmmmmlmmmmmlmlmlmmlmlllmlmmmmmm, mmm mmmllmmlmmmm m m mmlllml (~OF_~ File header ** FILE HEADER ** FILE NAME ~ GRFT °038 SERVICE NA~E : LOG vERSIO~ # : 32.4 DATE ~ 90/10/28 ~AX REC LEw PREVIOUS FILE Data format ENTRY V snecif~ication record ~ Se~ 41 type 64~:B object ALU~ REPCDDE SIZF ~ o . 66 2 0 66 3 146 79 2 4 1 66 1 5 0 66 6 -12 73 4 7 TNC~ 65 8 !2 73 4 9 .1I~ 65 4 I! 56 66 Schlumberger 5XST ~U~O:[]LISA.DAT; 11:17:01 Paqe 41, 13 I 66 I ~ . I IN 65 4 15 73 66 16 I 66 0 ~ 66 o~ ~et ~st~,n~ of set 0 type CHA, N .N'A~ S~RV U~,t!T :SE~VTCE API AP! .API ~PI F![~ ~U~B NI,,t~ SIZ~ R~P PROCESS ORDER ~ bOG.TYP Ct, S ~OD NUMB ELE~!. 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GR 163. rile trailer GRFT .03~ Schlumberger LIS? ~!I.8o:[]L!$A,DAT: 29-~!AR-93 11,'I.?:01 Page 42' VERSION ~ ~ ~2,4 DAT~ : 90/10/28 ~AX : REC. bEN,~ 8192 ~I't,~ TYPE ~ P~ ~EXT FILE : FILE SUMMARY #LR #pR #ENC #DR ~FM PI PI.UNITS MAXPI MINP! 24 24 0 20 1079 DEPT ,lin 7864428 7851492 9EPT F 655~6.9 654~9,! , DEPT ~ 19975.6471 19942,78968 File' header GRFT .039 ~ILM:NA~ : GRFT ,0~9 SE:~VICE NAME ~ bOG VERSION # : ~.4 DATE ~ 90/10/28 ~Ibg TYPE ~ PR PREVIOUS FIbE : Data ~ormat svecificat~.om recorO b]stln- of set 43 type 64EB object ENTRY VALIIE ~EPCODE SIZE 1 0 66 2 0 66 3 ~46 79 2 4 ~ 66 1 5 0 66 6 -12 7] 4 7 INCH 65 4 ~ ~2 73 4 9 .lI~ 65 ~! 56 66 ~3 ~ 66 1~- .lin 65 4 15 73 66 1 16 ! 66 ! 0 ! 66 1 ~nd of set SChlumberger LIST NUBO:[]LT'$AoDAT; 29-MAR-93 1!{17:01 Pa~e 4) L~stino of set 0 type CHAN ~"'""~"'3~ ..... ""'" ..... "'""2'"~C""~'""""'""'"'"'"'~'-' AME SER ..IT SERVICE APl APl AP1 PI E NU. B NUMB SIZE REP PROCE ID ORDER # LOG TYP C~S MOD ~I.}~BN.. E[,E~ SAND COD. CHEX ~nd of set Data record type 0 P~,,~l IMp 7864428 . lin 65536.9 FT. 19975.647{2 M ""'"'"'""'"';'"'"'"'"'"'' T:[",'," ~.~. . ..~: ,. ..... ~.,~o ~. ~~ ~ Data T~cord tyD~ 0 DEPT 7858428 .lin 65486.9 FT !9960,40712 ~ · ~3" 22 '"'""'"'"'"'"'""'""'""' '"",'",'"'"'"" 420 ETIM 150.3284 SGP, 5330,32, P NE ,. ~a~N 3, . PHUN 3o , , PTHO 5, GR 77,94 File trailer G.:,FT 039 ** FILE TRAISER FILE NAME SERVICE NA~E ~ LOC, VERSI~ # : ~2.4 DATE : 90/!0/28 ~AX. REC. LEN,: 8X92 FILE TYPE t PR ~]EXT F]L~ '' ........ ''''''''' '9975.6471 '9957.6639~ File header ~RWT .040 $chlumherqer LIST MUBO:[]LISA.DAT; 29-MAR-93 ~i:17:0! Paqe 44 Dat~ ~ormet sPe¢~f~cetiom re~ord t.~,~stinq oi set 45 type 64MB object O. ENTRY ~AI~U~ ~EPCODE . 66 3 146 79 2 4 1 66 5 0 66 ! 6 -12 73 4 7 TNCH 65 4 8 12 7] 4 9 .1I~ 65 4 ii 56 66 13 I 66 14 ..liN 65 4 15 73 66 !6 ! 66 0 ! 66 1 En~ of set 5istlnq o~ set 0 type CHAN TD ORDER ~ LOG TYP CbS ~OD NUMB ELE~ SA~P COD (HEX) ooo ...... oo , . o oo ooooo .... ETI~ GRFT S 97 636 21 0 40 I 1 4 68 0000800000 SGP GRFT PSIG ~7 000 O0 0 40 ! 1 4 68 0205800000 PONE ~RFT 97 000 O0 0 40 i 1 2 49 0205800000 PTEw ~RMT 97 000 O0 0 40 ! ~ ~ 49 0~05800000 PWUN ~FT 97 000 O0 0 40 ~ ~ 2 49 0~05800000 PTMO CRFT 97 0~0 00 0 40 ! ! ~ 49 0205800000 d~ ~RFT G~P~ 97 310 O1 0 40 ! 1 2 49 0400800000 End o~ set .Da. ta [::ar.d. type 0 .~P'r 7864428 .llN..6.5.5.36...9..F.T.!.9.g/.5,.6..47.12 TOD 3416214~5 ETTM 0.327 SGP. 5329.295 p~NF~ 9. PTEN 2. PH!JN 3. PTNO 5. GR 85,81 SchlumberGer LIST ~UBO:[ILISA.DAT; 29-~,~AR-9,] 11:17:Oi Paqe 45 im.l~., m m~.se ~. ~ m..~. m.........~. ~. ~.~ ~ ~--~.~. ~..-- ~--~ ~------------~---'--~ Data recer~ tyne 0 DEPT 78584~8 .lin 65486,9 FT 19960.40712 TOD 34162!636 ET!H 150,3273 SG~ 4815,8~ pON~ 5. PTEN 1. PHiIN 8. PT[~O 4. G~ 95,19 mmmmmm.m~mmmmmmmmmmmmmmm~mm...mm.~m..mmmm,~.mmmmmN~m.m.mmmmmmmm'm. Data record tvDe 0 DEPT 7852428 .ilN 654]6.9 FT 19945,167!2 ~ · *nB 341621785 ETIg 300.3~76 Sq~ 5329.377 PON~ 9 PTEN 2. P}~U~ 3. P~. O 5. 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PTHG 5, GR 58,06 Data record tV TOD 34162~634 PT~N De 0 OgP.~, 7858428 ,lin 65486,9 FT 19960,40712 : ETiM i50.3~R3 SGP, !8.!8964 PONE 8. PHUN 0. PTHO O, GR 82,88 mmm~mm~mmmmmmmm~m:m~mmmmmmmm~M~m~mmmmm~mm~m~mmm~m File traJler G.~T 04~ ** FILE TPAILER ** WlLENAM~ SERVICE FAME ~ LOG VE~SIO~ ~ : 32,4 DATE : FILE TYPE : PR N~XT FIL~ ,042 0/28 FILE SUMMARY ~m~~m~~m~m~mm~mm~3.~m~~mm~m~m~m~m~m~m~~m~m~m~m~m~ #LR #PW #FNC # R #FM PI PI_IINITS MAXP! MINP! ........... ........... .-.;-.......; .... ,.,,.---.,,-.-.-.-.............-... 15 15 0 ! 60 ~ . ,1... 7864428 7857204 D~PT F 65~]6.9 65476,7 DEPT ~ 19975.6471 19957,29816 (EnF) rile header GRFI' .043 -gchlu~ber~er LIST NIUBO:[]LISA,DAT; 29-MAR-9] !1:!7:01 PaOe' 40 ~AX. REC, LEN.~ ~192 FILE TYP~ ~ PR ~V!OU$ FIbE Table type CONS L~.stln~ Of set 7 type OadU.a~ ST~T P[iN! 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Paqe 5] Table type COWS Llstlno of set. 8 type CONS m~mmm~m~mmmm~mmmm~mmmmmmm ~ o~ ~et Data for~at specie,cat'on record Listlng of set 5~ tvpe 64~B object 0 ENTRY VAL[IE REPCDDE SIZE 1 0 66 1 ~ 0 66 3 374 79 5 1 66 7 TNCH 65 4 8 60 73 9 .~I~ 65 4 ~ ~! 66 [3 1 66 [4 .~I~ 65 4 ~ 73 66 lfi !. 66 0 ! 66 ! ~nd of set !,~stlnq of set o type CHAN ~D ORDER ~ LOG ?YP CLS M~D NUmB ELEM S~MP COD (HEX) m~m~m~mm~m~m~m~m~m~m~mmmm~m~~mm~m~m~~~mm~mmmm~m~~m~ ~Ol) TOH S 31 000 O0 0 46 1 1 4 73 8200000000 ETIM TOH S 31 636 21 0 46 ~ ! 4 68 8000000000 mmm~~m~m~~m~~mm~mm~m~~m~mm~mmm~~mm~m~mm~m~mm~mmm~mmmm En~ of Schiumber~erI~IST ~:UBO:[]SISA.DAT~ 29-NAR-93 11:17:01 Page 54 Data record type 0 DKPT 1663080 T~D 341~96311, E?IM 66,4100! Data record tvue 0 DEDT 1657080 ,{~IN 13809, FT 4:2.08,9832 TOD 3415965~I ET!~ ~75.68~ Data record tV~Oe :0 DKPT !651080 ..I!N. 13759. F? 4193,743~ ~ 34!596727 ~'.~M 40~.54 Data record type O.DEPT 1645080 .II'N 13709, FT 4t78,5032 N TOD 341.596934 ETIM 688.8077 . m~mmm~m~mmmmmMmmm~mmmmmmmmmmmmmmmmmmmmmmmNNNmm~mmmmm~m~mm~mmmmmmm . R gO 0. IN 59, . Data record type 0 D~.jPT 163 8 ,1 136 FT 4163 2632 TOD 341597141 ETIM ~95.g779 Data record tvDe 0 DEPT 1633080 .1IN 1360g, FT.4t48.0232 M mmmmmmmm~ .'i mmm~Nm~mmmmmmmm~m~N~mm~m m~m~m~mmmmm~mmmmmmmm~mmmmmm~mm ~ TOD 34159734). KTIM 1096,106 Data record tvve 0 DfPT 1627080 .1I~ 13559, FT 4132,7832 M ~mmmm~m~~m~~~m~m~mmm~m~m~m~~m~~m~m~~m~ 341597541 ETIM ~95,709 mmm~~~mmm~m~m~m~mm~~m~~~m~m~mm~~mmm~ Data r,cord type 0 DEPT 162)080 .lin 1~509. F? 4'~17.5439 W OD 341597740 ETIM 1494'5~4 mssmmsmmmmmmsmmmmmmmmm#mmmmmmmmmmmmmmmmmmm~mmm~msmm#mmm~m~Nmmm~m~m ~chlumberqer LTST ~!jBO.,[]LISA.DAT; 29-MAR-9] ll~l?;O~ Paqe 55 Data record type 0 D~PT i615080 ,lin 13459. FT 4~02.3032 ~ Data record type 0 DEPT 1,60~080 ,!IN 1.3409. FT 4087.0632 T[]D'''''''''''';''''''''''''''''''''''''''''''''''3415981 E?I~4 18.,4.1 .7 ......... '''''''''''' .~'''--''--'--~..mm~m~.......m..~.m.'W..'..........~.~....~.....~..... File trailer ,046 ** FIbE T~AILER ** FILE NA~ ~ TOH ,046 SERVICE NA~E ~ PLAY VERSION ~ ~ 32 4 DATE : 90;10/28 ~AX. REC, LEN,~ 8~92 FILE TYPE : PR NEXT FIbM ~L~ #P~ ~ENC #DR ~FM PlPI'iiMiTS MAXPI MIMPT DEPT F 13859. DEPT g 42~4.2~32 4073.652 ~EOF) TAPE S[IM~ARY .... -.,.,,.....,........... ~ L #!, #PR .... -~;-. .... -;~ .;.** ..... mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm FII~S T~PFS #I.R mmmmmmmmmmmMmmmmmmmmmmmmmmmmmmmmm c~iumberger LIST MUBO:[~L!$A.D~T; 29-}~AR-9] ~:17:01 ~a~e 56 End o~ l~st.~nq MUBO:[]bISA,DA~;