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198-232
Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov September 11, 2025 David Pascal Chief Operating Officer Cook Inlet Energy, LLC. 188 W. Northern Lights Blvd. Suite 510 Anchorage, AK 99503 RE: No-Flow Verification Badami Unit B1-36 PTD 198232 Dear Mr. Pascal: On July 3, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Badami Unit B1-36. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a 30-minute flow period through the test equipment to an open top tank – repeated 1 additional time. Initial gas rates exceeded the test meter limit and fell below the maximum allowed limit of 900 scf per hour within approximately 15 minutes. The flow period after a second 1-hour shut in resulted in similar results with the gas flow rate falling below the maximum allowed limit within approximately 17 minutes. There was no oil flow rate observed during the no-flow test. Badami Unit B1-36 may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion of the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Badami Unit B1-36 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter at the Badami field office. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.09.11 13:16:30 -08'00' 2025-0703_No-Flow_Badami_B1-36_gc Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 7/03/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector Badami B1-36 Cook Inlet Energy LLC PTD 1982320; Sundry 324-343 7/03/2025: The acceptable rig-up consisted of 2-inch hardline from the well to a 2-inch hardline choke manifold skid and then a 1-inch hose to a bleed trailer. The flow meter was scf/min instead of scf/hr in the 1-inch portion of the rig-up. Flow rate results in the table are converted to scf/hr. The test procedure was two 1-hour build up periods each followed by a 30-minute bleed off period. The pressure gauges/transmitters and flowmeter had current calibrations. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 11:24 0 / 0 / 30 Shut-in for build-up period 11:39 1 / 1 / 30 11:54 2 / 2 / 30 12:09 3 / 3 / 30 12:24 3 / 4 / 30 >1500 0 Open to bleed 12:29 2 / 2 / 30 >1500 0 12:34 1 / 1 / 30 >1500 0 12:39 1 / 1 / 30 890 0 14 min 30 sec to < 900 scf/hr 12:44 1 / 1 / 30 600 0 12:49 1 / 1 / 30 480 0 12:54 1 / 1 / 30 420 0 13:00 1 / 1 / 30 Shut-in for build-up period 13:15 2 / 2 / 30 13:30 2 / 3 / 30 13:45 3 / 3 / 30 14:00 4 / 4 / 30 >1500 0 Open to bleed 14:05 3 / 3 / 30 >1500 0 14:10 2 / 2 / 30 >1500 0 14:15 1 / 1 / 30 1050 0 14:20 1/1/30 600 0 16 min 20 sec. to < 900 scf/hr 14:25 1/1/30 480 0 14:30 1/1/30 450 0 End test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: Photo 2025-0703_No-Flow_Badami_B1-36_gc Page 2 of 2 No-Flow Test – Badami B1-36 (PTD 1982320) Photos by AOGCC Inspector G. Cook 7/3/2025 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Remove KX-valve 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: Badami Field 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,546 12,204 / 12,313 Casing Collapse Structural Conductor N/A Surface 2,270 Intermediate 3,090 Production 8,510 Liner 7,500 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 2-7/8" HES PHL Pkr & HES 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: Contact Email: Contact Phone: 907-433-3820 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 Stan Porhola sporhola@glacieroil.com Production & Wells Engineer CO 402C Badami Unit B1-36 Badami Oil Pool 12,729 14,060 11,392 1,816 10,599'7" 14,060 6/28/2024 12,338'-15,440'3,102' 2-7/8" 10,565'-12,623' Pkr @ 10,063' MD/8,744' TVD - SSSV @ 4,220' MD/4,172' TVD 9 5/8"10,211' 4,518' 10,244' 11,475'-11,879' 12,403' 4-1/2" 10,149'-10,356' 12,433' Perforation Depth MD (ft): 118' 4,554' 20" 13 3/8" 80' 5,750 N/A 5,020 118' 4,505' 8,962' Size Proposed Pools: L-80 TVD Burst 10,142' 11,220 MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 365533 198-232 188 W. Northern Lights Blvd. SUITE 510, ANCHORAGE, AK 99503 50-029-22933-00-00 COOK INLET ENERGY LLC AOGCC USE ONLY 8,440 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length m n P s 1 6 5 6 t t e N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.13 14:47:31 -08'00' 324-343 By Grace Christianson at 4:29 pm, Jun 13, 2024 MGR24JUN24 SFD 6/14/2024 DSR-6/13/24 * State witnessed 3 hour of period of no-flow per AOGCC Guidance Bulletin 10-004 *&:JLC 6/24/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.25 09:26:32 -08'00'06/25/24 RBDMS JSB 062624 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 June 13th, 2024 Jessie Chmielowski Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501-3572 Subject: Sundry Request: Badami Unit B1-36, remove KX-valve and No-Flow Test API No: 50-029-22933-00-00 Dear Commissioner, Cook Inlet Energy, LLC, hereby submits an Application for Sundry Approval for Badami B1-36, PTD: 198-232, requesting permission to remove the KX-valve SSSV, perform No-Flow Test and operate the well without an SSSV. If you have any questions, please contact Stan Porhola at (907) 433-3820. Sincerely, Stan Porhola Production and Wells Engineer Cook Inlet Energy, LLC (a Glacier Oil & Gas Corp. owned company) 188 W. Northern Lights Blvd, Suite 510 Anchorage, AK 99503 Attachments 1. B1-36: 10-403 2. B1-36: Remove KX-valve and No-Flow Test Program 3. B1-36: Current Wellbore Diagram 4. B1-36: Proposed Wellbore Diagram Stan Porhola Digitally signed by Stan Porhola DN: cn=Stan Porhola, o, ou=Glacier Oil & Gas, email=sporhola@glacieroil.com, c=US Date: 2024.06.13 14:47:02 -08'00' 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 WELL NAME – Badami Unit B1-36 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is a producing oil well utililzing gaslift. Scope of Work: x Rig up slickline. x Pull KX-valve SSSV set below SCSSV at 4,220’ MD. x Rig down slickline. x Perform No-Flow Test per AOGCC Guidance Bulletin 21-001 x Turn well over to production. x Operate well with no SSSV. General Well Information: Reservoir Pressure / TVD: 2,048 psi @ 10,094’ TVD (PT Survey on 5/31/2021) MASP: 2,048 psi - (Pressure Gradient from 5/31/2021 PT Survey) 2,048 psi – (10,094 ft X 0.023 psi/ft) = 1,816 psi Wellhead Type/Pressure Rating: 13-5/8” 10K Wellhead – 4 1/16” 10K tree Well Type: Oil Well Estimated Start Date: June 28, 2024 188 West Northern Lights Blvd, Suite 510, Anchorage, AK 99503 Main (907) 334-6745 | Fax (907) 334-6735 Program 1. Rig up slickline and test lubricator to 2,500 psi. 2. RIH w/ paraffin cutter and pump 80 bbl diesel for brush and flush above KX-valve. 3. RIH and drift 2-7/8” tubing down to KX-valve and AA-Slip Stop SSSV at 4,220’ MD. 4. RIH and pull AA-Slip Stop @ 4,220’ MD. 5. RIH and pull KX-valve and D-Collar Lock @ 4,220’ MD. 6. RIH and pull AD-2 Stop @ 4,250’ MD. 7. RIH and drift 2-7/8” tubing and drift through perfs to 11,900’ MD. a. Min ID = 2.205” @ XN profile at 10,097’ MD. b. Max hole angle = 55° down to 11,900’ MD. 8. RIH w/ press-temp gauges and make static stop at 11,450’ MD on bottom for 30 min. 9. Rig down slickline. 10. Submit a 48-hour notice to AOGCC to witness No-Flow Test. 11. Perform AOGCC witnessed No-Flow Test. a. Follow AOGCC Guidance Bulletin No. 21-001. 12.Turn well over to production. B1-36 RKB 35.25 Note: RKB = D.F. to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi - Manufactured by FMC inch inch Lbs/ft ft DF SS Tree 4-1/16"/10,000 psi - CIW Conductor 20.000 19.124 91.1 83 118 63 13o TMAXX-5e SCSSSV LOCKED OUT 4.750 2.313 6.5 4.19 2215 2149 AA-Slip Stop 0.875 4220 4172 2-7/8" HES K-valve (Closed 9/7/21 @ 124psi WHP)2.180 1.380 1.85 4220 4172 *3 -flow ports ½” each on top of K-Valve through an 1.38 internal flow tube D-Collar Lock 1.375 4237 4189 AD-2 Stop 0.875 4250 4202 13-3/8" 68# L-80 BTC 13.375 12.415 68 4518 4554 4449 4o GLM #4 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.98 4562 4460 44o GLM #3 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.96 7819 6941 31o GLM #2 CAMCO KBMG w/Dummy GLV 2-7/8" x 1" 4.750 2.313 6.5 6.97 9886 8588 GLM #1 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port S/O 4.750 2.313 6.5 6.99 10009 8695 26o HES 2-7/8" x 7" PHL Packer 7.000 2.360 23-29 5.35 10063 8744 HES "X" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 HES "XN" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 Top of Original 4½" Tubing Stub (Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8" 6.5# L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8" 9.2# 9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot @ 10,154'- - - - 10154 8825 Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations - 10,167' - 10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4½" Tubing Stub (EOT)4.500 3.958 12.6 76 10198 8864 9-5/8" L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23o Brookian Perforations - 11,475' - 11,510' - - - - 11475 10094 Brookian Perforations - 11,530' - 11,550' - - - - 11530 10133 Brookian Perforations - 11,562' - 11,600' - - - - 11562 10157 Brookian Perforations - 11,610' - 11,626' - - - - 11610 10180 Brookian Perforations - 11,632' - 11,879' - - - - 11632 10189 SL PMT FISH Not Tagged 3/5/21 - Assumed next to PT Fish Slickline PT Tool FISH TOP - 12,204'12204 4 1/2" Tail Pipe FISH TOF - 12,313'12313 10515 67o 7" x 4-1/2" Liner Hanger Packer 7.000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 7" 29#/ft P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 71o Maximum Deviation - - - - 12503 10567 Killian Peforations - 13,840' - 13,890' -Plugged - - - - 13840 11238 42o Baker CIBP set at 14,060' - 06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations - 14,896'-14,936' -Plugged - - - - 14896 12124 17o 4-½" 12.6# L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev. by Comments/Date B1-36 1 G. Vigil Initial configuration (5/11/2010) 2 E. Opstad Edit GLM graphic & add TVD values to schematic (05-14-10) 3E. Opstad Add top 4½" tubing stub at 10,101' MD & bottom (EOT) at 10,176' MD (06-24-10) 4 Static Survey Data: SBHP 2,445 psi, SBHT 151°F @ 8,830' TVD (Run 8/31/10) 5 R. Berube Updated 30 Aug 12 6 C. Perry Corrected 2 7/8" pkr to 7" 7 S. Ratcliff 10/23/15 - Corrected to Tubing Tally and Revised for Correct Information 8 C. Perry 12/28/15 Post Perf Adds and tail pipe severing 9 A. Dial 02/01/17 - PT Tool lost in hole, tagged at 12,204' 10 D. Clark 3/17/21 - SageRider PMT lost in hole, did not tag. Assumed next to PT tool. 11 S. Begins 8/30/21 - New K-valve placed @ 4220'WLM. Dome pressure set for depth of 4200' @ 450 psi @ 68º 12 D. Clark 5/10/2022 - Added perforations shot in April 2022 Badami UnitAPI No. 50-029-22933 Revised 05/10/22E. Opstad B1-36 RKB 35.25 Note: RKB = D.F. to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi - Manufactured by FMC inch inch Lbs/ft ft DF SS Tree 4-1/16"/10,000 psi - CIW Conductor 20.000 19.124 91.1 83 118 63 13o TMAXX-5e SCSSSV LOCKED OUT 4.750 2.313 6.5 4.19 2215 2149 13-3/8" 68# L-80 BTC 13.375 12.415 68 4518 4554 4449 4o GLM #4 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.98 4562 4460 44o GLM #3 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.96 7819 6941 31o GLM #2 CAMCO KBMG w/Dummy GLV 2-7/8" x 1" 4.750 2.313 6.5 6.97 9886 8588 GLM #1 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port S/O 4.750 2.313 6.5 6.99 10009 8695 26o HES 2-7/8" x 7" PHL Packer 7.000 2.360 23-29 5.35 10063 8744 HES "X" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 HES "XN" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 Top of Original 4½" Tubing Stub (Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8" 6.5# L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8" 9.2# 9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot @ 10,154'- - - - 10154 8825 Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations - 10,167' - 10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4½" Tubing Stub (EOT)4.500 3.958 12.6 76 10198 8864 9-5/8" L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23o Brookian Perforations - 11,475' - 11,510' - - - - 11475 10094 Brookian Perforations - 11,530' - 11,550' - - - - 11530 10133 Brookian Perforations - 11,562' - 11,600' - - - - 11562 10157 Brookian Perforations - 11,610' - 11,626' - - - - 11610 10180 Brookian Perforations - 11,632' - 11,879' - - - - 11632 10189 SL PMT FISH Not Tagged 3/5/21 - Assumed next to PT Fish Slickline PT Tool FISH TOP - 12,204'12204 4 1/2" Tail Pipe FISH TOF - 12,313'12313 10515 67o 7" x 4-1/2" Liner Hanger Packer 7.000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 7" 29#/ft P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 71o Maximum Deviation - - - - 12503 10567 Killian Peforations - 13,840' - 13,890' -Plugged - - - - 13840 11238 42o Baker CIBP set at 14,060' - 06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations - 14,896'-14,936' -Plugged - - - - 14896 12124 17o 4-½" 12.6# L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev. by Comments/Date B1-36 1 G. Vigil Initial configuration (5/11/2010) 2 E. Opstad Edit GLM graphic & add TVD values to schematic (05-14-10) 3 E. Opstad Add top 4½" tubing stub at 10,101' MD & bottom (EOT) at 10,176' MD (06-24-10) 4 Static Survey Data: SBHP 2,445 psi, SBHT 151°F @ 8,830' TVD (Run 8/31/10) 5 R. Berube Updated 30 Aug 12 6 C. Perry Corrected 2 7/8" pkr to 7" 7 S. Ratcliff 10/23/15 - Corrected to Tubing Tally and Revised for Correct Information 8 C. Perry 12/28/15 Post Perf Adds and tail pipe severing 9 A. Dial 02/01/17 - PT Tool lost in hole, tagged at 12,204' 10 D. Clark 3/17/21 - SageRider PMT lost in hole, did not tag. Assumed next to PT tool. 11 S. Begins 8/30/21 - New K-valve placed @ 4220'WLM. Dome pressure set for depth of 4200' @ 450 psi @ 68º 12 D. Clark 5/10/2022 - Added perforations shot in April 2022 13 S. Porhola Proposed (KX-valve removed) Badami UnitAPI No. 50-029-22933 Proposed 6/13/2024E. Opstad Glacier Oil & Gas Corporation 188 W. Northern Lights Blvd, Suite 510 Anchorage, Alaska 99503 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: To:Meredith Guhl From:Daniel Clark AOGCC Savant Alaska, LLC / Glacier Oil & Gas 333 W. 7th Ave, Suite 100 188 W Northern Lights blvd, Suite 510 Anchorage, Ak 99501 Anchorage, AK 99503 Phone: (907) 279 - 1433 Phone: (907) 659 - 1349 TRANSMITTAL DESCRIPTION Qty Description 1 Email contains: - B1-36 Perforation Log PDF - B1-36 Perforation LAS - B1-36 P/T Survey 2021 PDF - B1-36 P/T Survey 2021 LAS Please sign below to acknowledge receipt. Received By: Date: Returned to Glacier Oil & Gas Corporation Date Accepted By: November 18, 2022 Transmittal Form AOGCC.xlsx/Template_1pgGLA Date Modified:11/18/2022 bk By Meredith Guhl at 10:24 am, Nov 18, 2022 198-232 T37274 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.18 10:25:07 -09'00' $$%#)$$ ' #" &) #%!#"' & %#!' 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(/D/<B:/A9/"" )C07<5 @/23 )C07<5#4B&3@4=@/B7=<3>B6)+4B )C07<5(7H3 CB6=@7H32$/;3/<2757B/: (75</BC@3E7B6/B3 % ($ "% #!('#% '& 6734%>3@/B7<5%44713@ By Samantha Carlisle at 2:40 pm, Mar 11, 2022 David Pascal Digitally signed by David Pascal Date: 2022.03.11 11:31:31 -09'00' '65 $'/ 6)' 0*50$5 6)' 6)' &2& GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.30 11:52:02 -08'00' RBDMS SJC 040522 #>*7577 !! %! $$ # $ $ $#'% $$ 888$%<',*&%655 #* $ >>:56-8:<7 #"(& #)!! % + 6-8;!# #% $ ' % $ + 50-029-22933-00-00 # $$ #* % #)* *#)$& %$$& #) # 6-8;*+6>=-787#"&$% !# $$ % !# #% $% #$!# &% , ) &' )"&$% $*! $ %% # %>5<,><=,9687, # )* 6,65-958 7,# ! $ & #) 8, # % David Pascal Digitally signed by David Pascal Date: 2022.03.11 11:31:05 -09'00' ( $&## % )!# & , # " " ! 66*9<:.166*:55. 66*:85.166*::5. 66*:;7.166*:=7. 66*;65.166*;7;. 66*;87.166*=;5. •&%( , • &!%& (%$ #&$ $ &$, •& , •#%( % %% !# %#' , •# #%(%760=/& $ • (( , ! $ !!# ) ( !$465*79:.2,<5!$0%3 ( +'+,* !2$ ! 3 <*6<6!$1265*79:.( (%,8<!$0%$ 3 <*6<6!$18*<>5!$?8*8=6!$ & ) !!# " ( 66/ & % ( : & ( !" 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RKB 35.25 Note: RKB = D.F. to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi - Manufactured by FMC inch inch Lbs/ft ft DF SS Tree 4-1/16"/10,000 psi - CIW Conductor 20.000 19.124 91.1 83 118 63 13o TMAXX-5e SCSSSV LOCKED OUT 4.750 2.313 6.5 4.19 2215 2149 AA-Slip Stop 0.875 4220 4172 2-7/8" HES K-valve (Closed 9/7/21 @ 124psi WHP)2.180 1.380 1.85 4220 4172 *3 -flow ports ²“ each on top of K-Valve through an 1.38 internal flow tube D-Collar Lock 1.375 4237 4189 AD-2 Stop 0.875 4250 4202 13-3/8" 68# L-80 BTC 13.375 12.415 68 4518 4554 4449 4o GLM #4 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.98 4562 4460 44o GLM #3 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.96 7819 6941 31o GLM #2 CAMCO KBMG w /Dummy GLV 2-7/8" x 1" 4.750 2.313 6.5 6.97 9886 8588 GLM #1 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port S/O 4.750 2.313 6.5 6.99 10009 8695 26o HES 2-7/8" x 7" PHL Packer 7.000 2.360 23-29 5.35 10063 8744 HES "X" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 HES "XN" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 Top of Original 4²" Tubing Stub (Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8" 6.5# L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8" 9.2# 9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot @ 10,154'- - - - 10154 8825 Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations - 10,167' - 10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4²" Tubing Stub (EOT)4.500 3.958 12.6 76 10198 8864 9-5/8" L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23o Brookian Perforations - 11,475' - 11,500' - - - - 11475 10094 Brookian Perforations - 11,530' - 11,550' - - - - 11530 10133 Brookian Perforations - 11,562' - 11,582' - - - - 11562 10157 Brookian Perforations - 11,610' - 11,626' - - - - 11610 10180 Brookian Perforations - 11,632' - 11,860' - - - - 11632 10189 Slickline PT Tool FISH TOP - 12,204'12204 4 1/2" Tail Pipe FISH TOF - 12,313'12313 10515 67o 7" x 4-1/2" Liner Hanger Packer 7.000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 7" 29#/ft P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 71o Maximum Deviation - - - - 12503 10567 Killian Peforations - 13,840' - 13,890' - Plugged - - - - 13840 11238 42o Baker CIBP set at 14,060' - 06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations - 14,896'-14,936' - Plugged - - - - 14896 12124 17o 4-²" 12.6# L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev. by Comments/Date B1-36 1G. Vigil Initial configuration (5/11/2010) 2E. OpstadEdit GLM graphic & add TVD values to schematic (05-14-10) 3E. OpstadAdd top 4" tubing stub at 10,101' MD & bottom (EOT) at 10,176' MD (06-24-10) 4 Static Survey Data: SBHP 2,445 psi, SBHT 151F @ 8,830' TVD (Run 8/31/10) 5R. Berube Updated 30 Aug 12 6C. Perry Corrected 2 7/8" pkr to 7" 7S. Ratcliff 10/23/15 - Corrected to Tubing Tally and Revised for Correct Inf ormation 8C. Perry 12/28/15 Post Perf Adds and tail pipe severing 9A. Dial 02/01/17 - PT Tool lost in hole, tagged at 12,204' 10 D. Clark3/17/21 - SageRider PMT lost in hole, did not tag. Assumed next to PT tool. 11 S. Begins 8/30/21 - New K-valve placed @ 4220'WLM. Dome pressure set for depth of 4200' @ 450 psi @ 68º Badami Unit API No. 50-029-22933 Revised 08/30/21E. Opstad !9.;*=287< +*7-87 "5>0".;/8;*=287< ;*,=>;.$=26>5*=. 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APPLICATIONS MUST BE REVIEWED FOR SPECIFIC ENVIRONMENTAL COMPATIBILITY. MEETS MATERIAL SERVICE REQUIREMENTS OF NACE MR0175/ISO 15156 TOP THREAD 1 3/4-12 UNS CONNECTION TYPE BOX PRESSURE RATING 5000 psi TEMPERATURE RATING 20 TO 300 Deg.F LOCK MANDREL TYPE X RUNNING TOOL 13622 (41XO6) PULLING TOOL 100009893 (40GR23100) PISTON TORQUE 48.0 foot.pound CHARGING UNIT 101009567 (81TO620) DOME PRESSURE RATING 5000.0 psi DOME PRESSURE RATING (REMARKS) DOME CHARGE OVER 1000 PSI TO BE WITH NITROGEN ONLY RECOMMENDED DOME CHARGE AT TEST 275.0 psi VOLUME RATIO (CLOSED/OPEN) 1.211 Page 1 Page 2 DRIFT SLEEVE 101088184 (81R175) DRIFT SLEEVE INSIDE DIAMETER 2.2 inch DRIFT SLEEVE LENGTH 3.0 inch TEST FIXTURE(S) 101088676 (81TO1906), 101095596 (81T9572) TEST PRESSURE 5000 psi BDMI/TECHNICAL OPERATIONS MANUAL 22KX23111 (END) (Unless specified, Dim-inches, pres-psi, weight-lbs, temp-deg F) NOTE: Values of pressure, force and operating depths presented above are based upon empirical data and theoretical calculations. These values will vary within accepted engineering limits due to variations in material strength, dimensional tolerances and actual installed conditions. NOTE: Halliburton makes no warranty, either expressed or implied, as to the accuracy of the data or of any calculation or opinion expressed herein. Halliburton, Dallas, Texas, U.S.A. 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:HOO.% ϯϱΖ 0LQLPXP7XELQJ,' 0D[7RRO2' Ϯ͘ϮϱΗ ϳ͗ϯϬ Wͬd>hZ/dKZηϭϱϬϬ'KK ϳ͗ϯϱ Z/,ͬtϮ͘Ϯ>/EKydKϰϮϯϳ^ dKtE, < W,Ϯyd/D ^WKK,Ͳ/EKd^ &>h/> s > ϴ͗ϭϬ Z/,ͬtϮ͘ϱ'^EͲ^dKWdKϰϮϬϬdZzdK^, ZW/EEΖdWKK,KK,ͬtͲ^dKW ϲ͗ϬϬ D^DtͬWZKhd/KE/^h^^z^tKZ<' dW ZD/d ϲ͗ϯϬ d'^Dt/d,Z t/^h^^z^tKZ<WZ WE' d Yh/WD Ed ϲ͗ϰϬ ZͬhKEt >>^d D<dKdKK>^dZ/E' ϵ͗ϮϬ Z/,ͬt^D EKW/E/EͲ^dKWdKϰϮϬϬ^ dͲ^dKWdϰϮϮϬt>D^WE'KtE^, Z'^WKK, ϭϬ͗ϬϬ KK,Ͳ^dKW^ d :RUN6WULQJ'HWDLO 6L]HDQG/HQJWK 'HVFULSWLRQRIDQ\ WRROVRUGHEULVOHIW LQWKHKROH $6723#:/0 %ULHI6XPPDU\RI WKHZRUNFRPSOHWHG Z/,ͬt^D EKW/E/EͲ^dKWdKϰϮϬϬ^ dͲ^dKWdϰϮϮϬt>D^WE'KtE^, Z'^WKK, &UHZ6L]H 6WDQGDUUGUDWH KǀĞƌϭϮ,ƌƌĂƚĞ ^ƚĂŶĚĂƌĚ ĚĚŝƚŝŽŶĂů,ŽƵƌƐ 7RWDO+UV:RUNHG Ϯ͘ϰ 7RWDO7RRO&RVW 7RWDO+RXU&RVW ϯ Ϯ͘ϰ Ϭ ŵŝŶŝŵƵŵĚĂŝůLJƌĂƚĞĨŽƌĂ ŵĂŶĐƌĞǁ͘ :HOO'RZQWLPH+U 6KXWLQ +6330 $SSURYHGE\ BBBBBBBBBBBBBBBBBBBBBBBBBBBB ͺͺͺͺͺͺͺͺͺͺͺͺͺͺ 3'D\ &XPXODWLYH&RVW MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/11/2021 P. I. Supervisor FROM: Matt Herrera SUBJECT: SVS - K -valve Performance Test - Petroleum Inspector Badami Unit B1-36 Cook Inlet Energy PTD 1982320 :- 9/7/2021: Traveled to Badami Facility and met with Supervisor Don Jones and facility Lead Operator Richard Renke and went over job scope for well B1-36 testing with new the new K -valve (subsurface controlled subsurface safety valve). Tested the Low - Pressure Pilot (LPP), Surface Safety Valve (SSV) and new K -valve. It took some time to de -pressure the tubing after LPP trip and SSV performance test to get to the set pressure for the K -valve but once attained it held solid. � Test details can be found in AOGCC Inspection Report # sysMFH210908124217. Attachments: none 2021-0907_SVS_K-valve_Badami _B 1-36_mh.docx Page 1 of 1 By Samantha Carlisle at 4:01 pm, Jun 11, 2021 321-291 DLB 06/11/2021 X MGR15JUN2021 DSR-6/11/21 NA DLB * Per 20 AAC 25.265 Well safety valve systems (h)(5): a performance-test must be conducted semi-annually. 48 hour notice for AOGCC to witness. 10-404 dts 6/16/2021 JLC 6/16/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.16 10:43:00 -08'00' RBDSM HEW 6/16/2021 State to witness a performance test. B1-36 RKB 35.25 Note: RKB = D.F. to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi - Manufactured by FMC inch inch Lbs/ft ft DF SS Tree 4-1/16"/10,000 psi - CIW Conductor 20.000 19.124 91.1 83 118 63 13o TMAXX-5e SCSSSV LOCKED OUT 4.750 2.313 6.5 4.19 2215 2149 13-3/8" 68# L-80 BTC 13.375 12.415 68 4518 4554 4449 4o GLM #4 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.98 4562 4460 44o GLM #3 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port 4.750 2.313 6.5 6.96 7819 6941 31o GLM #2 CAMCO KBMG w/Dummy GLV 2-7/8" x 1" 4.750 2.313 6.5 6.97 9886 8588 GLM #1 CAMCO KBMG 1" LGLV Model BK w/ 1/4" Port S/O 4.750 2.313 6.5 6.99 10009 8695 26o HES 2-7/8" x 7" PHL Packer 7.000 2.360 23-29 5.35 10063 8744 HES "X" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 2-7/8" HES K-valve (dome pressure to be determined) 10083 8761 HES "XN" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 Top of Original 4½" Tubing Stub (Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8" 6.5# L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8" 9.2# 9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot @ 10,154'- - - - 10154 8825 Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations - 10,167' - 10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4½" Tubing Stub (EOT)4.500 3.958 12.6 76 10198 8864 9-5/8" L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23o Brookian Perforations - 11,475' - 11,500' - - - - 11475 10094 Brookian Perforations - 11,530' - 11,550' - - - - 11530 10133 Brookian Perforations - 11,562' - 11,582' - - - - 11562 10157 Brookian Perforations - 11,610' - 11,626' - - - - 11610 10180 Brookian Perforations - 11,632' - 11,860' - - - - 11632 10189 SL PMT FISH Not Tagged 3/5/21 - Assumed next to PT Fish Slickline PT Tool FISH TOP - 12,204'12204 4 1/2" Tail Pipe FISH TOF - 12,313'12313 10515 67o 7" x 4-1/2" Liner Hanger Packer 7.000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 7" 29#/ft P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 71o Maximum Deviation - - - - 12503 10567 Killian Peforations - 13,840' - 13,890' - Plugged - - - - 13840 11238 42o Baker CIBP set at 14,060' - 06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations - 14,896'-14,936' - Plugged - - - - 14896 12124 17o 4-½" 12.6# L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev. by Comments/Date B1-36 1 G. Vigil Initial configuration (5/11/2010) 2 E. Opstad Edit GLM graphic & add TVD values to schematic (05-14-10) 3E. Opstad Add top 4½" tubing stub at 10,101' MD & bottom (EOT) at 10,176' MD (06-24-10) 4 Static Survey Data: SBHP 2,445 psi, SBHT 151°F @ 8,830' TVD (Run 8/31/10) 5 R. Berube Updated 30 Aug 12 6 C. Perry Corrected 2 7/8" pkr to 7" 7 S. Ratcliff 10/23/15 - Corrected to Tubing Tally and Revised for Correct Information 8 C. Perry 12/28/15 Post Perf Adds and tail pipe severing 9 A. Dial 02/01/17 - PT Tool lost in hole, tagged at 12,204' 10 D. Clark 3/17/21 - SageRider PMT lost in hole, did not tag. Assumed next to PT tool. Badami UnitAPI No. 50-029-22933 Revised 02/01/2017E. Opstad 0,Pti oF/ 7 THE STATE Alaska Oil and Gas �w l��• �A of /\ Sjj\ Conservation Commission '���' ' n opt- =- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "M OF Main: 907.279.1433 ALA'S Fax: 907.276.7542 ' www.aogcc.alaska.gov David Pascal Production Manager Savant Alaska, LLC 601 W 5th Avenue, Suite 310 SC "` Anchorage,AK 99501 Re: Badami Field, Badami Oil Pool, B1-36 Permit to Drill Number: 198-232 Sundry Number: 318-129 Dear Mr. Pascal: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, HgE:5 Hollis S. French Chair r4 DATED this day of April, 2018. ASR V16 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MA' 2 7 201; APPLICATION FOR SUNDRY APPROVALS .,_-.-----_-_-_-_,...! 20 AAC 25.280A40 .• if `"° 1.Type of Request: Abandon 0 Plug Perforations ElFractureStimulate I=1 Repair Well e io shutdownII Suspend Perforate ® Other Stimulate Pull Tubin Change Approved Program Plug for Redrill Perforate New Pool Re-enter SuspWell Alter CasingOther: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska LLC Exploratory Development H.198-232 • 3.Address: B ® 6.API Number: Stratigraphic Service 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 50-029-22933-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.0.402A Will planned perforations require a spacing exception? Yes U No XI B1-36 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 365533• Badami Field, Badami Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15546 ' 12729 • 15440 12623 4400 psi 14060/12384(w.l.plug) N/A Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 110' 110' N/A N/A Surface 4,518' 13 3/8" 4,554' 4,505' 5020 2270 Intermediate 10,211' 9 5/8" 10,244' 8,962' 5750 3090 Production 12,403' 7" 12,433' 10,599' 11220 8510 Liner 3,102' 4 1/2" 12338-15440 10565-12623 8440 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11475-11860 10094-10189 4 1/2" L80 10097 Packers and SSSV Type: 7"x 2 7/8"HES Pkr Packers and SSSV MD(ft)and ND(ft): Pkr @ 10063'MD/8744'ND- TMAXX-5E SSSV SSSV @ 2215'MD/2149'ND 12.Attachments: Proposal Summary IN Wellbore schematic IXI 13.Well Class after proposed work: • Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development IXI W Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: ASAP OIL ® • WIND WDSPL p Sus ended El — 16.Verbal Approval:, Date: GAS ❑ WAG GSTOR _ SPLUG Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact David Pascal Email dpascal(c�glacieroil.com Printed Name Title David Pascal` ► Production Manager Signature LAal` ..---4 Phone Date 2 f a) t 907-433-3822 J t /! COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: 8 /� Plug Integrity El BOP Test El Mechanical Integrity Test Ei Location ClearanceEl Other: ' O C V% `` ' Sk L Post Initial Injection MIT Req'd? Yes El No i: loot -72.1A(.1 A Spacing Exception Required? Yes ElNoSubsequent Form Required: b0f:::2cC.MLLLJJJ APPROVED BY Approved by: — COMMISSIONER THE COMMISSION Date: ki 1' f 1 J /ff,Q y-a-Zo/S' ,{� \� Submit Form and �vl`r� Form 10-403 Revised 11/2015 Approvedmoi I a t v (INn s from the date of approval. Attachments in Duplicate ,' • i , < GLACIER March 26, 2018 Mr. Hollis French, Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501-3572 Subject: Sundry Request: Badami B1-36 Perf Add Application API: 50-029-22933-00-00 Dear Commissioner French, Glacier Oil and Gas as owner/operator of Savant Alaska, LLC, hereby submits an Application for Sundry Approval for Badami B1-36, PTD: 198-232, requesting permission to add perforations to increase production. A Sundry (Sundry Number: 317-084) was previously approved for the same work on Feb 21, 2017 which expired and hence the resubmittal request. If you have any questions, please contact me at (907) 433-3822 or at dpascal@glacieroil.com Sincerely, 2)\\\:::\\*5 ( Da id Pascal Production Manager Savant Alaska, LLC A Glacier Oil &Gas Company Attachments 1. B1-36: 10-403 2. B1-36: Perforation Program 3. B1-36: Current Wellbore Diagram 4. B1-36: Proposed Wellbore Diagram • GLACIER 1. WELL NAME - Badami B1-36 Requirements of 20 MC 25.005(J) Well Summary Current Status: The well is producing. Scope of Work: • RU E-line. Test Lubricator to 4,500 psi. • Perforate new interval. • RD E-line. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.7 psi/ft 7,248 psi @ 11,879 MD (10,355'TVD) MASP: 4,400 psi (half oil/half gas) Reservoir Pressure - (Oil Gradient) - (Gas Gradient) 7,248 psi - (5,178'with 0.45 psi/ft oil) - (5,177'with 0.1 psi/ft gas) = 7,248 psi - 2,330 psi - 518 psi = 4,400 psi Wellhead Type/Pressure Rating: 13-5/8" 10K Wellhead - 4 1/16" 10K tree BOPE: Rigless - E-line Lubricator Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: None Drilling Manager Production Manager Stephen Ratcliff David Pascal (907) 433-3808 (907) 433-3822 sratcliff@glacieroil.com dpascal@glacieroil.com 1 601 West 5th Avenue, Suite 310, Anchorage,AK 99501 Main (907) 334-6745 I Fax (907) 334-6735 S r GLACIER Program E-line Program 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Rig up E-line and test lubricator to 4,500 psi 3. Perform gauge ring run 4. RIH with 2-1/8" strip guns and perforate, 6 spf/ 60° phase, from 11,867' - 11,879' MD (10,348' - 10,356'TVD) 5. Rig down E-line. 6. Turn well over to production. 2 N • • , 3 6 B1 - 36 .. RKB 35.3 Note:6103=D.F.to Tubing Hanger Drill Floor to Tubing Hanger 35.25 00 10 We M Length ergM MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8'/11000 psi-Manufactured by FMC inch inch Lbelft ft DF SS L Tree 4-1/18"/10,000 psi-CNV Conductor 20.000 19.124 91.1 83 118 83 13° TMAX%-5e SCSSSV 4.750 2.313 8.5 6.19 2215 2149 4 6 , 13-3/8'88/1E-80 BTC 13.375 12.415 88 4518 4554 4449 4 4° GLM 84 CAMCO KBMG 1"LGLV Model BK w/1/4"Pon 4.750 2.313 6.5 6.98 4562 4480 41° Y I GLM 83 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.96 7819 6941 31° 4 i GLMO2 CAMCOKBMG w/Dummy GLV 2-7/8's 1" 4.750 2.313 65 6.97 9888 8588 II I GLM N1 CAMCO KONG 1"LGLV Model BK w/1/4"Port 5/0 4.750 2.313 8.5 8.99 10009 8605 26° EIJ B HES 2-7/8"x 7"PHL Packer 7.000 2.360 23-29 5.35 10083 8744 0 4 HES"X'Nipple 2-7/8"6.5f/9CR EUE 0/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8701 0 0 HES'XN"Nipple 2-7/8"6.58 OCR EUE 0/2.313 PKG Bore 3.680 2.205 8.5 1.30 10097 8773 Top of Original 4%"Tubing Stub(Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8'6.58 L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 W LEG 2-718"9.28(CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 - Split Shot R 10,154: • - - - 10154 8825 H Baker Permanent Pecker 7.000 3.875 3.75 10162 8631 Tubing Perorations•10,167' 10,173' - - - - 10167 8837 Tail Pipe Severed(010173' - - - - 10170 8848 HES X Nipple OCR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4X'Tubllg Stub(EOT) 4500 3.958 12.6 76 10198 8864 4 , 0-5/8'L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8011 23` Brooker Perforations-11,175'-11,500' - 11475 10094 Brooken Perorations-11,530'-11,550' 11530 10133 Betoken Perforations-11,562'-11,582' 11562 10157 Brookien Perorations-11,610'-11,826 - - - - 114110 10180 Brooken Perorations-11,832'-11,880' - - - - 11632 10189 Slicklne PT Tool FISH TOP-12,204' 12204 4 1/2'Tel Pipe FISH TOF•-12,313' 12313 10515 67° H 7's 4-1/2"Liner Henger Packer 7.000 3.958 29 - 12338 10552 L � I I I I I I I i i J HES X Nipple OCR ID 3.813' 4.500 3813 - - 12384 10533 7"298/8 P110 BTC Casing Shoe 7.000 6.184 20 12400 12433 10547 itI Maxmum Deviation - - - - 12503 10587 Killian Peforatons.13840'-13,890'-Plugged - - - 13840 11238 42' Baker CIBP set at 14,060-08/02/09 4.500 - - - 14060 11392 Kekiktuk Peforalons-14,898'-14,936'-Plugged - - 14808 12124 17° 4-7."12.68 L-80 BTC-M Liner 4500 3.968 12.6 3202 16440 12644 No. Rev.by Comments/Date 1 G.Viral Inliel configuration(5/11/2010) Ba am n 2 E.Opslad Edit GLM graphic 8 add TVD values to schematic(05-14-10) API No.50-029-22933 3 E.Opstad Add lop 4Y,'tubing stub at 10,101'MD 8 bottom(EOT)at 10,178'MD(08-24-10) 4 E.Opslod Static Survey Data,SBHP 2,445 psi,SBHT 151'F @ 8,830'TVD(Run 8/31/10) Revised 02/01!2017 5 R.Berube Updated 30 Aug 12 6 C.Perry Corrected 2 7/8'pkr to 7" SA.AM"' 7 S.Ratcliff 10/23/15-Corrected to Tubing Tally and Revised for Correct Information A I_ASKA 8 C.Perry 12/28/15 Post Per Adds and tail pipe severing 9 A.Diel 02/01/17-PT Tool lost in hole,lagged 01 12,204' 11111 1 • • r B RKB 35.3 Note:RKB=D.F.to Tubing Hanger Dnll Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8-/10,000 psi•Manufactured by FMC rich Poch Lbelt ft DF SS J L Tree 4-1/16"/10,000 psi-CIU Conductor 20.000 18.124 91.1 83 118 63 13' Dr TMAXX-Se SCSSSV 4750 2.313 65 4.19 2215 2149 13-3/8"680 L-80 BTC 13.375 12.415 68 4518 4554 4449 4` 1 1 GLM#4 CAMCO KBMG 1'LGLV Model BK w/1/4'Port 4.750 2.313 85 6.98 4562 4480 44' 4 1 GLM#3 CAMCO KBMG I'LGLV Model BK w/1/4'Port 4750 2.313 6.5 8.08 7810 6941 31' 1 1 GLM#2 CAMCO KBMG w/Dummy GLV 2-7/8"x 1' 4.750 2.313 6.5 6.97 8888 8588 y I GLM#1 CAMCO KBMG 1'LGLV Model BK w/1/4'Port 0/0 4750 2.313 8.5 8.00 10009 8695 26' Ej HES 2-7/8"0 7'PHL Packer 7.000 2.300 23-20 5.35 10083 8744 0 0 HES"X"Nipple 2.718"6.50 9CR EUE w2.313 PKG Bore 3.680 2.313 85 128 10083 8781 0 0 HES"XN"Npple 2-7/8"8 50 9CR EUE w12.313 PKG Bore 3.680 2205 8.5 1.30 10087 8773 Top of Original 4/4'Tubing Stub(Cut-Off) 4.530 3.958 12.6 0 10122 8795 2-7/8"6.50 L-80 EUE Tubing 2.875 2441 6.5 10141 10141 8817 ' WLEG 2-7/0"9.28 OCR IBT-M Box 2.875 2441 6.5 1 33 10142 8818 Split Shot 4j)10.154' - - - 10154 8825 B • Baker Permanent Packer 7.000 3.875 - 3.75 10182 8831 Tubing Perforations-10,167'-10,177 - - - - 10167 8837 Tail Pipe Severed 0)10173' - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10188 8853 Bottom of Original 4%"Tubing Stub(EOT) 4.500 3.058 12.6 76 10108 8864 9-5/8"L-80 Intermediate Casing Shoe 9.825 8.535 53.5 10211 10244 8911 27 Brookan Perforations-17475'-11,500' - - - - 11475 10094 Brookien Perforations-11,530'-11,550' - - - 11530 10133 Brookan Perforations-11,502'-11,582' - - - 11562 10157 Brookan Perforations-11,810'-11,626' - - • - 11010 10180 Brookien Perforations-11,832'-11,880' - - . - 11632 10189 .,T ,. ii;34 Slokline PT Tool FISHH TOP OP-12,204' 12204 4 12"Tai PIPs FISH TOF-12,313' 12313 10515 67° 7'x 4-12"Liner Hanger Pecker 7.000 3958 29 10338 10.522 j „ l I HES XNipple BCR ID 3.813' 4.500 3813 12384 10533 7'286/5 P110 BTC Casing Shoe 7.000 8.184 29 12400 12433 10547 Maximum Deviation - - - 12503 10587 Kilian Peforatons-13,840'-13.890'-Plugged - - - - 13840 11238 42' Baker CIBP set at 14,060'-06/02/09 4.500 - - - 14060 11392 Kekiktuk Peforatons-14,806-14,936'-Plugged - - - - 14806 12124 17' 4-14'1286 L-80 BTC-M Liner 4,500 3.858 12.8 3202 15440 12844 No. Rev.by Comments/Date 1 G.Vigil Initial confguretion(5/11/2010) a am n 2 E.Opsted Edt GLM graphic&add TVD values to schematic(05-14-10) API No.50-029-22933 3 E.Opsted Add top 414"tubing stub at 10,101'MD 6 bottom(EOT)el 10,176'MD(06-24-10) 4 E.Opeled Stolle Survey Data:601-/P 2,445 psi,SBHT 151'F @ 8,830'TVD(Run 8/31/10) Planned 5 R.Berube Updated 30 Aug 12 6 C.Perry Corrected 27/8'pkr to 7" Schematic Iemal+ ic 7 S.Ratcliff 10/23/15-Corrected to Tubing Tally and Revised far Correct Information 8 C.Perry 12/28/15 Post Pert Adds and tat pipe severing 9 A.Dol 02/01/17-PT Tool lost in hole,tagged at 12204' • OF Ty • • 431� THE STATE Alaska Oil and Gas I%�: � of/` LAS KA Conservation Commission Art 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 01"ALAE*P' Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager Savant Alaska, LLC • 601 W. 5th Ave., Ste.-310 Anchorage,AK 99501-6301 CAHMED MAR 2 2tt7' Re: Badami Field, Badami Oil Pool, B1-36 Permit to Drill Number: 198-232 Sundry Number: 317-084 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, !fif I . Daniel T. Seamount, Jr. Commissioner S DATED this 2.1 day of February,2017. RBDIVIS L 1' FEB 2 7 2017 ' • STATE OF ALASKA . RECEIVED ECEIVE ' ALASKA OIL AND GAS CONSERVATION COMMISSION FEBT7 201/ APPLICATION FOR SUNDRY APPROVALSO � �` 7 20 MC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 2 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska LLC Exploratory ❑ Development E. 198-232 ' 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 50-029-22933-00-00 , 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.402A ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / B1-36 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 365533 " Badami Field, Badami Oil Pool 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): 15546 • 12729 • 15440 • 12623 , 4400 psi 14060/12384(w.l.plug) N/A Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 110' 110' N/A N/A } Surface 4,518' 13 3/8" 4,554' 4,505' 5020 2270 1 Intermediate 10,211' 9 5/8" 10,244' 8,962' 5750 3090 Production 12,403' 7" 12,433' 10,599' 11220 8510 Liner 3,102' 4 1/2" 12338-15440 10565-12623 8440 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11700-11860 - 10245-10345 4 1/2" L80 10097 Packers and SSSV Type: 7"x 2 7/8"HES Pkr Packers and SSSV MD(ft)and TVD(ft): 1 Pkr @ 10063'MD/8744'TVD- TMAXX-5E SSSV SSSV @ 2215'MD/2149'TVD 12.Attachments: Proposal Summary U Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑✓ . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: ASAP Commencing Operations: OIL LI • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Conrad Perry Email cperry@glacieroil.com Printed Name Title Conrad Per/ Drilling Manager Signature /J ~hone Date 907-727-7404 ��/ -----/ 7 COMMISSION USE ONLY Conditions of approval: Notif Commissio/so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ��� Z 1 Z t ,. Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS t_u. FEB 2 / 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: l 0-- 0 9 i APPROVED BY 2121/ // ) 7 Approved by: / / COMMISSIONER THE COMMISSION Date: [/ 2 [ ASubmit Form and Form 10-403 Revi d 11 2015 Op • a r•�c t for 12 months from the date f approval. Attachments in Duplicate • • RECEIVED GLACIER i-Lb 1 7 2017 February 17th, 2017 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry: Badami B1-36—Perf Add Application Cook Inlet Energy: 50-029-22933-00-00 Dear Ms. Foerster, Savant Alaska, LLC, hereby submits an Application for Sundry Approval for Badami B1-36, PTD: 198- 232, requesting permission to add perforations to increase production. If you have any questions, please contact me at 907.747.7404. Sincerely, Conrad '- Sr. Vice resident Savant Alaska, LLC (a Glacier Oil &Gas Wholly Owned Company) 601 W. 5th Avenue STE 310 Anchorage, AK 99501 1 • • GLACIER 1. WELL NAME— Badami B1-36 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Scope of Work: • RU Eline. Test Lubricator to 4500 psi. • Perforate new interval. • RD Eline. • Turn well over to production. General Well Information: Reservoir Pressure/TVD: 0.7 psi/ft 7,248 psi @ 11,879 MD (10,355' TVD) MASP: 4,400 psi (half oil/half gas) Reservoir Pressure— (Oil Gradient) - (Gas Gradient ) 7,248 psi — (5,178' with 0.45 psi/ft oil)— (5,177' with 0.1 psi/ft gas) = 7,248 psi —2,330 psi —518 psi = 4,400 psi Wellhead Type/Pressure Rating: 13-5/8" 10K Wellhead —4 1/16" 10K tree BOPS: Rigless— [-line Lubricator Well Type: Oil Well Estimated Start Date: ASAP Waivers Requested: None Drilling Manager Sr. Drilling Engineer Production Manager Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-3808 (907) 433-3822 cperry@glacieroil.com sratcliff@glacieroil.com dkumar@glacieroil.com 2 • • GLACIER Program E-line Program 1. Conduct pre-job safety meeting with all personnel on location. o Review upcoming work and discuss safety first. 2. Rig up E-line and test lubricator to 4,500 psi. 3. RIH with 2-1/8" strip guns and perforate, 6 spf/600 phase, from 11,867'—11,879' MD (10,348'— 10,355' TVD). 4. Rig down E-line. 5. Turn well over to production. 3 • • _ • • RKB 35.3 Note:ROB=D.F.to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead t3-5/8"/10,000 psi-Manufactured by FMC inch inch Lbs/ft ft DF SS L Tree 4-1/16710,000 psi-CIW - Conductor 20.000 19.124 91.1 83 118 63 13° L:)C TMAXX-5e SCSSSV 4.750 2.313 6.5 4.19 2215 2149 13-3/8"68#L-80 BTC 13.375 12.415 68 4518 4554 4449 4° II I GLM#4 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.98 4562 4460 44° II I GLM#3 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.96 7819 6941 31° 4 I GLM#2 CAMCO KBMG w/Dummy GLV 2-7/8"x 1" 4.750 2.313 6.5 6.97 9886 8588 111 I GLM#1 CAMCO KBMG 1"LGLV Model BK w/1/4"Pod 0/0 4.750 2.313 6.5 6.99 10009 8695 26` I HES 2-7/8"x 7"PHL Packer 7.000 2.360 23-29 5.35 10063 8744 li I HES"X"Nipple 2-7/8"6.5#9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 It I HES"XN"Nipple 2-7/8"6.58 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 • Top of Original 4%"Tubing Stub(Cut-Off) 4500 3.958 12.6 0 10122 8795 2-7/8"6.5#L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8"9.2#9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 - Split Shot @ 10,154' - - - - 10154 8825 H Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations-10,167'-10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4500 3.813 - - 10186 8853 Bottom of Original 4%"Tubing Stub(EDT) 4.500 3.958 12.6 76 10198 8864 I , 9-5/8"L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23° Brookian Perforations-11,475'-11,500' _ - - - 11475 10094 Brookian Perforations-11,530'-11,550' 11530 10133 Brookian Perforations-11,562'-11,582' 11562 10157 Brookian Perforations-11,610'-11,626' - - - - 11810 10180 Brookian Perforations-11,632'-11,860' - - - - 11632 10189 ® Slickline PT Tool FISH TOP-12,204' 12204 4 1/2"Tail Pipe FISH TOP-12,313' 12313 10515 67° �� 7"x 4-1/2"Liner Hanger Packer 7,000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 12384 10533 7"29#/ft P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 ,1 Maximum Deviation - - - - 12503 10567 1114i. Killian Peforations-13,840'-13,890'-Plugged - - - - 13840 11238 42° Baker CIBP set at 14,060'-06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations-14,896'-14,936'-Plugged - - - - 14896 12124 17° 4-4"12.68 L-80 BTC-M Liner 4500 3.958 12.6 3202 15440 12644 No. Rev.by Comments/Date B1-36 1 G.Vigil Initial configuration(5/11/2010) :a.ami 1 nit 2 E.Opstad Edit GLM graphic&add TVD values to schematic(05-14-10) API No.50-029-22933 3 E.Opstad Add top 4h"tubing stub at 10,101'MD&bottom(EDT)at 10,176'MD(06-24-10) 4 E.Opstad Static Survey Data:SBHP 2,445 psi,SBHT 151°F @ 8,830'TVD(Run 8/31/10) Revised 02/0112017 5 C.BerubeUpdated 30 AugSAvANT 6 C.Perrypkr 2 7/8"pkr to 7" __ 7 S.Ratcliff 10/23/15-Corrected to Tubing Tally and Revised for Correct Information ALASKA 8 C.Perry 12/28/15 Post Perf Adds and tail pipe severing 9 A.Dial 02/01/17-PT Tool lost in hole,tagged at 12,204' , , , • B1 - 36 • J RKB 35.3 Note:RKB=D.F.to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8"/10,000 psi-Manufactured by FMC inch inch Lbs/ft ft DF SS J L Tree 4-1/16710,000 psi-CIW Conductor 20.000 19.124 91.1 83 118 63 3° TMAXX-5e SCSSSV 4.750 2.313 6.5 4.19 2215 2149 I, 13-3/8"68#L-80 BTC 13.375 12.415 68 4518 4554 4449 4° II I GLM#4 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.98 4562 4460 44° 4 I GLM#3 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.96 7619 6941 31° II I GLM#2 CAMCO KBMG w/Dummy GLV 2-7/8"x 1" 4.750 2.313 6.5 6.97 9886 8588 II I GLM#1 CAMCO KBMG 1"LGLV Model BK w/1/4"Port S/O 4.750 2.313 6.5 6.99 10009 8695 26 e e HES 2-7/8"x 7"PHL Packer 7.000 2.360 23-29 5.35 10063 8744 0 I HES"X"Nipple 2-7/8"6.58 9CR EUE w/2.313 PKG Bore 3.680 2.313 8.5 1.26 10083 8761 0 I HES"XN"Nipple 2-7/8"6.58 9CR EUE w/2.313 PKG Bore 3.680 2.205 8.5 1.30 10097 8773 • Top of Original 4%"Tubing Stub(Cut-Off) 4.500 3.958 12.8 0 10122 8795 2-7/8"6.5#L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8"9.2#9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot @ 10,154' - - - - 10154 8825 Baker Permanent Packer 7.000 3.875 - 3.75 10162 8831 Tubing Perforations-10,167'-10,173' - - - - 10167 8837 Tail Pipe Severed @10173' - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3,813 - - 10186 8853 Bottom of Original 4'/,"Tubing Stub(EDT) 4.500 3.958 12.6 76 10198 8864 9-5/8"L-80 Intermediate Casing Shoe 9.625 8.535 53.5 10211 10244 8911 23` Brookan Perforations-11,475'-11,500' - _ _ - 11475 10094 Brookan Perforations-11,530'-11,550' 11530 10133 Brookian Perforations-11,562'-11,582' 11562 10157 K Brookian Perforations-11,610'-11,626' / - - - - 11610 10180 �.Brookan Perforations-11,632'-11,860' ✓/ - - - - 11632 10189 / New Perfs:Brookian Perforations-11,867'-11,879' - . . - 11867 10348 _ Slickline PT Tool FISH TOP-12,204' 12204 4 1/2"Tail Pipe FISH TOF-12,313' 12313 10515 67` 7"x 4-1/2"Liner Hanger Packer 7,000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 I 7"29#/ft P110 BTC Casing Shoe 7.000 8.184 29 12400 12433 10547 Maximum Deviation - - - - 12503 10567 Killian Peforations-13,840'-13,890'-Plugged - - - - 13840 11238 42° Baker CIBP set at 14,060'-06/02/99 4.500 - - - 14060 11392 Kekiktuk Peforations-14,896'-14,936'-Plugged - - - - 14898 12124 17° 4-h"12.6#L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev.by Comments/Date B1-36 1 G.Vigil Initial configuration(5/11/2010) :a•amt U nit 2 E.Opstad Edit GLM graphic&add TVD values to schematic(05-14-t0) API No.50-029-22933 3 E.Opsted Add top 4,A"tubing stub at 10,101'MD&bottom(EDT)at 10,176'MD(06-24-10) 4 E.Opstad Static Survey Data:SBHP 2,445 psi,SBHT 151"F @ 8,830'TVD(Run 8/31/10) Planned 02116/2017 5 R.Berube Updated 30 Aug 12 6 C.Perry Corrected 2 7/8"pkr to 7" SAvA YT_ 7 S.Ratcliff 10/23/15-Corrected to Tubing Tally and Revised for Correct Information ALASKA 8 C.Perry 12/28/15 Post Perf Adds and tail pipe severing 9 A.Dal 02/01/17-PT Tool lost in hole,tagged at 12,204' STATE OF ALASKA • AIIlikA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown U Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator Savant Alaska LLC 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 2 Exploratory ❑ 198-232 3.Address: 601 W.5th Avenue,Suite 310 Anchorage,AK Stratigraphic❑ Service ❑ 6.API Number: 99501 50-029-22933-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 365533 B1-36 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Badami Field, Badami Oil Pool nu 2 8 ?O15 11.Present Well Condition Summary: Total Depth measured 15546 feet Plugs measured 12384 feeAOGCC true vertical 12729 feet Junk measured 12313 feet Effective Depth measured 15440 feet Packer measured 10063 feet true vertical 12623 feet true vertical 8744 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' N/A N/A Surface 4,518' 13 3/8" 4,554' 4,505' 5020 2270 Intermediate 10,211' 9 5/8" 10,244' 8,962' 5750 3090 Production 12,403' 7" 12,433' 10,599' 11220 8510 Liner 3,102' 4 1/2" 12338-15440 10565-12623 8440 7500 Perforation depth Measured depth 11,145'-11,860 feet See Schematic(attached for details) True Vertical depth 10094-10522 feet Tubing(size,grade,measured and true vertical depth) 2 7/8" L-80 10097 8773 Packers and SSSV(type,measured and true vertical depth) HES 2 7/8"x7" 10063/8744 2 7/8"TMAXX-5E 2215/2149 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 'SCANNED V r\R`; ''+ 4 2 1;1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 316 1507 13 796 165 Subsequent to operation: 562 1495 1 812 164 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑i Exploratory El Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ 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: Contact Conrad Perry Email conrad.perrycookinlet.net Printed Name Conr rry Title Drilling Manager Signature Phone 907-727-7404 Date 12/28/2015 Form 10-404 Revved 5/2015 VTC— RBDMS V ut:L 2 8 2015 Submit Original Only • • . B1 - 36 RKB 35.3 Note: RKB=D.F.to Tubing Hanger Drill Floor to Tubing Hanger 35.25 OD ID Weight Length MD TVD Ground Level to Sea Level 19.5 Wellhead 13-5/8710,000 psi-Manufactured by FMC inch inch Lbs/ft ft DF SS J L Tree 4-1/16"/10,000 psi-CIW Conductor 20.000 19.124 91.1 83 118 83 13` TMAXX-5e SCSSSV 4.750 2.313 6.5 4.19 2215 2149 13-3/8"68#L-80 BTC 13.375 12.415 68 4518 4554 4,449 4° 4 ' GLM#4 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 4.750 2.313 6.5 6.98 4562 4460 44° 4 I GLM#3 CAMCO KBMG 1"LGLV Model BK w/1/4"Pod 4.750 2.313 6.5 6.96 7819 6941 31° 4 I GLM#2 CAMCO KBMG w/Dummy GLV 2-7/8"x 1" 4.750 2.313 65 8.97 9886 8588 4 I GLM#1 CAMCO KBMG 1"LGLV Model BK w/1/4"Port 0/0 4.750 2.313 6.5 6.99 10009 8895 26` 1 HES 2-7/8"x 7"PHL Packer 7.000 2.360 23-29 5.35 10063 8744 0 I HES"X"Nipple 2-7/8"6.5#9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 0 I HES"XN"Nipple 2-7/8"6.5#OCR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8773 • .' Top of Original 4'//"Tubing Stub(Cut-Off) 4.500 3.958 12.6 0 10122 8795 2-7/8"6.58 L-80 EUE Tubing 2.875 2.441 6.5 10141 10141 8817 WLEG 2-7/8"9.2#9CR IBT-M Box 2.875 2.441 6.5 1.33 10142 8818 Split Shot in 154 - - - - 10154 8825 El 111 Baker Permanent Packer 7.000 3.875 - 3.75 10182 8831 Tubing Perforations-10,167'-10,173' - - - - 10167 8837 -':pe Severed @ I0173 - - - - 10179 8848 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 10186 8853 Bottom of Original 4''A"Tubing Stub(EDT) 4.500 3.958 12.6 76 10198 8864 I ® 9-5/8"L-80 Intermediate Casing Shoe 9.625 8535 53.5 10211 10244 8911 23° Brookian Perforations-11,475'-11500' - - - - 11475 10094 Brookian Perforations-11,530'-11,550' - - - - 11530 10133 Brookian Perforations-11,562'-11,582' - - - - 11562 10157 Brookian Perforations-11,610'-11,626' - - - - 11610 10180 Brookian Perforations-11,632'-11,880' - - - - 11832 10189 4 1/7 Tail Pipe FISH TOF-12,313' 12313 10515 67` 7"x 41/2"Liner Hanger Packer 7.000 3.958 29 - 12338 10522 HES X Nipple 9CR ID 3.813" 4.500 3.813 - - 12384 10533 A ® 7"29#/h P110 BTC Casing Shoe 7.000 6.184 29 12400 12433 10547 - - - - 12503 10567 KnorrPetorasons-13,840-13,80U- - - - 13840 11238 42° Baker CIBP set at 14,060'-06/02/99 4.500 - - - 14080 11392 Kekiktuk Peforations-14,898'-14,936'- - - - - 14896 12124 17° 4%"12.6#L-80 BTC-M Liner 4.500 3.958 12.6 3202 15440 12644 No. Rev.by Comments/Date B1-36 1 G.Vigil Initial configuration(5/11/2010) =a•amt 1 flit 2 E.Opstad Edit GLM graphic&add TVD values to schematic(05-14-10) API No.50-029-22933 3 E.Opstad Add top 4%"tubing stub at 10,101'MD&bottom(EDT)at 10,176'MD(06-24-10) 4 E.Opstad Static Survey Data:SBHP 2,445 psi,SBHT 151"F @ 8,830'TVD(Run 8/31/10) Revised 10/23/2015 5 R.Berube Updated 30 Aug 12 6 C.Perry Corrected 2 7/8"pkr to 7" SA1AV 7 S.Ratcliff 10/23/15-Corrected to Tubing Tally and Revised for Correct Information ALASKA 8 C.Peny 12/28/15 Post Pert Adds and tail pipe severing S • Savant Alaska, LLC SAANT DAILY DRILLING I WORKOVER REPORT ALASKA DATE 10/20/2015 LEASE AND WELL NO AFE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 1 4 10,183' 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative is POLLARD SL UNIT Accidents Incidents Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 12.0 03.78 $45.38 POLLARD-SL SERVICES 3 $270 $810.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 2:00 PM RIG UP SLICKLINE 2:20 PM RIH WITH 2.3"HELICAL PARAFFIN CUTTER,RIH WITH 2.1"BLB,RIH WITH 2.3"BLB,RIH WITH 2.4'BLB. CUT LIGHT PARAFFIN.(TAG DEBRIS AT 10,153 SLM) 4:40 PM RIG DOWN SLICKLINE 5:00 PM TURN WELL OVER TO PRODUCTION TO FLOW OVERNIGHT. 0 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST (HRS) 9121115 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 40 DAILY COST 4011188110 3 319 CUM TOTAL 40 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 55 DEGF N/A N/A NIA OPERATORS REP: Day DSM DANIEL CLARK Office (907)6s&1236 Cell (807)978-4132 email danieLcark@savantalaska.com Night DSM DANIEL CLARK Office Cell email i S Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 10/21/2015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 2 3 10,182' 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0 POLLARD SL/EL UNITS HSE Accidents Incidents Spills I COMMENTS NO SPILLS.ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Deily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 04.0 3.76 $355.32 POLLARD-SL SERVICES 12 $270 $3,240.00 DIRTY DIESEL FOR BRUSH AND FLUSH 1890.0 2.01 53,798.90 POLLARD-EL SERVICES $2,100.00 (SERVICE CHARGE/PRESSURE CONTROL) $0.00 $0.00 SD.DR 40.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM LOAD SHOT(SAVANT HOT OIL TRUCK)WITH DIRTY DIESEL FROM DAWG TANK FARM 7:00 AM SPOT SHOT ON B1-36 7:15 AM SPOT ELINE UNIT,MAKE UP LUBRICATOR,RUN WIRE,MAKE UP TOOLSTRING 8:20 AM PT SHOT LINES AND HOSES;START PUMPING HOT DIESEL DOWN THE TUBING 8:40 AM RIH WITH 2.4"BLB ON SL AND BRUSH BETWEEN SURFACE AND 5000' 11:15 AM PUMPING COMPLETE,BLEED DOWN THE LUBRICATOR AND SHOT 11:40 AM RIG DOWN SL AND RIG UP ELINE 12:45 PM PRESSURE TEST AND RIH WITH 3:00 PM POOH WITH ELINE. PRINT LOGS AND MATCH UP JEWELRY. 4:00 PM OOH WITH ELINE. POLLARD ANNOTATING AND PRINTING CCL LOG. 5:17 PM SEND LOG TO TOWN AND START WORKING ON MODIFYING TOOLSTRING TO MAKE THE CUT AT THE RIGHT DEPTH 7.30 PM COMPLETE TOOL MODIFICATIONS. SHORTEN THE ANCHOR BY 18"BY CUTTING THE ENDS OAND BUILD UP THE BULLNOSE FROM 1.37"OD TO 1.875"OD. 8:00 PM LAY DOWN LUBRICATOR AND SECURE UNITS FOR THE NIGHT. 40 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST OPYIPAP (HRS) 9/21115 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 213 1 DAILY COST 16 319 CUM TOTAL 253 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 55 DEGF N/A N/A NIA OPERATORS REP: Day DSM DANIEL CLARK OfficeI (907)659-1236 Cell (907)978-4132 email daniel.clark�lasavantalaska.com Night DSM DANIEL CLARK Office Cell email ! • Savant Alaska, LLC SAAISIT DAILY DRILLING/WORKOVER REPORT ALASKA DATE 10/22/2015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS MW MD NUMBER OF MISRUNS Badami-B1-36 3 2 10,182' 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0_ POLLARD EL UNITS Accidents Incidents I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 107.0 3.78 $40440 POLLARD-EL SERVICES $26,080.10 (SERVICE CHARGE/PRESSURE CONTROL/IWO RCT) 00.00 $0.00 00.00 00.00 $0.00 00.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM BLEED PRESSURE OFF OF B1-36;FLOW GAS TO PRODUCTION. 7:45 AM TAKE ECO-METER SHOTS ON B1-36 0:00 AM RIG UP ELINE 9:00 AM MEET WITH TOWN AND DISCUSS NEW INFORMATION AND PLAN FORWARD. DETERMINE THERE ARE TWO 10'PUPS ABOVE THE NIPPLE AND BELOW THE 4.5"PACKER. 9:30 AM CHANGE CONFIGURATION OF TOOLSTRING SO THAT THE RCT'S WILL CUT IN THE TOP 10'PUP JOING AT 10173'. 10:10 AM PT ELINE LUBRICATOR AND RIH WITH RCT#1 11:30 AM ON BOTTOM,CORRELATE TO JEWELRY POSITION RCT ON BOTTOM. SET DOWN AT 10182'ELMD WITH THE CUTTER CENTRALIZED AT 10173'. CONFIRM WITH TOWN;FIRE RCT AT 10173'ELMD. POSITIVE INDICATION OF FIRE BUT 4.5" 11:50 AM TUBING DID NOT FALL. SET DOWN 3 TIMES THEN POOH. 1:00 PM OOH WITH RCT;CONFIRM CUTTER FIRED. RIG DOWN FIRED RCT AND RIG UP RCT#2. 2:00 PM RIH WITH RCT#2 3:15 PM RCT ON BOTTOM;CALL TOWN TO CONFIRM:FIRE RCT AT 10173'. GOOD INDICATION OF FIRE,BUT TUBING DID NOT FALL. SET DOWN 3 TIMES THEN POOH. 4:30 PM OOH WITH RCT#2. 4:45 PM ELINE ON STANDBY WHILE I WORKED WITH PRODUCTION TEAM TO PRODUCE GAS OFF OF B1-36 TO SATISFY THE FACLITY AND COMPRESSOR NEEDS. 5:30 PM LAY DOWN ELINE 6:00 PM SECURE WELL AND TURN WELL OVER TO PRODUCTION FOR THE NIGHT. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD 253 (HRS) FROM 9/21115 WELL TEST) DEFERRED PRODUCTION PREVIOUS TOTAL PREVIOUS TOTAL COSTOOMPlealb (BBLS) DAILY TOTAL 253 DAILY COST 011111.11 19 319 CUM TOTAL 506 CUM TOTAL COST-ESTIMATED eitikaakab PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 55 DEGF N/A N/A N/A OPERATORS REP: Day DSM DANIEL CLARK Office (907)659-1236 Cell , email (907)978-4132 daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell email S Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 10/2312015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 4 3 10,182° 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative _ POLLARD SL UNITS HSE Accidents Incidents Spills COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 112.0 3.78 $423.36 POLLARD-SL SERVICES 8 $270 $2,180.00 POLLARD EL SERVICES(SERVICE CHARGE) $330.00 $0.00 $0.00 $0.00 $0.00 $0.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM RIG DOWN ELINE AND MOVE OVER. RIG UP SL. 8:10 AM RIH WITH SL;15'1 3/4"STEM AND 2.19"BLIND BOX. 8:30 AM ON BOTTOM;BEAT ON THE PLUG FOR ONE HOUR. SEE NO MOVEMENT BUT THE BOTTOM LOOKS HARD AND TOOLS ARE GETTING GOOD ACTION. 9:30 AM OOH WITH SL;ADD ANOTHER 5'1 3/4"STEM AND CHECK TOOLSTRING. 9:50 AM RIH WITH SL AND HEAVIER TOOLSTRING. 10:10 AM ON BOTTOM;BEAT ON THE PLUG FOR ONE HOUR. SEE NO MOVEMENT. 11:15 AM OOH WITH SL AND CHECK TOOLSTRING 11,30 AM RIH WITH SL AND THE SAME TOOLSTRING. 11:50 AM ON BOTTOM WITH SL AND BEAT ON PLUG FOR AN HOUR. STILL NO MOVEMENT. 1:00 PM OOH WITH SL. 1:15 PM RIG SL AND ELINE COMPLETELY DOWN OFF 81-36 AND TURN WELL OVER TO PRODUCTION. 2:00 PM RIG DOWN COMPLETE. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM 506 (HRS) 9/21115 WELL TEST) DEFERRED PRODUCTION PREVIOUS TOTAL PREVIOUS TOTAL COST111/111.11 (BBLS) DAILY TOTAL 80 DAILY COST 111110.111111 6 319 CUM TOTAL 586 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 55 DEGF N/A N/A N/A OPERATORS REP, Day DSM DANIEL CLARK Office (907)859-1236 Cell (907)978-4132 email daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell email Savant Alaska, LLC sArANT DAILY DRILLING/WORKOVER REPORT ALASKA DATE 10/24/2015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS My MD NUMBER OF MISRUNS Badami-B1-36 5 0 N/A 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0 POLLARD SL UNITS Accidents Incidents Spills I COMMENTS NO SPILLS.ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL POLLARD EL SERVICES(SERVICE CHARGE) $330.00 FLIGHTS FOR POLLARD ELINE CREW _ FROM BADAMI TO DEADHORSE VIA 70 NORTH $1,200.00 FROM DEADHORSE TO ANCHORAGE VIA AN AIRLINES 8813.98 80.00 80.00 80.00 So.o0 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION NO WELL WORK WAS PERFORMED ELINE CREW TRAVELED BACK TO ANCHORAGE WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM 586 0.1.111.11 (MRS) 9/21/15 WELL TEST) DEFERRED PRODUCTION PREVIOUS TOTAL PREVIOUS TOTAL COST (BBLS) DAILY TOTAL 0 DAILY COST 4.011.1116 0 319 CUM TOTAL 586 CUM TOTAL COST-ESTIMATED 0111.0.1.1111, PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A 55 DEGF N/A N/A NIA OPERATORS REP: Day DSM DANIEL CLARK Office (907)659-1236 Cell (907)978-4132 email danieLclark@savantalaska.com Night DSM DANIEL CLARK Office Cell email S • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/21/2015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS Mar MD NUMBER OF MISRUNS Badami-131-36 1 3 10,180' 0 Resent Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK •Daily 0.0 Cumulative POLLARD SL/EL UNITS HSF Accidents Incidents I Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 87.0 $3.78 $253.26 POLLARD-SL SERVICES 12 $270 _ $3,240.00 POLLARD-SL SERVICES-ADD HOURS 4 $108 - 5752.00 POLLARD-ELINE SERVICES - NO CHARGE _ - - $0.00 $0.00 $0.00 $0.00 $0.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 10,173.8'-10,179.1' 5(1'GAP BETWEEN GUNS) TUBING TAIL TUBING PUNCHER-O DEG PHASE PUNCH HOLES IN TUBING TAIL FOR RCT TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM RIG UP SL AND SPOT ELINE 6:45 AM RIH WITH SL DRIFT-2.24"GR TO THE XN NIPPLE 7:30 AM RIH WITH SECOND SL DRIFT-2.20"SWEDGE AND TAG DEBRIS ON TUBING TAIL PLUG. 8:40 AM LAY DOWN SL AND RIG UP ELINE 9:45 AM FLOW GAS FROM B1-36 TO PRODUCTION TO LOWER THE TUBING PRESSURE ENOUGH SO ELINE CAN RIH. BLEED TUBING PRESSURE FROM 1150 PSI TO 600 PSI. 10:15 AM RIH WITH ELINE-2"OD X 5'18 SHOT TUBING PUNCHER(.42'ENTRY HOLE)WITH DECENTRALIER MAGNETS,2 1/8"CCL AND WEIGHT BARS. 11:30 AM CORRELATE TUBING PUNCHER 11:50 AM FIRE TUBING PUNCHER AT 10,173.8'-10,179.1'. POOH AFTER FIRING TUBING PUNCHER AND BECOME STUCK IN THE XN NIPPLE AT 10,097'. ATTEMPT TO PULL FREE USING THE ELINE JARS BUT UNABLE TO GET ANY MOVEMENT. 230 PM PULL OUT OF THE WEAKPOINT AND POOH 3:10 PM RIG DOWN ELINE AND RIG UP.160 SL 6:00 PM RIH WITH.160 SL,15'O Fl 3/4"STEM AND JUC PULLING TOOL-PINNED WITH STEEL 6:30 PM LATCH FISH WITH JUC AND AFTER TWO ATTEMPTS TO PULL,SHEAR JUC. POOH 740 PM RIH WITH.160 SL 15'OF 1 3/4"STEM AND JDC PULLING TOOL-PINNED WITH BRASS 8:15 PM LATCH FISH AND PUT A 2000 LB OIL JAR LICK ON IT. PULL UP TO 3000 LBS AND FISH COMES FREE WITH OIL JAR LICK. (ABLE TO SEE ELINE JARS GO OFF AT 1500 LBS BOTH TIMES). 8:45 PM AT SURFACE AND VERIFY TOOLSTRING. BEGIN TO RIG DOWN ALL EQUIPMENT FOR THE NIGHT. 9:45 PM RIG DOWN COMPLETE. TURN 01-36 OVER TO PRODUCTION. WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL 0 PREVIOUS TOTAL COST (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION (BELS) DAILY TOTAL 184 DAILY COST ORPINIPPIP 14 316 CUM TOTAL 184 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A N/A N/A N/A WA OPERATORS REP: Day DSM DANIEL CLARK Office (907)855-1238 Cell (907)978-4132 email ddnie.0 dfk CSdvantdlaskd.Cull: Night DSM DANIEL CLARK Office Cell email S • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/22/2015 LEASE AND WELL NO. AFE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 2 5 11,920' 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0 POLLARD SL/EL UNITS Accidents Incidents Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 04 0 $3.78 $355.32 POLLARD-SL SERVICES 12 $270 $3,240.00 POLLARD-SL SERVICES-ADD HOURS 8 $108 51,188.00 POLLARD-ELINE SERVICES $28,025.50 Service Charge-Press Control-2-RCT-String Shot $0.00 $0.00 $0.00 Sow PERFORATION DETAILS RUN 9 PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM RIG UP SL(UNIT DID NOT START;PUT CHARGER ON BATTERIES) 7:30 AM RIH WITH SL DRIFT-2.3"HELICAL PARAFFIN CUTTER TO 6,000' B:30 AM OOH WITH SL AND BEGIN RIGGING UP ELINE AND STRING SHOT 9:15 AM RIH WITH ELINE STRING SHOT 11:25 AM SHOOT STRING SHOT AT 10,174'(CENTER OF STRING SHOT AT 10,174'). GOOD INDICATION OF FIRE.TAG TUBING TAIL PLUG. OOH WITH ELINE. WORK ON MODIFYING THE RCT"STOP". SHORTEN THE STOP BY ALMOST 2'WHICH GIVES US A LITTLE MORE ROOM TO WORK WITH IN THE 10'PUP WE WILL BE CUTTING. 1:00 PM BLEED OF THE TUBING PRESSURE TO PRODUCTION. 2:30 PM RIH WITH THE STOP ON SL. 3:30 PM SET THE STOP ON THE DEBRIS ABOVE TUBING TAIL PLUG. 4:00 PM OOH WITH SL AND BEGIN RIGGING UP ELINE FOR THE FIRST RCT RUN. 5:35 PM RIH WITH ELINE AND RCT#1 7:10 PM CORRELATE AND SHOOT RCT#1 AT 10,173'. GOOD INDICATION OF FIRE.TAG THE STOP;TUBING TAIL IS STILL THERE. POOH. 8:05 PM OOH WITH ELINE AND CHECK TOOLSTRING AND RIG UP RCT#2. 9:10 PM RIH WITH RCT#2 11 20 PM CORRELATE AND SHOOT RCT#2 AT 10,173'. GOOD INDICATION OF FIRE.PULL UP HOLE AFTER SHOT AND ATTEMPT TO SIT DOWN ON STOP BUT STOP IS GONE! DRIFT TO 11,920'. UPCOMING PERF INTERVALS ARE CLEAR AND CURRENT PERFS ARE CLEAR. DID NOT TAG TUBING TAIL IN CASING;SL WILL TAG TUBING TAIL ON 11/24/2015. 0:00 AM POOH 1:30 AM RIG DOWN ELINE. PARK UNIT IN THE SHOP FOR MAINTENANCE FIRST THING IN THE MORNING. 2:15 AM RIG DOWN COMPLETE. TURN 81-36 OVER TO PRODUCTION. 184 WELL SHUT-IN TIME DAILY PRODUCTION(80PD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 217 DAILY COST 4010111.10 17 316 CUM TOTAL 401 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL N/A N/A N/A N/A N/A OPERATORS REP: Day DSM _ DANIEL CLARK Office (907)659-1236 Cell (907)9784132 email daniel.clark@savantalaska.com_ Night DSM DANIEL CLARK Once Cell email • • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/23/2015 LEASE AND WELL NO. APE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 3 4 11,750' 0 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0 0 POLLARD SL/EL UNITS HSE Accidents Incidents Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 178.0 $3.78 $672.84 POLLARD-SL SERVICES 12 $270 $3,240.00 POLLARD-SL SERVICES-ADD HOURS 8 $108 $1,584.00 • POLLARD-ELINE SERVICES $16,188.80 Service Charge-Press Control-24 pert gun-Gamma ray-Eline Jars DIRTY DIESEL FOR WELL CLEANOUT 840.0 $2.01 $1,688.40 30.00 30.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 7 PSI CHANGE IN TUBING PRESS WAS NOTICED 1 11,676'-11,700' 24' 2 118"X 24'SNAKE STRIP GUNS AFTER SHOT TIME LOG TIME DESCRIPTION 5:45 AM DAILY OPS MEETING AND MORNING TOOLBOX 6:15 AM RIG UP SL FOR CLEANOUT RUN. 7:50 AM RIH WITH SL DRIFT-2.3"HELICAL PARAFFIN CUTTER TO 1080'AND UNABLE TO MAKE A HOLE. 9:15 AM ------- -------MOVE OVER TO B1-38 FOR CLEANOUT------------------------------------------_ 1:00 PM RIG BACK UP ON B1-36 AND PUMP DIESEL DOWN THE TUBING OF WHILE SL CLEANS THE TUBING WITH A GR AND A BLB. 3:00 PM FINISH MAKING UP PERF GUNS AND ELINE TOOLSTRING. 4:30 PM RIG DOWN SL AND RU ELINE FOR FIRST PERFORATION RUN. 5:45 PM PU UP TOOLSTRING AND STAB ONTO THE WELL.TAKE A WARM UP BREAK AS THE CREW IS STARTING TO SHOW SIGNS OF WEAR AND TEAR DUE TO COLD AND HIGH WINDS. 6:30 PM PT LUBRICATOR TO 3000 PSI WITH TRIPLEX. 6:50 PM RIH WITH FIRST PERF GUN. 9:00 PM PULL CORRELATION PASS AND GET TOOLSTRING ON DEPTH. 9:25 PM SEND LOGS TO TOWN FOR APPROVAL 9:45 PM PULL INTO POSITION AND PERFORATE 11676'-11700'. SEE AN INCREASE OF 7 PSI AT SURFACE AFTER FIRING GUN. 10:15 PM PULL INTO THE 2 7/8"WLEG AND BECOME STUCK. WORK TOOLS AND ELINE JARS WITH NO SUCCESS. 0:00 AM PULL OUT OF THE WEAK POINT 1:00 AM RIG DOWN ELINE. 2:00 AM RIG DOWN COMPLETE. LEAVE WELL SHUT IN FOR THE NIGHT. 401 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST 41011.11/1. (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 217 DAILY COST 1.3101.101. 17 316 CUM TOTAL 618 • CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A 1337 N/A N/A OPERATORS REP. Day DSM DANIEL CLARK Office (907)659-1236 Cell (907)978-4132 email daniel.clark@savantalaska.com Night DSM DANIEL CLARK Office Cell email • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT GATE 11/24/2015 LEASE AND WELL NO. AFE NO DAYS NUMBER OF RUNS Max MD NUMBER OF'AISRUNS Badami-B1-36 3 4 11,750' Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0 POLLARD SL/EL UNITS HSE Accidents Incidents Spills I COMMENTS NO SPILLS.ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 72.4 $3.56 $257.74 POLLARD-SL SERVICES 12 $270 $3,240.00 POLLARD-SL SERVICES-ADD HOURS3 $198 $504.00 POLLARD-ELINE SERVICES $750.00 Note:Eline cost is for the Double Centralizer Stop.(RC Stop) PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES TIME LOG TIME DESCRIPTION 7:00 AM Toolbox with crews. 730 AM Rig up.160 slickline and PT. 9:0o AM RIH with 2"JDC w/heavy skirt.Latched fish @ 10,031'slm.Jarred on fish twice to insure latch.Stand by for Dan and Art to C/O. 11:45 AM Continue fishing.Jarred for-2 hours.Sheared off and POOH. 14:45 PM Layed down checked tool string,rebuild oil jars with heavier oil and re-headed. 15:45 PM RIH with 2"JDC.Latched at 10,021'slm.Jarred up for-20 minutes.Fish started to move and came free.POOH 19:45 PM OOH with fish.Rig down both slickline and eline. 21:00 PM Location secured for the night. 401 WELL SHUT-IN TIME DAILY PRODUCTION(90PD FROM PREVIOUS TOTAL _ PREVIOUS TOTAL COST 21111011.1 (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 316 (BBLS) DAILY COST • 24 316 CUM TOTAL 717 CUM TOTAL COST-ESTIMATED 41111111111116 • PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A N/A N/A N/A 1 OPERATORS REP-. Day DSM ARTHUR HOFFMAN Office (907)659-1236 Cell (907)44&6011 email Arthur.Hoffman@savantalaska.com Night DSM ARTHUR HOFFMAN Office Cell email r • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/25/2015 LEASE AND WELL NO. APE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 5 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO B1-36 PERFORATION PREP WORK CumulatilE POLLARD SL/EL UNITS Accidents Incidents Spills I COMMENTS We had spots on the ground,that when cleaned up by HSE/ACS and documented,came up to-7/8th of a gallon.Protocal was followed,spill is documented and in report is in progress.This was due to not having enough pressure on the grease head while pulling out of hole. Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 26.7 $3.78 530.48 POLLARD-SL SERVICES POLLARD-SL SERVICES-ADD HOURS POLLARD-ELINE SERVICES 13 $26,474 40 Service Charge-Press Control-44'ped gun-Gamma ray-One Jars DIRTY DIESEL FOR WELL CLEANOUT 8 ASSIST ELINE OUT OF HOLE. 1260.0 $2 52,532.80 PERFORATION DETAILS RUN it PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 3 11,676'-11,632' 44' 2 118"X 13',15.5',15.5'SNAKE STRIP GUNS(3 shots fired) was after each shot.We can say the build up of This zone is completed. TIME LOG TIME DESCRIPTION 6:00 AM PJSM 6:30 AM Re-head,RU,Arm Gun.(13') 8:20 AM RIH while the SHOT pumped 20 bbls of hot diesel. 9:30 AM Run correlation pass 11750'-11500'.Run#2 perf2/passl 9:45 AM Send logs to Anchorage. 10.10 AM Pull into position @ 11656'(Tccl)to shoot 11663'-676'(13') 10:15 AM Fire gun.POOH.Well head dropped from-758 to-748 spi. 11:15 AM Hit paraffin/Hydrates©2550'.Pumped 10 bbls of hot diesel to free up and continue OOH. 11:25 AM Continue POOH. 11:45 AM OOH.MU Gun Run#3. 12:00 PM RIH with Gun#3. 13:05 PM Tie in log perf2/pass3 13:30 PM Send logs to Anchorage. 13:45 PM Run position pass perf2/pass4 @ 11647.5'ccl depth. 13:55 PM Shoot gun @ 11647.5-11663'.801 psi 15:05 PM OOH.MU Gun Run#4.(15.5') 15:30 PM RIH w/#4.(WH @ 1250 psi) 16:45 PM Cor pass perf4/pass4 17:00 PM Send in log to Anchorage. 17:28 PM Pull into position perf4/pass4. 17:30 PM Shoot gun @ 11632'-11647.5'.No change in WH. 18:51 PM OOH/rig down for the night. 717 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST NMI (HRS) 1111/15 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 316 DAILY COST 411111111116 24 316 CUM TOTAL 1,033 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A N/A N/A N/A OPERATORS REP. Day DSM ARTHUR HOFFMAN Office (907)65&123fi Cell (907)448-6011 email Arthur.Hoffman@asavantalaska.com Night DSM ARTHUR HOFFMAN Office Cell email • Savant Alaska, LLC SA ANT ALA�aKA DAILY DRILLING/WORKOVER REPORT DATE 11/26/2015 LEASE AND WELL NO. APE NO. DAYS NUMBER OF RUNS Max MD NUMBER OF MISRUNS Badami-B1-36 6 Present Operatoll NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative U.0 POLLARD SL/EL UNITS HSE Accidents Incidents Spills I COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 65.3 $3.78 $24683 POLLARD-SL SERVICES 8 $270 $2,180.00 POLLARD-SL SERVICES-ADD HOURS 2 $108 $366.00 POLLARD-ELINE SERVICES $0,558.80 SerOce Charge-Press Control-1S pert gun-Gamma ray-Eline Jars Seruce Charge-Press Control-2-RCT-String Shot $28,025.50 DIRTY DIESEL FOR WELL CLEANOUT&ASSIST ELINE OUT OF HOLE. 840.0 $2 $1,688.40 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 11,626'-11,611' 15" 2118"X 15.5'SNAKE STRIP GUNS shut in. J started to climb slowly,bot consistently.Our well head TIME LOG TIME DESCRIPTION Eline Log 6:00 AM PJSM-Well PS=1643 psi 7:30 AM Bleed pressure down to 1100 psi. 9:00 AM Stab lub&15'gus 9:05 AM Pump 20 bbls of hot diesel.Well head dropped to—358 psi. 9:25 AM RIH 10:30 AM Run tie pass petf5/pass3 10:45 AM Send log to town 11:00 AM Pull into position @ 11604(ccl depth)+Shoot @ 11611'-626'(15'). 11:07 AM Fire gun.POOH 647 psi/651 psi. 11:30 AM Stuck in tailpipe.(670 psi @ 11:10 am)(726 psi 0 11:19)(819 psi @ 11:30). Jars-3800#/Rope socket-4200#. 11:55 AM Pulled out o rope socket.POOH 0 10,080'. 13:00 PM OOH.RU Slickli Te. 21:00 PM Pulled fish on bank! Slickline Log 12:30 PM Assist eline in RJ.RU.160 wire to fish with. 13:00 PM Toolbox with elire on job. !4:30 PM RIH with 2"JDC w/heavy skirt.Latch fish 0 10,057'slm.Fish is moving up hole.3 hours of jarring.Shear off to check on toolstring. 18:00 PM 00H.Check toc.lstring and re-dress JDC. 18:30 PM RIH w/same.LEtch 0 10,037'slm.Worked fish until it came free.POOH with fish. 21:30 PM OOH with fish.FM eline and slickline for the night. 22:30 PM R/D completed. NOTE:I have added the cost of cutting of the tail pipe to this Report.The amount is$28,025.50 1,033 — WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST 411111111. (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION DAILY TOTAL 316 (BBLS) DAILY COST 10/1.0.11110/116 24 316 CUM TOTAL 1,349 CUM TOTAL COST-ESTIMATED 141111/20 PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A N/A N/A N/A OPERATORS REP: Day DSM ARTHUR HOFFMAN Office (907)659-1236 Cell (907)44&6011 email Arthur.Hoffman@savantalaska.com Night DSM ARTHUR HOFFMAN Office Cell email • • Savant Alaska, LLC SA ANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/27/2015 LEASE AND WELL NO. BEE NO. DAYS NUMBER OF RUNS Mar MD NUMBER OF VISCOUS Badami-B1-36 7 Present Operation NON PRODUCTIVE$11.E CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 Cumulative 0.0 POLLARD SL/EL UNITS NSF - Accidents Incidents Spills COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 65.6 $3.78 $247.97 POLLARD-SL SERVICES 3 $270 $810.00 POLLARD-SL SERVICES-ADD HOURS 3 $195 $594.00 POLLARD-ELINE SERVICES $19,52200 Service Charge-Press Control-15'pert gun-Gamma ray(Only 1 run)-Eline Jars DIRTY DIESEL FOR WELL CLEANOUT&ASSIST ELINE OUT OF HOLE. 12000 $2 $2,520.00 PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 2 11562'-82',11530'-50' 40' 2118"X13',15.5',15.5'SNAKE STRIP GUNS(2 shots fired) hour build up from 1190 psi. TIME LOG TIME DESCRIPTION Eline 6:00 AM RU eline&20'gun#6. 7:30 AM RIH with a well head of 1681 psi. 9:00 AM Tie in @ packers. 9:45 AM Tie in @ perfs. 10:10 AM Send log to Anchorage. 10:45 AM Position @ 11560 ccl to shoot @ 11562'-82'.(20') 10:47 AM Shoot,1619 psi/1621 psi after. 11:50 AM OOH.RU gun run#7. 1220 PM PU 20'gun. 12:25 PM RIH.Well head @ 1725 psi. 13:20 PM Tie in @ packers perf7/pass2. 13:40 PM Tin in @ perfs perf7/passl. 14:20 PM Pull into jposition @ 11528'ccl depth&shoot @ 11530'-50'.1791 psi/1794 psi after.Pass3 20'. 1425 PM POOH. 14:40 PM Stuck @ WLEG. 14:50 PM Pulled out of head @ 10080'at 3800#POOH. 15:30 PM L-111d AWI.n DI yrnASe 11ROU L Iw. LOOMro.3 RI11pleu w u .700 11/111/000o 11.Valve 1a u111 dIlu W111111/STI1111/1 aone.JIIUI tri 4Y1-V a dIIO UICCU WWII.WII.0165/1/N Well 110611 116 dU 11110,10651111$ 1/1JUI.d'1 1611 101 B0111y un 10 clinkline to fich Nllre Wind is 10,06011 neer An mnh Ctnnninn nneratinnc and cor-,1rinn w011,mfil.e cher nermitc 21:00 PM Well secured for night. 1,349 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST (HRS) 1111115 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 316 DAILY COST 24 316 CUM TOTAL 1,665 CUM TOTAL COST-ESTIMATED IMMO PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A N/A N/A N/A OPERATORS REP: Day DSM ARTHUR HOFFMAN Office 907 659-1236 Cell I email ( ) 907)006 so11 Arthur Hotfman a savantalaska COM Night DSM ARTHUR HOFFMAN Office Cell email # S Savant Alaska, LLC SAVANT ALASKA DAILY DRILLING/WORKOVER REPORT DATE 11/27/2015 LEASE AND WELL NO. AFE NO DAYS NUMBER OF RUNS Mar MD NUMBER OF MISRUNS Badami-B1-36 7 Present Operation NON PRODUCTIVE TIME CONTRACTOR AND RIG NO. B1-36 PERFORATION PREP WORK Daily 0.0 POLLARD SL/EL UNITS Accidents Incidents Spills COMMENTS NO SPILLS,ACCIDENTS OR INCIDENTS Safety Walk Around Day Safety Walk Around Night Daily Costs DESCRIPTION HOURS COST PER HOUR GALLONS COST PER GALLON TOTAL DIESEL FOR POLLARD UNITS 24.7 $3.78 $93.30 POLLARD-SL SERVICES 12 $270 $3,240.00 POLLARD-SL SERVICES-ADD HOURS POLLARD-ELINE SERVICES $12,102.00 Service Charge-Press Control-25'per(gun-Bine Jars PERFORATION DETAILS RUN# PERFORATION INTERVAL TOTAL FT PERFORATED PERFORATION ZONE TYPE OF GUN NOTES 1 11475'-11500' 25' 21/8"X 13',25'SNAKE STRIP GUNS psi.There was no significant build up that we TIME LOG TIME DESCRIPTION Slickline coo AM R/U.160 slickline and toolstring with BHA and fished out the dine cable. 11:45 AM RIH with a 2"JDC w/heavy skirt.Latched fish @ 10,068'slm.Start jarring! 15:00 PM Fish is out of nipples and moving up hole with heavy drag!54 jars at and average of 3200#. 15:40 PM OOH with fish.We recovered the whole shot.R/D,clean up area and switch over to eline. 16:15 PM Assist eline with Ft/U. 20:00 PM Assist eline with R/D,securing well and cleaning up location. 21:00 PM Day completed. ELINE 5:00 AM R/U to extract 150'of dine cable. 11:45 AM Fishing cable completed.R/U slickline to fish dine toolstring. 13:30 PM R/D slickline and R/U eline. 16:45 PM MU 25'strip gun.RIH w/a 750 psi well head pressure. 17:45 PM Packer tie-in perf8/pass3. 18:00 PM Perf tie-in perf8/passl. 18:15 PM Send logs to Anchorage. 18:40 PM Bleed well down to 900 psi under 1000 psi.(Per Conrad)Pull into position @ 11473'(ccl depth)(911 psi). 18:45 PM Shoot gun @ 11475'-11500'.POOH(916psi) 19:45 PM R/D. 1,665 WELL SHUT-IN TIME DAILY PRODUCTION(BOPD FROM PREVIOUS TOTAL PREVIOUS TOTAL COST (HRS) 11/1/15 WELL TEST) DEFERRED PRODUCTION (BBLS) DAILY TOTAL 316 DAILY COST 24 316 CUM TOTAL 1,981 CUM TOTAL COST-ESTIMATED PRE-PERF SI WELLHEAD PSI PRE-PERF FLOWING TEMP POST-PERF SI PSI POST-PER TEMP DAYS SINCE LAST LTA: LAST SPILL 1,330 N/A N/A N/A N/A OPERATORS REP: Day DSM ARTHUR HOFFMAN Office (907)659-1236 Cell (907)448-6011 email Arthur.Hoffman@savantalaska.com Night DSM ARTHUR HOFFMAN Office Cell email • • • LOF ?If I y/��sV THE STATE Alaska Oil and Gas Conservation Commission o fALASKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 F ALASP Fax: 907.276.7542 www.aogcc.alaska.gov Conrad Perry Drilling Manager JAN 1 12.016 Savant Alaska, LLC 601 W. 5th Ave., Ste. 310 f 1 Anchorage, AK 99501 Re: Badami Field, Badami Oil Pool, B 1-36 Sundry Number: 315-516 Dear Mr. Perry: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this � d y of September, 2015 BDM SEp 11 2015 Encl. RECEIVED • STATE OF ALASKA AUG 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION off' <<1 I S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate 2• Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Savant Alaska LLC Exploratory ❑ Development ❑✓ 198-232 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th Avenue,Suite 310 Anchorage,AK 99501 50-029-22933-00-00 ' 7.If perforating: 6, 7 / 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 2 S75 J4. >r‘` B1-36 . Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): 4 t) L. 365533 ,,n� E•‘- '''15--- Badami Field, Badami Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ` 15546 > 12729 15440 12623 14060 /12384(w.l.plug) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' N'A N/A Surface 4,518' 13 3/8" 4,554' 4,505' 5020 2270 Intermediate 10,211' 9 5/8" 10,244' 8,962' 5750 3090 Production 12,403' 7" 12,433' 10,599' 11220 8510 Liner 3,102' 4 1/2" 12338-15440 10565-12623 8440 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11700-11860 10245-10345 4.5" L80 10,097' Packers and SSSV Type: 7"x 2 7/8"HES Pkr/TMAXX-5E Packers and SSSV MD(ft)and TVD(ft): Pkr @ 10063/8744 TVD-SSSV 2215'/2149' 12.Attachments: Description Summary of Proposal ❑✓ • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ • Service ❑ 14.Estimated Date for 14-Sep-15 15.Well Status after proposed work: Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stephen Ratcliff Email stephen.ratcliff( cookinlet.net Printed Name cgd perry Title Drilling Manager Signature •..7 . Phone 907-727-7404 Date July 30th,2015 COMMISSION USE ONLY Conditions of approval: N6tify Commission so tha'. representative may witness Sundry Number: I -- c' Ut Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ J Other: Spacing Exception Required? Yes ❑ No LTJ Subsequent Form Required: /0 `'/0 it APPROVED BY / i Approved by: _ COMMISSIONER THE COMMISSION Date: g—/( '/S RBSn� Submit Form and . c- _.%.151 r v�d�gpI a� id for 12 months from the date of approval. Attachments in Duplicate s • RECEIVED AUG 2 1 2015 MI Miller AOGCC Energy August 21St, 2015 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage,Alaska 99501 RE: Sundry Application Savant Alaska LLC: 50-029-22933-00-00 Dear Ms. Foerster, Miller Energy Resources, Inc as manager of Savant Alaska LLC hereby submits a sundry for Badami B1-36, PTD: 198-232 requesting permission to add perforations to increase production. If you have any questions, please contact me at 907.433.3804. Sincerely, Conrad P rry Drilling Mang- Miller Energy Resources, I c. as Manager of Savant Alaska, LLC 1 • • 1. WELL NAME - Badami B1-36 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is currently producing. There is a 7" x 4 1/2" packer/tailpipe below the 2 7/8" completion with a 4 1/2" wireline plug in it. The tail pipe was perforated for production above the plug. A split shot was fired also above the plug, but the tail pipe did not fall. The plug/tailpipe must be dropped to add perfs. Current Perforations MD TVD 11700' - 11860' 10245' - 10345' Scope of Work: • Clean up tubing with slickline brushes and diesel washes • Shut well in. ./ • Rig up eLine. Test Lubricator to 5000psi • Fire string shot across split collar. Repeat if necessary • Gauge well to bottom perf at 11,700' minimum. Tag and report fill if any. • Perforate with 2" guns, recording wellhead pressure after each run 7 • Rig down. Flow well General Well Information: Reservoir Pressure /TVD: 7171psi @ 10,245' TVD (.70 psi/ft) MASP: 4866 psi (Half oil/Half gas) 7171 psi - (5123'well with .35 psi/ft oil) -( 5122'with .1 psi/ft gas gradient) 4866 psi = 7171 psi - 1793 psi -512 psi Wellhead Type/Pressure Rating: 11" Multibowl 5K Wellhead Well Type: Oil Well Estimated Start Date: September 15th, 2015 CIE Drilling Manager: CIE Sr. Drilling Engineer: CIE Production Manager: Conrad Perry Stephen Ratcliff David Kumar (907) 727-7404 (907) 433-9738 (907) 433-3822 conrad.perry@CookInlet.net Stephen.Ratcliff@CookInlet.net David.Kumar@CookInlet.net 3 • Program 1) Clean up well bore with slick line/diesel washes. 2) Recover SSSV. 3) Make dummy run with 2" gauge ring and sinker bars to 10,164' (4 '/2"Xplug) 4) Shut well in. 5) Rig up eLine. Test lubricator to 5000 psi. 6) Make GR/CCL run to top of 4 '/2" plug. Attempt to correlate to previous split shot run. 7) Assuming that the split shot area is clear, make up a string shot and run in hole across the collar. 8) Fire the string shot and check to see if tail pipe fell. Repeat again if unsuccessful. a) The goal is to leave a clean pin looking down to prevent bird nesting the eLine. 9) Make dummy run to bottom perforations to ensure casing is clear. 10)Perforate with 2" carrier guns 6 SPF as follows: a) 11475-11500 25' b) 11530-11550 20' c) 11562-11582 20' d) 11610-11626 16' e) 11632-11700 68' NOTE: be aware that any of these zones may be virgin pressure. It appears that the original perforating was done with a full column of unknown fluid and 1100 psi WHP without issue. 11)Evaluate whether to re-perforate original zones. 12)Re-install SSSV. 13)Place well back on production 4 I► 0 0 • Current Badami B1-36 Schematic Drill Floor to Ground Level 41.5 referenced to Doyon Rig 15 Drill Fborto Tubng Hanger 22.0 referenced to Doyon Rig 15 OD ID weight Length MD ND Ground Level to Sea Level 19.5 1Abllhead 13-5/8710,000 psi-Manufactured by FMC inch inch Lbs/ft ft DF SS J L Tree 4-1/16710,000 psi-CNV Conductor 20.000 19.124 91.1 80 118 38 2-7/8"6.5#L-80 EIDE Tubing 2.875 2.441 6.5 10143 10143 8817 13° O < TMAXX-Se SCSSSV 4.750 2.313 WA 4.19 2215 2149 A , 13-3/8"68#L-80 BTC 13.375 12.415 45.5 4518 4554 4449 4° 11 I GLM#4 CAMCO KBMG 1"LGLV Model BK w/1/4"Fbrt 4.750 2.313 6.98 4562 4460 44° II I GLM#3 CAMCO KBMG 1"LGLV Model BK w/1/4"fort 4.750 2.313 6.96 7819 6941 31° 4 I GLM#2 CAMCO KBMG w/Durmy GLV 2-7/8"x 1" 4.750 2.313 6.97 9886 8588 II I GLM#1 CAMCO KBMG 1"LGLV Model BK w/1/4"Fbrt SAD 4.750 2.313 6.99 10009 8695 26° HES 2-7/8"x 7"PFIL Packer 5.980 2.360 23-29 0.35 10063 8744 FES"X"Kipple 2-7/8"6.5#9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8761 FES"XM Fipple 2-7/8"6.5#9CR EUE w/2.313 PKG Bore 3.680 2205 6.5 1.30 10097 8773 r.jil WLEG 2-7/8"9.2#9CR IBT-M Box Top of cutoff 4'h"tibing scrub10101 8777 B , , Baker Fbrmmnent Packer 3.875 10141 8815 y�); __...r.: Tubb Tail perforations 10146'-10158' 3.900 3.813 10164 8835 I'"✓ l XNipple9CR�3.813" G� Bottomof argnal434"tubng(EDT}._ _ 10176 8846 T Mal 9-5/8"L-80 Intermediate Casing Shoe 9.625 40 10211 10244 8911 I , Brookian Fbrfarations 11700-11860-(ltxyr, , T x 4-1/7 Liner Hanger Packer 12338 10522 II F ES X Npple 9CR ID 3.813" 7.625 3.813 12384 10533 7"29#/ft P110 BTC Casing Shoe 7.000 29 12403 12433 10547 Kilian Fbfarations 13840-13890-I'tAgsxt ,'1" I1 Max intim Dev"rvtion 12445 10549 Baker aBP set at 14,060' 14060 11350 Kekiduk Pbforations 14896-14936-11)99(x - 4-W'17#L-80 BTC-M Liner 15540 12672 No. Rev.by Corments/Date B 1-36 1 G.Vgi Initial configuration(5/11/2010) Badami Unit 2 E Opstad Edl GLM graphic&add ND values to schematic(05-14-10) API No.50-029-22933 3 E Opstad Add top 4X"tubing stub at 10,101'MD&bottom(EDT)at 10,176'MD(06-24-10) 4 E Opstad Static Survey Data:SBHP2,445 psi,SBF IT 151•F Q 8,830'TVD(Run 8/31/10) Revised 7/31/2015 5 5 R Berube Updated 30 Aug 12 6 CJR1' Corrected 2 7/8"pkv to T SAT1ANT ALASKA /?8-a23/Z_ bp • • Date 09/09/2015 C> 62 3 a Vo Transmittal Number: 93455 0 BPXA WELL DATA TRANSMITTAL RECEIVED SEP 092015 Enclosed are the materials listed below. AOGCC (BPXA LOG DATA) If you have any questions,please contact Analisa Steger at the PDC at 564-5439 Delivery Contents 1 CD-ROM Containing Mudlog ASCII Digital Data for B1-36. There are also 2 pdfs which are just copies of the labels of the floppy disks (which has the format, rig, well, inclusion, and location). Note: There were 2 floppy disks combined into 1 CD. Disk 1 has the DB_ascii.doc that enables one to read the ASCII data. Please Sign and ' z turn one copy of this transmittal to; gancpdc@bp.cm Analisa Steger Petrotechnical Data Center SCOW MAY 0 2 2016 Attn: State of Alaska - AOGCC Attn: Meredith Guhl 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 • • 06;a 3� Date: 12-20-98 Disk: 1 of 1 t, BPX ALASKA,Inc. DS1 Format: ASCII of d.(see Db_ascii.doc RECEIVED Self Extractive rc ive Rig: Nabors 28E API:50-089-22899 SEP 0 9 2015 Well: Badami B1-36&B1-36 ST Inclusions: BI,CG,CO,DR,FE,GC,GE,LA,LI, /\OGCC LO,MU,RE,RU,SU �'"� Location: Lat 70:09:08.55"Long: 147:05:33.996" Footage From 8200' to 11876' Rev: Duplicate Copies for Delivery Assurance RECEIVED SEP 092015 AOGCC Date: 12-20-98 Disk: 1 of 1 DirjK, BPX ALASKA,Inc. Unit: 40087 Format: Sperry-Sun Documents l Rig: Nabors 28E API:50-089-22899 Well: Badami B1-36&B1-36 ST Inclusions: ADT,GEMS,DOCS Location: Lat 70:09:08.55"Long:147:05:33.996" Footage From 118200'to 11876' Rev: Duplicate Copies for Delivery Assurance 9 2 32 Guhl Meredith D (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, September 08, 2015 1:56 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: RE: Core data from Badami B1-36 (PTD 198-232) Meredith, We've researched through our archives, and also checked with our core store. We've reviewed the inventory of what was submitted to GMC and only see core chips. We cannot find any analysis done on those chips in our records. To the best of my knowledge and ability we do not have any core data. Thank you, Joe Lastufka SCANNED ',f i 1) 9 Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 ONO BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788D1Anchorage,AK From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, August 11, 2015 10:28 AM To: Lastufka, Joseph N Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA) Subject: Core data from Badami B1-36 (PTD 198-232) Hello Joe, I wonder if BP can assist me with my request. It was noted that cores were taken in Badami B1-36, but no data related to the cores was submitted to the AOGCC.The cores are now at the GMC, as shown on the inventory. Does BP have the core data, and if so, could BP please provide the data as required by regulation? I have contacted Savant Alaska, but haven't received a response at this time. If you have any questions, please contact me. Thank you, Meredith 1 Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Thursday, June 11, 2015 11:10 AM To: 'mary.rush@savantalaska.com' Cc: Davies, Stephen F(DOA); Bettis, Patricia K(DOA) Subject: Core data from Badami B1-36 (PTD 198-232) Mary, Per the Well Completion report for B1-36 (attached) it appears that cores were taken in the Killian Interval and the Kekiktuk Interval.Also the GMC inventory(attached) reports 3 cores from Badami B1-36. The applicable regulation, 20 AAC 25.071,at the time of the well completion, required (b)(3) a lithologic description of all cores and a chip or chips from each foot of recovered core and (b)(7) a copy of all drill stem test data and charts;core analysis determinations of porosity, permeability and fluid saturations;and formation water analyses obtained by the operator(regulation attached). After reviewing the AOGCC records I am unable to locate any data related to the cores taken in this well, including lithologic descriptions or core analysis as required by regulation. Please supply the required information. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning pro)ect. 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: z.//-Z~ ~/~,~//~ Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA ,/~ Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by.Mildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha ~n Lowell Date: STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS RECEIVED ~IAY 2 ~ 210 1. Operations Abandon Repair Well Plug Perforations Stimulate Performed: Alter Casing ^ Pull Tubing (] Perforate New Pool^ Waiver ^ Time Extension ~~LM's Change Approved Program ^ Operat. Shutdow^ Perforate ^ Re-enter uspended Well ^ 2. Operator 4. Well Class Before Work: .Permit to Drill Number: Name: Savant Alaska, LLC Developmentl~ Exploratory ^ 198-232 3. Address: PO Box 112212 Anchorage, AK Stratigraphic ^ Service ^ .API Number: 99511-2212 029-22933-00-00 7. Property Designation (Lease Number): ~ 8. Well Name and Numbe\ ADL 365533 B1-36 9. Field/Pool(s): Badami Field Badami Oil Pool 10. Present Well Condition Summary: Total Depth measured 15,546 feet Plugs (measured) 14,060 feet true vertical 12,729 feet Junk (measured) None feet Effective Depth measured 15,440 feet Packer (measured) 10,063 feet true vertical 12,623 feet (true vertical) 8 798 feet Casing Length Size MD TVD Burst Collapse Structural Conductor $0' 20" 91.1 # H-40 118' 118' 1,490 470 surface 4,518' 133/x" 68# L-80 4,554' 4,505' 5,020 2,270 Intermediate 10,211' 9%8" 40# L-80 10,244' 8,964' 5,750' 3,040 Production 12,403' 7" 29# P-110 12,433' 10,593' 11,220 8,510 Liner 3,102' 4%" 12.6# L-80 12,338' - 15,440' 11,565' - 13,623' 8,440 7,500 Perforation depth: Measured depth: 11,700'-11,860' 13,840'-14,936' NOTE: 4h"tbg. tailpipe is perforated from 10,146'to 10,158'MD True Vertical depth: 10,245'-10,345' 11,242'-12,132' Tubing (size, grade, measured and true vertical depth): 2-7/8" EUE 6.5# L-80 10,143' MD 8,870' TVD Replaced pulled 4/"tubing Packers and SSSV (type, measured and true vertical depth): 2-7/8" x 7" HES PHL 10,063'MD (8,798' TVD 2-7/8" TRMAXX-5e 2,215' MD 2201' TVD 4%:" x 7" Baker 10,141'MD ~ 8,869' TVD 11. Stimulation or cement squeeze summary: None Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: None 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-in Shut-in Shut-in 0 0 Subsequent to operation: Shut-in Shut-in Shut-in 0 0 13. Attachments: .Well Class after work: Copies of Logs and Surveys Run Well Schematic Exploratory ^ Development ~' Service ^ Daily Report of Well Operations IADC Tour Reports .Well Status after work: Oil ~ Ga WDSPL GSTOR^ WAG^ GINJ^ WIND SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-063 contact Erik Opstad or Gary Hammon Printed Name Erik O stad Title General Manager Signature Phone 244-5210 or 868-1258 Date 15-May-10 Form 10-4 'sed 7/2009 Submit Ori final Only. S Z~ - lJ ~~~~~~ • referenced to Doyon Rig 15 Wellhead 13-5/8"/10000 si/FMC OD inch ICS inch Weight Lbs!ft Length ft iv1D DF TVD #t Tree 4-1/16"/10000 psi/CIW Conductor 20.000 19.124 91.1 80 118 118 2-7/8" 6.5# L-80 EUE Tubing 2.875 2.441 6.5 10143 10143 8870 TMAXX-5e SCSSSV 4.750 2.313 N/A 4.19 2215 2201 13-3/8" 68# L-80 BTC 13.375 12.415 45.5 4518 4554 4505 GLM CAMCO KBMG w/dgly 2-7/8" x 1" 4.750 2.313 6.98 4562 4512 GLM CAMCO KBMG w/dgly 2-7/8" x 1" 4.750 2.313 6.96 7819 6995 GLM CAMCO KBMG w/dgly 2-7/8" x 1" 4.750 2.313 `' 6.97 9886 8641 GLM CAMCO KBMG w/dgly 2-7/8" x 1" 4.750 2.313 6.99 10009 8749 HES 2-7/8" x 7-5/8" PHL Packer 5.980 2.360 23-29 0.35 10063 8798 HES "X" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.313 6.5 1.26 10083 8816 HES "XN" Nipple 2-7/8" 6.5# 9CR EUE w/2.313 PKG Bore 3.680 2.205 6.5 1.30 10097 8828 WLEG 2-7/8" 9.2# 9CR IBT-M Box Baker Permanent Packer 3.875 10141 8869 ubing Tail perforations 10146-10158' 3.900 3.813 10164 8914 HES X Nipple 9CR ID 3.813" 9-5/8" L-80 Intermediate Casing Shoe 9.625 40 10211 10244 8964 Brookian Perforations 11700-11860' -Open 7" x 4-1/2" Liner Hanger Packer 12338 10575 HES X Nipple 9CR ID 3.813" 7.625 3.813 12384 10615 7" 29#/ft P110 BTC Casing Shoe 7.000 29 12403 12433 10593 Killian Peforations 13840-13890 -Plugged Baker CIBP set at 14,060' ,/ 14060 11450 Kekiktuk Peforations 14896-14936 -Plugged 4-''/2" 17# L-80 BTC-M Liner 15540 13723 No. Rev. by Comments/Date 1 2 G. Vigil E. Opstad Initial (5/11/2010) Edit GLM graphic & add TVD (05-14-10) Badami Unit API No. 50-029-22933 ~..' ~#-'~1~11"VT" __ __ ALASKA Drill Floor to Tubing Hanger 22.0 ~ U ~" 10 HALLIBURTDIV Clinton Johnson, Service Specialist 2805 Spine Road Prudhoe Bay, Ak 99734 (907)-659-2805 Customer SAVANT Customer Representative GARY HAMMON Well 61-36 Field BADAMI Dale 03/21/10 9 Casing Size 9-5/8" Casing Weght 53.5# Casing Grade L-80 From SURF To 10,244' Tutting Size 2-7/8" Tubing Weght 6.5# Tutting Grade L-80 Tubing Threatl EUE - - Casing Size 7" Casing Weght 29# Casing Grade L-80 From SURF To 12,433' Pick Up Weght 145k Down Weght 130k Block Weght SOk Weght on Locator N/A Liner Size 4-1/2" Liner Weight 12.6# Liner Grade L-80 From 12,338' To 15,440' Release 54,6001bs Cen[er of Pkr. Elem. 10,065' Original RT-LDS 35.25' PBTD 15,440' Mac. Deviation 70 DEG 12,414' Deviation Thru Peril 54 DEG KOP Release 54,6001bs Center of Pkr. Elem. 10,065' r Completion Fluitl 6.8#DIESEL BHT BHP Pertorations 11,700'-11,860' 13,840'-13,860' 13,870'-13,890' 14,896'-14,936' Item # Descri tion I.D. O.D. Len th De th 7 RKB 35.25 0.00 11 13-5/8" x 4.5" FMC HANGER TC-II BOX TOP AND BTM 3.900 13.47 0.69 35.25 4.5" 12.6# L-80 X-OVER PUP JT TC-II PIN x IBT PIN 3.958 4.53 2.33 35.94 10 X-OVER 4.5" IBT x 2-7l8" EUE 2.441 5.200 1.50 38.27 2-7/8" 6.5# L-80 EUE TBG JT #251-320 (# of jts=70) 2.441 3.68 2167.57 39.77 g 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.10 2,207.34 9 2-7/8" TMAXX-5E SSSV W12.313 X-PROFILE 8rd EUE BxP 2.313 4.75 4.19 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.05 2,219.63 2-7/8" 6.5# L-80 EUE TBG JT #176-250 (# of jts=75) 2.441 3.68 2326.71 2,227.68 5 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.08 4,554.39 8 2-7/8" x 1" GLM CAMCO KBMG W/DGLV PN 100164401 2.347 4.75 6.98 2-718" 6.5# L-80 EUE PUP JT 2.441 3.68 8.10 4,569.45 2-7/8" 6.5# L-80 EUE TBG JT #72-175 (# of jts=104) 2.441 3.68 3233.11 4,577.55 I 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.05 7,810.66 =1- ''~ j 7 2-7/8" x 1" GLM CAMCO KBMG W/DGLV PN 100164401 2.347 4.75 6.96 4 2-718" 6.5# L-80 EUE PUP JT 2.441 3.68 8.04 7,825.67 2-7/8" 6.5# L-80 EUE TBG JT #3-71 (# of jts=69) 2.441 3.68 2143.80 7,833.71 ' 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.06 9,977.51 6 2-7/8" x 1" GLM CAMCO KBMG W/DGLV PN 100164401 2.347 4.75 6.97 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.19 9,992.54 3 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 7.99 10,000.73 5 2-7/8" x 1" GLM CAMCO KBMG W/DGLV PN 100164401 2.347 4.75 6.99 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.20 10,015.71 2-7/8" 6.5# L-80 EUE TBG JT #2 2.441 3.68 31.32 10,023.91 2 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.19 10,055.23 4 PHL PACKER 2-7/8" x 7" 23-29# PN 68266 2.360 5.98 5.35 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 8.18 10,068.77 2-718" 6.5# L-80 EUE PUP JT 2.441 3.68 6.12 10,076.95 3 X-NIPPLE 2-7/8" 6.5# 9CR EUE W/2.313" PKG BORE 2.313 3.68 1.26 1 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 6.16 10,084.33 A 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 6.18 10,090.49 2 XN-NIPPLE 2-7/8" 6.5# 9CR EUE W/2.313" PKG BORE 2.205 3.68 1.30 B 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 6.14 10,097.97 2-7/8" 6.5# L-80 EUE TBG JT #1 2.441 3.68 31.16 10,104.11 2-7/8" 6.5# L-80 EUE PUP JT 2.441 3.68 6.13 10,135.27 _ 1 WLEG 2-7/8" 6.5# 9CR EUE BOX 2.441 3.68 1.33 C EOT 10,142.73 EXISTING LOWER COMPLETION A 4-1/2" TUBING STUB 3.992 10,101.00 B 7" x 4-1/2" BAKER PERM. PACKER 3.875 10,141.00 p C 4-1/2" X-NIPPLE W/3.813" PKG BORE 3.813 10,164.00 D 4-1/2" X-NIPPLE W/3.813" PKG BORE 3.813 12,384.00 E BAKER CIBP 0.000 14,060.00 E NOTES ' EOT MEASUREMENT 10.132' DRILL PIPE MEASUREMENT ' # OF CANON CONTROL LINE CLAMPS: COLLAR=25 MID JOINT=24 # OF SIS BANDS=1 BELOW HANGER No. 393663158156 DAILY DRILLING REPORT REPORT N0. 1 LEASE WELL N0. WELL NUMBER waTERtEmH DATE BADAMI ADL365533 ! B1.36 50-029.22933-00-00 12lAas oPERAroR courRACroR No SAVANT ALASI(A, LLC Doyon Drilling Inc 15 SIGNATURE OF OPERATOR'S REPRESENTATIVE SKiNATURE OF CONTRACTORS TOOL PUSHER Garv Hammon Steve Dambacher I John Rolland TWE1HaTPoSUTaDN LtlDOB CPEPATX]N Nltl N PIG UPAro rEARpgNN 2 pNILLACTUPI 9 FEAMNG • w coRNG caromoxxuD E flCmWIAiE fi TRIPS , weRlcArE Rlc B PEPNRPIG cur GFA 9 DAILLND LNE 10 DEVIArIUN6URVE it WIAEU1E L035 Rux cnwxc 138CFMEM 13 WArt GN CFMENi II NIPPLEIx BO P. ~nesr sGP I6 DRRL 610A rE61 1)PLUG aACH tB GOUEEZE CEMENr 19 FISHING 2001R.WDRx art RECORD _ BIT NO. TIME SV.E WEIGI IAOC CODE PRES; MANUFACTURER GRADI TYPE fUNNI wsco SERIAL NO. pvttp JETS GEL TFA STREI DEPTH DUT FLUID LOSS DEPTH IN TOTAL DRILLED pH TOTAL HOURS SOLID CUTTING STRUCTURE INNER WiER DULL CHAR IOLAixw TYP BBAWNGGI SEALS GAGE OTHER DULLCHAR REA9IN1 PULLED MUDtffiCORD xx e. ruslxG mlPs c mEarwc o. swAaelxG E. rssrn+c TOTAL DAVWORK _ NG Cf DAVE mOMGND cuMUarnh PO1AiwG HGURS Dnnrxxrocasr roru muD Casr w, a Y enrtECaRD BIT N0. 512E IADC CODE MANUFACTURER TYPE SERIAL N0. TOTAL DRaLEo TOTAL HOURS SOLmS CUTTING STRUCTURE wNER ouTER DuLL arAR LOCAnoN MUD BGHEMICAL ADDED STANDS D.P. TYPE UNT TYPE MOUI SINGLES 0. NELLY DOWN ~9EALGN Gnc~ ouu auq PULLED TOTAL 7F STRING WALNAROUND COMPLETE, PJSM PRIORTO EACHTASK CHECKED COM a DRILLING UNEInE DOWN, ND ACC, ILLS, SPILL DRILL•52 SEC, USLD=SEO, 1, USEDR2K LEDPs2781, RECb, USED=1371; WTIR124, RECsO, USED~7 t Gmxtl _ DAILY DRILLING REPORT WELL B736 RELOOaoarMCT muxtt sraTErcauNmr BADAMI FIELD Norm slope AK UriaO Seas SRE NN(E WEIGHT N0. LENGTH RKS TO SET AT GRADE JOINTS GH0. NerLJm nv. WIRELaERFtDim REELxo. Sff 1.375 xoUNFS 7B LExom LAPPED 139 DRIILNG CREW PAYROLL DATA D/,1E 11Nar2010 E LASr 10 80 ~ LExoTx araFr FRESRlfLENGFX 128 5141 waLxaKEaxo. apppap ADL365533I 8136 .Opp '~ crswG ruawG DA IINER 13.376 45u ~ wFaR ORTWPaswcELas7cm 186 oxPaxr Do DrWI Inc xo 9 815 10144 702 cuwuTNEwFAxmlmPS 7811 oaLFUSxEa Steal DambndWrl John Radand 15 . R h Worroou AmorNlr LxIL[ irr.a W.w oaFINM[ ' .a ro 1z:oo raRiaLW FAeLr 6:W Y tMRJDNG NeM! TIE 1W& r EMIIaL `" 4 L DWkr Chad Johnson 0 DEPTH OEV D IR. ND D EPTH DEV Dm. PN DEPTN DEV DIR. NO DEVIATION RECORD INOIn to ~ GlaPb (yyspGpaMensMawxw andRwMfi N I G H T T U R E w~u ,,~ ,b,~,rPa, Wr a nMi , r a ror w. °0E NO. DAYS SINCE LAST LOST 711E ACDUENT ,Alncn, FRON t2:oo ro 6:00 o11aLY Mavualn. rwE alla eaw: Drlfer Ronny Gold 1 DEPTN DEV DI R IVO DE PTH DEV Dlq. TVD D PrH DEV D]A. ND DenleWnan MGb11170n Russell Ge6en M81k Newman 2 2 DEVNTION k Di J 2 RECO RD Fborman c oe Fborman Stephan Lord 2 Rw. d:00 To 6:0 ~ 9Wa 0 2:0 ~ CO~ 0 1 DwY00F~tiasoerroxMdplmFLS o PJSMmove pits amDlez. MOVE PIT COMplE1(AWAY FISUB CONIPLE%AND STAGE OFF OF Fbaman FaMiN ~ Andrew Runkle Gary AWa 2 2 D MATTING BOARDS. PJSMSKID FLOOR FMISN PREP RIG FLOOR FOR SNIDDNG. piMatdMr Shawn Fox 2 A Y RodOVasher Roustabold Tom Toguchi Allied Dayton 2 2 T 0 V R f N0. DAYS SWCE UST LOST 711E ACDIDFJJT »,Ma~.,M No. 393063158158 ®~~~~' No. 393063758158 No. 393063158157 DAILY DRILLING REPORT REPORT N0. 2 I Faa BADAMIADL•365533 I WELL N0. ~ 87-36 API WELL NUMBER 50-029.22933-00-00 aTER oEPtx ppTE 13-Mar-2oto OPERATOR CONTRACTOR RIG N0. DAILY DRILLING REPORT WELL BiJ6 REPORT N0. 2 DATE 13~Aar-2010 SAVANT ALASKA, LLC SIGNATURE OF OPERATORS REPRESENTATNF G9ryNammon Doyon Drilling Inc 15 SIGNATURE OFCONTRAC70R'S TOOL PUSHER SN!YCDambaChe1lJOhnRGdland RELOaoMTRMT ~,., sTAielcouxmY BADAMI FlELO NoM SIDpe AK Urited SteNK 9RE 1W(E ~~ ~ IENGTllflKBTOSETAT GRADE JaNTS CSG.X0. waa uNelwcDRO aTUxD. SQE NOUNES UJpiNELaPFO 1.375 10 t28 DRILLWG CREW PAYROLL DATA aiE 13A1ar4a0 DPSIZE WEIGHT GRADE TOOL Ji OD. 0.8 TYPE iHREAp XT39 BTRWGNO. 496 PIIM1IP NO. 1 PWPMANIIFACTURER SKYTOP BREWSTER ttPE 1600 swaMe 12000 LAST cnslNC ~ ~ W LFNGTNCUTDFf /RESBITLEXmN 128 5214 NELLNAME8N0. BADAMI ADL3355301 BW6 4 14.00 5735 75 2 SKYTOP BFLETNSTER 1600 12000 ruBlrvG ORLINER 13.375 455 1 uM wrJLpRmlvs ewcELASrclrt 183 caMRAxr On DAllp RC 8 625 1024 1 102 cuMINATNEwEAxoRtRPS roowMwa RIGNO. 15 TMffi OBT RIBUTIONNOURB ~ ~ ' Y BIT REWRO MUD R6CORD . ~n ' `~ aG ~^0M pxow Gds "M'[ ~.°' .art °1~ MAa1NIaLe r s T811 ui Stew DamhxMrl Jahn ROtllend M41F mok nnY 600 To ~18:OD ~ CROW lMPLDaO. JIM[ K7<6. fe1PY. NODE OPERALION O NIGH r DAV BIT NO. TIME DWkr Chad Johnson 12 RICUPANO rEAR DDWN 12e 0 72:a SIZE WEIGFI7 DEPiN DEV DIR TVD DEPTH DEV mR TV- DEPTH DEV DIR . TVD DardcWnan Chr4stop@r OIIM 12 Z DNLL ACrLNI IADC CODE DEVIATION . . MOtOmlan Randy Hermon t2 J RHU.!INO MANUFACTURER PRESSURE GRADIENT RECORD fl00mlan KUn CIB81% 12 < coRlNC FUNNEL h }e MYNd pt•yp{ylygprpM6MawnaNpgn~q FI0011nan ROIkR BBimon 12 rwxeuO D TYPE vISC051Tr N sa ~ _ Floaman Hardd Walker 12 l s cox NclxuArE SERIAL NO. PV/YP 8:00 6:3 0 0:30 t PJSM WITH CREW COMING ON TOUR=SKID RIG FLOOR AND RISE FEET PRwatcher Jesse Janie 12 s mlPS JErs I 6:30 8:0 0 1:30 1 SKID RIG FLOOFL AND RI5E STOMPERS IN CEDER Rockwasher Yzlcenl Beckw9h 12 T weRlcnrERls TFA GEL STRENGTH G BW 8:3 0 0:30 1 MOVE SUB fORWARDAWAY FRad WELL 81-18A TO GA9J AC55E5 TO CELLAR WRH LOADER Loader Opemta JeR NoHman 12 a REPNRRIS FLUD H 8:30 10:0 0 1:30 1 LOWER STOMPERS AND SKID FLOOR BACK OVER CELLAR RoustaholM Pusher RudoOo Medina 12 DEPTH OUr Loss T 10:00 12:0 0 2:00 1 NPPLE DOWN tOK STACK I DOIRILE GATES 8 BAG I RouslaboNl Clinton Andrews 12 curoEE oRlulxc uxE DEPtn IN 12:00 18:0 0 6:00 1 NIPPLE UP 5K STACK BAG wI IJFTING RIG,TOP RAM5,8lJNDS,MIA CROSS,BOTTOM , PH Ekchician Troy Lockea 12 ,ooEVUrroxsLH TDTAL DRILLED RAMS, AND SPACER SPOOL I/FINISH LAYING OUT HERCULIIE AND RIG MATS FORWELL 813fi Mechanic Mark Grosdidler 1Z „wIRELINE LOOS TOTAL HOURS soups T Welder Randy spencer 12 ~ "sce c ' Q SPO Mark Dunkp 12 r u n C UTTING STRUCTU RE ]WAIL ON LEMENI IMaLx omen Duu cww LacaraN MUDS CHEMICAL ADDED U 1 NIPPLE W B DP. STANDS D P TYPE AMOUNT TYPE MOUNT R s resT eoP. . . SINGLES D ,soalLSrEMrTSr . KELLY GOW N eEARMGSI SEALS cACE OTHEfl DULL CHAR REASON PuLEL M TOTAL IrxuceAC WT.O F STRING ,ssauEErE CeMExr WSPECT IXiILt UNE 8 TIE DOWN NO PJSM PPoORTO EACH TASK CHECKED COM SPCC WALNAROUNDS COMPLETE ,sFlsxlrc , , , ACC.NO SPILLS ISPILL DRL@1200 AN=1 NIN RESPONSE THE 2UDR WORM OAYSSNLE LAST 103T THE ACLIDENT NO GRILLMt OudJMman . DRKJJMG MIB ~ Y BIT RECORD MIa1~COR0 ~ rslOUJIPI wrNON raesu4 n¢ .1 Pose aArloYll Ta al 18:00 Yo 8:00 AT ,CURB EIIK4oN0. NAIE MS, M7111. A PERFORAnNG BR NO. TIME DdlMr Juatln Hays M12 "" B NBING LRIPe BCE WEIGHT DEPTH DEV DIR TW DEPTH DEV DIR. IVO ~ DE PrH OEV DIR . TVD DBmGMan Russell Gallen 12 C TNEATWG IADC CODE DEVIATION . Motorman Mark Newman 12 D. 5WA1381IL MANUFACTURER PREESURE GRADIENT RECORD Fbamen JDB Dwk 12 E rESnNG FUNNEL - a T B~ 0yytb 9yYIpgPMrlPmh6aparclMRNnr4 fkwrman Stephen Lord 12 TYPE vlscoslTV ma p TME Fbaman Andrew Rankle 12 F c sERwL No, PvnP 18:00 22:00 4:0 0 1 CONE. NN 13 5R X 5 K STACKS RACK BACK ON STUMP, RN 80PE LANOWG, CONE. LAYING / FoddM Gary Adla 12 JETS D PULL DRAGLINKS, WARM UP SUB MCVN4G SYS. MATS FOR B1J6 Sh F 12 x GEL A 22;00 6:00 6:0 0 1 , MOVE SUB85POT OVER BI.36, MOVE PIT MODULE85P0T TI SUB, LOWER STOMPER58PRE p8wakher Rockwaslwr awn oz Tom Toguchi 12 ipr AiS 12:a 12:a TFA DEPTH OUT STRENGTH FLUID Y IAAD WI500 PSI. CLEAN UP AROUND 81.18A wrwarix nw suMMr av LOSS oEEICE UbE aN~v pEPTHIN NarRSWCONrROS, TOTAL DRILLED PH T NOUPSWCPa DP. TOTALHWRS SOLIDS Q xouaswHxour oP. V HDlx+s srANDev C UTTING STRUCTU RE INNER ourER DULLCNAe LacAnoN MU O S CHEM IC AL ADD ED R P STANDS D TYPE AMOUNT TYPE A MOUNT . SINGLES D. a s KELLY DOWN s His cA~ Duu CHAR P~EO TOTAL oRM WT.O F STRING roTAL OAVw aDAVS xO PJ6M ACC WALKAROIINDB COMPLETE NO SP PRIOR TO EACH TASK NO ACC ILLS . moM SPxD , . CUMIttA-ME RarnnrvcNCURS 01 USD~95IMTR=12G REt~O l lI5D~10Am DARV MW COST ULSDdRBI RECNOI USD=10611 LEPD=24 59/REC•57 Toro MUD WSt dULLER ~ Juan Xrya .._~... ...~. NO. PAYS SaCE UST 2 My ,r LOSTPME ACCI DENT No. 393063158157 ~~,'~`~®~• No. 393063158157 =N.w~ No. 393063158157 No. 3930631581 DAILY DRILLING REPORT REPORT N0. 3 LEASE WELL N0. I WELL NUMBER wa Tk3tDEPTI DATE BADAMI AD LJ65533 1 81.36 50-029.22933-0D-00 t44Aar~2010 OPERATOR CONTRACTOR - ~'~' DAILY DRILLING REPORT WELL 8146 REPORT N0. 3 DATE 14dW-2010 SAVANT AL ASKA, LLC Do on Drilling Inc 15 SIGNATURE OF OPERATOR'S REPRESENTATIVE SIGNATURE OF CONTRACTOR'S TOOL PUSHER r~DOaolsrwcT azpn srarelcauxrm LweRfLORDRmxD. 9ADANI FIELD NaM Slope AK Upled States GRILLING CREW PAYROLL DATA Gary Hammo n SteveDambacherlJohnRodland wE1Gl1r xa RKBTD xoLwES xatxuPPSO N TH SET AT wrE ROp G 9QE MAI(E GRWE JOIHfS LE 1.375 10 12 CSG. HD. 6 144Jer@010 OP SIZE 4 WEIG 1l HT .OD GRADE S•135 TODl JT 0.0. 4.875 TYPE THREAD 7R•39 STRING NO. 696 PUMP NO. 1 PUMP MANUFALn1RER SKYfOP BREWSTER NPE 1600 12000 LAST cASINC 20 8 0 LeaDrxclROFF 1~IRk'SBIrLEN0111 524 4 xapEaxo. BADAMIADLJ665S0 1 81x6 1 SKYfOP BREWSTER 160D 12000 rualNG oRLINER 13376 '156 4 aarwPSSpcsuarcuT 18 caMRnxr 6 Os o D ili k uwzarNEwTAROemes y n ~ n k roouuvrn spry 9. 625 1021 1 102 7811 Steve DemDecherlJDtn flaBand . 15 E DI8TPo8UT T ION NOURa A Y 4KT RECORD MLKI RECOIA N E~w.A ~ ~ T wT.611 ~ ~ a IIdNr401N 1w7~ 6:OD To iB;W wM laOd IM T$1~O F T pHae HQ~OPERAnON NIGH T wv STNO. TIME L7~' 141PI.~M4 M11~ ~ ~a1Nl RIGBPAxN ~ A GOWN 6:O D SIZE Drille r Chad Johnson 12 TEA WEIGHT DEPTH DEV DIR i4D DEPTH DEV DIR. TVO DEPTH DEV DIR. TVD DeMckman C rOMen hflBtOpe 12 CRIUAGTUAL IADC CDDE DEVIATION ~~~ ~nd/Ma~ 12 PRESSURE RECORD S RFJMING MANUFACTVRER GRADIENT FIOOwnan Kud Geary t2 caRING A rrvE FUNNEL ~, ~ arow 7M ~y~ y~aM~~rssd Rr~ Fbdman RObeR Behan t2 coxpnrox MUU 5 nGRCl49TE 12:00 SERIAL NO. WscoSlTV N - Floormen Hardd Walker 72 N'RIPS PvttP I 6:00 6:3 0 0:3 0 21 JSN = SKID RIG FLOOR PKwatche r Jesse Jerue 11 JETS GEL G 6:30 7:3 0 1:0 0 1 KID RIG FLOOR CELLER PUMP CE CHECK LIST INSTALL PLUGS WCENTEFlCAL PUMPS E T Rodcwasher WncaM Bedndlh 12 itueRCATERIG TFA STRENGTH H T:30 12:3 0 5: ~ 1 • , PRE4LIG ACC P AN ( BERM IR AROUND RIGBROCKWASHER INSTALL HANDRAILS POST PERMENT B RM LOadef Dperaror JeR HOMman t2 a REPAwRIG DEPTH OUT FLUiD , , , ALA , RoIlslalroW Pusher RLltlolk Medina 12 cuioFF Loss T HOOK UP INTER CONNECTS , FUNCTgN DOORS IN SEED, SKATE, AND PIPE ELEVATORS, PITB s pRluwc LwE DEPTH IN WATBT STEAM8A84 MNFLOW LNEd BRIG READY TO TAKE ON WATER HOOK UP MUD RaustffiouL Clinton Andrews 12 ,opEVIATIOxsuxvE TOTAL DRILLED pH , , , , CHOKE LINES) EMddcian Troy Lackes 14 „wlaETwELms sollDS 12 30 13 0 0 0 3 0 21 REAgVEVALVE HANDLE ON MASTER VALVE ON TREEBLEWJER BOPS LANDNG Mechenk MadcGrosdidier 72 TOTAL HOURS T : : : WBldef Randy 6pellar 12 2RUxcASwc ncEMEni CUTTING STRUCTURE 13:00 16:4 5 3u1 5 21 REMOVE GAUGES ON TREEIFLANGE UP PUMPIN SUB ON WING VALVEIRN DNES FOR SPO AlarX Dunlap 12 PUMPM4G DESEL I BLOW THOUGH IJFES 1700 PSI ON M1, RN TD BLEED TANK 8 BLEE01 RN ,3WAN ON CEMENT IPNER W1ER UULI LHAA LOC0.TpN U ' u NRPLE UPeon. MU TYPE D 8 CHE AMOUNT MICAL ADD TYPE ED MOUNT R LUSCAl1ER I PULL BPV (550 ON TUBING) I NOTE: TRUCK SHOWED UP AT 14:00 TO SPOT ONCE SPOTED INSTALL HAND RAILSAND BERM UPI ROCKWASHER ,sissl enP. STANDS D.P 16:45 18:0 0 1:1 5 21 , BLEED IA TO BLEED TANKILOAD PIPE SHED wl2718"TUBING(169 JTS) ,SGRnL STEM TEST SINGLES D. KELLY GOW N eEARwcN cxcE ciHER aEUax TOTAL SEALS WLL CHAR PUTTED NOTE: GROUND LEVEL=40.30'ILOWER LDS=37.65'IUPPER LDS=3515 ,FP,uc encK I"JT.OF STRING NOTE: RIG ACCTENCE= 2f:00113-10 (RIG ACC~TANCE PUSHED BACK 1312 HRS FOR N108 ,5 SauEEEE LTMENI CHECKED COM INSPECT GRILL LINE 8 TIE DOW NO PM R TO EACHTASK C F8U ROPE 10K TO SK +s HSxlec C WALNAROUNDS COMPLETE, PJSM , , SP O N ACC, NO SPIl1Sl FIRE OR8L ~12W PM =I MIN RESPONSE A UIR WORN s' eLEEDwroe 2] 6A0 ~~ ~~~ NO. MYS SINCE LAST LOSiTME ACLIOQIT ss 10 ASSEI68lr B1T RE4KNI0 iUD RECORD OFT ap1p ~°Y•110M AK N1.° w"" woe ~ rw ape m rus D4YIWR nlpl 18:08 ro 6:00 an APEREORAiwG BIT ND. TIME aRDw ~~ IIWE ~ aYRAI a.,uelxc TRIPS SIZE DHNer JusOn Hays 12 yy p GiREATING WEIGHT DEPTH DEV DIP. iW DE PTH DEV DIR. TN DEPTH OEV DIR. TVD Demchman Russell GalMn 12 W[ IADC CDDE PRESSURE DEVATON RECORD Mororman Mark Newman 12 D.SWAHaIIp MANVFACNRER GRADIENT Fklorman Joe Dick 12 E TESTING T19E FUNNEL lrsro to ~ tYAaNP OarleGtOpeo/s~ABgiwwAa4ReMa - Fkxxman Stephan Lord 12 E' SERIAL NO wscosirY - Floonnan Andrew Rustle 12 G . PvnP ~ 18:00 3:d5 9:4 5 5 CONE. BLEEDING GAS FIANNULUSBNSNG T08LEED TANK, LOAD SHED WI2718TUB84G, RN 8 BLEED TUBING 8 ANNULUS TO POOR BOY T RC FoddHl Gary Altla 12 JETS GEL A RN I CI . SHUT NI ANNULUS 8 TUBING 0 PSI WHILE PLLNPMG BB OW TUBING PlNVatcher Slaws Foz 12 TFA 9TAENOTH 3:45 6:00 2:1 5 5 . PUMP 4,000 GAL 195 L D N , Rcekwaehaf Tam TOgud11 12 0iP1S 12:00 12:00 DEPTH our FLUio Y 8 MONROR PRESSURES, TUBING ON VAC. ANNULUS 10 PS. WHILE WAKING ON WESEL, PREP; RoueMlwul Allied Daytal 12 oxvwaRKUME suEwA Rr Loss 716" TUBNG 8J SHED OPFlGE USE ONLV DEPTH IN H HW RS WrWNix CP. TOTAL DRILLED P HauxswraPROP. SOLIDS T TOTAL HOURS NOURSWiIIgUI DP. CUTTING STRUCTURE U MYJR551PNaeY PR acanoN e 1{ IxNER WTER wu CX L MU DBCHEM ICAL ADD ED NPE MOUNT TYPE AMOUN7 STANDS D.P. SINGLES D. KELLY DOWN BEARINGS, GAf£ OiXER REASON TOTAL eEALS CULL LHPR FULLED O WT F BTRINO iomL wvwoRK . xaacnvs ~ WALKAROUNDS COMPLETE, PJSM PRIOR TO EACH TASK, NO ACC, NOSPILIS moMSPUD LUMUTATIYE Raianxcxauas BluLruwcosT ULSD•100061 REC~0001 USD=39L lEPD~68911 REC=60001 USD=17681 WIR•1601 REC=TOT USD€WllBef iOTH MUD GOGI DRILLER Jwen Meye N 0. DAYS SINLE LAST LOST IINEA~Ni ~"~""''°° ,~ No. 393063156159 ~ No. 393063156159 ~, .~~P~p„ No. 393063158159 No. 393063158160 DAILY DRILLING REPORT REPORT N0. 4 LL,ASE BADAMI ADL365533 ! W91 N0. 6136 API WELL NUMBER 50-029.22933-00-00 WATER DEPTN DATE t548ar30W OPERATOR CONTRACTOR ~ RIG N0. DAILY DRILLING REPORT WELL 8136 REPORT N0. 4 DATE 15~Mard010 SAVANT ALASKA, LLC SIGNATURE OF OPERATORS REPRESENTATIVE Gary Hammon DGyon Dulling Inc 15 SIGNATUREOF CONTRACTOR'S TOOLPUSHER S72veDambacherlJohnRodland nunoso¢rRKT cwnr srARlcaalmv BADAMI FlELD Nash Slope AK 1 Urvlad Stales sME NAI(E ~~ ~' LENGTN RK6TO SETAT GRADE JaNT3 CSC. NO. wweur[RewROREELxo. ~ Nouns LaxGrxNSVSO 1.375 1D 128 DRILLING CREW PAYROLL DATA DAR 1548ar3010 OP 617E WEIGHT GRADE TOOLJr O.D. TYPETHREAD STRING NO. PUMP NO. PUMP MPNUFACNRE0. NPE srftarcE 12000 LAST CASING ~ 0 0 ~ LdOMCUiOR PRESF1rt LdGTX 126 5244 WELLNAYE lNO. BADAMI ADLJ65533 18136 4 14.00 5735 4.675 XT39 496 1 SKYTOP BREWSTER 1600 ruawc aTPoRSawcELSS7ca cowrwr 2 SKYTOP BREWSTER 1600 12.000 OR LINER 13.775 4% 4 45 b5 pDyDN Drning lnc 825 6 tO21 4 102 CUMULATNE NFAROR iNPe 7811 LIXIWGNd RIG NO Stew Oanaucherl John Radland 15 . ~ Y C01~ MUD RECOW rN a:aR a 1Y1.D 'A csa raWLDI, aA[sDLDR T wt.Ox av Nv rN~M I YDe .a Walt tOUR FA011 8:00 fi 118:00 iRlfi OgTMBUT gN NOURS DOF 7 617 RE h n m CRLOY EaPIJDND. NAIM faa. 611NL rqE GPFRArION wGxr DAV BIT NO. TIME DWMr Chad Johnson 12 ftlc wAxo SIZE d a D W er OMen Christa ~ rUROOwrv WEIGHT DEPTH OEV DIR. PA DEPTH DEV DIR. T VO DE PTN DEV DIR . TVD er n n c p 12 z DRiLL ACrLwL IADC CODE DEVIATION Motorman Wndy Maman MANUFACTURER PRESSURE RECORD Floorman Robed Gelman 12 e REWARD GRAOIEM FUNNEL pw6a0RrrMwbasyaBaAMikRwIM Floarman Kun Geary 12 <coRlxc TwE wscoslrv RaP b ~ Ma.NN Floorman Hardd Walker 12 wrvolnorvuuo aeclRCUaE SERIAL tro, Pvm N 6:00 6:30 0:30 11 WAIT ON DIESELILOAD RIG FLOORWffHDOUBLESTACK TONG56HANO SLIPSIPJSM Roehwasher Vincent BeckwMh 12 6 rRiP6 JETS I PUYIPING DIESEL ~ H CHOKE 7B Loader Operator Jeff HOflman 12 iLLeRICArEMC TFA GEL TRENGTH G 8:30 6:00 1:30 22 @ FILL WELL VrtfH DIESEL(PUMP DOWN NBING AND TAI~RETURNS THOUG PMwatthBf Jesse J@rue 12 S FLUIp H SPM, 0 PSI (PUMP 64 BBLS) SNUT GOWN WHEN ONCE START GETnNG RENRNS (0 PSI ON Electdcian Troy Lakes 12 e REPAawc DEPrHOUi Loss T NBING,100 PSI ON W) Roustabout Rasher Ruddb Mee6na 12 R cur orT DalulxcuxE DEPTHIN 8:00 10:00 2:00 22 SHUTIN WELLBMONROR PRESSURES(TUBING=OPSI, a=110 PSI)ILOAD SHED WffH2 RouslabolA Cknton Andrews 11 ,NDEVUraxswwE TOTAL DRILLED PH 7B'TUBING RABBRAND STRAP ( I Mechanic Mark Grosadier 12 „Wlft¢In6LGGS Toru roues soups T 7o:ao 13:15 3:15 21 CBUS (a11~~SpM, 370 PS1(/SOO STKS) Wglder Randy 8pevlur 18 zRUrv caslxc ' eLEMENi CUTTING STRUCTURE Q 13:15 13:30 0:75 0 45 21 21 MONRGT ANNULUS(10 P51) PERFORM CASING TEST 2000 PSI br 30 Mnute test (SO STKS) Good Test ~ Mark pABap 72 V 73:30 1/:15 : ,swwr on cEMExr Ixrvd DuRd a cHAN Laanox MUO B CHEMICAL RODEO 74:15 15:15 1:00 21 BID TINES I RID LINES I MONRORANNULUS OT weld on Bell NjppM wPPLE UPeo.P. ~ ip;aN TYPE AMOUNT TYPE AMOUNT R 15:15 15:15 0:30 22 INSTALL 2JNAY CHECKin m9. hgr. u rssr6o.P STANDS D.P SINGLES 0. 15:15 16:00 0:75 21 PJSM=WD TREE ,6 DRIL15iEM iE6i KELLY DOW N aEnftnca 6E,1L6 oAGE orxER DJLL CHAR RFA60N PULLED 16:00 78:00 2:00 22 PAl ON TREE WITH BRIDGE CRANE I OPEN SEGMENTS I PN iREE TOTAL ,ixuc euN WT.O F STRING NOTE: FLUID LEVEL W WELLAT /,890MD BEFORE PUMRNG FlLLING WELLBORE ,69]UEE2E CEMENT NO NSPECT GRILL LINE 8 TIEOOWN CHECKER COM TO EACH TAS P W 19f1~'~ , , ALKAROUNOS COMPLETE, PJSM PPoOR K S CC ISPIII DRILL~4:30 PM =1 MIN RESPONSE TIME ACC mow wa+N . TI PJ6M=WDR 2:00 DPoLId NO. WYS SINCE IA3T LOST RME ACCIDENT Ru a+TREEw 1o:GO Chad JdNSan G Y '"~ une e p ~ wa T .~ A< WYIBeII MOM 18:00 ro 6:00 m A6 OILLLM T BND W 3~L TOIRt BIT RECORD MNIO RECORD YD ~ ~ i OMM' MlI.ONO AMkE LMM lOOSL a PERFDRAnNG &T NG. TIME ~iIIBr Justin Flays 71 rU61NGrftIP6 . id D Russell Geller 12 ~ ~ wEIGMr. DEPTH DEV DI R. NO DEPrN DEV DIR. iW DE PTH DEV aR. ND en lnnn 12 C. TREATING IADC CODE DEVIATION Maomman Merk Newman o swnaslxG MANUFACTURER PRESSURE GRADIENT RECORD FlPorman JOB Drck 12 E rE6nrvG TYPE FUNNEL Rynf TR ~ [adaW , fiN6pOpNa6aslnegMMwAMRsaMS Floorman Fl Stephan LoN Askew Ralkle 12 72 wscoslTV " oorman sERAL NO. pynp 18:00 6:0 0 12:0 0 14 50K ADADTER SPOOL aIon i 7 ONT. NIDTREE, NN 135'6"tOK HUBX13518 Fodditt Gary AMa 72 JETS ~ 73518" 5K DSA FLANGED SPOOL, LOAD SHED Wl4" DP. B: PREP, CUT ROPE BOLTS TO LENGTH ~~ Shawn Faz 72 TFA GEL TH A NRI13518" X 5,000 PSI STACK ROCkM28her Tom TogalM 12 s STRENG Y Roustabout Alfred Daytal 12 Toru oArvra,rcxME Imo SUMMA 1a:m Rr DEPTH OUT FLUID Loss SPO Mark Dunlap 3 oFFlc6us6 orvLr DEPTH IN Weller Randy Spencer 3 Naxs w~cGxrftoP TOTAL DRILLED H P T OT FUELING xWfts wrom DP. RS soups ~ OT WELD on BELL NIPPLE rDTAL HOU Naas wlrxcur oP. CUTTING STRUCTU RE U xwRS sraioev IrNm ouTER GULL CHAR LDUrroN R MU DBCHEM ICAL ADD ED TYPE MOUN TYPE AMOUNT STANDS D P SINGLES D . KELLY GOWN a6naMav once orxER REASOx lEO TOTAL SEALS ouucHaR Put WT O F STRING rout onrwoln . P W H T NOA AS NO SP CC ILLS xo oronrs mad 6PV0 . ALKAROUNDS COANLETE, PJSM PMORTO EAC K CC S WMLLAIIVE RoTAnxc NOURS B11 REC=L+U30=217w WIFR32N REC=1001 USD=4011M/lf 4 nnuvMUCOSr 5 ULSD~779 REC91 USWKJI7 LEPD rota MW COST OPoLLd JNNn Nays ,~,r,wW ..nw+,. +e,r..w NO.OAYSSINCE LAST LOSTNM1ff ACCIOdi ~m~oM,uR„.,,o„ w`.. m.,.,.' No. 393063756760 No. 393063159760 no. ,,a.,Nw I.A,~„ No. 393063158161 DAILY DRILLING REPORT REPORT N0. 5 / ' • LEASE BADAMI ADL-365533 I N0. B136 API WELL NUMBER W 50-029.22933-00-ILO ATER OEPrH PATE t6fitar-z9to OPERATOR LLC SAVANT ALASKA CONTRACTOR on Drilling Inc Do RIG N0. 15 DAILY DRILLING REPORT WELL 6136 REPORT N0. 5 DATE 1644ar3010 , SIGNATURE OF OPERATOR'S REPRESENTATNE y SIGNATURE OF CONTRACTORS TOOL PUSHER Fr1DORaefacT cOUNtt mATEICdelIRY BADAMIFEtD NoM Slope AK UMtRd Sari IaEREtaa RFa NO. DRILING CREW PAYROLL DATA Gary Hammon SNweDambacherlJohnR odlatM s~ MaKE wElclrt rxi ~~ RKe.ro sErnr elrE xoLMES LPraTxsLMPw 1 375 10 17 wrE 0 DP 312E WEIGHT GRADE TOOL JT O.p. ttPF THREAD STRING ND. PUMP ND. PUMP MANUFA CTURER TYPE 9rR0NE um GRA DE JORTrS CSG. HD. . LEmi1NCm0Ff PRESEMLFAGTN i6#1erd010 WMINAMF4 N0. 4 1a00 5135 4B75 Xi39 496 1 3KYfOP BREW5IE R 1600 42.000 LASING 9.62 5 1021 0 1 t28 ~/ / IiADAMl ADW65533/ B136 2 SNYTOP BREWSTE R 1600 72000 r~l~ ORLINER T 1743 3 12432 ORT~BaNCELASTgIT 33 carARr 5 CUMIIIATINEM,FAR ORTaPe On D111RnA Inc i001PU51FA ~~ TWE OI$IAIBUNBIHW DRILUN6 A69EtABLY AT DOF BIT A6CORD IBID RECORD + a rtAe~i N 5 ~ a roAxMeaLl ramwwae 1M7 6 wr.AN eq tOi Par RR24r111E I t 1p.N N0.L 7611 Tr~ Slave DanbeoMrlJohn Rodbnd IeGIRTOVN fig01 6:00 Ta 16:00 edAII YIII 75 MOrM cooE ERnnoN x r ° BIT N0 f~A' maPi-0lq. MNB xIM. M1ML DP N xlc . TIME D iIk Ch d J ~ flIG lP0.W ~ iEAR DOWN SIZE I M a ohnson 14 A WEIGHT DEPTH OEV DI R. ND 1O"` D EPTH OEV DIP. ND OE PTM OEV DIR. 7VD Denickman Chrbtoper OMen 13 z D IUACTUU ~ IADC CODE DEVIATION Moorman Rall Mammon 13 a RFnMwc MANUFACTURER PRESSURE GRADIENT RECORD Floolman y Robed Belmar 13' cDRNG ~ TYPE FUNNEL ~. TA ~ ~~ tlrbad0et1peNlRlrlnaeONMIaMLRIARb fI00mIM Kud Cleary 13 corom°x HUO E dCIRGILArE SERIAL N0. NSCOSITY N M BOPES I STALL BELL NIPPLE FLOW UNE AND FILL IR UNE E N P LE Floolman HaroM WalNer 13 Pvm I 6:00 16:0 0 109 0 id N CON71PAl I P l ( , , UNE CK7 SPOOLS ON CHOKE HOSE TO EUMINAIE BEND Loader Operator JeH HoRman 13 JE73 GEL G , REAR TIGHTEN BOTTOM FLANGE ON STACKTO ADAPTER IN HOSE PNwalcher JesBe JBM 14 ,wsRIGTE RIG TFA srRENGTH ) , Roekwasher Vinunt BeclLxkh 13 eREPAIRRm e;ro oEPTHODT FLDIO Loss H i6:W 18:0 0 2:0 0 21 PN4'TEST JTd M71 CROSSOVER,10'PUPS HEAD PWIMN 71W8DART VAIVEI FLT. STACJS WfiH WA7ER CLOSE BUNDS #16 k17 tl1B CHOKE VALVE58 PERFORM BOGY TEST( Roustabout Pusher Ruddk Medina 13 s cur aP RNUxcuxE ° DEPTH IU T , , , , PSI LOW 3500 PSI HIGH) Roustabout CFnton Andntws 13 IooEVwrbxsuavE TOTAL DRILLED PH , EleclrlGan Mike McDonald 13 1, WIREUNELGGS SDLDS ' Mechank Mark Grosdidier 13 TOTAL HOURS T WBldef Randy Spencer 13 RIIN GSING 1zdcEwmr CUTTING STRUCTU RE 0 SPD Merle Dunlap ib ,>wnxaWCrM~ ,xxER aureR Duu cwa LDCnroN MU D 5 CHEMIC AL ADD ED V ,PwPPLE Imo ao P. tN.00 TYPE MOUN TYPE AMOUNT R =WEEIO_Y SAFEtt MEETING s rssreo P. 6:W STANDS O,P. =SAFETY CAMP s°alu srEM resr SINGLES D. KELLY DOW N euRlxcs, GACe orHER Reasau iHR Bxpedl8ng TOTAL 9EAL8 WLL CHAR PuLIED „rtuGBACK WTA FSTRING BNDlIEE1E CEMENT RAROUNOS COMPLETE PJS CC WA M PPoOR T O EACH T ASK CHE CKED COM NSPECT GRILL LI NE d TIE DO WN NO ,s sls"Imo , SP L ACC.NO SPILLSI @03:00 PM SPILL DRI , LL=7 MW RESPONSE , , m woRN E' PNN"LEST a1 200 aRRLFR ~~~, - NQ GAYS SINCE LAGT LOST iNE ACCgEm as ADA ~Itp ~A S~BLY B/T RECORD MI~RL~ORD a Ma o ~++a ' pa wr wr Ro.T ,~,~~, W+sPaL mo ll 18'AO ro 6:00 A rExroRAnxc BIT NO. TIME CIIfP' EYN.O MG MALE IRIS 46W 11D DAll J ti H e. ruewc rwPS slzE er us n ays 10 $ iPEarNC p C WEIGHT pEPiH pEV DI R. TVD DE PLN DEV DIR. ND DEP TH OEV DIR. ND - Derdckman Russell GaOen 13 . [ IADC CDDE DEVIATION Motorman Male Neiman 13 W o. swnselxc MANUFACTVRER PRESSURE GRADIENT RECORD FlGarman Joe Dkk 13 ETESnNC FVNNEL FIOOman $te ke Lo d TYPE vlscosiTr frpa To ~ Cadlb LYMb0111pn114p6afprmMdP de n r P 13 F SERIAL N0. ' Floorman Andrew Runkle 13 ° PvNP 0 18:00 0:00 6:0 0 15 LEST BODE Tf 250 LOW 3,SW HIGFI TEST CHOKE YALVEB 1.16, 3 VALVE ON KLL LWE, KILL 8 UPPER & LOWER IBOP Wl4" TEST JT TEST UPPER 31Y CHOKE HCR d MANUAL /" TIW 8 DART FodJik Gary AWa 13 JETS GEL A , , , LOWER 3112" X S' VARIABLE PIPE RAMS BLIND RAMS X 5" PWE RAMS POwaM.her Shawn Fox 13 TFA STRENGTH , , ROtkwaeh@r TOm TOgucN 1/ orALS DavwoflxnME t2A0 SUUxx 17:00 Rr DEPTH OUi FwID Y 0:00 6:00 6:0 0 6 NOTE WETO CONTINUWG PROBLEMS WITH SIEIaTA LEI GAS DETECTION SYSTEM,PoG THIS "DOWNTIME" STATUS WILL WAS PLACED ON'TIOWNTWE" AS OF 0000 HR5 3777110 RGUStaboul Nhed Dayton 13 aFlcsusE Oxir DEPTH IN LOSS . . CONTINUE UN71L LEL SYSTEM IS FULLY FUNCTIONAL xcuRS w,eDxrR DP TOTAL DRILLED pH T . ° 1 HR WSM xauRS wrom DP. B=SAFELY CHAMP TOTAL HOURS SOLIDS Q xouaswnHDUr D.P. CUTTING STRUCTURE V xDNflGHLAxDEr IxNER ourEx DmL WAR LOCenoN MU DB CHEM ICAL ADDE D R TYPE MOUNT TYPE MOUNT STANDS D.P. SINGLES D. KELLY DOWN eEARlxca GAGE DrHER Rusox TOTAL SEALS DULL CHAra PuuED WTA F STRING rorA, oarw°flx xD. of DAVS SPCC WALKAROlWOS COMPLETE, PJSM PRIOR TO FACX TASK INSPECTDRILL LM1E B TIE DOWN NO ACC. PROxsPUD NO SPILLS, SPIU pLILLHELDI MN.IS S EC. RESPONSEnME CIxNDLATIWE RDTArNG xows REL O USD Ib DARYMUD GD91 ULSD=[ 83731 RECg01 LrJDgfiA2j LEPD+(5 912I REC=[35001 USD"(2169J WnTg1767 h j =( j ioru MUD CasT aaLLFR ,~ONwe NO. DAVS SNCE LAST L OST TIME ACCID ENT ~d.... m,. No. 393063158161 ~~~~"N"~~ No. 393063156161 ~~s'°'°'°`~~ No. 393063758167 No. 393063158162 DAILY DRILLING REPORT REPORT N0. 6 • LEASE . BADAMI ADL365533 1 WELL NO. 61-36 WELL NUMBER 50-0Z9.22933-00.00 WATER DEPTH pA7E 17+nao-zolo OPERATOR SAVANT ALASKA, LLC CONTRACTOR DDyon Drgling Inc RIG N0. 15 DAILY DRILLING REPORT WELL 6136 REPORT N0. 6 DATE 77•M11ar•2010 RFiDOaoMTMCr carom TATercaxTRr wRELIXEREWAD pmxa DRILLING CREW PAYROLL DAT0. SIGNATURE OF OPERATOR'S REPRESENTATIVE SIGNATURE Of LONTRACTORSTOOL PUSHER BADAMI FIELD North Slap AK Unimd Slaps Gary Hammon SteveDambacherlJohnRadland glg µdKE WEIOlif CH+AOE ND' JOINTS LENGT H RNS7O X0. SET AT 9DE NOUNEB IENGMaINPFD 1.375 10 128 DATE 174Jar4010 Op SIZE WEIGHT GRADE i0l%JiOD TYPE THREAD STRING NO. PUMP NO. 1 PUMP MANVFACTURER SKYTOP BREWSTER TYPE 1600 aiRDNE 12000 LAST DASwG m 8 0 BO LRYfsTN WTOFF M63ENTLwG1N 128 5244 NF1l NAYEd ND BADANIADW65573 I B13fi 4 14.00 S•135 4975 7(739 496 2 5KYi0P BREWSTER 1600 12000 TuewG pq uNEq 17.775 455 1 45 DRTMasaxcELASrwr 735 carAxr DDyon DNN Inc 8 625 1024 1 l curAlurMEwFAnaTMPS raouwxw Rcxo, d 15 M l J h R dh S D b TRH 6131 Wa1RIDK DIBWN G /CiSEM6l Y a1T RECORD NUD RFCDRD . Aw.A °p"F ~ M1xDn T m ~ ' ~ Pulw ` 7811 r o n O n NVe am ec aa3xtiam FMM 6:00 ro 18:00 euW man T ENDO F TOUR Cf44Y lA1PLIDMO. MAa[ Nr6. aAiMl ~ NnE fFERAnDN Nlcx r Dar BIT NO. TIME Driller Chad Johnson 12 RIGV-AND i rrnNDDwx 6QE wElcxr DEPTH DEV DIR. TVD D EPTH DEV DIR. ND DEPTH DEV DIR . ND Derrickmen Chdaloperl7Nen 12 2 DR4LACiu4L WDC CODE DEVIATION MMaman Randy Namwn 12 3 REN+Iwc MANUFACNRER PRESSURE GRADIENT RECORD - Floorman ROherl Gelman 12 FUNNEL p y LRasae4 DdL G LYMasQ'OprMMnrpdegawwa AeORaarrb Flogmen NMrt Cleary 12 a tDRIxG TYPE VISCOSITY an D T~ q o FIOOflllan Herdd Walker 12 Caxort10NMUD s aaxcuuTE 1:30 SERIAL NO. PVIYP N 6:OD 8:0 0 2:00 15 CONTINUE TEST ROPE BAG wl4'TEST JT,TOP RAMS M74112'TEST JTS, DRAW DOWN Logder Operebr Jeff Hofiren 72 crams g;gg 3:00 JETS ~ =1550 P51=200 PN NCREASE=20 SECS, FULL PRESSURE=3025=3MINS 215ECS,SBOTTLE p8waleher Jesse Jerue 12 r weRCATE RIG TFA GEL STRENGTH G NRROGEN AVBiAGE=2350 PSI RockMrasher YnceN B8Ckw9h 12 e aEPAIRRIC 5:00 DEPTH our FLUID H 8:00 9:0 0 1:00 15 RID TEST EWIPMENi f BID LNES 1 SUCK WATER OUT OF STACK ~ RousfaboW Pusher Ruddb NeNrla 12 curGFr Loss T 9:00 10:0 0 190 fi CIO ELEYATORS(4"DP)IPN MOUSE HOLEI PJSM=PN PIPE OF SKATE AND RACK BACKN Roustahout CliMOn Andrews 12 oanuxcL rE +oosvlAnox suHVE DEPTH IN Toiu DRILLED PH 10:00 18:0 0 8:00 6 DERPoCK MOVE PIPE AROUND IN DERPoCK AND STRAPIPN 4'DP AND RACK83TRAPNDERRICK(168 Elearbian Mike McDonald 18 Mechalie MarkGrosddkr 12 f+wIaELNELOCS toraL HOUgs soups T JTS)DPoFT WfTH 2" Welder Randy Spencer 12 NW CASING 0 SPO Mark DUMap 12 + 'ecEMWr C UTTING STRUCTU RE NOTE:IA= 0 PSI, OA= OPSI, DOA= 200 PSI swwr oxcEMSNT INNER ouTER Duu cxaR LDUTroN MU D B CHEMI CAL ADD ED U ON GAS MONITORS awvaE LV eo.P. T NDS O P TYPE AMOUNT TYPE AMOUNT R +sTESreoa. 7:00 A . S SINGLES O +s DRlusrEM resr . KELLY DOW N asF~LS GAGE n~ul xaR PuL TOTAL nPLLG SACrc WT.O F STRING tBaWEEfftENENi EIE PJSM S COkR PPoOR T O EACHT CHE ASK CKED COM NSPECT DRILL LN E 871E DO WR NO +sFexING , , , L SPCC WAl1Wt0UND pCC. NO SPILL51 BOPE DRILL W 17:00=1 MN RESPONSE TINE 2a DiR. WORT( DMLLw Lhad Jdmon NQ DAYS SINCE lA3T LOST RME ACCIDENT DRIl1.IM6 &ID D Y FT SIT RECORD NUD Rf00R'D ~" o eFa art war aD rm+uruN pnawoslrt AewYwn T n.a+ sn wM FaeauX xOw N ' ' rma wrmel CREW FRO DMPlblp M 18:00 ro 8:00 xaME RRt YAIA 1 MTwL tlDOa ou0.P ~ A PEaEORAriNG BR No. nME Driller Jusfin Hays 12 `' e TUBwo roves 2:3D SQE WEIGHT DEPTH DEV qR MI D EDiN OEV DIR. ND DEPTH OEV DIR . N- Denickman Rus8811 Galen 12 c. TREAnNC IAOC CODE DEVIATION . MDbrman Mark Nepman 12 D. swABNING MANUFACTURER PRESSURE GRADIENT RECORD FIDDrman JOa Dlck 12 ErEanNC FUNNEL ENprd C M TpaaawgprslbpfaaMaaew ape AplMds Floomlan Stephan Lord 12 U T1PE wscosltY flaw TA A°s D a Floorman Andrew Runkle 72 F' SERIAL N0. Pvm 18:00 21:OD 3:00 6 CONT. PN /" D.P. RACKWG BACK, CONT. WORKING ON SIERRA GAB DE C ForMM Gary AWa 12 G ~ . (FUG OFF DOWN TIBE~2000HR5) h PK t n FOx Sh 12 x JETS GEL A 21:00 1:30 4:30 S RN ON NTO REVERSE GRC. RN TI PULLd112'PRODUCTK3N TUBNG, er wa c ROCkNaSher aw TDm TDGllthl 12 rOr ALa 12n0 72:00 TFA DEPTH OLR STRENGTH FLIIID Y 1:30 2:00 0:30 8 EST RIG FLOOR GAS ALARMS Roustataut Alfred Dayton 12 DAVwoRrcnME wMM Aar LASS 2:00 3:30 1:30 5 PNTBAR&ORY R002 WAYCNECK AS PER FMC REP. REVERSE CIRC. BN W1210 GPM, 620 orFNE usE DNLV DEPm IN P31.14'k FLOW OUT, PUfxWED 2,412 TOTAL SKS, RN CO2C. EQUIP. BID LINES xcuxs w~coxraoa TOTAL DRILLED ~ T 3:30 4:45 1:15 8 RIU SCHLUMBERGER CONTROL LNE SPOOLER RN TU81NG WaNIXJNG EQUIP. NWI SPEARAS xouasw~ePR OP. SO IDS - PER BOT REP TOTAL HOURS L O CONN CONT MAKE T D ON ELEVATORS WORK THROUGH TOP OF HANGER xouaswirxour DP. CUTTING STRUCTU RE U 4:45 6:00 1:15 B . . . , RIH WI SPEAR s srrNDEV o ING THRU HANGER APPEARS GRAPPLES IN HANG x ua WNw WTEF Duu fIUR LOCenoN MU DS CHEMI CAL MD ED R OUT SUCCESS, PUMP OUT STACK P TANDS D TYPE MOUNT TYPE AMOUNT . . S SINGLES 0. KELLY GOWN BEPRINGw SEALS GAGE OMER Duu OIAR aEABON PuuEo TOTAL WT.O F STRING Tool. DArwoax PJSN MP ETE C PRKMT O E4CH T NSP ASK ECT DPoLL LINEdn E DOWN N O ACC xo. aF DAVS m'a^$PUO L , C WAINARWNDS CO SP NOSPILLS, MAN DOWN DRILL TABLETO , P HELD , . LUMLLAIIVE amanxc nauRS %KX EP 37781IU50=16201XK)IOVI D=8081 REf R=142][RETrO]NS0=34WtX DOILY MIA 0031 IL (ULSD=7504I IREt•01 NSD~I 11 s iOTAI MVDCOai ORILIFq JastlD Neyx .m.. ,F6 ,m. u., N0. DAYS SINCE LAST ewunr.«m Taro JL'u,w~ LOSTTWE ACCI DENT ~" w`. ,., ,~„ No. 393063158162 No. 393063158162 No. 393083158162 No. 393063158163 DAILY DRILLING REPORT REPORT N0. 7 II 11 u LEASE BADAMI ADLa65533 1 WELL NO. B1.36 WELL NUMBER 5D-029.22933-00-00 WATER DEPrH PATE i6~AaT-2010 ~~~ OR RIG N0. DAILY DRILLING REPORT WELL 87.36 REPORT N0. T DATE 1841ar•2070 SAVANT ALASKA, LLC SIGNATURE Of OPERATOR'S 0.EPRESENTATIVE Gary Hammon Doyon Drilling Inc 16 SIGNATURE OF CONTRACTOR'S TOOL PUSHER Slew DmbacherlJ.ROdIandN.Evans nFLOOROBTwcr couerc srarBlcauxmr BAOANI RECD NorYLSlspe AK UniNO Slates WBGM xa ItKa io NZE HAKE tliADE JOINTS LENGTH LSG.XD. SETAT uxBxFCawemxo uE xouxBS LENG1N eLPPFD iS75 10 120 DRILLING CREW PAYROLL DATA B.Are t84aari0lo DP SIZE WEIGHT GRADE i00LJr O.D. NPE TNREAp STRING NO. PUMP NO. PUMP MANUFACTURER TYPE eiaoxE IASi Slxc ~ 8 0 LFNBix CIROFF wiESEMLFNeTX 128 5214 wELLNAMEANO BADAMI ADL385593 167x6 id.00 5.135 4.875 1839 496 1 g(1TOP BREWSTER 1 600 12.OW cA 1uelwG ox twwvxcBLAarcui canAxr 2 5NYTOP BREWSTER 1 600 12.000 oxuNER 13.37 5 866 1 q6 335 Doyan ONlin Inc 62 9 5 1024 4 102 uNUU7rwATAROeTxes 7811 7ooLFUSINR Stew DembacMNJ.RodIamND.Evans ewxo. l5 , ' w ` ' ro 1B D6 auw BOtN TINE dBnlMUTI ONN OUAa DAT fr~iD ~O~Y BIT RECORD NUD RECORD ~'" rAALE M urwxwECnerrl wr.a sn rnn ~aarsF ~ . + poi Bart7DUR dMN' Faa 91R.DN0. : a 6:00 NNE !Ik NFML NO.. Na OPERAnax wCxlr UAV BIT NO. TIME Odller Chad Johnson 18 wG LFAxo D k QhHslo ef DNm ~ rEAR GOWN SRE WEIGHT DEFiH DEV DIR. iVD DEPTH DEV DIP. i VD DE PTH DEV DIR . TVD 4RIC mm p it a oRlu ACruu IADC CODE DEVIATION Mobmtm Randy Meman RER PRESSURE RECORD Floormm RoOert BeBnm 12 3 REAMwG MANUFACTU GRADIENT L ~p~e d feau+tn6rWMa+blARea~M Ya dG D FIOOfr112n Kud Cleary 12 a WRMG TYPE FUNNE VISCOSITY Ppw Te ikN ixol LabM p I I e Fksamm Hardd Walker 11 coxmnoxxuo ° sclRCULAiE SERIAL NO. Pvnp N 6;00 8:30 0:3 0 22 SUCKOUT STACKTO SEETOP OF HANGERIMN TOPDRNE TO SINGLEISET GRAPPLESINTO DYwatcher Jesse JenN 12 I ~~ Loader Operator JeR HOfMan 12 s rxws i lUewEgiE RIG 6;00 JETS TFA GEL STRENGTH G 6:30 7:00 0:3 0 B BACK OIIT UDS AS PER FMC REP. ROCkYy88Mf Wncerrt BedcwNh it FLUiD H 7:00 8:00 7:0 0 8 PN ON HAN(~R 210K TO BREAK OVER UP W7= ROUShbod Pu6her RudoNo Medina 12 e REPMRRIG DEPTH OUr Loss T l1D HANGER, SPEAR, CROSSOYER,PUP JTS,BgNGLE Roueaboul CYnton Andlevn 12 s curoFF oanuncure DEPTH IN 8:00 9:30 1:3 0 22 CLEAR RIG FLOOR(CN T1BtEAU PROTECTORS,IA SPOOLER, CIO ELEVATORS, YVU FLOOR Ek,ctdeian Mike McDonald 12 ,aosvwian suPVE OFKLED °H VALVE FOR TUBING Il1rC NSC7) h M M Mark GrosdMNr 12 „wwsuxE LOOS TOTAL roTALHOURS SouDS '~ 9:30 16:00 8:3 0 B POOH LAYING DOWN 41rC'TU&NG I12.6 ppf](14T JTS,2GLM wl PUP5,1%41PPlE wI PUPS] a c ec WMder Randy Spmar 12 RUx aswc SPO Dennis Alien 12 v ~ 6CEMENI CUTTING STRUCTURE Q U ,3WArt ONCEMENI INNER OUTER WLI CHAR LOCAl10N MU D 8 CHEMICAL ADDED e 6 HRS OT EXPEDOING u NwPLE Lweo.P. P TM1D5 D TYPE AMOUNT TVPE AMOUNT R m iesr BC a. . . S SINGLES D E i . KELLY DOW N A~N GV sE DAOE ucn aEUi~o IsuRlusiEM 3 S TOTAL S ~ aR ou Pwc eACx Vyr.OF STRING ,x BOUEE2E fEMENi wF.V.etx HECKED COM NO WSPECT DRAL LINE 8TE DOWN ,s Elsxwc SPCC WALKAROUNOS CgAPLETE, PJSN PRKR TO E4OH TASK, C ACC NO SPLLSIBOP DI71LL~16:00=1 MIN RESPONSE THE , , m oIa woxrc z, DRLIFA ChtlJOMxon N0. DAYS NNLE IASi LOBT iMEA I 41I9A o aFARRWND 2:00 A OgIE~ S ~Y ~~~ WN RECORD s " lwL.n c ~~a wN rwwTxw xa DDREASeoLfan T xn.a en fuw Ilaeaws a r t x wslL ar7ouA xly d iB:00 ro 6:00 .. ~ A tdbl' EYPUDw0. MATE lall M7NL ~ ERrORanxc BIT NO. TIME DdINr Justin Hays 12 a Tu6lxc rxws to:oo 6:00 ROPE SPFAti 5.675 6.51 SrzE Oerdckman Russell Gallen 12 BUMPER 516 4.750 7.50 WEIGM DEPTH DEV DIR. TVD DEPTH DEV DIR. iVD DEPTH DEV DIR. iVD d N M 12 c. rREAiINC OIL JAR 1 750 11 d NGC CODE DEVIATION Motormen ewman a l swASelxo o . d NI15 . i fi0 PRESSURE RECORD Fkarman Joe Dick it . RUIiaTeUB %OVER . 4 075 . 1 TI MANUFACTURER GRADIENT ~ welhxekNpwxwAndRxMa Ydg D Fklorman Stephan Lord 12 ETESrIxc 6 SPIRAL D.C. . , 179.45 TVPE FUNNEL VlSCOSm Arats 7o iw A CaYl eN P b Fbarman Andrew Runkle 12 `~ SERIAL No. PVIYP 18:00 0:0 0 B:0 0 B POOH LAYING DOVYN 41/1" PRODUCTION TUBING (12.6 ppf ] TI JTp 244, FOUND APPROJC 30' " FortdNt Gery Attla 12 O ~ OF CONTROL LWE ON JTS 147.718, THE RECOVERED 10' CUT OFF TBG STUB MEASURED 4.875 PYwatcher grown Fox 12 H JETS FA GEL A FLARE OD~CUT. MONROR HOLE FYI VIA TRIP TANK RackwasMr Tan TOgUChI 12 T STRENGTH Y 0:00 1:1 5 1:1 5 6 RN 4117 HANDLING EQUIP. CLEAR FLOOR Roustatloul ANred DayWn it roiALS OnvwORxnME lzoo suLwe u:ao nr GEPTH OUr FLUID LOSS 1:15 1:d 5 0:3 0 B RN! 3.N" HANDIJNG EQUIP. FOR ROPE SPEAR RUN OFFICE USE OxLr DEPTH IN 1:45 2:3 0 O:d S 6 INSTALL WEAR BUSHING RI2IDS ,rouRS wrcoxrao P. TOTAL DItaLEO °H j 2:30 3:4 5 1:1 5 6 PJSM, MN ROPE SPEAR BHA, MONROR HOLE Vl4 TRP TANK xouxs w,aPR oP SOLmS 3:15 6:0 0 2:1 5 6 TIH ON ELEVATORS WIROPE SPEAR BHA ON 4" D.P. AB PER 807 MON80R DEiP. VW. TRIP . TOTAL HOURS Q xOURSwnxarO.P. CUTTING STRUCTU RE U TANK xowssrANOBr eNER ouiER Duu cxAR LacATlox MU D BC HEM IC AL ADD ED R P STANDS D TYPE MOUNT TYPE AMOUNT . SINGLES D. KELLY DOW N BFARwGSI eACE OTHER uu cHwi REASON Puuso TOTAL 205.09 SEALS o WT O F STRING iorAL OArwaRx ~ SP ECT DRILL LINE BTY : DOWN N NO O ACC xO. or Onvs FROM Sxuo CWALNAROUNDS CONPLE7E, PJS SPC NICK WHBE TRIPPING GRILL NE SPILLS N PRIOR TO EACH TASK, N LD I'MIN225EC RESPONSE TINE , . gIMV ATNE ROUimc HOUns , ISD=26 % X EC 0 % onEV MUOCasr NLLg,61651K(REC O]x NsD=1039]X ( LEPD=B6B8]%piEC•DI XIUSD=1373]%N 1 Pt • ] RR•116J O 10141 MUOC051 [RRU:0. JUetla Hays ,wn+u=w rw~wx ra,vw NO. DAYS NNQ L45T ~ o~tvwr•,n+arrrw LOSi71NE ACCI DENT ~~~...,w, No. 393063158163 ®~~~~,. No. 393063156163 „~. no. No. 393063158164 DAILY DRILLING REPORT REPORT N0. e • LEASE WELL NO. API WELL NUMBER A TEaoEmt DATE BADAMI ADL-365533 1 6136 50-029-22933-00-00 19+ean20to OPERATOR CONT~CT~ 8~' DAILY DRIWNG REPORT WELL 8136 REPORT NO. 6 DATE t9Mar~2070 SAVANT ALASKA, LLC Doyon Drilling Inc 15 SIGNATURE OF OPERATOR'3 REPRESENTATNE SIGNATUREOF CONTRACTOR5 TOOL PUSXER w~oBpDOwAIaI~FELD ~Nath Maps ATElccuxmr ( Uribd Stabs wllatx+ERECrno RaL xa DRILLMG CREW PAYROLL DATA GaryHarlmon SDambacherlD.Evans sME xexE wacHT ND ~xciH RKe,TO sErnr sMS trES LaxEntMmpao oa,E OP SIZE WEIGHT GRADE i00L JT 0.0. NPE THREAD STRWG NO. PIRJP NO. PUMP MANUFACTURER TYPE eTP1INE GRADE JINNTS ND. 1.375 10 12 ~T 181GMOUrOFF Nd:BENTLBleIN B 19aadr$010 NAMEa NO 4 44.00 5.436 0.875 )R39 096 1 5KYTOP BREWSTER 1600 72.000 cnsWC ID B G 128 511 . 4 BADAMIADW85531/ 8136 2 SKYTOP BREWSTER 7600 42.000 nreING OR LINER 53.315 055 0 wsARGRTRMSaxrtuercur 705 OMWANY 1 aauLAmEwTAROnmcs DDydn DNlli he iooLSUwFn B. 6I5 1024 4 4 BEE T SAanbacherlD.Eram Ms ~ 15 TWE OLRTRBlUia„1HWRB A ~~ SL Y Bn tBCIN~ WAITECORO a srF 1°~ p ,. 1Ob"a~' ° T~ia X01 Pe11 a welw a +y~ Tpyq fMfM 6:00 To 18:00 GN No_E wEanriax n,GH r Dxr . BIT NO. TIME ~.. ~. ~DYO. NAR ~G' .: ~~ NO sac uP ANO rFAaoowx ROPE SPEAR 5.875 B.ST ~ Drille r Chad.bhnson 6 BUAPERSUB 4.750 7.58 WEIGHT OEPTN DEV DIR. ND D EPTH OEV DIA. T VO DE PTH DEV DIR. irD Dardckma n Chffslopef ~sen 5 2Daluacrunl OILJAR 4.TW 11.04 wDC CODE PRESSURE DEVIATION RECORD Motame n Randy Marmon 5 d REAUixc FvMROtnsts 4.6875 1.88 MANUFACNRER GRADIENT Floaman Robert Belmen a waiuG 8 %OVER SPIRAL D C 4.575 1.71 176 45 TYPE FUNNEL M1aai W tib~iA C96Nd psrY0lQdAeMNBaPeaaFMa Raeaq - Fkorman KuR Chary 5 coxDinoNMUU s dciacuutE 1:30 . . . SERIAL NO. VISCOSITY N 6 W 6 3 0 0 3 0 T SERII~E GREASE UPPER 8 LOWER 80P ON TOP ORNE Floaman ~ HaroM Walker 6 s rams 7:30 JETS PvNP I : 6:30 : 10:~ : 4: ~ 19 I ) TIH ON ELEVATORS W! ROPE SPEAR BHA ON 4" D P FI3 950'Mm TI70 020'MD MN TOP DRIVE Pihralche r Jeue Janie 6 T weairarE ac G . . , , , CONNECTION85'IN HOLE T070 112'MD(TAG ON NOGOIUPWT=260 K DOWN WT=180KI Loader O ~ ~ ~ 6 0:30 7FA SiRENGiH H , , WORK SPEAR(OTIMES)UPBDOWN ROTATED IO RPM=)K TOROE WORK TO TAG DEPTH Rac M ra she r Yxicen & with 5 e REFURRic DEPTH OUi FLLnD LOSS , THEN RELEASED TORCE AS PER BOT REP RolnWbom Pushe r Ruddfo Medna 12 cur DEV ADAiuwcuxF DEPTH IN T 10:30 17:3 0 7:0 0 19 , POOH ON ELEVATORS WI ROPE SPEAR BHA ON 4" D P f/ 10 717 MD Rousbboul Clinton Andrews 5 .a oEVArax suave total DRaLEO PH 77:30 18:0 0 0:3 0 79 . . , lA ROPE SPEAR BHA 1 PIECE OF CONTROL LNE APPROX 8" LONG RETRIEVED EkcMcian Mike McDonald 12 I wREUxELas soLlDS Mechanic Marty Crosddier 12 rotAL HOURS T Welder Randy Spencer ty 2RUx GSixc ' dcEMExr CUTTING STRUCTU RE Q SPO 0emla Allen tp Idwnrt oxcwEUr IxNEa GuTEa ouu axR LOCarroN MU CK CHEMIC AL ADD ED <NIPhE WBOP. STANDS D P TYPE MOUNT TYPE AMWNt R Ddlkr JusOn Hays 6 sreov . . SINGLES O Derdckman Russell Gallen 5 ,aoau STEM resr . KELIY DOW N eEAAWCSI sEAU GAGE oTHEa ouu cHrn RFasgJ Pmuo MoWrman Melt Newman 5 nPLUG sun TOTAL 20899 Fklorman Joe Dick 6 WT.O F STRING Fkamtan Stephan LOrd 5 IesouFe2E CEMExr vows SPCC WAUtAR0UND5 COMPLETE, PJSM PRIOR TO EACH TASK, CHECKED COM, MSPECT DRILL WE BTIE DOWN, NO Floomtan Andrew Runkle 5 Is Eia ~ Na0 7:00 ACO NO SPILLSIKICNWHILE TRIPPING GRILL HELDi MIN de SEC. RESPONSE THE ForkliN GaryAMa 6 m ow.wcaN Pihxalcher Shawn FOx g 2, RackMasher Tom Toguchi 6 22 oMUax Jlotln Xnyd NQ DAYSSINCE LAST LOST TIME ACCIOBTf m AT~BED~~ ~T SLY Btt RetiWU! NUD Ra~ORO .4i ~ ~~" TNtt ~ ~ "o, ttw , ao _. a K {y~'ypdUp na M 18:00 Ta s:00 N1Al1 IDOM A PEPfoRAnNC BR NO. TIME hJllW 51R4ND. INJ[ ~.. leflll Iq e TuaWC ra~PS DnYler Roy Files g s¢E WEIGHT Demakman Jason WeNin ty C. raEATNG IAOC000E DEVIATION DEPTH OEV dR. iW DEPTH DEV DIR. ND DEP7H OEV DIR. TM Motomtan MkheelH D. swAeawc MRNUFACTURER PRESSURE GRADIENT RECORD fl0aman umes $hewn CER011 12 E rESnnc FUNNEL ~ Fl C 12 TYPE Ftam Ta ~ taarwa 0WF010pNalw MaepwnddAtlAMSrM oaman heyne FOS 12 SERLAL No. wscoslrY 18 00 19 30 1 7 0 79 N DRESS OFFISCRAPER BHA AS PER BOT REP Flaarman Tmvie Huse fy JErS PvnP ~ : 19:30 : 23 30 : 6:0 0 6 TIH ON ELEVATORS T/10 142'MD MONROR qSP VIA PIT88 HOLE 70011 PROPER DBP Fork LiK Dan Fowbr 1Y " GEL A 13:30 : 0:30 1:0 0 79 , . TAGGED UP 10 412' MD ROT DRESS OFF SHOE OVER STUAP 8 CONE TI 10 120' MD Pil Washer Jason WtUtell 4P TFA STRENGTH , . , Raek Washer Chds Nollner 41 rorALS 1290 72.00 L ~ 0:30 2:00 7:3 0 5 CBUBPUMP 238BL5 H2O SWEEP 170 V8 280 GP 1250 PSI, 16%flO. kIA1(GAS OBSERVED ~ ~ DAYWOPN TIME aUMMA Rr DEPTH OVT O&S L =44060MT5 ROUStabOm GhriE Olsen 42 ancs uss oxLr DEPTH IN 2:00 2:30 0:3 0 19 RID CIRC EOUIPMENT l1D SPACE OUT PUPS xcuas wwaxra o.P. Total ORULED OH T 2:30 6:00 3:3 0 6 . POOR ON ELEVATORS FI 40 12G MD 71279' MD MONROR DISP VIA PD 0S HOLE TOOK novas wgVRDP. , . TOTAL NOURS SoLaS Q PROPER dSP NOJaE WITnDUr DP. CUTTING STRUCTURE U Haassr,woer INVEa ourER wucnAA Locanax MU DB CHEM IC AL ADDE D R P STANDS D TYPE MOUNT TYPE MOUNT . . SINGLES D BARAAN 4 . KELLY DOWN aEARwGSr cola orHER ucHAR REASox PULED TOTAL SEALS ou ioru DArwoaN WT.O F STRING xD. DE Dnrs NOACCSRPILLSSPCC COMPLETED.DJSi wHRCS BEFORE EVERY TASKCHECKED COMORLG LNERIE DN FROM ePUD cuuuLArlu arANxc xcuRS ULSDOL•5815GALSd1L5DRxOGALS-0LSD WOL•101BBLSAYR•TOBBLSWO41BBLS WBSOGALSLEPOOL=SIOBGAL3IEPOR "OGALSIEPDIIw1281GALS oaLVMUOCOSr Taro MUOtcsr 0.Iy F~H1U N O. DAYS SINCE L14Tl O5TTIME ACCID ENT ~,~.. # ~„~ No. 393063158164 ~~., n~. ~ No, 3963458164 ~~a m. No. 393083158161 No. 393663156165 DAILY DRILLING REPORT REPORT N0. 9 LEAS BADAMI AD L365533 I WELL N0. 8136 I WELL NUMBER 50-029.22933-00-00 wATER0EP7yl DATE 204,1an2070 OPERATOR ~~T~ ~P ~' DAILY DRILLING REPORT WELL 6736 REPORT N0. 9 DATE 104r1ao-2070 SAVANTAL SIGNATURE OF GaryH~amo A$KA,LLC OPERATOR'S REPRESENTATNE n DoyonDrillingine 15 SIGNATURE OF CONTRACTOR'S TOOL PUSHER S.DambacherlD.Evars FlEIadtMeiRlLi WNTY STPTEILWNiRY BADAMI FIELD NaN Slope ~~ 0. PN~SfaNs SQE MAKE LENGTH SET AT GR0.0E JOINTS LSO. HO. MIRRECORORFFlN0. s~ xouNES LSxsmawPEO 1.375 10 126 DRILLING CREW PAYROLL DATA DATE 204deri0lD OP$I7E WEIGH T GRADE TOOL Ii O.D. NPE THREAD 51RWGN0. PUMP NO. PUMP MANUFACTURER ttPE sxorcs LAST 13.375 155 4 45 LFIKiN CUi OFF PRESENILENGM t28 5244 WELLNA1E8N0. BADAMI ADL365533 I 8136 4 74 .110 S•135 4.875 7039 49fi t SIMOP BREWSTER 1 600 12.000 caslNG TUBING WEARORIRPSSNCE LASTCUT CIXiANY D l i l 2 SKYfOP BREVJSTER 1 600 12.000 OR LINED Bb25 1021 4 10241 1062 Do on ri l ng nc 7 1247 3 12133 cuMUUTxEwuROR tMPS ~ raoLPUSxEa Mc xD. S.Damoacherl D.Ewrw 75 DRI N AB Y EO BIT REC YUD RECORD !u d CV w-N p +M IbI1M1pY car r w1.Ol ert PIyA nsexa M0 1 4 f IM. y P!xi NOxT TOW fROM IR00 TG 18:00 i 01MY~ THE OMTPoBUTI ON ~ p ~ A T O~ CRIw D14xLD Na MuFE Wli. MML NO toUE OPEPARM Nlcxr 0.r BIT NO. TIME D19kr JusBn Hays 72 xD. O CONCAVE MLL 3314 t rtidanan D Russell Gallen 12 RIGUPAx ! rEAR OOwx BR SUB 7118 1.42 $2E wE1GM DEPTH DEV DI R. TVD DE PTH DEV DIR. T VD DE PTH OEV DIR . T'JD a nan k N M 12 cruA! 9242 1AOC 000E DEVIATpN M010rman ar exT z pRlun g ppC ER 3118 /3N 1A7 PRESSURE RECORD Floomnan Joe Dick 12 s R~,,wG %OY BUMPER SUB d34 TSB MANUFACTURER GRADIENT weerwbaeaAmrAn4Rwwxa pxaNplO flo0rman Stephan Lob 12 <coalxc OIL JAR 1L4 11A4 TYPE FDNNEL vlSCOSITY F!w, fo ~ Co4eN p e floorman Anrkaw RunlJe 12 s coxomoxmu aciRClnarE DOMPgRStlB 4 t1H6 t.6a SERIAL No. pVnp N 6:OD 7:30 1:30 6 CONT: POOH WI $CRADER Ff 277 MD, LN SCRAPER BHA AB PER BOT REP. i BAND 8 3 PIECES ForMiR Gary Altla 12 ER 1718 77 1 I OF CONTROL UNEIMCUP OF SMALL CONTROL LINE&BAND, HOLE TOOK PROPER FILL piNAatcher Shawn Foz 72 craws trop 6;00 %OV . JETS GEL RAl POWER TONGS 1B HANDLING SOUP EOUP RA12 " 12 SFlRAL D.C. / Y4 179.45 G 1:30 9:30 2:00 6 . 7 . HANDLNG RN 4 Rxkxa6her Tam Toguchi F wBRIGrFAa TFA STRENGTH H 9:30 70:75 0:45 6 NN CLEAN OUT BHA WI2717'DP 63314"MILL TICLEAN OUT TUBING STl18 AS PER BOT REP. Roustabout Pusher RudoRo Nadine 12 BREPAIPWC DEPTHOUT FLUID Loss T 1291 MD Roustabpul Nixed Dayton 72 s aroFF CRnuxG UNE oEPTxIN 10:15 14:30 4:15 6 HF129T MD TI70173'MD CLEAN OUT BHAWI LTI CLEAN OUT M Ekc8lcian Mike McDonald 72 iBDfvlArgNSUPVE TOTAL DRILLED pH TUB AS PER BOT REP. TAGGED UP AT 70173'. %X PLUG ~ 10775' GPM. Y FIILCONTROL LINE ' Mechanic Slave CarpenUf 12 I!wwsuNE!ocs q pp TOTAL HOURS Souos T 8 NTOPX%PLUG. DECISION MADE TO NOT A7TEMPf TOdRC. FILL OUT. PULL UP 7070765 WNtler Randy Spencer 12 RUxcASwG ; MO'~WO~' SPO Dennis AYen 72 + 4ncsmEU CUTTING STRUCTURE Q 14:70 78:00 3:30 6 POOH SIDEWAYS F110,173'MDT18,~'L'MD, PN Wi_2pp K, Sp WT=172KMONffOR HOLE nwwT Ox ccmExr. wNEx GurER uucxAR LOCano" MU DSC HEMI CAL ADD ED U FILL ON TRP TANK, SPREAD HERWLfiEBLAY MATS AROUND B138 u NIPP!EweGV. TYPE MOUNT TYPE AMOUNT R !srssr BOe STANDS D.P. SINGLES D. BEAWNG& GAGE OTHEP REASON !sowu srsuresr KELLY DOWN 297 39 SEALS Duu cww Puuo ITmuG eux O TOTAL F STRING . +escuEF4E CEmFx! WT. ON NOACC NO SPILLS NSPECT DRILL !sesxmc 2:00 , . , SPCC WAlNAR0UND3 COMPLETE, PJSN PRKN7 TO EACH TASK CHECKED C RESPONSE TIME 55 SEC SPILL DRILL NELO 7 MIN NE B TIE DOWN . . , L 10 010. WORx fl N0. DAYS SINCE 1A37 LOSTTAIE ACCIOBJT 42 ~ ~ rx -s oa u raeMmx n.ox T Puw xa.a nx- xo.T A0.1 FqY F P~urµw 6Art0wl iMOM 18:00 40 6:00 p~ y W OigTW O ~ ~&Y BiT RECORD MW RECORD x w cone uLF wr r ' raa dYr141 A aERPORAnuG A ~ 317 No. TIME CtlEIY DAlkr t9JKJDPo7 NAME Roy Friha + 72 No Demckman Jason WeRin 72 e. ruxxG rRiPS slzE WEIGHT DEPTH OEV DIR. NO DEPTH OEV DIR. itN DE PTH DEV DIR . TVD mes Mik H 72 c ,REArnc laoc CODE DEVIATION Motomun e u PRESSURE RECORD Floorman Shawn Carroll 72 D. SwAEeINC MANUFRCNRER GRADIENT FlOaman Cheyne Foz 72 E TESxrc rrPE FUNNEL ITY hom Te ~ CobN P DwiF0T0pwFLwr~bSepnMaMtlWnY4 Floorman Travis Huse 12 SERIAL N0. VISCOS pvWp 18:00 223 0 4:3 0 6 POOH SID DP FI 8,897 MD TI4,31T MD. MONITOR D03P VUI PIT RS Fork LM pan FowNr 12 JETS ~ 22:30 0:0 0 7:3 0 6 CONT POOH STD BACK IN DERRICK FI d;31T MD TI 297 ND. MONTOR DISP NA PIT d5 Flt Watcher Jason MNcMII 12 GEL A 0:00 1:3 D 1:3 0 79 WENUA AS PER BOT REP Rack Washer Chds Nollner 72 TFA STRENGTH Y 1:30 2:0 0 0:3 0 19 CLEANBCLEAR RIG FLOOR Roustabout CMis ONen 12 ToTAIS ixnmE t2:0e SUwu t2:00 Rr DEPTH OUT FLUID LOSS q:pp 2;3 0 0:3 0 71 PJSM,RN SLICKLINE ' Garwa oFFVE usE Gxrv DEPTH IN 270 5:3 0 3;0 0 17 . POOH RIH W16.05"GUAGE RWGIJUNK BSKT ON SUCINNE. ENCW NTERED SLUSH ICE ~ 800 " xouxs wicoxrR o P . Toth GRILLED pH T EMPTY BSKT OF SLUSH ICE 2ND RIH qC. TAG UP @ 10174' SLN. POOH. RECOVERED 2.6 xGUxs wIGPROP i01AL HOURS Sa1DS O PECES OF CONTROL LINEIN BSKT. xGUxswlrxcuroB V 5:30 6:0 0 0:7 0 17 RID SLICKLINE C UTTING STRUCTU RE HOUP981A~MBY wxER ouTER DuucxAn LOCanoN CHEM ICAL ADD ED R NOTE: WILL RUN 2T17'iBG. STOP@2100'. CIRG CLEAN DIESELTO SURFACE TO ELIMINATE MU TVPE DB RMOUNT TYPE AMOUNT SLUSH ICEISSUE. THEN PROCEFA IN HOLEWITHTl1G. STANDS D.P SINGLES D. BEARINGSI GAGE OrMER REASON NELLY DOWN SEALS Duu cxAn PuLLEO TOTAL W7.O F STRING Tu GavwoPrc LINE B TIE DOWN ND DRI !a. of wvs FROm sPUG , LL SPCCWALKAFi0UND5COMPLETE, PJSMPRIOR TOEACH TASK, CHECKED CON, INSPECT NO SPILLS OC rumunnvE . A ULSDOL•B813GAL5,ULSDR•732TCFALS,ULSDIk329GALSLEP00l=T091GAL8Jl:PDRO880GAL5,LEPDU~195GAL RDruINC!rouxs NpL~14~BL5•WR=7pBSLSYAk35BBLS CAILYMIx1t0G1 rora.muo cosr eR4LDi Roy FWb ~~" " .,.., N0. GAYS SINCE LAST L0.aT iNJE ACGOFNT °"'^'"""°" ~... „ n.m.ce ~„w~xp.,k No. 593067158165 ~~...,,~„~." ~, No. 393pi315atgo ~~„~. ,•"• No. 393063158166 DAILY DRILLING REPORT REPORT N0. 10 WELL ND API WELL NUM~R ATER OEPTx DATE LEASE BADAMI ADL365533 1 . 8136 50-029.22933-00-00 2f44ar•2o10 CONIHACTOR RIG NO. DAILY GRILLING REPORT WELL 87.36 OPERATOR SAVANT ALASKA, LLC Doyon Drilling Inc 16 RELDDAOISTIECi CDUNfY eTA1EILWNi SIGNATURE OF OPERATOR'S REPRESENTATIVE SIGNA7UREOF CONTRACTOR'S TOOL PUSHER BADANI FlELD Nortl rSlape o Gary Hammon S.Dambacherl D.Evans sDE HAKE ~ GR ~ ADE Jaxrs DP 512E WEIGHT GMDE T DOLRD.D. TYPE THREAD STRING ND. PUMP Nn. PUMP MANUFACTURER TYpE SrRDNE LAST cASIxG 13.375 6 14 00 5135 d.875 %739 496 1 SKYiOP BREVOSTER 1600 12.OOD NBING . 2 SKYTOP BREVVSTER 1600 12000 OR LINER 8.625 7 Y x a+r+ o ~~ coaE ro,oAAtd f TN3E pI8TAlaU7 gNIN NJRB A~~OF BIT R ECORD M UD REC ORD o Aa ,R AYCGk~ WDE aPERAI)oN xIGHr oAV BIT NO. TIME RmuPAxo ~ rEAR aDWrv BIT en SUB 8118 6 OS 3.23 SIZE WEIGHT DEPTH DEV DI R. TVD I z oalu ACrwL IADC CODE PRESSURE DEVIATION RECORD 3 RFAI,u,t '00 MANUFACTURER GRADIENT REPORT N0. 10 DATE 21•BYr-2010 vaAEUrxAECDAO AFFl xo. DRILLING CREW PAYROLL DATA ePe NDUNFa IFNDM 511PFD DAiE 2/YAar-2010 1.375 10 IFNfiill aTaF RRESENTLWleTN 5244 waLxALS:axo. BADAMI ADL385SL31 BWB vrtAAOAmnNxcELASrar c~~ Tli I D D 1974 nc n o on cuuuTlYEwEARDATWFS 0000 rooLfvsNEA S.Dambacherl OEvans Nx .u IP L No.+ roTµ NkINTTOUR yAO a 6:00 ro 18:00 CHEW HOS.IDM0. %4f Driller JusBn Hays Denlckman RuasMl Gallen rvo DE PTH DEV DIR . rvo Mam~RAn ~* Hammes 1. FUNNEL Mn To TM C a W A DN/a~Daypya,aAepNwM4RaRYb e coalxs 7WE VISCOSITY coxortaxMxo NO N 00 6 8:00 2:00 14 DRAIN STACK CIO BOTTOM PIPE RAMS F131T2A6"VARIABLES T127B"$WD 5 6CIRCUL SERIAL . PVIYP I : 8!00 11:45 3:45 21 PULL WEAR BUSHNG, SET TUNNG HANGER W12 WAY CHECK NSTALLED IN PLACE OF TES s TRIPS 12;M JETS Get (~' PLUG, RILDS, PN TEST JT FILL STACK, RIU TEST EQUIP. UNLOAD TOOLS FISHED, CLEAN P r WBRiGTE rac TF0. STRENGTH H 11:45 12:15 0:30 15 TEST ANNULARd2718"Ll3WER PIPE RAMS W1271B'TEST J7, CONT. CLEANI AREPAIRRic DEPTH OUr FLUO LOSS T 12:15 12:45 0:30 15 RID TEST EOUP. BID LINES cur ofF ' DEPTH IN 12:45 15:00 2:15 B RN TI PN 2 7 S" PRODUCTION N _ oxulxcuxE PH 15:00 17:00 2:00 B TIH WI2 TIB"6.5 PPF L30 EUE PI2000CTIg4TUBNG AS PER DETAE T1268'MD6TAG UP, BI oEVlAnaxsuR"E a roTAL ORUEO • WORK STRNG THROUGH TI283' MD, DECISKIN MADE TO POOH B PN CL DOWN STRING WT wlREUxE lots , TOiAI HOURS SOODS ~ , OUT A53. MONROR DISP.ON PR 5, PN WT= 82 K, SIO WT a 82 K z Rux caslxc aCEMENT CUTTING STRUCTURE ~ i7:OD 18:OD 1:00 3 MN BITBBRSUB TI d"DP.STIH T120Y MDSTAG l1P, SET DOWN STRNG Wf PIUBMAKE swert CN CEMExr IxxER ounR ouu cxAR LOCnnax MUD B CHEMIC AL ADD ED V T.D. COFN.AREAM NHOLE TI2IY MD WI50 RP_N,2KTO OFF, PN VJT=88 K, SIO WT=BBK UN TYPE OUNT R e wavLE LP SCa 2:00 STANDS D.P. TYPE u resre.o.P 1:00 SINGLES O. SEArxNGSI GAGE OixEA REASON ,6 t1ULL SrEM TEST KELLY DOWN eEAt3 WLLCMPA PULI® n Pwceacc TOTAL 3.73 WT.OF STRING ,e SpllEEZE CEMENT SC WALNAROUNDS COMPIFIE, PJSM PRgRTO FACH TASK, NSPECT DRILL UNE 6 TIE DOWN, NO ACC. ,9 flsxlw zoom woRh NO SPLLS CHEEd(ED COM, RRE DNLLHELD S4ffC. RESPONSE TIME ~' PuurrTANeus 3:45 oaAl~ ALLIN Hays a ~ ~ Y 617 R6COR0 MUD RECORD T -' w u. m @tlNEWVEe,7 saw iBND O TWR f A PExfoRArlrc BIT NO. TIME e. rueiwc rpms 1:15 SIZE WEIGHT DEPTH DEV DIR. TVD crnurNC IAOC CODE PRESSURE DEVIATION RECORD 'o. SWAreAG MANUFACNRER GRADIENT iEEnNG E P FUNNEL Pmm b 1~I Iy Cadalb OMaaO1DAN~ak BaONxaAAldiMaMA . P TY E o VISCOSITY 1&00 19:00 AI 1:00 6 REAM IN MOLE FI 227 MD TI235' MD, 65 RPM, tOK WOB . . SERIAL N Pvm 0 LN BRBBR SUB 235'MD f D SETS 18:00 19:30 0:30 6 . POOH l T WEARBUSHING " cEl /~ 19;30 pg;gp 2:W g COLLARS. SE NBRACK BACK6JTg4314 N TFA STRENGTH Y 21:30 23:00 1:30 6 P T torus 11:00 32A0 DEPTH OUT FLUID 23:W 0:00 1:00 6 REAMIN HOLE F1235 BO T1250'MD, 50 RPM,5$K WOB oArwwxnME SUMMA Rr toss 00 2 00 6 RIU BOT SWNEL ROTATRIGIGRC HEAD, DP PUPS S CRC HOSE LINE afTlcEUSE cav DEPTH IN PH 0:00 2: : 00 6 ASHSRFAM WICONTAMNATED DIRTY DESEL FI25O MD TI2S0'MD, 95 xaxs wicoxmoP TOTAL ORIUeO T 2:00 3:00 1: xwas wlcPaor. TOTAL HOURS SOLIDS O 20 RPM, 2K TO 3:00 3:50 0:30 6 RN BOT SWRkL HEAD Rcuxewnlum o.P. CUTTING STRUCTURE V 4 00 30 0 6 ATTEMPT TI RIH FI280'MD, OBSTRUCTK)N~300'MD, ATTEMPT TI ROT7 xtuAS sraxoav wra•.R ou1ER ouu cHAx LDCATION MUDB CHEMI CAL ADD ED R 3;30 4:00 : 6:00 : 2:00 B RIU BOT SWArEL HEAD, CONT WASHSREAM F1300'ND TI378'MD STANDS O.P. TYPE MOUNT TYPE AMOUNT SINGLES D. eEARwcsl cncE OMER REASON KELLY DOWN SEALS ouu GRAB PuucO TOTAL rare oxrnowc WT.OF STRING xo of oars A~SPILLS SPCC COMPLETED,PJSWHRCS BEFORE EVERY TASKCHECKED COMORLG LNERIE ON. • FROM EPLD amunnvE ULSDOLe8088GAL3,ULSOReOGALS,ULSDU•12gGALSLEPDOL=5363GALS,LEPDRaOGALS,LEPDIk1T28GALS WOLF Aornuxcxouas 150 BBLS•1AR =70 BBL54Vll=82 BBLS ngILV MiO C0.Si DRLIER ^ Tcix uuocasr Roy Fritle ,,,,, . e.,~."~~ N0. 383063153166 m~~u~ ~~' No. 38306315BI66 ND. 15 Roustataul Pusher RudoNO Med'na iZ Roustabout Allred Dayton 12 FJetdiclan Mike McDonald 12 Medrenk Steve Carpenter 12 Waller Randy Spencer 12 cm rY.n.,e alien 12 N0. DAYa eIXCE LABT LOSTTNE ACCIDENT -•-- 9aT i0NAiouA ~- rAdr 1 DREW 1811PLa1MR d~_ NAAE NM. a1IAAL 12 12 12 12 12 12 12 12 12 12 Fborman Tmu Huse Fork LM Dan Fovder PKWaMrer Jason Mitchell Rock Washer Chris Noliner Rastahout Chris gSBn N0. OAYeaINCE LABT LDai TINE ACCIDENT N0. 3930fi31581fi6 u„ 3R3nR11se1s7 DAILY DRILLING REPORT REPORT N0. 11 1~II I i• LEASE BADAMIADL-365533 1 WELL N0. B1J6 API WELL NUMBER 50-029-22933-00-00 WATER DEPTH DATE 2244ar-2o1a OPERATOR SAVANT ALASKA, LLC SIGNATURE OF OPERATOR'S REPRESENTATIVE Gary Hammon CONTRACTOR RIG N0. Doyon Drilling Inc 15 F SIGNATURE OF CONTRACTOR'S TOOLPUSHER S.Dambacher 1 D.Evans NERONE OPSIZE WEIGHT GRADE TOOL Jt 0.0. TYPE THREAD eTAINGNO. PUMP NO. PUMP MANUfACTUREP TYPE 4 14.00 5135 4.x75 7(739 4% 1 2 SNYTOP RREWSTER 1 SKYTOP BREWSTER 1 600 600 12.000 12AW 7111E INSTRaU110N AT~OF TAY BR RECOflO NUD RECORD ~ ovEAAnax xiGNT DAV BIT NO. TIME ND ~ RI6UPAN0 SQE 1EAR [OWN WEIGHT x DRiu ALNAI IADC CODE PRESSURE 3 RFAMMJC 5:00 MANUFACTURER GRADIENIT a LORNG TYPE GUNNEL wscosrcr N coxomoxMw s ac,RwLArE 4:30 1:30 SERIAL N0. PVIYP e TaPS 1:30 1:30 JETS GEL G' r tU6aiCATEAG TFA STRENGTH u FLUID El e REPURRic DEPTH OUT LOSS T cur aFF N aR4LNG lNJE DEPTH IN H P DEViAnOx SUAVE TOTAL DRILLED SOLIDS T i,wiaaiNE Lacs T07AL HOURS ~zauN CASwc CEME 1 CUTTING STRUCTURE iswul cx cEMExr wNER ouTER Duo cxAR Lacarax DB CHEMI CAL ADD ED V u NiPPLELV Ba.P. MU TYPE MOUNT TYPE AMOUNT R R STANDS D.P uTESreo SINGLES D. BEARINGY GAa OTXEA RFABDII ~NDmu s1EMTESr NEILY DOWN SEALS Duo Cx49 PuueD n vLLU emrc TOTAL WT.O F STRING ~B SaUEEZE CEMWI Is Fisxiuc ~C WALNAROUNDS COMPLETE, PJSN PRpRTO EACHTASK, NSPECT DRILL LINE d TIE DOWN, CHECKED COM,NOALC.NO SPLLS, KICKWHILE TMPPING DNLL HELDI NIN 59 SEC RESPONSETIME zo Doc woRR x~ gWNSTAgC 1:00 OPoLIEx ~ xa A PERFDRATixG Juatln Wya OP1t4.RAT A~S SE11BlY BITAECOIiO BIT NO. YUD RLi00RD TIME s rAiPS B. ruax g00 6IZE WEIGHT c. iREATNG IADC CODE PRESSURE 0. SWOaBNL NIANllFACNRER GRADIENT ]EanNa TYPE FUNNEL c VISCOSITY SERIAL NO. PVfiP G JET9 A x iFA GEL STRENGTH rDEALS 1ZA0 SDMMN 7YOD N DEPTH OIR FLlpo LOBS DAYWDRNPME aEFltEUBE INIUR6 WItaNleaP, DNLV DEPTH IN PH T R DP TOTAL DRILLED SOLKIS . xDUaSw~CP TOTAL.HOURS Q xaxswnxour D.P. CUTTING STRUCTURE V XWRBSIANDBY wxaR ourEA DULL diA R LDCnnoN MUD d CHEM ICAL ADD ED R AMOUNT STANDS D.P . TYPE MWNT TYPE SINGLES D. KELLY DOW N eEARiNGSI SEALS GAGE DrHER DULL CXA AEASGN R PULIED WT. TOTAL OF STRING TDrALDArwDRN xt. of DArs maMSPUD GanuAnvs RDrAriNCxaRS 9i gDCCWALNARWNDSCOMPLETE, PJSM PRIOR TO EACHTASK, CHECKED COM, NSPECT DRILLLNE LTIE DONN. NO ACC.NO SPILLS ULSDOL•7036GALS,ULSDR=OGALS,ULSDW1052GALSLEPDOL•3568GALS,LEPDR~OGALS,LEPDU•1TS7WL6 yypL=133 BBlS WR•708BL3 WU•97 B6L5 pAILYNW C0 iOrAL MUDta91 OPoLLa Roy FdxN No. 393063156167 GAILY DRILLING REPORT WELL B1-36 REPORT N0. 11 DATE 2244ar-2010 EooaasmDT cauxTr eTATEICWmaY WwEUxE AECaNDa~xD. DRILLNG CREW PAYROLL DATA BADAMI FIELD NOdh SlDpe AK I United Sdbs SI7E NM(E ~ JgNf4 LENGTH ~Np SET AT ~ 1.375 NOUNEe 10 LFN01xSLPNEO DArt 224,10r-2010 laST CASING 13.375 4556 ~ ENOTx tuioR vRFSFNrLamx ~ WF1lNALEaxo. BADAMIADL385533I 1UEING R LINER 9.fi25 iD246 1D2 a11RIP5NNCELABTCUI f9$4 DMPAXY RDNR Inl C uNDLArrNEwEARORrPoPS TOOteusxRL Evars charl D S D t 7 1N33 1 9559 . . em w nw ~ : No.N race • wrw ~~ Ran 16:00 a~ a wn a a roar rDnIATNM TxSF vrt nir rD - ND, ~ con aide BAOLbNO. MAMf DEVIAT RECO ION RD ,...,.,,,..,... ~ FkxNman ..._....._..__- Dick 9 4 A +~aA eR Fbaman Stephan Lord pO"' 6:00 TO 6:15 1 ara 11m• 2:15 C0a'N° 3 n ae OUlra~loB•au•w CONE WASHING d REANdNG IN HOLE W7BOT SWIVEUCIRC HEAD F13T6' MD TI391' MD 2 BPM, Fbaman FoddiR Andrew Runlde Gary AMa 6:15 8:30 0:15 6 170 PSI WI NO RPM, PN WT•68 K, SIO WT=BB K, MONROR HOLE ON PITS POOH WI MILL d SCRAPER FI 391' MD, MONTOR HOLE FILL ON PR 5 pilwatther Rackwastler Shawn Foz Tom Toguchi 8:30 9:30 9:30 10:15 1:00 0:45 21 6 DRAIN STACK, PULL WEAR BUSHING, NSTALL CORRECT WEAR BUSHNG LN L30T SWNEUGRC IffAO 8 HANDLING EQUIP. lIN LINES, BLINDS SHUT RousFiboul PuffiTer Roustabout Rudolfo Medinl Need Dayton 10:75 13:00 245 3 TIH TI4W' MD TAG UP, MAKE T.D. CONN. d WASH IN HOLE REAN9NG WHEN NffDED TI 1,670' Eladrician MNe McDonald 13:00 13:30 0:30 6 MD WI 5 BPM, 290 PSI. 14%FLOW OUT, MONTOR DISP. ON PR 5 TIH ON ELEVATORS F11,87G A1D Tl2,703'Mq PN WT=112K510 WT=112KMONROR GSP. Mechanic ~~ Steve CalperlM Randy Spenur 13:30 15:30 2:00 5 ON PR 5 ~ 2,703' MD CIRC. DIESEL IN %LL 1 WHILE OFFLON)NG CLEAN DIESEL TI PR 5, STAGE HOT gpp Dennis Nlen WATER TRUCK FOR DISPLACEMENT, RN TI REV6i5E OT E7(PFDRINI 15:30 16:00 0:30 5 d REVERSE GRC. DIESEL IN PILL 1 WHILE OFFLOADNG CLEAN DIESEL TI PR 5, STACf xs~nn 1900 2:00 5 HOT WATER TRUCK FOR DISPLACEMENT, REVERSE CIRC. PUMPNG 3088E SWEEP FOLLOWED BY 290 BBL HOT FRESH WATFR ND. DAYS SINCE LASTLOaT 71MEACGOFNT a N n faeaATYfN Lw.p /IIILF rn,T. wt NINIr p eDN TAL OAYTOUR FIIO Y 16:00 Ip w N4NUIa akaE CR®I MIPLD IR Driller Royfriro Dertidunan Jason WeNn OEYIATION DevrN Dev DiR. iV0 DEPTH Dev DIR. rw DEPrN oev DiR. rvo Motorman Mike Humes RECORD Floaman Shawn Carroll ti NY NrnN NN IRrNMILN Floaman Cheyne Fox hr,• To ~ CndNb NIN OwANaONN 4 Floaman Travis Huse 19 30 1 3 0 5 DISP WELL WI DIESEL REVERSE GRC WI ANNULAR CLOSED, 100 GPM, 430 PSI, TOTAL STKS Fcdl ~ pan Fowler 18:00 : : PUAIP®=1122 STKS (95 BBLS) GOOD CLEAN gESEL RETURNS TO SURFACE PR Washer Jason Mitchell 19:30 21:00 1:3 0 6 HW/6"MILLdSCRAPER Rock Washer Chris Ndlner Dd•nn 6:0 0 9:0 0 B RU & RUN 2 7M" COMPLETION STRNG TI 7,357 Ym. MONITOR DISP Vb1 TRIP TANK RoustabaLl Chds Olsen No. 393063156167 NQ MYS SNLE LA9i LOSTTINE ACCIOB7T 12 12 12 12 12 No. 393063156167 xD. No. 393063i5816S DAILY DRILLING REPORT REPORT N0. 12 • LEASE BADAMI ADL-365533 I WF11 N0. 6136 API WELL NUMBER 50-029.22933-00-00 ATER DEPTx ATE 2381ar~2010 OPERATOR CONTRACTOR RB ~' DAILY DRILLING REPORT WELL 8736 REPORT N0. 12 DATE 2181ar-2010 SAVANTALASKA, LLC SIGNATUREOF OPERATORS REPRESENTATIVE Gary Hammon Doyon Drilling Inc 15 SIGNATURE OF CONTRACTOR'S TOOL PUSHER S.DambacherlD.Evans nELOOaMBFRDT ouxrr ATElcauemr BADAMI FIELD NRM Slope AK I MOIad StMes 5¢E Mw(E ~~ ~~ LENGTH CSG. MD SE7Af LNeRECOro ReaxD. Nouxes IErlsTxaNVeo 1.375 10 pRIWNGCREW PAYROLL DATA wre 23#1arv2010 DP SIZE WEIGHT GARDE TDOI JT O.D. NPE THREAD STRING NO. PUMP NO. PUMP MANUFACNAER ME sixorw UST 13.375 455 4 4356 LDimx araF PREBENTLFNGTN 5249 ~~Ea ~ BADAMIADW05533 18130 4 14.00 5-135 4.875 XTJ9 d96 1 SKYTOP BRENSTER 1 600 12.000 cnslNG TuawG 102 wEARCRmfsswcEUSrcur GAMPANY De nDAl6 Inc 2 5KYTOP BREVYSTER 1 600 12AW OR LINER 9.625 1024 / 1~ RIG Nt. T 1243 3 12433 cuuurrrteswaamPS 9~ i001PU9~ SAambadler(D.Evam 15 DR&L1NG JU LSEMBLY WD RECORD x w< xB rxu y Nth PAOa6we t u ~ xwr NIONi TOW /WY 6:00 io 18:00 64M Ma lDON TeIE OA57RIBUtIDN NWpl9 AT END Di tQUR Ni RECORD R a CA49 N%.NNO. NA1[ 1116 AOtYiL 0°E oPEAAn°x ° wcHr onv BIT NO. TIME ONMer JusOn Hays id ~ a0;pp 12:00 18:00 Dsrddlman Russell Gallen 13 RIC UPAm ~ rEARODwN gpE WEIGHT 6 8 6 8 6 8 DEPTH DEV D IR. NO DE PTH DEV DIR. T VD DE PTH DEV DIR . TVD ~ Ma* 13 a oAIUACTUAI IADC CODE PRESSURE . . . 92 pEVIATgN RECORD ~~ Floorman Joe Dkk 13 6 REAMIrw MANUFACTURER GRADIENT 0. 35292 0.35292 0.352 R H N dR rM Floamat Stephen LOrd 13 A coRxc TYPE FUNNEL v15CO51T1' ~ TO aaRR tiw• ~N Ae O6Wp4>ar.ReNNaASR6IINxR e Floamen AMrew RuNde 14 6 ca+o~lruo°ArE'uo s6alAL SJO. PvnP N 6:00 6:45 0:45 B ONT.TIHWI2TIB PRODUTK)N NBNG FI7,353'ND T17,923'MD,PN WS=K, SIOWf=K Forldifl Gary Altla 13 I MONTOR DISP. ON TRH TANK PKwaldler Shawn Fox 13 s rRIPS JETS GEL G 6:45 9:30 2:45 B PN SSSV & RN TI RUN CONR90L DNE AS PER SCHLUMBERGER REP. CINJTROL LINE Rcekwasher Tom Togltchi 73 r weRCArE RIC TFA STRENGTH H PLUGGED PRKIRTO TE IN. COVER 8 THAW. TIE IN TO SSBV 8 TEST 716,000 P51. FOR 10 MIN I RoushbW Pueher Rudolfo Medina 13 s REFAw Rr DEPTH OUT FLUm Loss T ) RouskboW ANred Daybn 13 s cur OEE owwxc uxE DEPTH IN 9:30 14:30 5:00 B CONT. TIN WI2 718 PRODUCTION TUBING F17,353' MD 7110,124' MD TAG UP, PIU WT=142 K; Ekclrkian Sknky WoNard 13 io°EVwTlox SURVE TGTAL DRILLED pH SA) WT =125 K, MONROR DISP.ON TRIP TANK, PN 321 JTS 8' PU 85 PUP, NOTE: REPLAC Mechank Slave Caryenkr 13 lDS Sa 266 WI JT 324, REPLACE JT 287 Wf JT 325 NO CORRECTIDN TO TALLY Welder Randy Spencer 13 I. wIRE1wEIGGS 3:30 7:00 rotAL HOURS . T RN HALLIBURTON WRELINE 114'MD LN JT 231 10 13 Rw aslxG O 1d:70 15:15 0:45 11 , , POOH T1 ' SpO Dercis Allen 1z a cEMENi CU TTING S TRUCTU RE 15:15 18:00 2:45 11 WLM HAD TO WORK RR WI GRICCL 82 WEIGHT BARS ON HALLBURTCN4 W9REDNE 7110,166 IswA~roNCEMEw INxeR ouTER ouu cxAR LOCnraN MU DB C HEMI CAL ADD ED R WIRE TO GET OFF BOTTOM POH WIELINE A=iHRWSM HNVP~wBOV TYPE AMOUNT TYPE AMOUN R=SAFEfYCHAMP sr6srsoa STANDS 0.P. . I SINGLES D. rss esn 0P°E m~ Eo u leoa,u siEMTESr KELLY DOWN ~ ~ P L n RIUGeACn TOTAL G ~a seusEg cEMexi Wi.OF STRIN TIE DOWN N O ACC ~a HSxwc . , SPCC WALKAROIINDS COMPLETE, PJSM PRIOR TO EACH TASK INSPECT DRLL LINE 8 RESPONSE THE IB SEC FIRE DRLL HEL0I NIN SPILLS . . , NO xo mR.noxe ql ORIIIER N0. DAYS SINCE LAST L04T RNEACCIOEN7 zz Juatln Hays ~. c dP ~~ ~. ~, MRn " A~ oAVrO~ fR0 1r 18:00 ro 6:00 ~ O F i Y EIT REWRD MUD RECORD To +> TAU N' CREW 01R1DN0. rMNE TIRO, MFNL ~ APEPfo1141wG BIT NO. TIME Driller Roy FdNS 14 Derrickman Jawn WBNin 13 aruslraG mlPS 8:30 5:00 SIZE WEIGHT pEPTH DEV DIR. ND DEPTH DEV DIR. TVD DE PTH pEV DIR . iVp Mik H 14 ' crREATIxG NDC CODE DEVIATgN ECORD Mokrman e unes ll C Sh 13 PRESSURE R Fborman awn arro o. swAeelw MANUFACTURER GRADIENT Fbaman Cheyne FOx 13 ETESnxc FUNNEL ~R TO E4sea e D°arx 1Mel6r IXDPNMINRInBwIN+ArtlRNSda ° H T i 13 TYPE wscoslTr 71xR O WORK ' Fbaman rav ute s SERIAL ND. Pvrp 18:OD 19:0 0 1:0 0 11 MD HAO T RR WI GRRCL 82 WEIGHT BARS ON HALLIBURTON W82ELINE 1110,166 forX Lift Dan Fowler 13 ~ RE TO GET OFF BOTTOM. POH WIEIJNE pk Walther Jaeon MOchell 1J JETS GEL A 1300 19:3 0 0:3 0 11 WD E4JNE E6N11PMENT Raek Washer Chrk NoBner 13 TFA STRENGTH 0 8 MN HANGER ASSEMBLY b t Chris Olsen 13 TmALS t2:ae t2eo oEPrH OUT FLUID Y 19:30 20:00 20:0 21:0 0 0:7 0 1:0 0 8 ERMNATE CONTROL LINE TI HANGER ou Rousta DA1WUiNiIME oFncEUSS BUA%wRY oxAr DEPTH IN Loss 21:00 22:0 0 1:0 0 B LAND 2718" PRODUCTION ST WEEKLY SAFETY MEETING xouxswlc°nm°P px T 22;00 0:3 0 2:3 0 11 RNIRIH 8INSTALL STANDING VALVE IN TNE%N NIPPLE ON SLICK LINE, POOH SAFETY CHAMP nswlcea ow TOTAL DRILLED SOLIDS 0:30 3:0 0 2:3 0 B RN 8 SET PHL PRODUCTION PACI~R AS PER HALLIBURTON. PSI UP TI500 PN ON TUBING, . xou TOTAL HOURS O PSI UPT13500 PSI ON IDBING, HOLD F130 MN. GOOD TEST. BLEED TUBING PSI HOLD Fl t MIN H.wRSwlTxom o P. CUTTING STRUCTURE U , DDWN 711000 PSI. PSI UP IA T13000.P51 TITEST ANNULIIBIPACKER, HOLD FI30 MIN. G000 TES' IgUR661ANDBV wNEA GuiER ouucxra Lacnnan 8 CHEM ICAL ADD ED R 3:00 6:0 0 3:0 0 11 RiH WI SLICKLNE RETRIEVE STANDING VALVE. RD SLICNLNE UNR MU D OUNT STANDS D.P . TYPE MOUNT i1PE SINGLES D. Y GOW N BEARINGS( GAGE OTXER REASON PuuED KELL TOTAL SEALS Dlu cxAR r°iuDArwaRA WT.OF STRING PJS NDS COMPLETE P W CNECKB]COM M PRIORTO EACH TASK NSPECT DRILL LINE OTIE DOWN,NO xoor oars FRan SPED , ALKARW CC S PLLS , , cu unnvE pCt. NO S ULSD0..010.1GALS,ULSDR~GALS,ULS DU•893GALSiEPDOL•5492GALS,LEPDR •3703GALS,LEPDU=17/7GAL5 WDL= RorwnxG xouRS 158 aBL549R•70 BBLS4IN •44 BBLS uuv AnnccsT NO. DAYS SmCE L0.5i LOST RNEAtC DENT ToiAL N1DC061 pPoLLER ~yf4uf ~~ , ~,• ,a„ •. _ ~ 'V01" Arw. ' u. 1wnA HrMAR R . ~`~,.,.,~~,-. ND. 393063156168 ®,"x`°a'..mA, N0. 4Y4waTao lao ~"~,y..m„ u,. 3a'IOfi3158169 DAILY DRILLING REPORT REPORT N0. 13 • WELL NO. API WELL NUMBER aTER OEPm D ATE LEASE BADAMI ADL -365533 1 61.36 50-029.22933-00-00 zanar3mD 13 DATE 244Aar-2010 CONTRACTOR RIG N0. DAILY DRILLING REPORT WELL 8136 REPORT N0. OPERATOR SAVANT ALA LL SKA C an DTlllin Inc 15 ~ 9 nuooaoreTala cauxTr srarElcw~xrxr UnkedSMps mREUxs RECgN RFFL ND. DRILLWGCREWPAYROLLDATA SIGNATURE OF O , PERATOR'S REPRESENTATIVE SIGNATURE OF CONTRACTOR'S TOOL PUSHER BADAMIFELD NGMSIope ~~ Mo. RI(&io SEi AT LENGTH sae xo uxES Iexca anno o 10 .Are 24Afer•2010 Gary Hammon Dambach9rlingrrMn David Evans smGxE SRE MAKE H0. atADE JaM6 1.375 xaxcurarF pAes6xTL6xcTx w'DiNaMEaNO. BppAMI ADW85S731 8136 OP 912E WEIOH T GRADE TOOL Ji O.D. TYPE THAEaD 6TRINONO. PUMP NO. PUMP MANUFACTRER ER TYFE 1600 12DD0 DA35NG 13375 ~ ~ r C 0^'P'f"r' 4 10. 005.135 0.875 7(739 496 1S KVTOP BRENST YfOP BRE9VSTER 1800 12.000 TuelNC DR LwER 9.625 10244 102 aarMPSSwcELrsrw 2035 DG D191i Inc RIG xD. 2 S K 12u3 12 T wauuTrxTVEAAORTAPS 9fi60 aolnulMR DamWCherAngran Avid Evans 15 7 v p T~ YO l MBHf IDW FIaM 6:00 (0 '16:00 ILAMM Od DRILL64G A8SEyABLY BIT RE CORD I IUD RECORD D o]I¢ rpanox M.ox MM aue..x b. pwlrtdp eo rvewxre . . x s y~ NPY CIaBMI ~~~~ Aa1NL TNIE DISTPJWtI DNH13UR3 ATEKD OFT 12 H J 9 (]Ile OPER41iGN nc. NiGNI DAV &T NO. TIME Ddlku Dertkkman n ays MB Russell Gallen 12 ' iE~ua x sizE wEIGESr o EPTx DEV olA. Tm o cPTH oEV DIR. Tw oEPrx oEV DIA, rvD Mean Mek Newman 12 a oRlu ACmAL I AOC CODE PRESSURE DEVIATION RECORD Floorman Joe Dick iy ~ REAMwc MANVFACTURER GRADIENT 6rRaNdA6ev~a a a FIOOrman Slepharl LOrd 12 TYPE FUNNEL hwn Te ~ Cadxlb 6 ap axlrNalgpxYoo Floaman AaMew Runkle 12 coRwG wSCOSITy N LEAR FLOOR " F Mi% Gary Alga 12 CONGUIGx MUa SER44L NO: 6:00 7:00 1:00 21 HANDLING EWIP. C lN2]IB or 6 smxcuaTE PvrcP I N Ef TWO WAY CHECK AS PER FMC REP. PNwatcher Shawn Fos 12 6rRps JErs GEL G 7:00 0 7:30 00 9 0:30 1:30 21 ERMWATE CONTROL LWE, lA CONTROL LINE SPOOLER, SHLUMBERGER CONTROL LME Rakwasher Tan To¢kFll 12 TFA STRENGTH 7:3 : COR her t P t RudolFo Medina 12 r waRlcprERlc H C-0LS, CLEAR FL Rousle au us 6 REPpw WG DEPTH OUT FLVID Loss T 9:OD 12:00 3:00 16 PJSM. NO ROPE BN LMES RWSIabON A%fed DeylDn d 12 12 curoFr DEPTH IN 12:00 14:30 2:30 21 NRl TREE, CYAN PRS, BN MUOLINE 8 RID EkfclricNn Stanley Woohr s GRiu NCUxE pH 14:30 18:00 300 21 1ST TEST ON HANGEAVOID NO GOOD, ADJUST SPEED CLAMP 8 TEST VOID ON TUBING Mechanic Mere CalperlMr 12 .a oEVw,loxsxavE TOTAL DxaLED HANGERTI5,000 PSI. BLED OFF /0 PSL M 10 MIN. TEST TREE TI4,000 PSI, RN M WIJNE, Welder Randy Spencer 12 wwELwE LGCS TOTAL HOURS 6OllDS T g(~ppgy LOLL, RN F40, MW BUCKET, BLEED OFF, CEMENT LINES UNDER FLOOR SFO Dennis A9en 12 Rux cASxc CUTTING STRUCTURE D 'sa fFMExT iawprt orvcnnsur INNER oursa ouu rauR LDCArxw MUD SCHEM ICAL ADDED V TYPE MOUNT TYPE AMOUNT R iaxlPPLLw6cP ]:00 P STANDS D arESrs G.P . SINGLES D I60RRl6iEM rE6i . KELLY DOWN BEDRING61 gAL6 GAGE OTHER DULL CMM REASON PULLED TOTAL RoGeaa WT.O F STRING 1Nfi0UEEIICFMENI PJBM PRKMTO EACH TASK, NSPECT DRILL LINE a TIE DONTI, ~C WAIXAROUTAS COMPLETE 'xrlswrw , NO ACC. NO SPILLS, MAN DOWN TABLE TOP XEID p ptR WORK T LD3T TWEALa DEm A' DRraaowaw 9:00 0:30 ~~ + x ale N0. DAY661NCE LAS fa016 18:00 ro 6:00 asI1~ TMS1 1W zz aD6NDW 3:00 Jusen Han I Data a eaa ~,,R,I rn.ax +uF a ~ xD. 9A7 TdA A 99EMBI.Y 15n RECORD ANN RECORD m AN '° coal eR FRtaMlxe CREW BsR.DKO. MAME MRM aNRLL ~ Z3 rwG ~ ATT END 817 N0 TINE Driller Rey Ffl%e 12 A PEfboRA 8;30 . Dlxddurlan Jason Wekin 12 B. NBINGTNIPS $IlE WEIGHT DEPTH DEV DIR. NO DEPTH OEV DIR. T1D DEPTH OEV DI R. TVO MlMOrman Mike Humes 12 c. mEnrwc IADC CODE PRESSURE DEVIATION RECORD Floaman Shawn Carroll ip o. swAaeRG MANUFACTURER GRADIENT fl00rlllan Che3me f0K 12 F r[sTING rypE FUNNEL hAlr Po ~ Cx/rNR Bltrra DO~aw~laa~YNrAMiMNxlt Floaman Trovi6 Huse 12 viscaslTY LM Dan Fowler 12 IaL NO 18:00 18:30 0:3 0 21 DRY ROD TWO WAY CHECK Fork E . SER PvnP D MAKE WEGHT BAR RIM 701900'. HAD TO WORK EUNE U63f 8 LUBRICATOR PII Watcher Jason Mkchell 12 c JErs 18:30 3:00 8:3 0 A . RN HES MAKE UP 19116' 6' LENGTH TUBING PUNCHER W14 SPF. RIH POH ' d 265 9 k Wesha R Chrls Nollner 12 x TFA GEL STRENGTH A Y . . 5 THRU 2 SPOTS ~ 1 8 PERF 10152' 7010158' PERF GUNS. MAKEUP 2ND 19N5' 6' LENGTH NBING PUNCHER oc RouslabaA Chris Olsen 12 Torahs 12:00 1760 DEPTHDVT 1055 PHASED 45 DEG.OIR Frd>DI Mtl.ARI1.RFRCGTMSa'Tfl1MFS'RnYRaIFIIIF T CLEAN 0.4rwGRrc11Fr 611MM MY 00 3 6:00 3: 00 22 BID 8 RID LMES, RN TI BULLHEAD 13 BBLS METHANOL DOWN TBG ~ 2ER0 PSI. CON IDFF¢E usE oxLr DEPTH IN OH T : PITS. &D STEAM & H2O LMES DISCONNECT AIR, MRID 8 FUEL L91ES xGURSwwoNIRO V . TOTAL DRILLED NOUR6 wropx OP TOTAL NGURS SOLIDS O PoG RELEASED @06:00 wuRSwnxour o.p . CUTTING STRUCTURE U R HouRSSTAxoer INrAR wrER wucHa R LDCarION MU DS CHEMI CAL AD DED 7VPE MOUN T TYPE MOUNT STANDS D.P SINGLES 0 . KELLY GOW N BEARINGSI SEALS GAGE OTHEA DuucHA REASON R Puueo Tarsi WT. OF BTRING Tout opvwoRx PJSM PpOR TO EACH TA6K, CHECKED COM, INSPECT DRILL W E eDE DWVN, Na PA WALKAROUND6 COMPLETE xG. soars LRGM Spun , S pCC.NO SPILLS. CAAW FIRE DRILL HELDQ70:30 IEPDU•1993GALS WOL= LEPDR~GALS S aMUUnw , , ULSDOL=5003GAL5,ULSDRgOGAt3,UlSDU=1140GALSLEPOOL•3S09 GAL acurwG xouxs 90 B8L5, WR•O EBLS,WU=698BL5 NO. DAY651NCE LAST LOST TIME 0.CDIOEm Optr MNCOST '°'" roTU MWCGfir ORa1E11 RoyFrMa Jle` ~a. "' ,wx u., :LA3nR31s9169 ~ "," ~ ilA3 No. 393D631581M „wp~. •~„~ No. 3930631581 >,~~ °~, a WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record /Gamma Ray-CCL Log: B 1-36 Run Date: 3/23/2010 C~ Apri19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 B1-36 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-22933-00 Perforating Record / GR-CCL 1 Color Log 50-029-22933-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr o haburton.com Date: ~~~ ~ ~ ?(?1.? !g~_a~~ 19~5~~ Signed: ~~ t~ trorn • • Page 1 of 1 Schwartz, Guy L (DOA) From: Gary Hammon [ghammon@offshoresystemsinc.com] Sent: Monday, March 22, 2010 9:47 AM To: Schwartz, Guy L (DOA) ( "' f °~ ~ Z 3 Z Cc: Erik Opstad Subject: Savant Weekly Operations Summary for DDI 15 on B1-36 Drilling Operations Savant Doyon 15 from 35/10 to 3/22/10 for B1-36 • Pull & LD 4 %" tubing. Some lost control line was discovered in well. • Made 3 separate DP trips fishing control line • RU & run new 2 7/8" completion string. Encountered some slushy ice in permafrost interval. POH w/2 7/8" tubing • RIH w/DP to circ. out slushy ice/diesel mixture & replace with new clean diesel. Planned Operations on B1-36 for upcoming week • Finish removal of slushy ice from wellbore. Place clean diesel across permafrost interval. • Run new 2 7/8" tubing completion string. Set packer. Pressure test packer, tubing & IA. • Release DDI 15 for move to 61-38 to commence 7 5/8" casing repair Planned Operations on 61-38 for upcoming week • MIRU DDI 15 • Cut & pull 3 %" completion string • Repair 7 5/8" casing communication from IA to OA. Gary Hammon Drilling Manager Savant Alaska, LLC 907-448-6011 North Slope Cell 907-868-1258 ext. 105 Anchorage Office 3/22/2010 Page 1 of 2 Regg, James B (DOA) ~ ~~{ r~_~,~ From: Gary Hammon [ghammon@offshoresystemsinc.com] ~`jC.(.e~~i, g I-3(v Sent: Thursday, March 18, 2010 4:40 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Erik Opstad Subject: RE: Request to Use Portable Gas Monitoring Device on DDI 15 As of 1500 hrs. 3/18/10, DDI 15 Sierra LEL detection system has been tested & is 100% functional. m Gary Hammon Drilling Manager Savant Alaska, LLC Cell: 206-963-6151 NS Cell: 907-448-6011 Savant Office 907-868-1258 ext. 105 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, March 18, 2010 3:42 PM To: Gary Hammon Cc: Schwartz, Guy L (DOA); Foerster, Catherine P (DOA); Seamount, Dan T (DOA); Norman, John K (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Request to Use Portable Gas Monitoring Device on DDI 15 have reviewed your request for a variance to allow the use of portable gas detection meters in the locations where Doyon 15 has 4non-functioning LEL sensors. I understand from discussions with AOGCC Inspector John Crisp last evening (3/17/2010; 8:OOpm) that your gas detection system has failed and crews have been unable to restore functionality for the required 4 sensing points on this rig. Thank you for providing the current specifications of the portable monitoring meters that your are proposing for use. 20 AAC 25.066(d)(3) allows for a variance if the proposed alternative provides at least an equally effective means of gas detection. Your request for variance is approved for the use of portable gas detection meters as a temporarymeasure to allow time for Doyon 15 to repair the rig's gas monitoring system. This approval expires on March 24 or the date of your next BOPE test, whichever occurs first. Jim Regg Inspection Supervisor AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Gary Hammon [mailto:ghammon@offshoresystemsinc.com] Sent: Thursday, March 18, 2010 12:58 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: Request to Use Portable Gas Monitoring Device on DDI 15 I spoke to John Crisp about the content of this email. Savant Alaska, LLC as operator of the B1-36 well at Badami on which DDI 15 is currently working would like to request AOGCC approval to utilize portable gas detection meters in the locations where the 4non-functioning LEL sensors on DDI 15 are placed. These portable battery powered gas detection meters Savant has will monitor for H2S, methane, LEL and oxygen levels. These meters also have an audible and visual alarm. Savant has a total of 7 monitoring meters. With this number of units we will be able to have constant gas 3/18/2010 • Page 2 of 2 monitoring by swapping out meters as needed in order to keep the batteries fully charged. Doyon will continue to trouble shoot the rig's gas monitoring systems until it is fully functional. Once it is fully functional then use of the temporary portable gas detection meters will cease. See the attached information for specifics of each of the 7 monitoring meters. Once the portable gas detection meters are in place on the rig and proper functioning is confirmed Savant will then resume well RWO operations as has been approved by AOGCC. Thank you for your consideration of this request. Gary Hammon Drilling Manager Savant Alaska, LLC Cell: 206-963-6151 NS Cell: 907-448-6011 Savant Office 907-868-1258 ext. 105 3/18/2010 • • ~+;. _ ~~: _ r. .1' ~ ., ,. _. _,.., ~~~~rt~ YES 1 __~~.~ Page 1 of 1 Regg, James B (DOA) From: Gary Hammon [ghammon@offshoresystemsinc.com] Sent: Tuesday, March 16, 2010 9:37 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Erik Opstad Subject: Request for Waiver on Initial BOPE Test on 61-36 Well Attachments: B1-36 -Well Schematic.pdf Mr. John Crisp is the AOGCC Inspector on site. The LEL sensor in the cellar area of DDI 15 is not functioning. Upon successful completion of testing all remaining BOPE components, Mr. Crisp has said that if Savant asked for a waiver that he would give a verbal waiver approval to continue well operations provided the following is done: 1. Anew LEL sensor is currently being installed (2000 hrs. 3/16/10). It will take this sensor approx. 24 hrs. to calibrate itself. 2. During this approx. 24 hr. period Doyon will station a crew member full time in cellar area with a functioning hand held LEL sniffer and with direct communication at all times to rig floor as an alternative to the newly installed remote LEL sensor until it is calibrated & fully functional. At this time the crew member on station in cellar area with the hand held LEL sniffer will be discontinued. 3. Planned well operations during the next 24 hr. period are: a) After BOPE testing is completed, pull & lay down 4 %" tubing which has previously been a-line powercut@ 10101'. b) Pickup & RIH with 4" DP for cleanout to 4 %2" XX plug which is set in 4 %:" tubing tailpipe ar? 10164'. The packer @ 10141' is in place. This XX plug, packer & 7" casing have been pressure tested OK. c) All well perforations are fully isolated from well operations & will continue to be throughout the AOGCC approved procedure for this RWO operation. d) See attached well diagram Gary Hammon Drilling Manager Savant Alaska, LLC Cell: 206-963-6151 NS Cell: 907-448-6011 Savant Office 907-868-1258 ext. 105 3/18/2010 TREE= 4-1116" / 10000 PSI / CNV WELLHEAD = 13-5i8" / 10000 PSI /FMC ACTUATOR = _.~.~.~~,.ri._. KB. ELEV = 53.08' BF. ELEV = 19.5' KOP= Max Angle = 70 @ 12414' Datum MD = DatumTVD= .... II 13-318" CSG, 68#, L-80 BTC, ID = 12.415" I-I 4554` Minimum ID = 3.813" ~ 2236' 4-1 /2" HES HXO SSSV ~ B1-36 SA ES: BPV (o2/oa/oa> 2236' 4-1/2" HES HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3024 2930 10 KBG-2LS 5 4056 3953 5 KBG-2LS 4 6628 6097 46 KBG-2LS 3 9049 7897 34 KBG-2LS 2 9966 8655 28 KBG-2LS 1 10074 8751 26 KBG-2LS 7712' I-{ 9-518" X 7" TIEBACK PKR, ID = 3.875" 4-112" TBG, 12.6#, L-80 IBT-MOD, .0152 bpf, ID = 3.958" 9-518" CSG, 53.5#, L-80 I 10244 I 10141' -j 7" X 4-1 /2" BKR PERM. PKR, ID = 3.875" 10164' 4-112" X NIP, ID = 3.813" 10164' 4-1/2" XX PLUG (02/04108} 10176 4-112" WLEG, ID=3.958" C~ ELMD TT NOT LOGGED 7" X 4-112" LNR HNGR PKR, ID = ???? 12384' ~4-112" X NIP, ID = 3.813" 1236T SLM - 4-~/2° wL PLUG (olio 7" LNR, 29#, P110 BTC, ID = 6.184" ~ 12433' PERFORATION SUMMARY REF LOG: MWD ON ???? ANGLE AT TOP PERF: 54 @ 11700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD} Opn/Sqz DATE 11700 - 11860 C 06/08/99 13840 - 13860 C 06/04/99 13870 - 13890 C 06/02/99 14896 - 14936 C 05!30/99 PBTD 15440' 4-112" LNR, 12.6#, L-80 BTC MOD 15440 .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS ???? ORIGINAL COMPLETION 02/09/08 RCT/PJC 5ET XX PLUG & BPV (02/04/08) 06/02/99 STEWART SET BKR CIBP 02!09/08 PJC LOCATION CORRECTION 06/03/99 JTP INITIAL PERFS _ - 06!06/99 POWERS SETXXPLUG 08/30/06 WRR/TLH FORMAT CORRECTIONS 09/01/07 SWClPJC SET' XX PLUG ~ BPV BKR CIBP (06/02!99) BADAMI WELL: B1-36 PERMIT No: 1982320 API No: 50-029-22933-00 SEC 8, T9N, R20E, 1421' FNL & 94' FWL SP Exploration {Alaska} Page 1 of 3 Schwartz, Guy L (DOA) From: Erik Opstad [eopstad@gci.net] Sent: Monday, March 01, 2010 2:42 PM ~'j ~~ ~ ~'l ~-z 3Z To: Schwartz, Guy L (DOA) Subject: Stuff for this week -Answers. Q (- 3(0 "''"~ Guy: We're thinking that it would not be necessary to perforate the tubing before cutting. The reasoning is that when we cut the tubing on B1-18, the tubing was completely severed and actually "offset" at cut. We know this because HES had some trouble pulling the RCT up after the cut was made (apparently HES has an a-line oil jar to run with RCT assembly this time in case we get hung up on the "offset"). Since we are at a 25° hole angle in B1-36 where the cut will be made, we expect the same "offset" action to occur which is the reason we thought that perforating the tubing before cutting wasn't necessary. We should have plenty of circulating bypass area through the "offset". The only reason we might still want to perforate would be if HES said that it was necessary to relieve the shock force from RCT. We will plan to do all pressure testing after DDI Rig-15 is on well and we are able to displace & get the wellbore fluid packed with hot water as was done on B1-18. This will all be done prior to nippling down the tree. We'll pressure test the BPV as suggested. Erik From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 01, 2010 10:08 AM To: Erik Opstad Subject: RE: Stuff for this week. Erik, Thanks for the procedure. Couple of comments: 1. Before the BOP's are nippled up a test of both the tubing and IA will be needed. You list a test of the tubing only in step 3 (bullet # 3) . Once the tubing is cut, could fluid pack , do a Combo MIT and get both before the rig arrives. (I am not sure what the IA status is... is it fluid packed already or gas?) 2. HAL RCT may need a tubing punch before the radial torch is used to cut the tubing. 3. The BPV should be tested from below also in step 3 (last bullet) before the tree is removed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 3/1/2010 Page 2 of 3 444-3433 (cell) From: Erik Opstad [mailto:eopstad@gci.net] Sent: Monday, March 01, 2010 9:09 AM To: Schwartz, Guy L (DOA) Subject: RE: Stuff for this week. Guy: Wow! Only a 10-403. I had a temporary in the office on Friday because my admin was ill, so I'll bet we dropped the ball in town. Here is the whole package. Thanks, Erik From: Schwartz, Guy L (DOA) [mailto:guy.schwarrz@alaska.gov] Sent: Monday, March 01, 2010 8:49 AM To: Erik Opstad Subject: RE: Stuff for this week. Erik, I have the Sundry request for B1-36 but there are no supporting documents at all. Need the procedure, well sketch, etc. I need these before I can approve the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Erik Opstad [maitto:eopstad@gci.net] Sent: Monday, March 01, 2010 6:38 AM To: Schwartz, Guy L (DOA) Cc: 'Ron Jaye'; 'Gary Hammon' Subject: Stuff for this week. Morning Guy: Things are progressing well on B1-18A at Badami. I've attached a cartoon of the well plan and a couple of snapshots for your viewing enjoyment. We're rotary drilling 80 - 120 fph and sliding 10 - 20 fph to build angle into the target. No issues to report other than a little connection gas and minor crude oil cut in the mud! As of this morning we were circulating a sweep at 10,800' MD with an inclination of 61.7° azimuth of 14.26° on the last survey, which is on plan. My best guess now is that we'll have the hole made by late Wednesday or early Thursday morning. Ron Jay will have a weekly B1-18A operations summary for you shortly if it's not already in your inbox. On other matters: • You should have a Application for Sundry Approvals from us for B1-36 on your desk. I'd like to start the wireline preparation work on the well Wednesday or Thursday of this week, so if you can turn the Sundry around fairly quickly or give 3/1/2010 Page 3 of 3 me a verbal for the wireline prep-work, I would appreciate it. I'm at Badami, so use the NS cell number or email if you have any questions. We ran the leak detection survey on B1-38 the end of last week, which revealed a breach at ~661'MD. According to our casing tally from last year, that more-or-less coincides with coupling #16 in the 7-5/8" casing string, so we are assuming that the coupling failed. We'll have a work plan for the repair put together in a few days, which will be submitted as part of the Shutdown Sundry. Right now our plan is to get back on B1-38 to make the 7-5/8" casing repair as soon as we're finished with B1-18A, then side over on to B1-36. Give me a shout if you need anything else from us near-term. Thanks, Erik SA~AIVT ALASKA Erik Opstad, General Manager Mail To: P. O. Box 112212 Anchorage, Alaska 99511-2212 Office: Fax: ANC Cell: NS Cell: Physical Location: 4720 Business Park Blvd. Suite G40 Anchorage, AK 99503 907-868-1258 x101 907-868-1455 907-244-5210 907-44$-6010 3/1/2010 • • Mr. Erik A. Opstad General Manager Savant Alaska LLC ~~" P.O. Box 112212 ~C~. Anchorage, Alaska 995 1 1-1 122 M~ Re: Badami Field, Badami Oil Pool, Badami B 1-36 Sundry Number: 310-063 Dear Mr. Opstad: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. /'~ DATED this 1 day of March, 2010. Encl. • • ~a,lv ~~~~iv~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNQRY APPROVALS ~ts0~&G»sCoIls.Corrurlission 20 AAC 25.280 1, Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Poot ^ Repair WeII ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing Q Time Extension ^ Operations Shutdown ^ Re-enter Susp. WeII ^ Stimulate ^ Alter Casing ^ Ghange out SCSSSV R GLM Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: /V~~~ ~c~..~i.~+~~,~ ~L~ Development Q ~ Exploratory ^ 198-232 ` 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. BOX 112212, ANCHORAGE, AK 99511-1122 5Q-029-22933-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. WeII Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ pp //~~ ~~//~~ p ,/ ~+ 1~!'''l~Al~l ~ B 1 ~3 V ' 9. Property Designation (Lease Number): 10. Field/Pool{s}: ADL-365533 BADAMI FIELD - BADAMI OIL POOL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft}: Plugs (measured): Junk (measured}: 15,546 12,728.57 15,440 12,623.40 Several BP Legacy None Casing Length Size MD TVD Burst Cailapse Structural n!a Conductor 80' 2D" 91.1# H-40 110' 118' 1,490 psi 470 psi Surface 4518' 13-318" 68ft L-$0 4,554' 4,5{35' 5,020 psi 2,270 psi Intermediate 10,211 9-5/8" 4D# L-80 10,244' 8,962' 5,750 psi 3,090 psi Production 12,403' T' 29# P-110 12,433' 10,599' 11,220 psi 8,51D psi Liner 3,102 4Y::" 12.6# L-80 12,338' - 15,440' 10,565' - 12,623' 8440 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD {ft): 11,70D' - 11,860' OPEN 10,244.67' - 10,344.78' OPEN 4'r4" 12.6# L$0 30' - 10,176' Packers and SSSV Type: Packers and SSSV MD {ft) and TVD {ft): Tbg Pkr @ 10,141' MD - 8869' TVD T' x 4'/" Permanent Baker Packer & 7" x 4'r4" Liner Top Packer Liner Pkr 12338' MD-10575' TVD, SSSV 2236' MD-2222' TVD I 12. Attachments; Description Summary of Proposal ~ 13. Well Class after proposed work: Summary Operations Program Q BOP Sketch Q Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Monday, March 01, 2010 Commencing Operations: Oil Q ~ Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WIND ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Erik Opstad or Gary Hammon 907-868-1258 Printed Name Erik A. Opsta Title General Manager Signature P ne _244-5210 Date Thursday, February 18, 2010 COMM1SS10N USE ONLY /j~ Conditions of approvaP tify Commission so that a representative may witness Sundry Number: / ` `-' ~~/G/~3 Plug Integrity ^ BOP Test ~ Mechanical integrity Test ^ Location Clearance ^ p Other: ~ 3 500 P S ~- ~~ 1 ~ 5 f ~. / Subsequent Form Required: ~ ~ / Q ~ APPROVED BY n 3~f ~~ f/ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 ReviOse~1~~Q9 ~ Submit in Duplicate s'D z. ~ r fc~ ~~/~ • s J ,~ B 1-36 RWO Summary of Proposal & Program Overview General Information Field: Badami ADL# 365533 V1Sell Name: B1-36 Permit to Drill: 198-232 API #: 50-029-22933-00-00 Geometry: 20" @ ±80' MD Conductor-existing 13 3/8 " @ 4,554' MD Surface casing-existing 9 5/8" @ 10,244' MD intermediate casing -existing 7" @12,433' MD Production casing-existing 4'/2" Liner@ 15,440' MD Top of 4'/z" Liner @ 12,338'-existing PBTD @ 15,440' Baker CIBP @ 14060' MD 4'h" Tbg. tail @ 10176' MD Existing tubing SEE V~ELL SCHEMATIC EXHIBIT A Objectives: Optimize B1-36 Production for Badami CPF Restart August 2010 • Retrieve 4'/2" Tubing and Gas Lift Mandrels • Clean out 7" casing to 4'/z" Tubing stub @ -10,140' MD' • Run new 2-7/8" Tubing Completion Assembly with Packer, GLMs, and SCSSSV. • Turn well over to Badami Production Facility. • No Accidents! No Spills! Page 1 of 7 ~A~AIVT ALASKA Summary of Proposal Badami B1-36 spudded November 23, 1998 and reached TD on April 28, 1999. Through two shut-in and re-start cycles of production of the Badami Field, B1-36 has variously produced from the Kekiktuk (14,896' - 14,936' MD), the Killian (13,840' - 13,860' MD) and the- Brookian Pool (11,700' - 11,860' MD). Presently only Brookian perforations are open and both the well and the field are shut-in. Under terms of its Farmout Agreement, requested that BP Explorations (Alaska) Inc. Production Facility (CPF) by August 2010, a number of wells back on production. Savant Alaska LLC (SALLC) has (BPXA) restart the Badami Central t which time SALLC intends to put a To prepare for CPF restart, SALLC proposes a wireline and Rig Workover (RWO) on B1-36 to optimize its production. Prior to its 2007 shut-in the well was producing 543 BOPD and had 2,296 psi static pressure. Since then, static pressure has increase steadily and was recently measures at 2,750 psi in August 2009 (Exhibit B). Savant wishes to take further advantage of the increased reservoir pressure by improving the geometry of the well prior to putting it back on production. In abbreviated summary, this proposed work will: 1. Retrieve existing 4 '/z" Tubing & Gas Lift Mandrels. 2. Clean-out the 7" casing down to the 4 %2" Tubing-Stub @ 10,140' MD' left in-place by operations in Step 1 above. 3. Run new 2-7/8" Tubing Completion Assembly with Packer, GLMs, and SCSSSV. 4. Perforate 3-feet of the 4'/2" tubing tail at 4 SPF between bottom of the 4%i" x 7" permanent packer top at 10,141' (bottom @ 10145') and the "XX" plug @ 10,164' MD to bring the well in. 5. Close SSSV & install BPV. 6. Release the well to Badami CPF Operations pending CPF re-start. Exhibit C provides a schematic of the final completion as proposed. This work will upgrade the safety valve and gas lift systems, while also increasing flow velocity by installation of a more appropriately sized production string. Page 7 of 7 ~iA~ANT ALASKA We expect that increase production velocity and associated heat transfer up-hole, will significantly reduce paraffin precipitation from the crude and its buildup in the production tubing, thus optimizing production rate and decreasing remedial "brush & flush" work thereby improving the economics of the project. The proposed Program to achieve these results is perhaps a bit unorthodox, however, because the reservoir is depleted, we wish to avoid any work that will put fluid against the existing perforations. Given the current depleted reservoir pressure, to do so would most certainly result in loss of that fluid to the formation, thus requiring us to spot an LCM pill or take other fluid loss mitigations steps. As we have seen recently with other depleted Badami wells (B1-18), implementing fluid loss management efforts would likely damage the formation requiring re- perforation to restore production. The proposed SALLC Program never puts any fluid of any kind on existing perforations thereby eliminating likely formation damage and additional costly steps that would be needed to re-perforate the reservoir and bring the well in again. The disadvantages of this approach are that the "XX" plug @ 10,164' MD & WL plug @ 12,367, MD could never be retrieved with this 2-7/8" completion string in place. No a-line or slickline activities could be conducted below 10,164' MD unless Savant ran in thru the 2.31" minimum ID and cut the tubing below to drop the 4%" tubing tail atop the 4%" liner @12,338' MD. We don't see this limitation to be material, because we view the proposed workover program as a short-term optimization of production. Longer-term (12- 24 months) Savant intends to P & A the current production interval in B1-36, and then sidetrack out of the 7" casing to a new horizontal completion at another significantly offset bottom-hole location. Page 7 of 7 „'r`iA~AI'VT ALASKA Badami B 1-36 Wi rel i n e & Ri g Wo rkover Program 1. Check tubing & annulus for any pressure. Bleed if needed. Note: /f tubing p/ug in tai/pipe is ho/ding & packer is sea/ing, there shoo/d be no pressure on either tubing or annu/us. 2. Remove BPV from tubing hangar and open SSSV. Bleed both tubing and annulus pressure to zero. Monitor for any build-up. There should be no build-up if plug in XX nipple at 10,164' MD is holding. 3. MIRU Halliburton Wireline Unit & Crew. Hold Safety/Pre-Job Meeting with crew and Savant HSE & Operations Support. • Rig up HES Lubricator and test to 3,000 psi (rated 10k for H2S service). • Pull BBE wireline retrievable safety valve from Halliburton 4'/z" HXO landing nipple at 2236'. This landing nipple has dual control lines. • Using diesel, pressure test 4.5" tubing to 3,000 psi to insure that "XX" plug set at 10,164' MD is holding pressure. -~!e~i- _~A ~(5~,. • Assuming that the pressure test is good, leave XX plug at 10,164' MD in place where it will remain for the entire workover procedure. • With AC powered instrumentation off and Safety Switch Key outside truck, arm HEs RCT with RF Secure detonator. • RIH with assembly. After depth of 200-ft has been reached, the Safety Switch Key can be used to restore AC Power to unit; continue to RIH. • Tie in to collars and/or gamma ray using log and confirm tie in with final correlation pass. • Log into cutting position, stop winch. • Confirm with company man that tool is at desired cut depth approximately 1' above completion packer at 10,141' MD. • Apply power for tubing cut. POOH when complete. Page 7 of 7 SA~~-I~IT ALASKA • RD E-Line unit. ~ P~ • Install BPV in tubing hanger then nipple down 4-1/16" 10K CIW Xmas-tree -~ '~ NOTE: Have FMC inspect and repair tree as required. 4. Move in and rig up Doyon 15 on B1-36. Record RKB distances to gravel pad and sea level on morning and IADC reports. The recorded DF to sea level on well during initial drilling was 53.9' to MSL (GL 19.1 above MSL. DF 35.3' to GL). Doyon 15 DF is comparably 44.3' DF to GL. Therefore all currently existing DP & tubing measurements referred to in this plan are in reference to a RKB of 53.9' which equates all such depths with Doyon 15 will be encountered 9' lower. Post AOGCC permits and SPCC plan in the Doghouse. • Notify AOGCC for nipple up & pressure test of 13 5/8"5K BOPE. AOGCC notifications remain the same as development drilling requirements. Notify AOGCC Slope Inspector @ 659-2714 or 659-3607 (pgr#) at least 48 hours in advance. • Prior to workover operations, a safety meeting should be held with the rig crews to discuss procedures. • Suggested topics include: / Hole fill calculations with various sizes of pipe and tubing. / Well control procedures. / Proper tripping practices- incl. complete & accurate trip sheets for all trips! / Flow rates and hole cleaning. / Correct and accurate documentation of all BOP tests, LOT's, and safety drills. / Conductor Broach contingency. • An 'Accumulator' drill should be held with rig crews prior to operations. Document drill and record on morning report. • Shut-in drills should be held on a regularly scheduled basis. A suggested minimum is once per day on alternating tours. Document and record on morning report. • Trip sheets must be completed and submitted to the Savant Drilling Supervisor after each trip. Page 7 of 7 • ~A~ANT ALASKA • The trip tank system should be checked for leaks prior to spud. Confirm that all trip tank gauges are calibrated and working properly. Make sure that all crews understand how to utilize and interpret the trip tank system on Doyon 15. • All drills shall be performed and documented as per the written procedures listed in the current 'Drill Expectations and Procedures'. 5. Top flange on wellhead is 11" 10K HUB adapter. Using a 13 5/8" 5K flange stud x 11" 10K HUB Adapter spool, NU 13 5/8" 5K BOP stack with 4 1/2" rams installed. Test all BOPE and choke manifolds per AOGCC. Insure a 2" ID (minimum) check valve is installed in the kill line and is purged and clear at all times. Notify AOGCC 48 hours prior to performing BOPE test • Per AOGCC requirement, all stack tests will have a low 250 psi and a high 5,000 psi test (against test plug). Each test will be held 10 minutes. • The AOGCC requires a BOPE test every 7-days. The AOGCC has indicated that they will be somewhat flexible with this requirement, but the Slope Inspector must be contacted and consulted regarding the seven day test 48 hours before testing. • A 'Stripping' drill should be conducted with rig crews. Document drill and record on morning report. • A 'Well Kill' drill should be held with rig crews. Document drill and record on morning report. • A Well Kill Sheet shall be posted in the doghouse and updated each tour. Following BOPE test and retrieval of BPV from tubing hanger and circulate well with hot water through tubing cut to warm up wellbore. NOTE: At this point pressure test 7° casing to 3, 500 psi. 6. Retrieve tubing hanger pack-off. Back out wellhead hold- down studs on tubing hanger. PU jt. of 4" XT-39 DP with 4 %z" XT-39 box x 4 %" NSCT pin x crossover sub landing joint to screw onto 4'/z" tubing hanger which has 4'/s" NSCT top thread. Have FMC representative on site when pulling hangar. NOTE: Be sure crossover from 4 %A /BTMbox to 2 7/8° EUE 8rd. pin is made for new 2 7/8'° Comp/etion string to be run. Page 7 of 7 'SiA~ANT ALASKA 7. Pull up to shear tubing from cut made 1' above completion packer at 10,141' MD. POOH laying down all 4 %2" tubing string and associated jewelry. Install FMC wellhead wear protector sleeve. NOTE: Send a// 4 i4° tubing to Tuboscope in Deadhorse for c/easing & inspection have 4 ~° /BTM thread protectors on hand to put on tubing during /ay down send 4 %° tubing hanger & pack-off to FMC for refurbishment. Be sure - crossoversub (4 ~° /BTMboxx2 7/8° EUEBrd. pin) is made to go on bottom of tubing hanger for when the new 2 7/8° comp/etion string is run. 8. PU 4" drillpipe and make 7" casing scraper run to top of cut-off stub. Have one (1) joint of 2-7/8" DP with mule shoe guide on bottom of scraper to serve as wash-pipe. Wash to "X" nipple at 10,164' MD. Circulate bottoms up. POOH laying down DP. NOTE: Prior to POH treat water in ho% with app/icab/e biocid~nhibitors as needed. 9. Change BOPE rams to 2 7/8" if not covered by VBR & test. Pull wellhead wear - protectorsleeve. 10. Run new 2-7/8" 6.5 # L-80 EUE 8rd tubing with new SCSSSV and GLM completion string and land with mule shoe wireline entry guide (WLEG) placed just into top of 4%2" tubing cut-off stub. Verify WLEG depth with eline GR/CCL before setting packer. NOTE: Do not over dope tubing. See attached chart for Max/Min recommended make up torque for 2 7/8° EUE 8rd tubing in ft/lbs. FOLLOVI~ COMPLETION STRING RUNNING/PACKER SETTING PROCEDURE NOTE: Make sure the four (4) Gas Lift Mandre/s have been pressure tested with 0° E dummy va/ves wBK Series latch in p/ace. The uppermost GLM to be run is to have a 7.0° SDCK-2 differential dump/ki// valve wBEK type latch in place. This wi// be used to circu/ate diesel freeze protection in ho% after NU free. The bottom GLM/s for a memory gauge. LGL Vs to be insta/led after rig moves off. 11. MIRU Halliburton Perforating Unit & Crew. Hold Safety/Pre-Job Meeting with crew and Savant HSE & Operations Support. 12. Pull BPV and open SCSSSV. 13. RU HES Lubricator and test to 3,000 psi. Page 7 of 7 • sA•AN-r ALASKA 14. PU perforating gun assembly RIH through 2-7/8" tubing and perforate 3-feet of the 4%2" tubing tail at 4 SPF between bottom of the 4%2" x 7" permanent packer top at 10,141' (bottom @ 10145') and the "XX" plug @ 10,164' MD. 15. POH w/gun assembly, verify shots then RD Lubricator, release HES unit. 16. Close SCSSSV. Install BPV. Release well to Badami Production Facilities. They will install flow line, SCSSSV surface controller panel tie-in and well house prior to putting the well on production. NOTE: SubmitAOGCCFo~ms 403/407 within 7days of~ig ~e%ase. Page 7 of 7 TREE= 4-1/16" / 10000 PSI / CM/ WELLHEAD = 13-5/8" / 10000 PSI /FMC ACTUATOR = KB. ELEV = 53.08' BF. ELEV = 19.5' KOP= Max Angle = 70 @ 12414' Datum MD = DatumTVD= ~~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" Minimum ID = 3.813" @ 2236' 4-1/2" HES HXO SSSV B 1-36 SA ES: BPV (02104/08) 2236' 4-1/2" HES HXO SSSV NIP, ID = 3.813" GAS I IFT MANnRFI C ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3024 2930 10 KBG-2LS 5 4056 3953 5 KBG-2LS 4 6628 6097 46 KBG-2LS 3 9049 7897 34 KBG-2LS 2 9966 8655 28 KBG-2LS 1 10074 8751 26 KBG-2LS 7712' ~--{ 9-5/8" X 7" TIEBACK PKR, ID = 3.875" 4-1/2" TBG, 12.6#, L-80 IBT-MOD, .0152 bpf, ID = 3.958" 9-5/8" CSG, 53.5#, L-80 1 I 10244' I 10141' -17" X 4-1/2" BKR PERM. PKR, ID = 3.875" 10164' 4-1/2" X NIP, ID = 3.813" 10164' 4-1/2" XX PLUG (02/04/08) 10176' 4-1/2" WLEG, ID=3.958" ELMD TT NOT LOGGED 12338' ~--~ 7" X 4-1 /2" LNR HNGR PKR, ID = ???? J~ 4-1 /2" X NIP, ID = 3.813" LM 4-1/2" WL PLUG (06/0 7" LNR, 29#, P110 BTC, ID = 6.184" ~ 12433' PERFORATION SUMMARY REF LOG: MWD ON ???? ANGLE AT TOP PERF: 54 @ 11700' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 11700 - 11860 C 06/08/99 13840 - 13860 C 06/04/99 13870 - 13890 C 06/02/99 14896 - 14936 C 05/30/99 PBTD 15440' 4-1/2" LNR, 12.6#, L-80 BTC MOD 15440' .0152 bpf, ID = 3.958" 14060' ~~ BKR CIBP (06/02/99) EXHIBIT A BA DA MI WELL: B1-36 PERMIT No: 1982320 API No: 50-029-22933-00 SEC 8, T9N, R20E, 1421' FNL & 94' FWL BP F~cploration (Alaska) EXHIBIT B 1000000 100000 10000 1000 100 10 1 ~~ `L ~~ `L ~b~ `L R>~ `L~ ~~ ti ~~ ti ~~ `l: R~~ `L ~~ `L R~ `L ~~ `L 4>~ Date ~-Oil (bbls)I f Gas (MCt) • Days On -~ Static Pressure (psia) B1-36 Monthly Production Cum Oil Prod 1,695,115 Need to change out tubing. redesign gas lift valves, and install paraffin inhibition drip. '- " G SAVANT HALLIBURTON Dan Brown, Account Representative ALASKA 6900 Arctic Blvd. Anchorage, Alaska 99518 SCSSSV not shown (907) 275-2600 Customer Savant Alaska. LLC Customer Representative Ga Hammon Well B1-36 Field Badami Date 02/18/10 Casing Slze 7 Casing Weight 29 Casing Grade L80 From 0 To •8400 Tubing Size 2.875 Tubing Weighl 6.5 Tubing Grade L80 Tubing Thread EUE 8 rd Casing Size Casing Weight Casing Grade From To Pick Up Weght Down Weight Block Weght Weghl on Locator Liner Size Liner Weight Liner Grade From To Release Center of Pkr. Elem. Original RT-LDS PBTD ~- F Max. Deviatbn Deviatbn Thru Perfs KOP Release Center of Pkr. Elem. Com pletion Fluid 6HT BHP Perfora~t~on= ~ E Item # Descri tion I.D. O.D. Len th Depth RKB 46.00 0.00 H Tubin Han er 2.441 1.00 0.00 2 7/8" 6.5# Pu Joint 2.441 3.668 4.00 1.00 2 7/8" 6.5# Tubin 2.441 3.668 2185.00 5.00 ~ D 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 2190.00 G 2 7/8" 6.5# TRSV 2.313 7.00 2200.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 2207.00 2 7/8" 6.5# Tubin 2.441 3.668 2278.00 2217.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 4495.00 ~ C F 2 7/8" 6.5# Gaslift Mandrel #3 2.441 7.00 4505.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 4512.00 2 7/8" 6.5# Tubin 2.441 3.668 2046.00 4522.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 6568.00 E 2 7/8" 6.5# Gaslift Mandrel #2 2.441 7.00 6578.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 6585.00 __ 2 7/8" 6.5# Tubin 2.441 3.668 1465.00 6595.00 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 8060.00 ® D 2 7/8" 6.5# Gaslift Mandrel #1 2.441 7.00 8070.00 m a 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 8077.00 2 7/8" 6.5# Tubin 2.441 3.668 1934.00 8087.00 2 7/8" 6.5# x-over IBT-M Box xEUE-M Pin 2.441 3.668 10.00 10021.00 ~ B C T' x 2 718" 26-29# PHL h dr. set acker 2.360 5.980 5.70 10031.00 2 7/8" 6.5# x-over EUE-M Box xIBT-M Pin 2.441 3.668 10.00 10036.70 2 7/8" 6.5# Tubin 2.441 3.668 10.00 10046.70 ~ A 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 10056.70 B 2 7/8" 6 5# X Landin Ni le 2.313" ID 2.313 3.240 1.20 10066.70 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 10067.90 2 7/8" 6.5# Tubin 2.441 3.668 31.00 10077.90 2 7/8" 6.5# Pu Joint 2.441 3.668 10.00 10108.90 A 2 7/8" 6.5# XN Ni le 2.205" NO-GO 2.205 3.240 1.20 10118.90 ~ 1 2 7l8" 6.5# Pu Joint 2.441 3.668 10.00 10120.10 ®: 2 7/8" 6.5# WLEG 2.441 3.900 1.50 10130.10 ® Existin lower com letion ~ 2 1 7" x 4 1/2 " Baker erm. acker 3.875 10141.00 2 4 1/2 X Landin Ni le 3.813" ID 3.813 10164.00 3 4 1/2 X Landin Ni le 3.813" ID 3.813 12384.00 4 Baker CIBP 0.000 14060.00 O en Perforations 11,700' -11,860' MD E EE f- 3 1 E E i _ ~ 4 EXHIBIT C ?J g: 8' '...1» rKi N/pti. AMMAAA S~ m4~ra lol•,~ai+eaa? rsxraw i' 14 illf ~~ CHI i-~ ,ill' 1dL ~~ii/e' Rwa'r~ i+ia vu~ a i/S' saoo P51 sew n• r i FtAMCCfl ~ + Ni ~ R~ ~~ n,' S p~J, t;l' IR6 fiP[RItN43 irct~inot +aw ~ 5 ~MID~EAIt ter' iN'L Oi~,iAi0119 (~ STAOFD t0V/iWHIG] 80"Id BX ?6n,_ 4, ~ 3 a j'a^ SObb ~ HU! VKK Lf a •,/~^ ~wm a~ c+ac wxmc ,IAJUr~ ~ i!U ~swaF n s/a' saao as1 i~' wPi goes IfNP6 FNF: IW+ stlmotn >a'rni~iJOFO eoelar ®r seo ABMIEN 3VO01. N~ r IVaSE BOP SEAC1t ELkl+A710I!i e aic io~ti€ ~ ,• s b. + ui~ F ysr '~ S ~fjlb' Y (d' ACCUMUiATOR MANIFGiy 20 #OTTLES, t= GALLONS EACH t s N~.T ~..6~~uP,~I~TF ! S tt1;E5, 7.25 GU. FT., ~ 3000 P51 vFr irrr.;n Fs=1rv,rpr+. ..~.ocii c~l~uuECeormu .~iNCri1-..w;a ?K ,~ e" flN'l ::L'MCLTCfl C/M 31 f/+' YWC PSI FIANCE VALVE LEGEND '_ t BYRASS 2 If ILL ._. 3 CHGKE _ a t~=roul anus 5 IJO MANS $ 7C~ PIRE RAMS 7 ANNULAR ~ ~ . ~% '~/ tF~ss.u._ i7 0 's t) Q ~ ~ O Ns OFtlX ,~1 4 fl ~'~ a L~ ~=IAOtF PANEL iN OOGHOU~= 2fd=.i..1J!U"' MODULE • C~ SI.kRFACE OIVFStTER CONFIGtkRA31ON • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, March 01, 2010 10:08 AM To: 'Erik Opstad' Subject: RE: Stuff for this week. (3 /- 3G ~w v Page 1 of 3 PTD /9' ~ - 2 3 Z- Erik, Thanks for the procedure. Couple of comments: 1. Before the BOP's are nippled up a test of both the tubing and IA will be needed. You list a test of the tubing only in step 3 (bullet # 3) . Once the tubing is cut, could fluid pack , do a Combo MIT and get both before the rig arrives. (I am not sure what the IA status is... is it fluid packed already or gas?) 2. HAL RCT may need a tubing punch before the radial torch is used to cut the tubing. 3. The BPV should be tested from below also in step 3 (last bullet) before the tree is removed. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Erik Opstad [mailto:eopstad@gci.net] Sent: Monday, March 01, 2010 9:09 AM To: Schwartz, Guy L (DOA) Subject: RE: Stuff for this week. Guy: Wow! Only a 10-403. I had a temporary in the office on Friday because my admin was ill, so I'll bet we dropped the ball in town. Here is the whole package. Thanks, Erik From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, March 01, 2010 8:49 AM To: Erik Opstad Subject: RE: Stuff for this week. Erik, I have the Sundry request for B1-36 but there are no supporting documents at all. Need the procedure, well sketch, etc. I need these before I can approve the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 3/112010 Page 2 of 3 s • 444-3433 (cell) From: Erik Opstad [mailto:eopstad@gci.net] Sent: Monday, March 01, 2010 6:38 AM To: Schwartz, Guy L (DOA) Cc: 'Ron Jaye'; 'Gary Hammon' Subject: Stuff for this week. Morning Guy: Things are progressing well on B1-18A at Badami. I've attached a cartoon of the well plan and a couple of snapshots for your viewing enjoyment. We're rotary drilling 80 - 120 fph and sliding 10 - 20 fph to build angle into the target. No issues to report other than a little connection gas and minor crude oil cut in the mud! As of this morning we were circulating a sweep at 10,800' MD with an inclination of 61.7° azimuth of 14.26° on the last survey, which is on plan. My best guess now is that we'll have the hole made by late Wednesday or early Thursday morning. Ron Jay will have a weekly B1-18A operations summary for you shortly if it's not already in your inbox, On other matters: • You should have a Application for Sundry Approvals from us for B1-36 on your Q desk. I'd like to start the wireline preparation work on the well Wednesday or 3v Thursday of this week, so if you can turn the Sundry around fairly quickly or give ~~-2 me a verbal for the wireline prep-work, I would appreciate it. I'm at Badami, so use the NS cell number or email if you have any questions. • We ran the leak detection survey on B1-38 the end of last week, which revealed a breach at ~661'MD. According to our casing tally from last year, that more-or-less coincides with coupling #16 in the 7-5/8" casing string, so we are assuming that the coupling failed. We'll have a work plan for the repair put together in a few days, which will be submitted as part of the Shutdown Sundry. Right now our plan is to get back on B1-38 to make the 7-5/8" casing repair as soon as we're finished with B1-18A, then side over on to B1-36. Give me a shout if you need anything else from us near-term. Thanks, Erik ~~/~T ALASKA Erik Opstad, General Manager Mail To: P. O. Box 112212 Anchorage, Alaska 99511-2212 Physical Location: 4720 Business Park Blvd. Suite G40 Anchorage, AK 99503 3/1/2010 Office: 907-868-1258 x101 Fax: 907-868-1455 ANC Cell: 907-244-5210 NS Cell: 907-448-6010 Page 3 of 3 3/1/2010 ) I,'~ Pc' f/~-,,', ì~\ in, !/~r i, 1~1ù\': n]:7,/ /,~~ , I' ! :, 'I ' J :', \ i,,1 '.' ,fi ,,¡I'~, \,,' \. í i /, ,i n \, !' i ¡ l ¡ r ' I' I I ".,j '~ \' !!, \ i U 1 \~) LJ 1.r-~' Ll:u-u ® li \~ Lr:\ \ ) AI,A~&A. OIL AND GAS CONSERVAnONCO~SSION / / I j FRANK H. MURKOWSKI, GOVERNOR Carolyn Kirchner Petroleum Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Badami Field, Badami Oil Pool, B 1-36 Sundry Number: 306-220 1;"J- Cb./ 7 \~ Dear Ms. Kirchner: ~CANNfD JUN 2 3 2006 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this22 day of June, 2006 Encl. fie,. 1ð / ~/ ¡ CJ~ c;n,. f.tl L2jO£;. STATE OF ALASKA) AL kA OIL AND GAS CONSERVATION COMMI.....J1oN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Ala~ka Oil &' G~ Cons. Comnission Operational shutdown U PerforateL:J Waiv~ harage Other U Plug Perforations D Stimulate D Time Extension Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Development ~ Exploratory 0 198-2320 /' I' Abandon U Alter casing D Change approved program D 2, Operator Name: BP Exploration (Alaska), Inc, 3, Address: P,O. Box 196612 1. Type of Request: Suspend U Repair well D Pull Tubing D Stratigraphic 0 Anchorage, AK 99519-6612 7, KB Elevation (ft): 9. Well Name and Number: 53.05 KB 8. Property Designation: ADL-365533 11. Total Depth MD (ft): 15546 Total Depth TVD (ft): 12728.57 10. Field/Pools(s): Badami Field / Badami Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 15440 12623A Size MD / TVD Casing Length Conductor 80 Surface 4518 Intermediate 10211 Production 12403 Liner 3102 20" 91.1# H-40 38 118 38 13-3/8" 68# L-80 36 4554 36 9-5/8" 40# L-80 33 10244 33 7" 29# P-110 30 12433 30 4-1/2" 12.6# L-80 12338 15440 10565.21 RE~tEf)'2.¿12..00' JUN 2 0 2006 Service 0 6, API Number: 50-029-22933-00-00 /' B1-36 / Plugs (measured): Junk (measured): Jun-38 None Burst Collapse 118 1490 470 4505 5020 2270 8962 5750 3090 10599 11220 8510 12623 8440 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 11700·11860 Open 10244.67 - 10344.78 Open 4-1/2" 12.6# L-80 13840 -14936 Closed / 11241.64 -12132A4 Closed /' Packers and SSSV Type: 4-1/2" Baker Packer 4-1/2" Liner Top Packer Packers and SSSV MD (ft): 12. Attachments: Descriptive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for /l" Commencing Operations: ~06 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Printed Name Carolyn Kirchner Title Petroleum Engineer Signature n \ . --1'i l L - '(' I Phone 564-4862 Date 'v(,,,"v¿; IA~{ ,,' ,------- COMMISSION USE ONLY Tubing MD (ft): 30 - 10176 10141 12338 /' 13. Well Class after proposed work: Exploratory 0 Developm ent ~ ,/ Service 0 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Date: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: Subsequent Form Required: \ 0 - to ~ Approved bØr ~ . A [MMISSIONER Form 10-403 Revised 7/2005 RIG I N Abandoned 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Carolyn Kirchner 6/20/2006 Sundry Number: ~(Q - a Q.() RBDMS BFL JUN 23 2D06 APPROVED BY THE COMMISSION Date "/2 Z£ c' ,1 i:S/~' 7. /ï'(~ ;' ,,' - i \.~ ',>/, Submit in Duplicate No portion of the belo""~rork should be peñormed w/out fi"'-ltaking time to ensure No Accident~. ,40 harm to People, and No damag~.! the Environment To: B. Green I B. Clemens Well Operations Team Leader Date: June 20,2006 From: Carolyn Kirchner - Badami Production Engineer Subject: B1·36 RePerfs & Adperfs AFE BAWELLOPS Est. Cost: $80,000 Est. lOR: 430 BOPD Type S E lOR 430 430 DSWL B 1-36 B 1-36 AFE BAWELLOPS BAWELLOPS Job Description Drift to TD w dummy gun Re-Perforate 30' of F5 11,800' - 11,830' MD Perforate 10' of F5 11,690'-11,700' MD Re-perforate 20' of F5 11,700'-11,720' MD Perforate 30' of F5 11,670' - 11,700' MD /" Perforate 30' of F5 11,630' - 11,660' MD Perforate 30' at 11,560'-11,590' MD Current Status: Producer Last Test: 05/29/06: BOPD: 430, BWPD: 0; MMCFPD: 1.666 Max Inclination: 71 ° at 12,445 md; 50° at Perfs Max Dog Leg: 27.1 deg/100' at 11,727' md Minimum ID: 3.813" @ 10,164' md, X Nipple Last TD tag: 04/04/02: Brush & Flush TAG TD wi 3.80 GR @ 12320' SLM RDMO Last Downhole Op: 06/09/06: Brush and Flush to 4000' SLM Latest H2S value: None anticipated B 1-36 is one of the two main producers at Badami. It produces from the F5 fan lobe. The well has shown great response to Brush and Flush treatments. Increased production may be achieved through adperf and reperf potential by accessing additional reservoir. Due to the potential of accessing original reservoir pressure in the adperf sections, a step procedure will be used to help gradually bleed off reservoir pressure allowing pressures to equilibrate in the well bore. This will help to / prevent a possible sudden release of reservoir pressure that could sever the gun shooting it uphole or losing it downhole. · Working from the bottom up, reperforate a 30' section from 11,800' - 11,830' MD. · Move up the wellbore to 11,690'-11,700' MD. This 30' interval consists of 10' of adperfs and 20' of reperfs. Allow pressure to equilibrate after shooting this section. · Shoot 11,670'-11,690' MD. Allow pressure to equilibrate after shooting this 20' section. · Shoot 11,650'-11,660' MD. Allow pressure to equilibrate after shooting this 10' section. · Shoot 11,630'-11,650' MD. Allow pressure to equilibrate after shooting this 20' section. · Shoot 11,580'-11,590' MD. Allow pressure to equilibrate after shooting this 10' section. · Shoot 11,560'-11,580' MD. Allow pressure to equilibrate after shooting this 20' section. ) Please note that the adperf interval is dependent on the tag depth. In the event that the drift is unable to access the entire proposed perforation interval, the proposed adperf interval may have to be shortened. /' For questions or comments please call Carolyn Kirchner at 564-4862 (w), 345-0336 (h), or (603) 781-4062 (cell). Abbreviated Historv 04/27/06 BnF: 3.8" GR to 3500', 69 bbls 190*F diesel into Tbg --> 360 bbls oil. 12/19/05 BnF 3.805" GR-->85 bbls oil. 10/04/05 HOT: 3/45/3 bbls Meth/180*F diesel/Meth into IA. 3/40 bbls Meth/180*F diesel into Tbg. 10 bbls 180*F diesel into flowline. 03/31/05 HOT: 271 bbls 150*F diesel into coil, 20 bbls 180*F diesel into lA, 10 bbls warm diesel to clean hardline tanks. 04/04/02 BnF: W/3.8" GR. Tag TD @ 12320' SLM-->35 bbls oil inc. 09/13/99 GL Vs: Pulled DGL Vs @ Sta. #1,3,5 and pulled RP from Sta. #6 and installed dummy. 09/12/99 Fish Tool String @ 10050' WLM. 07/03/99 STP,.., 06/09/99 Perfs: 11700-11860'. i// ) 06/04/99 Plug set at XX Nipple: 12367' WLM. Plugs (KiII iaX:v. 06/03/99 Perf: 13840-13850'. 06/02/99 Perfs: Killian: 13850-13860', 13870-13890'. 06/01/99 Plug Kekituk Formation. 05/30/99 STP OS/29/99 Perf: 13860-13890', 14896-14906'. OS/27/99 Perfs: 14906-14936'. Procedure: Slickline: 1. MIRU 2. Drift with dummy gun. E-Line: 3. Rig up E-Line 4. Shoot perforations allowing pressure to bleed off between shoots of adperfs. · Working from the bottom up, reperforate a 30' section from 11,800' - 11,830' MD. · Move up the well bore to 11,690'-11,700' MD. This 30' interval consists of 10' of adperfs and 20' of reperfs. Allow pressure to equilibrate after shooting this section. · Shoot 11,670'-11,690' MD. Allow pressure to equilibrate after shooting this 20' section. · Shoot 11,650'-11,660' MD. Allow pressure to equilibrate after shooting this 10' section. · Shoot 11,630'-11,650' MD. Allow pressure to equilibrate after shooting this 20' section. · Shoot 11,580'-11,590' MD. Allow pressure to equilibrate after shooting this 10' section. · Shoot 11,560'-11,580' MD. Allow pressure to equilibrate after shooting this 20' section. 5. Move off. ) ) RT. ELEV = 54,8' BF, ELEV = 19,5' MAX, DEV, = 70 @ 12,414' MD TREE: 4-1/16" / 10000 psi / C IW WELLHEAD: 13-5/8"/ 10000 ps i / FMC B1-36 13-3/8" 68#1ft L-80, BTC, CSG, I 4554 I ...~ .. . HES HXO Safety Valve Nipple ID (3,813") c=J 4 1/2" L-80 IBT MOD ~ Gas Lift Summary 12,6#1ft Tubing Camco 1" KBG-2-LS GLM MD TVD DEV 6 3024 2930 10 ß 5 4056 3953 5 4 6628 6097 46 3 9049 7897 34 Tie Back paCkerEJ ] 2 9966 8655 28 ] 1 10074 8751 26 ~ Z Baker 1101411 Permanent Packer 95/8" Intermediate Casing Shoe L-80 110244' I lJ HES X Nipple 9CR 1101641 ID (3,813") ... ~ WLEG ~ ~ ELMD D ZJ ~ 7" X 4 1/2" Liner 11 233~ Wireline plug set in X nipple ~ ~ Hanger Packer HES X Nipple 9CR 11 2384 ID (3,813") T' 29#1ft P11 0 1124331 ... ~ BTC CSG Shoe Deviation @ perfs 50 degrees ~ 4 1/2" L-80 BTC Perforation Summary: MWD Mod Liner Date Interval Status 6- 8- 99 11700-11860 Open ~ Baker CIBP Set at 14,060' 6-4- 99 13840-13860 Plugged ~ 6-2-99 13870-13890 Plugged PBTD 115440 I 5-30-99 14896-14936 Plugged Casing ShO~ DATE REV. BY COMMENTS JTP Initial Perforations BADAMI WELL B1-36 PE RMIT # 98-232 API # 50-029-22933 6-30-99 BP EXPLORATION, INC. 198-232-0 BADAMI UNIT B1-36 50- 029-22933-00 BP EXPLORATION (AL^SK~) INC Roll #1: Start: Stop Roll #2: St~~'' Stop MD 15546/~-TVD 12729 ~C°mpletion Dat .~r~/J'5/27/99~C(°mpleted Status: 1-OIL Current: T Name Interval C 9272 ~'~ 2-8 SCHLUM IMP-ADN OH D 8870~ 4-8 SPERRY MPT/GR/EWR4 PB 1 OH L COMBOMUD-MD~FINAL SPERRY 12485-15546 OH 2 , L DGR/CNP/SLD-TVD/~NFINAL 10615-12163 OH L DGR/EWR4-MD~/~FINAL 4560-11874 PBI OH L DGR/EWR4-TVDC/~FI~AL 4511-10339 PB1 OH L ENG LG-MD6,-~ FINAL SPERRY 12485-15546 OH 2 L GR/CCL-PERF '~'~.FINAL 15274-15482 CH 5 L GR/RES-MD J FINAL 12436-15549 OH L GR/RES-TVD J FINAL 10600-12690 OH L JWL ~ I 9900-10205 5/30/99 CH 5 L NGP/DGR/EWR4-MD I~N~ 4560-14878 OH L NGP/DGR/EWR4-TVDL,~NINAL 4511-12163 OH L NT/DT-MD J FINAL 12436-15549 OH L NT/DT-TVD t~"'~"-- FINAL 10600-12690 OH L PERF-GR/CCLj 1 14880-15142 5/27/99 CH 5 CH 5 CH 5 CH 5 L PERF-PFCGR ~ 1 L PERF-PLUG SE~ 1 L PROD ~ 1 11700-1195O 13800-13982 6/3/99 155-13970 6/4/99 Sent Received T/C/D 7/30/99 8/2/99 2/19/99 2/22/99 2/26/99 3/4/99 5/18/99 5/20/99 5/18/99 5/20/99 5/18/99 5/20/99 3/24/99 3/25/99 3/24/99 3/25/99 3/24/99 3/25/99 3/24/99 3/25/99 5/18/99 5/20/99 5/18/99 5/20/99 7/21/99 8/2/99 7/21/99 8/2/99 7/21/99 8/2/99 3/24/99 3/25/99 3/24/99 3/25/99 7/21/99 8/2/99 7/21/99 8/2/99 7/21/99 8/2/99 7/21/99 8/2/99 7/21/99 8/2/99 7/21/99 8/2/99 L PROD-STAT PRES/~ FINAL 7-12200 7/3/99 CH 5 L SBTJ FINAL 12200-15440 CH 5 L TEMPi' I 12z300-15347 5/30/99 CH 5 R FINAL WELL S UMRY F-W4~'~ SPERRY 12444.62-15486.04 OH R SRVY RIST ,_~SCHLUM 12444.62-15486.04 OH R SRVYRPT ~s/PERRY 0-11874 PB1 OH R SRVY RPT /~g~ERRY 11687.93-14878. PB2 OH 9/20/99 10/8/99. 5/18/99 5/20/99 7/21/99 8/2/99 5/18/99 5/20/99 5/25/99 5/25/99 5/25/99 5/25/99 5/25/99 5/25/99 Wednesday, May 02, 2001 Page 1 ofl BPXA PDC Transmittal Badami Well Log Data Trans# Date: Enclosed are the materials listed below. If you have any questions please contact me in the PDC at 564-4636 90834 o9~20~99 Name -36 Rec Date Record Type Company Log type Jul 03 1999 CASED HOLE LOG .BAKER PRODUCTION PROFILE RECEIVED OCT 0 8 1999 ,.It ),, I/' Please Si=n am] return one copy of this transmittal. Thank You, Scott LaVoie Petrotechnical Data Center BP EXPLORATION Date: 7-21-1999 Trans#90635 BPIBADAMI CASED HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type Log Type Rec Date Company Code 'Comments B1-36 CASED HOLE LOG PERFOPJ~TION 27-May-99 BAKER G~MMA I{AY/CCL RECORD/LOG B1-36 CASED HOLE LOG TEMPERATURE 30-May-99 B~ER DIFFERENTIAL TEMPER3~TURE LOG, LOGS SURFACE RECORDED PRESSURE LOG B1-36 CASED HOLE LOG CASING COLLJ~R 30-May-99 BAiCER JEWELRY LOG LOG B1-36 CASED HOLE LOG PERFORATION 03-Jun-99 BA/CER PLUG SETTING RECORD RECORD/LOG B1-36 C3LSED HOLE LOG PERFORJATION 08-Jun-99 B~ER PFC G~MMA RAY LOG RECORD/LOG B1-36 CASED HOLE LOG PRODUCTION (SPINNER) LOG 04-Jun-99 BAKER Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center CH LOGS Madelyn Millholland MB 3-6 AOGCC FINA DNR Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: 7-30-1999 Trans#90648 BPIBADAMI OPEN HOLE LOGS ~.. ~-~- Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type Log Type Rec Date Company Code Comments B1-36 OPEN HOLE LOG RESISTIVITY 29-Apr-99 SCH GA/Z24A R_AY, COMPOSITE MEMORY LOG iB1-36 OPEN HOLE LOG RESISTIVITY 29-Apr-99 SCH GAI~MA i{AY, COMPOSITE MEMORY LOG 'B1-36 OPEN HOLE LOG DENSITY/NEUTRON 29-Apr-99 SCH COMPOSITE MEMORY LOG POROSITY B1-36 OPEN HOLE LOG DENSITY/NEUTRON 29-Apr-99 SCH COMPOSITE MEMORY LOG POROSITY B1-36 DISKETTE MWD: AZIMUTH3LL 29-Apr-99 SCH DENSITY NEUTRON Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center OH LOGS Madelyn Millhoiland MB 3-6 AOGCC FINA DNR Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 tt L, i13ENTiAL ~ STATE OF ALASKA JUN 2- 4999 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPI~Illi~CCi~~~~LOG Anchorage . 1. Status of Well Classification of Service Well [] Oil E~ Gas [] Suspended E~ Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-232 399-054 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22933 4. Location of well at surface ~'~ ~, 9. Unit or Lease Name ' ' ....... Badami 3859 NSL, 5186' WEL, SEC. 9, T9N, i2OE, UM i-= .r., /,~:t-::-:~''-.' ~:.j ~¢"~ : Unit At top of productive interval ~,.',,J ~ -~ L~ , "'* : B1-36 3545' NSL, 1251' WEL, SEC. 9, T9N, R20E, UM At total depth ,"-':'c ':;" : ;'-~.~ 11. Field and Pool 3411' NSL, 1468 EWL, SEC. 10, TeN, R20E, UM ~,~_~.:_ ! ~' Badami 5. Elevation in feet (indicate KB, DF, etc.) 16. Lea§e'D~S~ln~ti'6d' and Serial No. DF = 53.05'I ADL 365533 12. Date Spudded ,13. Date T.D. Reached, 14. Date Comp.. Susp., or Aband.,15. Water C~epth, if offshore ,16. No. of Completions 11/23/98I 4/28/99I 5/27/99I N/A MSL1 One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 15546 12729 FTI 15440 12623 FTI [] Yes [] No (Nipple) 2235' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, DDS, CBL ;23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 110' 24" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 36' 4544' 16" 3003 sx PF 'E', 533 sx Class 'G' 9-5/8" 40# L-80 33' 10244' 12-1/4" 440 sx Class 'G' 7" 29# P-110 Surface 12438' 8-1/2" 500 sx Class 'G' 4-1/2" 12.6# L-80 12338' 15541' 6" 383 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 2-3/4" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10176' 10141' MD TVD MD TVD Brookian Brookian Kekiktuk Kekiktuk 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11700' - 11860' 10246' - 10346' 14896' - 14936' 12095' - 12133' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Killian Killian 15483' - 15493' Perf'd for 4-1/2" Liner Cement Job (EZSV at 15440') 14060' Set Baker N-1 Bridge Plug for Kekiktuk Isolation 13840' - 13860' 11242' - 11256' 13870' - 13890' 11263' - 11277' 12384' Installed 'XX' Plug for Killian Isolation 2200' Freeze Protect with 80 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) U May 30, 1999I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL iCHOKE 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 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Killian Interval: Silty sandstone, quartz rich, fine to very fine grained. Kekiktuk Interval: Interbedded sandstone, siltstone, shale and hard boney coals. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top of Canning 9733' 8511' Top of Brookian (Badami) 11474' 10094' Top of Killian 13837' 11240' Top of HRZ 14645' 11867' Top of Kekiktuk 14895' 12094' ¢ONrm£ TI L 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Formation Integrity Tests 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ."~_~{~.,, ~ Title TechnicalAssistant Date B1-36 98-232 399-054 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERA': This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEIW 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate.'none'. Form 10-407 Rev. 07-01-80 CONFIDENTIAL 10-407 Attachment, Section 27. Well Name: B1-36 Permit Number: 98-232 APl Number: 50-029-22933 Date First Production Method of Operation (Flowing, gas lift etc) KEK~[KTUK 5/30/99 Gas Lift Date of Test Hours Tested Production for Oil- BBL Gas-Mcf Water-BBL Choke size ~GOR 5/30/99 24 test period 0 3 0 100% ~ not applic, Flow Tub Pres Casing Pres Calculated Oil- BBL Gas-Mcr Water-BBL Oil Gravity APT 320 psi n/a 24-hour rate 0 3 0 not applic, Date First Production Method of Operation (Flowing, gas lift etc) K]:LL]:AN Flowing Date of Test Hours Tested Production for Oil- BBL Gas-Mcf Water-BBL Choke size IGOR 6/3/99 29,75 test period 0 0 0 100% ~ not applic, Flow Tub Pres Casing Pres Calculated Oil- BBL Gas-Mcf Water-BBL Oil Gravity AP! 220 psi n/a 24-hour rate 0 0 0 not applic, Operator BP Exploration Date 22:31, 24 Jun 99 Page 1 Formation Integrity Test for B1-36 The analysis is from - 03:00, 13 Dec 98 - to - 03:00, 13 Dec 98 Programs in Result Table: B 1-36 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Depth MDR Hole Size MDR B1-36PB1 Event 03:00, 13 Dec 98 03:00, 13 Dec 98 0 hr 0 min Obtained required level of integrity 13.5 10277.0 8-3/4 Performance Enquiry Report CONFIDENTIAL Operator BP Exploration Date 22:33, 24 Jun 99 Page 1 Formation Integrity Test for B1-36 The analysis is from - 11:00, 08 Apr 99 - to - 11:00, 08 Apr 99 Programs in Result Table: B 1-36 Re-Drill Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Depth MDR Hole Size MDR B1-36 Event 11:00, 08 Apr 99 11:00, 08 Apr 99 0 hr 0 min Obtained required level of integrity 14.2 12520.0 6 Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 1 Date 23 June 99 Date/Time 21 Nov 98 22 Nov 98 23 Nov 98 24 Nov 98 25 Nov 98 26 Nov 98 27 Nov 98 28 Nov 98 18:00-00:00 00:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-14:30 14:30-18:00 18:00-20:00 20:00-21:00 21:00-21:30 21:30-22:30 22:30-00:45 00:45-01:45 01:45-06:00 06:00-00:30 00:30-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-06:00 06:00-13:45 13:45-15:00 15:00-16:15 16:15-17:15 17:15-18:30 18:30-21:45 21:45-06:00 06:00-12:30 12:30-13:30 13:30-06:00 06:00-09:45 09:45-12:15 12:15-15:30 15:30-18:30 18:30-20:45 20:45-00:00 00:00-01:30 01:30-01:45 01:45-02:00 02:00-02:45 02:45-03:15 03:15-06:00 06:00-14:30 14:30-14:45 14:45-17:45 17:45-18:15 18:15-18:30 18:30-19:30 19:30-20:30 20:30-21:30 Duration 6hr 6hr 1/2 hr 3-1/2 hr 1 hr 1 hr 1 hr 1-1/2 hr 3-1/2 hr 2 hr 1 hr 1/2hr 1 hr 2-1/4 hr lhr 4-1/4 hr 18-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 24 hr 7-3/4 hr 1-1/4 hr 1-1/4 hr 1 hr 1-1/4 hr 3-1/4 hr 8-1/4 hr 6-1/2 hr lhr 16-1/2 hr 3-3/4 hr 2-1/2 hr 3-1/4 hr 3hr 2-1/4 hr 3-1/4 hr 1-1/2 hr 1/4hr 1/4hr 3/4 hr 1/2 hr 2-3/4 hr 8-1/2 hr 1/4 hr 3hr 1/2hr 1/4 hr lhr 1 hr 1 hr Activity Rig moved 25.00 % Rig moved 75.00 % Rig moved 80.00 % Rig moved 95.00 % Rig moved 100.00 % Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Bell nipple Rigged up Kelly Rigged up Drillfloor / Derrick Held safety meeting Rigged up Flowline Made up BHA no. 1 Drilled cement to 110.0 ft Drilled to 280.0 ft Drilled to 1141.0 ft Serviced Other sub-surface equipment Circulated at 1141.0 ft Pulled out of hole to 817.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 1141.0 ft Drilled to 1901.0 ft Drilled to 2425.0 ft Circulated at 2425.0 ft Pulled out of hole to 369.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 2425.0 ft Drilled to 3051.0 ft Drilled to 3490.0 ft Reamed to 3490.0 ft Drilled to 4366.0 ft Drilled to 4560.0 ft Circulated at 4560.0 ft Pulled out of hole to 817.0 ft R.I.H. to 4560.0 ft Circulated at 4560.0 ft Pulled out of hole to 817.0 ft Pulled BHA Removed Drillfloor / Derrick Held safety meeting Installed Casing handling equipment Held safety meeting Ran Casing to 356.0 ft (13.325 in OD) Ran Casing to 4544.0 ft (13.325 in OD) Rigged up Cement head Circulated at 4544.0 ft Held safety meeting Pumped Water based mud spacers - volume 90.000 bbl Mixed and pumped slurry - 130.000 bbl Mixed and pumped slurry - 117.000 bbl Displaced slurry - 700.000 bbl Progress Report Facility Badami CPF Well B1-36 Page 2 Rig Nabors 28E Date 23 June 99 Date/Time 29 Nov 98 30 Nov 98 01 Dec 98 02 Dec 98 03 Dec 98 04 Dec 98 21:30-01:45 01:45-02:00 02:00-02:15 02:15-05:15 05:15-06:00 06:00-06:15 06:15-08:00 08:00-13:00 13:00-14:30 14:30-20:30 20:30-22:00 22:00-02:00 02:00-02:15 02:15-02:30 02:30-05:30 05:30-06:00 06:00-07:15 07:15-08:00 08:00-08:15 08:15-09:30 09:30-13:00 13:00-13:15 13:15-14:30 14:30-14:45 14:45-06:00 06:00-20:30 20:30-21:30 21:30-00:00 00:00-00:15 00:15-01:15 01:15-02:15 02:15-02:30 02:30-03:15 03:15-06:00 06:00-06:00 12:45-13:30 13:30-18:00 18:00-20:00 20:00-22:30 22:30-00:00 00:00-00:15 00:15-01:30 01:30-03:00 03:00-05:45 05:45-06:00 06:00-09:30 09:30-10:45 10:45-11:00 11:00-14:30 14:30-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-22:00 Duration 4-1/4 hr 1/4 hr 1/4 hr 3hr 3/4 hr 1/4 hr 1-3/4 hr 5 hr 1-1/2 hr 6 hr 1-1/2 hr 4hr 1/4 hr 1/4 hr 3 hr 1/2 hr 1-1/4 hr 3/4 hr 1/4 hr 1-1/4 hr 3-1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 15-1/4 hr 14-1/2 hr 1 hr 2-1/2 hr 1/4 hr lhr lhr 1/4 hr 3/4 hr 2-3/4 hr 24 hr 3/4 hr 4-1/2 hr 2hr 2-1/2 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1-1/2 hr 2-3/4 hr 1/4 hr 3-1/2 hr 1-1/4 hr 1/4hr 3-1/2 hr 1 hr 2 hr 1/2 hr 1/2hr 3-1/2 hr Activity Circulated at 2185.0 ft Held safety meeting Pumped Water based mud spacers - volume 120.000 bbl Mixed and pumped slurry - 1030.000 bbl Displaced slurry - 329.000 bbl Displaced slurry - 329.000 bbl Rigged down Casing handling equipment Removed Bell nipple Installed Casing head Installed BOP stack Rigged up Instrument lines Tested All functions Rigged down Instrument lines Installed Wear bushing Made up BHA no. 4 R.I.H. to 2150.0 ft Drilled installed equipment - DV collar R.I.H. to 4443.0 ft Circulated at 4443.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float shoe Drilled to 4580.0 ft Circulated at 4580.0 ft Tested Casing - Via annulus and string Drilled to 5338.0 ft Drilled to 6026.0 ft Circulated at 6026.0 ft Pulled out of hole to 4544.0 ft Held safety meeting Serviced Block line R.I.H. to 6026.0 ft Drilled to 6034.0 ft Circulated at 6034.0 ft Drilled to 6130.0 ft Drilled to 7122.0 ft Circulated at 7404.0 ft Drilled to 7529.0 ft Circulated at 7529.0 ft Pulled out of hole to 1478.0 ft Serviced Draw works Pulled out of hole to 663.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 7529.0 ft Drilled to 7535.0 ft Drilled to 7560.0 ft Took MWD survey at 7532.0 ft Flow check Pulled out of hole to 663.0 ft Pulled BHA Made up BHA no. 6 Held safety meeting R.I.H. to 726.0 ft R.I.H. to 7456.0 ft Progress Report CONFIDENTIAL Facility Badami CPF Well B1-36 Rig Nabors 28E Page 3 Date 23 June 99 Date/Time 22:00-22:45 22:45-06:00 05 Dec 98 06:00-06:00 06 Dec 98 06:00-06:00 07 Dec 98 06:00-19:30 19:30-20:00 20:00-22:15 22:15-23:00 23:00-23:45 23:45-06:00 08 Dec 98 06:00-19:00 19:00-22:00 22:00-22:30 22:30-22:45 22:45-01:30 09 Dec 98 01:30-04:15 04:15-05:30 05:30-06:00 06:00-07:00 07:00-10:15 10:15-10:30 10:30-12:30 12:30-13:00 13:00-14:00 14:00-14:15 14:15-15:30 15:30-16:00 16:00-17:30 17:30-21:45 21:45-22:45 22:45-00:00 10 Dec 98 00:00-00:15 00:15-01:00 01:00-01:45 01:45-04:15 04:15-05:00 05:00-05:30 05:30-06:00 06:00-08:15 08:15-09:00 09:00-12:30 12:30-13:00 13:00-13:30 13:30-16:45 16:45-17:45 17:45-18:15 18:15-19:45 19:45-22:15 22:15-02:30 11 Dec 98 02:30-05:30 05:30-06:00 06:00-15:00 15:00-15:45 15:45-19:30 Duration 3/4 hr 7-1/4 hr 24 hr 24 hr 13-1/2 hr 1/2 hr 2-1/4 hr 3/4 hr 3/4 hr 6-1/4 hr 13hr 3 hr 1/2 hr 1/4 hr 2-3/4 hr 2-3/4 hr 1-1/4 hr 1/2 hr 1 hr 3-1/4 hr 1/4 hr 2 hr 1/2 hr 1 hr 1/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 4-1/4 hr 1 hr 1-1/4 hr 1/4 hr 3/4 hr 3/4 hr 2-1/2 hr 3/4 hr 1/2 hr 1/2 hr 2-1/4 hr 3/4 hr 3-1/2 hr 1/2 hr 1/2 hr 3-1/4 hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 4-1/4 hr 3 hr 1/2 hr 9 hr 3/4 hr 3-3/4 hr Activity Washed to 7560.0 ft Drilled to 7658.0 ft Drilled to 8480.0 ft Drilled to 9180.0 ft Drilled to 9484.0 ft (cont...) Serviced Main engine Circulated at 9454.0 ft Pulled out of hole to 8948.0 ft R.I.H. to 9454.0 ft Drilled to 9775.0 ft Drilled to 10253.0 ft (cont...) Circulated at 10253.0 ft Pulled out of hole to 9689.0 ft R.I.H. to 10253.0 ft Circulated at 10253.0 ft Pulled out of hole to 4500.0 ft Serviced Block line Pulled out of hole to 3372.0 ft Pulled out of hole to 664.0 ft Pulled BHA Held safety meeting Serviced Top ram Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Installed Casing handling equipment Held safety meeting Installed Float shoe Ran Casing to 2829.0 ft (9-5/8in OD) Serviced Draw works Ran Casing to 3429.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 4437.0 ft (9-5/8in OD) Circulated at 4437.0 ft Ran Casing to 6850.0 ft (9-5/8in OD) Circulated at 6850.0 ft Ran Casing to 6890.0 ft (9-5/8in OD) Serviced Casing Ran Casing to 8475.0 ft (9-5/8in OD) Circulated at 8475.0 ft Ran Casing to 10201.0 ft (9-5/8in OD) Circulated at 10201.0 ft Washed to 10244.0 ft Circulated at 10237.0 ft Rigged up Cement unit Mixed and pumped slurry - 90.000 bbl Displaced slurry - 748.000 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged down BOP stack Serviced Seal assembly Serviced Seal assembly (cont...) Installed Seal assembly Installed Casing head Facility Date/Time 12 Dec 98 13 Dec 98 14 Dec 98 15 Dec 98 16 Dec 98 17 Dec 98 18 Dec 98 19 Dec 98 Progress Report CONFIDENTIAL Badami CPF Well B 1-36 Rig Nabors 28E Page 4 Date 23 June 99 19:30-23:30 23:30-00:00 00:00-00:15 00:15-04:45 04:45-05:00 05:00-06:00 06:00-07:30 07:30-12:30 12:30-14:00 14:00-15:00 15:00-16:00 16:00-18:45 18:45-21:00 21:00-23:30 23:30-00:30 00:30-01:00 01:00-02:15 02:15-03:00 03:00-06:00 06:00-11:15 11:15-06:00 06:00-13:45 13:45-15:45 15:45-16:30 16:30-16:45 16:45-17:00 17:00-17:15 17:15-18:00 18:00-22:15 22:15-22:30 22:30-23:30 23:30-00:00 00:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-08:45 08:45-09:15 09:15-10:30 10:30-12:30 12:30-18:00 18:00-18:30 18:30-06:00 06:00-06:00 06:00-06:00 06:00-13:00 13:00-14:00 14:00-01:00 01:00-03:00 03:00-05:15 05:15-05:30 05:30-06:00 06:00-07:30 07:30-07:45 Duration 4hr 1/2 hr 1/4 hr 4-1/2 hr 1/4 hr 1 hr 1-1/2 hr 5hr 1-1/2 br lhr 1 hr 2-3/4 hr 2-1/4 hr 2-1/2 hr 1 hr 1/2 hr 1-1/4 hr 3/4 hr 3 hr 5-1/4 hr 18-3/4 hr 7-3/4 hr 2 hr 3/4 hr 1/4 hr 1/4 hr 1/4hr 3/4 hr 4-1/4 hr 1/4 hr 1 hr 1/2 hr 6 hr 1/4 hr 1/4 hr 1 hr 1-1/4 hr 1/2 hr 1-1/4 hr 2 hr 5-1/2 hr 1/2 hr 11-1/2 hr 24 hr 24 hr 7 hr 1 hr llhr 2 hr 2-1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/4hr Activity Installed BOP stack Held safety meeting Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 6 Made up BHA no. 6 R.I.H. to 9953.0 ft Circulated at 9953.0 ft Washed to 10157.0 ft Circulated at 10157.0 ft Tested Casing - Via annulus and string Held drill (Kick (well kill)) Drilled installed equipment - Float collar Drilled installed equipment - Float shoe Drilled to 10277.0 ft Circulated at 10277.0 ft Performed formation integrity test Circulated at 10233.0 ft Circulated at 10233.0 ft Drilled to 10812.0 ft Drilled to 11094.0 ft Circulated at 11094.0 ft Pulled out of hole to 10226.0 ft Flow check Pulled out of hole to 9756.0 ft Flow check R.I.H. to 11085.0 ft Circulated at 11085.0 ft Flow check Pulled out of hole to 10223.0 ft Flow check Pulled out of hole to 2350.0 ft Pulled out of hole to 658.0 ft Flow check Pulled BHA Downloaded MWD tool Pulled BHA Made up BHA no. 8 Serviced LWD tool R.I.H. to 11084.0 ft Functioned downhole tools at 11084.0 ft Drilled to 11245.0 ft Drilled to 11484.0 ft Drilled to 11725.0 ft Drilled to 11800.0 ft Circulated at 11800.0 ft Drilled to 11872.0 ft Drilled to 11876.0 ft Circulated at 11845.0 ft Flow check Pulled out of hole to 11650.0 ft Pulled out of hole to 10150.0 ft Held safety meeting Facility Badami CPF Progress Report Well B1-36 Rig Nabors 28E CONFIDENTIAL Page 5 Date 23 June 99 Date/Time 20 Dec 98 21 Dec 98 22 Dec 98 23 Dec 98 07:45-08:45 08:45-09:00 09:00-13:00 13:00-13:30 13:30-15:15 15:15-16:15 16:15-16:45 16:45-21:00 21:00-21:15 21:15-23:00 23:00-00:00 00:00-03:15 03:15-04:00 04:00-04:45 04:45-05:15 05:15-06:00 06:00-06:30 06:30-06:45 06:45-07:45 07:45-08:30 08:30-10:00 10:00-10:15 10:15-14:00 14:00-14:15 14:15-14:45 14:45-15:45 15:45-19:15 19:15-20:00 20:00-21:00 21:00-21:30 21:30-22:30 22:30-00:00 00:00-02:00 02:00-02:30 02:30-02:45 02:45-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-09:30 09:30-10:00 10:00-11:30 11:30-14:30 14:30-14:45 14:45-19:00 19:00-20:15 20:15-20:45 20:45-22:00 22:00-06:00 06:00-03:45 03:45-04:00 04:00-06:00 06:00-09:30 09:30-10:00 Duration 1 hr 1/4 hr 4 hr 1/2 hr 1-3/4 hr 1 hr 1/2 hr 4-1/4 hr 1/4 hr 1-3/4 hr 1 hr 3-1/4 hr 3/4 hr 3/4 hr 1/2 hr 3/4 hr 1/2 hr 1/4 hr 1 hr 3/4 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1/4 hr 1/2 hr 1 hr 3-1/2 hr 3/4 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 3 hr 1/4hr 4-1/4 hr 1-1/4 hr 1/2 hr 1-1/4 hr 8 hr 21-3/4 hr 1/4 hr 2hr 3-1/2 hr 1/2 hr Activity Serviced Block line Circulated at 10150.0 ft Pulled out of hole to 653.0 ft Flow check Pulled BHA Serviced SCR Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 9 Repaired Iron roughneck R.I.H. to 8472.0 ft Circulated at 8472.0 ft R.I.H. to 10240.0 ft Circulated at 10240.0 ft R.I.H. to 11750.0 ft R.I.H. to 11792.0 ft Reamed to 11867.0 ft Circulated at 11867.0 ft Reamed to 11869.0 ft Pulled out of hole to 10150.0 ft Flow check Pulled out of hole to 586.0 ft Flow check Pulled BHA Made up BHA no. 10 R.I.H. to 8473.0 ft Circulated at 8473.0 ft R.I.H. to 10231.0 ft Circulated at 10231.0 ft R.I.H. to 11828.0 ft Reamed to 11872.0 ft Milled Other sub-surface equipment at 11873.0 ft Circulated at 11873.0 ft Flow check Pulled out of hole to 10231.0 ft Circulated at 10231.0 ft Pulled out of hole to 6000.0 fl Pulled out of hole to 626.0 ft Pulled BHA Serviced Wear bushing Flow check Made up BHA no. 11 Tested MWD - Via string R.I.H. to 10248.0 fl Circulated at 10248.0 ft R.I.H. to 11717.0 ft Circulated at 11717.0 ft Drilled to 11722.0 ft Drilled to 11736.0 fl Flow check Drilled to 11750.0 ft Drilled to 11775.0 ft Circulated at 11775.0 ft Facility Badami CPF Progress Report Well B 1-36 Rig Nabors 28E CONFIDENTIAL Page 6 Date 23 June 99 Date/Time 24 Dec 98 25 Dec 98 26 Dec 98 27 Dec 98 28 Dec 98 10:00-11:30 11:30-12:30 12:30-16:30 16:30-16:45 16:45-18:00 18:00-21:00 21:00-22:45 22:45-23:15 23:15-02:15 02:15-03:00 03:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:15 06:15-06:00 06:00-09:30 09:30-10:30 10:30-10:45 10:45-12:30 12:30-13:00 13:00-17:00 17:00-18:00 18:00-18:45 18:45-19:15 19:15-19:30 19:30-23:00 23:00-01:30 01:30-06:00 06:00-06:15 06:15-07:30 07:30-08:15 08:15-08:30 08:30-09:00 09:00-10:30 10:30-11:15 11:15-13:00 13:00-13:15 13:15-14:45 14:45-16:00 16:00-06:00 06:00-18:30 18:30-00:00 00:00-01:00 01:00-01:15 01:15-03:00 03:00-03:30 03:30-06:00 06:00-07:00 07:00-08:00 08:00-10:15 10:15-10:45 Duration 1-1/2 hr lhr 4 hr 1/4 hr 1-1/4 hr 3 hr 1-3/4 hr 1/2 hr 3 hr 3/4 hr 1/2 hr 1/2 hr 1 hr lhr 1/4 hr 23-3/4 hr 3-1/2 hr 1 hr 1/4 hr 1-3/4 hr 1/2 hr 4 hr 1 hr 3/4 hr 1/2 hr 1/4 hr 3-1/2 hr 2-1/2 hr 4-1/2 hr 1/4 hr 1-1/4 hr 3/4 hr 1/4 hr 1/2 hr 1-1/2 hr 3/4 hr 1-3/4 hr 1/4 hr 1-1/2 hr 1-1/4 hr 14hr 12-1/2 hr 5-1/2 hr 1 hr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr lhr 1 hr 2-1/4 hr 1/2 hr Activity Pulled out of hole to 10190.0 ft Serviced Block line Pulled out of hole to 626.0 ft Flow check Pulled BHA Made up BHA no. 12 R.I.H. to 3515.0 ft Serviced Drillfioor / Derrick R.I.H. to 10183.0 ft Circulated at 10248.0 ft R.I.H. to 11090.0 ft Functioned M.W.D. tool R.I.H. to 11687.0 ft R.I.H. to 11717.0 ft R.I.H. to 11775.0 ft Drilled to 11982,0 ft Drilled to 11990.0 ft Circulated at 11960.0 ft Flow check Pulled out of hole to 10190.0 ft Flow check Pulled out of hole to 652.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Installed BOP test plug assembly Tested BOP stack Made up BHA no. 13 R.I.H. to 9800.0 ft R.I.H. to 10261.0 ft Circulated at 10305.0 ft R.I.H. to 10972.0 ft Took MWD survey at 10972.0 ft R.I.H. to 11500.0 ft Reamed to 11590.0 ft R.I,H. to 11715.0 ft Circulated at 11715.0 ft R.I.H. to 11730.0 ft Logged hole with LWD: Formation evaluation (FE) from 11720.0 ft to 11922.0 ft Logged hole with LWD: Formation evaluation (FE) from 11922.0 ft to 11990.0 ft Drilled to 12060.0 ft Drilled to 12140.0 ft Drilled to 12185.0 ft Circulated at 12185.0 ft Flow check Pulled out of hole to 10244.0 ft Flow check Pulled out of hole to 4250.0 ft Pulled out of hole to 663,0 ft Pulled BHA Serviced Drilling tool / logs Pulled BHA Progress Report CONFIDENTI^L Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 7 Date 23 June 99 Date/Time 10:45-12:00 12:00-16:45 16:45-17:30 17:30-18:15 18:15-19:00 19:00-19:30 19:30-20:45 20:45-06:00 29 Dec 98 06:00-11:00 11:00-12:30 12:30-13:45 13:45-15:45 15:45-17:00 17:00-20:30 20:30-21:15 21:15-22:15 22:15-00:15 30 Dec 98 00:15-02:00 02:00-02:30 02:30-02:45 02:45-03:15 03:15-03:45 03:45-06:00 06:00-09:15 09:15-09:45 09:45-10:45 10:45-11:30 11:30-12:30 12:30-13:15 13:15-14:45 14:45-15:15 15:15-16:30 16:30-06:00 31 Dec 98 06:00-11:00 11:00-13:30 13:30-14:00 14:00-15:30 15:30-16:30 16:30-22:00 22:00-00:00 01 Jan 99 00:00-06:00 06:00-14:30 14:30-16:00 16:00-17:00 17:00-17:45 17:45-06:00 02 Jan 99 06:00-20:00 20:00-22:15 22:15-22:30 22:30-01:30 03 Jan 99 01:30-04:00 04:00-04:30 04:30-06:00 06:00-09:15 Duration 1-1/4 hr 4-3/4 hr 3/4 hr 3/4 hr 3/4 hr 1/2 hr 1-1/4 hr 9-1/4 hr 5 hr 1-1/2 hr 1-1/4 hr 2 hr 1-1/4 hr 3-1/2 hr 3/4 hr lhr 2 hr 1-3/4 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr 2-1/4 hr 3-1/4 hr 1/2 hr lhr 3/4 hr lhr 3/4 hr 1-1/2 hr 1/2hr 1-1/4 hr 13~1/2 hr 5 hr 2-1/2 hr 1/2 hr 1-1/2 hr lhr 5-1/2 hr 2hr 6hr 8-1/2 hr 1-1/2 hr lhr 3/4 hr 12-1/4 hr 14hr 2-1/4 hr 1/4 hr 3hr 2-1/2 hr 1/2 hr 1-1/2 hr 3-1/4 hr Activity Made up BHA no. 14 R.I.H. to 10270.0 ft Circulated at 10270.0 ft Serviced Block line R.I.H. to 11681.0 ft Set tool face R.I.H. to 12185.0 ft Drilled to 12425.0 ft Drilled to 12480.0 ft Circulated at 12480.0 ft Pulled out of hole to 11493.0 ft Circulated at 11493.0 ft Pulled out of hole to 10272.0 ft Pulled out of hole to 663.0 ft Pulled BHA Serviced Drilling tool / logs Made up BHA no. 15 Serviced SCR Pulled BHA Functioned Drilling tool / logs Made up BHA no. 15 R.I.H. to 2500.0 ft R.I.H. to 3850.0 ft R.I.H. to 10270.0 ft Circulated at 10270.0 ft Serviced SCR R.I.H. to 11227.0 ft Serviced SCR R.I.H. to 11697.0 ft Took MWD survey at 11767.0 ft R.I.H. to 12386.0 ft Reamed to 12480.0 ft Drilled to 12771.0 ft Drilled to 12970.0 ft Circulated at 12970.0 ft Serviced Rotary table Pulled out of hole to 12418.0 ft R.I.H. to 12970.0 ft Drilled to 13179.0 ft Circulated at 13179.0 ft Drilled to 13420.0 ft Drilled to 13743.0 ft Circulated at 13743.0 ft Pulled out of hole to 12723.0 ft R.I.H. to 13743.0 ft Drilled to 14041.0 ft Drilled to 14400.0 ft Circulated at 14400.0 ft Flow check Pulled out of hole to 10216.0 ft Rigged up Block line Circulated at 10216.0 ft Rigged up Block line Serviced Block line Facility Date/Time 04 Jan 99 05 Jan 99 06 Jan 99 07 Jan 99 Badami CPF Progress Report Well B 1-36 Rig Nabors 28E CONFIDENTIAL Page 8 Date 23 June 99 09:15-09:30 09:30-12:15 12:15-13:30 13:30-14:00 14:00-18:30 18:30-19:00 19:00-00:00 00:00-00:15 00:15-02:45 02:45-03:45 03:45-05:45 05:45-06:00 06:00-07:00 07:00-12:00 12:00-13:30 13:30-14:30 14:30-16:00 16:00-17:00 17:00-19:45 19:45-20:15 20:15-00:30 00:30-01:00 01:00-02:30 02:30-03:30 03:30-05:30 05:30-06:00 06:00-08:30 08:30-11:00 11:00-17:30 17:30-18:00 18:00-18:45 18:45-19:00 19:00-19:45 19:45-20:00 20:00-22:30 22:30-22:45 22:45-02:30 02:30-03:45 03:45-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-07:45 07:45-08:00 08:00-08:15 08:15-08:45 08:45-09:15 09:15-12:00 12:00-12:30 12:30-18:30 18:30-19:30 19:30-20:30 20:30-00:45 00:45-01:45 Duration 1/4 hr 2-3/4 hr 1-1/4 hr 1/2 hr 4-1/2 hr 1/2 hr 5 hr 1/4 hr 2-1/2 hr lhr 2 hr 1/4 hr 1 hr 5 hr 1-1/2 hr 1 hr 1-1/2 hr lhr 2-3/4 hr 1/2 hr 4-1/4 hr 1/2 hr 1-1/2 hr 1 hr 2hr 1/2 hr 2-1/2 hr 2-1/2 hr 6-1/2 hr 1/2 hr 3/4 hr 1/4 hr 3/4 hr 1/4 hr 2-1/2 hr 1/4 hr 3-3/4 hr 1-1/4 hr 3/4 hr 1 hr 1/2 hr 1-1/2 hr 1/4hr 1/4 hr 1/4 hr 1/2hr 1/2 hr 2-3/4 hr 1/2 hr 6hr 1 hr 1 hr 4-1/4 hr 1 hr Activity Circulated at 10216.0 ft R.I.H. to 14355.0 ft Washed to 14400.0 ft Took MWD survey at 14400.0 ft Drilled to 14477.0 ft Took MWD survey at 14477.0 ft Drilled to 14570.0 ft Serviced Mud shakers Drilled to 14651.0 ft Took MWD survey at 14651.0 ft Drilled to 14695.0 ft Circulated at 14695.0 ft Circulated at 14695.0 ft Drilled to 14780.0 ft Circulated at 14750.0 ft Pumped out of hole to 14390.0 ft Circulated at 14390.0 ft Pulled out of hole to 13670.0 ft Circulated at 13670.0 ft R.I.H. to 14390.0 ft Reamed to 14780.0 ft Drilled to 14797.0 ft Circulated at 14797.0 ft Pulled out of hole to 14171.0 ft Circulated at 14797.0 ft Pulled out of hole to 14200.0 ft Pulled out of hole to 10220.0 ft R.I.H. to 14797.0 ft Circulated at 14797.0 ft R.I.H. to 14797.0 ft Circulated at 14797.0 ft Flow check Pulled out of hole to 13785.0 ft Flow check Pulled out of hole to 10244.0 ft Flow check Pulled out of hole to 679.0 ft Pulled BHA Serviced Drilling tool / logs Pulled BHA Serviced Top ram Serviced Top ram Removed Wear bushing Tested Top ram Retrieved Wear bushing Rigged up Casing handling equipment Held safety meeting Ran Liner to 1067.0 ft (7in OD) Held safety meeting Ran Casing to 4727.0 ft (7in OD) Installed Other sub-surface equipment Circulated at 4709.0 ft Ran Liner to 10244.0 ft (7in OD) Circulated at 10244.0 ft Facility Date/Time 08 Jan 99 09 Jan 99 10 Jan 99 11 Jan 99 Progress Report CONFIDENTIAL B adami CPF Well B 1-36 Rig Nabors 28E Page 9 Date 23 June 99 01:45-03:30 03:30-06:00 06:00-13:30 13:30-14:00 14:00-02:00 02:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:45 08:45-09:15 09:15-09:45 09:45-10:45 10:45-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-18:00 18:00-19:00 19:00-19:30 19:30-19:45 19:45-20:00 20:00-23:00 23:00-05:30 05:30-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-15:30 15:30-15:45 15:45-02:00 02:00-02:30 02:30-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-12:45 12:45-14:30 14:30-16:15 16:15-17:00 17:00-17:15 17:15-17:45 17:45-19:00 19:00-19:30 19:30-21:00 21:00-21:30 21:30-22:30 22:30-01:00 01:00-02:45 Duration 1-3/4 hr 2-1/2 hr 7-1/2 hr 1/2 hr 12hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1-1/4 hr 1/2 hr 1/2 hr 1 hr 1-1/4 hr 1/2 hr 4 hr lhr 1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 3 hr 6-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2hr 5 hr 1/4 hr 10-1/4 hr 1/2 hr 3-1/2 hr 4 hr 1 hr 1 hr 3/4 hr 1-3/4 hr 1-3/4 hr 3/4 hr 1/4 hr 1/2 hr 1-1/4 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 1-3/4 hr Activity Ran Liner to 12438.0 ft (7in OD) Worked stuck pipe at 12438.0 ft Worked stuck pipe at 12438.0 ft Circulated at 12438.0 ft Worked stuck pipe at 12438.0 ft Circulated at 12438.0 ft Held safety meeting Rigged up Cement head Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 102.000 bbl Displaced slurry - 305.000 bbl Circulated at 7711.0 ft Rigged down Cement unit Pumped out of hole to 7150.0 ft Serviced Block line Laid down 7030.0 ft of 5in OD drill pipe Held safety meeting Laid down 3900.0 ft of Drillpipe Retrieved Setting tools R.I.H. to 550.0 ft Pulled BHA Removed Drillfloor / Derrick Serviced Wear bushing running tool Installed Well control Installed BOP stack Tested BOP stack Serviced Bell nipple Serviced Bell nipple Serviced Surface lines Tested Casing Rigged down Drillfloor / Derrick Bleed down well Held safety meeting Made up BHA no. 16 Tested MWD/LWD - Via string R.I.H. to 12226.0 ft Laid down 188.0 ft of 5in OD drill pipe Drilled cement to 12226.0 ft Drilled cement to 12348.0 ft Tested Liner - Via annulus and string Drilled cement to 12352.0 ft Held drill (Kick (well kill)) Drilled installed equipment - Float shoe Circulated at 12439.0 ft Held safety meeting Tested Liner - Via annulus and string Laid down 153.0 ft of 5in OD drill pipe R.I.H. to 14683.0 ft Reamed to 14756.0 ft Circulated at 14756.0 ft Reamed to 14797.0 ft Drilled to 14819.0 ft Pumped out of hole to 14527.0 ft Reamed to 14785.0 ft Facility Date/Time 12 Jan 99 13 Jan 99 14 Jan 99 Progress Report CONFIDENTIAL Badami CPF Well B 1-36 Rig Nabors 28E Page 10 Date 23 June 99 02:45-03:30 03:30-05:15 05:15-06:00 06:00-06:15 06:15-08:30 08:30-08:45 08:45-09:45 09:45-10:15 10:15-12:15 12:15-19:00 19:00-19:30 19:30-21:00 21:00-22:00 22:00-00:00 00:00-02:30 02:30-04:00 04:00-06:00 06:00-12:30 12:30-13:45 13:45-14:30 14:30-16:15 16:15-16:30 16:30-17:15 17:15-18:15 18:15-19:00 19:00-04:00 04:00-06:00 06:00-07:15 07:15-07:30 07:30-08:30 08:30-09:00 09:00-09:30 09:30-09:45 09:45-10:00 10:00-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-21:30 21:30-22:30 22:30-01:30 01:30-01:45 01:45-02:30 02:30-02:45 02:45-03:45 03:45-04:30 04:30-06:00 06:00-08:00 08:00-08:15 08:15-09:00 09:00-10:00 10:00-12:30 12:30-13:00 13:00-13:30 Duration 3/4 hr 1-3/4 hr 3/4 hr 1/4 hr 2-1/4 hr 1/4 hr lhr 1/2 hr 2 hr 6-3/4 hr 1/2 hr 1-1/2 hr lhr 2 hr 2-1/2 hr 1-1/2 hr 2hr 6-1/2 hr 1-1/4 hr 3/4 hr 1-3/4 hr 1/4 hr 3/4 hr 1 hr 3/4 hr 9 hr 2 hr 1-1/4 hr 1/4 hr 1 hr 1/2 hr 1/2hr 1/4hr 1/4 hr 2hr 1/2 hr 4 hr 1 hr 4 hr 1 hr 3 hr 1/4 hr 3/4 hr 1/4 hr lhr 3/4 hr 1-1/2 hr 2 hr 1/4 hr 3/4 hr 1 hr 2-1/2 hr 1/2 hr 1/2 hr Activity Worked toolstring at 14795.0 ft Circulated at 14756.0 ft Pulled out of hole to 14021.0 ft Pulled out of hole to 14089.0 ft Circulated at 14057.0 ft R.I.H. to 14124.0 ft Reamed to 14215.0 ft R.I.H. to 14714.0 ft Washed to 14787.0 ft Circulated at 14621.0 ft R.I.H. to 14787.0 ft Worked toolstring at 14787.0 ft Washed to 14815.0 ft Worked toolstring at 14787.0 ft Circulated at 14819.0 ft Washed to 14819.0 ft Drilled to 14840.0 ft Drilled to 14878.0 ft Circulated at 14878.0 ft Flow check Pulled out of hole to 12340.0 ft Flow check Circulated at 12340.0 ft Pulled out of hole to 11178.0 ft Circulated at 11178.0 ft Pumped out of hole to 600.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Pulled BHA R.I.H. to 460.0 ft Laid down 460.0 ft of 4in OD drill pipe Removed Bore protector Installed Bore protector Ran Drillpipe in stands to 2000.0 ft Held safety meeting Ran Drillpipe in stands to 6000.0 ft Ran Drillpipe to 682.0 ft (4in OD) Ran Drillpipe in stands to 12438.0 ft Serviced Block line Ran Drillpipe in stands to 14779.0 ft Held safety meeting Batch mixed slurry - 23.000 bbl Mixed and pumped slurry - 23.000 bbl Displaced slurry - 193.000 bbl Pulled Drillpipe in stands to 13960.0 ft Circulated at 13960.0 ft Circulated at 13934.0 ft Mixed and pumped slurry - 36.000 bbl Displaced slurry - 177.000 bbl Pulled Drillpipe in stands to 12525.0 ft Circulated at 12525.0 ft Held safety meeting Mixed and pumped slurry - 22.000 bbl Facility Badami CPF Progress Report Well B1-36 Rig Nabors 28E CONFIDENTIAL Page 11 Date 23 June 99 Date/Time 15 Jan 99 13:30-14:00 14:00-14:45 14:45-17:30 17:30-18:00 18:00-19:45 19:45-03:30 03:30-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:15 09:15-10:30 10:30-11:00 11:00-14:00 14:00-15:00 15:00-16:00 16:00-18:30 18:30-20:00 Duration 1/2 hr 3/4 hr 2-3/4 hr 1/2 hr 1-3/4 hr 7-3/4 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1 hr lhr 1 hr 1/4 hr 1-1/4 hr 1/2 hr 3hr lhr lhr 2-1/2 hr 1-1/2 hr Activity Displaced slurry - 145.000 bbl Pulled Drillpipe in stands to 11588.0 ft Circulated at 11588.0 ft Rigged down Kelly Pulled Drillpipe in stands to 6643.0 ft Laid down 4956.0 ft of 4in OD drill pipe Ran Drillpipe in stands to 2004.0 ft Fill pits with Water Circulated at 2004.0 ft Circulated at 2004.0 ft Freeze protect well - 125.000 bbl of Diesel Held 1000.0 psi pressure on 6.000 bbl squeezed cement Pulled Drillpipe in stands to 2004.0 ft Retrieved Bore protector Installed Hanger plug Held safety meeting Removed BOP stack Removed Hanger plug Installed Hanger plug Held 2000.0 psi pressure on 9.000 bbl squeezed cement Removed BOP stack Facility Date/Time 04 Apr 99 05 Apr 99 06 Apr 99 07 Apr 99 08 Apr 99 09 Apr 99 10 Apr 99 Progress Report CEiNFIBENTIAL Badami CPF Well B 1-36 Rig (null) Page 1 Date 23 June 99 00:00-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-16:00 16:00-18:00 18:00-19:00 19:00-06:00 06:00-12:00 12:00-13:00 13:00-16:00 16:00-20:00 20:00-06:00 06:00-07:00 07:00-07:30 07:30-10:00 10:00-13:00 13:00-14:00 14:00-14:30 14:30-16:30 16:30-18:00 18:00-22:30 22:30-01:00 O1:00-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-21:30 21:30-02:30 02:30-05:00 05:00-06:00 06:00-08:00 08:00-10:30 10:30-11:00 11:00-13:30 13:30-16:00 16:00-20:00 20:00-23:00 23:00-06:00 06:00-07:00 07:00-08:00 08:00-10:30 10:30-17:00 17:00-18:30 18:30-20:00 20:00-20:30 20:30-21:30 21:30-22:30 22:30-00:00 00:00-06:00 06:00-06:00 Duration 6hr 4 hr 1 hr lhr 4 hr 2 hr 1 hr llhr 6hr lhr 3hr 4 hr 10hr 1 hr 1/2 hr 2-1/2 hr 3 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 4-1/2 hr 2-1/2 hr 2hr 1/2 hr 2-1/2 hr 1/2hr 15hr 5 hr 2-1/2 hr 1 hr 2hr 2-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 4 hr 3 hr 7 hr 1 hr lhr 2-1/2 hr 6-1/2 hr l- 1/2 hr 1-1/2 hr 1/2 hr lhr lhr 1-1/2 hr 6hr 24 hr Activity Rigged up Drillfloor / Derrick Rigged up Standpipe manifold Rigged up Top drive Rigged up Mud pumps Rigged up Top drive Rigged up Surface tree Removed Surface tree Rigged up BOP stack Rigged up BOP stack Held safety meeting Rigged up BOP stack Rigged up Choke line Tested BOP stack Installed Additional services Installed Kill manifold Installed Top drive Made up BHA no. 1 R.I.H. to 1000.0 ft Serviced Drillstring handling equipment R.I.H. to 2500.0 ft Circulated at 2500.0 ft Singled in drill pipe to 8164.0 ft Serviced Top drive Circulated at 8164.0 ft Singled in drill pipe to 8164.0 ft Singled in drill pipe to 9300.0 ft Singled in drill pipe to 9309.0 ft (cont...) Washed to 12070.0 ft Circulated at 14070.0 ft Washed to 12421.0 ft Drilled cement to 12483.0 ft Reamed to 12519.0 ft Circulated at 12519.0 ft Performed formation integrity test Drilled to 12520.0 ft Pumped out of hole to 9000.0 ft R.I.H. to 12520.0 ft Circulated at 12520.0 ft Pulled out of hole to 450.0 ft Pulled BHA Serviced Top drive Made up BHA no. 2 R.I.H. to 12185.0 ft Logged hole with LWD: Formation evaluation (FE) from 12185.0 ft to 12370.0 ft Serviced Block line Logged hole with LWD: Formation evaluation (FE) from 12370.0 ft to 12420.0 ft Circulated at 12420.0 ft Logged hole with LWD: Formation evaluation (FE) from 12370.0 ft to 12485.O ft Drilled to 12485.0 ft Drilled to 12488.0 ft Drilled to 12536.0 ft Facility Date/Time 11 Apr 99 12 Apr 99 13 Apr 99 14 Apr 99 15 Apr 99 16 Apr 99 17 Apr 99 18 Apr 99 19 Apr 99 Badami CPF Progress Report Well B 1-36 Rig (null) CONFIDENTIAL Page 2 Date 23 June 99 06:00-16:30 16:30-17:00 17:00-18:00 18:00-01:00 01:00-02:30 02:30-06:00 06:00-07:00 07:00-09:00 09:00-15:00 15:00-16:00 16:00-19:30 19:30-00:30 00:30-01:00 01:00-06:00 06:00-07:00 07:00-08:30 08:30-14:00 14:00-17:00 17:00-18:00 18:00-20:00 20:00-21:00 21:00-22:00 22:00-23:00 23:00-06:00 06:00-17:00 17:00-21:00 21:00-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-15:30 15:30-16:30 16:30-18:00 18:00-06:00 06:00-06:00 06:00-07:30 07:30-08:30 08:30-11:30 11:30-14:30 14:30-21:00 21:00-21:30 21:30-06:00 06:00-08:30 08:30-09:30 09:30-12:30 12:30-15:30 15:30-16:30 16:30-18:30 18:30-19:30 19:30-21:00 21:00-21:30 21:30-01:00 01:00-06:00 Duration 10-1/2 hr 1/2 hr 1 hr 7 hr 1-1/2 hr 3-1/2 hr 1 hr 2 hr 6 hr 1 hr 3-1/2 hr 5 hr 1/2 hr 5 hr 1 hr 1-1/2 hr 5-1/2 hr 3hr 1 hr 2 hr 1 hr 1 hr 1 hr 7 hr llhr 4 hr 8 hr 1 hr 1 hr 1 hr 1-1/2 hr 6 hr 1 hr 1-1/2 hr 12hr 24 hr 1-1/2 hr 1 hr 3hr 3hr 6-1/2 hr 1/2 hr 8-1/2 hr 2-1/2 hr lhr 3 hr 3 hr 1 hr 2 hr 1 hr 1-1/2 hr 1/2 hr 3-1/2 hr 5 hr Activity Drilled to 12663.0 ft Circulated at 12663.0 ft Pulled out of hole to 12438.0 ft Pulled out of hole to 495.0 ft Pulled BHA Tested BOP stack Tested BOP stack Made up BHA no. 3 R.I.H. to 12450.0 ft Circulated at 12450.0 ft R.I.H. to 12663.0 ft Drilled to 12665.0 ft Reamed to 12497.0 ft Pulled out of hole to 5000.0 ft Pulled out of hole to 540.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 8314.0 ft Serviced Top drive R.I.H. to 12421.0 ft Serviced Block line Circulated at 12450.0 ft R.I.H. to 12663.0 ft Drilled to 12825.0 ft Drilled to 13471.0 ft Circulated at 13471.0 ft Pulled out of hole to 0.0 ft Pulled BHA Pulled BHA Serviced Top drive Made up BHA no. 5 R.I.H. to 12460.0 ft Circulated at 12460.0 ft R.I.H. to 13471.0 ft Drilled to 13555.0 ft Drilled to 13740.0 ft Drilled to 137500.0 ft Circulated at 13750.0 ft Drilled to 13780.0 ft Circulated at 13780.0 ft Pumped out of hole to 250.0 ft Pulled BHA Worked on BOP - BOP stack Worked on BOP - BOP stack Serviced Top drive Made up BHA no. 6 R.I.H. to 8280.0 ft Serviced Block line R.I.H. to 12462.0 ft Circulated at 12462.0 ft R.I.H. to 12600.0 ft Serviced SCR Serviced Top drive R.I.H. to 12500.0 ft Facility Date/Time 20 Apr 99 21 Apr 99 22 Apr 99 23 Apr 99 24 Apr 99 25 Apr 99 26 Apr 99 Progress Report CONFIDENTIAL Badami CPF Well B 1-36 Rig (null) Page 3 Date 23 June 99 06:00-08:00 08:00-10:30 10:30-06:00 06:00-10:00 10:00-13:30 13:30-14:00 14:00-16:15 16:15-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-02:30 02:30-04:30 04:30-05:15 05:15-05:30 05:30-06:00 06:00-09:30 09:30-10:00 10:00-12:30 12:30-14:30 14:30-20:30 20:30-22:00 22:00-22:30 22:30-02:00 02:00-03:30 03:30-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-10:30 10:30-11:30 11:30-06:00 06:00-17:30 17:30-19:00 19:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-12:00 12:00-12:30 12:30-16:00 16:00-19:00 19:00-20:00 20:00-03:30 03:30-04:15 04:15-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-17:00 17:00-18:00 18:00-19:00 19:00-19:30 19:30-20:30 Duration 2 hr 2-1/2 hr 19-1/2 hr 4 hr 3-1/2 hr 1/2 hr 2-1/4 hr 11-1/4 hr 2-1/2 hr 1/2 hr 1 hr 19hr 2 hr 3/4 hr 1/4 hr 1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 2 hr 6hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr lhr 1 hr lhr lhr 18-1/2 hr 11-1/2 hr 1-1/2 hr 8 hr lhr 1 hr 1 hr 6 hr 1/2 hr 3-1/2 hr 3 hr 1 hr 7-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 1/2 hr 3-1/2 hr 7hr 1 hr 1 hr 1/2 hr 1 hr Activity R.I.H. to 12507.0 ft R.I.H. to 13780.0 ft Drilled to 14410.0 ft Drilled to 14508.0 ft Circulated at 14508.0 ft Pulled out of hole to 13471.0 ft R.I.H. to 14508.0 ft Drilled to 14832.0 ft Circulated at 14832.0 ft Circulated at 14832.0 ft Pulled out of hole to 14250.0 ft Drilled to 14958.0 ft Pulled out of hole to 12650.0 ft Reamed to 14650.0 ft Pulled out of hole to 14480.0 ft Set tool face Set tool face Circulated at 12500.0 ft Pulled out of hole to 10000.0 ft Held safety meeting Pulled out of hole to 120.0 ft Pulled BHA Serviced Top drive Made up BHA no. 7 R.I.H. to 8200.0 ft R.I.H. to 12400.0 ft Circulated at 12430.0 ft Set tool face R.I.H. to 14680.0 ft Reamed to 14950.0 ft Circulated at 14950.0 ft Drilled to 15102.0 ft Drilled to 15197.0 ft Circulated at 15197.0 ft Drilled to 15267.0 ft Circulated at 15267.0 ft Investigated pressure change Pulled out of hole to 13000.0 ft Pulled out of hole to 9700.0 ft Held safety meeting Pulled out of hole to 528.0 ft Pulled BHA Serviced Top drive Tested BOP stack Held safety meeting Made up BHA no. 8 R.I.H. to 1000.0 ft Functioned Downhole measurement tools Serviced Drilling tool / logs R.I.H. to 12400.0 ft Serviced Block line R.I.H. to 12478.0 ft Held safety meeting Serviced Top drive Facility Date/Time 27 Apr 99 28 Apr 99 29 Apr 99 30 Apr 99 01 May 99 02 May 99 03 May 99 Progress Report CONFiDENTiAL Badami CPF Well B 1-36 Rig (null) Page 4 Date 23 June 99 20:30-21:00 21:00-21:30 21:30-23:00 23:00-03:00 03:00-03:30 03:30-06:00 06:00-08:30 08:30-11:00 11:00-13:00 13:00-16:30 16:30-21:00 21:00-21:30 21:30-06:00 06:00-15:00 15:00-16:30 16:30-23:00 23:00-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-09:30 09:30-21:30 21:30-01:00 01:00-02:00 02:00-02:30 02:30-06:00 06:00-11:30 11:30-12:30 12:30-13:30 13:30-14:30 14:30-15:30 15:30-02:00 02:00-03:30 03:30-06:00 06:00-12:00 12:00-19:00 19:00-20:00 20:00-20:30 20:30-00:00 00:00-04:00 04:00-06:00 06:00-14:30 14:30-17:00 17:00-17:30 17:30-19:30 19:30-00:30 00:30-02:30 02:30-06:00 06:00-06:30 06:30-19:00 19:00-20:00 20:00-21:00 21:00-21:30 21:30-00:00 Duration 1/2 hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2hr 3-1/2 hr 4-1/2 hr 1/2 hr 8-1/2 hr 9 hr 1-1/2 hr 6-1/2 hr 2 hr 1 hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 12hr 3-1/2 hr 1 hr 1/2 hr 3-1/2 hr 5-1/2 hr 1 hr 1 hr lhr 1 hr 10-1/2 hr 1-1/2 hr 2-1/2 hr 6 hr 7hr 1 hr 1/2 hr 3-1/2 hr 4 hr 2 hr 8-1/2 hr 2-1/2 hr 1/2 hr 2 hr 5 hr 2 hr 3-1/2 hr 1/2 hr 12-1/2 hr 1 hr lhr 1/2 hr 2-1/2 hr Activity R.I.H. to 12478.0 ft Reamed to 12577.0 ft R.I.H. to 14887.0 ft Took MWD survey at 14887.0 ft Reamed to 15266.0 ft Drilled to 15310.0 ft Drilled to 15338.0 ft (cont...) Circulated at 15338.0 ft Drilled to 15355.0 ft Circulated at 15355.0 ft Drilled to 15412.0 ft Circulated at 15412.0 ft Drilled to 15475.0 ft Drilled to 15546.0 ft Circulated at 15546.0 ft Pulled out of hole to 9795.0 ft R.I.H. to 12438.0 ft Circulated at 12438.0 ft R.I.H. to 15546.0 ft Circulated at 15546.0 ft Circulated at 15546.0 ft Pulled out of hole to 500.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 1022.0 ft (4-1/2in OD) Ran Liner to 3156.0 ft (4-1/2in OD) Serviced Top drive Ran Liner to 3198.0 ft (4-1/2in OD) Circulated at 3198.0 ft Ran HWDP in stands to 4104.0 ft Ran Drillpipe in stands to 14000.0 ft Circulated at 12100.0 ft Ran Drillpipe in stands to 13466.0 ft Ran Liner to 15541.0 ft (4-1/2in OD) Circulated at 15541.0 ft Rigged down sub-surface equipment - Setting tools Circulated at 15541.0 ft Investigated pressure change Worked toolstring at 12353.0 ft Circulated at 15445.0 ft Pulled Drillpipe in stands to 0.0 ft Serviced Block line Held safety meeting Rigged up Lubricator Perforated from 15483.0 ft to 15493.0 ft Rigged up Drillstring handling equipment Ran Drillpipe to 1000.0 ft (2-3/8in OD) Ran Drillpipe to 3232.0 ft (2-3/8in OD) Ran Drillpipe in stands to 15440.0 ft Rigged up Circulating head Circulated at 15440.0 ft Held safety meeting Circulated at 15440.0 ft Facility Date/Time 04 May 99 05 May 99 06 May 99 07 May 99 08 May 99 09 May 99 10 May 99 Progress Report CONFIE]ENTI L B adami CPF Well B 1-36 Page 5 Rig (null) Date 23 June 99 00:00-02:00 02:00-06:00 06:00-08:00 08:00-17:00 17:00-22:00 22:00-03:00 03:00-06:00 06:00-09:00 09:00-14:00 14:00-21:00 21:00-00:00 00:00-06:00 06:00-13:30 13:30-16:00 16:00-22:30 22:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-16:00 16:00-19:00 19:00-20:00 20:00-22:00 22:00-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-07:30 07:30-09:30 09:30-10:00 10:00-03:00 03:00-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-11:30 11:30-12:00 12:00-14:00 14:00-18:00 18:00-19:00 19:00-19:30 19:30-20:00 20:00-00:00 00:00-03:00 03:00-05:00 05:00-06:00 06:00-08:30 08:30-09:30 09:30-10:00 10:00-22:00 22:00-05:00 Duration 2 hr 4hr 2hr 9hr 5hr 5 hr 3hr 3 hr 5hr 7hr 3hr 6 hr 7-1/2 hr 2-1/2 hr 6-1/2 hr 7-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 6-1/2 hr 3 hr 1 hr 2 hr 6 hr 1/2 hr 1-1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 17hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 2hr 4hr 1 hr 1/2 hr 1/2 hr 4 hr 3 hr 2hr 1 hr 2-1/2 hr lhr 1/2 hr 12hr 7hr Activity Mixed and pumped slurry - 78.000 bbl Circulated at 15440.0 ft Circulated at 15440.0 ft Pulled Drillpipe in stands to 3235.0 ft Laid down 3235.0 ft of 2-3/8in OD drill pipe Tested BOP stack Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Ran Drillpipe on landing string to 8000.0 ft Ran Drillpipe on landing string to 12345.0 ft Set packer at 12353.0 ft with 3000.0 psi Circulated at 12323.0 ft Circulated at 12323.0 ft Circulated at 12323.0 ft Circulated at 12323.0 ft Tested Casing Pulled Drillpipe in stands to 0.0 ft Serviced Tie back packer Serviced Packer assembly Circulated at 7700.0 ft Laid down 7500.0 ft of Drillpipe Removed Wear bushing Serviced Block line Installed BOP stack Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 7712.0 ft (7in OD) Serviced Rig services Ran Casing to 7712.0 ft (7in OD) Serviced Rig services Held safety meeting Circulated at 7712.0 ft Tested Locator seal assembly - Via string Tested Casing - Via string Conducted electric cable operations Held safety meeting Installed Slip & seal assembly Installed Rig services Installed Emergency seal assembly Tested Seal assembly Installed Casing head Installed BOP stack Installed Rig services Installed BOP stack Tested Pipe ram Tested Pipe ram (cont...) Ran Drillpipe to 506.0 ft (3-1/2in OD) Pulled Drillpipe in stands to 506.0 ft Conducted electric cable operations Conducted slickline operations on Slickline equipment - Tool run Facility Date/Time 11 May 99 12 May 99 13 May 99 14 May 99 15 May 99 Progress Report CONFiDENTi L Badami CPF Well B 1-36 Page 6 Rig (null) Date 23 June 99 05:00-06:00 06:00-07:00 07:00-08:00 08:00-13:30 13:30-14:30 14:30-17:00 17:00-18:30 18:30-23:00 23:00-23:30 23:30-06:00 06:00-07:30 07:30-20:15 20:15-03:30 03:30-05:30 05:30-06:00 06:00-19:30 19:30-03:00 03:00-05:30 05:30-06:00 06:00-11:00 11:00-14:00 14:00-16:00 16:00-18:45 18:45-00:00 00:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-10:30 10:30-16:00 16:00-19:00 19:00-21:45 21:45-23:00 Duration 1 hr lhr 1 hr 5-1/2 hr 1 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 12-3/4 hr 7-1/4 hr 2hr 1/2 hr 13-1/2 hr 7-1/2 hr 2-1/2 hr 1/2 hr 5 hr 3hr 2 hr 2-3/4 hr 5-1/4 hr 3-1/2 hr 1 hr 1-1/2 hr 1/2 hr 4 hr 5-1/2 hr 3hr 2-3/4 hr 1-1/4 hr Activity Rigged up Top ram Rigged up Top ram (cont...) Tested BOP stack Ran Drillpipe to 3191.0 ft (2-3/8in OD) Circulated at 3191.0 ft Ran Drillpipe in stands to 11095.0 ft Circulated at 11095.0 ft Ran Drillpipe to 15440.0 ft (4in OD) Held safety meeting Circulated at 15440.0 ft Circulated at 15440.0 ft Laid down 15440.0 ft of 4in OD drill pipe Conducted electric cable operations Worked on BOP - Top ram Rigged up Tubing handling equipment Ran Tubing on landing string to 9706.0 ft Laid down 1720.0 ft of Tubing Held safety meeting Rigged down sub-surface equipment - Completion string sub-assemblies Rigged down sub-surface equipment - Completion string sub-assemblies (cont...) Ran Tubing to 10176.0 ft (4-1/2in OD) Rigged up High pressure lines Circulated at 10176.0 ft Reverse circulated at 10176.0 ft Tested Permanent packer - Via string Tested Permanent packer - Via annulus Rigged down High pressure lines Installed Hanger plug Removed Bell nipple Serviced BOP stack Removed BOP stack Installed Xmas tree Installed Hanger plug BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 CONFIDENTIAL June 16, 1999 Mr. Robert Christianson Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Request for Confidentiality Badami B1-36 Test Production Dear Commissioner Christianson: Enclosed is the Monthly Production Report for production from the Kekituk formation in the Badami B1-36 Well. The production resulted from production tests, which concluded 5/31/99. BP Exploration (Alaska), Inc. requests that the enclosed report of test production be held confidential under AS 31.05.035(c) and 20 AAC 25.537(d). Sincerely, Robert A. Reynolds Manager, State Taxes & Royalty CC: Nina Thornton (Fina) Gary Osborne (BPXA) Run Date: 06/16/99 Run Time: 10:28:21 BP Exploration (Alaska) Inc. State of Alaska Alaska Oil and Gas Conservation Commission Monthly Production Report 2O AAC 25.23O Badami Daily Average Production Page 2 May, 1999 Total Monthly Production Well APl C Field M Days Name Number L & Pool T In 50- S Code H ~ B1-36 2293300 O 060160 1 2 Gas-Oil Tubing Oil Water Ratio PSIG BBL BBL 0 256 060160 Badami, Kekitktuk undefined Pool Production Totals .......................... 0 0 Gas Oil Water Gas MCF BBL BBL MCF 1,258 0 0 2,516 2,516 CONFIDENTIAL Form 10-405 ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Badami, Pad 1 28-Apr-1999 16:07:35 Page CONFIDENTIAL 1 of 8 Well ..................... : B1-36 Re-entry Spud date ................ : April-06-1999 API number ............... : 50-029-22933-00 Last survey date ......... : 28-Apr-1999 ~"~ngineer ................. : bosse Rig: .................... : Nabors 28E State: .................. : Alaska Total accepted surveys...: 194 MD of first survey ....... : 12444.62 ft MD of last survey ........ : 15486.04 ft ORIGINAL Survey calculation methods- - Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller Pipe Tally GL above permanent ....... : 20.30 ft KB above permanent ....... : Top Drive DF above permanent ....... : 53.05 ft Vertical section origin- '!atitude (+N/S-) ......... : Jeparture (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Azimuth from rotary table to target: 100.20 degrees Geomagnetic data Magnetic model ........... : BGGM version 1998 Magnetic date ............ : 05-Apr-1999 Magnetic field strength..: 1148.28 HCNT Magnetic dec (+E/W-) ..... : 28.56 degrees Magnetic dip ............. : 80.83 degrees MWD survey Reference Criteria Reference G .............. : 1002.67 mGal Reference H .............. : 1148.28 HCNT Reference Dip ............ : 80.83 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 28.56 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.56 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6_0B_70] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course TVD ~ depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) First survey in list is the tie in point. 2 12411.78 70.21 105.45 92.12 10591.41 3 12444.62 71.18 105.10 32.84 10602.27 4 12516.81 66.88 104.19 72.19 10628.10 5 12613.59 64.15 104.36 96.78 10668.21 6 12635.65 64.22 101.18 22.06 10677.81 7 12732.22 64.05 102.74 96.57 10719.95 8 12830.33 64.86 102.34 98.11 10762.25 9 12923.41 65.72 105.36 93.08 10801.17 10 13017.68 66.47 103.37 94.27 10839.37 11 13113.95 67.18 105.85 96.27 10877.26 12 13207.96 66.61 104.85 94.01 10914.16 13 13302.33 65.57 106.93 94.37 10952.41 14 13397.89 64.58 105.30 95.56 10992.68 15 13468.40 63.79 106.06 70.51 11023.38 16 13564.66 60.83 101.65 96.26 11068.13 17 13599.03 58.05 98.81 34.37 11085.60 18 13630.59 55.45 96.01 31.56 11102.91 19 13658.47 52.77 92.65 27.88 11119.25 20 13691.82 50.25 88.98 33.35 11140.01 21 13723.34 48.30 84.83 31.52 11160.58 22 13780.07 45.52 80.96 56.73 11199.34 23 13875.58 44.23 78.36 95.51 11267.03 ~ii 24 13971.30 43.49 78.69 95.72 11336.05 25 14065.72 42.60 80.12 94.42 11405.05 26 14160.88 41.42 81.55 95.16 11475.76 27 14256.74 39.87 81.65 95.86 11548.49 28 14351.02 37.76 80.48 94.28 11621.95 29 14448.31 35.58 78.88 97.29 11699.98 30 14543.69 32.15 79.44 95.38 11779.17 28-Apr-1999 16:07:35 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) __ 4671.03 -290.26 4693.82 4701.91 -298.43 4723.71 4769.09 -315.48 4788.91 4856.94 -337.19 4874.26 Page 2 of 8 CONFIDENTIAL Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) i00f) type type 4702.78 93.54 2.85 MWD - 4733.13 93.61 3.12 MWD - 4799.29 93.77 6.07 MWD 6-axis 4885.91 93.96 2.83 MWD 6-axis 4876.78 -341.58 4893.63 4905.53 93.99 4963.63 -359.58 4978.63 4991.60 94.13 5052.07 -378.80 5065.04 5079.19 94.28 5136.44 -399.05 5147.12 5162.57 94.43 5222.39 -420.42 5230.61 5247.48 94.60 5310.62 -442.75 5316.24 5334.64 94.76 5396.74 -465.64 5399.62 5419.66 94.93 5482.58 -489.25 5482.59 5504.38 95.10 5568.77 -513.31 5565.84 5589.46 95.27 5631.96 -530.46 5626.95 5651.90 95.39 5716.98 -550.91 5709.66 5736.17 95.51 5746.56 -556.17 5738.77 5765.66 95.54 5772.92 -559.59 5764.94 5792.03 95.54 5795.38 -561.30 5787.45 5814.61 95.54 5821.13 -561.69 5813.54 5840.61 95.52 5864.22 95.48 5904.65 95.40 5969.53 95.22 6033.09 95.04 6095.17 94.88 6156.97 94.73 6217.79 94.60 6275.26 94.48 6331.45 94.34 6382.75 94.22 5844.37 -560.41 5837.38 5883.91 -555.32 5878.48 5947.01 -543.24 5944.76 6008.64 -530.05 6009.76 6068.89 -518.19 6073.11 12.98 1.46 0.90 3.09 2.09 2.48 1.15 2.30 1.86 1.48 5.09 10.77 11.09 13.70 11.46 11.74 6.99 2.35 0.81 1.40 1.60 1.62 2.37 2.45 3.61 6128.96 -508.04 6135.97 6188.14 -498.92 6197.74 6243.97 -489.76 6256.12 6298.39 -479.37 6313.27 6347.98 -469.36 6365.47 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6 -axis MWD 6 -axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)1999 Anadrill IDEAL ID6_0B_70] ANADRILL SCHLUMBERGER Survey Report 28-Apr-1999 16:07:35 Page 3 of 8 CONFIDENTIAL Seq Measured Incl Azimuth Course TVD Vertical Displ Displ # depth angle angle length depth section +N/S- +E/W- - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) 31 14639.08 28.22 79.66 95.39 11861.61 6392.85 -460.66 6412.62 32 14734.03 25.70 82.58 94.95 11946.24 6433.50 -453.97 6455.13 33 14830.36 22.90 82.23 96.33 12034.02 6471.24 -448.74 6494.42 34 14924.06 20.06 81.90 93.70 12121.21 6503.85 -444.01 6528.40 35 15021.43 17.03 85.61 97.37 12213.51 6533.51 -440.56 6559.16 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 6429.15 94.11 4.12 6471.07 94.02 3.00 6509.90 93.95 2.91 6543.48 93.89 3.03 6573.94 93.84 3.34 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 36 15112.58 13.69 88.19 91.15 12301.39 6556.98 -439.20 6583.25 37 15212.08 11.15 92.15 99.50 12398.56 6578.03 -439.19 6604.64 38 15302.99 9.77 94.60 90.91 12487.96 6594.41 -440.14 6621.11 39 15403.45 8.15 103.55 100.46 12587.19 6610.00 -442.49 6636.53 40 15486.04 7.02 108.47 82.59 12669.06 6620.84 -445.46 6647.01 6597.89 93.82 3.74 6619.23 93.80 2.69 6635.72 93.80 1.59 6651.27 93.81 2.12 6661.92 93.83 1.58 MWD - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis Final survey projected to driller's total depth. 41 15546.00 7.02 108.47 59.96 12728.57 6628.10 -447.78 6653.96 6669.01 93.85 0.00 MWD [(c)1999 Anadrill IDEAL ID6_0B_70] CONFIDENTIAL North Slope Alaska Alaska State Plane Zone 3 Badami CPF, Slot B1-36 B 1-36 PB 1 Job No. AKVC90020, SurVeyed: 23 November, 1998 SURVEY REPORT ORIGINAL 23 June, 1999 Your Reft API-500292293370 KBE-55.60 MWD SurVey Instrument Surface Coordinates: 5906424.99 N, 364106.00 E (70° 09' 08.0546" N, 147° 05' 33.9968" W) Kelly Bushing: 55.60ft above Mean Sea Level I:1 R I L,,L I, N E~ .... S E R,V I c:; E S Survey Ref: svy894 Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONFiDENTiaL North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -55.60 27.00 0.000 0.000 -28.60 35,30 0.000 0.000 -20.30 81.74 0.230 279.810 26.14 181.47 0,230 293.640 125.87 272.88 0.480 310.400 217.28 364.75 0.480 250.510 309.14 454.39 1.640 194,370 398.77 544.28 2.980 199.490 488.58 633.78 3.390 189.480 577.95 723,56 3.780 180.190 667.55 816.26 4.910 176.310 759.98 910.20 4.420 182.360 853.61 1004,70 5.080 180.620 947,79 1099.17 6.810 174.450 1041,75 1192.65 7.200 170.460 1134.53 1286.41 6.620 167.940 1227.61 1381.08 7.290 168.100 1321.58 1474,87 8.110 167.450 1414.52 1568.55 6.900 170.770 1507.40 1662.99 7.900 172,410 1601.05 1757.80 9.230 170,040 1694.80 1851.64 8.870 167.210 1787.48 1944.46 8.260 164.270 1879.26 2037.88 7.200 166.970 1971,83 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.00 N 0.00 E 5906424.99 N 364106.00 E 27.00 0.00 N 0.00 E 5906424.99 N 364106.00 E 35.30 0.00 N 0.00 E 5906424.99 N 364106.00 E 81.74 0.02 N 0.09W 5906425.01 N 364105.91 E 181.47 0,13 N 0.47W 5906425.13 N 364105,53 E 272.88 0.45 N 0.93W 5906425.46 N 364105.08 E 364.74 0.57 N 1.59W 5906425.59 N 364104,42 E 454.37 0.79 S 2,26W 5906424.24 N 364103.73 E 544.18 4,24 S 3.36W 5906420.81 N 364102.57 E 633.55 9.05 S 4.57W 5906416.03 N 364101.27 E 723.15 14.62 S 5.02W 5906410,46 N 364100.72 E 815,58 21,64 S 4,77W 5906403.44 N 364100.84 E 909.21 29.27 S 4,66W 5906395.81N 364100.81 E 1003.39 37.09 S 4.86W 5906387.99 N 364100,48 E 1097.35 46.85 S 4.36W 5906378.23 N 364100.80 E 1190.13 58,14 S 2.86W 5906366,91 N 364102.10 E 1283,21 69,22 S 0,75W 5906355.79 N 364104.01 E 1377.18 80.44 S 1.63 E 5906344.54 N 364106.18 E 1470.12 92.72 S 4.29 E 5906332.21 N 364108.63 E 1563.00 104.72 S 6,63 E 5906320,17 N 364110.75 E 1656,65 116.75 S 8.40 E 5906308,10 N 364112.30 E 1750.40 130,70 S 10.57 E 5906294.12 N 364114.23 E 1843.08 145.17 S 13.48 E 5906279.60 N 364116.87 E 1934.86 158.57 S 16.87 E 5906266,15 N 364120.02 E 2027.43 170.73 S 20,01 E 5906253.93 N 364122.94 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°ll00ft) (fi) Comment 0.00 0,000 0.00 0.000 0.00 0.495 -0.09 0.056 -0.48 0.293 -0.95 0.522 -1.61 1.594 -2.22 1.507 -3.14 0.770 -4.11 0.778 -4.28 1.259 -3.68 0.739 -3.19 0.715 -2.99 1.950 -2.01 0.667 0.07 0.698 2.72 0.708 5.66 0.879 8.94 1.372 11.88 1.082 14.25 1.451 17.12 0.610 20.74 0.809 24.80 1.199 28.55 Continued.,. 23 June, 1999 - 9:33 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONF DENT ^L North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 2132.56 9.500 166.570 2065.50 2225.73 14.080 160.200 2156.69 2320.54 16.650 149.450 2248.12 2407.86 17.660 150.180 2331.55 2501.80 16.500 150.470 2421.35 2595.89 15.080 152.850 2511.89 2689.27 13.730 150.630 2602.33 2784.24 12.780 150.940 2694.77 2877.58 11.580 149.000 2786.00 2971.33 10.240 146.860 2878.06 3065.49 9.910 146.010 2970.77 3159.65 9.850 146.650 3063.53 3253.46 9.340 148.800 3156.03 3346.93 8.280 150.770 3248.39 3441.23 7.540 150.070 3341.80 3535.17 6.340 150.660 3435.05 3629.35 6.170 151.050 3528.67 3723.08 5.780 149.930 3621.89 3817.23 5.450 152.720 3715.58 3911.54 5.420 157.110 3809.47 4004.94 5.390 159.710 3902.46 4098.53 5.230 163.830 3995.64 4192.81 5.020 172.310 4089.55 4287.73 5.030 175.990 4184.10 4380.46 5.590 178.340 4276.44 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2121.10 184.11S 23.16 E 5906240.49 N ' 364125.85 E 2212.29 202.26 S '. 28.79 E 5906222,24 N 364131.15 E 2303.72 224.82 S 39.60 E 5906199.50 N 364141.56 E 2387.15 247.08 S 52.55 E 5906177.00 N 364154.11E 2476.95 271.06 S 66.21 E 5906152.79 N 364167.34 E 2567.49 293.57 S 78.38 E 5906130.06 N 364179.10 E 2657.93 314.04 S 89,36 E 5906109.40 N 364189,71 E 2750.37 333.04 S 99,99 E 5906090.21 N 364200.00 E 2841,60 350,10 S 109.83 E 5906072.98 N 364209.53 E 2933,66 365.14 S 119.23 E 5906057.77 N 364218.66 E 3026.37 378,87 S 128.34 E 5906043.88 N 364227.52 E 3119,13 392,32 S 137,29 E 5906030.27 N 364236.23 E 3211.63 405.53 S 145.65 E 5906016.91N 364244.35 E 3303.99 417.89 S 152.86 E 5906004.42 N 364251.34 E 3397.40 429.18 S 159.27 E 5905993.02 N 364257.54 E 3490,65 439.04 S 164.88 E 5905983,06 N 364262,98 E 3584.27 448.00 S 169.88 E 5905974.01 N 364267.82 E 3677.49 456.50 S 174.69 E 5905965.43 N 364272.47 E 3771.18 464,57 S 179,11 E 5905957.28 N 364276.75 E 3865.07 472.66 S 182,90 E 5905949.13 N 364280,39 E 3958,06 480.83 S 186.13 E 5905940.89 N 364283,48 E 4051.24 489.05 S 188.84 E 5905932.63 N 364286.04 E 4145.15 497,27 S 190,59 E 5905924.38 N 364287.64 E 4239.70 505.54 S 191.44 E 5905916.10 N 364288.34 E 4332.04 514.11S 191.85 E 5905907.53 N 364288.60 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.430 32.37 5.103 38.90 4.036 50.84 1.183 64.88 1.238 79.73 1.658 93.02 1.562 105,01 1.003 116.58 1.358 127.26 1.493 137.41 0.384 147.19 0.133 156.81 0.664 165.82 1.179 173.64 0.791 180.61 1.280 186.71 0.186 192.15 0.434 197.37 0.455 202.20 0.442 206,39 0.264 210.03 0.442 213.15 0.833 215.31 0.340 216.57 0.648 217.41 Continued... 23 June, 1999 - 9:33 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONFIDENTIAL North Slope Alaska Measured Depth (ft) Incl. 4474.o7 4553.74 4648.20 4741.21 4834.91 4928.52 5022.43 5115.92 52o9.18 5303.83 5397.41 5493.81 5584.63 5678.62 5772.36 5866.59 5960.22 6054.43 6148.76 6242.17 6336.29 6429.94 6524.48 6618.23 6712.33 5,290 4.880 5.350 6.560 8,950 12.01o 15.89o 19.o7o 21.33o 26.980 33.44o 38.370 42.850 46.580 47.080 48.74o 50.970 50.400 49.270 48.12o 49.OLO 49.12o 47.470 45.900 45.19o Azim. 181.52o 181.17o 18o,76o 166.27o 151.54o 137.44o 121.22o 113.52o 105.14o 98.740 96.390 95.960 95.430 95.740 93.660 89.960 89.860 89.520 87,430 85.390 85.270 85.820 85.560 85,990 89.560 Sub-Sea Depth (ft) 4369,62 4448.98 4543.06 4635.58 4728.42 4820.47 4911.63 5000.80 5088.34 5174.68 5255.51 5333.57 5402.50 5469.28 5533.42 5596.59 5656.95 5716.64 5777.49 5839.15 5901.43 5962.79 6025.69 6090.00 6155.91 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fl) (ft) (ft) (ft) (ft) 4425.22 522.98 S 191.87 E 5905898.66 N 364288.46 E 4504.58 530.04 S 191.71 E 5905891.60 N 364288.17 E 4598.66 538.46 S 191.57 E 5905883.18 N 364287.88 E 4691.18 547.95 S 192.77 E 5905873.67 N 364288.91 E 4784.02 559.56 S 197.51 E 5905861.97 N 364293.44 E 4876.07 573.14 S 207.57 E 5905848.21N 364303.26 E 4967.23 587.02 S 225.19 E 5905834.03 N 364320.62 E 5056.40 599.75 S 250.15 E 5905820.85 N 364345.35 E 5143.94 610.26 S 280.50 E 5905809.79 N 364375.51 E 5230.28 618.03 S 318.38 E 5905801.35 N 364413.24 E 5311.11 624.13 S 365,03 E 5905794.41N 364459.78 E 5389.17 630.20 S 421.22 E 5905787.34 N 364515.85 E 5458.10 636.05 S 480.03 E 5905780.43 N 364574.54 E 5524.88 642.49 S 545.83 E 5905772.81N 364640.22 E 5589.02 648.09 S 613.96 E 5905765.99 N 364708.24 E 5652.19 650.26 S 683.83 E 5905762.56 N 364778.06 E 5712.55 650.15 $ 755.40 E 5905761.39 N 364849.62 E 5772.24 649.76 S 828.29 E 5905760.48 N 364922.50 E 5833.09 647.85 S 900.34 E 5905761.09 N 364994.57 E 5894.75 643.47 S 970.36 E 5905764.22 N 365064.66 E 5957.03 637.72 S 1040.69 E 5905768.70 N 365135.08 E 6018.39 632.23 S 1111.22 E 5905772.93 N 365205.70 E 6081.29 626.93 S 1181.60 E 5905776.97 N 365276.17 E 6145.60 621.90 S 1249.63 E 5905780,78 N 365344.27 E 6211.51 619.28 S 1316.72 E 5905782.19 N 365411.40 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/100fi) (fi) Comment 0.454 217.88 0.516 218.06 0.499 218.35 2.065 220.03 3.298 225.35 4.242 236.08 5.829 254.37 4.199 279.93 3.931 310.77 6.571 348.99 7.017 395.90 5.121 452.32 4.947 511.35 3.975 577.39 1,704 645.72 3.405 715.60 2.383 787.08 0.666 859.85 2,074 931.72 2.051 1001.43 0,950 1071.38 0.459 1141.55 1.757 1211.58 1.708 1279,26 2,811 1346.14 Continued... 23 June, 1999 - 9:33 - 4 - DrillQuest Sperry-Sun Drilling Services Survey RePort for B1-36 PB1 Your Ref: A PI-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 80NFIDEN'Ti^L North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (fl) (fi) (ft) 6806.32 44.240 92,620 6222.71 6278.31 620.52 S 1382.83 E 6900.69 44,740 92.420 6290.03 6345.63 623.43 S 1448.89 E 6994.14 44.330 88.530 6356.66 6412.26 623.98 S 1514.41 E 7087.72 42.640 86.550 6424.55 6480.15 621.23 S 1578.74 E 7181.43 43.910 87.580 6492.78 6548.38 617.95 S 1642.89 E 7275.83 44.590 89.190 6560.40 7369.32 44.940 88.810 6626.78 7463.36 45.420 87.300 6693.07 7551.17 46.910 85.980 6753.88 7644.82 46.390 85.610 6818,17 7739.40 44.410 85,360 6884.58 7832.31 44,290 86.120 6951.02 7926.62 43,840 85.520 7018.78 8020.15 42.250 83.460 7087.14 8113.87 41.980 83,480 7156.66 8208.03 41.430 84.880 7226.96 8301.75 39,940 85.020 7298.02 8395.39 38.390 84,840 7370.62 8489.52 37.390 85.520 7444.91 8582.82 37.040 86.910 7519.21 8677.32 36.680 87,790 7594.82 8770.67 35.750 87.540 7670.14 8865.22 35.730 87.620 7746.88 8959.12 35.120 88,140 7823.40 9052.95 34.260 85.820 7900.55 6616.00 616.10 S 1708.73 E 6682.38 614.95 S 1774.56 E 6748.67 612.68 S 1841.22 E 6809.48 608.96 S 1904.44 E 6873.77 603.97 S 1972.36 E 6940.18 598.67 S 2039.49 E 7006.62 593.84 S 2104.26 E 7074.38 589,07 S 2169.67 E 7142.74 582.95 S 2233.21 E 7212.26 575.81S 2295.66 E 7282.56 569.45 S 2357.97 E 7353.62 564.07 S 2418.83 E 7426.22 558.85 S 2477.74 E 7500.51 553.98 S 2535.34 E 7574.81 550.26 S 2591.64 E 7650.42 547.63 S 2648.27 E 7725.74 545.39 S 2703.37 E 7802.48 543.06 S 2758.55 E 7879.00 541.04 S 2812.94 E 7956.15 538.24 S 2866.26 E 5905779.76 N 365477.47 E 5905775.67 N 365543.48 E 5905773.95 N 365608.97 E 5905775.54 N 365673.34 E 5905777.67 N 365737.54 E 5905778.34 N 365803.40 E 5905778.31N 365869.24 E 5905779.38 N 365935.93 E 5905781.96 N 365999.21E 5905785.74 N 366067.21E 5905789.83 N 366134.42 E 5905793.49 N 366199.27 E 5905797.10 N '366264.76 E 5905802.07 N 366328.40 E 5905808.10 N 366390.96 E 5905813.33 N 366453.38 E 5905817.62 N 366514.32 E 5905821.79 N 366573.31 E 5905825.61N 366630.99 E 5905828.33 N 366687.35 E 5905829.94 N 366744.02 E 5905831.19 N 366799.15 E 5905832.54 N 366854.36 E 5905833.57 N 366908.78 E 5905835.42 N 366962.14 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 2.503 1412.22 0.550 1478.36 2.952 1543.81 2.320 1607.93 1.551 1671.83 1,391 1737.50 0.471 1803.18 1.248 1869.65 2,014 1932.61 0.625 2000,19 2.102 2066.97 0.586 2131.41 0.651 2196.50 2.269 2259.65 0.288 2321.66 1.149 2383.58 1.593 2444.09 1.660 2502,66 1.151 2559.95 0.976 2615.99 0.676 2672.41 1.009 2727.34 0.054 2782.33 0.725 2836.55 1.679 2889.66 Continued... 23 June, 1999 - 9:33 - 5 - DriliQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONFI[ ENTi L North Slope Alaska Measured Depth (ft) Incl. 9146,61 924O,87 9333,59 9428,07 9522.04 9615,78 9709,04 9803,48 9897,02 9990.94 10085,15 10182,20 10275.70 10369.59 10465,71 10559,71 10653,69 10747.95 10842,12 10936,48 11028.22 11091.85 11123,47 11154.95 11186.55 34.290 35,240 34,680 36.180 36,78O 36.000 34.110 32,140 30.090 27,970 25.670 23.380 22.140 21,730 20,720 20.050 19,540 18.690 18.090 17.210 16,780 16.860 18,500 21.040 23,390 Azim. 84,120 82,560 82,270 80,520 81,040 79,500 79,400 80,020 78,870 76,930 77,230 76,350 76,530 76.730 76,540 78,980 78,340 78.630 77,380 78,390 78,480 80.160 81,200 81,100 78,680 Sub-Sea Depth (ft) 7977,95 8055,38 8131,37 8208,36 8283,91 8359.38 8435,71 8514.80 8594,88 8677.00 8761,07 8849,36 8935,58 9O22,67 9112.27 9200,38 9288,81 9377,87 9467.23 9557,15 9644,88 9705.79 9735,92 9765,54 9794,79 Vertical Local Coordinates ' Global Coordinates Depth Northings EaStings Northings Eastings (fi) (ft) (fl) (ft) (ft) 8033,55 533,62 S 2918,80 E 5905839,10 N 367014,76 E 8110,98 527,37 S 2972,18 E 5905844,38 N 367068,24 E 8186,97 520,36 S 3024,84 E 5905850,45 N 367121,02 E 8263,96 512,15 S 3078,99 E 5905857,69 N 367175,30 E 8339,51 503,20 S 3134,13 E 5905865,64 N 367230,60 E 8414,98 493,81S 3188,95 E 5905874,05 N 367285,57 E 8491,31 484,01 S 3241,60 E 5905882,91 N 367338,40 E 8570,40 474,78 S 3292,38 E 5905891,22 N 367389,33 E 8650,48 465,94 S 3339,89 E 5905899,21 N 367437,00 E 8732,60 456,41 S 3384,46 E 5905907,94 N 367481,72 E 8816,67 446,91 S 3425,88 E 5905916,70 N 367523,31 E 8904,96 437,71S 3465,10 E 5905925,19 N 367562,69 E 8991,18 429,23 S 3500,26 E 5905933,04 N 367598,00 E 9078,27 421.12 S . 3534,39 E 5905940,53 N 367632,26 E 9167,87 413,08 S 3568,24 E 5905947,97 N 367666.26 E 9255,98 406,13 S 3600,23 E 5905954,34 N 367698,37 E 9344,41 399,87 S 3631,44 E 5905960,04 N 367729,68 E 9433,47 393,71 S 3661,68 E 5905965,66 N 367760,03 E 9522,83 387,54 $ 3690,74 E 5905971,30 N 367789,19 E 9612,75 381,53 S 3718,71E 5905976,81N 367817,27 E 9700,48 376,15 S 3744,98 E 5905981,72 N 367843,63 E 9761,39 372.74 S 3763,07 E 5905984.80 N 367861,78 E 9791,52 371,19 S 3772,55 E 5905986.18 N 367871.28 E 9821,14 369,55 S 3783,07 E 5905987,63 N 367881,83 E 9850,39 367,44 S 3794,83 E 5905989,53 N 367893,62 E Alaska State Plane Zone 3 Badami CPF Dogleg Vertical Rate Section (°/100fi) (ft) Comment 1,023 2941,90 1,381 2994,90 0,630 3047.14 1,917 3100,81 0.718 3155,44 1,281 3209,71 2,028 3261,81 2,117 3312,05 2.282 3359,07 2,470 3403,10 2,446 3443.99 2,389 3482,70 1,328 3517,39 0,444 3551,07 1.053 3584.48 1,151 3616,08 0,590 3646,93 0,907 3676,82 0.762 3705.54 0,987 3733.17 0,470 3759,14 0,774 3777,04 5.282 3786.42 8,069 3796.85 7,979 3808,48 Continued,., 23 June, 1999 - 9:33 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONFiDENTI/tL North Slope Alaska Measured Depth (ft) Incl, 11217,81 11249.64 11280.78 11311.53 11342.75 11374.31 11405.76 11437.04 11468,53 11500.07 11531.14 11563.19 11594.19 11625.57 11656.71 11687.93 11719.22 11750.81 11782.05 11813.24 11874.00 25.080 26.550 28.300 30.240 32.550 34.690 36.400 38.060 40.180 42.460 44.860 46.990 48.500 49.880 51.330 53.200 55.080 56.040 56.780 58.110 58.110 Azim. 73.980 71.o3o 69.090 67.320 68.390 66,800 68.760 68.300 67.300 65.940 64.730 67.760 65.93o 67.230 68.1oo 69.750 7o.13o 73.80o 76.46o 77.880 77.880 Sub-Sea Depth (ft) 9823.30 9851.95 9879.59 9906.41 9933.06 9959.34 9984.93 10009.84 10034.27 10057.95 10080.43 10102.72 10123.57 10144.08 10163.84 10182.95 1O201.28 10219.15 10236.43 10253.22 10285.32 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9878.90 364.40 S 3807.28 E 5905992.35 N 367906.13 E 9907.55 360.22 S 3820.49 E 5905996.29 N 367919.42 E 9935.19 355.32 S 3833.97 E 5906000.95 N 367932.98 E 9962.01 349.74 S 3847.93 E 5906006.28 N 367947.03 E 9988.66 343.61 S 3862.99 E 5906012.14 N 367962.20 E 10014.94 336.95 S 3879.14 E 5906018.51 N 367978.47 E 10040.53 330.04 S 3896.07 E 5906025.11 N 367995.52 E 10065.44 323.11 S 3913.68 E 5906031.72 N 368013,25 E 10089.87 315.60 S 3932.07 E 5906038.90 N 368031.77 E 10113.55 307.33 S 3951.18 E 5906046.83 N 368051.03 E 10136.03 298.38 S 3970.67 E 5906055.43 N 368070.68 E 10158.32 289.12 S 3991.74 E 5906064.31 N 368091.91 E 10179.17 280.09 S 4012.83 E 5906072.96 N 368113.16 E 10199.68 270.65 S 4034.63 E 5906082.00 N 368135.12 E 10219.44 261.51 S 4056.89 E 5906090.75 N 368157.54 E 10238.55 252.64 S 4079.92 E 5906099.20 N 368180.74 E 10256.88 243.94 S 4103.74 E 5906107.47 N 368204.71 E 10274.75 235.88 S 4128.51 E 5906115.09 N 368229.62 E 10292.03 229.21 S 4153.66 E 5906121.31 N 368254.88 E 10308.82 223.37 S 4179.29 E 5906126.68 N 368280.61 E 10340.92 212.54 S 4229.73 E 5906136.61 N 368331.24 E Alaska State Plane Zone 3 Badami CPF Dogleg Rate (°/lOOff) Vertical Section (ft) Comment 8.201 6,132 6.309 6.908 7.611 7.332 6.533 5.381 7.024 7.769 8.179 9.501 6.543 5.4Ol 5.133 7.304 6.088 10.051 7.478 5.736 o.000 3820.77 3833.76 3846.97 3860.63 3875.37 3891.16 3907.72 3924.96 3942.95 3961.62 3980.64 4001,22 4021.83 4043.13 4064.90 4087.46 4110.82 4135.15 4159.93 4185.24 4235.O7 Projected Survey Continued... 23 June, 1999 - 9:33 - 7 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB1 Your Ref: API-500292293370 Job No. AKVC90020, Surveyed: 23 November, 1998 CONF E ENT AL North Slope Alaska Alaska State Plane Zone 3 Badami CPF , All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. '"' Vertical depths are relative to Well. Northings and Eastings are relative to Well. ,,~ The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 92.877° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11874.00ft., The Bottom Hole Displacement is 4235.07ft., in the Direction of 92.877° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 11874.00 10340.92 212.54 S 4229.73 E Projected Survey 23 June, 1999 - 9:33 - 8 - DrlllQuest CONFIDENTIAL North Slope Alaska Alaska State Plane Zone 3 Badami CPF, Slot B1-36 B1-36 PB2 Job No. AKVC90020, Surveyed: 5 January, 1999 ORIGINAL SURVEY REPORT 23 June, 1999 Your Ref: AP1-500292293371 KBE-55.60 MWD Survey Instument Surface Coordinates: 5906424.99 N, 364106.00 E (70° 09' 08.0546" N, 147° 05' 33.9968" W) Kelly Bushing: 55.60ft aboVe Mean Sea Level Survey Ref: svy892 Sperry-Sun Drilling Services Survey Report for B1-36 PB2 Your Ref: API-500292293371 Job No. AKVC90020, Surveyed: 5 January, 1999 CONFiDENTiAL North Slope Alaska Measured Depth (ft) Incl. 11687.93 11719.22 11729.25 11760.32 11791.80 11822.82 11854.Ol 11885.1o 11926.53 11968.95 12000.85 12032.03 12063.43 12o94.51 12134.29 12226.92 12319.66 12414.33 12502.87 12597.19 12690.88 12785.16 12878.8o 12973.1o 13067.05 53.200 55.080 53.540 49.81o 49.16o 49.940 52.360 54.91o 57.930 59.320 6o.11o 60.960 62.290 63.530 64.19o 65.51o 67.600 70.210 71.460 69.930 68.420 66.61o 64.950 63.070 61.61o Azim. 69.750 70.130 67.380 70.300 75.640 80.320 82.930 85.860 86.550 89.880 91.400 93.640 98.180 101.370 102.410 102.700 105.770 105.450 101.390 100.480 102.100 99.030 98.240 101.780 97.520 Sub-Sea Depth (ft) 10182.95 1O201.28 10207.13 10226.40 10246.86 10266.99 10286.55 10304.99 10327.90 10349.99 10366.08 10381.42 10396.34 10410.50 10428.03 10467.39 10504.30 10538.37 10567.44 10598.62 10631.93 10668.00 10706.41 10747.74 10791.37 Vertical Depth (ft) 10238.55 10256.88 10262.73 10282.00 10302.46 10322.59 10342.15 10360.59 10383.50 10405.59 10421.68 10437.02 10451.94 10466.10 10483.63 10522.99 10559.90 10593.97 10623.04 10654.22 10687.53 10723.60 10762.01 10803.34 10846.97 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 252.64 S. 4079.92 E 5906099.20 N 368180.74 E 243.94 S 4103.74 E 5906107.47 N 368204.71 E 240.99 S 4111.34 E 5906110.29 N 368212.35 E 232.18 S 4134.05 E 5906118.69 N 368235.22 E 225.17 S 4156.92 E 5906125.28 N 368258.21 E 220.26 S 4180.00 E 5906129.78 N 368281.37 E 216.74 S 4204.02 E 5906132.87 N 368305.46 E 214.30 S 4228.93 E 5906134.86 N 368330.41 E 212.02 S 4263.37 E 5906136.52 N 368364.88 E 210.90 S 4299.56 E 5906136.99 N 368401.09 E 211.21S 4327.10 E 5906136.19 N 368428.62 E 212.41S 4354.22 E 5906134.51 N 368455.71 E 215.26 S 4381.69 E 5906131.17 N 368483.12 E 219.96 S 4408.95 E 5906125.98 N 368510.30 E 227.32 S 4443.90 E 5906117.99 N 368545.10 E 245.54 S 4525.74 E 5906098.30 N 368626.61E 266.48 S 4608.19 E. 5906075.89 N 368708.67 E 290.24 S 4693.25 E 5906050.60 N 368793.29 E 309.63 S 4774.58 E 5906029.75 N 368874.26 E 326.52 S 4861.97 E 5906011.30 N 368961.33 E' 343.66 S 4947.84 E 5905992.63 N 369046.88 E 359.64 S 5033.46 E 5905975.11N 369132.20 E 372.47 S 5117.89 E 5905960.77 N 369216.38 E 387.18 S 5201.34 E 5905944.57 N 369299.56 E 401.14 S 5283.34 E 5905929.14 N 369381.30 E Alaska State Plane Zone 3 Badami CPF Dogleg Rate (°/100ft) Vertical Section (ft) Comment 6.088 27.046 14.o86 13.o58 11.751 lO.132 11.173 7.420 7.460 4.802 6.823 13.4o7 9.970 2.874 1.453 3.782 2,775 4,555 1,86o 2.282 3.569 1.932 3.919 4.306 4087.62 411o.78 4118.15 414o.2o 4162.53 4185.21 4208.94 4233.62 4267.81 4303.84 4331.34 4358.47 4386.07 4413.6o 4448.97 4531.87 4615.58 4702.08 4784.56 4872.91 4959.76 5046.28 5131.39 5215.67 5298.44 Tie-On Survey Window Point Continued... 23 June, 1999 - 9:33 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB2 Your Ref: AP1-500292293371 Job No. AKVC90020, Surveyed: 5 January, 1999 gONFIUENTIAL North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (fi) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13161.77 60.190 96.090 10837.44 10893.04 410.96 S 5365.52 E 5905917.85 N 369463.28 E 13256.23 58.800 971960 10885.39 10940.99 420.90 S 5446.29 E 5905906.46 N 369543.86 E 13350.09 57.730 97.760 10934.76 10990.36 431.82 S 5525.36 E 5905894.12 N 369622.73 E 13443.68 55,420 94.420 10986.32 11041.92 440.13 S 5603.01 E 5905884.42 N 369700.21 E 13537.01 53.220 94.940 11040,75 11096.35 446.31S 5678.56 E 5905876.88 N 369775.64 E 13631.15 50,480 94.500 11098.90 11154.50 452.41 S 5752.33 E 5905869.47 N 369849.29 E 13724.50 48.110 93.320 11159.77 11215.37 457.24 S 5822.92 E 5905863.36 N 369919.79 E 13809.12 46.420 92.780 11217.20 11272.80 460.56 S 5884.99 E 5905858.94 N 369981.78 E 13908.90 44.620 92.510 11287.11 11342.71 463.84 S 5956.10 E 5905854.38 N 370052.82 E 14006.45 42.640 91.540 11357.71 11413.31 466.23 S 6023.36 E 5905850.78 N 370120.03 E 14100.31 41.150 91.520 11427.57 11483.17 467.91 S 6086.02 E 5905847.98 N 370182.64 E 14194.29 38.920 91.890 11499.53 11555.13 469.70 S 6146.44 E 5905845.11 N 370243.02 E 14287.48 36,410 89.640 11573.29 11628.89 470.49 S 6203.36 E 5905843.29 N 370299.92 E 14381.75 33.880 87.830 11650.37 11705.97 469.32 S 6257.61 E 5905843.49 N 370354.18 E 14475.73 28.180 86.320 11730.87 11786.47 466.90 S 6305.97 E 5905845.04 N 370402.58 E 14568.52 22.910 85.620 11814.56 11870.16 464.11S 6345,87 E 5905847.11N 370442.52 E 14661.61 19.840 81.250 11901.24 11956.84 460.33 S 6379,56 E 5905850.29 N 370476.27 E 14714.56 17.610 78.730 11951.39 12006.99 457.39 S 6396,30 E 5905852.93 N 370493.06 E 14878.00 17.610 78.730 12107.17 12162.77 447.73 S 6444.79 E 5905861.72 N 370541.72 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 28.644° (05-Jan-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 93.974° (True). . Based upon Minimum Curvature type calculations, at a Measured Depth of 14878.00ft., The Bottom Hole Displacement is 6460.32ft., in the Direction of 93.974° (True). Alaska State Plane Zone 3 Badami CPF Dogleg Rate (°/100ft) Vertical Section (ft) Comment 1.997 2.253 1.154 3.868 2.400 2.934 2.714 2.051 1.814 2.143 1.588 2.386 3.071 2.902 6.121 5.689 3.713 4.479 0,000 5381.10 5462.36 5542.00 5620.04 5695.84 5769.85 5840.61 5902.76 5973.93 6041.19 6103.81 6164.21 6221.05 6275.09 6323.16 6362.78 6396.12 6412.62 6460.32 Projected Survey Continued... 23 June, 1999 - 9:33 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for B1-36 PB2 Your Ref: AP1-$00292293371 Job No. AKVC90020, Surveyed: 5 January, 1999 CONFiDENTiAL North Slope Alaska Alaska State Plane Zone 3 Badami CPF Comments Measured Depth (ft) 11687.93 11719.22 14878.00 Station Coordinates TVD Northings Eastings (ft) (ft) (fi) 10238.55 252.64 S 4079.92 E 10256.88 243.94 S 4103.74 E 12162.77 447.73 S 6444.79 E Comment Tie-On Survey Window Point Projected Survey 23 June, 1999 - 9:33 - 4 - DrillQuest Tubing NSTC. Camco 4 1,,'2' x 1' GLM Camco 4 1/2' × 1" GLM Camc~ 4 1~' x 1" GLM Camco 4 i f2' × i ' GLM O~mco 4 1/2' × I" GLM C~co 4 '~" × 1' GLM intermediate Ca~ing L~O Z" × 4 l/~~ Un~r Hanger/Packer Liner L.80 -... BP Exploration (Alaska) ,_ ,,~. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-0955 Tel, (907) 561-5111 TO'. COMPANY: FAX NUMBER: TEL. NUMBER: DATE; FROM: FAX TRANSMI'Fi'AL BP EXPLORATION (ALASKA), INC. - LAND DEPARTMENT (907) 564-5132 (FAX) Blair Wo. ndzell AOGCC, 276-7542 279-1433 6/4/99 ~ PAGE(S) TO FOLLOW (EXCLUDING THIS COVER SHEET) URGENT I~1 FY! ~._.PLEASE REPLY I~1 CONFIDENTIAL KRI$SELL CRAND^LL ~~ JERRY SIOK (907) 564-5199 MESSAGE: Badami B1-36 Well Diagram, Fax Transmission Problems: Please conta~ Sandra Peterson (907-564-5228) or Verna Westlake (907-564-5401), BP EXPLORATION, Alaska Date: 0511811999 Trans: 90516 Badami Open & Cased Hole Logs Enclosed are the materials listed below. If you have any questions please contact David Douglas in the BP Exploration (Alaska), Inc. Petrotechnical Data Center at (907) 564-5929. Well Name Date Company Log Type Description B1-36 28-Apr-99 SPERRY FINAL WELL SUMMARY BOUND REPORT WITH ASCII DISKETTES (WELL NAME REFERENCED AS B1-36RD) B1-36 28-Apr-99 SPERRY COMBINATION MUD LOG - MD (WELL NAME REFERENCED AS B1-36RD) B1-36 28-Apr-99 SPERRY COMBINATION MUD LOG - TVD (WELL NAME REFERENCED AS B1-36RD) B1-36 28-Apr-99 SPERRY COMBINATION SHOW LOG - MD (WELL NAME REFERENCED AS B1-36RD) B1-36 28-Apr-99 SPERRY ENGINEERING LOG - MD (WELL NAME REFERENCED AS B1-36RD) B1-36 02-May-99 ATLAS GR/CCL/PERFORATION RECORD B1-36 05-Ma¥-99 ATLAS SEGMENTED BOND TOOL Please sign and return one copy of this transmittal letter. Open/Cased Hole Loqs ---- FINA / l~t.f'~ AOGCC ENS - Jerry Siok ~,~c~. AEX - Gary Pelka RECEIVED ;,!AY ,E 0 !999 AJaska 0ii & Gas Cons, .Mon0ra:je Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 995t9-6612 BP EXPLORATION April 15, 1999 Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ~SR ENO NRO STA S'i' .",. FiLE Dear Mr. Christenson, Re: Area Injection Order No. 17' Injection of Kekiktuk Gas into the Badami Reservoir The side-track of the B1-36 development/exploration well is currently underway. Upon its successful completion, we plan to begin a production test of the Kekiktuk formation. BPX as Badami operator, seeks Commission concurrence for the injection of gas from the Kekiktuk Formation into the Badami reservoir. Please advise us if there is anything we need to do, before injection of the Kekiktuk gas commences, to comply with your regulatory requirements. The well is expected to be completed, tied in to the facilities, and available for testing from the Kekiktuk interval by the middle of May. Sincerely, Gary Osborne Eastern North Slope Subsurface Manager CC: B.Turnbull 3. Dukes File: AOGCC _---- STATE OF ALASKA .... ALASK,-...)IL AND GAS CONSERVATION CO,viMISSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I--IAbandon [] Suspend [] Plugging []Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Re-Enter Cps S/D Well 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3859' NSL, 5186' WEL, SEC. 9, T9N, R20E, UM At top of productive interval 3588' NSL, 1151' WEL, SEC. 9, T9N, R20E, UM At effective depth 3412' NSL, 1259' EWL, SEC. 10, T9N, R20E, UM At total depth 3412' NSL, 1259' EWL, SEC. 10, T9N, R20E, UM 5. Type of well: [~ Development [] Exploratory [-I Stratigraphic []]Service 6. Datum Elevation (DF or KB) Plan KBE = 55.6' 7. Unit or Property Name Badami Unit 8. Well Number B1-36 9. Permit Number 98-232 10. APl Number 50-029-22933 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 14878 feet Plugs (measured) 12163 feet 14878 feet Junk (measured) 12163 feet Top of Cement Plugs at 12020' MD (01/99) None 0RIG NAL Length Size Cemented M D TVD 72' 20" 260 sx Arctic Set I 110' 110' 4508' 13-3/8" 3001 sx PF' E', 571 sx 'G' 4544' 4495' 12220' 9-5/8" 440 sx Class 'G' 10244' 8962' 4726' 7" 500 sx Class 'G' 7712 - 12438' 6921' - 10602 Perforation depth: measured N/A i i '.~.,~' ~;'.~ ? true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments [] Description summary of proposal [] Detailed operations program []] BOP sketch 4. Estimated date for commencing operation March 31, 1999 16. If proposal was verbally approved Name of approver Date approveu Contact Engineer Name/Number: Andy G. Krieger, 564-5390 Prepared By Name/Number: 17. I hereby certify tha~going is,t~n~orrect to the best of my knowledge Signed Commission Use Only 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Terrie Hubble, 564-4628 Date-~,~,~ ~/Ffft IApproval No.,~.'C~t- ~_~ Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test__'"'" Locat io. pac learancer..u~ov ' -- ..~,,~ ~] Mechanical Integrity Test __ Subseque.n,.~t~iYrkreq..ui, r¢. d 10- /--fO'7' Approved by order of the Commission ORIGINAL SIGNEDBY ~~ Commissioner Date~¢-" ~ Form 10-403 Rev. 06/15/88 Nol;)ert i4. C~h,-~6,";;c,,'~ ¢./ Submit In Triplicate ! hea re.d rvlces Alask; rilling To: Blair Wondzell - AOGCC Date: March 25, 1999 From' Andy G. Krieger Subject: B1-36 Re-entry Reference: Permit to Drill #98-232, APl #50-029-22933 Nabors 28E is expected to move on B1-36 the first week of April following completion of the Red Dog Exploration Well. This memo is written as an attachment to form 10-403 to resume operations on B1-36 (APl Cf 50-029- 22933). Operations are expected to follow the previously approved Permit to Drill #98-232 using a new directional plan to target the same bottom hole location. OVERVIEW Well B1-36 is a development/exploration well targeting both Badami and Kekiktuk intervals. The original well was drilled with 8 3A" hole to a depth of 11876' where all 3 cones were left in the hole. The well was open hole sidetracked and drilled to a TD of 14797'. While running the 7" drilling liner, it became differentially stuck at 12438'. Attempts to free the casing were unsuccessful and the string was cemented in place. The casing was drilled out with a 6" assembly recovering the existing 8 3A" hole to 14797'. An additional 81' of 6" hole was drilled before the motor shaft failed, leaving the bit in the hole. Due to time constraints surrounding the Red Dog Exploration Project, the well was abandoned with three cement plugs: 14628'-14878' Abandoning the Put River and Kekiktuk 13640'-13960' Abandoning the Killian 12020'-12525' Isolating the 7" shoe Note: All Badami sands are currently isolated by the cemented 7" liner. The B1-36 well will commence drilling out the 7" liner and kicking off in the open hole. The revised directional plan targets the same bottom hole location originally permitted. Once the target is achieved, the well will follow the previously approved operations with one modification: 1 ) The 4 1,~,, liner top will be placed at 12348' providing 90' of liner lap into the 7" casing. This will allow future access to all Badami intervals. The liner lap will be cemented with a liner top packer and pressure tested to 3500 psi. Should you need any more information or have any question please feel free to give me a call. An~y~G/.~ Krieger ' Operations Drilling Engineer 564-5390 Office 349-9585 Home 275-9869 Pager B1-36 Prop ed Sidetrack Schematic B1-36 Wellhead: BF / MSL = 19.1' ----= -----~, Nabors 28E: KB / BF = 35.3' I md: Valve ~i ~ ~ 2,100' Safety Landing Nipple ~. Camco 4-112" X 1" GLM @ 4,050', 6,400', 8,500', & t0,100' md kl~4544'md13-318",68#,L.80BTC - · ~ ~ ~ ........................ 5960' md 50.4 degrees ~ ~I[ 7,712' md Top 7" Liner % ' ' I ' ¥ ....................... 7739' md 44.4 degrees ~ ~ \ ~ 10244' md 9-5/8", 40#, L-80 BTC [, - - :- "~ .................. ~!0275' md 22.1 de§rees ~ ' md Wireline Entry Guide ~]~~~,438' md 7", 29#, Pl10 BTC DATE REV. BY COMMENTS BADAMI 3122/99 MTT Proposed Sidetrack WE L L: B 1-36 APl NO: 50-029-22933 BP EXPLORATION(AK.) Aaadrill $chlumkerge£ Alaska Dis~ric~ 3940 Arctic Olv~. Anchorage, AK 99503 (907] 273-1700 Fax 561-8537 DIRECTIONAL WELL PLkN fcr SHARED SERVICES DRILL~NS Well ......... : B1-35 (PSA) Field ........ : Badami Pad 1 C¢~putation..: r4[nimurn CurvaTure Units ........ : FEET Surface Lat..: 70.15223~36 1~ Surface Lonq.: 1~7.09277689 N Legal D~scrip~iom Surface ...... : 3859 FSL $186 T/e-in ~urvey: 3567 FSL 494 FEL SO9 TOgN.RlOR DM Target ....... : 3220 FSL 37~2 ~L .......... : 3201FSL 3605 FEL $1O T09N R2OE UM LOCATIONS - ALASKA Zone: 3 X-Coord Y-Coord 36~06.00 5906424.99 368792.84 ~9060gG.65 370779.00 590567~.00 378955.72 5905648.0U PROPGSED WELL PROFILE STAT/ON MEASURED fNCLN DIRECTION Z DENT IFI CATION DDP'£M AI?'D~LE AZ i>~ TOP C~Z NG TiE-II~ SQRVR"f 1241,1.33 70.21 105.45 PROP 5/100 12~40.~0 79,56 104.27 DROP' 1.5/lOG 12500.00 6'1, S~ 104.27 VERTICAL-DMPTHS SECTION TVD SUB-SEA bEPART 8553.60 8498.00 9~20~60 0965.00 105~3.97 10538.37 46~0.53 ].0602.5~ 105~6.9~ 4694,63 16'62~.D2 1856~.42 4750,52 Prepared ..... : 25 Mar 1999 Vert sect az.: 100.19 KB mlevatiom,: 55.60 f% Magnetic Dc]n; +28.561 (E) Scale Factor,: O.99992008 Convergence..: -1.02757822 ANADR]LL AKA-DPC APPROVED MAR 5 999 tNITIAL~/Z WBLLt{EAD X Y 290.23 $ 4693.18 256..43 S 4716.SS 310,24 S 4770,85 368?92,84 5906050.65 368~16.10 5906044.03 368870.14 5906029.25 CORVE O.vS/ZO0 1260~,00 66.06 Z04.27 10663.39 1-0607.79 4842.20 332.$9 S ~859.94 E2700_OD E5.81 ~83.49 10704.17 10~48,57 4533.32 354.V9 S 4~48.58 12890.80 65.56 102.72 1074~,35 10~89.75 5024.33 3~S.~6 S 5037.33 12900.00 65.3t 101.~4 10786.92 1873i.32 5115,22 394.88 S 5126,18 ~300O.DO 65.07 ZOI.16 1C828.$8 10773.28 5205.D6 413.05 S $215,~2 368958.80 59D6ffO5.O1 369D47.03 5905981.52 369].35.39 5905959.27 369225.~7 5905938.26 369312.~5 59~5918.49 13lOG.Q0 64.83 ~00.5~ 10871.23 10815.63 5296.55 429.97 S 530~.11 B 36940~,12 5905899.98 TOOL DL/ FACE 73L 1,9 4,56 LS 5,00 ll0L 1.50 llOL 0.75 logL 0.75 Z09~ 0,75 109L 0.75 108L 0.75 (A~adri]l {c}99 Ei36P.R 3,2C 10:45 STAT roN 5DE>~I'iFICATION '~RVE 2/1D0 TOP KILL-I~%.N TOP SKALB WALL TOP HRZ TOP PUT RTVER TOP KCK ZONE 2 / LCU PRDPC, SEDWELL PROFILE MEASURED fNCLN DIRECTIOI{ DEPT~ ANGLE AZIMUT~ 13200.00 64,60 99.58 13212.65 6~,57 99.48 13300.OD 62,52 99.]9 ~3~00.~0 6~.82 99.28 L3500.00 58.83 99.17 13600,00 56.83 13700.00 54.~3 538~0.00 52,53 13827.3~ 52.29 13900.00 50.84 14000.0~ 48.84 14200.60 ~6.84 142c0.g~ 44.85 14300.00 42.85 l&']OO. O0 40.85 14448.52 39 .89 14500.00 14600, 00 J6.86 14~97 , 54 34 . 91 ~4700 . O0 34 , 87 1460©,00 32.87 14900.00 30.88 l~gBB.1D 29.13 1500O.OQ 28,~9 15033.6~ 28.22 15033.69 28.22 ~5100.00 26.89 1.52~0.00 24.89 (Anadril] {c}99 ~136P8 3.2C _1_0:45 VERT £ CAL- DEFTR'S 'EVg SUB - SEA SF, CT I 0I~ DH PART 5286.96 53 98,3~ 5476.68 5564.82 5651.25 10913.94 ~085~.34 10919.37 10863.77 10955.0B 10902.~8 11005.30 109~9,?0 11055.56 10999,96 99.05 98.93 98.80 98.76 11108,81 !1053.21 ZllS4.97 11109.37 k1223.98 11168.38 ~1240.6~ 11185.00 11285.77 11230.17 5735.87 5899.29 5920.99 5977.89 98.52 98 97.83 11350.26 1~294.66 ~14~7.38 1i36/.78 ~14~7.03 1143],43 11559.15 31583.55 11633.63 11578.03 6054,28 6128,37 6200.07 6269.30 ~335.96 97.73 97.62 97.¢0 97.16 97.15 11710.39 11654.79 11789.34 11733.?{ 11868,60 /lg13.DO 6367,36 6399.99 6&61.29 96.8B 96.57 96.27 96. 23 96.11 ~1953.~0 11897.80 12038.31 11982.71 12114,60 12059.00 12125,~1 12~69.41 !2154,60 12059.0C 6575,45 662~.16 6672.11 6677.87 6~.93,93 ~6.11 $6.11 96.~1 12154.60 12099.00 12213,39 12157.79 12303.35 12247.75 6693.93 6724.53 6768,08 COORDiNATES-FROM ~;ELLHEAD 4{5.64 S 447~53 S 4~0,~7 S 474,68 S 488.54 S __. ALASKA Zon~ 3 TOOL DL/ X Y FACE 5391.16 E 369489.87 5905882.72 1OSL 5404.43 E 369551.10 5905880.62 1771 0.75 5~81,67 E 369578.09 59~5B66.~0 1771 ~.0O 5568.65 E 369664.79 5905550,54 1775 2.00 5853.97 E 3697~9.85 5905835.15 1771 2.00 501.94 514.87 527.31 536.63 539.25 ~737.55 E 369833.16 5905820.25 1771 2.00 5819.26 E 369914.62 590580~.86 577~ 2.00 5899.02 E 369994.14 5905791,99 ~?'?b 2.00 5920.47 E 370015.53 59057~8,30 1771 2,00 5976,73 E 370071.62 5905778.67 177L 2.90 550.66 563.. 54 .%71.87 581.04 590.84 6052.29 6125.62 6196.61 6265.19 6331.27 37'0146.96 5905765.90 ~771 2.00 370220.07 5905753.71 L771 2,00 3702~0.86 5905~42.11 1771 2.00 370359.25 59C3731.11 1761 2.00 390425.15 5905720,72 1761 2.00 595.10 599.46 607,49 614.75 614.91 6362.{1 E 370456.20 5905715.9~ 17~L 2.00 f390.77 E 370488.48 5905710.97 1~61 6455,6~ E 37~549.1~ 598570~.B5 1761 f512.~0 E 370605.91 5905693.~7 176L 2.0~ 6513.'t3 E 370607.13 5995692.39 17{L 2.C0 621,72 S 627.90 S 632.84 S 633.47 S 635.20 S 6621.49 6665.26 6671.00 6687,00 370~62.31 5905685.59 1761 2.00 3707~,63 59~567B.46 1755 2.00 370758.3P 5905672.75 3751 2.00 370764.03 5905672.02 1751 2.D0 370780,~0 5905670,00 LS 2.00 635.20 S 63~. 46 S 6687.00 6717.51 g760,92 ANADRILL APPROVED 1999 S1-3~ i_:'.,~.%.. 2.:, ;,l&l' 199~,, ?age 3 STAT ION M RASUREE, l NCI21 I ~El~fI F ICA~I ON DEPTH ANGLE ~ROPC, SEU WELL PRO~SE DIRECTION VERTICAL-DEPtHS AZ IMUTH TVD SU~- SEA SECT~Ot4 E-EPART ~B08.48 684~.67 65?0.$9 6g?~.59 15300.O0 END 2/100 CURVE 15472.48 TD 15472.48 22.8~ 20.89 19.44 L9.4~ 96.31 ~2394.78 1233~.1~ 96.33 12457.56 12431.96 96.i~ i2555.6~ 125Q0.~ 96.11 ~2555.60 32500.00 O00P~INATES-~ROM WELLHEAD 647.41 S 68~1.19 651.38 S 6838.26 654.04 S 68~3.11 654.04 $ 6863.1L ALASKA Zone 2 TOOL DL/ X Y FACE 37~89B.94 $905655.74 L~ 2.8C 37093D.93 5905651.11 LE 2.00 3~095S.92 5905548.00 2.00 3~D955.72 5905648.00 ANADRILL AKA-DPC APPROVED r AR 2, 5 1999 (Ana.~r£1/ (c}9~ B13698 3.2C ]0:45 ~%! P) FROM ANADRILL SCHLUMBERGER TO 5645193 P.05 VER.TICAL SECTION VIEW , ~ ,. Dep Scale' i inch = 1500 feet I Drewn ' 85 Mar 1999 \,.; · ,~nadnil] $chlumberge~ ~J Marker Identification MD §KB SECTN INCLN I A) TIE-IN SURVEY ~24~4 10594 487'~ 70 21 I ' , B) DROP 5/100 ~.2440 10603 4695 70 56 I · J C) DROP 1.5/100 12500 1062~ 4751 67.56 --- [ ................. i D) CURVE 0.75/100 12GO0 10663 deal2 66.05 } E) CURVE 2/10o 13213 109~9 5398 64.57 l~, I Fl T~RGET ~~ 15034 ~2155 6694 28.22 ' Gl ~ND 2/~00 CURVE 15472 12556 6871 , : H] TO 15472 12556 6871 % I ,.~. ~ ANADRILL AKA.,DPC %, ~R S 5 1999 ~ ... ...~ .................. -- ~ -- =, ..~ , ,. . ~ ~ I I ~ ..... ~ ..... . . I 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 . _ .l . i i .=_._. ~ ,,, i ! .... -- - i i , .... B -35 (PSA) VEBTICAL SECTION VIEW 10000-.-- - ~. ...... ,~['~-~Lt~ULI /~. _~-L.t~'t. OUL L ~U~ ~L- 1UU, lU , : ~ Dep Scale. 1 inch = 500 feet ~°~s°-XN,,.~ '~ ..... ~AR ~, 5 199~' -' ~ ~ ~larker Id.gn~Jfication MD ~a SECTN . ~u ~ CJ DROP ~.5/lO0 12500 ~0624 475l 67.56 ~0750- ~,:'-~- ~ ..... ! 8) CURVE 0.75/100 12600 10553 4842 66.1; ' ~~ · E) CURVE 2/100 132i3 IO91g 5398 64.] ; .~ ' F) TARGEI xxxx~***~** i5034 12l~ 6694 28.; ) ....... ~ 6) END 2/100 CURVE ~5472 ~2556 6871 ~9., ..... : H) ID ~547~ ~2556 6871 ~9., ,. )- ~~u~3 ~ t ................................... - . i . ) ............... I I ~ ~ ' ............. ~ ~ ....... ........... : .... ~ ~¢~- n~¢ , ~ ........ I ................... , ........................... ': ::: ........ , -4 ...... ~ .... / ..... ; ....... ... ,: ........ : , i -- ~ . .... I ........... ~ ...................... . . , ~ . 4250 4500 4750 5000 5250 5500 5750 6000 6~0 6500 6750 7000 7250 7500 7750 8000 8250 8501 Section Departure 1275( ! 4000 d ;'cj~] (2)99 8~2~738 3.26 ~t: 35 ,~N P.I An~dr J 11 S£h lu~berger , -36 (P8A) PLAN VIEW _ LOSURE · 6B94 feet at Azisuth 95.44 ECL CAEE RAt~N. i )rker TIE-i I]lqOP CURVE CURV[ TAR6EI END ...... SHARED SERVICES DRILLING ......... h . iii Il I ' ', I I n, I I I Il I __ Ill I J Ill I ' NAT[ON.' +28 561 (E) . ~ -i i ' 1 inch -- 1200 feet ~ . ' 25 MaP 1999 .............. -, ..., ......... ; AN/,DRILL AKA-E)PC -11'i SUFI~[EY 124~4 290 S 4693 E ' ; ~ §/100 12440 296 S 4717 E ' ].5/t00 ']2500 3]0 $ 4773 E i ~ARg ~ 1!199 IE 2/100 132J3 448 S 5404 E 2/100 CURYE 15472 654 S 6063 E ' IIX ITIA i : ............... ~ , KB 600 0 600 1200 '1800 2400 3000 3600 42.00 4800 5400 6000 6BO0 7200 71300 8400 9000 9600 10200 <- NEST · EAST -> ........ · qt) :"~1] (C) 8~3E:'fl ~J.Z~: 11:~3 I,K SHARED . SERVICES DRILLING i i ii m · __ i i · _ ii ,4nadr i l l Sch ]u~fler'ger iiii iii i i . Bi-36 (PGA) PLAN VIEW ii _1 CLOSURE ' 6894 feet at Azimuth 95.44 t250- 1000 750- 5O0 25O 0- 250- 1250- ' ' ~ ! ...... ; IDECLfNAT[0N.' +28.561 (E) : AN,~,DRILL AKA-DPC i SCALE ' I inch = 500 feet ~ i i ii i _ ii ~= ~ ~__~nn~,Noo Marker Identification MD N/S E/~ ~'~K A} TIE-]~ SURVEY ~2414 290 S 4693 E ' : B) Oa~ S/i00 12440 29~ S 4717 E ~~,.~//~,<~~ i , C)' mOP 1.5/~00 t2500 310 S 477~ E ...... ~mmm~ ..... ~ .... ~ E~ CURVE 2/100 1~3 448 S 5404 E FI TARGET ~xxx~x 15034 635 S 6687 E : GJ END 2/100 C~RVE ]5472 654 S 6863 E ........ ' H) TD 15472 654 S 66~3 E .... , -, 'x /' I ' ~~~ ,~,~ ,~o/~'~ .... ~ I ~ ~-i~ ~ ....... ~ ........ i ~ ' ............ I ..... ~ ...... I ..... ' ~ " ~ [ - . ' , I ....i ............................. I "' ' '1 ..... I ...... I I' I ......... I - ' -~ 4000 425'2 450I 4750 5000 5250 5500 5750 G000 6250 6500 5750 7000 72~ 7500 7750 GO0~ 8250 8500 E~ST -> , i, SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska CONFIDENTI FINAL c~g. ~o2. ~n~ s~~ ~o~RECE~VED BP E~LO~TION Bad~B1-36~ f~qAY ~0 !999 Bad~ ~oducfion Pad North Slope, ~ka ~.~ka0i~ ~ ~n~,~~ Final Report Summary April 1999 PREPARED FOR: BP EXPLORATION PREPARED BY: D. Walters and D. Wilson Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska TABLE OF CONTENTS Introduction .............................................................................................................................. A Well Sunm~ary ......................................................................................................................... B 1) Summary 2) Pore Pressure 3) Geology 4) Shows Show Reports ......................................................................................... C Survey Record ............................................................................ ~ ........... D INTRODUCTION Drilling operations for Badami B1-36RD well were initiated 3 April, 1999, by BP Exploration Alaska. The well was drilled by Nabors Alaska Drilling Rig 28E on the Badami Production Pad location. The surface location is in Section 9, Township 9 North Range 20 East. Badami B 1-36RD was designed as an injector well and to investigate the Kekituk formation to the East below 15000' Measured Depth. 7"" OD intermediate casing was in place on this well at 12438" MD-10600' TVD. Badami B1- 36RD was drilled to a total depth of 15546' MD-12728' TVD. The total number of operating days that were required to reach this depth was 26. A Sperry-Sun Logging Systems LS2000 Unit was in operation from 12485' MD-10600' TVD providing Mud Logging Services and Pore Pressure analysis. Additional services included the integration of real-time Gamma Ray, EWR and Directional Survey information from data supplied by Anadrill Schlumberger MWD. The mud logging crew for this job was Don Walters and Doug Wilson. The sensors incorporated in this unit are independent from the rig sensors and may differ slightly from those reported by the rig contractor. In addition, any evaluations in this report regarding formation evaluations, pore pressure estimates, or other geologic interpretations are made entirely by Sperry-Sun personnel from examination of the data collected by the LS2000 Unit and reference material made available by the Operator at the rig site. WELL SUMMARY Days: 26 Hole Size: 6.0 No. Bits: 8 Deviation: 71.18 - 7.02 deg Mud Weight: 12.8 Nabors Alaska Drilling Rig 28E was positioned on location prior to the spud in date of April 3, 1999. 7" casing was in place at 12438' MD. Drilling operations commenced by kicking off the original B 1-36ST well in open 8.5" hole at 12485' with a 6" bit. The directional part of the well was started at 12485' MD, sliding to change hole azimuth and maintain hole inclination at 66 degrees. The hole azimuth was built to 88 degrees and the inclination was allowed to drop to 8.5 degrees to hit target in the Kekituk Formation. The final survey was taken at 15486' calculating a tree vertical depth of 12669'. The projected bottom hole location for this well is 447.8' S and 6654' E of the surface well head location from the last survey taken, 694' True Vertical Depth below the top of the Kekituk Formation. Bit No. 1, a 6" STR-09D cone type and mud motor, was used to drill, wash and ream cement in the 7" casing and 8.5" open hole from the B1-36 Sidetrack hole previously drilled. Maximum bottoms up gas from the re-entry into the B 1-36 Sidetrack was recorded at 4250 units for washing from 9309-10610' MD with a mud weight of 13.3 ppg. Washing and reaming from 10610' to 10710' MD and circulation of bottoms up resulted in a maximum gas of 2400 units. Washing and reaming continued down to 12520' MD, reducing mud weight to 12.8 ppg and average circulating gas down to 250 units, with a maximum of 903 units at bottoms up. A FIT was performed to 14.2 ppg EMW with 12.8 ppg mud prior to kicking offhole at 10602' TVD. Kickoff, time drilling, commenced at 12520' MD to 12520' MD without result. The average mud gas recorded was 200 units. After a 37 stand short trip, 525 units of gas was recorded. Bit No. 2 a STR-1 cone type with mud motor was mn in to kick off the 6" hole at 12485' MD. This bit was time drilled at 1 foot / 5 minutes to 12663' MD. A short trip to the 7" shoe and 2 successful re-entries of the hole were performed. Bit No. 3, a DS105DF+NSU PDC type with mud motor was mn at 12663' MD and pulled after no footage, balled up due to 2 attempts to enter kickoff. Bit No. 4, a DS681NPV PDC type with mud motor drilled from 12663-13471' MD while maintaining a hole inclination of 64 deg and azimuth of 106 deg was pulled for inability to drop inclination. Bit No. 5, a STR-09D cone type with mud motor drilled from 13471-13780' MD, dropping inclination to 45 deg and turning azimuth to 81 deg was pulled because of slow ROP. Bit No. 6, a FM 2643 PDC type with mud motor drilled from 13780-14958' MD, dropping inclination to 20 deg and maintaining azimuth at 81 deg was pulled due to slow ROP. Bit No. 7, a STR-30D cone type with mud motor drilled from 14958-15267' MD, dropping inclination to 11 deg and turning azimuth to 92 deg was pulled because of mud motor revolutions. Bit No. 8, a STR-30D cone type with mud motor, drilled fi.om 15267-15546' MD. It was pulled due to torque, dropping inclination to 7 deg and turning azimuth to 108 deg. Total depth for the B1-36 RD was 15546' MD 12728' TVD. PORE PRESSURE The Estimated Pore Pressure at the commencement of mud logging at 12485' MD 10600' TVD was 12.0 ppg EMW. The drilling mud weight at this depth was 12.8 ppg. Prior to completing the Formation Integrity Test to 14.2 ppg EMW, the original KCL Polymer mud system weight of 13.3 ppg in the B1-36 Sidetrack was conditioned and reduced to 12.8 ppg. This mud weight was maintained to TD. Background and connection gasses were closely monitored which revealed no consistent connection gasses. One connection in the upper section of the HRZ and some sporadic connection gasses associated with coals in the Kekituk were noted. The sporadic nature of the connection gasses suggests that factors such as kelly cut mud, pipe movement creating cavings that liberate formation gas and formation hydrocarbon content in addition to the normal pore pressure trend in the interval below the Badami sand interval produced these connection gasses. The mud weight was maintained at 0.4/0.6 ppg overbalance over Estimated Pore Pressure through the Killian, HRZ and Kekituk. The Estimated Pore Pressure at the base of the Killian was 12.0 ppg. with a drilling mud weight of 12.8 ppg. One high connection gas was noted while drilling the HRZ, while the second connection in the HRZ produced no connection gas. Connection gasses associated with coal caving were noted in the Kekituk, whereas connections in shales or sandstones produced little connection gas. The Estimated Pore Pressure was raised to 12.2 ppg EMW with a drilling mud weight of 12.8 ppg at the top of the Shale Wall based upon data from B 1-36 Sidetrack and an observed increase in formation drilled gas fi.om 14540' MD in the B 1-36 RD well. Drilling mud losses occurred at 15338' MD, 15355' MD and 15412' MD in the Kekituk. The .6 ppg overbalance while drilling to TD was sufficient to maintain hole integrity safely. GEOLOGY FORMATION TOPS: MD(RKB) TVD(RKB) Killian 13837' 11237' Shale Wall 14418' 11675' HRZ 14645' 11867' HR Base 14865' 12064' SHOWS B 1-36RD was logged with 13 intervals of interest ( See Show Reports ). The first show interval fi.om 13835'-13915' MD / 11240'-11275' TVD in the Killian formation had fair to good oil show quality. The primary sample fluorescence in these sands was mostly pinpoint dull orange-yellow. The cut fluorescence had predominately an instantaneous flash yellow/white color. The oil gravity in the first zone is estimated 30 gravity. Steam still chromatographic analysis indicates this zone contains oil and possibly some water saturation. MWD resistivity had a range of 10-20 ohm-m/m2. The second show interval fi.om 14865'-14980' MD / 12069'-12173' TVD in the Put River or Uppem~ost Kekituk had a fair oil show quality. The primary sample fluorescence in this sand was mostly faint yellow. The cut fluorescence was of an instantaneous flash yellow color. Estimated oil gravity was 30. Steam still chromatographic analysis indicates this zone contains oil. MWD resistivity ranged from 25-40 ohm-m/m2. The third zone is in the Kekituk fi.om 15060'-15080' MD / 12245'-12270' TVD, interpreted as a coal from high methane ratio and sample examination. No fluorescence or cut was observed in the cuttings samples. The fourth zone ( Show Report 3A ) is in the Kekituk from 15045'-15055' MD / 12262'-12272' TVD, a tight sandstone. Overall low drilled gas and low chromatograph readings from steam still support tight sand. No observable fluorescence or cut flourescence. MWD resistivity in this zone is 8 ohm-m/m2. The ill=th zone is in the Kekituk from 15108'-15115' MD / 12300'-12305' TVD, interpreted as a coal due to high methane ratio and sample examination. The sixth zone is in the Kekituk from 15131'-15139' MD / 12320'-12330' TVD, interpreted as a coal because of methane ratio and sample examination. The seventh zone is in the Kekituk from 15173'-15178' MD / 12355'-12365' TVD, rated a poor show for oil as nonproductive hydrocarbons in a sandstone. No sample fluorescence was observed. The cut fluorescence was a very slow streaming white-yellow color. Steam still chromatographic analysis indicates zone to be oil and possibly water beating. MWD resistivity for this interval is 22 ohm-m/m2. The eighth zone is in the Kekituk from 15184'-15197' MD / 12370'-12380' TVD, interpreted as coal from high methane ratio in steam still hydrocarbon analysis and sample examination. The ninth zone is in the Kekituk from 15225'-15305' MD / 12410'-12490' TVD, rated as a poor to fair show for oil and gas in a sandstone. No sample fluorescence was noted. The cut fluorescence was a trace crush cut of white color. Steam still chromatographic analysis indicates oil and gas in this zone. Sample examination indicates zone to be well cemented to friable. MW23 resistivity data shows a decreasing trend in resistivity readings from approximately 2-6 ohm-m/m2 consistent with water saturation. The approximate top of the oil/water contact is 15210' MD / 12420' TVD The tenth zone is in the Kekituk from 15327'-15355' MD / 12511'-12540' TVD, rated as a poor show for oil in a tight sandstone and is rated as nonproductive. The sample fluorescence was 20% dull orange in color. The cut fluorescence was a slow streaming yellow in color. Steam still ratio analysis indicates oil and gas below a wet sand interval above. MW-D resistivity readings ranged from 10-51 ohm-m/m2. The eleventh zone is in the Kekituk from 15363'-15425' MD / 12546'12610' TVD, rated as water and non-producible hydrocarbons. The sample fluorescence was a dull yellow-orange in color. The cut fluorescence was poor slow to fast streaming yellow-orange-white in color. MWD resistivity was 2 ohm-m/m2. Zone appears to contain water and residual hydrocarbons from a water drive flush. The twelfth zone is in the Kekituk from 15465'-15485' MD / 12658'-12670' TVD, rated as nonproductive hydrocarbons. No sample fluorescence in sample. The cut fluorescence was a very faint slow white color. MWD restivity 2-6ohm-m/rn2. This is a poor show interval, with water saturation. The thirteenth zone is in the Kekituk from 15485'-15525' MD / 12670'-12707' TVD, rated as coal gas show and non-producible for oil. The cuttings samples from the first ,plot had no fluorescence and no cut. The second plot sample had no fluorescence and a very faint slow yellow/white cut fluorescence on unconsolidated sands. This is a poor oil show. It was difficult to use primary fluorescence and cut fluorescence to estimate the oil gravity in this well because the overall sample quality was poor. Much of the sandstone in the pay intervals came back unconsolidated from being broken apart by the PDC bit mechanics. This caused the oil that would have been contained in the matrix of sandstone cuttings to be "washed" on the way up the hole and significantly reduced our ability to estimate oil gravity from fluorescence. Sample quality in the Kekituk formation was very poor because of the fluid loss control material being added to the mud. This volume of material overwhelmed the cuttings with the slow penetration rates experienced in much of this zone. spe y-sun I~'R I L. LING ~ I::: RV I r c:: c; MUD LOGGING Operator B P Exploration Well Name B1-36RD Location North Slope Alaska ZONE PRODUCTION [] r_~ Show Report Depth Interval True Vert. Depth Prepared by Delivered to Date oiL [] WATER 13835 to 13915 11240 to 11275 D. WALTERS J. Siok 4/23/99 Time 6:00 [] NON-PRODUCT~EHYDROCARBON$ CONTACT DEPTH Gas~Oil ft Gas/Water ft. Oil~War:er ft DEPTH 13840 ft GAS 222 unit CHLOR. 30 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 11,100- 106 = 10,994 C~/C2 = 10 C2 1,119 - 32 = 1,087 C~/C3 = 6 C3 1,970- 105 = 1,865 C~/C4 = 9 C4 1,464- 191 = 1,273 C~/C5 = 27 C5 586 - 176 = 410 PRODUC'RON /~N_YSIS ri GAS ~1 O[!. [] WATER [] NON-PROD, DEPTH 13890 ft GAS 420 .unit CHLOR. 30 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 16,700 - 189 = 16,511 C~/C2 = 9 C2 2,000 - 77 = 1,923 C~!C3 = 4 C3 4,100 - 288 = 3,812 C~tC4 = 5 Ca 3,610 - 505 = 3,105 C~/C5 = 12 C5 1,690 - 302 = 1,388 PRODUCTION ~NALYS~S [] CAS [] OiL [] WATER [] NON-PROD. LITHOLOGY SANDSTONE-WHITE, OPAQUE, FiNE TO MEDIUM GRAINED, ANGULAR TO SUBANGULAR, WELL SORTED, POORLY CEMENTED, CALClC CEMENT, QUARTZ. SHOW EVALUATION 20% PINPOINT DULL ORANGE/YELLOW FLUORESCENCE, INSTANTANEOUS FLASH YELLOW/WHITE CUT FLUORESCENCE. ESTIMATED 30 GRAVITY OIL. STEAM STILL CHROMATOGRAPH RATIO ANALYSIS INDICATES THIS ZONE CONTAINS OIL AND POSSIBLY WATER. REMARKS MWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 10-20 OHM-M2/M FROM DATA PROVIDED BY ANN)RILL SCHLUMBERGER. OVERALL SHOW QUALITY IS FAIR FOR OIL. 1,000 lO0 10 1,1 00 oo 10 HYDROCARBON RATIOS C1/C2 C1/C3 C1/C4 C1/C5 HYDROCARBON RATIOS Cl/C2 Cl/C3 C1/C4 CltC5 NONI )RODI ]CTIV ~ .. O~L ~,,,,~ ii;~., ,,,..,,~ r ____ m line mm imm mm mmm m m mm~ m~ m m rtR II_I_IN G Operator Well Name Location ZONE PRODUCTION MUD LOGGING Depth Interval 14865 to 14980 True Vert. Depth 12068 to 12173 Prepared by D. WILSON B P Exploration Delivered to J. Sick B 1-36RD Date 4~24~99 Time 3:00 North Slope Alaska ri GAS [] OIL [] WATER n NON-PRODUCTIVEHYDROCARBONS CONTACT DEPTH Gas/Oil ft GasNVater ft OilNVater ft DEPTH 14900 ft GAS 680 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 6,150- 189 = 5,961 C~/C2 = 7 C2 930- 77 = 853 C~/C3 = 5 C3 1,560- 288 = 1,272 C~iC4 = 5 C4 1,656 - 505 = 1,151 C~/C5 = 17 Cz 654 - 302 = 352 PRODUCTION ANALYSIS n GAS ~1 O11 [] WATER [] NON-PROD. DEPTH 14940 ft GAS 207 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 12,900- 189 = 12,711 Cl/C2 = 10 C2 1,320 - 77 = 1,243 C~!C3 = 12 C3 1,360 - 288 = 1,072 C~/C4 = 13 C4 1,520 - 505 = 1,015 C~lC5 = 22 Cz 890 - 302 = 588 PRODUCTION ~NALYSIS [] GAS [] o]1. [] WATER [] NON-PROD, LITHOLOGY SANDSTONE-OPAQUE TO CLEAR, BLACK, WHITE, GRAY, VERY FINE TO MEDIUM GRAINED, ANGULAR TO SUBANGULAR, POORLY SORTED, 90% UNCONSOLIDATED, 10% WELL CEMENTED WITH CHERT, CARBONACEOUS SPECKS, TIGHT IN PART. SHOW EVALUATION IFAINT YELLOW FLUORESCENCE, INSTANTANEOUS FLASH YELLOW CUT FLUORESCENCE. ESTIMATED 30 GRAVITY OIL. STEAM STILL CHROMATOGRAPH RATIO ANALYSIS INDICATES THIS ZONE CONTAINS OIL. REMARKS IMWD RESISTIVITY READINGS IN THIS ZONE HAD A MAXIMUM OF 25-40 OHM-M2JM FROM DATA PROVIDED BY ANADRILL SCHLUMBERGER. OVERALL SHOW QUALITY IS FAIR FOR OIL. 1,000 lO0 10 1,000 100 10 HYDROCARBON RATIOS C1/C2 C1/C3 C1/C4 C1/C5 HYDROCARBON RATIOS C1/C2 C1/C3 C1/C4 C1/C5 Operator Well Name Location ZONE PRODUCTION :~___ Show Report 3 r'Sur'l. MUD LOGGING Depth Interval 15060 to 15080 R'd I r- G S; True Vert. Depth 12245 to 12270 Prepared by D WALTERS Exploration Delivered to J. Siok B1-36RD Date 4/26/99 Time 3:00 North Slope Alaska Oc_~s no~. OW^TER [] NON-PRODUCTIVE HYDR~NS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15065 ft GAS 593 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 47,000- 545 = 46,455 Cl/C2 = 13 C2 3,760 - 77 = 3,683 C~/C3 = 30 C3 1,680- 124 = 1,556 C~/C4 = 74 C4 804 - 174 = 630 C~/C5 = 160 C5 446 - 156 = 290 PRODUC~ON ,ANALYSIS [] GAS [] O'n [] WATER [] NON-PROD. DEPTH 15070 ft GAS 955 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 74,500 - 545 = 73,955 ClJC2 = 12 C2 6,300 - 77 = 6,223 Cl/C3 = 27 C3 2,860 - 124 = 2,736 C~/C4 = 61 C4 1,395 - 174 = 1,221 C~/C5 = 113 C5 813 - 156 = 657 PRODIJCTION ~N~J_YSIS [] GAS [] OT] n WATER [] NON-PROD. LITHOLOGY ZONE INTERPRETED AS COAL DUE TO HIGH METHANE RATIO AND SAMPLE EXAMINATION. SHOW EVALUATION FLUORESCENCE IN SAMPLE. NO CUT. REMARKS 1,000 lOO 10 1,000 lOO 10 HYDROCARBON RATIOS C1/C2 CllC3 Cl/C4 Cl/C5 HYDROCARBON RATIOS Cl/C2 C11C3 Cl/C4 C11C5 · BIJD L, O661NG Depth Interval 15045 to 15055 nR~I_LINr= ¢;~RV~C~=c; TrueVert. Depth 12262 to 12271 Prepared by D WALTERS Operator B P Exploration Delivered to J. Siok Well Name B1-36RD Date 4/26/99 Time 3:00 Location North Slope Alaska ZONE PRODUCTION [] GAS [] o]1. a WATER ~! NON-PRODUCTIVE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15050 ft ' GAS 90 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl 2,660- 545 = 2,115 Cl/C2 = 8 02 358 - 77 = 281 Cl/C3 = 7 C3 415 - 124 = 291 C~iC4 = 8 C4 451 - 174 = 277 Cl/C5 = 7 CO 481 - 156 = 325 PRODUCTION ANALYSIS [] GAS [] O11 [] WATER I~ NON-PROD. DEPTH ft GAS unit CHLOR. k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl = C~/C2 = C2 = Cl/C3 -- C3 = C~/C4 = C4 = CliO5 = C5 = PRODUCTION ANALYSIS [] GAS [] OIL [] WATER [] NON-PROD. LITHOLOGY SANDSTONE-CLEAR TO WHITE, VERY RNE TO RNE GRAIN, ANGULAR TO SUBANGULAR, MODERATELY TO WELL CEMENTED, CARBONACEOUS SPECKS, SHALE FRAGMENTS, AS LAMINATIONS AND INTERBEDS IN SHALE, MEDIUM HARD. 0 SHOW EVALUATION FLUORESCENCE IN SAMPLE. NO CUT. REMARKS JRESISTIVITY FROM ANADRILL MWD 80HM-M2/M AT 15052 MD SHOWS THAT THIS ZONE IS POSSIBLY WET OR TIGHT 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS Cl/C2 CllC3 Cl/C4 Cl/C5 NONi~RODt JCTIVI'~ elm _o . Oil_ HYDROCARBON RATIOS 01t02 C1/C3 Cl/C4 C1/C5 ~l~l"l ,~'~1 I1'1 MUD LOGGING nRILLING c:: c: R~ I l- Gc:: Operator B P Exploration Well Name B1-36RD Location North Slope Alaska Show Report '. ..... 4 Depth Interval 15108 True Vert. Depth 12300 Prepared by D WALTERS Delivered to J. Siok Date 4~26~99 to 15115 to 12305 Time 3:00 ZONE PRODUCTION [] GAS [] O]1. [] WATER [] NON-PRODUCT'/VE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15110 ft GAS 524 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl 35,200- 545 = 34,655 C1/C2 = 9 C2 3,800 - 77 = 3,723 CltC3 = 14 C3 2,540 - 124 = 2,416 CI/C4 = 26 C4 1,490 - 174 = 1,316 C1/C5 = 47 C5 899 - 156 = 743 PRODUCTION ANALYSIS [] GAS [] O]1. [] WATER, [] NON-PROD. DEPTH ft GAS unit CHLOR. k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl = C~/C2 = C2 = C~/C3 = C3 = Cl/C4 = C4 = Cl/C5 = C5 = PRODUCTION ANALYSIS [] GAS [] o]]. [] WATER [] NON-PROD. LITHOLOGY ZONE INTERPRETED AS COAL DUE TO HIGH METHANE RATIO AND SAMPLE EXAMINATION. SHOW EVALUATION FLUORESCENCE IN SAMPLE. NO CUT. REMARKS 1,000 100 10 1,000 100 lO HYDROCARBON RATIOS C1/C2 CltC3 Cl/C4 C1IC5 HYDROCARBON RATIOS Cl/C2 C1/C3 CllC4 C1/C5 NONI~RODIJCTIVE o, __ -- mm m~mmmm mm mm mm mm mm mm m m mm mm mm m mmmm mm MUO LOGGING OIF:I I LLI~J I~ Operator B P Exploration Well Name B1-36RD Location North Slope Alaska ZONE PRODUCTION [] GAS Show Report ----- 5 Depth Interval 15131 True Vert. Depth 12320 Prepared by D WALTERS Delivered to J. Siok Date 4/26~99 [] OTL [] WATER to 15139 to 12330 Time 3:00 ~ NON-PRODUCTIVE HYDROCARBONS CONTACT DEPTH Gas/Oil ft GasNVater ft Oil/Water ft DEPTH 15140 ft GAS 258 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 22,600- 0 = 22,600 CliO2 = 18 C2 1,260 - 0 = 1,260 Cl/C3 = 27 · 03 840- 0 = 840 Cl/C4 = 1,027 C4 22- 0 = 22 C~/C5 = 779 05 29- 0 = 29 PRODUC~0N N~IALYStS [] GAS [] O~ [] WATER ~1 NON-PROD. DEPTH ft GAS unit CHLOR. k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 = C~/C2 = C2 - = ClJC3 -- 03 = Cl/C4 C4 = Cl/C5 = C5 = PRODUCTION ,~LYSIS [] GAS [] O]1. [] WATER [] NON-PROD. LITHOLOGY GAS PEAK STEAM STILL SAMPLE WAS MISSED BECAUSE OF SHORTNESS OF PEAK. RUN PLO'FEED IS NORMAL AUTOMATIC SAMPLE CHROMATOGRAPH RUN AT 15140'. ZONE IS INTREPRETED AS COAL BECAUSE OF METHANE RATIO AND SAMPLE EXAMINATION. SHOW EVALUATION FLUORESCENCE IN SAMPLE. NO CUT. INO REMARKS 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS Cl/C2 Cl1C3 C1/C4 Cl/C5 NONI 'RODI ~CTIV!~ ,j ~A) / iF.... -- ) OIL mm m lB m m m m m m m HYDROCARBON RATIOS Cl/C2 Cl/C3 Cl/C4 Cl/C5 NONI~RODIICTiVE .. -- speed,j-sun DRILLING c; E; RV I I- E;c:: MUD LOGGING Operator B P Exploration Well Name B1-36RD Location North Slope Alaska ZONE PRODUCTION [] GAS Show Report .... 6 Depth Interval 15173 True Vert. Depth 12355 Prepared by D WALTERS Delivered to J. Sick Date 4/26/99 [] OIL ri WATER. to 15178 to 12365 Time 3:00 [] NON-PRODUCTZVE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15140 ft GAS 258 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C1 1,610- 545 = 1,065 C1/C2 = 5 C2 282 - 77 = 205 Gl JO3 = 4 C3 398 - 124 = 274 Cl/C4 = 5 C4 392- 174 = 218 CI/C5 = 6 C5 340 - 156 = 184 PRODUCTION ,N',IALYSIS [] ~ ~10TW OI WATER [] NON-PROD, Cl "- C2 = C3 = C4 = C§ = DEPTH ft GAS unit CHLOR. k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl/C2 = Cl/C3 = Cl/C4 ----' 0.~/C5 = PRODUCTION ,~N/~LYSIS [] GAS n O]]. [] WATER 0 NON-PROD. LITHOLOGY SANDSTONE-LIGHT GRAY, VERY FINED GRAINED, SUBANGULAR TO SUBROUND, WELL SORTED, POORLY CEMENTRD, VERY FRIABLE, QUARTZ. SHOW EVALUATION FLUORESCENCE, VERY SLOW STREAMING WHITE/YELLOW CUT FLUORESCENC. REMARKS IGAMMA RAY, RESISTIVITY AND SAMPLE EXAMINATION INDICATE THIS ZONE TO BE 0IL BEARING. PLOT ANALYSIS ALSO INDICATE THIS ZONE MAY BE WATER BEARING. THIS IS RATED A FAIR SHOW. 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS C1/C2 Cl/C3 C1/C4 C1/C5 NONI~RODt ICTIV!,-.. ,elm ~ m m m : -- OIL F ~ HYDROCARBON RATIOS Cl/C2 C1/C3 Cl/C4 Cl/C5 NONI )RODI ICTIV = .. ,'- __ -- m mm m -- mine mm OIL spe .m -sun DRI/LI~r- C; l:= RV I r- c: c: Operator Well Name Location ZONE PRODUCTION '-~' Show Report '-- J 7 MUD LOG61N6 Depth Interval 15184 to 15197 True Vert. Depth 12370 to 12380 Prepared by D WALTERS B P Exploration Delivered to J. Siok B1-36RD Date 4/26/99 Time 3:00 North Slope Alaska [] ~ [] OTI [] WATER I]1 NON-PRODUCT~E HYDR~NS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15190 ft GAS 583 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Ct 47,500- 545 = 46,955 C~/C2 = 13 C2 3,600 - 77 = 3,523 CltC3 = 35 C3 1,470- 124 = 1,346 C~/C4 = 101 C4 639- 174 = 465 C~/C5 = 356 C5 288 - 156 = 132 PRODUCTION ,N',I/~J_YSIS [] ~ [] OIL n WATER [] NON-PROD. DEPTH ft GAS unit CHLOR. k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS = C1/C2 = 0~/C3 = = C~lC,~ = = C~IC~ = .. O1 C3 C4 PRODUCTION ~IALYSIS [] GAS [] OIL [] WATER [] NON-PROD, LITHOLOGY THIS ZONE IS INTRPRETED TO BE COAL FROM HIGH METHANE RATIO AND SAMPLE EXAMINATION SHOW EVALUATION FLUORESCENCE IN SAMPLE. NO CUT REMARKS 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS CllC2 C1/C3 C1/C4 C1/C5 ,, '"NON t J? __ m m m m m ~ ~ m m m "OIL ' I i I ~ ' ,,, .... HYDROCARBON RATIOS Cl/C2 C1/C3 Cl/C4 Cl/C5 · NONI~RODIJCTIVE ,. Ii-, _~ .-_-~__-'' '"". Z .... . ORILLING c; I;; RV I C c c; Operator Well Name Location ZONE PRODUCTION MUD LOGGING Depth Interval 15225 to 15305 True Vert. Depth 12410 to 12490 Prepared by D WILSON B P ~ploration Del~ered to J. Siok B1-36RD ~+~ ~o,~ ~;~ ~.~ North Slope Alaska Co~¢rACT DEPTH Gas/Oil fi: Gas/Water fi: Oil~¢~'ater ^r~oo~v ~ ~r~ ~, DEPTH 15290 ff GAS 243 un;~ CHLOR. 36 k, FLOWLINE SUCTION SHOW ppm ppm P. AT. iOS C~ 16,600- i,530 = !5,070 CliO2 = 9 C2 2,040 - 308 = 1,732 C~!C3 = 12 C3 1,850 - 550 = 1,300 C!IC4 = 22 C4 1,350 - 662 = 688 C;IC5 = 44 C5 827 - 488 = 339 FHIJIJUU A~MLYSiS ~11 GAS [] O~. [] WATER [] NON-~OD. DEPTH 15300 fi: GAS 140 unil: CHLOR. '~ FLOWL!NE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl 15,100- 1,530 = 13,570 Cl/C2 = 10 C2 1,700- 308 = 1,392 CliO3 = 15 C3 1,480 - 550 = 930 C~/C4 = 28 C4 1,148 - 662 = 486 C~/C5 = 53 C5 744 - 488 = 256 PRODUC~0N /~ALYSIS [] GAS [] O]1. [] WATER [] NON-PROD. LITHOLOGY SANDSTONE-CLEAR, GRAY, BLACK, VERY FINE TO FINE GRAIN, SUBANGULAR, WELLSORTED, WELL CEMENTED TO FRIABLE,ARGILLACEOUS COAL FRAGMENTS IN PART. SHOW EVALUATION ITRACE WHITE CRUSH CUT FLUORESCENCE IN SANDSTONE. REMARKS IRESIDUAL OIL AND GAS IN THIS ZONE. MWD RESISTIVITY SHOWS A DECREASING TREND IN THIS ZONE FROM OIL/WATER CONTACT. RESISTIVITY READINGS FOR SAND PACKAGE RANGE FROM OHM-M/M2. POSSIBLE RESIDUAL OIL FROM WATER DRIVE. 2-6 I nnn !00 10 1 ,( 00 00 10 HYDROCARBON RATIOS I I I I I I I I I I I I ~~I I I __ ¢ - I I ~ ~ I I I ~ ~ I I ~ i I I I I I I I I I I I i I I I t I OIL mmml ~ ama lima ~ ~ ~ ama maim arum HYDROCARBON RATIOS Cl/C2 Cl/C3 Cl/C4 Cl/C5 NONI )RODI JCTIVIE .. GAS ~'-' -- rIRILLING c c:: R V I I-'c:: c; MUD LOGGING Operator Well Name Location B P Exploration B1-36RD North Slope Alaska Show Report -~---' 9 Depth Interval 15327 to 15355 True Vert, Depth 12511 to 12540 Prepared by D WILSON Delivered to J. S/ok Date 4/28/99 Time 3:00 ZONE PRODUCTION [] GAS [] OIL [] WATER [] NON-PRODUCFJVE HYDROCARBONS CONTACT DEPTH Gas/Oil ~t Gas/Water ft Oil/Water ft DEPTH 15330 ft GAS 144 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 11,000 - 1,530 = 9,470 C~1C2 = 7 C2 1,660- 308 = 1,352 C~/C3 = 8 C3 1,760 - 550 = 1,210 C1/C4 = 12 C4 1,422- 662 = 760 C~/C5 = 24 C5 880 - 488 = 392 PRODUCTION ANALYSIS n GAS [] 0]% [] WATER I~ NON-PROD. DEPTH 15340 ft GAS 172 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS Cl 16,500- 1,530 = 14,970 C~1C2 = 8 C2 2,180 - 308 = 1,872 C~/C3 = 10 C3 2,020 - 550 = 1,470 C~1C4 = 20 C4 1,424 - 662 = 762 C~/C5 = 39 C5 871 - 488 = 383 PRODUCTION ANALYSIS [] GAS [] 011. [] WATER [] NON-PROD. LITHOLOGY SANDSTONE-BROWN,LIGHT GRAY, FINE GRAIN, ANGULAR TO SUBANGULAR, WELL SORTED,WELL INDURATED. SHOW EVALUATION 20% DULL ORANGE SAMPLE FLUORESCENCE, SLOW STREAMING YELLOW CUT FLUORESCENCE. REMARKS lOlL AND GAS IN THIS TIGHT ZONE BELOW WET SAND PACKAGE ABOVE. MWD RESISTIVEY READINGS 10-51OHM-M/M2 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS C1/C2 Cl/C3 C1/C4 Cl/C5 HYDROCARBON RATIOS C11C2 C1/C3 C1/C4 Cl/C5 ,.. NONI )RODI )CTIViE .. -,- lmmm ,il mil ~ m mm mm mm~~m~mm ~ ~-- -- _~mm~mlF ! I · -~L.Jr~ MUD LOGGING Depth Interval 15363 to 15425 I::)FtlLLINI~ c:¢=RVlr-¢:=c; TrueVert. Depth 12546 to 12610 Prepared by D WILSON Operator B P Exploration Delivered to J. Sick Well Name B1-36RD Date 4/28/99 Time 3:00 Location North Slope Alaska ZONE PRODUCTION [] G/L5 [] OIL [] WATER [] NON-PRODUCTIVE HYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15370 ft GAS 251 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 8,700- 615 = 8,085 C~/C2 = 7 C2 1,370 - 158 = 1,212 C~/C3 -- 8 C3 1,330 - 312 = 1,018 C~/C4 = 15 C4 942- 415 = 527 C~/C5 = 39 C5 600 - 390 = 210 PRODUCTION AN~YSIS [] GAS a OIL a WATER [] NON-PROD. DEPTH 15410 ft GAS 230 unit CHLOR. 36 k FLOWLINE- SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 8,700- 615 = 8,085 Cl/C2 = 13 C2 800 - 158 = 642 C~/C3 = 33 C3 560 - 312 = 248 C~/C4 = -172 C,; 368- 415 = -47 C~/C5 = -57 C5 247- 390 = -143 PRODUCTION ANALYSIS a GAS a 011. [] WATER [] NON-PROD. LITHOLOGY SANDSTONE-CLEAR, WHITE, GRAY, BLACK, FROSTED, BROWN IN PART, VERY FINE TO FINE GRAIN, WELL SORTED, UNCONSOLIDATED IN SAMPLE, CALACREOUS FRAGMENTS INFER CALCAREOUS CEMENT, TRACE VERY FRIABLE, 85% QUARTZ, 15% LITHIC FRAGMENTS. GOOD NFERRED POROSITY FROM SAMPLE EXAMINATION AND LOST 31RCULATION INTERVAL AT 15412 MD. SHOW EVALUATION IDULL YELLOW - ORANGE SAMPLE FLUORESCENCE, POOR SLOW TO FAST STREAMING YELLOW-ORANGE-WHITE CUT FLUORESCENCE. TRACE GRAY RING WHITE LIGHT CUT. REMARKS WATER AND NONPRODUCABLE HYDROCARBONS. SECOND STEAM STILL PLOT RATIOS CONTAINS NEGATIVE VALUES AND ALL THE C4 AND C5 GASES ARE FROM GAS ENTRAINED IN THE DRILLING MUD AS BACKROUND. 1,000 100 10 1,00o 100 lO HYDROCARBON RATIOS C1/C2 C1/C3 C1/C4 Cl/C5 HYDROCARBON RATIOS Cl/02 C11C3 Cl/C4 CltC5 NONI)RODIJCTIV= .. e~ spe .r -sun DFI II_L. IN G c; c: RV I I:: c:: c; MUD LOGGING Operator B P Exploration Well Name B1-36RD Location North Slope Alaska ZONE PRODUCTION n GAS Show Report ~ Depth Interval True Vert. Depth Prepared by Delivered to Date [] OTI [] WATER 11 15465 to 15485 12658 to 12670 D WILSON J. Siok 4/28t99 Time 3:00 ~ NON-PRODUCT'~EHYDROCARBONS CONTACT DEPTH Gas/Oil ft Gas/Water ft Oil/Water ft DEPTH 15470 ft GAS 220 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 5,350 - 665 = 4,685 C~/C2 = 10 C2 655- 186 = 469 C~/C3 = 15 C3 640 - 320 = 320 C~/C4 = 33 C4 501 - 361 = 140 C11C5 = -360 C5 350 - 363 = -13 PRODUC~0N ,~NALYSIS n~ r'lo~ OWATER I]INON-PROD. DEPTH 15480 ft GAS 230 unit CHLOR. 36 k FLOWLINE-SUCTION = SHOW HYDROCARBON ppm ppm RATIOS C~ 7,550 - 665 = 6,885 C~/C2 = 9 C2 960 - 186 = 774 C~iC3 = 11 C3 950- 320 = 630 C~/C4 = 20 C4 714- 361 = 353 C~/C5 = 53 C5 492- 363 = 129 PRODUC~ON ~J_YSIS [] GAS ri O~ [] WATER DI NON-PROD, LITHOLOGY SANDSTONE-OPAQUE, BLACK, GRAY, VERY RNE TO MEDIUM GRAIN, ANGULAR TO SUBANGULAR, POOR LY SORTED, UNCONSOLIDATED, QUARTZ, CHERT, CARBONACEOUS MATERIAL. SHOW EVALUATION INO FLUORESCENCE IN SAMPLE. VERY FAINT WHITE SLOW CUT FLUORESCENCE.. REMARKS PRODUCTIVE HYDROCARBONS INON 1,000 100 10 1,000 100 10 HYDROCARBON RATIOS C1/C2 Cl/C3 C1/C4 Cl/C5 NONI'KOUIICTIV: · HYDROCARBON RATIOS C1/C2 Cl/C3 C1/C4 C11C5 NONI)RODIJCTIV-- .. -" e.- e~' (;AS ~' I spe .r -sun I~R I L'LIN; SERVIE;C Operator Well Name Location ZONE PRODUCTION Show Report v- .... 12 MUD LOGGING Depth Interval 15485 to 15525 True Vert. ~'""'~' ~"~-'" '-- "~""-' iJgj~u ~ Iz.v~ v &v I/I VI Prepared by D WILSON B P Exploration DelN'ered to J. Siok NoAh Slope Alaska c0hq'ACT DEPTH Gas/Oil VIII I DEPTH I.~500 ff GAS -q46 :,n~. t.~,t ~ AR k ............... ~_'_ ...... _-__' ........... _- ...... _-JZ_'___-_'_'__-_]_'_Z ........ _-_--_-_ _'_'. I FLO'VVLiNE-SUCTION = -SHOW ' I ppm ppm RATIOS C~ 59,500- !,600 = 57,900 C~!C2 = !3 Ce 4,850- 334 = 4,516 r-.~r_..~,.,~ : 32 C.~_ 2.,300. - 490: 1.810. ,.,., v4'"' '~' = 119 C~ 965- 480 = 485 C;iC5 : 2, i44 C5 409 - 382 = 27 FH. UUUL: ! IUN A~MLYS!S !~ ~ [] O~, [] WAI~R [] NON-PROD. A~ ~"~1..! I DEPTH 15520 ft GAS 1..,,.,unit,-,, --,.,,-. 36 k FLOWLINE- SUCTION = SHOW h~'DROCARBON ppm ppm P, ATIOS I C~ 5, G50- l,SO0 : 4,050 r-.tr-_~,~...z -- ~,-- I ~ ~-,~ ooo 334 -- CJC_~ "" _ - ~ C3 675 - 490 = !85 C;iC4 -- 78 C4 532 - 480 = 52 Ci/C5 = -79 I ,.,.~ 331 PRC£A jC-i~C)N ' A~&LYS!S $~! GAS !'! O~ [] WATER ~! NON-~OD, ~ I L,, HOLOGY 'HIGH ~AS iN RRST P~,T?O PLOT iNTERPRET, ED AS CO,~ ~OM P,A~O ANALYSIS AND TRACES OF COAL IN CUTTINGS SAMPLE. RRST RATIO PLOT CUTTINGS CONTAIN LARGE AMOUNTS OF SAND CAV1NGS. SECOND RATIO PLOT FROM BELOW COAL-SAND-OPAQUE, BLACK, GRAY, VERY RNE TO MEDIUM GRAIN, ANGUALR TO SUBANGULAR, POORLY SORTED, UNCONSOLIDATED, QUARTZ, CHERT, CARBONACEOUS MATERIAL-TRACE COAL. SHOW EVALUATION INO FLUORESCENCE IN SAMPLE AND NO CUT FOR SAMPLE IN RRST RATIO PLOT. SECOND RATIO PLOT-NO FLUORESCENCE, VERY FAINT WHITE SLOW CUT FLUORESCENCE. REMARKS WATER AND GAS FROM COAL. !O0 i0 1,000 100 10 I'lT I - ~ ~ I I I I I I I I I I I I I I I I I I I I I I I ,~k,. I I UlL I I 1 I I I I I I I I ! I ! ' ' I I I I I I l ! I I ! t I I ! ! l ! ! ! ! ! ! I 11lltll~(pl~/l~A ~lDFql&l D A'ri/NO. &~i'N.q,,dtq~ttB'qrlkE~rql~l~ll ~ I Iq~hl~ C1 tC2 Cl/C3 C!1C4 C1 tC5 Client ................... : BP Exploration (Alaska) Field .................... : Badami, Pad 1 ANADRILL SCHLUMBERGER Survey report Inc. 28-Apr-1999 16:07:35 Page 1 of 8 Well ..................... : B1-36 Re-entry Spud date ................ : April-06-1999 API number ............... : 50-029-22933-00 Last survey date ......... : 28-Apr-1999 Engineer ................. : bosse Rig: .................... : Nabors 28E State: .................. : Alaska Total accepted surveys...: 194 MD of first survey ....... : 12444.62 ft MD of last survey ........ : 15486.04 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller Pipe Tally GL above permanent ....... : 20.30 ft KB above permanent ....... : Top Drive DF above permanent ....... : 53.05 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point ................ Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ : 0.00 ft Azimuth from rotary table to target: 100.20 degrees Geomagnetic data Magnetic model ........... Magnetic date ............ Magnetic field strength..: Magnetic dec (+E/W-) ..... Magnetic dip ............. BGGM version 1998 05-Apr-1999 1148.28 HCNT 28.56 degrees 80.83 degrees MWD survey Reference Reference G .............. Reference H .............. : Reference Dip ............ : Tolerance of G ........... Tolerance of H ........... Tolerance of Dip ......... Criteria 1002.67 mGal 1148.28 HCNT 80.83 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees Corrections --- Magnetic dec (+E/W-) ..... : 28.56 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.56 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1999 Anadrill IDEAL ID6 OB 70] ~ ANADR'~[LL SChLUMBERgER Sur{zey Rep~ort Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) First survey in list is the 2 12411.78 70.21 105.45 3 12444.62 71.18 105.10 4 12516.81 66.88 104.19 5 12613.59 64.15 104.36 28-Apr-1999 6: 07: b Course TVD Vertical Displ length depth section +N/S- (ft) (ft) (ft) (ft) 6 12635.65 64.22 101.18 7 12732.22 64.05 102.74 8 12830.33 64.86 102.34 9 12923.41 65.72 105.36 10 13017.68 66.47 103,37 tie in point. 92.12 10591.41 32.84 10602.27 72.19 10628.10 96.78 10668.21 11 13113.95 67.18 105.85 12 13207.96 66.61 104.85 13 13302.33 65.57 106.93 14 13397.89 64.58 105.30 15 13468.40 63.79 106.06 Displ +z/w- (ft) 16 13564.66 60.83 101.65 17 13599.03 58.05 98.81 18 13630.59 55.45 96.01 19 13658.47 52.77 92.65 20 13691.82 50.25 88.98 Page 21 13723.34 48.30 84.83 22 13780.07 45.52 80.96 23 13875.58 44.23 78.36 24 13971.30 43.49 78.69 25 14065.72 42.60 80.12 Total displ (ft) 26 14160.88 41.42 81.55 27 14256.74 39.87 81.65 28 14351.02 37.76 80.48 29 14448.31 35.58 78.88 30 14543.69 32.15 79.44 At Azim (deg) 4671.03 -290.26 4693.82 4702.78 93.54 4701.91 -298.43 4723.71 4733.13 93.61 4769.09 -315.48 4788.91 4799.29 93.77 4856.94 -337.19 4874.26 4885.91 93.96 22.06 10677.81 4876.78 -341.58 4893.63 4905.53 96.57 10719.95 4963.63 -359.58 4978.63 4991.60 98.11 10762.25 5052.07 -378.80 5065.04 5079.19 93.08 10801.17 5136.44 -399.05 5147.12 5162.57 94.27 10839.37 5222.39 -420.42 5230.61 5247.48 96.27 10877.26 94.01 10914.16 94.37 10952.41 95.56 10992.68 70.51 11023.38 93.99 94.13 94.28 94.43 94.60 5310.62 -442.75 5316.24 5334.64 94.76 5396.74 -465.64 5399.62 5419.66 94.93 5482.58 -489.25 5482.59 5504.38 95.10 5568.77 -513.31 5565.84 5589.46 95.27 5631.96 -530.46 5626.95 5651.90 95.39 5716.98 -550.91 5709.66 5736.17 95.51 5746.56 -556.17 5738.77 5765.66 95.54 5772.92 -559.59 5764.94 5792.03 95.54 5795.38 -561.30 5787.45 5814.61 95.54 5821.13 -561.69 5813.54 5840.61 95.52 5844.37 -560.41 5837.38 5864.22 5883.91 -555.32 5878.48 5904.65 5947.01 -543.24 5944.76 5969.53 6008.64 -530.05 6009.76 6033.09 6068.89 -518.19 6073.11 6095.17 96.26 11068.13 34.37 11085.60 31.56 11102.91 27.88 11119.25 33.35 11140.01 31.52 11160.58 56.73 11199.34 95.51 11267.03 95.72 11336.05 94.42 11405.05 95.16 11475.76 95.86 11548.49 94.28 11621.95 97.29 11699.98 95.38 11779.17 95.48 95.40 95.22 95.04 94.88 6128.96 -508.04 6135.97 6156.97 94.73 6188.14 -498.92 6197.74 6217.79 94.60 6243.97 -489.76 6256.12 6275.26 94.48 6298.39 -479.37 6313.27 6331.45 94.34 6347.98 -469.36 6365.47 6382.75 94.22 2 offS8 DLS (deg/ iOOf) 2.85 3.12 6.07 2.83 12.98 1.46 0.90 3.09 2.09 2.48 1.15 2.30 1.86 i.48 5.09 10.77 11.09 13.70 11.46 11.74 6,99 2.35 0.81 1.40 1.60 1.62 2.37 2.45 3.61 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID6 OB 70] Survey ~ z ~_Ap~r_1999 ~ ±b: 07: ~3 ~ Fage~ J U 0 f'" .Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 31 14639.08 28.22 79.66 32 14734.03 25.70 82.58 33 14830.36 22.90 82.23 34 14924.06 20.06 81.90 35 15021.43 17.03 85.61 Course TVD Vertical Displ length depth section +N/S- (ft) (ft) (ft) (ft) 95.39 11861.61 94.95 11946.24 96.33 12034.02 93.70 12121.21 97.37 12213.51 Displ Total At DLS Srvy Tool +E/W- displ Azim (deg/ tool qual (ft) (ft) (deg) 100f) type type 6392.85 -460.66 6412.62 6429.15 6433.50 -453.97 6455.13 6471.07 6471.24 -448.74 6494.42 6509.90 6503.85 -444.01 6528.40 6543.48 6533.51 -440.56 6559.16 6573.94 94.11 4.12 MWD 94.02 3.00 MWD 93.95 2.91 MWD 93.89 3.03 MWD 93.84 3.34 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 36 15112.58 13.69 88.19 91 37 15212.08 11.15 92.15 99 38 15302.99 9.77 94.60 90 39 15403.45 8.15 103.55 100 40 15486.04 7.02 108.47 82 .15 12301.39 6556.98 -439.20 6583.25 6597.89 .50 12398.56 6578.03 -439.19 6604.64 6619.23 .91 12487.96 6594.41 -440.14 6621.11 6635.72 .46 12587.19 6610.00 -442.49 6636.53 6651.27 .59 12669.06 6620.84 -445.46 6647.01 6661.92 93.82 3.74 MWD 93.80 2.69 MWD 93.80 1.59 MWD 93.81 2.12 MWD 93.83 1.58 MWD 6-axis 6-axis 6-axis 6-axis Final survey projected to driller 41 15546.00 7.02 108.47 59 [(c)1999 Anadrill IDEAL ID6 OB 70~] 's total depth. .96 12728.57 6628.10 -447.78 6653.96 6669.01 93.85 0.00 MWD BP EXPLORATION, Alaska Date: 3-24-1998 Trans# 90377 BPIBADAMI OH LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636. Sw Name RecType Rec Date Company Code Comments B1-36 OH 04-Dec-98:SPERRY MWD, NGP, DGR, EWR4. RUN 4 ON 12-4-98, RUN 5 ON 12-4-98, RUN 6 ON 12-9-98 AND RUN 7 ON 12-15- 98. B1-36 OH 04-Dec-98 SPERRY MWD, ROP, NGP, DGR, EWR4. RUN 4 ON 12-4-98, RUN 5 ON 12-4-98, RUN 6 ON 12-9-98 AND RUN 7 ON 12-15-98. B1-36 OH 06-Jan-99 SPERRY MWD, DGR, CNO, SLD. RUN 13 ON 1-6-99, RUN 14 ON 1-13-99. B1-36 OH 06-Jan-99 SPERRY MWD, DGR, CNO, SLD. RUN 13 ON 1-6-99, RUN 14 ON 1-13-99 B1-36PB1 OH 04-Dec-98 SPERRY MWD, ROP, DGR, EWR4. RUN 4 ON 12-4-98, RUN 5 ON 12-4-98, RUN 6 ON 12-9-98 AND RUN 7 ON 12-15- 98. B1-36PB1 OH 04-Dec-98 SPERRY MWD, DGR, EWR4. RUN 4 ON 12-04-98, RUN 5 ON 12,04,98, RUN 6 ON 12-9-98, RUN 7 ON 12-15-98. Please sign and return one copy of this transmittal letter to the address shown below. Thank-you, Scott LaVoie Petrotechnical Data Center OH Loqs DNR(Tim Ryherd) FINA(Mike Engle) Madellyn Millholland MB 7-1 AOGCC 2 5 F)99 Ajaska 0il & Gas 60ns. C0mmis~n Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nabors Rig No. 28e PTD # BPX Re p.: B1-36 Rig Rep.: 7" Set @ 12,438'md Location: Sec. Weekly X Other DATE: 4/17/99 98-232 Rig Ph.# 659-1201 Dick Maskell Bill Bixby 9 T. 9N R. 20E Meridian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F I 350/3500 P 1 350/7000 P 1 350/7000 P* 1 350/7000 P '1 350/7000 P 2 350/7000 P 1 350/7000 P N/A N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 350/7000 P 350/7000 P 350/7000 P 350/7000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 17 350/7000 P 42 350/70OO P 2 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 8@2000 avg. 3,000 J P 1,600 P minutes 25 sec. minutes 13 sec. P Remote: P Psig. Number of Failures: 2 ,Test Time: 8.5 Hours. Numlger of valves tested 31 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to tl~e AO0CC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The lower set of pipe rams had a door seal leak and the kill line hose had a leak at the manual valve Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED.') YES X NO 24 HOUR NOTICE GIVEN ,.. YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12/94) a7wldqgf. XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,¥~-' DATE: Chairman March 16, 1999 THRU: Blair Wondzell, 4~1~~ FILE NO: P. I. Supervisor z~[~ FROM: John H Spaulding,V_~,~ SUBJECT: Petroleum Inspecf6r a7wldpgf.doc BOPE Test Nabors 28E BPX Badami B1-36 PTD 98-232 March 2, 1999' I traveled this date to witness the BOPE Test on Nabors 28E, located atBPX's Badami Field. The AOGCC BOPE Test Report is attached for reference. As noted on the inspection report two failures were observed. The bottom pipe rams had a door seal failure and we~¢' repaired, the kill line hose that attaches to the manual kill line valve had a flange leak and was repaired. These failures resulted in a rather long test time. The test went well and the rig was found to be in excellent condition. All areas around the rig were clean and orderly with good access. The BOPE Test was to 7000 psi on the components, thus the somewhat longer time for testing. SUMMARY' I witnessed the successful BOPE Test on, Nabors 28E, Badami B1-36, 2 failures, 8.5 hours. Attachment' a7wldpgf.xls Not-Confidential BP EXPLORATION, Alaska Date: 02-26-99 Trans# 90320 BADAMI LOG DATA Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 B1-36 DISK 05-Jan-99 SSN MPT/GR/EWR4/ROP Please sign ,and return one copy of this transmittal to: Scott Lavoie Petrotechnical Data Center LOG DATA AOGCC-1 blueline/1 sepia/1 disk Howard Oakland PETROFINA-1 blueline/1 sepia/1 disk Mike Engle DNR- 1 blueline/1 disk Tim Ryherd RECEIVED -',.'- -~ 0 4 1999 Alaska Oil & Gas Cons. Commission ~ohorage Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 02-19-99 Trans# 90302 BADAMI OPEN HOLE LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 ISw Name IRec Type Rec Date ICompany Code Comments ~' ~'~..- IB1-36PB1,DISK 19-Dec-981SPERRY MWD, MPT, GR, EWR4, ReP this to: Please sign and return one copy of,~_~~'~ Carla H. Mclntosh Petrotechnical Data Center LOG DATA AOGCC- 1 disk PETROFINA 1 disk DNR- 1 disk Howard Oakland Mike Engle Tim Ryherd RECEIVED '::EB 2 ?_ 1999 Gas Ccs. C0mmis~i0n Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA O~-~-AND GAS CONSERVATION COMh~;.-,CSION 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.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3859' NSL, 5186' WEL, SEC. 9, T9N, R20E, UM At top of productive interval 3588' NSL, 1151' WEL, SEC. 9, T9N, R20E, UM At effective depth 3412' NSL, 1259' EWL, SEC. 10, T9N, R20E, UM At total depth 3412' NSL, 1259' EWL, SEC. 10, T9N, R20E, UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic [~]Service 6. Datum Elevation (DF or KB) Plan KBE = 55.6' 7. Unit or Property Name Badami Unit 8. Well Number B1-36 9. Permit Number / Approval No. 98-232 399-008 10. APINumber 50-029-22933 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 14878 feet 12163 feet 14878 feet 12163 feet Length 72' 4508' 12220' 4726' Size 20" 13-3/8" 9-5/8" 7" Plugs (measured) None Junk (measured) None Cemented 260 sx Arctic Set I 3001 sx PF' E', 571 sx 'G' 440 sx Class 'G' 500 sx Class 'G' MD TVD 110' 110' 4544' 4495' 10244' 8962' 7712-12438' 6921'-10602 Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure O Ig!NAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Mike E. Miller ,...- __ Title Badami Drilling Team Leader Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Date Terrie Hubble, 564-4628 Submit In Duplicat~ Performance Enquiry Report Operator BP Exploration Date 02:46, 11 Feb 99 Page ! Formation Integrity Test for B1-36 The analysis is from - 03:00, 13 Dec 98 - to - 03:00, 13 Dec 98 Programs in Result Table: B 1-36 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Depth MDR Hole Size MDR B1-36 Event 03:00, 13 Dec 98 03:00, 13 Dec 98 0 hr 0 min Obtained required level of integrity 13.5 10277.0 8-3/4 Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 1 Date 10 February 99 Date/Time 21 Nov 98 22 Nov 98 23 Nov 98 24 Nov 98 25 Nov 98 26 Nov 98 27 Nov 98 28 Nov 98 18:00-00:00 00:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-14:30 14:30-18:00 18:00-20:00 20:00-21:00 21:00-21:30 21:30-22:30 22:30-00:45 00:45-01:45 01:45-06:00 06:00-00:30 00:30-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-06:00 06:00-13:45 13:45-15:00 15:00-16:15 16:15-17:15 17:15-18:30 18:30-21:45 21:45-06:00 06:00-12:30 12:30-13:30 13:30-06:00 06:00-09:45 09:45-12:15 12:15-15:30 15:30-18:30 18:30-20:45 20:45-00:00 00:00-01:30 01:30-01:45 01:45-02:00 02:00-02:45 02:45-03:15 03:15-06:00 06:00-14:30 14:30-14:45 14:45-17:45 17:45-18:15 18:15-18:30 18:30-19:30 19:30-20:30 20:30-21:30 Duration 6hr 6hr 1/2 hr 3-1/2 hr lhr lhr lhr 1-1/2 hr 3-1/2 hr 2hr lhr 1/2 hr lhr 2-1/4 hr lhr 4-1/4 hr 18-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 24 hr 7-3/4 hr 1-1/4 hr 1-1/4 hr lhr 1-1/4 hr 3-1/4 hr 8-1/4 hr 6-1/2 hr lhr 16-1/2 hr 3-3/4 hr 2-1/2 hr 3-1/4 hr 3 hr 2-1/4 hr 3-1/4 hr 1-1/2 hr 1/4 hr 1/4 hr 3/4 hr 1/2 hr 2-3/4 hr 8-1/2 hr 1/4 hr 3hr 1/2 hr 1/4 hr lhr lhr lhr Activity Rig moved 25.00 % Rig moved 75.00 % Rig moved 80.00 % Rig moved 95.00 % Rig moved 100.00 % Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Bell nipple Rigged up Kelly Rigged up Drillfloor / Derrick Held safety meeting Rigged up Flowline Made up BHA no. 1 Drilled cement to 110.0 ft Drilled to 280.0 ft Drilled to 1141.0 ft Serviced Other sub-surface equipment Circulated at 1141.0 ft Pulled out of hole to 817.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 1141.0 ft Drilled to 1901.0 ft Drilled to 2425.0 ft Circulated at 2425.0 ft Pulled out of hole to 369.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 2425.0 ft Drilled to 3051.0 ft Drilled to 3490.0 ft Reamed to 3490.0 ft Drilled to 4366.0 ft Drilled to 4560.0 ft Circulated at 4560.0 ft Pulled out of hole to 817.0 ft R.I.H. to 4560.0 ft Circulated at 4560.0 ft Pulled out of hole to 817.0 ft Pulled BHA Removed Drillfloor / Derrick Held safety meeting Installed Casing handling equipment Held safety meeting Ran Casing to 356.0 ft (13.325 in OD) Ran Casing to 4544.0 ft (13.325 in OD) Rigged up Cement head Circulated at 4544.0 ft Held safety meeting Pumped Water based mud spacers - volume 90.000 bbl Mixed and pumped slurry - 130.000 bbl Mixed and pumped slurry - 117.000 bbl Displaced slurry - 700.000 bbl ' _ .l Progress Report Facility Badami CPF Well B1-36 Rig Nabors 28E Page 2 Date 10 February 99 Date/Time 29 Nov 98 30 Nov 98 01 Dec 98 02 Dec 98 03 Dec 98 04 Dec 98 21:30-01:45 01:45-02:00 02:00-02:15 02:15-05:15 05:15-06:00 06:00-06:15 06:15-08:00 08:00-13:00 13:00-14:30 14:30-20:30 20:30-22:00 22:00-02:00 02:00-02:15 02:15-02:30 02:30-05:30 05:30-06:00 06:00-07:15 07:15-08:00 08:00-08:15 08:15-09:30 09:30-13:00 13:00-13:15 13:15-14:30 14:30-14:45 14:45-06:00 06:00-20:30 20:30-21:30 21:30-00:00 00:00-00:15 00:15-01:15 01:15-02:15 02:15-02:30 02:30-03:15 03:15-06:00 06:00-06:00 12:45-13:30 13:30-18:00 18:00-20:00 20:00-22:30 22:30-00:00 00:00-00:15 00:15-01:30 01:30-03:00 03:00-05:45 05:45-06:00 06:00-09:30 09:30-10:45 10:45-11:00 11:00-14:30 14:30-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-22:00 Duration 4-1/4 hr 1/4 hr 1/4 hr 3hr 3/4 hr 1/4 hr 1-3/4 hr 5hr 1-1/2 hr 6hr 1-1/2 hr 4hr 1/4 hr 1/4 hr 3hr 1/2 hr 1-1/4 hr 3/4 hr 1/4 hr 1-1/4 hr 3-1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 15-1/4 hr 14-1/2 hr lhr 2-1/2 hr 1/4 hr lhr lhr 1/4 hr 3/4 hr 2-3/4 hr 24 hr 3/4 hr 4-1/2 hr 2hr 2-1/2 hr 1-1/2 hr 1/4 hr 1-1/4 hr 1 ~ 1/2 hr 2-3/4 hr 1/4 hr 3-1/2 hr 1-1/4 hr 1/4 hr 3-1/2 hr lhr 2hr 1/2 hr 1/2 hr 3-1/2 hr Activity Circulated at 2185.0 ft Held safety meeting Pumped Water based mud spacers - volume 120.000 bbl Mixed and pumped slurry - 1030.000 bbl Displaced slurry - 329.000 bbl Displaced slurry - 329.000 bbl Rigged down Casing handling equipment Removed Bell nipple Installed Casing head Installed BOP stack Rigged up Instrument lines Tested All functions Rigged down Instrument lines Installed Wear bushing Made up BHA no. 4 R.I.H. to 2150.0 ft Drilled installed equipment - DV collar R.I.H. to 4443.0 ft Circulated at 4443.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float shoe Drilled to 4580.0 ft Circulated at 4580.0 ft Tested Casing - Via annulus and string Drilled to 5338.0 ft Drilled to 6026.0 ft Circulated at 6026.0 ft Pulled out of hole to 4544.0 ft Held safety meeting Serviced Block line R.I.H. to 6026.0 ft Drilled to 6034.0 ft Circulated at 6034.0 ft Drilled to 6130.0 ft Drilled to 7122.0 ft Circulated at 7404.0 ft Drilled to 7529.0 ft Circulated at 7529.0 ft Pulled out of hole to 1478.0 ft Serviced Draw works Pulled out of hole to 663.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 7529.0 ft Drilled to 7535.0 ft Drilled to 7560.0 ft Took MWD survey at 7532.0 ft Flow check Pulled out of hole to 663.0 ft Pulled BHA Made up BHA no. 6 Held safety meeting R.I.H. to 726.0 ft R.I.H. to 7456.0 ft Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 3 Date 10 February 99 Date/Time 22:00-22:45 22:45-06:00 05 Dec 98 06:00-06:00 06 Dec 98 06:00-06:00 07 Dec 98 06:00-19:30 19:30-20:00 20:00-22:15 22:15-23:00 23:00-23:45 23:45-06:00 08 Dec 98 06:00-19:00 19:00-22:00 22:00-22:30 22:30-22:45 22:45-01:30 09 Dec 98 01:30-04:15 04:15-05:30 05:30-06:00 06:00-07:00 07:00-10:15 10:15-10:30 10:30-12:30 12:30-13:00 13:00-14:00 14:00-14:15 14:15-15:30 15:30-16:00 16:00-17:30 17:30-21:45 21:45-22:45 22:45-00:00 10 Dec 98 00:00-00:15 00:15-01:00 01:00-01:45 01:45-04:15 04:15-05:00 05:00-05:30 05:30-06:00 06:00-08:15 08:15-09:00 09:00-12:30 12:30-13:00 13:00-13:30 13:30-16:45 16:45-17:45 17:45-18:15 18:15-19:45 19:45-22:15 22:15-02:30 11 Dec 98 02:30-05:30 05:30-06:00 06:00-15:00 15:00-15:45 15:45-19:30 Duration 3/4 hr 7-1/4 hr 24 hr 24 hr 13-1/2 hr 1/2 hr 2-1/4 hr 3/4 hr 3/4 hr 6-1/4 hr 13hr 3hr 1/2 hr 1/4 hr 2-3/4 hr 2-3/4 hr 1-1/4 hr 1/2 hr lhr 3-1/4 hr 1/4hr 2hr 1/2 hr lhr 1/4hr 1-1/4 hr 1/2 hr 1-1/2 hr 4-1/4 hr lhr 1-1/4 hr 1/4hr 3/4 hr 3/4 hr 2-1/2 hr 3/4 hr 1/2hr 1/2 hr 2-1/4 hr 3/4 hr 3-1/2 hr 1/2 hr 1/2 hr 3-1/4 hr lhr 1/2 hr 1-1/2 hr 2-1/2 hr 4-1/4 hr 3hr 1/2 hr 9hr 3/4 hr 3-3/4 hr Activity Washed to 7560.0 ft Drilled to 7658.0 ft Drilled to 8480.0 ft Drilled to 9180.0 ft Drilled to 9484.0 ft (cont...) Serviced Main engine Circulated at 9454.0 ft Pulled out of hole to 8948.0 ft R.I.H. to 9454.0 ft Drilled to 9775.0 ft Drilled to 10253.0 ft (cont...) Circulated at 10253.0 ft Pulled out of hole to 9689.0 fi R.I.H. to 10253.0 ft Circulated at 10253.0 ft Pulled out of hole to 4500.0 ft Serviced Block line Pulled out of hole to 3372.0 ft Pulled out of hole to 664.0 ft Pulled BHA Held safety meeting Serviced Top ram Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Installed Casing handling equipment Held safety meeting Installed Float shoe Ran Casing to 2829.0 ft (9-5/8in OD) Serviced Draw works Ran Casing to 3429.0 ft (9-5/8in OD) Held safety meeting Ran Casing to 4437.0 fi (9-5/8in OD) Circulated at 4437.0 ft Ran Casing to 6850.0 ft (9-5/8in OD) Circulated at 6850.0 ft Ran Casing to 6890.0 ft (9-5/8in OD) Serviced Casing Ran Casing to 8475.0 ft (9-5/8in OD) Circulated at 8475.0 fi Ran Casing to 10201.0 fi (9-5/8in OD) Circulated at 10201.0 ft Washed to 10244.0 ft Circulated at 10237.0 fi Rigged up Cement unit Mixed and pumped slurry - 90.000 bbl Displaced slurry - 748.000 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged down BOP stack Serviced Seal assembly Serviced Seal assembly (cont...) Installed Seal assembly Installed Casing head Progress Report Facility Badami CPF Well B1-36 Rig Nabors 28E Page 4 Date 10 February 99 Date/Time 19:30-23:30 23:30-00:00 12 Dec 98 00:00-00:15 00:15-04:45 04:45-05:00 05:00-06:00 06:00-07:30 07:30-12:30 12:30-14:00 14:00-15:00 15:00-16:00 16:00-18:45 18:45-21:00 21:00-23:30 23:30-00:30 13 Dec 98 00:30-01:00 01:00-02:15 02:15-03:00 03:00-06:00 06:00-11:15 11:15-06:00 14 Dec 98 06:00-13:45 13:45-15:45 15:45-16:30 16:30-16:45 16:45-17:00 17:00-17:15 17:15-18:00 18:00-22:15 22:15-22:30 22:30-23:30 23:30-00:00 15 Dec 98 00:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-08:45 08:45-09:15 09:15-10:30 10:30-12:30 12:30-18:00 18:00-18:30 18:30-06:00 16 Dec 98 06:00-06:00 17 Dec 98 06:00-06:00 18 Dec 98 06:00-13:00 13:00-14:00 14:00-01:00 19 Dec 98 01:00-03:00 03:00-05:15 05:15-05:30 05:30-06:00 06:00-07:30 07:30-07:45 Duration 4hr 1/2 hr 1/4 hr 4-1/2 hr 1/4 hr lhr 1-1/2 hr 5hr 1-1/2 hr lhr lhr 2-3/4 hr 2-1/4 hr 2-1/2 hr lhr 1/2 hr 1-1/4 hr 3/4 hr 3hr 5-1/4 hr 18-3/4 hr 7-3/4 hr 2hr 3/4 hr 1/4 hr 1/4hr 1/4 hr 3/4 hr 4-1/4 hr 1/4 hr 1 hr 1/2 hr 6hr 1/4 hr 1/4 hr lhr 1-1/4 hr 1/2 hr 1-1/4 hr 2hr 5-1/2 hr 1/2 hr 11-1/2 hr 24 hr 24 hr 7hr lhr llhr 2hr 2-1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1/4 hr Activity Installed BOP stack Held safety meeting Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 6 Made up BHA no. 6 R.I.H. to 9953.0 ft Circulated at 9953.0 ft Washed to 10157.0 ft Circulated at 10157.0 ft Tested Casing - Via annulus and string Held drill (Kick (well kill)) Drilled installed equipment - Float collar Drilled installed equipment - Float shoe Drilled to 10277.0 ft Circulated at 10277.0 ft Performed formation integrity test Circulated at 10233.0 ft Circulated at 10233.0 ft Drilled to 10812.0 ft Drilled to 11094.0 ft Circulated at 11094.0 ft Pulled out of hole to 10226.0 ft Flow check Pulled out of hole to 9756.0 ft Flow check R.I.H. to 11085.0 ft Circulated at 11085.0 ft Flow check Pulled out of hole to 10223.0 ft Flow check Pulled out of hole to 2350.0 ft Pulled out of hole to 658.0 ft Flow check Pulled BHA Downloaded MWD tool Pulled BHA Made up BHA no. 8 Serviced LWD tool R.I.H. to 11084.0 ft Functioned downhole tools at 11084.0 ft Drilled to 11245.0 ft Drilled to 11484.0 ft Drilled to 11725.0 ft Drilled to 11800.0 ft Circulated at 11800.0 ft Drilled to 11872.0 ft Drilled to 11876.0 ft Circulated at 11845.0 ft Flow check Pulled out of hole to 11650.0 ft Pulled out of hole to 10150.0 ft Held safety meeting Progress Report Facility Badami CPF Well B1-36 Rig Nabors 28E Page 5 Date 10 February 99 Date/Time 07:45-08:45 08:45-09:00 09:00-13:00 13:00-13:30 13:30-15:15 15:15-16:15 16:15-16:45 16:45-21:00 21:00-21:15 21:15-23:00 23:00-00:00 20 Dec 98 00:00-03:15 03:15-04:00 04:00-04:45 04:45-05:15 05:15-06:00 06:00-06:30 06:30-06:45 06:45-07:45 07:45-08:30 08:30-10:00 10:00-10:15 10:15-14:00 14:00-14:15 14:15-14:45 14:45-15:45 15:45-19:15 19:15-20:00 20:00-21:00 21:00-21:30 21:30-22:30 22:30-00:00 21 Dec 98 00:00-02:00 02:00-02:30 02:30-02:45 02:45-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-09:30 09:30-10:00 10:00-11:30 11:30-14:30 14:30-14:45 14:45-19:00 19:00-20:15 20:15-20:45 20:45-22:00 22:00-06:00 22 Dec 98 06:00-03:45 23 Dec 98 03:45-04:00 04:00-06:00 06:00-09:30 09:30-10:00 Duration lhr 1/4 hr 4hr 1/2 hr 1-3/4 hr lhr 1/2 hr 4-1/4 hr 1/4hr 1-3/4 hr 1 hr 3-1/4 hr 3/4 hr 3/4 hr 1/2 hr 3/4 hr 1/2 hr 1/4 hr lhr 3/4 hr 1-1/2 hr 1/4 hr 3-3/4 hr 1/4 hr 1/2 hr lhr 3-1/2 hr 3/4 hr lhr 1/2 hr lhr 1-1/2 hr 2hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1/2hr 1-1/2 hr 3hr 1/4 hr 4-1/4 hr 1-1/4 hr 1/2 hr 1-1/4 hr 8 hr 21-3/4 hr 1/4 hr 2hr 3-1/2 hr 1/2 hr Activity Serviced Block line Circulated at 10150.0 ft Pulled out of hole to 653.0 ft Flow check Pulled BHA Serviced SCR Installed BOP test plug assembly Tested BOP stack Installed Wear bushing Made up BHA no. 9 Repaired Iron roughneck R.I.H. to 8472.0 ft Circulated at 8472.0 ft R.I.H. to 10240.0 ft Circulated at 10240.0 ft R.I.H. to 11750.0 ft R.I.H. to 11792.0 ft Reamed to 11867.0 fl Circulated at 11867.0 ft Reamed to 11869.0 ft Pulled out of hole to 10150.0 ft Flow check Pulled out of hole to 586.0 ft Flow check Pulled BHA Made up BHA no. 10 R.I.H. to 8473.0 ft Circulated at 8473.0 ft R.I.H. to 10231.0 fl Circulated at 10231.0 ft R.I.H. to 11828.0 fl Reamed to 11872.0 ft Milled Other sub-surface equipment at 11873.0 fl Circulated at 11873.0 ft Flow check Pulled out of hole to 10231.0 fl Circulated at 10231.0 ft Pulled out of hole to 6000.0 fl Pulled out of hole to 626.0 ft Pulled BHA Serviced Wear bushing Flow check Made up BHA no. 11 Tested MWD - Via string R.I.H. to 10248.0 fl Circulated at 10248.0 ft R.I.H. to 11717.0 ft Circulated at 11717.0 ft Drilled to 11722.0 ft Drilled to 11736.0 fl Flow check Drilled to 11750.0 fl Drilled to 11775.0 fl Circulated at 11775.0 ft Progress Report Facility Badami CPF Well B 1-36 Page 6 Rig Nabors 28E Date 10 February 99 Date/Time 24 Dec 98 25 Dec 98 26 Dec 98 27 Dec 98 28 Dec 98 10:00-11:30 11:30-12:30 12:30-16:30 16:30-16:45 16:45-18:00 18:00-21:00 21:00-22:45 22:45-23:15 23:15-02:15 02:15-03:00 03:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:15 06:15-06:00 06:00-09:30 09:30-10:30 10:30-10:45 10:45-12:30 12:30-13:00 13:00-17:00 17:00-18:00 18:00-18:45 18:45-19:15 19:15-19:30 19:30-23:00 23:00-01:30 01:30-06:00 06:00-06:15 06:15-07:30 07:30-08:15 08:15-08:30 08:30-09:00 09:00-10:30 10:30-11:15 11:15-13:00 13:00-13:15 13:15-14:45 14:45-16:00 16:00-06:00 06:00-18:30 18:30-00:00 00:00-01:00 01:00-01:15 01:15-03:00 03:00-03:30 03:30-06:00 06:00-07:00 07:00-08:00 08:00-10:15 10:15-10:45 Duration 1-1/2 hr lhr 4hr 1/4 hr 1-1/4 hr 3hr 1-3/4 hr 1/2 hr 3 hr 3/4 hr 1/2 hr 1/2 hr 1 hr 1 hr 1/4 hr 23-3/4 hr 3-1/2 hr lhr 1/4 hr 1-3/4 hr 1/2 hr 4hr lhr 3/4 hr 1/2 hr 1/4 hr 3-1/2 hr 2-1/2 hr 4-1/2 hr 1/4 hr 1-1/4 hr 3/4 hr 1/4 hr 1/2 hr 1-1/2 hr 3/4 hr 1-3/4 hr 1/4 hr 1-1/2 hr 1-1/4 hr 14hr 12-1/2 hr 5-1/2 hr lhr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr lhr lhr 2-1/4 hr 1/2 hr Activity Pulled out of hole to 10190.0 ft Serviced Block line Pulled out of hole to 626.0 ft Flow check Pulled BHA Made up BHA no. 12 R.I.H. to 3515.0 ft Serviced Drillfloor / Derrick R.I.H. to 10183.0 ft Circulated at 10248.0 ft R.I.H. to 11090.0 ft Functioned M.W.D. tool R.I.H. to 11687.0 ft R.I.H. to 11717.0 ft R.I.H. to 11775.0 ft Drilled to 11982.0 ft Drilled to 11990.0 ft Circulated at 11960.0 ft Flow check Pulled out of hole to 10190.0 ft Flow check Pulled out of hole to 652.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Installed BOP test plug assembly Tested BOP stack Made up BHA no. 13 R.I.H. to 9800.0 ft R.I.H. to 10261.0 ft Circulated at 10305.0 ft R.I.H. to 10972.0 ft Took MWD survey at 10972.0 ft R.I.H. to 11500.0 ft Reamed to 11590.0 ft R.I.H. to 11715.0 ft Circulated at 11715.0 ft R.I.H. to 11730.0 ft Logged hole with LWD: Formation evaluation (FE) from 11720.0 ft to 11922.0 ft Logged hole with LWD: Formation evaluation (FE) from 11922.0 ft to 11990.0 ft Drilled to 12060.0 ft Drilled to 12140.0 ft Drilled to 12185.0 ft Circulated at 12185.0 ft Flow check Pulled out of hole to 10244.0 fi Flow check Pulled out of hole to 4250.0 ft Pulled out of hole to 663.0 ft Pulled BHA Serviced Drilling tool / logs Pulled BHA Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 7 Date 10 February 99 Date/Time 10:45-12:00 12:00-16:45 16:45-17:30 17:30-18:15 18:15-19:00 19:00-19:30 19:30-20:45 20:45-06:00 29 Dec 98 06:00-11:00 11:00-12:30 12:30-13:45 13:45-15:45 15:45-17:00 17:00-20:30 20:30-21:15 21:15-22:15 22:15-00:15 30 Dec 98 00:15-02:00 02:00-02:30 02:30-02:45 02:45-03:15 03:15-03:45 03:45-06:00 06:00-09:15 09:15-09:45 09:45-10:45 10:45-11:30 11:30-12:30 12:30-13:15 13:15-14:45 14:45-15:15 15:15-16:30 16:30-06:00 31 Dec 98 06:00-11:00 11:00-13:30 13:30-14:00 14:00-15:30 15:30-16:30 16:30-22:00 22:00-00:00 01 Jan 99 00:00-06:00 06:00-14:30 14:30-16:00 16:00-17:00 17:00-17:45 17:45-06:00 02 Jan 99 06:00-20:00 20:00-22:15 22:15-22:30 22:30-01:30 03 Jan 99 01:30-04:00 04:00-04:30 04:30-06:00 06:00-09:15 Duration 1-1/4 hr 4-3/4 hr 3/4 hr 3/4 hr 3/4 hr 1/2 hr 1-1/4 hr 9-1/4 hr 5hr 1-1/2 hr 1-1/4 hr 2hr 1-1/4 hr 3-1/2 hr 3/4 hr lhr 2hr 1-3/4 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr 2-1/4 hr 3-1/4 hr 1/2 hr lhr 3/4 hr lhr 3/4 hr 1-1/2 hr 1/2 hr 1-1/4 hr 13-1/2 hr 5hr 2-1/2 hr 1/2 hr 1-1/2 hr 1 hr 5-1/2 hr 2hr 6hr 8-1/2 hr 1-1/2 hr lhr 3/4 hr 12-1/4 hr 14 hr 2-1/4 hr 1/4 hr 3hr 2-1/2 hr 1/2 hr 1-1/2 hr 3-1/4 hr Activity Made up BHA no. 14 R.I.H. to 10270.0 ft Circulated at 10270.0 ft Serviced Block line R.I.H. to 11681.0 ft Set tool face R.I.H. to 12185.0 ft Drilled to 12425.0 ft Drilled to 12480.0 ft Circulated at 12480.0 ft Pulled out of hole to 11493.0 ft Circulated at 11493.0 ft Pulled out of hole to 10272.0 ft Pulled out of hole to 663.0 ft Pulled BHA Serviced Drilling tool / logs Made up BHA no. 15 Serviced SCR Pulled BHA Functioned Drilling tool / logs Made up BHA no. 15 R.I.H. to 2500.0 ft R.I.H. to 3850.0 ft R.I.H. to 10270.0 ft Circulated at 10270.0 ft Serviced SCR R.I.H. to 11227.0 ft Serviced SCR R.I.H. to 11697.0 ft Took MWD survey at 11767.0 ft R.I.H. to 12386.0 ft Reamed to 12480.0 ft Drilled to 12771.0 ft Drilled to 12970.0 ft Circulated at 12970.0 ft Serviced Rotary table Pulled out of hole to 12418.0 ft R.I.H. to 12970.0 ft Drilled to 13179.0 ft Circulated at 13179.0 ft Drilled to 13420.0 ft Drilled to 13743.0 ft Circulated at 13743.0 ft Pulled out of hole to 12723.0 ft R.I.H. to 13743.0 ft Drilled to 14041.0 ft Drilled to 14400.0 ft Circulated at 14400.0 ft Flow check Pulled out of hole to 10216.0 ft Rigged up Block line Circulated at 10216.0 ft Rigged up Block line Serviced Block line Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 8 Date 10 February 99 Date/Time 09:15-09:30 09:30-12:15 12:15-13:30 13:30-14:00 14:00-18:30 18:30-19:00 19:00-00:00 04 Jan 99 00:00-00:15 00:15-02:45 02:45-03:45 03:45-05:45 05:45-06:00 06:00-07:00 07:00-12:00 12:00-13:30 13:30-14:30 14:30-16:00 16:00-17:00 17:00-19:45 19:45-20:15 20:15-00:30 05 Jan 99 00:30-01:00 01:00-02:30 02:30-03:30 03:30-05:30 05:30-06:00 06:00-08:30 08:30-11:00 11:00-17:30 17:30-18:00 18:00-18:45 18:45-19:00 19:00-19:45 19:45-20:00 20:00-22:30 22:30-22:45 22:45-02:30 06 Jan 99 02:30-03:45 03:45-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-07:45 07:45-08:00 08:00-08:15 08:15-08:45 08:45-09:15 09:15-12:00 12:00-12:30 12:30-18:30 18:30-19:30 19:30-20:30 20:30-00:45 07 Jan 99 00:45-01:45 Duration 1/4 hr 2-3/4 hr 1-1/4 hr 1/2 hr 4-1/2 hr 1/2 hr 5hr 1/4 hr 2-1/2 hr lhr 2hr 1/4 hr lhr 5hr 1-1/2 hr 1 hr 1-1/2 hr lhr 2-3/4 hr 1/2 hr 4-1/4 hr 1/2 hr 1-1/2 hr lhr 2hr 1/2 hr 2-1/2 hr 2-1/2 hr 6-1/2 hr 1/2 hr 3/4 hr 1/4 hr 3/4 hr 1/4 hr 2-1/2 hr 1/4 hr 3-3/4 hr 1-1/4 hr 3/4 hr lhr 1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 2-3/4 hr 1/2 hr 6hr 1 hr lhr 4-1/4 hr lhr Activity Circulated at 10216.0 ft R.I.H. to 14355.0 ft Washed to 14400.0 ft Took MWD survey at 14400.0 ft Drilled to 14477.0 ft Took MWD survey at 14477.0 ft Drilled to 14570.0 ft Serviced Mud shakers Drilled to 14651.0 ft Took MWD survey at 14651.0 ft Drilled to 14695.0 ft Circulated at 14695.0 ft Circulated at 14695.0 ft Drilled to 14780.0 ft Circulated at 14750.0 ft Pumped out of hole to 14390.0 ft Circulated at 14390.0 ft Pulled out of hole to 13670.0 ft Circulated at 13670.0 ft R.I.H. to 14390.0 ft Reamed to 14780.0 ft Drilled to 14797.0 ft Circulated at 14797.0 ft Pulled out of hole to 14171.0 ft Circulated at 14797.0 ft Pulled out of hole to 14200.0 ft Pulled out of hole to 10220.0 ft R.I.H. to 14797.0 ft Circulated at 14797.0 ft R.I.H. to 14797.0 ft Circulated at 14797.0 ft Flow check Pulled out of hole to 13785.0 ft Flow check Pulled out of hole to 10244.0 ft Flow check Pulled out of hole to 679.0 ft Pulled BHA Serviced Drilling tool / logs Pulled BHA Serviced Top ram Serviced Top ram Removed Wear bushing Tested Top ram Retrieved Wear bushing Rigged up Casing handling equipment Held safety meeting Ran Liner to 1067.0 ft (7in OD) Held safety meeting Ran Casing to 4727.0 ft (7in OD) Installed Other sub-surface equipment Circulated at 4709.0 ft Ran Liner to 10244.0 ft (7in OD) Circulated at 10244.0 ft Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 9 Date 10 February 99 Date/Time 01:45-03:30 03:30-06:00 06:00-13:30 13:30-14:00 14:00-02:00 08 Jan 99 02:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:45 08:45-09:15 09:15-09:45 09:45-10:45 10:45-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-18:00 18:00-19:00 19:00-19:30 19:30-19:45 19:45-20:00 20:00-23:00 23:00-05:30 09 Jan 99 05:30-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-15:30 15:30-15:45 15:45-02:00 10 Jan 99 02:00-02:30 02:30-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-12:45 12:45-14:30 14:30-16:15 16:15-17:00 17:00-17:15 17:15-17:45 17:45-19:00 19:00-19:30 19:30-21:00 21:00-21:30 21:30-22:30 22:30-01:00 11 Jan 99 01:00-02:45 Duration 1-3/4 hr 2-1/2 hr 7-1/2 hr 1/2 hr 12hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 1-1/4 hr 1/2 hr 1/2 hr 1 hr 1-1/4 hr 1/2hr 4hr lhr 1/2 hr 1 hr 1/2 hr 1/4 hr 1/4 hr 3 hr 6-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 5hr 1/4 hr 10-1/4 hr 1/2 hr 3-1/2 hr 4 hr lhr 1 hr 3/4 hr 1-3/4 hr 1-3/4 hr 3/4 hr 1/4 hr 1/2 hr 1-1/4 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 2-1/2 hr 1-3/4 hr Activity Ran Liner to 12438.0 ft (7in OD) Worked stuck pipe at 12438.0 ft Worked stuck pipe at 12438.0 ft Circulated at 12438.0 ft Worked stuck pipe at 12438.0 ft Circulated at 12438.0 ft Held safety meeting Rigged up Cement head Pumped Water based mud spacers - volume 50.000 bbl Mixed and pumped slurry - 102.000 bbl Displaced slurry - 305.000 bbl Circulated at 7711.0 ft Rigged down Cement unit Pumped out of hole to 7150.0 ft Serviced Block line Laid down 7030.0 ft of 5in OD drill pipe Held safety meeting Laid down 3900.0 ft of Drillpipe Retrieved Setting tools R.I.H. to 550.0 ft Pulled BHA Removed Drillfloor / Derrick Serviced Wear bushing running tool Installed Well control Installed BOP stack Tested BOP stack Serviced Bell nipple Serviced Bell nipple Serviced Surface lines Tested Casing Rigged down Drillfloor / Derrick Bleed down well Held safety meeting Made up BHA no. 16 Tested MWD/LWD - Via string R.I.H. to 12226.0 ft Laid down 188.0 ft of 5in OD drill pipe Drilled cement to 12226.0 ft Drilled cement to 12348.0 ft Tested Liner - Via annulus and string Drilled cement to 12352.0 ft Held drill (Kick (well kill)) Drilled installed equipment - Float shoe Circulated at 12439.0 ft Held safety meeting Tested Liner - Via annulus and string Laid down 153.0 ft of 5in OD drill pipe R.I.H. to 14683.0 ft Reamed to 14756.0 ft Circulated at 14756.0 ft Reamed to 14797.0 ft Drilled to 14819.0 ft Pumped out of hole to 14527.0 ft Reamed to 14785.0 ft Progress Report Facility Badami CPF Well B 1-36 Rig Nabors 28E Page 10 Date 10 February 99 Date]Time 12 Jan 99 13 Jan 99 14 Jan 99 02:45-03:30 03:30-05:15 05:15-06:00 06:00-06:15 06:15-08:30 08:30-08:45 08:45-09:45 09:45-10:15 10:15-12:15 12:15-19:00 19:00-19:30 19:30-21:00 21:00-22:00 22:00-00:00 00:00-02:30 02:30-04:00 04:00-06:00 06:00-12:30 12:30-13:45 13:45-14:30 14:30-16:15 16:15-16:30 16:30-17:15 17:15-18:15 18:15-19:00 19:00-04:00 04:00-06:00 06:00-07:15 07:15-07:30 07:30-08:30 08:30-09:00 09:00-09:30 09:30-09:45 09:45-10:00 10:00-12:00 12:00-12:30 12:30-16:30 16:30-17:30 17:30-21:30 21:30-22:30 22:30-01:30 01:30-01:45 01:45-02:30 02:30-02:45 02:45-03:45 03:45-04:30 04:30-06:00 06:00-08:00 08:00-08:15 08:15-09:00 09:00-10:00 10:00-12:30 12:30-13:00 13:00-13:30 Duration 3/4 hr 1-3/4 hr 3/4 hr 1/4 hr 2-1/4 hr 1/4 hr lhr 1/2 hr 2 hr 6-3/4 hr 1/2 hr 1-1/2 hr lhr 2hr 2-1/2 hr 1-1/2 hr 2hr 6-1/2 hr 1-1/4 hr 3/4 hr 1-3/4 hr 1/4 hr 3/4 hr 1 hr 3/4 hr 9hr 2 hr 1-1/4 hr 1/4 hr 1 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 2hr 1/2 hr 4hr lhr 4hr lhr 3hr 1/4 hr 3/4 hr 1/4 hr lhr 3/4 hr 1-1/2 hr 2hr 1/4 hr 3/4 hr lhr 2-1/2 hr 1/2 hr 1/2 hr Activity Worked toolstring at 14795.0 ft Circulated at 14756.0 ft Pulled out of hole to 14021.0 ft Pulled out of hole to 14089.0 ft Circulated at 14057.0 ft R.I.H. to 14124.0 ft Reamed to 14215.0 ft R.I.H. to 14714.0 ft Washed to 14787.0 ft Circulated at 14621.0 ft R.I.H. to 14787.0 ft Worked toolstring at 14787.0 ft Washed to 14815.0 ft Worked toolstring at 14787.0 ft Circulated at 14819.0 ft Washed to 14819.0 ft Drilled to 14840.0 ft Drilled to 14878.0 ft Circulated at 14878.0 ft Flow check Pulled out of hole to 12340.0 ft Flow check Circulated at 12340.0 ft Pulled out of hole to 11178.0 ft Circulated at 11178.0 ft Pumped out of hole to 600.0 ft Pulled BHA Downloaded MWD tool Pulled BHA Pulled BHA R.I.H. to 460.0 ft Laid down 460.0 ft of 4in OD drill pipe Removed Bore protector Installed Bore protector Ran Drillpipe in stands to 2000.0 ft Held safety meeting Ran Drillpipe in stands to 6000.0 ft Ran Drillpipe to 682.0 ft (4in OD) Ran Drillpipe in stands to 12438.0 ft Serviced Block line Ran Drillpipe in stands to 14779.0 ft Held safety meeting Batch mixed slurry - 23.000 bbl Mixed and pumped slurry - 23.000 bbl Displaced slurry - 193.000 bbl Pulled Drillpipe in stands to 13960.0 ft Circulated at 13960.0 ft Circulated at 13934.0 ft Mixed and pumped slurry - 36.000 bbl Displaced slurry - 177.000 bbl Pulled Drillpipe in stands to 12525.0 ft Circulated at 12525.0 ft Held safety meeting Mixed and pumped slurry - 22.000 bbl Progress Report Facility Badami CPF Well B1-36 Rig Nabors 28E Page 11 Date 10 February 99 Date/Time 15 Jan 99 13:30-14:00 14:00-14:45 14:45-17:30 17:30-18:00 18:00-19:45 19:45-03:30 03:30-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-09:15 09:15-10:30 10:30-11:00 11:00-14:00 14:00-15:00 15:00-16:00 16:00-18:30 18:30-20:00 Duration 1/2 hr 3/4 hr 2-3/4 hr 1/2 hr 1-3/4 hr 7-3/4 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr lhr lhr 1/4 hr 1-1/4 hr 1/2 hr 3hr lhr lhr 2-1/2 hr 1-1/2 hr Activity Displaced slurry - 145.000 bbl Pulled Drillpipe in stands to 11588.0 ft Circulated at 11588.0 ft Rigged down Kelly Pulled Drillpipe in stands to 6643.0 ft Laid down 4956.0 ft of 4in OD drill pipe Ran Drillpipe in stands.to 2004.0 ft Fill pits with Water Circulated at 2004.0 ft Circulated at 2004.0 ft Freeze protect well - 125.000 bbl of Diesel Held 1000.0 psi pressure on 6.000 bbl squeezed cement Pulled Drillpipe in stands to 2004.0 ft Retrieved B ore protector Installed Hanger plug Held safety meeting Removed BOP stack Removed Hanger plug Installed Hanger plug Held 2000.0 psi pressure on 9.000 bbl squeezed cement Removed BOP stack Exploration'/Arco Alaska Date: To: At, n: Reference: From: January 13, 1998 Alaska Oil & Gas Conservation Commission Blair Wondzell Badami Well, B1-36 Permit #98-232 APl #50-029-22933 Mike Miller Badami Drilling Team Leader Blair: The attached Application for Sundry Approval requests an Operations Shutdown. The rig currently drilling well B1-36 is scheduled to move to an Exploration well. Due to time constraints, B1-36 operations will be shutdown temporarily. The rig will return to complete operations on the well in April 1999. Thank you. Attachments Cc: Well File RECEIVED JAN 1999 A!~.ska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Alter Casing [] Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc, 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Suspend [] Plugging [] Repair Well [] Pull Tubing [~Operation Shutdown E~] Re-Enter Suspended Well .'~ 5. Type of well: [] Development [] Exploratory [] Stratigraphic rlService 4. Location of well at surface 3859' NSL, 5186' WEL, SEC. 9, T9N, R20E, UM At top of productive interval 1574' SNL, 822' WEL, SEC. 9, TgN, R20E, UM (Planned) At effective depth N/A At total depth 3412' NSL, 1251' EWL, SE.~. 10, _T_~N.._,_.R~_2_0E, UM 12, Present well condition summary Total depth: measured 14878 feet true vertical 12165 feet Effective depth: measured 14878 feet true vertical 12165 feet [] Time Extension [] Perforate ~ Variance [] Other Itimulate 6. Datum Elevatloff (DF or KB) Plan KBE = 55.6' 7. Unit or Property Name Badaml Unit 8. Well Number B1-36 9. Permit Number ~. 98~2~2 Plugs (measured) None Junk (measured) None !10. APl Number 50-029-22933 .11. Field and Pool Badami Casing Length Size Structural Conductor Surface intermediate Production Liner 72' 20" 4508' 13-3/8" 12220' 9-5/8" 4726' 7" Cemented MD TVD 260 sx Arctic Set I 3001 sx PF' E', 571 sx 'G' 440 sx Class 'G' 50O sx Class 'G' 110' 110' 4544' 4494' 10244' 8940' 7712-12438' 10602 Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A RECEIVED JAN !3 1999 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4, Estimated date for commencing operation January 12, 1999 16. If proposal was verbally approved Blair Wondzell ~ Name of approver contact Engfneer Name/Number: Mike E. Miller, 564-5066 1/12/99 Date approved 15, Status of well classifications as: [] Oil [] Gas [~ Suspended Service Prepared By Name/Number:. Carol Withey, 564-4114 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Mike E, Miller Title Badami Drilling Team Leader Commission Use Only I Approval No..~??-- g~ Conditions of Approval: Notify Commissi~qn so representative may witness Plug integrity v' BOP Test Location clearance Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission :orm 10-403 Rev. 06/15/88 ORIGINAL SIGNED-BY I~obort N ~hri~ten.~nn Commissioner Date ~/'~/9~ Submit tn Triplicate Approved Copy Retur, ned Badami B1-36 Plan for Operational Shutdown version: 2030 hrs 1/12/99 activities from 1400 hrs 1/12/99: · 2. 3. 4. ! 6. 7. 8. 9. 10. 11. 12. 13. 14. POH, LD BHA. RIH wt 4" open-ended drill pipe to 14797 (8-3/4" hole TD).. Establish circulation. Place a 23 bbl 15.8 ppg cement plug from 14878 - 14628' (est. after squeeze in step 6). POOH in stands to 13,960. Close annular, pressure up too 500 psi (to block squeeze as per AOGCC). Place a 36 bbl 15.8 ppg cement plug from 13960-13640' md. Pull up to 12,538'md. Place a 22 bbl 15.8 ppg cement plug from 12538 - 12238' md. Pressure test cement plug to 1000 psi for 15 minutes- record. Install tubing hanger and BPV. ND BOP. Freeze protect annulus. Release rig (clean pits, etc.), Badarni B1-36 Operation shutdown Procedure 1 1112/98 Badaml B1-36 base permafrost- 1950' top 7" liner - 7712' md 13-3/8" 68# L-80 BTC 4544' md 9-5/8' 40 # L-80 BTC 10244' md actual Badami Sands 10293-12300' md cement 7", 29# Pl10 BTC - actual 12438' md Killian Sand - 13740- 13860' md Put River Sand 14728- 8-3/4' hole TD = 14797' md Kekiktuk Sands 14803 - TD 6" open hole - 14878 'md. 12238 12538 13640 13960 j14628 Abandonment Plugs: Badami B1-36 Operation shutdown Procedure 2 1/12/98 ~ 11 ~99 09:0~ BPX E~DI~©T¥ ~E~P To: Mr. Wondzell AOGCC From: Mike Miller BP Exploration Date: January 11, 1999 Subject: Badami B1-36 - 7" liner stuck off bottom Mr. Wondzell: As per our telephone conversation on January 8, 1999, the following is the status of B1- 36, Badami 7" liner: The well was drilled to 14797' md with 9-518" intermediate casing set at 10244' md. The objective, as described in the Drilling Permit, was to run a 7" liner to TD, During running of the liner, the liner became stuck at 12438' md. This is just below the base of the Badami sands. Attempts at moving the liner were unsuccessful. The liner was cemented in place on 1/8/99. The liner was pressure tested successfully to 3500 psi and the floats were drilled out. An FIT to 14.0 ppg was performed with the hole cleaned 20' below the shoe. Plans are for drilling to proceed as per permitted plan: continue to drill the Kekiktuk formation and complete the well. Should any further changes occur, I will contact you as usual. Yo , Mike Miller DEC 17 '9~ 10:09RM BPX EMDICOTT DEVP BP EXPLORATION BPExplorafion(Alaska),lnc. FAX MESSAGE EN~ - Endicott ISusino~s Unit 9~0 F_ Ben,on I~lvd. P.o. Box ~06612, M~-I An~omge, Al~ka 9951~612 De~mem Fe~: (~ Ce~l ~ (~ S64~441 Team: Eastern North Slope--Endicott Asset Group Date: i2 I I~,[=~$ Tel: ~-b ~- b~b(~ (~ Fax No: 1-(907)-564-5200 Pages to Follow: ~. ,URGENT ORDINARY CONFIDENTIAL Company: A...o~ cc_ Dept; Fax No: ~.-~ Tel; Copy To: Ot[c 1 7 t )98 0il & Gas Cons, Commission Badami B1--36 Gravel Pack Water Sand Procedure Scope Dec. 16, 1998 Goal' possible completion of B1-36 as a water source well for water injection for pressure maintenance in the Badami sands, If the Kekiktuk is oil or water productive it may be completed as a oil or water producer through a cemented 4-1/2" liner. If the Kekiktuk is deemed unproductive at this time, it may be abandoned by downsqueezing a 6" hole volume of cement below a retainer, and completing the well as a shallow water source well at 3000'. This is the scope for the completion as a water source well. . . . If the Kekiktuk is to be abandoned: Set an E7 drill cement retainer 75' inside 7" casing shoe and pump a 6" open hole volume of cement below the retainer and 50' of cement on top of retainer, If the Kekiktuk may be produced at a later date, run 4-1/2" liner and liner-top packer and cement entire length of liner. Pressure test liner to 3000 psi. Set a bridge plug in the 7" liner 50' above top of 4-1/2' liner. Down squeeze cement followed by diesel down the 9-5/8" x 13-3/8" casing annulus. Cement to be placed from the 13-3/8" shoe to 2000', diesel from 2000' to surface. 4. Perforate the water sand interval 3000' to 3200'. 5, Run 4-1/2" tubing and gravel pack completion. OEC l ? t998 DEC 17 "98 10~1B~1"1 SPX ENDICOTT SEVP'~ P.3/3 base permafrost- 1950' TOO 2000' 2700' water sand interval perfs:3000-3200' 3400' 13-3/8"68# L-80 BTC 4544' md mud Cement downsqueezed, displaced with diesel 9-5/8" 40 # L-80 BTC 10244' md actual Badami Sands EZ Drill Bridge Plug Kekiktuk Sands 7", 29# Plt0 BTC - est, 15449' md Kekiktuk will either be abandoned or a liner will be run and cemented. open hole - est. 16052' md. TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ,ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 18. 1998 Mike Millcr Badami Drilling Team Leader BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Badami Unit B 1-36 BP Exploration (Alaska) Inc. Permit No: 98-232 Sur Loc: 3859'NSL. 5186'WEL. Sec. 09. T09N. R20E. UM Btmholc Loc. 2047'SNL. 1948'EWL. Sec. 10, T09N. R20E. UM Dear Mr. Miller: Enclosed is thc approved application for permit to drill thc above refercnced well. The permit to drill does not exempt you from obtaining additional permits requircd by law from othcr governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dcterminations arc made. Your request for a divcrter waiver is approved. Thc blowout prcvention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical intcgrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 A~&C 25.030(g)(3). Sufficicnt notice (approximatcly 24 hours) of thc MI test bcforc operation, and of thc BOPE tcst performed before drilling below thc surface casing shoe. must be givcn so that a rcprcscntative of thc Commission may witness thc tests. Notice may be given by contacting the Commission petroleum field inspcctor on thc North Slope pager at 659-3607. Chairman "~-.__..~ BY ORDER OF THE COMMISSION dlffEnclosures CC: Dcpamnent of Fish &Gamc. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA>~,-AND GAS CONSERVATION COrw.~,:lSSlON PERMIT TO DRILL 20 AAC 25.005 - la. Type of work [] Drill I-1Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas l'-ISingle Zone [] Multiple Zone 2'i'"' Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 55.6' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365533 '"" 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3859' NSL, 5186' WEL, SEC. 9, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 1574' SNL, 822' WEL, SEC. 9, T9N, R20E, UM B1-36 At total depth i9. Approximate spud date Amount $200,000.00 2047' SNL, 1948' EWL, SEC. 10, T9N, R20E, UM 11/18/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 365535, 3233'I B1-28, 58.61' @ 1196' MD 5120 16052' MD / 12656' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6024' MD Maximum Hole Angle 60° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 16" 13-3/8" 68# L-80 BTC 4544' 35' 35' 4579' 4555' 3850 sx PF 'E', 480 sx Class 'G' 12-1/4" 9-5/8" 40# L-80 BTC 10451' 33' 33' 10484' 8955' 410 sx Class 'G' 8-1/2" 7" 29# Pl10 BTC-Mod 15418' 31' 31' 15449' 12256' 850 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 753' 15299' 12161' 16052' 12655' 90 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production ORIGINAL "? Liner ~'~ ~; ~ ~ !~; !~ Perforation depth: measured ~'~["'~ '~Jl ~ ~' true vertical Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mike Cook, 564-5390 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~r'~ Mike E. Mill Title Badami Drilling Team Leader Date t t Commission Use Only Permit Number I APl Number Approval Date I See cover letter C~ ~ - ~ ~,~I 50- 0 ~ o~ -- ,~.~ O~ .~ 3 //-/~ ~ ~I for other requirements Conditions of Approval: Samples Required E~Yes [~No Mud Log Required []Yes [~No Hydrogen Sulfide Measures []Yes [~No Directional Survey Required ,[~.Yes [-I~ Required Working Pressure for BOPE FI2K; 1--13K; []4K; []5K; [-I10K; I--I15K ~ Other: Original Signed By by order of Approved By OavJd W. Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: Mike Cook I Well Name: I B1-36 Type of Well (producer or injector): Well Plan Summary 564-5390 I lnject°r I Surface Location: 3859' FSL 5186' FEL SEC 9, T9N, R20E, UM, AK Badami Sand F5 Primary target Kekiktuk Primary Target Bottom Hole Location (TD) 1574'FNL 822' FEL SEC 9, T9N, R20E, UM, AK 2059' FNL 1499' FWL SEC 10, T9N, R20E, UM, AK 2047' FNL 1948' FWL SEC 10, T9N, R20E, UM AK AFE Number: 1880461 KBE: 155.6 I 28E J I Spud Date' I11/18/98 I I Design: I Big Bore Injector I Formation Tops MD TVD (bkb) Remarks base permafrost 2025 2005 Top Middle Brookian (TMBK) 7334 7134 M90 9287 8220 Base West Sak (M85) 9773 8505 Shallowest Badami Sand 10581 9021 Badami Sand H3 11244 9502 Badami Sand A0 11498 9698 Badami Sand F4 12077 10165 Badami Sand F5 12319 10368 Primary Sand Badami Sand Q5 12573 10582 Top Killian 14000 11406 Top Shale Wall 14718 11816 Top HRZ 15088 12036 LCU 15449 12256 Top Kekiktuk 15449 12256 Total Depth 16052 12656 Casing/'rubing Program: Hole ~ize ' Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. . MDfl'VD MDrrVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 16" 13-3/8" 68# L-80 BTC 4544 35/35 4579/4555 12-1/4" 9-5/8 .... 40# LB0 BTC 10451 33/33 10484/8955 8-1/2" 7" 29# P110 BTC 15418 31/31 15449/12256 mod 6" 4-1/2" 12.6# L80 BTC 753 15299/12161 16052/12655 cont.liner mod IInternal yield pressure of the 7" 29#/ft P110 casing is 11220 psi, which is greater than the maximum anticipated surface ?,ressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/fi, surfac~-~'~~, 0.36 psi/ft, 6570 to 10094 tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Directional' KOP: I 6024'md / 6000' tvd Maximum Hole Angle: Close Approach Well: 3036' md / 10898' tvd B1-28 · 58.61' (tolerance line dist.) @ 1196' in B1-36 Logging Program: Op~ H~le L~gs' Surface none Intermediate MWD/GR @ hole section TD Brookian Interval MWD/GR/RES Wireline: MAC/ZDL, FMT's Kekiktuk Interval MWD/GR/RES Wireline: MAC/ZDL/CNL, FMT's Cased Hole Logs: none Mud Program: Special design considerations I displace OH to 5% KCL water based muds Surface Mud Properties' I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 - 10.0 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to 10.1 55 20 10 25 9.5 4-6 Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 12.0 45 10 8 15 8.5 4-5 to to to to to to to 12.5 55 15 10 20 9.5 4-5 Well Control (Secondary) · Diverter Waiver Requested Well control equipment consisting of 10,000 psi W.P.(2) pipe rams, (1) blind rams, and 5M WP annular preventer will be installed and is capable of handling maximum potential surface pressures.10 M WP Choke & kill manifold. BOPE and drilling fluid system schematics on file. Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. ,~i~ !~-. ~. ..... ~i--- ~'. ~"~! Annular Injection: No annular injection is planned at this time. ~ ~ ..... - .......... DRILLING HAZARDS AND RISKS: Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Badarni sands are overpressured - normally 12.2ppg mw required at TD. Pressure transition begins just above shallowest sand. Shallow sands typically pressured between normal and the 12.2 ppg required in lower sands. Maintain minimum mud weight and utilize latest techniques to manage lost circulation hazards in shallow sands (flow rates, tapered drill string). Weight up as wellbore pressures dictate, maintaining a 200 psi overbalance throughout. Hazards of well control and stuck pipe are managed by setting 9-5/8" casing above shallowest sand, before penetrating the full overpressure. Hazard of lost circulation is managed by proper techniques to maintain Iow ECD - ECD of 13.5 ppg noted to be maximum allowable to prevent lost circulation. Kekiktuk Formation may be normally pressured. Intermediate 7" 29# P110 casing potentially could be used to top set the Kekiktuk if loss circulation problems are encountered at or near the LCU. All exploration wells in the Badami locale drilled the Kekiktuk interval w/12.3ppg - 12.5 ppg mud weights without experiencing loss circulation problems. Badami B1-36 Summary of Operations 1. Weld the starting head on the conductor. 2. Prepare the location for the rig move. 3. MIRU Nabors 28E drilling rig. Build spud mud. A diverter waiver is requested from AOGCC. The Hydril 21-1/4" 2M MSP will not be N/U. Bell nipple will need to be spliced/elongated to ensure flowline centerline is at appropriate elevation. Do not allow the splicing/welding of bell nipple to exist on the critical path of the rig mobilization. 4. PU 16" bha & drill surface hole as per directional plan. Run directional MWD from surface to TD. 5. Run 13-3/8" surface casing and cement to surface in two stages. 6. NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi. 7. RIH with BHA, test casing to 3000 psi. Drill out float equipment and 20' of new formation. Perform a LOT as per SSD Standard Operating Procedure. Contact the Badami Drilling Team Leader or SSD Superintendent with LOT test results before drilling ahead. 8. Drill 12-1/4" hole to intermediate casing TD as per directional plan, with MWD directional surveys. Plan to P/U MWD-GR collar on last bit run prior to TD of 12-1/4" intermediate hole section. 9. Run 9-5/8 "casing and cement as per Cement Procedure (1000' md of cement above shoe). Test BOPE to 6000 psi. 10. RIH w/8.5" BHA, test 9-5/8" 40# L80 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg minimum equivalent. 11. Drill 8.5" hole to top of LCU @ 15,449' md / 12,256' tvd as per directional plan with GR/4 phase resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). Run open hole e-line logs per program. 12. Run and cement 7" 29# P110 drilling liner from top of LCU to 150'md inside of 9-5/8" 40 LB0 intermediate csg w/hanger and liner top packer assembly. 13. RIH w/6" BHA, test 7" 29# P110 csg. to 3500 psi. Drill out float equipment and 20' of new formation. Perform FIT to 13.5 ppg equiv, mud wt. 14. Drill 6" hole from top ofLCU @ 15,449' md / 12,256' tvd to TD as per directional plan with GR/4 phase resistivity MWD. Utilize latest techniques for reducing lost circulation risk (tapered string, flow rate limitations, ECD limits, mud rheology, etc.). Run open hole e-line logs per program. 15. Run and cement 4-1/2" 12.6# L-80 production liner. Tie-back 7" 29# P110 casing to surface. 16. Run 4-1/2" 12.6# L80 NSCT tubing per completion procedure. Set two way check in FMC 4-1/2" tubing hanger. Note: B1-36 will require a Cameron ll"10M x 4-1/16" 10M tubing head adaptor and 4-1/16" 10M Cameron tree. 17. ND 13-5/8" 10M Hydril BOPE, NU 11" 10M x 4-1/16" 10M FMC tubing head adapter and 4-1/16" 10M Cameron tree and test tree to 5500 psi. Pull two way check. 18. Freeze protect 4-1/2" x 7 "annulus and 4-1/2" tubing with diesel - U- tube from annulus to tubing via 2-1/16" 10M FMC tubing head isolation valve. Freeze protect 7"x 9-5/8" annulus to 2200' tvd. B 1-36 Opertions Summary Cont'd: 19. Drop Halliburton "TNT" packer setting ball/rod assembly - to locate in RHC sub in XN nipple. Set HES TNT permanent packer with 5000 psi. Test 4-1/2" 12.6# L80 NSCT tubing to 5500 psi for 30 minutes. Test 4-1/2" x 7" annulus above packer to 5500 psi for 30 minutes. Set BPV in 4-1/16 1 OM FMC tubing hanger. 20. Rig down and prep Nabors 28E/location for rig move. Badami B1-36 CASING SIZE: 13-3/8" SPACER: SURFACE CASING CEMENT PROGRAM - HALLIBURTON 100 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 350 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 1000' above the casing shoe to the ES cementer at 2200' md, plus 30% excess. Premium 2% calcium chloride 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 480 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of fill in the gauge hole plus 30% excess plus 80' shoe joint. i SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 3500 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: To be determined on job x job basis INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 9-5/8" SPACER' 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 410 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. PRODUCTION LINER CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 850 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume baSed on 5115 ' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint CASING SIZE: 4-1/2" Production Liner (Contingency) SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 90 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 752' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. SI:ImI~I~-SUl-I SHARED SERVICES DRILLING DrillQuesf "'"'~-5.',~,?_."Z~"~d~'~" Welt' B1-36 Wp3 Current Well Properties Well: WPS_B1-36 ~~~-- ~ ~ Horizontal Coordinates: Ref. Global Coordinates: 5906424.99 N, 364106.00 E Ref. Geographical Coordinates: 70° 09' 08.0546" N, 147° 05' 33.9968" W 0 -- ~~ RKB Calculation: 35.30 ft Rig (EST) -/'"'Start Dir @ 1.000°/100ft: 300.00fi MD, 300.00fi TVD 20.30 ft Well (CBE) 400.00 ' North Reference' True North Units: Feet Coordinate System: NAD27 Alaska State Planes, Zone.3, US Foot 800.00 ~ ~ PLOT DATE: 11105/98 / Created Ely: ~7,~',~,~ ~ / 1200.00' CheckedBy:,~,J~,C&'¢(-/°j Approved By : f Iii End Dir: 1647.2@ff MD, 1635.71ft TVD a~ 15oo - 1goo.co ' ~ Start Oir @ 1.ooo°/loo.: 17o7.29. MO, 1694.~7~t ~/0 Proposal Target Summ Tm-get Name: TVDss: TVDrkb: Wellhead Offsets: Global Coordinates: ' ' ' (~)00.0~ ' ' .................................................. ~ase Per~nafrost - 2005.60 TVD B1-26 (598428) I0396.00 10451.60 152.74 S, 4363,44 E 5906194.00 N, 368466.00 E : Circle , 2400.00 ~ T2/Kekituk 580440 ]2200.00 12255.60 635.14 S, 6686,47 E 5905670.00 N, 3?0?80.00 E I Circle , 28oo.00 ~End Dir: 3007.2gff MD, 2983.05~t TVD proposal Data for B1-36 3 0 0 0 : Ho6zmtaI Origin: Referonce i Measurement Units: 3200.00 I Noah Reference: Trc~e Nodh Dogleg seve6~: Degrees per lOOft Ve~dcal Section A~muth: 94.993° 3600,00 VerlJcal Section De~ription:Well Reference Verdcal Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg 4000.00 ~ Depth Depth Section Rate 0.00 0.0o3 355,972 0.00 0.00 N 0.(30 E 0.00 300.OO 0.0O3 35~.972 3OO.60 0.O3 N 0.O3 E O.CO 0.0O3 g00.00 5.0O3 180.000 ?99.3? 21 .~0 S O.(30 E 1.9O 1.000 4400.00: Sail @ 0.000° Inclination 1~47.29 13.000 160.000 1635.71 148.51s 32.65E 45.45 1.o30 [ 1707.29 13.o30 160.o30 1694.17 161.19 s 37.2715 51.16 0.o30 4500 - 1:3:3/8" Ga~in~ - 4,579.84 MD, 455,5.~0 TYD 3co7.29 o.ooo 3ss.9~2 ,_~83.o~ 29~.1s s sT.5OE 113.2o 1.ooo 602424 0.O30 358.972 6OOO.OO 299.18 S 87.5O E 113_20 0.000 4.600.00 ~ 7474.24 58.000 96.001 7214.74 369.58 S 7:57.15 E 786.44 4.000 9856.11 53.526 91.244 8555.0O 496.O6 S 2720.79 E 2753.64 0.250 10483.31 47.254 85.128 8954.9O 481.96 S 3203.12 E 3232.91 1.250 10513.31 47.254 85.128 8975.26 480.09 S 3225.07 E 3254.62 0.000 12418.63 31.740 58.266 1O451.60 152.74 S 4363.44 E 4360.18 1.197 5200.00 124~8.63 31.740 58.266 10477.11 144.44 S 4376.86 E 4372.83 0.000 13036.40 60.E00 114.001 10897.87 167.985 4762.76 E 4759.31 8.OOO 13066.4O 60.0OO 114.001 1O912.87 178.55 S 4786.5O E 4783.87 0.000 15449.25 51.999 91.973 12255.60 635.14 S 6686.47 E 6716.38 O.834 6600.00 I 16051.73 44.812 84.628 12655.60 623.41 S 7136.02 E 7163.20 1.500 /Start Dir @ 4.000°/100fl: 6024.24ff MD, 6000.00ff TVD ~000 -I 6000.00" .oo.oo 6600.00 ............ -~2. o. 9..o.o. . . . .~:~. .BHA. .T. en_den. ¢y. @..O_.ZS.0°ZI_QO~I.:. 7.4.7.4..2.4 _~.M0, .7_2.1.4,?.4~ _~. . .D. ............................................. Top Mid Brookian (TMBK) - 7134.60 TVD 7600.00 ~ 7500 ........................ 6000:06- :~ ................................................................................................. Top West Sak - 7514.60 TVD 8400.00 8600.00 .................. . .0200~00 . .~,~ .................................................................................. M90 - 8220.60 ~/D ~.0..9.0' ...~....~..BH^ Tendency @ 1 250°/1001t · 985~.1 lfI MD 8555 00ff TVD .............. ~-~-~.'r-~- - -'~z~ ...................... ' ........... : .............. ' ...... ' ..................... Base West. Sak (M85_) - 8505.60 TVD Top Canmng ~605 60 TVD ..................... ~666:66~ ........ §'5?8"; ~h'~i'fi~'-'] 0'48'4.'~-' ~D;'8~$S'.G0"i'VD ................ · '~, /End Dir: 10483.31ft MD, 8954.90fi'l-VD ~0400.00 ~ BNA Tendency @ 1.197°/100ff: 10513.31R MD, 8975.2~ff 'I'VD 9000 ~0800.00 ~ .......................... ..r% ....................... . .......................................... Shallowest Badami Sand - 9021.60 TVD ................... ~00.®- 'x .................................................................................. ~ ~ 9501.60 ..................................................................... i i'do'o'.;'o'~' " ........................................................................... -~0 - 9697.60 12000.0012000.00 ............................................................................~- F4 - 1016460 TVD '\' , [nd Dir: 12418.63~ ~D 10451.~0rrt TVD · ........................... _ .~Slart Dir.@ .8.Q007/100~': .12448.~31t MD,.10&~TA1[t-I~.D ............ F5 1036~60 TVD _ 12400.06-~'~-- - . 0500 .............. ~42~)-~rc/e-- -'~ ....................................................................... 0.5 ~ 1O581.60 TVD _12800.00~,.~ End Dir: 13036.40ft MD, 10897.87ft TVD I'S~.~-S; 4363.44" ~.~28°°'°° ~ BHA Tendency @ 0.834°/100ft: 13066.40ft MD, 10912.87ft TVD 13200.00 ~. 13600.00 ~ BHA'l-endency @ 1.500°/100ff: 2000 -- 15449.25ft MD, 12255.~0~ TVD .............. . .......................... KEK. - 12255.60 TVD 635.14 S 6686.47E 16000 O0 ' ' Total Depth: 16051.73~ MD, 12~55.60ff 'I-VD 7" kiner - 1~05~ .73 MD, 12~55.~0 'i-VD 0 1500 3000 4500 ~000 7500 Scale: linch = 1 500ft Vc, rtical ~¢,ntinq Section Azimuth: 94.993° (True North) ~=l:llal~l~'~LJn SHARED SERVICES DRILLING DrillQ ~ ="" ~'27~2,72'~'~="" welt' B1-36 Wp3 uest Current Well Properties PLOT DATE: 11mS/98 Created By: ~~ Well: WPS_B1-36 HorizontalCoordinates: ~~__~ CheckedBy: "i],,~J_ ~. Approved By =~[" J.- Ref. Global Coordinates: 5906424.99 N. 364106.00 E Reft Geographical Coordinates: 70° 09' 08.0~6" N. 147° 05' 33.9968" W Proposal Target Summa~~ R KB Ele vat ion: 55.60~ ab ova Mean Sea Level ~~~ T~get N~: T~s: ~b: WcI~ earl Offs e~: O lob~ ~rd~ ..... RKB Calculation: 35.30 It Rig (EST)~~~ B1-26 {59~28) 10396.~ 1~51.60 152.74 S, 4363.~ E 5906194.~ N. 368466.~ E 20.30 ft Well (CBE) ~ I~ ~ c~,~ ' North Reference: True No~h ~e~mk 58~0 122~.~ 12255.~ 635.14 S, 6686.47 E 5905670.00 N, 370780.~ E Units: Feet Ckcle Coordinate System: NAD27 Alaska State Planes, Zone 3, US Foot Scale: linch = 70Oft Eastings -700 0 700 1400 2100 2800 I I I I I I ... Start Dir ~ 1.000°/10~: 300.00ff MD, 300.00ff ~D · ' - End Dir: 1~7.29E MD; 1635.71ff~D 0 - ['" ...~}. Sta~ Dir ~ 1.000°/10~: 1707.2~ MD, 1694.17ffWD - 0 ~ .'.-' .- End Dir: 3007.2~ MD, 2983.05ff ~D ¥.'-' .' S~l ~ 0.000° Inclination m ~ ..' .Sta~ Dir ~ 4.000°/100ff: 6024.24ff MD, 6000.00ff ~D ~ ~ ~ ~' ~" .- BHATendency~ 0.250°/1~ff:7474.24ffMD, 7214.74ff~D 95/8"Casing. ~ c o ~o ." 10484.34 MD, ~ ~ -700 - .. - -700 ~ ~ BHA Tendency ~ 1.250°/100~: 9856.1 lff MD, 8555.0~ WD ~ I I I I I ,I -700 0 700 1 400 2100 2800 Scale: linch = 70Oft Eastings Reference is True No~h Scale: linch = 700ft Eastings 3150 3850 4550 5250 5950 6650 7350 : I I I I I I I 0 - z ~O ..- End Oir: 12418.63~ MD, 10451.60ftWD -- 0 o~_ -.oq ~9~ .... ~ .- Sta~ Dir ~ 8.000°/100fl: 12448.63ff MD, 10477.11fl ~D ~Oo~ [~~ ......... End Dir: 13036.40~ MD, 10897.87, ~D O~Oo uo.o° ~ ~ 13 40 MD 1 f /Ke~k580440 Ctrcle ~ J ~ ~ BHATendency'~ 0.834°/100,: 066.. , 109 2.87tW~ ' - ' ~~ 'O ~x / ~~0~ ~ z 12255.60 ~ O~ 0 '0~ '~0/ ~ ~ ' O~ , 635.14S, 6686.47E ~ ~0~ ~00 '00 ~ BI~ (598428) ~ircle ~Q '~ ~ ~ _ oo- ........ . ..... .K' J ....-" - oo ~ 9 5/8" Casing - BHA Tendency ~ 1.500°/100~: 1~49.25ff MD, 122~5.60ff ~ :' ~ · 5 10484.34 M D, '5 ~ 8955.60 TVD ~ ~ Total Depth: 16051.73ff MD 12655.60ft ~D ~ ~ 7 L ner- 16051.73 MD, 12655.60 ~D o I I I I I I I 3150 3850 4550 5250 5950 6650 7350 Scale: linch = 70Oft Eastings Reference is True North Sperr',-Sun Drilling S~ivices proposal Data - WPS_B 1-36 - B 1-36 Wp3 29 ~9 ~3 :ooo ~o.oo6 ]: :':~ : : : : ' ' ~ :::::::::::: :: ::: ::::::::::~':'F.~i~'~ '"'~'.~ ] ~ *~24~8 63 30 O0 3t 740 *;58::266'10~7~ 5 November, 1998 - 9:55 - I - DrillOuest Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Proposal Report for WPS_B 1-36 - B 1-36 Wp3 Revised: 4 November, 1998 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.000 0.000 -55.60 0.00 300.00 0.000 0.000 244.40 300.00 800.00 5.000 180.000 743.77 799.37 1000.00 6.786 171.128 942.70 998.30 1647.29 13.000 160.000 1580.11 1635.71 1707.29 13.000 160.000 1638.57 1694.17 2000.00 10.073 160.000 1925.34 1980.94 2025.04 9.823 160.000 1950.00 2005.60 3000.00 0.073 160.000 2920.16 2975.76 3007.29 0.000 0.000 2927.45 2983.05 4000.00 0.000 0.000 3920.16 3975.76 4515.77 0.000 0.000 4435.92 4491.52 4579.84 0.000 0.000 4500.00 4555.60 5000.00 0.000 0.000 4920.16 4975.76 6000.00 0.000 0.000 5920.16 5975.76 6024.24 0.000 0.000 5944.40 6000.00 7000.00 39.030 96.001 6846.42 6902.02 7333.80 52.382 96.001 7079.00 7134.60 7474.24 58.000 96.001 7159.14 7214.74 8000.00 56.997 94.993 7441.64 7497.24 8031.84 56.937 94.932 7459.00 7514.60 9000.00 55.113 93.013 8000.05 8055.65 9286.48 54.579 92.429 8165.00 8220.60 9772.86 53.679 91.419 8450.00 8505.60 9856.11 53.526 91.244 8499.40 8555.00 9940.37 52.666 90.484 8550.00 8605.60 10000.00 52.060 89.936 8586.41 8642.01 10483.31 47.254 85.128 8899.30 8954.90 10484.34 47.254 85.128 8900.00 8955.60 10513.31 47.254 85.128 8919.66 8975.26 Alaska State Plane Zone 3 Badami CPF 0.00 N 0.00 E 0.00 N 0.00 E 21.80 S 0.00 E 42.20 S 1.82 E 148.51 S 32.65 E 161.19 S 37.27 E 216.20 S 57.29 E 220.26 S 58.77 E 299.18 S 87.49 E 299.18 S 87.50 E 299.18 S 87.50 E 299.18 S 87.50 E 299.18 S 87.50 E 299.18 S 87.50 E 299.18 S 87.50 E 299.18 S 87.50 332.61S 405.44 357.53 S 642.51 369.58 S 757.15 412.07 S 1198.50 414.38 S 1225.10 470.14 S 2025.94 481.26 S 2259.90 494.51S 2653.79 496.06 S 2720.79 497.08 S 2788.16 497.26 S 2835.38 481.96 S 3203.12 481.89 S 3203.87 480.09 S 3225.07 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 5906424.99 N 5906424.99 N 5906403.19 N 59O6382.77 N 59O6275.92 N 5906263.16 N 5906207.80 N 5906203.71N 5906124.29 N 5906124.28 N 5906124.28 N 5906124.28 N 5906124.28 N 5906124.28 N 5906124.28 N 5906124.28 N 5906085.16 N 5906056.00 N 5906041.89 N 5905991.48 N 59O5988.7O N 5905918.59 N 5905903.27 N 59O5882.96 N 5905880.20 N 5905877.97 N 5905876.95 N 5905885.65 N 59O5885.70 N 5905887.13 N 364106.00 E 0.00 364106.00 E 0.000 0.00 364105.61E 1.000 1.90 364107.07 E 1.000 5.49 364135.98 E 1.000 45.45 364140.37 E 0.000 51.16 364159.40 E 1.000 75.89 364160.81E 1.000 77.72 364188.11E 1.000 113.20 364188.11E 1.000 113.20 364188.11E 0.000 113.20 364188.11E 0.000 113.20 364188.11E 0.000 113.20 364188.11E 0.000 113.20 364188.11E 0.000 113.20 364188.11E 0.000 113.20 364505.40 E 4.000 432.84 364741.99 E 4.000 671.19 364856.40 E 4.000 786.44 365296.92 E 0.250 1229.82 365323.47 E 0.250 1256.51 366123.18 E 0.250 2059.17 366356.90 E 0.250 2293.21 366750.50 E 0.250 2686.76 366817.45 E 0.250 2753.64 366884.79 E 1.250 2820.84 366932.00 E 1.250 2867.89 367299.96 E 1.250 3232.91 367300.71E 0.000 3233.66 367321.94 E 0.000 3254.62 Comment Start Dir @ 1.000°/100ft ' 300.00ft MD, 300.00ft TVD End Dir: 1647.29ft MD, 1635.71ft TVD Start Dir @ 1.000°/100ft: 170.7.29ft MD, 1694.17ft TVD Base Permafrost End Dir: 3007.29ft MD, 2983.05ft TVD Sail @ 0.000° Inclination 13 3/8" Casing Start Dir @ 4.000°/100ft ' 6024.24ft MD, 6000..00ft TVD Top Mid Brookian (TMBK) BHA Tendency @ 0.250°/100ft · 7474.24ft MD, 721,4.74ft TVD Top West Sak M90 Base West Sak (M85) BHA Tendency @ 1.250°/100ft · 9856.1 lft MD, 8555.00ft TVD Top Canning End Dir' 10483.31ft MD, 8954.90fl TVD 9 5/8" Casing BHA Tendency @ 1.197°/100ft ' 10513.31ft MD, 8975.26ft TVD 5';;5,~ Cr~;: ,....., .,,,:' %;,, Continued... 4 November, 1998 - 8:39 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for WPS_B 1-36 - B 1-36 Wp3 Revised: 4 November, 1998 Badami Alaska State Plane Zone 3 Badami CPF Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (fi) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOOft) (ft) Comment 10581.17 46.615 84.443 8966.00 9021.60 475.58 S 3274.44 11000.00 42.769 79.869 9263.77 9319.37 435.80 S 3566.09 11244.04 40.622 76.893 9446.00 9501.60 403.21 S 3725.07 11498.21 38.474 73.511 9642.00 9697.60 361.99 S 3881.51 12000.00 34.565 65.839 10045.40 10101.00 259.33 S 4161.31 12076.98 34.012 64.531 10109.00 10164.60 241.13 S 4200.67 12319.52 32.366 60.163 10312.00 10367.60 179.65 S 4318.26 12418.63 31.740 58.266 10396.00 10451.60 152.74 S 4363.44 12448.63 31.740 58.266 10421.51 10477.11 144.44 S 4376.86 12573.51 35.052 75.455 10526.00 10581.60 118.09 S 4439.67 13000.00 57.674 111.954 10823.44 10879.04 155.82 S 4734.09 13036.40 60.000 114.001 10842.27 10897.87 167.98 S 4762.76 13066.40 60.000 114.001 10857.27 10912.87 178.55 S 4786.50 14000.00 56.402 105.871 11349.74 11405.34 449.73 S 5530.95 15000.00 53.190 96.446 11927.02 11982.62 608.85 S 6330.74 15449.25 51.999 91.973 12200.00 12255.60 635.14 S 6686.47 16000.00 45.410 85.327 12563.49 12619.09 626.62 S 7099.51 16051.73 44.812 84.628 12600.00 12655.60 623.41 S 7136.02 E 5905890.74 N 367371.38 E 1.197 3303.41 E 5905925.28 N 367663.70 E 1.197 3590.49 E 5905955.02 N 367823.24 E 1.197 3746.03 E 5905993.43 N 367980.39 E 1.197 3898.28 E 5906091.05 N 368261.99 E 1.197 4168.09 E 5906108.54 N 368301.67 E 1.197 4205.72 E 5906167.90 N 368420.34 E 1.197 4317.51 E 5906194.00 N 368466.00 E 1.197 4360.18 E 5906202.06 N 368479.57 E 0.000 4372.83 E 5906227.28 N 368542.84 E 8.000 4433.10 E 5906184.27 N 368836.54 E 8.000 4729.69 E 5906171.60 N 368864.98 E 8.000 4759.31 E 5906160.61 N 368888.52 E 0.000 4783.87 E 5905876.11 N 369627.99 E 0.834 5549.10 E 5905702.67 N 370424.80 E 0.834 6359.71 E 5905670.00 N 370780.00 E 0.834 6716.38 E 5905671.11 N 371193.13 E 1.500 7127.11 E 5905673.67 N 371229.69 E 1.500 7163.20 Shallowest Badami Sand H3 A0 F4 F5 End Dir: 12418.63ft MD 10451.60ft TVD Target: B1-26 (598428),'200.00 Radius., Geological Start Dir @ 8.000°/100ft: 12448.63ft MD, 10477.1 lft TVD Q5 End Dir · 13036.40ft MD, 10897.87ft TVD BHA Tendency'@ 0.834°/100ft · 1'3066.40ft MD, 10912.87ft TVD BHA Tendency @ 1.500°/100ft ' 15449.25ft MD, 12255.60ft TVD KEK. Target: T2/Kekituk 580440, 200.00 Radius., Geological Total Depth' 16051.73ft MD, 12655.60ft TVD 7" Liner All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 0.000° (04-Nov-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 94.993° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16051.73ft., The Bottom Hole Displacement is 7163.20ft., in the Direction of 94.993° (True). Continued... 4 November, 1998 - 8:39 - 3 - DrillQuest Badami Sperry-Sun Drilling Services Proposal Report for WPS_B 1-36 - B 1-36 Wp3 Revised: 4 November, 1998 Alaska, State Plane Zone 3 Badami CPF Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 300.00 300.00 0.00 N 0.00 1647.29 1635.71 148.51 S 32.65 1707.29 1694.17 161.19 S 37.27 3007.29 2983.05 299.18 S 87.50 4515.77 4491.52 299.18 S 87.50 6024.24 6000.00 299.18 S 87,50 7474.24 7214.74 369.58 S 757.14 9856.11 8555.00 496.06 S 2720.79 10483.31 8954.90 481.96 S 3203.12 10513.31 8975.26 480.09 S 3225.07 12418.63 10451.60 152.74 S 4363.44 12448.63 10477.11 144.44 S 4376.86 '13036.40 10897.87 167.98 S 4762.76 13066.40 10912.87 178.55 S 4786.50 15449.25 12255.60 635.14 S 6686.47 16051.73 12655.60 623.41 S 7136.02 Comment Start Dir @ 1.000°/100ft: 300.00ft MD, 300.00ft TVD End Dir: 1647.29ft MD, 1635.71ft TVD Start Dir @ 1.000°/100ft: 1707.29ft MD, 1694.17ft TVD End Dir: 3007.29ft MD, 2983.05ft TVD Sail @ 0.000° Inclination Start Dir @ 4.000°/100ft: 6024.24ft MD, 6000.00ft TVD BHA Tendency @ 0.250°/100ft: 7474.24ft MD, 7214.74ft TVD BHA Tendency @ 1.250°/100ft: 9856.1 lft MD, 8555.00ft TVD End Dir: 10483.31ft MD, 8954.90ft TVD BHA Tendency @ 1.197°/100ft: 10513.31ft MD, 8975.26ft TVD End Dir: 12418.63ft MD, 10451.60ft TVD Start Dir @ 8.000°/100ft: 12448.63ft MD, 10477.1 lft TVD End Dir: 13036.40ft MD, 10897.87ft TVD BHA Tendency @ 0.834°/100ft: 13066.40ft MD, 10912.87ft TVD BHA Tendency @ 1.500°/100ft: 15449.25ft MD, 12255.60ft TVD Total Depth: 16051.73ft MD, 12655.60ft TVD Continued... 4 November, 1998 - 8:39 - 4 - DrillQuest Badami Sperry-Sun Drilling Services Proposal Report for WPS_B 1-36 - B 1-36 Wp3 Revised: 4 November, 1998 Alaska State Plane Zone 3 Badami CPF Forma~on Tops Measured Depth 2025.04 7333.80 8031.84 9286.48 9772.86 994O.37 10581.17 11244.04 11498.21 12076.98 12319.52 12573.51 15449,25 Vertical Depth (ft) 2005.60 7134.60 7514.60 8220.60 8505.60 8605.60 9021.60 9501.60 9697.60 10164.60 10367.60 10581.60 12255.60 Sub-Sea Depth (ft) 1950.00 7079.00 7459.00 8165.00 8450.00 8550.00 8966.00 9446.00 9642.00 1O1O9.O0 10312.00 10526.00 12200.00 Northings (ft) 220.26 S 357.53 S 414.38 S 481.26 S 494.51 S 497.08 S 475.58 S 403.21 S 361.99 S 241.13 S 179.65 S 118.09 S 635.14 S Eastings (ft) 58.77 642.51 1225.1o 2259.90 2653.79 2788,16 3274.44 3725,07 3881.51 4200,67 4318.26 4439.67 6686.47 Formation Name E Base Permafrost E Top Mid Brookian (TMBK) E Top West Sak E M90 E Base West Sak (M85) E Top Canning E Shallowest Badami Sand E H3 E AO E F4 E F5 E Q5 E KEK. Casing details From Measured Depth (ft) <Surface> <Surface> <Surface> Vertical Depth (ft) <Surface> <Surface> <Surface> To Measured Depth (ft) 4579.84 10484.34 16051.73 Vertical Depth (ft) 4555.60 8955.60 12655.60 Casing Detail 13 3/8" Casing 9 5/8" Casing 7" Liner Continued... 4 November, 1998 - 8:39 - 5 - DrillQuest Badami Sperry-Sun Drilling Services Proposal Report for WPS_B 1-36 - B 1-36 Wp3 Revised: 4 November, 1998 Alaska State Plane Zone 3 Badami CPF Targets associated with this wellpath Target Name B1-26 (598428) T2/Kekituk 580440 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 10451.60 152.74 S 4363.44 E 10396.00 5906194.00 N 368466.00 E 70° 09"06.5399" N 147° 03' 27.6905" W 12255.60 635.14 S 6686.47 E 12200.00 5905670.00 N 3707'80.00 E ,, 70° 09' 01.7784" N 147° 02' 20.4593" W Target Shape Circle Circle Target Type Geological Geological 4 November, 1998 - 8:39 - 6- DrillQuest Shared Services Drilling Mike Cook Mike, The above mentioned well has been scanned using standard anti-collision methods via DEAP. The scan was performed with the following parameters: Start Scan Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (per 1000') 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 AWD Proximity Review B1-36wp3.xls 35.30' 16,051.73 ' 200.00' 100.00 ' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 98.235' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 101.765' at the Start Scan Inspection Zone as stated above. These numbers are used to produce a final scan radius of 1801.643' which is 899.0565' larger than DEAP's default value of 902.5865' At this enlarged radius the following wells were detected during the scan (Based on closest 'Allowable Deviation fi:om Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Comparison Subject Well Planned Well Relative AHowable Well: Depth Seperation Azimuth Deviation ['= Existing Surve¥~ ('= Well Plan MD} (Point to Point) [TC Direction) (Approx. TL Dist) Shut-in Required? (Seperation nor Status as Tested B1-28 B 1-23 Wp6 1196.27'MD 83.44' 284.10 o 58.61 ' No MAJOR MAJOR Planned well listed for future considerations 5099.95 'MD 151.00' 321.50 o 85.78 ' Tolerance Plot required: Close Approach Comments: YES Close Approach Scan Performed by: Checked by: Approved by: Pta t Shared Services Approval: Date: 1 of I 11/5198 · i 140327 I °^"'" ] ,:;,-,,~o,,.o. I oz/~.~./s,q [ oo:t4o~7I VENDOR A _AS~AST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )709915 CI4070998P 100. O0 100. 00 HANDL, IN~ INST: s/h kathg campoamo~ x 51~ ~ // ';/ "~ ;j/. ~ (.C , ,' knACHED CHECK IS IN P~YME~ FOR roMS DE~fllBED ABOVE. 1 OO. OO 1 OO. OO BP EXPLORATION (ALASKA), INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No. H 140327 CONSOLIDA rED COMMERCIAL ACCOUNT 00140327 ~AY ro Th e ]T`d eT' O~ ONE HUNDRED & O0/lO0~~~w~~~~w~~~ US DOLLAR ALASKA STATE DEPT OF REVENUE 3001 PORCUPINE DR ANCHORACE AK 99501-3120 DATE 07/13/98 NOT VALID AFTER 120 DAYS AMOUNT ~100.0~ '~' ..... 7t/~L~..-'~i~ CHECKLIST COMPANY ~ ..... ~ WELl_ NAME ~ e~,.c,-*.~, PROGRAM: exp [-1 dev [] redrll [] serv~,wellbore seg II ann. disposal para req ! FIELD S POOL __.~t~..J..~.._O....... ADMINISTRATION INIT CLASS ~ ~. v' J [MI/,J,.) GEOL Permit fee attached ....................... (~ N Lease number appropriate ................... (~ N Unique well name and number .................. ~ N Well located in a defined pool .................. (~ N Well Iocaled proper dislance from drilling unil boundary .... (~ N Well located proper distance from other wells .......... ~ N Sufficienl acreage available in drilling unit ............ (~ N If deviated, is wellbore plat included .............. ~ N Operator only affected pady ................... i~ N Operator has appropriate bond in force ............. (~ N Permit can be issued without conservation order ........ (~' N Permit can be issued without administrative approval ...... {J) N Can permit be approved before 15-day wait ........... N , 6. 7. 8. 9. 10. 11. 12. 13. ENGINEERING APPR. DATE GEOLOGY 14. Conductor string provided ................... 15. S[uface casing protects all known USDWs ........... 16. CMl' vol adequate to circulate on conductor & surf csg ..... 17. CMf vol adequate to tie-in long string to surf csg ........ 18. CMl' will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~'~' .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of I.-I=S gas probable ................. 30. Permit can be issued w/o hydrogen sul~s ..... 31. Data presenled on potential over~qgomsCEre zones ....... 32. Seismic analysis of s~.haUew~as zones ..... '. ....... 33. Seabed con~,QdJt~r¢~' urvey (if off-shore) ............. 34. (~ly progress reports ....... xploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will nol impair mechanical integrity of the well used for disposal; (I)) will nol damage producing formation or' impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. AREA ~ c(. (~ tJNIT# [ O ~ b c(. ON/OFF SHORE b v',.. Y N Y N ......... Y N Y N Y N Y N Y N GEOI. OGY: ENGINEERING' UIC/Annular COMMISSION: JDH ~ R co ~"/~lq v Comments/Instructions: Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Feb 12 14:23:21 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 99/02/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LO~S WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-VC-90020 J.PANTER D.MASKELL RECEIVED FEB 22 500292293370 B.P. EXPLORATION (ALASKA),INC. SPERRY-SUN DRILLING SERVICES 12-FEB-99 MWD RUN 5 MWD RUN 6 AK-VC-90020 AK-VC-90020 M.CADY M.CADY B.OWEN D.MASKELL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE:. FNL: FSL: FEL: MWD RUN 7 AK-VC-90020 K. FERGUSON N. SCALES MWD RUN 8 AK-VC-90020 K. FERGUSON N. SCALES 9 09N 20E 3859 5186 FNL: FSL: 3859 FEL: 5186 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 55.60 DERRICK FLOOR: 53.60 GROUND LEVEL: 20.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 20.000 116.0 2ND STRING 16.000 13.375 4544.0 3RD STRING 12.250 9.625 10244.0 PRODUCTION STRING 8.750 11874.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 4-6 ARE DIRECTIONAL WITH NATUP_AL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RI/NS 7, 8 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TI/BE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , PRESSURE WHILE DRILLING (PWD), AND DYNAMIC DRILLSTRING SENSORS (DDS). THE CHANGE FROM NGP TO DGR SENSORS OCCURS AT 10178'MD, 8901'TVD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN D. GOODWIN OF BP EXPLORATION (ALASKA), INC. AND R KALISH OF SPERRY-SUN DRILLING SERVICES ON 02/04/98. THIS DATA IS PDC. 6. MWD RUNS 4-8 REPRESENT WELL B1-36 PB1 WITH API#: 50-029-22933-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11874'MD, 10341'TVI). SROP = SMOOTHED RATE OF PENETRATION. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 4494.0 ROP 4560 0 FET 10219 5 RPD 10219 5 RPM 10219 5 RPS 10219 5 RPX 10219 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 11834 0 11873 5 11843 5 11843 5 11843 5 11843 5 11843 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 4 4560.0 7530.0 5 7530.0 7561.0 6 7561.0 10255.0 7 10255.0 11095.0 8 11095.0 11874.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 GR MWD AP I 4 1 68 RPM MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 4 8 12 16 20 24 28 2 3 4 5 6 7 8 Name Min Max Mean Nsam DEPT 4494 11873.5 8183.75 14760 ROP 0.51 1726.22 74.0244 14628 GR 23.0769 165.641 97.2864 14681 RPM 3.32 1847.58 19.3876 3249 RPX 0.36 358.53 10.762 3249 RPS 1.23 876.58 15.4912 3249 RPD 0.72 2000 40.5965 3249 FET 0.46 30.67 2.83498 3249 First Reading 4494 4560 4494 10219.5 10219.5 10219.5 10219.5 10219.5 Last Reading 11873.5 11873.5 11834 11843.5 11843.5 11843.5 11843.5 11843.5 First Reading For Entire File .......... 4494 Last Reading For Entire File ........... 11873.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4494.0 R0P 4560.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7459.0 7529.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURJkL GAMMA PROBE $ BOREHOLE AATD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet 03-DEC-98 ISC 5.06 DEPII 2.22A MEMORY 7530.0 4560.0 7530.0 4.9 51.0 TOOL NUMBER NGP SPC 183 12.250 12.3 BENTONITE 9.80 53.0 8.3 1000 7.2 .000 .000 .000 .000 108.0 .6 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEFT 4494 7529 6011.5 6071 4494 GR 23.0769 165.641 93.6966 5931 4494 ROP 3.5742 1726.22 95.1994 5939 4560 Last Reading 7529 7459 7529 First Reading For Entire File .......... 4494 Last Reading For Entire File ........... 7529 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7459.5 ROP 7530.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ 7484.5 7560.5 NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REFLARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 04-DEC-98 ISC 5.06 DEPII 2.22A MEMORY 7561.0 7530.0 7561.0 .0 .0 TOOL NUMBER NGP SPC 319 12.250 12.3 BENTONITE 9.80 52.0 8.5 1100 5.8 .000 .000 .000 .000 .0 .6 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7459.5 7560.5 7510 203 7459.5 GR 100.25 124.379 112.981 51 7459.5 ROP 3.9117 69.9069 21.972 61 7530.5 Last Reading 7560.5 7484.5 7560.5 First Reading For Entire File .......... 7459.5 Last Reading For Entire File ........... 7560.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7485.0 10178.0 ROP 7562.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10254.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 08-DEC-98 ISC 5.06 DEPII 2.22A MEMORY 10255.0 7561.0 10255.0 23.4 46.9 TOOL NUMBER NGP SPC 183 12.250 12.3 BENTONITE 10.10 48.0 7.9 720 5.4 .000 .000 .000 .000 137.5 .6 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7485 10254 8869.5 5539 7485 GR 43.0769 157.38 105.51 5387 7485 ROP 4.3449 316.992 67.286 5384 7562.5 Last Reading 10254 10178 10254 First Reading For Entire File .......... 7485 Last Reading For Entire File ........... 10254 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE N-u-MBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10179.0 11050.0 FET 10219.5 11059.5 RPD 10219.5 RPM 10219.5 RPS 10219.5 RPX 10219.5 ROP 10255.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11059.5 11059.5 11059.5 11059.5 11094.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA1W-DOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 14-DEC-98 ISC 5.06 DEPII 2.22A MEMORY 11095.0 10255.0 11095.0 16.8 22.1 TOOL NUMBER Pl169CW6BR6 Pl169CW6BR6 8.750 8.8 KCL/POLYMER 11.90 59.0 7.8 19500 4.4 .170 .085 .140 .200 143.0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 7 FT/H 4 1 68 MWD 7 API 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 OHMM 4 1 68 MWD 7 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 10179 11094.5 10636.8 1832 ROP 2.9602 189.963 68.4936 1679 GR 50.3 118.97 94.9737 1743 RPX 0.36 13.39 5.94705 1681 RPS 1.23 769.48 7.20011 1681 RPM 3.32 1847.58 11.4678 1681 RPD 0.72 2000 43.509 1681 FET 0.46 12.34 1.56485 1681 First Reading 10179 10255.5 10179 10219.5 10219.5 10219.5 10219.5 10219.5 Last Reading 11094.5 11094.5 11050 11059.5 11059.5 11059.5 11059.5 11059.5 First Reading For Entire File .......... 10179 Last Reading For Entire File ........... 11094.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STA/~T DEPTH STOP DEPTH GR 11050.5 11834.0 FET 11060.0 11843.5 RPD 11060.0 11843.5 RPM 11060.0 11843.5 RPS 11060.0 11843.5 RPX 11060.0 11843.5 ROP 11095.0 11873.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS% 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 19-DEC-98 ISC 5.06 DEPII 2.22A MEMORY 11874.0 11095.0 11874.0 16.9 58.i TOOL NI3MBER Pl180}{WGVR6 Pll80HWGVR6 8.750 8.8 KCL POLYMER 12.70 52.0 9.2 21000 4.5 .180 .890 .140 149.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .220 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 RPM MWD 8 OHMM 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 20 6 FET MWD 8 HOUR 4 1 68 24 7 ROP MWD 8 FT/H 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD FET ROP Min 11050.5 39.65 5 41 6 11 5 99 6 28 1 38 0 51 First Max Mean Nsam Reading 11873.5 11462 1647 11050.5 120.33 84.674 1568 11050.5 358.53 15.924 1568 11060 876.58 24.3798 1568 11060 317.04 27.8782 1568 11060 966.76 37.474 1568 11060 30.67 4.19568 1568 11060 566.9 24.7149 1558 11095 Last Reading 11873.5 11834 11843.5 11843.5 11843.5 11843.5 11843.5 11873.5 First Reading For Entire File .......... 11050.5 Last Reading For Entire File ........... 11873.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/12 Origin ................... STS Tape Name..' .............. UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 99/02/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Wed Feb 17 21:09:18 1999 Reel Header Service name ............. LISTPE Date ..................... 99/02/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 99/02/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-VC-90020 J.PANTER D.MASKELL B1-36 500292293300 B.P. EXPLORATION (ALASKA),INC. SPERRY-SUN DRILLING SERVICES 17-FEB-99 MWD RUN 5 MWD RUN 6 AK-VC-90020 AK-VC-90020 M.CADY M.CADY B.OWEN D.MASKELL JOB NUMBER: LOGGING ENGINEER: OPER3tTOR WITNESS: MWD RUN 7 AK-VC-90020 K. FERGUSON N. SCALES MWD RIIN 8 MWD RUN 9 A/K-VC-90020 A/<-VC-90020 K. FERGUSON J.PANTER N. SCALES B. OWENS JOB NUMBER: LOGGING ENGINEER: MWD RUN 10 AK-VC-90020 R. KRELL MWD RLIN 11 A/K-VC-90020 R. KRELL MWD RUN 12 AK-VC-90020 R. KRELL OPERATOR WITNESS: B. OWEN B. OWEN B. OWEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 13 AK-VC-90020 R. KRELL B. OWEN MWD RUN 13 AK-VC-90020 R. KRELL B. OWEN MWD RUN 14 AK-VC-90020 B. ZIEMKE N. SCALES 9 09N 20E 3859 5186 55.60 53.60 20.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 4544.0 2ND STRING 16.000 9.625 10244.0 3RD STRING 12.250 7.000 12438.0 PRODUCTION STRING 8.750 14797.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-3 ARE DIRECTIONAL ONLY AND NOT PRESENTED. MWD RUNS 4-6 ARE DIRECTIONAL & NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. MWD RUNS 7, 8 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PPIASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND DYNAMIC DRILLSTRING SENSORS (DDS). THE CHANGE FROM NGP TO DGR SENSORS OCCURS AT 10178'MD, 8901'TVD. 4. MWD RUN 9 IS DIRECTIONAL ONLY AND ONLY ROP DATA IS PRESENTED. 5. MWD RUNS 10-13 ARE DIRECTIONAL, DGR, EWR4, PWD, AND DDS. MWD DATA FROM RUN 10 IS REPLACED BY MEASUREMENT AFTER DRILLING (MAD) DATA FROM RUN 11 OWING FAILURE OVER THE INTERVAL l1719'MD, 10257'TVD TO '11775'MD, 10292'TVD. THROUGH CASING DGR DATA WAS OBTAINED ON A MAD PASS FROM 2434'MD, 2414'TVD TO 3808'MD, 3762'TVD WHILE RUlkrNING IN THE HOLE FOR MWD RUN 13. 6. MWD RUN 14 IS DIRECTIONAL WITH DGR, EWR4, COMPENSATED THERMAL NEUTRON (CTN) STABILIZED LITHO-DENSITY (SLD), AND PWD. 7. DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN D. GOODWIN OF BP EXPLORATION (ALASKA), INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 02/04/98. MWD RUN 14 EWR4, CTN, AND SLD DATA IS CORRECTED TO DGR DEPTHS OWING TO DRILLPIPE COMPRESSION DISCREPANCIES. 8. MWD RUNS 4-14 REPRESENT WELL B1-36 WITH API#: 50-029-22933-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14878'MD, 12163'TVD. SROP = SMOOTHED RATE OF PENETRATION. SGRD = SMOOTHED GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). ENVIRONMENTAL PARAMETERS USED IN LOG PROCESSING: HOLE SIZE: 6" MUD FILTRATE SALINITY: 5600 PPM CHLORIDES MUD WEIGHT: 13.1-13.6 PPG FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 4494.0 ROP 4560.0 FET 10219.5 RPD 10219.5 RPM 10219.5 RPS 10219.5 RPX 10219.5 FCNT 14707.5 NCNT 14707.5 NPHI 14707.5 PEF 14722.0 DRHO 14722.0 RHOB 14722.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 14823.5 14875.5 14825.0 14825.0 14825.0 14825.0 14825.0 14794.5 14794.5 14794.5 14807.0 14807.0 14807.0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE MWD 4 4560 MWD 5 7530 MWD 6 7561 MWD 7 10255 MWD 8 11095 MWD 9 11719 MWD 10 11775 MWD 11 11990 MWD 12 12185 MWD 13 12480 MWD 14 14797 $ REMARKS: MERGED MAIN PASS. $ TOP 0 0 0 0 0 0 0 0 .0 .0 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 7530.0 7561.0 10255.0 11095.0 11719.0 11775.0 11990.0 12185.0 12480.0 14797.0 14878.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BAR/~ 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 16 20 24 28 32 36 4O 44 48 52 5 6 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 4494 14875.5 9684.75 20764 GR 23.0769 376.97 100.554 20660 ROP 0.06 1726.22 66.0252 20632 RPX 0.36 83.98 8.01186 9212 RPS 1.23 769.48 9.54445 9212 RPM 1.47 1847.58 10.7182 9212 RPD 0.72 2000 17.5404 9212 FET 0.46 185.47 7.18554 9212 NPHI 19.61 53.4 36.039 175 RHOB 2.013 2.704 2.30879 171 DRHO -0.094 0.153 0.0126433 171 PEF 12.05 19.99 18.5306 171 FCNT 5.17 13.04 7.04446 175 NCNT 346.1 781.17 579.176 175 First Reading 4494 4494 4560 10219.5 10219.5 10219.5 10219.5 10219.5 14707.5 14722 14722 14722 14707.5 14707.5 Last Reading 14875.5 14823.5 14875.5 14825 14825 14825 14825 14825 14794.5 14807 14807 14807 14794.5 14794.5 First Reading For Entire File .......... 4494 Last Reading For Entire File ........... 14875.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 2434.0 3808.0 2496.5 3851.0 MAD RUN NO. MAD PASS NO. MERGE TOP 13 2434.0 MERGED MAD PASS. $ MERGE BASE 3852.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 2434 3851 3142.5 2835 2434 RAT 26 2526 828.056 2710 2496.5 GR 11.35 45.19 26.2531 2749 2434 Last Reading 3851 3851 3808 First Reading For Entire File .......... 2434 Last Reading For Entire File ........... 3851 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4494.0 7459.0 ROP 4560.0 7529.0 $ LOG HEADER DATA DATE LOGGED: 03-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWN-HOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7530.0 TOP LOG INTERVAL (FT) : 4560.0 BOTTOM LOG INTERVAL (FT) : 7530.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 4.9 MAXIMUM ANGLE: 51.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: ISC 5.06 & INSITE 3.2 & TOOL NUMBER NGP SPC 183 12.250 12.3 BENTONITE MIlD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.80 53.0 8.3 1000 7.2 .000 .000 .000 .000 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 108.0 First Name Min Max Mean Nsam Reading DEPT 4494 7529 6011.5 6071 4494 GR 23.0769 165.641 93.6966 5931 4494 ROP 3.5742 1726.22 95.1994 5939 4560 Last Reading 7529 7459 7529 First Reading For Entire File .......... 4494 Last Reading For Entire File ........... 7529 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7459.5 7484.5 ROP 7530.5 7560.5 $ LOG HEADER DATA DATE LOGGED: 04-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7561.0 TOP LOG INTERVAL (FT) : 7530.0 BOTTOM LOG INTERVAL (FT) : 7561.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: ISC 5.06 & INSITE 3.2 & TOOL NI/MBER NGP SPC 319 12.250 12.3 BENTONITE MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MIID CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.80 52.0 8.5 1100 5.8 .000 .000 .000 .000 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 .0 First Name Min Max Mean Nsam Reading DEPT 7459.5 7560.5 7510 203 7459.5 GR 100.25 124.379 112.981 51 7459.5 ROP 3.9117 69.9069 21.972 61 7530.5 Last Reading 7560.5 7484.5 7560.5 First Reading For Entire File .......... 7459.5 Last Reading For Entire File ........... 7560.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE N-UMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7485.0 10178.0 ROP 7562.5 10254.0 $ LOG HEADER DATA DATE LOGGED: 08-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10255.0 TOP LOG INTERV~d5 (FT) : 7561.0 BOTTOM LOG INTERVAL (FT) : 10255.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 23.4 MAXIMUM ANGLE: 46.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: ISC 5.06 & INSITE 3.2 & TOOL NUMBER NGP SPC 183 12. 250 12.3 BENTONITE MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10.10 48.0 7.9 720 5.4 .000 .000 .000 .000 .6 137.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7485 10254 8869.5 5539 7485 GR 43.0769 157.38 105.51 5387 7485 ROP 4.3449 316.992 67.286 5384 7562.5 Last Reading 10254 10178 10254 First Reading For Entire File .......... 7485 Last Reading For Entire File ........... 10254 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10179.0 11050.0 FET 10219.5 11059.5 RPD 10219.5 11059.5 RPM 10219.5 11059.5 RPS 10219.5 11059.5 RPX 10219.5 11059.5 ROP 10255.5 11094.5 $ LOG HEADER DATA DATE LOGGED: 14-DEC-98 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11095.0 TOP LOG INTERVAL (FT) : 10255.0 BOTTOM LOG INTERVAL (FT) : 11095.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 16.8 MAXIMUM ANGLE: 22.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ ISC 5.06 & INSITE 3.2 & TOOL NUMBER Pl169CW6BR6 Pl169CW6BR6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.750 8.8 KCL/POLYMER 11.90 59.0 7.8 19500 4.4 .170 .085 .140 .200 143.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD 7 HOUR 4 1 68 4 2 RPD MWD 7 OHMM 4 1 68 8 3 RPM MWD 7 OHMM 4 1 68 12 4 RPS MWD 7 OHMM 4 1 68 16 5 RPX MWD 7 OHMM 4 1 68 20 6 GR MWD 7 API 4 1 68 24 7 ROP MWD 7 FT/H 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 10179 11094.5 10636.8 1832 10179 FET 0.46 12.34 1.56485 1681 10219.5 RPD 0.72 2000 43.509 1681 10219.5 Last Reading 11094.5 11059.5 11059.5 RPM 3.32 1847.58 11.4678 1681 RPS 1.23 769.48 7.20011 1681 RPX 0.36 13.39 5.94705 1681 GR 50.3 118.97 94.9737 1743 ROP 2.9602 189.963 68.4936 1679 10219.5 10219.5 10219.5 10179 10255.5 11059.5 11059.5 11059.5 11050 11094.5 First Reading For Entire File .......... 10179 Last Reading For Entire File ........... 11094.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NIIMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE S UMM3LRY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4.0 11050.5 11060 0 11060 0 11060 0 11060 0 11060 0 11095 0 SURFACE SOFTWARE VERSION: STOP DEPTH 11719.0 11719 0 11719 0 11719 0 11719 0 11719 0 11719 0 19-DEC-98 ISC 5.06 & INSITE 3.2 & DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXI~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPII 2.22A MEMORY 11874.0 11095.0 11874.0 16.9 58.1 TOOL NUMBER Pll80HWGVR6 Pl180HWGVR6 8.750 8.8 KCL POLYMER 12.70 52.0 9.2 21000 4.5 .180 .890 .140 .220 149.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 FET MWD 8 HOUR 4 1 68 RPD MWD 8 OHMM 4 1 68 RPM MWD 8 OHMM 4 1 68 RPS MWD 8 OHMM 4 1 68 RPX MWD 8 OHMM 4 1 68 GR MWD 8 API 4 1 68 ROP MWD 8 FT/H 4 1 68 0 4 8 12 16 20 24 28 Name Min Max Mean Nsam DEPT 11050.5 11719 11384.8 1338 FET 1.59 30.67 4.31726 1319 RPD 6.28 124.8 17.1966 1319 RPM 5.99 93.61 15.1865 1319 RPS 6.11 109.01 14.4476 1319 RPX 5.41 44.2 10.8831 1319 GR 39.65 120.33 89.7414 1338 ROP 0.56 406.19 24.1364 1249 First Reading 11050.5 11060 11060 11060 11060 11060 11050.5 11095 Last Reading 11719 11719 11719 11719 11719 11719 11719 11719 First Reading For Entire File .......... 11050.5 Last Reading For Entire File ........... 11719 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH# INCREMENT: 5000 ~ ~'i,~ i._~ ~? i ! ? FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 11719.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : STOP DEPTH 11775.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CA/CE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 23-DEC-98 ISC 5.06 & INSITE 3.2 & DEPII 2.22A MEMORY 11775.0 11717.0 11775.0 .0 .0 TOOL NUMBER 8.750 8.8 KCL POLYMER 12.70 58.0 9.2 16000 3.8 .000 .000 .000 .000 137.0 .6 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 9 FT/H 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 11719.5 11775 11747.2 112 11719.5 ROP 0.2 184.46 21.4074 112 11719.5 Last Reading 11775 11775 First Reading For Entire File .......... 11719.5 Last Reading For Entire File ........... 11775 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEAJDER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11775.5 11990.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A1W-D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: M3~TRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 25-DEC-98 ISC 5.06 & INSITE 3.2 & DEPII 2.22A MEMORY 11990.0 11775.0 11990.0 49.2 87.7 TOOL NUMBER Pll80HWGVR6 Pll80HWGVR6 8.750 8.8 KCL POLYMER 12.70 57.0 9.0 12500 3.7 .410 .190 .340 .440 156.0 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 10 FT/H 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 11775.5 11990 11882.8 430 11775.5 ROP 0.09 102.85 17.8231 430 11775.5 Last Reading 11990 11990 First Reading For Entire File .......... 11775.5 Last Reading For Entire File ........... 11990 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 11719.5 12155.5 RPD 11719.5 12155.5 RPM 11719.5 12155.5 RPS 11719.5 12155.5 RPX 11719.5 GR 11719.5 ROP 11950.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 12155.5 12146.0 12185.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAlkrDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 27-DEC-98 ISC 5.06 & INSITE 3.2 & DEPII 2.22A MEMORY 12185.0 11990.0 12185.0 59.3 64.2 TOOL NUMBER Pl169HWGVR6 Pl169HWGVR6 8.750 8.8 KCL POLYMER 12.80 61.0 9.0 11500 3.7 .420 .186 .220 .580 160.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 11 API 4 1 RPX MWD 11 OHMM 4 1 RPS MWD 11 OHMM 4 1 RPM MWD 11 OHMM 4 1 RPD MWD 11 OHMM 4 1 ROP MWD 11 FT/H 4 1 FET MWD 11 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 11719.5 12185 11952.2 GR 32.69 109.81 81.8255 RPX 4.36 83.98 16.6814 RPS 5.99 138.24 21.7104 RPM 5.99 174.62 25.0353 RPD 6.17 230.16 30.5339 ROP 0.24 900.65 16.2311 FET 1.91 144.27 27.0384 First Last Nsam Reading Reading 932 11719.5 12185 854 11719.5 12146 873 11719.5 12155.5 873 11719.5 12155.5 873 11719.5 12155.5 873 11719.5 12155.5 390 11990.5 12185 873 11719.5 12155.5 First Reading For Entire File .......... 11719.5 Last Reading For Entire File ........... 12185 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12146.5 12441.0 FET 12156.0 12450.5 RPD 12156.0 12450.5 RPM 12156.0 12450.5 RPS 12156.0 12450.5 RPX 12156.0 12450.5 ROP 12186.5 12480.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4.0 SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3tTURE: MUD FILTRATE AT MT: 29-DEC-98 ISC 5.06 & INSITE 3.2 & DEPII 2.22A MEMORY 12480.0 12185.0 12480.0 65.5 70.2 TOOL NUMBER Pl169HWGVR6 Pl169PIWGVR6 8.750 8.8 KCL POLYMER 12.80 64.0 9.3 10800 3.8 .420 .188 .220 158.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .580 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 12 API 4 1 68 RPX MWD 12 OHMM 4 1 68 RPS MWD 12 OHMM 4 1 68 RPM MWD 12 OHMM 4 1 68 RPD MWD 12 OHMM 4 1 68 ROP MWD 12 FT/H 4 1 68 FET MWD 12 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 -4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 12146.5 12480 12313.2 668 GR 67.08 122.03 101.801 590 RPX 4.78 13.91 6.74683 590 RPS 5.21 17.47 7.60439 590 RPM 5.29 18.12 7.873 590 RPD 5.47 17.18 8.33585 590 ROP 0.66 163.34 46.1547 588 FET 0.81 35.06 3.61951 590 First -Reading 12146.5 12146.5 12156 12156 12156 12156 12186.5 12156 Last Reading 12480 12441 12450.5 12450.5 12450.5 12450.5 12480 12450.5 First Reading For Entire File .......... 12146.5 Last Reading For Entire File ........... 12480 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE ST~LRT DEPTH STOP DEPTH GR 12441.5 14734.0 FET 12451.0 14743.5 RPD 12451.0 14743.5 RPM 12451.0 14743.5 RPS 12451.0 14743.5 RPX 12451.0 14743.5 ROP 12483.0 14796.5 $ LOG HEADER DATA DATE LOGGED: 05-JAlg-99 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWN-HOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14797.0 TOP LOG INTERVAL (FT) : 12480.0 BOTTOM LOG INTERVAL (FT) : 14797.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 17.6 MA~XIMUM ANGLE: 71.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. $ ISC 5.06 & INSITE 3.2 & TOOL NUMBER Pl169HWGVR6 Pl169HWG~-R6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MLTD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.750 8.8 KCL POLYMER 12.80 62.0 9.0 5600 4.2 .400 · 153 .300 .600 189.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 API 4 1 68 4 2 RPX MWD 13 OHMM 4 1 68 8 3 RPS MWD 13 OHMM 4 1 68 12 4 RPM MWD 13 OHMM 4 1 68 16 5 RPD MWD 13 OHMM 4 1 68 20 6 ROP MWD 13 FT/H 4 1 68 24 7 FET MWD 13 HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 12441.5 14796.5 13619 4711 12441.5 GR 43.86 376.97 111.64 4586 12441.5 Last Reading 14796.5 14734 RPX 1.41 28.56 6.26618 4586 RPS 1.5 37.31 6.6676 4586 RPM 1.47 41.83 6.56176 4586 RPD 1.54 41.87 6.80307 4586 ROP 0.06 863.41 52.0328 4628 FET 0.93 35.8 3.11995 4586 12451 12451 12451 12451 12483 12451 14743.5 14743.5 14743.5 14743.5 14796.5 14743.5 First Reading For Entire File .......... 12441.5 Last Reading For Entire File ........... 14796.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP 14 .5000 START DEPTH 14707.5 14707.5 14707.5 14722.0 14722.0 14722 0 14736 5 14745 5 14745 5 14745 5 14745 5 14745 5 14797.0 STOP DEPTH 14794 5 14794 5 14794 5 14807 0 14807 0 14807 0 14823.5 14825 0 14825 0 14825 0 14825 0 14825 0 14875 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 12 -JAN- 99 ISC 5.06 & INSITE 3.2 & DEPII 2.22A MEMORY 14878.0 14797.0 14878.0 17.6 17.6 TOOL NUMBER Pl186GR4 Pl186GR4 Pl186GR4 Pl186GR4 6.000 6.0 KCL 13.60 82.0 8.6 4400 9.9 1.200 .428 .740 1.800 203.0 .0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RHOB MWD 14 G/CM 4 1 68 DRHO MWD 14 G/CM 4 1 68 GR MWD 14 API 4 1 68 RPX MWD 14 OHMM 4 1 68 RPS MWD 14 OHMM 4 1 68 RPM MWD 14 OHMM 4 1 68 RPD MWD 14 OHMM 4 1 68 ROP MWD 14 FT/H 4 1 68 FET MWD 14 HRS 4 1 68 NPHI MWD 14 PU-S 4 1 68 FCNT MWD 14 CNTS 4 1 68 NCNT MWD 14 CNTS 4 1 68 PEF MWD 14 BA/~N 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 14707.5 14875.5 14791.5 337 RHOB 2.013 2.704 2.30879 171 DRHO -0.094 0.153 0.0126433 171 GR 31.62 208.54 109.96 175 RPX 1.99 49.52 13.5191 160 RPS 3.26 48.87 17.0908 160 RPM 3.49 46.76 17.6412 160 RPD 4.1 44.28 18.5997 160 ROP 0.83 70.66 20.9847 158 FET 4.57 185.47 109.703 160 NPHI 19.61 53.4 36.039 175 FCNT 5.17 13.04 7.04446 175 NCNT 346.1 781.17 579.176 175 PEF 12.05 19.99 18.5306 171 First Reading 14707.5 14722 14722 14736.5 14745.5 14745.5 14745.5 14745.5 14797 14745.5 14707.5 14707.5 14707.5 14722 Last Reading 14875.5 14807 14807 14823.5 14825 14825 14825 14825 14875.5 14825 14794.5 14794.5 14794.5 14807 First Reading For Entire File .......... 14707.5 Last Reading For Entire File ........... 14875.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.013 Comment Record FILE HEADER FILE NIJMBER: 14 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 13 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2434 . 0 3808 . 0 PAT 2496 . 5 3851.0 $ LOG HEADER DATA DATE LOGGED: 05 - JAN- 99 SOFTWARE SURFACE SOFTWARE VERSION: 4.0 DOWNHOLE SOFTWARE VERSION: DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 14797.0 TOP LOG INTERVAL (FT) : 12480.0 BOTTOM LOG INTERVAL (FT) : 14797.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 17.6 MAXIMUM ANGLE: 71.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA PAY $ BOREHOLE ~dqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : ISC 5.06 & INSITE 3.2 & TOOL NUMBER Pl169HWGVR6 8.750 8.8 KCL POLYMER 12.80 62.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CA/CE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.0 5600 4.2 .4O0 .153 .300 .600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 13 FT/H 4 1 68 4 2 GR MAD 13 A~I 4 1 68 8 3 189.0 First Name Min Max Mean Nsam Reading DEPT 2434 3851 3142.5 2835 2434 RAT 26 2526 828.056 2710 2496.5 GR 11.35 45.19 26.2531 2749 2434 Last Reading 3851 3851 3808 First Reading For Entire File .......... 2434 Last Reading For Entire File ........... 3851 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/02/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/02/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/02/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
