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Home My WebLink About198-063MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 15, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Cook Inlet Energy, LLC. B1-14 BADAMI UNIT B1-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2023 B1-14 50-029-22874-00-00 198-063-0 N SPT 8992 1980630 2248 1325 1335 1335 1335 300 580 585 580 4YRTST P Austin McLeod 7/28/2023 AIO 17A. Swing well. Batch injection. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:BADAMI UNIT B1-14 Inspection Date: Tubing OA Packer Depth 200 2535 2488 2479IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230728184554 BBL Pumped:1.9 BBL Returned:1.9 Friday, September 15, 2023 Page 1 of 1            STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .� ry t1' 't) k H �d r 1. Operations Abandon LJ Plug Perforations U Fracture Stimulate Li Pull Tubing LJ Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _Convert to Swing Well ❑� 2. Operator Savant Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑Q Exploratory ❑ Stmtigraphic ❑ Service ❑ 198-063 3. Address: 188 W. Northern Lights blvd., Suite 510 6. API Number: Anchorage AK 99503 50-029-22874-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 367011, ADL 365533 B1-14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Badami Field, Badami Oil Pool 11. Present Well Condition Summary: Total Depth measured 11525 feet Plugs measured none feet true vertical 10490 feet Junk measured none feet Effective Depth measured 11440 feet Packer measured see schematic feet true vertical 10419 feet true vertical see schematic feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' 4450 psi 1600 psi Surface 4498' 9-5/8" 4533' 4523' 5750 psi 3090 psi Intermediate 10000' 7" 10033' 9334' 8160 psi 7020 psi Production Liner 1666' 4-1/2" 9848'- 11525' 9168'- 10490' 8430 psi 7500 psi Perforation depth Measured depth 11122'-11160' 11312'-11362' feet True Vertical depth 10174'-10203' 10321'-10360' feet Tubing (size, grade, measured and true vertical depth) 4.5" 12.6# L-80 9861' MD 9015' TVD Packers and SSSV (type, measured and true vertical depth) 7" x 4-1/2" HES TNT Packer 9652' MD 8992' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 223 0 268 1700 Subsequent to operation: Injection / Production --> 898/217 0 486 1700 14. Attachments (required per 20 AAc 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas [zel WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319.245 Authorized Name: David Pascal Contact Name: David Pascal Authorized Title: VP OperationsContact Email: d Pascal I @9 acieroil.com q 5 3 I " Authorized Signature: Date: J Contact Phone: 907-433-3822 11 /11 Form 10-404 Revised 4/2 17 ✓L/��D Submit Original Only GLACIER September 3rd, 2019 Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Report of Sundry Savant Alaska LLC, a Glacier Oil and Gas company (GLA): Badami B1-14 Permit to Drill NO: 198-063 API No: 50-029-22874-00-00 Dear Commissioner, Savant Alaska, LLC, hereby submits a Report of Sundry Well Operations for the conversion of B1-14 to a swing well per approved Sundry 319-245. If you have any questions, please contact me at (907) 433-3822. Sincerely, ^ �^ C/ " Tl I VP'Operations Savant Alaska, LLC (a Glacier Oil & Gas Corp. owned company) 188 W. Northern Lights blvd, Suite 510 Anchorage, AK 99503 GLACIER B1-14 Daily Operations Summary API: 50-029-22874-00-00 Permit #: 198-063 Date Activity 25 July 2019 Perform charted MITxIA to 2,500 psi for 30 minutes. Witnessed by ACGCC Inspector Austin Mcloud. 6 August 2019 Complete flow totalizer installation and programming. Current Badami B1-14 Schematic Drill Floor to Sea Leel 54.8 Drill Floor to Tubing Hanger 32.3 Tree 4-1116" / 5,000 psi - CM7 OD I ID Weight Lmph ND I TVD1VD Crround Lewl. to Sea Lewl 195 Wellbead 11 "/10,000 psi - FMC nwh inch Lbs% 8 DF 8 SS 7` 1111 111 C— Conductor, 1140 20.000 13.124 91A 115 115 59 19. 26° HES X Nipple: K -Valve first installed 819112 Csg. LA0, BTC 4.500 1 3.813 2189 1 2157 1 2126 9.625 1 8.681 1 47 1 4498 1 4533 1 4523 1 4469 5245 1 5225 1 5171 x 7" Annulus Capacity= .0175 Btdslft TBG, LA0. NSCT Capacity= 0.0152 BWshli 1 4.5 1 3.958 1 12.6 x 4-1/2" HES T14T PKR 1 5.875 1 3.875 1 1 1 9652 1 8990 1 8935 112"XN NIP, (Note: Min TBG ID=3.725") 5.010 3.725 Sand Peforations 11122'- 11160' [10189 - 10224 TVDss] 9667 9007 8952 Frac'd 03-19-98 45' 9667 9007 8952 112" WLEG 5.000 3.958 n 9681 9015 8965 x 4-112" Liner Hanger Packer 7.000 3.875 Frac'd 08-11-98 9854 9174 9119 USS -95, BTC Capacity = 0.0371 Bblsllt 7.000 6.184 29 10000 10033 9334 9280 USS -95, BTC Casing Shoe 10033 9334 9280 44.n Sand Peforations 11122'- 11160' [10189 - 10224 TVDss] Frac'd 03-19-98 45' 10636 9812 9759 mm Dni ,. n Sand Peforations 11312' .11342' 110323 - 10350 TVDss] 14%- Frac'd 08-11-98 Open Sand Peforations 11342'- 11362' [10350 -10368 TVDss) Frac'd 08-06-98 37'41D-- PBM 11440 10419 10365 LIAR, LA0 BTC -MOD, Shoe Capacity = 0.0152 Bblsfft 4.500 1 3.95812.6 11525 10490 10436 Badanti Unit No. Rei --by Camments'Date 1 WFUVn-H Fomrat Corrections 0373N00 2 SWC(PJC Set XXN Plug @ 9667 08x29107 AN No. 59-029-22874-00-00 3 SWC/PJC Set BPV (Shutdown) 08MI07 PTD To: 198-063 4 R. Benne Updates 10!02112 Last Revised 02-01-2014 5 E. Opstad Updates to 11/15112 SA, ANT 6 E Opstad Updates to 09101/13 ? E. Opstad Updates to 0'101114. Add SSSV test date 8 format edits. ALASKA MEMORANDUM State of Alaska Depth Pretest Alaska Oil and Gas Conservation Commission Well BI -14 DATE: Wednesday, July 31, 2019 TO: Jim Regg _7> P.I. Supervisor 6/ -710 SUBJECT: Mechanical Integrity Tests 1520. 1110- it -o -. Savant Alaska LLC. Type s1. BI -14 FROM: Austin McLeod BADAMI UNIT BI -14 Petroleum Inspector BBIL Returned: rened ,8. Ste: Inspector _ — 210 Reviewed By: — 3P ;» - P.I. Sup"_I1S — OTHER p/F NON -CONFIDENTIAL Comm Well Name BADAMI UNIT BI -14 Insp Num: mitSAM190725125451 Rel Insp Num: API Well Number 50-029-22874-00-00 Inspector Name: Austin McLeod Permit Number: 198-063-0 Inspection Date: 7/25/2019 Wednesday, July 31, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well BI -14 - Type Inj N TVD 8993 Tubing 1480 -i 1520. 1110- it -o -. PTD ledoa0 Type s1. ,1 I IA 61- 24'1 1d2 BBL Pum BBIL Returned: rened ,8. _ — 210 3208 i — 3P ;» - Interval OTHER p/F r -T-- Notes: MIT_�IA post well converted to a gas storage/production well (swing well). Sundry 4 319-245. Wednesday, July 31, 2019 Page I of 1 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY George Morris Chief Operating Officer Savant Alaska, LLC. 188 W. Northern Lights Blvd., Suite 510 Anchorage, AK 99503 Re: Badami Field, Badami Oil Pool, B1-14 Permit to Drill Number: 198-063 Sundry Number: 319-245 Dear Mr. Moms: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the 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 fturther 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, Daniel T. Seamount, Jr. Commissioner OFJ DATED this day of May, 2019. ROW ' MAY 1 61019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 `EGEk MAY 10 2019 A0GQQ 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 ❑ Atter Casing ❑ Convert to Swing Well ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Savant Alaska LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 198-063 • 3. Address: 6. API Number: 188 W. Northern Lights Blvd., Suite 510 Anchorage, AK 99503 50-029-22874-00-{� S -i3• 7. If perforating: B. Well Name and Number: ' What Regulation or Conservation Order governs well spacing in this pool? N/A B1-14 Will planned perforations require a spacing exception? Yes ❑ No ❑v 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL -367011 L 365 315 s' (3' ) Badami Field, Badami Oil Pool 11. r PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,525' 10,490' 11,440' 10,419' 1,180 WA N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20' 110' 110' 4450 psi 1600 psi Surface 4498' 95/8.1 4533' 4523' 5750 psi 3090 psi Intermediate 10000' 7" 10033' 9334' 8160 psi 7020 psi Production Liner 1666' 1 4 1/2" 9848' - 11525' 9168'- 10490' 8430 psi 7500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 10174'-10203' 10321'-10360' Tubing Size: 4.5" 12.6# Tubing Grade: L-80 Tubing MD (ft): 9681' 11122'-11160' 11312'-11362' Packers and SSSV Type: 7" x 4 1/2" HES TNT Pkr Packers and SSSV MD (ft) and TVD (ft): K -valve SSSV set in HES x -nipple Pkr @ 9652' MD / 8992' TVD, K -valve in HES x -nipple @ 2188' MD / 2179' TVD 12. Attachments: Proposal Summary Lwj Wellbore schematic L4J 13. Well Class after proposed work: Vf Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service 14. Estimated Date for 5/27/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS [ ( WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: ,/K��'/3'0 GINJ ❑� Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: George Morris Contact Name: George Morns Authorized Title: Chief Operating Officer Contact Email: morriS Iacieroil.Com \ Contact Phone: 713-859-0336 Authorized Si nature: Date: `a /19 z�/ •�' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Sundry Number: CJ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Fe, Location Clearance ❑ Other: RBDMS�� MAY 16 2019 r� Post Initial Injection MIT Req'd? Yes No ❑ LJ L/ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: I o — Ll U 1 APPROVED BY ' [/) / • �Y Approved by: COMMISSIONER THE COMMISSION Date: ,J L 5�15�� I V PP'-' 1PP�o 1\ V f 1 11�� pP F 10-403 Revi ed 4/ 17 A roved a IIc ti I r om the date of approval. Submit Form and Attachments in Duplicate 1111 /�// �5_"-/ q GLACIER May 101h, 2019 Ms. Jessie Chmielowski, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Application Savant Alaska LLC, a Glacier Oil & Gas company (GLA): Badami B1-14 API No.: 50-029-22874-00 Permit to Drill: 198-063 Dear Commissioner, Glacier Oil & Gas, on behalf of Savant Alaska, LLC, submits a Sundry Application for Badami 131-14, PTD: 198-063, requesting permission to convert B1-14 from an oil producer to a well which will cycle between gas storage injection and production per 20 AAC 25.265.(d).(5) and in association with AIO 17A. If you have any questions, please contact me at 713.859.0336. Sincerely, George Morris Chief Operating Officer Savant Alaska, LLC (a Glacier Oil and Gas wholly owned company) 188 W. Northern Lights Blvd., Suite 510 Anchorage, AK 99503 4 GLACIER 1. WELL NAME — Badami B1-14 Requirements of 20 AAC 25.005(f) Well Summary Current Status: The well is producing. Current Perforations: MD TVD 11,122'— 11,160' 10,189'— 10,224' 11,312'— 11,342' 10,323' —10,350' 11,342'— 11,362' 10,350'— 10,368' Scope of Work: • Complete flowline instrumentation • Perform Mechanical Integrity Test (MIT) General Well Information: Reservoir Pressure/ TVD: 3525 psi @ 10,420' TVD (.15 psi/ft) MASP: 1180 psi (half oil/half gas) 3525 psi — (5210' with .35 psi/ft oil) - (5210' with .1 psi/ft gas) 1180 psi = 3525psi - 1824psi - 521psi Wellhead Type/Pressure Rating: 11" Multibowl 10K Wellhead Well Type: Oil Well Estimated Start Date: May 27th, 2019 Program 1. Shut in well. 2. Install flow totalizer. 3. Perform AOGCC witnessed MIT. 4. Turn well over to production. Current Badami B1-14 Schematic Unn l•Toor to Jea Level 34.8 Drill Floor to Tubing Hanger 32.3 Tree 41' 16" 15.000 psi - CIW _ Ground level to Sea level 19.5 5T,'ellhead 1I") `10.000 psi - FNIC 7' i CS r. RAG X Nipple: K -Valve first installed 8/19112 19° Cell, L-84, BTC CD Wch ID inch Washt Ib -J8 Leoglh It IID DF TVD R I WD SS 20.800 4.500 13.124 3.813 91.1 115 2189 115 2157 59 2126 Cell, L-84, BTC 9.625 &681 I 47 4498 4533 I 4523 I 69 8990 8935 4112" XN NIP, (Note: Min TBG ID = 3.725") 5245 5225 �71 x 7" Annulus Capacity = .0175 BbWit TBG, L-80, NSCT Capacity= 0.0152 Bbls, t 1 4.5 1 3.958 1 12.6 T' x 4112" HES TNT PKR 5.875 3.875 9652 8990 8935 4112" XN NIP, (Note: Min TBG ID = 3.725") 6.010 3.725 9667 9007 8952 9667 9007 8952 4112" WLEG 5.000 3.956 9681 9015 8966 T' x 4112" Liner Hanger Packer 7.000 3.875 9854 9174 9119 260 T' USS -9& BTC Capacity=0.0371 Bbistft 7.000 &184 29 10000 10033 9334 9280 - T' USS -96. BTC Casing Shoe 10033 9334 9280 4',. Open Send Peforations 11122'- 11160'[10189 -10224 TVDss] Frac'd 08-19-98 10636 4812 4759 .-s•^.,+: n. +c-cr Open Sand Peforations 11312'- 11342' [10323 -10350 TVDss] Frac'd 08-11-98 Open Sand Peforations 11342' -11362' [10350 -10368 TVDss] Fracd 08.O&% 37" PBTD---TOFTagontf-09.12V11,376'fdD— 11440 10419 10365 -- 4'h" LNR, L-00 OTC -MOD, Shoe Copacity - Q.Oir2 Oblalft 4.500 3.950 12.0 111&i20 10490 10430. Na Rea-bv c. ,,O e 1 PdRRRLH Format Corre tions 03/30300 Badami Unit 2 SWCIPJC Set XXN Plug @ 966T 08(29107 AN NO. %-029-22M-00-00 3 SWC/PJC Set BPV (Shitdorn) 08!30107 PID No: 148-063 a R. Benne Updates 10102/12 Last Revised 02-01-2014 5 E. Opstad Updates to 11/15/12 . 6 E. Opstad Updates to OWO1/13 7 E. Opstad Updates to 0:lD1/14. Md SSSV test date 8: format edits. ALASKA RECEIVED . STATE OF ALASKA • AL KA OIL AND GAS CONSERVATION COMMISSION OCT 1 ! 2012 REPORT OF SUNDRY WELL OPERATIONS ABC 1. Operations Abandon U Repair Well Li Plug Perforations LJ Perforate U Other a Instai ,K -Valae Performed: Alter Casing 0 Pull Tubing 0 Stimulate - Frac ❑ Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Stimulate - Other E Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: SAVANT ALASKA LLC Development ❑ Exploratory ❑ 198 -063 3. Address: P.O. Box 112212, Anchorage, AK Stratigraphic 0 Service 0 6. API Number: �y 99511 -2212 50- 029 - 22874 -00 - 00 7. Property Designation (Lease Number): ., 8. Well Name and Number: _ ADL 367011 B1 -14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): None BADAMI/ Badami Oil Pool 11. Present Well Condition Summary: 1 Total Depth measured 11525 feet Plugs measured feet true vertical 10490 feet Junk measured feet Effective Depth measured 11440 feet Packer measured 9652 feet true vertical 10422 feet true vertical 8993 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 110' 110' 4450 psi 1600 psi Surface 4499' 9 -5/8" 4533' 4523' 5750 psi 3090 psi Intermediate 10000' 7" 10033' 9334' 8160 psi 7020 psi Production Liner 1677' 4%2" 11525' 10490' 8430 psi 7500 psi Perforation depth Measured depth 11122' - 11160' & 11312' - 11362' feet True Vertical depth 101 19' - 10149' & 10267' - 10306' feet Tubing (size, grade, measured and true vertical depth) 4%2 ", 12.6 #, L -80 NSTC 9680' MD 9019' TVD Packers and SSSV (type, measured and true vertical depth) HES TNT Packer 9652' MD 1 8992' TVD HES K -Valve 2189' MD 1 2170' TVD 7 "x4' / : :" 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): SCANNED JAN 2 3 Z013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0' 4 . 1 0, " ' . ' "'140 2104 Subsequent to operation: 0 5000 0 140 2104 14. Attachments: 15. Well Class after work: .• Copies of Logs and Surveys Run SBHPS Exploratory 0 Development Service ii Stratigraphic 0 Daily Report of Well Operations HES Log, Set K -Valve 16. Well Status after work: Oil n , Gas 8/ WDSPL O GSTOR ❑ WINJ El WAG fl GINJ SUSP U SPLUG D 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: 312 -115 Contact: Erik Opstad or Mary Rush @ 907-8: 58 email: Erik.0ostad(p�SavantAlaska.com /� Printed Name Erik Opstad __ j -1111F," Title: Drilling & Wells Manager Signature: /-/ Phone: 907-433-7803 Date: 10/1/2012 ��ef Form 10 -404 Revised 1 'I S OCT 1 9 LU I� �—' � t, ∎, Original l Only 1 • • B1-14 Drill Floor to Sea Level 54.8 Drill Floor to Tubing Hanger 32.3 Tree 4- 1/16" / 5,000 psi - CIW OD 1D Weight Length MD TVD TVD Ground Level to Sea Level 19.5 Wellhead 11" /10,000 psi - FMC inch inch Lbs /ft fl DF ti SS 7° <— Conductor, H -40 20.000 13.124 91.1 115 115 59 (. 4 -1/2" HES X NIP (K -Valve installed 9/28/12; next test 11- 03.2012) 4.500 3.813 2189 2157 2126 A ,< 9 -5/8" Csg, L -80, BTC 9.625 8.681 47 4498 4533 4523 4469 1 19° 5245 5225 5171 ■ 4%" x 7" Annulus Capacity = .0175 Bbls /ft 4 -1/2" TBG, L -80, NSCT Capacity = 0.0152 Bbls /ft 4.5 3.958 12.6 8 1 < 7" x 4 -1/2" HES TNT PKR 5.875 3.875 9652 8990 8935 4 -1/2" XN NIP, (Note: Min TBG ID = 3.725 ") 5.010 % %= 9667 9007 8952 9667 9007 8952 4 -1/2" WLEG 5.000 3.958 9681 9015 8965 • < 7" x 4 -1/2" Liner Hanger Packer 7.000 3.875 9854 9174 9119 26° < 7" USS -95, BTC Capacity = 0.0371 Bbls /ft 7.000 6.184 29 10000 10033 9334 9280 A < 7" USS -95, BTC Casing Shoe 10033 9334 9280 40° I Sand Peforations 11122' - 11160' [10120 - 10155 TVDss] Frac'd 08 -19 -98 I Maximum Well Deviation 10636 9812 9759 Sand Peforations 11312' - 11342' [10270 - 10297 TVDss] Frac'd 08 -11 -98 1 11342' - 11362' [10284 - 10302 TVDss] Frac'd 08 -06 -98 37° .rrrrrr: PBTD 11440 10419 10365 4 - %" LNR, L -80 BTC -MOD, Shoe Capacity = 0.0152 Bbls /ft 4.500 3.958 12.6 11525 10490 10436 Sn. Rec_ h■ Comments B1 -14 WO Design 1 WRR /TLH Format Corrections 03/30/00 Badami Unit 2 SWC /PJC Set XXN Plug @ 9667' 08/29/07 API No. 50- 029 - 22874 -00 SWC /PJC Set BPV (Shutdown) 08/30/07 PTD No: 198 -630 4 R. Berube Updates 10/02/12 Last Revised 10 -02 -2012 SAVANT ALASKA • • HA.LLIBiURTDN Alaska District Sales Order No.: 9757994 Well: 81 -14 Customer: SAVANT ALASKA, LLC Slicdine Unit: 10026769 HAL Crew: GRAHAM/512094, CRAIG/446751,EVANS/526159 Mast Truck: 10025846 Pickup: N/A JOB SUMMARY: GRAHAM/512094 SET 4-1/2" K-VALVE © 2164' SLM, 218W MD ( DOME 500 PSI) CRAIG/446751 EVANS /526159 T 1600 IA 150 OA 50 Date Time Description 08/19/12 CONT MIN 15:00 SWING OVER FROM B1 -15 GET PERMIT SIGNED PJSM,LIFT PLAN CONT MIN .108 WIRE, RS, 12' x 1- 7/8" STEM, OJ, LSS 15:16 S/1 WELL, STAB ON 15:25 RIH W/ 41/2" BLB, 3.80" G- RING,BRUSH NIPPLE FOR 20 MINS © 2164' SLM 2189' MD ...POOH 16 :25 OOH STAND BY FOR K -VALVE END MIN 17:00 END 12 HR MIN 17:10 K -VALVE ARRIVES GET READY 17:20 RIH W/ 4-1/2" X-LJNE RUNNING TOOL, 41/2" X -LOCK, X EQU ASSEMBLY, K -VALVE (OAL 43 ", SER # 2398279 -2 DOME 500 PSI) SD c• 2164' SLM , 2189' MD HAND SPANG 20 MIN FELT DOUBLE BOBBLE SHEAR OFF...POOH 18:00 OOH W/ NO K -VALVE BEAGN BLEED K-VALVE WHILE R/D 18:20 CO REP CALL AND SAID STOP BLEEDING K -VALVE DOWN AND RID 3ND TICKE1 19:00 R/D COMPLETE END TICKET 2 ADD HRS • • II HALLIBURTON 1 PO Sr Pressure Gauge Report Savant Alaska, LLC B1 -14 Badami Static BHP Survey June. 15 2012 i. S 1 . I.. I Nit 1 III ' emu This report is based on sound engineering practices, but because of variable well conditions and other information which must be relied upon, Halliburton makes no warranty, express or implied, as to the accuracy of the data or of any calculations c opinions expressed herein. Halliburton shall not be liable for any loss or damage whether due to negligence or otherwise arising out of or in connection with such dab calculations or opinions. • • H A L L I B U R T A N CUSTOMER WELL NO. Savant Alaska, LLC B1 -14 CUSTOMER REP PHONE NO. Erik Opstad 907 - 868 -1258 x104 Bottom Hole Pressure Survey Results FIELD SALES ORDER Badami 9602408 JOB TYPE NETWORK CODE Static BHP Survey AK076507 WELL API PAD/WELL ENGINEER HALLIBURTON REP(S) 50- 029 - 22874 -00 Erik Opstad R. Curtis Duncan Gary Rainey LOG START DATE LOG END DATE June 13, 2012 June 18, 2012 Delta Upper Gauge Lower Gauge Date Time Time SLMD MD TVD TVDss 78425 Sapphire 78458 Sapphire (hrs) Press. (psia) Temp. Press. (psia) Temp. 06/15/2012 08:16:31 0.74 0' SLMD 54' MD 54' TVD -0.20 TVDss 2103.91 53.97° F 2104.96 49.03° F 06/15/2012 08:30:12 0.97 1,000' SLMD 1,054' MD 1,051' TVD 996' TVDss 2203.12 34.58° F 2205.34 34.33° F 06/15/2012 08:43:00 1.18 2,000' SLMD 2,054' MD 2,045' TVD 1,991' TVDss 2304.11 32.78° F 2306.33 32.58° F 06/15/2012 08:56:22 1.41 3,000' SLMD 3,054' MD 3,045' TVD 2,990' TVDss 2405.19 43.37° F 2406.86 43.22° F 06/15/2012 09:10:17 1.64 4,000' SLMD 4,054' MD 4,044' TVD 3,990' TVDss 2504.57 53.92° F 2505.68 52.85° F 06/15/2012 09:25:51 1.90 5,000' SLMD 5,054' MD 5,041' TVD 4,987' TVDss 2600.60 67.65° F 2601.18 67.51° F 06/15/2012 09:42:13 2.17 6,000' SLMD 6,054' MD 5,981' TVD 5,926' TVDss 2688.26 84.91° F 2688.77 84.48° F 06/15/2012 10:01:56 2.50 7,038' SLMD 7,092' MD 6,843' TVD 6,788' TVDss 2762.64 101.09° F 2763.10 101.98° F 06/15/2012 10:21:42 2.83 8,000' SLMD 8,054' MD 7,625' TVD 7,571' TVDss 2840.33 117.60° F 2841.17 119.37° F 06/15/2012 10:35:37 3.06 9,000' SLMD 9,054' MD 8,467' TVD 8,413' TVDss 2898.59 134.80° F 2899.45 135.34° F 06/15/2012 10:51:58 3.33 10,000' SLMD 10,054' MD 9,353' TVD 9,299' TVDss 2967.58 155.33° F 2968.73 155.53° F 06/15/2012 11:07:24 3.59 11,000' SLMD 11,054' MD 10,121' TVD 10,067' TVDss 3025.79 171.90° F 3027.13 172.04° F 06/15/2012 11:31:53 4.00 11,100' SLMD 11,154' MD 10,198' TVD 10,144' TVDss 3031.78 171.72° F 3033.18 171.56° F 06/15/2012 11:54:20 4.37 11,000' SLMD 11,054' MD 10,121' TVD 10,067' TVDss 3026.96 172.45° F 3028.10 172.42° F 06/15/2012 12:12:42 4.68 10,000' SLMD 10,054' MD 9,353' TVD 9,299' TVDss 2969.19 157.30° F 2970.30 157.12° F 06/15/2012 12:28:48 4.95 9,000' SLMD 9,054' MD 8,467' TVD 8,413' TVDss 2901.83 137.94° F 2902.28 137.76° F 06/15/2012 12:43:11 5.19 8,000' SLMD 8,054' MD 7,625' TVD 7,571' TVDss 2833.43 121.18° F 2833.79 121.07° F 06/15/2012 12:56:00 5.40 7,038' SLMD 7,092' MD 6,843' TVD 6,788' TVDss 2767.40 105.15° F 2767.58 105.09° F 06/15/2012 13:08:30 5.61 6,000' SLMD 6,054' MD 5,981' TVD 5,926' TVDss 2694.36 87.69° F 2694.55 87.61° F 06/15/2012 13:20:32 5.81 5,000' SLMD 5,054' MD 5,041' TVD 4,987' TVDss 2607.45 70.28° F 2607.79 70.28° F 06/15/2012 13:29:07 5.95 4,000' SLMD 4,054' MD 4,044' TVD 3,990' TVDss 2512.71 56.49° F 2513.36 56.80° F 06/15/2012 13:39:08 6.12 3,000' SLMD 3,054' MD 3,045' TVD 2,990' TVDss 2414.56 45.09° F 2415.71 45.04° F 06/15/2012 13:49:44 6.30 2,000' SLMD 2,054' MD 2,045' TVD 1,991' TVDss 2314.00 34.22° F 2316.20 34.25° F 06/15/2012 13:58:35 6.44 1,000' SLMD 1,054' MD 1,051' TVD 996' TVDss 2214.69 34.11° F 2217.03 33.79° F 06/15/2012 14:10:15 6.64 0' SLMD 54' MD 54' TVD -0.20 TVDss 2114.40 47.33° F 2115.69 47.25° F Comments: TVD & TVDss Correlations were provided by the MWD/Well Planners from Sperry Sun in Anchorage. These correlations are based on the survey that Savant Alaska Provided the Gauge department. Unusual Events: • • • HALLIBURTON CUSTOMER WELL NO. Savant Alaska, LLC B1 -14 CUSTOMER REP PHONE NO. Erik Opstad 907 - 868 -1258 x104 Sequence of Operations FIELD SALES ORDER Badami 9602408 JOB TYPE NETWORK CODE Static BHP Survey AK076507 WELL API PAD/WELL ENGINEER 50- 029 - 22874 -00 Erik Opstad HALLIBURTON REP(S) LOG START DATE LOG END DATE R. Curtis Duncan Gary Rainey June 13, 2012 June 18, 2012 Date Time Description 6/13/2012 8:00:00 Jim Weimer called about gauge availability 8:15:00 Selected tools, programmed with 1 sec. samples, depassified batteries 8:20:00 Begin job log 9:05:00 Handed tools over (un- started) to Jim Weimer to take out to location 6/15/2012 7:45:00 Both Gauges started FBHPS performed as per procedure 15:00:00 Finished 6/16/2012 Gauges delivered to Slickline office Pickup Gauges; download, good data, begin processing job report, redress tools. Savant wants us to correlate the MD to ND /SS - don't have the software to do this in house, asking Sperry for assistance. 6/20/2012 17:00:00 Recd Correlated data for Savant. Process Report & Data, send to engineers. 6/21/2012 9:30:00 Rec'd signed ticket, assemble packet & turn in. • • HALL I B U R T O N CUSTOMER CUSTOMER REP PHONE NO. NETWORK CODE HALLIBURTON REPS) Savant Alaska, LLC Erik Opstad 907- 868 -1258 x104 AK076507 R. Curtis Duncan JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1 -14 9602408 Gary Rainey Pressure Plots Savant Alaska B1 -14 SBHP Survey (78458) 06 -15 -2 Preeuurc Temperature 3001) - .- - -- — 100 2504 - --* ---- fi + _ —140 2000 - f i — +__.__.. 120 -i -- i - 3 - - n m m 1500 I — 1 m m 2 ) - 41 a- - — - R[) 1000 - I . i - — - 60 504 �� _ — - 40 0 1 , - —..i_.,......1 i I II I I I I I I I I I ) 1 I I I I I I I i I I I 4 5 6 Time (hi) . , • • HALL 1 B U R TD N CUSTOMER CUSTOMER REP PHONE NO. NETWORK CODE HALLIBURTON REPIS) Savant Alaska, LLC Erik Opstad 907- 868 -1258 x104 AK076507 R. Curtis Duncan JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1 -14 9602408 Gary Rainey Pressure Plots Savant Alaska B1 -14 SBHP Survey (78425) 06 - Pressure Tcmpc rat urc , 3000 - = - { - — -- - i i i i i — 100 2500 - + * - — -1- - — 140 , i 2uuU -- 4 - 4 — t + 120 -+ CD s n m m i — 100 m R 1500 - — N _ I i T — - t;n 1000 - — t -- - — - 60 500 i - - 40 I 1 t I t I I I I I I I I 1 I I I 0 1 2 3 I I 0 7 Time (ITOO r . e • CUSTOMER CUSTOMER REP PHONE NO. NETWORK CODE HALLIBURTON REINS) HALL 1 B U RTO N Savant Alaska, LLC Erik Opstad 907- 868 -1258 x104 AK076507 R. Curtis Duncan JOB TYPE FIELD WELL NO. SALES ORDER Static BHP Survey Badami B1 -14 9602408 Gary Rainey WELL API PAD/WELL ENGINEER LOG START DATE LOG END DATE 50- 029 - 22874 -00 Erik Opstad June 13, 2012 June 18, 2012 Equipment Specifications DynaMem Pro Specifications I Gauge Serial Number 78425 Calibration Date March 28, 2012 Pressure Rating 15,000 psi Temperature Rating 170 °C / 338 °F Data Points Available 1,000,000 I Sensor Type Sapphire Pressure Accuracy 0.025% Resolution 0.0003% Temperature Accuracy 0.20° F Pressure Drift < 3 psi / year I Housing Material Inconel 718 O.D. 1.25" Length 17.25" III DynaMem Pro Specifications Gauge Serial Number 78458 Calibration Date March 28, 2012 I Pressure Rating 15,000 psi Temperature Rating 170 °C / 338 °F Data Points Available 1,000,000 Sensor Type Sapphire I Pressure Accuracy 0.025% Resolution 0.0003% Temperature Accuracy 0.20° F Pressure Drift < 3 psi / year Housing Material Inconel 718 O.D. 1.25" Length 17.00" • • TAATirE rcw irk‘ PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Opstad Drilling & Well Manager - �.:�'� :. , 4 Savant Alaska, LLC �� P.O. Box 112212 Anchorage, Alaska 99511 -2212 (A Re: Badami, Badami Oil Pool, B1-14 Sundry Number: 312 -115 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 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.Foerster. Chair, Commissioner DATED this / day of September, 2012. Encl. 1 I 0 01-1 , \I11---------IR EC F IVE D C- li c • - I STATE OF ALASKA 1 , ALASKA OIL AND GAS CONSERVATION COMMISSIbN r. APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 : .„!:1,1",r;, , ..i . Commi I 1. Type of Request: Abandon El Plug for Redrill 0 Perforate New Poly 0 Repair Well E :Acp9411rovecl Prograti Suspend p Plug Perforations 0 Perforate p Pull Tubing 0 . - - - - - - . - Time.txte90311 Operations Shutdown': Re-enter Susp. Well 0 Stimulate 0 Alter Casing El Convert to gas supply weft al . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number SAVANT ALASKA LLC Development 0 Exploratory 0 198-063 . 3, Address: 6, API Number Stratigraphic 0 Service El . P.O. Box 112212, Anchorage, Alaska 99511-2212 50-029-22874-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: N/A B1-14 • Spacing Exception Required? Yes 0 No el 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 367011 Badami / Oil Badami 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): 11,525 • 10,490 ' 11,440 10,422 None None Casing Length Size MD TVD Burst collapse Structural Conductor 80' 20" 110' 110' 4,450 psi 1,600 psi Surface 4,498' 9-5/8" 4,533' 4,523' 5,750 psi 3,090 psi Intermediate 10,000' 7" 10,033' 9,334' 8,160 psi 7,020 psi Production Liner 1,666' 4W' 9,848' - 11,525' 9,168' - 10,490' 8,430 psi 7,500 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (11): 11122-11160' 11312-11362 10174 10321 4W' 12.6# L-80 9,680 Packers and SSSV Type: 7"x4'12" HES TNT Pkr Packers and SSSV MD (ft) and TVD (ft): 7"x435" HES TNT Pkr @ 9,652'MD 1 8,992' TVD MCX SSSV in HES X-Nipple MCX SSSV in HES X 0 218eMD 12,179' TVD 12. Attachments: Description Summary of Proposal 151 13. Well Class after proposed work: Detailed Operations Program el BOP Sketch INI Exploratory 0 Development II Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Monday, April 09, 2012 • Oil 0 Gas el • WDSPL. 0 Suspended 0 16. Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Erik Opstad or Mary Rush Printed Name Erik Opstad Title Drilling & Wells Manager Signature 11."'' PA*1 Date 907-868-1258 Tuesday, March 27, 2012 ,, o r "* " v44111/ , COMMISSION USE ONLY ,--- b Conditions of appr•val: Notify Commission so that a representative may witness Sundry Number: 3N2:-.1■ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 55$V rr g', i' 1 cl .„- iv , h .- fii it /-, w i'i-rif ss e 105 i-e 1 e 1 1 1 114' 55,v i--7 t/licie r CO I 14/c 1 l iv bf °P'" Subsequent Form Required: / a - 4 0 4 APPROVED BY Approved by: 6:4 a e 99,6 COMMISSIONER THE COMMISSION Date: 4 i - 7 - / 2._ 0 ORIGINA L 4 84EP 1 0 201i Submit in Du licate q/71/Z ,IP/Lais • • Drill Floor to Sea Level 54.8' Drill Floor to Tubing Hanger 32.3' Tree 4- 1/16" / 5,000 psi - CIW OD ID Weight Length MD TVD Ground Level to Sea Level 19.5' Wellhead 11 "/10,000 psi - FMC inch inch Lbs /ft ft DF ft el 4 -1/2" HES X NIP, ID = 3.813" 4.500 3.813 2189 2170 with MCX SSSV installed (Gas Injection) 1 ° @2215'MD • 9 -5/8" 47# L -80 BTC ID = 8.835" 9.625 8.835 40 4499 4533 4523 A 1 ° @ 4576'MD • 4 -1/2" TBG, 12.6#, L -80 NSCT, .0152 bpf, ID = 3.958" 4.500 3.958 12.6 9657.5 9680 9019 28° @ 6007' MD 41-- 7" 29 #, USS -95 BTC Casing ID = 6.184" @ .0371 bpf 7.000 6.184 29 10000 10033 9334 H 8 7" x 4 -1/2" HES TNT PKR, ID = 3.875" 7.000 3.875 9652 8993 • • 4 -1/2" XN NIP, ID = 3.725" (Note: Min TBG ID) 4.500 3.725 9667 9007 -, 4 -1/2" WLEG, ID = 3.958" 4.500 3.958 9681 9020 7" x 4 -1/2" Liner Hanger Packer, ID = 4.375" 7.000 4.375 9854 9149 7" 29# USS -95 BTC Casing Shoe @ 26° 7.000 10033 9334 l---- 4 -1/2" 12.6# L -80 BTC -M Liner @ .0152 bpf 4.500 3.958 12.6 1677 11525 10490 Peforations 11122' - 11160' [10200 -10260 TVD] @ 40° Frac'd 08 -19.98 Peforations 11312' - 11342' [10308 -10365 TVD] Frac'd 08 -11 -98 Peforations 11342' - 11362' [10365 - 10372 TVD] Frac'd 08 -06 -98 > Max. Point of Deviation 45 ° @ 10,636' MD < 10636 9813 PBTD @ 37° 11440 10419 4-1/2" 12.6# L -80 BTC -MOD @ 0.0152 BPF 4.500 3.958 12.6 11525 10490 No. Rev. by Comments /Date B1-14 1 WRR/TLH Format Corrections 03/30/00 Badami Unit 2 SWC /PJC Set XXN Plug @ 9667' 08/29/07 API No. 50 -029- 22874 -00 3 SWC /PJC Set BPV (Shutdown) 08/30/07 Permit # 1980630 4 RB /EO Savant Post Restart Edits As of 02-15-2012 SAVANT ALASKA - • • Badami Wireline Rig -Up & Pressure Control System SOP - Wireline Setup Typical Pressure Control Ib Slop dank • Secure wf chain. f Wellhouse - Bleed lank '; i Bleed Tank Hoses: f - Line Wiper f I)I)T ham bWWed ream le.s BOP 10 Tank web wbrpcheeks b 3)2' bum hardlieod ham Prtop In Sub 1 so Tawh wilt wiy bocba 5)Flo• Ire Senn Stn. ... Pan speaker Flow beefy ualrenpen line .. 0 g Tanner Lin. • i. Crum .. A f - Grease , r, 7 I/2" how Trance wit from lower Cf m . BOP brancTir{c.lh.hycheis 1 C l 111‘k/. — y (eaearvehe m BOP) f y,�, Grease 6 Head Catcher Note: TriPIe r e me pnn 14ee is 15o r0 be moved lo lbe slop ink and used r 6r Mph pressure Logger Had late after Faun Moline cioarfbt 1sepleRun. Grousdiag Stnps Other Notes: _ 1) rpidon sources 25' from bleed iamb or meib obey =SIP Pressure Hoses 2J F.quipmea should he a Man nm of III from •va bone r L berm wellhead � 1) Dr pu Mould be Sub uld be Bee reach h ...Bolding oer pm ;'.�, ` • Drip Pans 4) Drip ipPaasp5s xal amderallr. mmng opegwipment 1 msod rbme:n/iakdabove. f� 5) lla oaab1y maim drama k orona CnM'Whak aM WbWWeilbouae 1 e Other items to note • Placement of Mein Trader, grounded 10 Triplett. • Fall restraint systems to be utaiaed when cldnbeig and descendi ^g wet house ladders "l f • H2S Personnel moml:ors to be noun at ad limes • Heater trunks ensure these are off the ground as much as possib'e r t • Cranes outrigger pads are clear of snow. ice, and are an a furl surface. Donnage (-3x surface area of the pads themselves) n be used during snowmen conditions to provide larger area tor ' 7 Low r 2 L ine 10 slap tank stability during meltirq conditons IIIMIIMIIII 1 sa"al " • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaoCcr�alaska.aov, doa .aoacc.prudhoe.bavC?alaska.gov, phoebe.brooks(a.alaska.00v; tom.maunder(alalaska.00v OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Badami / ACT / Badami DATE: 12/02/10 OPERATOR REP: Jerry Murphy AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B1 -14 Type Inj. G TVD 8,990' Tubing 3620 3620 3620 3620 Interval 1 P.T.D. 1980630 Type test P Test psi 2247.5 Casing 100 2600 2580 2570 P/F P Notes: AOGCC MITIA to 2500 psi post- injection OA 10 10 10 10 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) I Form 10 -426 (Revised 06/2010) MIT ACT B1-14 12-02-10 • • SAYANT ALASKA Badami Well B1 -14 MCX SSSV Removal, SBHPS & Installation of K -Valve SSSV Proposal Summary & Background Information PTD Number: 1980630 Current Status: Well has been used as a gas injector. This capacity is no longer require. Proposed Work Scope: Remove MCX SSSV located at 2,189' MD (2,162' SLM). Run SBHPS then collect open choke flowing pressure survey at HES X- Nipple to set K -Valve dome V pressure. Install K -Valve thereby changing the well from a gas injector to a gas ?r supply well. Production Rate: N/A Minimum ID: 3.725" thru 4.5" XN NIP at 9,667'MD Last Down Hole Ops: 9/2/2010 HES Pulled 4 -Yz" XN Plug at 9,652'SLM 9,667'MD, HES Set 4 -1/2" MCX (1.563" Bean, 4x 3/16 "Ports) in SSSVN at 2,189'MD 2,162'SLM Latest H2S: No H2S measured at B1 -14 or observed at Badami generally. • Wellbore Fluids Tbg: Produced gas and some paraffin with occasional hydrates. • Gas Lift Mandrels: None. Last MIT December 2, 2010 [Attached] Timing: This work is planned for 04/09/2012. ' Badami Logistics: Coordinate activities with Erik Opstad at Erik.OpstaditSavantAlaska.com, North Slope phone 448 -6010 & Chris Boren [1- 907 - 232 -0639] Chris.Boren@ SavantAlaska.com or Sonny Kula [1- 907 - 315 -4423] Sonny.Kula@ SavantAlaska.com. Page 1 of 6 • • • Procedure to Pull MCX SSSV 1. Hold pre -job safety meeting inclusive of the Savant Drilling & Well personnel, Savant Facility Manager, HES Slickline crew, AES Lead, Control Room Representative and Badami Safety Officer. Attach attendance sign -in sheet to WSR at end of job. 2. Proceed to the Control Room and obtain a Unit Work Permit for the expected work activities as specified in the pre -job meeting and this document. 3. Ensure that communication protocols are well understood including phone and Harmony radio contact numbers. 4. MIRU HES Slickline Unit, Boom Truck, Bleed Trailer, Air Heater and Light Plants as Required. a. Adhere to HES Job Safety Analysis (JSA) guidelines while rigging -up and throughout the job. Should there be any safety questions, STOP to consult with other team members and job supervisors until concerns are addressed. b. Ensure COW cones, barriers and signage has been deployed. c. Inspect tree & flowline connections. Grease and service tree as necessary. d. Verify that wellhead and annulus pressure gauges are in service and working properly. e. RU SSV remote control and test. f. Install & pressure test lubricator to 3,000 psi (follow HES SOP for testing) using diesel. 5. RIH with 3.813" drift to 2189' MD 2162' SLMD lightly tag MCX SSSV. POOH. 6. If any paraffin or hydrate obstructions were encountered on the drift run, it may be necessary to clean the tubing. In that case, using pump -in sub, RU Savant Hot Oil Truck onto HES lubricator and wash the 4 %" production tubing with 180 °F LSD in conjunction with Slickline brushing to remove any paraffin buildup from the surface to "'20 -feet below the 4%" HES 3.813" ID X- Nipple at 2,180' MD. 7. Prior to RIH with MCX SSSV pulling tool, any pressure differential must be equalized above and 4 below MCX. This will be accomplished by jumping lift gas from "B1 -15" to the B1 -14 tubing. 8. Once the pressure above and below the MCX valve has been equalized, RIH with MCX SSSV pulling tool to 2189' MD (2162' SLMD) and latch onto the MCX and remove the valve. POOH. Page II • • Procedure for Bottom Hole Pressure Survey 1. Prepare pressure survey tool and note time that data recorder was activated on WSR. 2. PU pressure survey tool string and hang in lubricator for 5- minutes to establish a surface pressure reference data point. Note time on WSR. 3. RIH with memory gauge tool string to 2000' SLMD. Stop and hold on station for a 5- minute data check. NOTE: Be sure to show Slickline Measured Depth for each 5-minute stop made on final data plot. 4. Continue to RIH stopping every 2000' for a 5- minute check stops until reaching the last check stop at 10,000'SLMD. 5. Having completed the last check stop at 10,000' SLMD, RIH slowly to a depth of 11,250' MD and set the brake. 6. RUN SBHP survey- Record static bottom hole pressure for 15 minutes at this depth. 7. Once the data has been collected, POOH, stopping again at each check station to record data for 5- minutes until reaching the HES X- Nipple at 2189' MD. Stop at X- Nipple and notify the control room to flow the well to the plant for 1 -hour while recording the flowing pressure. Monitor line tension to ensure the gauge is not being pushed up -hole. During the one -hour period set the production choke at 1 /4, 1 /z, 3 /4 & full -open and record the flowing pressure for 15- minutes at each choke setting. When complete POOH into lubricator. 8. Laydown P/T memory gauge tool BHA and confirm good data read. If the data dump is good, expedite delivery of raw data to Halliburton in Deadhorse for processing and proceed with following steps to secure the well and rig down. If the data dump is bad, PU new memory gauge tool and rerun the pressure survey portion of the program. 9. RDMO Slickline Unit, Boom Truck and Other Support Equipment a. RD Slickline remote SSV panel and return control to the Badami Board Operator. b. Take care to catch /cleanup any small drips generated while rigging down the lubricator. c. Move Slickline Unit and Support Equipment to the appropriate staging areas. d. Inspect job site area and tidy up as necessary. Page 3 of 6 • • 10. Slickline Job Closeout: a. Unit Work Permit will be closed out at the well with the Slickline Operator, AES Well Technician, and the Savant Rep. b. Verify with AES Well Tech and Savant Rep that all valves are in the proper position, all caps and plugs are in place, and that the work area is clean and tidy. c. Categorize and coordinate post -job waste disposal with Savant HSE Coordinator or ACS Environmental Specialist. d. Submit any post -job incident reports as may be required (spills, first aid, etc.) e. Turn in job WSR to Savant Representative electronically in PDF format. f. Submit SBHPS data in MS Excel format with data density portrayed at one data set listed for each 30- second interval. Submit a graphical presentation of Time vs. Pressure over period RIH, Static and POOH. Station depths should be appropriately labeled with the corresponding SLD. Present Service Field Ticket for signoff by Savant representative. NOTE: Once Halliburton has received the X- Nipple flowing pressure data from Savant and set the appropriate K -Valve closing pressure, recall the HES Slickline crew to install the K -Valve in the X- Nipple at 2189' MD and test (see following procedure). Page 4 of 6 • • Installation Procedure for K -Valve SSSV Prior to installing K- Valve, put well on production to clean -up until stable. Pump Paraffin Dispersant slug 24- hours prior to setting the valve to help soften and clear paraffin buildup that may be present in the tubing. 1. Conduct well row walk -down with Service Companies. Inspect tree, flow -line connections and gauges. Grease and service tree as required. Record WHP, IAP, OAP and Choke Setting with Gas Lift Rate as appropriate. 2. Hold pre -job safety meeting with Savant Drilling & Wells Group, all Service Company personnel associated with the work plan, Plant Operator Representative, Safetyman and HSE Coordinator. Review the procedure for this work, as well as all other elements as related to safe and efficient operations on the Badami CPF Pad. MIRU Slickline, Crane Unit & Other Support Equipment (Refer to relevant RU /RD Job Safety Protocols) a. Obtain Unit Work Permit from Control Room. b. Insure COW barriers & appropriate warning signage is in place. c. Check PPE for job site personnel & confirm adequate fire suppression equipment and ad hoc spill mitigation supplies are readily available. d. Insure Harmony or other communication protocols are understood & operational between Control Room & Service Company elements. e. RU SSV remote control in Service Company unit and test. f. Pressure test lubricator to 3,000 psig. g. Note & record Slickline measured depth offset to original rig measured depth. 3. If the well has been flowed for some time in order to stabilize and obtain necessary flowing pressure data, we may need to clean the tubing again. In that case, RU Savant Hot Oil Truck onto HES lubricator and wash the 4%2" production tubing with 180 °F LSD using pump -in sub, in conjunction with Slickline brushing, to remove any paraffin buildup from the surface to — 20 -feet below the 4 %Z" HES 3.813" ID X- Nipple at 2,180' MD. Page 5 of 6 • • 4. Once brushed, drift tubing with full -gauge ring from surface to below X- Nipple to ensure that the tubing is free of paraffin or other obstructions. This will also insure that the X- Nipple is clean and ready to receive the new valve. 5. Confirm the K -Valve SSSV dome pressure is set in accordance with specifications called out based on the open choke flowing well pressure data. Generally the valve will be set to close at the observed flowing pressure at the X- Nipple and be open at flowing pressures above the observed flowing pressure, which is created by choking back the well slightly at the surface. a. Set -up lock that fits the Nipple profile for the well and the K -Valve assembly to X -Line setting tool. b. Assemble O -Rings on EQ device and fix to X Running Prong. Assemble XO Equalizing Sub to K- Valve (EQ device will be off seat). 6. RIH with X -Line Running Tool. Check for correct position (top nipple — run in control position). 7. Note and record P/U weight prior to sitting down on Nipple. 8. Lightly jar down to seat packing. Continue to jar down to shear the top pin in the Running Tool. 9. Once the top -pin is sheared, do a pull test to a minimum of 500 - pounds over the P/U weight observed in Step #9 above. Proceed to shear the lower -pin in the Running Tool by jarring up, which will release the Running Tool from the K -Valve assembly along with the XO EQ device on the seat. 10. POOH and inspect Running Tool. 11. RDSSV remote control in Slickline Unit and return control to Badami Control Room and notify Operator that the well is ready to put back on production. RDMO Slickline Unit & Support Equipment a. Return to Control Room & closeout Unit Work Permit. b. Take care to catch /cleanup any drips resulting from lubricator tear -down. c. Inspect job site after pulling Unit away and tidy up as necessary. d. Categorize and coordinate post -job waste disposal with Savant HSE Coordinator or ACS Environmental Specialist. e. Submit any post -job incident reports as may be required (spills, first aid, etc.) f. Turn in job Well Service Report (WSR) to Savant Companyman electronically in PDF format. g. Submit job field ticket to Savant Alaska representative for approval before leaving location. NOTE: Notify AOGCC Inspector @ 1- 907 - 659 -2714 and arrange for him to witness a closure test on the newly installed K -Valve SSSV. Page 6 of 6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Savant Alaska, ) Docket Number: OTH -12 -29 LLC for an exception to the gas -oil ratio ) Conservation Order No. 402C limitations of 20 AAC 25.240(a) to allow ) the Badami Unit B1-14 well to be ) Badami Field produced at more than twice its original ) Badami Unit gas -oil ratio. ) Badami Oil Pool ) North Slope Borough, Alaska ) September 4, 2012 IT APPEARING THAT: 1. By letter dated June 18, 2012, Savant Alaska, LLC (SALLC) requested an exception to the gas-oil ratio (GOR) limitations of 20 AAC 25.240(a) to allow the Badami Unit (BU) B1 -14 well to be produced at more than twice its initial GOR. 2. Pursuant to 20 AAC 25.540, the Alaska Oil and Gas Conservation Commission (AOGCC) scheduled a public hearing for August 21, 2012. On July 10, 2012, the AOGCC published notice of the opportunity for that hearing on the State of Alaska's Online Public Notice website and on AOGCC's website, electronically transmitted the notice to all persons on the AOGCC's email distribution list. On July 11, 2012, the AOGCC mailed copies of the notice to all persons on the AOGCC's mailing distribution list. On July 15, 2012, the notice was published in the Alaska Journal of Commerce. 3. No protests to the application or requests for hearing were received. 4. On August 7, 2012, AOGCC requested that SALLC provide additional information to support its request. SALLC provided the requested information on August 10, 2012. 5. Because SALLC provided sufficient information upon which to make an informed decision, the request can be resolved without a hearing. 6. On August 13, 2012, the tentatively scheduled public hearing was vacated. FINDINGS: 1. SALLC is the operator of the BU and the B1 -14 well, which are located on the coastline east of Deadhorse Alaska, North Slope Borough, Alaska. 2. Conservation Order (CO) 402B defines the Badami Oil Pool (BOP). 3. A GOR limit waiver for the BOP was approved by CO 402A and readopted in CO 402B. AOGCC granted this waiver "...so long as the provisions of 20 AC 25.240(c) apply." Since CO 402B was approved, AOGCC's regulations have been revised, and the previous provisions of 20 AAC 25.240(c) are currently contained in 20 AAC 25.240(b). The GOR { • Conservation Order 402C September 4, 2012 Page 2 of 4 waiver issued in accordance with current regulation 20 AAC 25.240(b) requires an ongoing enhanced oil recovery (EOR) project to be valid. 4. Area Injection Order (AIO) 17 authorized gas injection for EOR purposes in the BOP. 5. The B1 -14 well is the last EOR injection well in the BOP. Cumulative injection in this well is approximately 10.5 BCF. 6. SALLC plans to convert the B1 -14 well from a gas injector to a producer. If this occurs, there will no longer be an ongoing EOR injection project in the BOP and the GOR -limit waiver granted by CO 402B is not valid. 7. The volume of gas presently produced from the BU is not sufficient to provide an adequate supply of fuel gas for the BU production facilities or gas for an EOR injection project. SALLC must purchase gas from BP Exploration (Alaska), Inc.'s Duck Island Unit to operate the BU facilities. 8. There has not been significant EOR injection activity in the BOP since February 2011. 9. Since AOGCC approved AIO 17 in 1998, it has become apparent that the BOP is more highly compartmentalized than originally anticipated. Individual reservoir compartments are too small to be mapped using seismic interpretation, and they are typically isolated from one another. 10. On June 12, 2012, AOGCC granted SALLC a temporary GOR waiver allowing production from the B1-14 well for the purposes of obtaining reservoir and well performance information. CONCLUSIONS: 1. The numerous, isolated reservoir compartments of the BOP prevent implementation of an effective FOR project for several reasons: a. Each compartment requires its own producer- injector pair of wells; b. Since individual compartments cannot be mapped confidently using seismic data, it would be very difficult to place two wells properly within a single compartment, c. The reserves contained in most of the compartments are generally too small to justify the expense of drilling a single well, let alone a producer - injector pair that is necessary for an optimal EOR project. 2. Purchasing gas to operate the BU facilities increases operating costs. Higher operating costs will lead to earlier abandonment of the field and decrease reserve recovery. 3. Converting the B1 -14 well from a gas injector to a producer will make several BCF of gas available to fuel the BU facilities. Additional produced gas will lower operating costs, extend the economic limit of the BU, and increase ultimate recovery. 4. If B1 -14 is converted from a gas injector to a producer, the basis for granting the GOR waiver in CO 402B is no longer valid. • Conservation Order 402C September 4, 2012 Page 3 of 4 5. Regulation 20 AAC 25.240(c) gives AOGCC the discretion to grant —after opportunity for public comment and hearing —an exemption to the GOR limitations of 20 AAC 25.240(a) for reasons other than an ongoing EOR project. 6. Amending CO 4028 to allow a GOR waiver that is not based on an ongoing EOR project will not promote waste and will increase ultimate recovery from the BU. NOW THEREFORE IT IS ORDERED: That Conservation Order 402B be amended to grant an exception to the gas -oil ratio limitations of 20 AAC 25.240(a) that is not based upon an ongoing EOR project, and that the terms and conditions of Conservation Order 402B be reissued as Conservation Order 402(C). The findings, conclusions, and administrative records and amendments of Conservation Orders 402, 402A, and 402B are adopted and incorporated in this decision. The rules set out below now apply to the affected area described in Conservation Order 402 and restated below. Umiat Meridian (C0402) T9N R19E Section 1 T9N R20E Sections 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 14, 15, 16, 17 TION R19E Sections 24, 25, 36 T10N R20E Sections 19, 29, 30, 31, 32, 33, 34, 35 Rule 1 Field Name and Pool (CO 402B) The field is the Badami. Hydrocarbons underlying the affected area and within the herein defined interval of the Canning Formation constitute a single oil and gas reservoir called the Badami Oil Pool. Rule 2 Pool Definition (CO 402B) The Badami Oil Pool is defined as the accumulation of hydrocarbons common to and correlating with the interval between the measured depths of 9,500 feet and 11,500 feet in the Badami No. 1 well. Rule 3 Well Spacing (CO 402B) Nominal 20 -acre well spacing is established for the pool within the affected area. No well bore may be open to the pool with 500 feet of the external boundary of the affected area, or within 700 feet of another well capable of producing from the pool. Rule 4 Administrative Action (CO 402B) Upon proper application or its own motion, the AOGCC may administratively waive the requirements of any rule stated in this order or administratively amend this order as long as the change does not promote waste, jeopardize correlative rights, or compromise ultimate recovery and is based on sound engineering principles. • • Conservation Order 402C September 4, 2012 Page 4 of 4 Rule 5 Gas -Oil Ratio Limitation (Revised This Order) Wells producing from the Badarni Oil Pool are exempt from the gas -oil ratio limits of 20 AAC 25.240(a). DONE at Anchorage, Alaska and dated September 4, 2012. °n. 110 . ...- Daniel T. Seamount, Jr. i . , K. o rm Commissioner . rn , ' loner 9rlatq • ` RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05,080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 3105.080(b), "[t}he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." hr computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • sliosE ALAEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 11, 2012 Mr. Erik Opstad Manager, Drilling and Wells „ Savant Alaska, LLC �_ .D - 0 ( P.O. Box 112212 . Anchorage, AK 99511 -2212 Re: Temporary Waiver to Allow Gas Production from Badami Gas Injection ell B1 -14 Dear Mr. Opstad: On June 8, 2012, Savant Alaska, LLC. (Savant) requested a temporary waiver of the gas oil ratio limitations of 20 AAC 25.240 to allow for testing of the gas production potential of the Badami B1-14 well and to ensure that and adequate supply of gas was available at Badami to continue operations while the Endicott facility is shutdown for routine maintenance and repairs. Savant's request is hereby GRANTED subject to the condition listed below. The Badami Unit was originally operated by BP Exploration (Alaska) Inc. (BPXA). BPXA obtained pool rules and an area injection order for the Badami Oil Pool based on its understanding of the reservoir at the time of field startup. The pool rules included a waiver of the GOR limit contained in 20 AAC 25.240 based on an ongoing EOR project and reinjection of produced gas in the pool. Because the reservoir proved to be more complicated than originally anticipated performance did not meet expectations. BPXA shut in the field numerous times over the years due to its poor performance. Over time Savant increased its level of involvement with the Badami field and has now taken over full operatorship from BPXA. Because oil is trapped in individual unconnected pockets within the reservoir structure, the EOR project BPXA originally envisioned, and permitted, did not work as anticipated. Savant has worked to redevelop the field in a manner that is more appropriate for the reservoir. Because of the unconnected pockets, the injection wells did not provide the anticipated EOR benefit, and Savant has converted all but one of the original injection wells to production wells. The Badami B1 -14 well is the last remaining injection well. Injection is minimal due to the fact that the production wells rarely produce gas in an amount in excess of what is necessary to operate the production facilities and gas lift system. However, since this well is still an injection well the GOR waiver provided in Conservation Order 402B (CO 402B) is still valid. Current production at Badami usually provides just enough gas to keep the facility and gas injection systems on line. If there is any production upset Badami needs to obtain gas from • • Mr. Erik Opstad Manager, Drilling and Wells Savant Alaska, LLC June 11, 2012 Page 2 of 3 another source to keep the systems online. Currently the source for extra gas is the BPXA's Endicott field. Since Savant believes the EOR project at Badami is not providing any benefit, it would like to use the as that has been injected into the field over the years as its backup source g injected Y p of gas, instead of the Endicott field, to keep the field up and running when insufficient associated gas is being produced by the oil wells. To this end Savant would like to flow test the Badami B1-14 well during an upcoming planned shutdown of the Endicott facility to see if the well will operate as anticipated and gather reservoir pressure information. However, since the B1 -14 well is the only well classified as an EOR injection well in the field converting it to production will negate the GOR waiver that is in place. As such, Savant has requested a temporary GOR waiver to allow the Badami B1-14 well to be tested during the Endicott shutdown, which is scheduled to begin on June 13 In addition to gathering the test data a temporary GOR waiver will ensure that the Badami field remains on production during the Endicott shutdown. Without the temporary GOR waiver if Badami had any sort of production upset it would likely result in an insufficient amount of gas being available for the production systems at Badami and thus the field would be shut in. Without an alternate source of gas, which would normally be provided by Endicott, the field would have to remain shut in until Endicott resumed production and thus could ship gas to Badami. Based on the need to gather production and reservoir information to support a future GOR waiver request, and the desire to ensure that production from Badami is not impacted by the Endicott shutdown, the AOGCC hereby grants Savant's request for a temporary GOR waiver for the Badami Oil Pool with the following condition: - The waiver is valid starting when Endicott is shut down, which is anticipated to be June 13, 2012, and lasts for 14 days or until Endicott is once again able to ship gas to Badami, whichever is later. DONE at Anchorage, Alaska and dated June 11, 20 10." r 1 I , jjA ._ Daniel T. Seamount, Jr. . N. an Commissioner ommissioner r • • Mr. Erik Opstad Manager, Drilling and Wells Savant Alaska, LLC June 11, 2012 Page 3 of 3 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. application for reconsideration must set out the respect the notice was mailed, then the period of time shall be 23 days. An pp ect in which the order p or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. 4Q2010 Not Operable Injector Rep. • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Attachments: Not Operable Injector Report 402010.zip MANED JUL 1 2D Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: Removed from Quarterly Injection Report: - B1 -14: P d AOGCC MITIA with Badami field restart,.E 1 R -13: Furmanite wrap repaired startinghead leak. - Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. MPL -09: Added until Furmanite clamp is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/5/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, December 08, 2010 Bll l (G'{!C P.I. Supervisor ? SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B1 -14 FROM: Chuck Scheve BADAMI UNIT B 1 -14 Petroleum Inspector Src: Inspector Reviewed By: r P.I. Su ry P NON - CONFIDENTIAL Comm Well Name: BADAMI UNrr B1 -14 API Well Number: 50- 029 - 22874 -00 -00 Inspector Name: Chuck Scheve mitCS1012031 424 / 2010 Ins Num: 5 7 Permit Number: 198 -063 -0 Inspection Date: 12/2 P P Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Blaa ' i Type Inj. G) TVD 8992 IA I 100 2600 2580 2570 - P.T.D 198063 y T peTest SPT Test psi 2248 OA 10 10 10 -- 10 Inter INITAL P/F P ' Tubing 3620 3620 3620 3620 Notes: Wednesday, December 08, 2010 Page 1 of 1 Regg, James B (DOA) • From: Brooks, Phoebe L (DOA) Sent: Thursday, September 02, 2010 11:01 AM ~~~ To: Savant HSE Cc: Regg, James B (DOA) Subject: RE: B1-14 MIT-IA Test 9-1-10 Attachments: MIT BAD B1-14 09-01-10 Revised.xls `~ ~J Page 1 of 2 P~ ~~~ ((~~ \f~ Thank you for sending the Excel file. I've attached a revised report with the following changes: the Test psi field should have included a formula to calculate 25% of the TVD, I've added the formula back; the interval field was changed to 4 (versus a) and the P/F field was changed to P (versus 4). Also, the file naming convention should include MIT Well Name (or Pad if multiple wells on one report} mm-dd-yy (ex: MIT BAD 61-14 09-01-10). If you have any questions please let me know. Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phane:907-793-1242 Fax: 907-276-7542 n; ~, ~'~ ~I~~:l2 From: Savant HSE [mailto:savanthse@gmail.com] Sent: Thursday, September 02, 2010 10:00 AM To: Brooks, Phoebe L (DOA) Cc: Regg, James B (DOA) Subject: Re: B1-14 MIT-IA Test 9-1-10 Phoebe, Here is the excel file with the AOGCC Rep field left blank. Thanks for the guiding me through my first AOGCC MIT report! Zane On Thu, Sep 2, 2010 at 9:16 AM, Brooks, Phoebe L (DOA) <phoebe.brooks(cr~,alaska.~ov> wrote: Zane, Could you please send this MIT report in an F,xcel format so ~~~e can inrpork the data? Also, ifthe witness is waived, the AOGCC; Rep field. should be left blank. Thank you, Phoebe Phoebe F3rooks Statistical Technician II Alaska Oil and Cias Conservation Commission Phone: 907-793-1242 1~'ax: 907-276-7542 9/2/2010 • • Page 2 of 2 From: Savant HSE [mailto:savanthse~a~gmail.com] Sent: Thursday, September 02, 2010 8:49 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: Erik Opstad; Gary Hammon; Savant HSE Subject: B1-14 MIT-IA Test 9-1-10 All, Attached is the AOGCC form for MIT-IA performed on 9-1-2010 to B1-14. John Crisp waived the witness until the Badami Facility is restarted and the well is on injection. Please let me know if you require any other information. Regards, Zane Zane Henning Savant HSE Coordinator Anchorage Cell (907) 240-0637 HSE Slope Cell (907) 448-6013 Harmony Radio (907) 758-5505 ID# 5505 email - SavantHSE(a,~mail.com Alternate: Rob Crotty Zane Henning Savant HSE Coordinator Anchorage Cell (907) 240-0637 HSE Slope Cell (907) 448-6013 Harmony Radio (907) 758-5505 ID# 5505 email - SavantHSE(a,~mail.com Alternate: Rob Crotty 9/2/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg(r~alaska.gov: doa.aoacc.orudhoe.bav@alaska.gov; phoebe.brooks~alaska.gov; tom.maunder(rDalaska.aov OPERATOR: Savant Alaska LLC ~rZ~r °~ t ~ ~ i f'C FIELD /UNIT /PAD: Badami/ BAD/ Badami DATE: 09/01 /10 OPERATOR REP: Gary Hammon AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B1-14 ~ Type In'. G ND ~ 8,990' Tubin 1,500 1,920 1,920 1,920 1,920 1,920 Interval 4 P.T.D. 1980630 Type test P Test si ` 2247.5 Casin 150 '2,550 2,490 2,480 2,470 ' 2,470 P/F P Notes: MITIA to 2550 psi for AOGCC and Badami restart OA 0 350 350 350 300 300 Pum ed 3.0 bbls of diesel to test ' Well T pe In'. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover 0 =Other (describe in notes) Form 10-426 (Revised 06/2010) MIT eAD B1-ta os-ol-lo Revised.xls NOT OPERABLE: Injector B1 -14 (PTD #1980630) Defer Compliance Testing due to Sh... Page 1 of 1 • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellIntegrityEngineer @BP.com] Sent: Monday, April 12, 2010 9:54 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Sauve, Mark A; Oakley, Ray (PRA); NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); END /BAD Area Manager; BAD, Operations Lead Tech Subject: NOT OPERABLE: Injector B1 -14 (PTD #1980630) Defer Compliance Testing due to Shut -In Well All, Injection well B1 -14 (PTD #1980630) is due for an AOGCC MITIA for compliance testing on 4/27/10. Given the well has not been on injection since August 2007 and is now secured with a TTP, the well has been reclassified as Not Operable. An AOGCC MITIA will not be conducted for compliance testing at this time. An AOGCC MITIA will be required to return the well to injection. Please let us know if you have any questions. Thank you, Anna Dube, P.E. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 7/5/2011 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Re11 5( ZIO(p DATE: Monday, May 01,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC BI-14 BADAMI UNIT BI-14 Src: Inspector \o~ c.t,'O \f\ Reviewed By: P.I.Suprv~ Comm FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Well Name: BADAMI UNIT BI-14 API Well Number 50-029-22874-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060428111813 Permit Number: 198-063-0 Inspection Date: 4/27/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i B1-14 ¡Type fnj.] G ! TVD i 8990 I IA I 720 I 2550 i 2470 i 2470 ! ! P.T. I 1980630 iTypeTest! SPT i Test psi I 2247.5 ! OA ! 240 430 I 430 430 ¡ i I Tubing i 5050 5050 I 5050 i 5050 I I Interval 4YRTST P/F P I I Notes 2.2 bbl's pumped, well stabilized quickly. Good test by Grant. t.:;;.t-' f1 W\.1\¡¡'ili::~) \;~~Ó~8\ t~r¡.;,", I] ~ 20D5 Monday, May 01, 2006 Page I of I RE: Badami B 1-14 MIT e a.3 Hi Jim. Please feel free to contact Anna or I any time you have a question regarding who does a particular task in BP. We are the contacts for all UIC program operational questions (i.e. MIT forms). Harry Engel takes care of the "bigger picture" policy-type issues. Attached is an MIT form for the Bl-14 MIT conducted 10/S/0S. It passed. Sorry about the delay. Timing for the Bl-14 MIT sounds good. Please let me know if you have any questions. Joe 6S9-S102 "¡ c; 2X} (\ r) .1 {/ . '''1,,1; Ü. - - - - -Original Message- - - - - SGt,~.~I\X;"" f From: James Regg [mailto:jim regg@admin.sLate.ak.Ùs] Sent: Monday, April 10, 2006 12:SS PM To: NSU, ADW Well Integrity Engineer Cc: Bob Fleckenstein Subject: Badami Bl-14 MIT Hope you are the right contact. MIT for Well Bl-14 was apparently done as required before restart back in October 200S - we did not witness and have not received a copy of the test report. Please send a report for our files (copy to Bob Fleckenstein and myself). Thank you. Also, the Commission will witness an MIT on or about 4/28/06 when inspector next travels to the location. I believe Lou Grimaldi has worked this out with Badami personnel. Jim Regg AOGCC Content-Description: MIT BAD Bl-14 lO-05-05.xls MIT BAD Bl-14 lO-05-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of! 4/10/20064: 10 PM e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION \ \ Mechanical Integrity Test ~ I>c \0 ~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.uS;Jim_Regg@admin.state.ak.us;Tom_Maun1~dmin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Badami I Badami I B1 1 0105/05 Anna Dube \ o..f/,- oltJ 7J Packer Depth Pretest Initial 15Min. 30 Min. We1l1B1-14 I Type Inj. I G TVD I 8,990' Tubing 4,650 4,550 4,560 4,560 Interval I P.T.D.11980630 I Type test I P Test psi! 2248 Casing 500 2,590 2,590 2,590 P/FI P Notes: For well re-start OA 20 20 20 20 Weill I Type Inj. I , TVD , Tubing Interval P.T.D.I I Type test I , Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 , TVD I Tubing Interval! p.T.D.1 I Type test I , Test psi' Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval I p.T.D·1 I Type test I Test psil Casing P/F Notes: OA Weill I Type Inj. TVD I Tubing Interval I p.T.D·1 I Type test Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT BAD B1-14 10-05-05-1.xls / Re: Badami trip ) ) PïD::t.t- I qß- t% 3 S~~Ject:.~ê:>~~~~it~ì~ ..< ...... .... .... ·....i.( ..' ... ........ ...... E.......r.............o.·..... m.·............·.:.·..·.J. a......m....... .e.....s.....··...R.·....·..e.·.. g.....g... ....<....Jim....· .. Jl".e.g... g... ..@......a......d.fu....·.............l.·P..,.s.t. ..a.,. ..t.... e;ª:k.·.<.µ.....s~. '":. "":"" .." . ....:..:......:.". :"". . .". .".. ...... . .". : :.:.:-.:..:...... '". :.. :.., ":":.:..:", Dªte·:··l\4:QP,·.J7··09r~9051~¡:2.~.·:5$···~()~.9q,·......: .}i<Liîi~l~ :~i~~!~ ',...::...... ::." .................. :..........,..:....::..::., Not concerned about B1-01 - that is the Class 1 disposal well. Last MIT on Bl-14 was 3/28/02; well has been shut in 2 years (since Aug 2003). I think an MIT is appropriate. This is my call; regulations and AIO 17 are silent on testing an injector after SI for extended period of time. Passing the test would restart the 4 year clock. Jim Lou Grimaldi wrote: Hi Jim, I will be going to Badami tomorrow at 13:45 and returning Thursday morning, no flights on Wenesday and rest of week pretty busy for them. I will be doing SVS and meters while there. They have injectors B1-01 and Bl-14 online, do you need any work done on them? Lou .'....-~~.. ~E[)I NOV 1 tt¡ 2005 1 of 1 10/17/20054:22 PM STATE OF ALASKA ALASKA (_,-:_~..,ND GAS CONSERVATION COMi~.~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate ~ Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Converted to Gas Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 1670' NSL, 73' WEL, SEC 5, T9N, R20E, UM At effective depth 3192' NSL, 2990' WEL, SEC 3, T9N, R4E, At total depth 2137' NSL, 162' WEL, SEC 5, T9N, R20E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11525' feet 10490' feet 11440' feet 10422' feet Plugs (measured) Junk (measured) 5. Type of well: i--I Development [] Exploratory [] Stratigraphic [~:] Service 6. Datum Elevation (DF or KB) KBE = 54.2 7. Unit or Property Name Badami 8. Well Number B1-14 9. Permit Number / Approval No. 98-63 10. APl Number 50-029-22874 11. Field and Pool Badami Field/Badami Oil Pool ORIGINAL Casing Length Size Structural Conductor 74' 20" Surface 4499' 9-5/8" Intermediate 10000' 7" Production Liner 1677' 4-1/2" Cemented 260 sx Arctiset 3870 sx PF 'E', 340 sx Class 'G' 200 sx Class 'G' 220 sx Class 'G' MD 110' 4533' 10033' 11525' TVD 110' 4523' 9334' 10490' Perforation depth: measured 11122'-11160'; 11312'-11362' true vertical 10119-10149'; 10267'-10306' Tubing (size, grade, and measured depth) 4-1/2' 12.6# L-80 @ 9681' Packers and SSSV (type and measured depth) Packer @ 9651' SSSV @ 2188' 13. Stimulation or cement squeeze summary Intervals treated (measured) Converted from Producer to Gas Injector on 12/8/98 Treatment description including volumes used and final pressure 14. Prior to well operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 15. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run Ii F~ C)il [---I (~ [~l .~l iqnCnriCH [] Daily Report of Well Operation// I.,¢~, ......... ~' ...... 7. I hereby ceCf~th.¢ the_,f, orego,~g is true and/~r~ect to the best of my knowledge Signed ~"~~ / .~,,~_~'//~ MI 'f .4 _ Title Technical Assistant IV Prepared By Name/Number: Service Gas Injection Date Form 10-404 Rev. 06/15/88 Submit In Duplicate BP EXPLORATION, Alaska Date: 1-20-98 Trans# 90169 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 Sw Name ~ec TyPe Rec Date Company Code Comments B1-14 DISK 27-Apr-98 ATLAS MULTIPLE ARRAY ACOUSTILOG - LAS FORMAT B1-21 DISK 05-Jan-98 ATLAS · MULTIPLE ARRAY ACOUSTiLOG - LAS FORMAT Please sign and return one copy of this transrnitt_~.' Carla H. Mclntosh ~~:~'~~/~/~ Petrotechnical Data Center LOG DATA AOGCC - 1 disk Howard Oakland PETROFINA 1 disk Mike Engle I I DNR - 1 disk Tim Ryherd ~ (~) RECEIVED JAN 21 lg99 Naka0il&GasCons.~n Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-5-98 Trans# 89595 BADAMI CASED 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 Trans Num Sw Name Log Type Rec Date Company Code Run Num Api Num 89595 B1-14 STATIC 21-Aug-98 ATLAS 4 500292287400 89595. B1 - 16 STATIC 20-Aug-98 ATLAS I 500292288000 1.4~c. 89595 B1-11 PFC 07-Aug-98 ATLAS I 500292282900 Please sign and return one copy of this transmittal to: Carla Harris ~ ~ Petrotechnical Data Center LOG DATA AOGCC- 1 blueline/1 sepia PETROFINA 1 blueline/1 sepia DNR - 1 blueline BP - - 1 blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh RECEIV[. ' OCT 06 199i-'-' Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 10-5-98 Trans# 89627 BADAMI CASED 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 Trans Num Sw Name Log Type Rec Date Company Code Run Num Api Num 89627 B1-15 SPINNER/TEMP 09-Sep-98 ATLAS 1 500292287800 89627 B1-14 PFC 14-Sep-98 ATLAS 1 500292287400 89627 B1-16 PFC 15-Sep-98 ATLAS 1 500292288000 89627 B1-16 PFC 04-Sep-98 ATLAS 1 500292288000 89627 iB1-21 SPINNEPJTEMP 09-Sep-981 ATLAS 1 500292280900 89627 iB1-15 GAS LIFT SURVEY 09-Sep-981 ATLAS 1 500292287800 89627 B1-21 PFC 05-Sep-98i ATLAS 1 500292280900 LA~ (.,89627 ! B1-11 PRODUCTION LOG 13-Sep-98! ATLAS 1 500292282900 Please sign and return one copy of this transmittal to' Carla Harris Petrotechnical Data Center _ . Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh LOG DATA AOGCC- 1 blueline/1 sepia PETROFINA 1 blueline/1 sepia DNR - 1 blueline BP-- I blueline OCT 06 1998 AJasi',,a O~ & Gas Cons. .~nch0raa~e Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA '.~ .~. AND GAS CONSERVATION COM-~,JSSION 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 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 1670' NSL, 73' WEL, SEC. 5, T9N, R20E, UM At effective depth 2087' NSL, 152' WEL, SEC. 5, TgN, R20E, UM At total depth 2137' NSL, 162' WEL, SEC. 5, T9N, R20E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11525 feet 10490 feet 11440 feet 10422 feet Length Size Structural Conductor 80' 20" Surface 4498' 9-5/8" Intermediate 10000' 7" Production Liner 1666' 4-1/2" Plugs (measured) Junk (measured) 6. Datum Elevation (DF or KB) KBE = 54.2' Type of well: [~ Development [~ Exploratory [.~tratigra~c ~ervice ~v~ 7. Unit or Property Name Badami Unit 8. Well Number B1-14 9. Permit Number / Approval No. 98-63 10. APl Number 50-029-22874 11. Field and Pool Badami Field / Badami Oil Pool Cemented Anch0mg~ MD TVD 260 sx Arcticset I (Approx) 110' 110' 3870 sx PF 'E', 340 sx Class 'G' 4533' 4523' 200 sx Class 'G' 10033' 9334' 220 sx Class 'G' 9848'-11525' 9168'-10490' Perforation depth: measured true vertical 11122'-11160', 11312'-11362' 10174'-10203', 10321'-10360' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 9680' Packers and SSSV (type and measured depth) ORIGINAL 7" x 4-1/2" HES TNT Packer at 9651 '; HES HXO SSSV landing nipple at 2188' 13. Stimulation or cement squeeze summary Intervals treated (measured) 11136'- 11156'; 11338'- 11358' Treatment description including volumes used and final pressure Hydraulic propped fracture, placed 101,000# sand behind pipe. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation: Subsequent to operation: 673 336 5. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I [] Oil ~,Gas E] Suspended [] Daily Report of Well Operations 7' I hereby certify that/thleo~.g°ing ~rue and c°rrect t° the best °f mY kn°wledgeSigned Bill Turnbull ~ Casing Pressure Tubing Pressure Service Title Sr. Petroleum Engineer, ENS Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Date fi I~--"~ !O~ -L~ Bi//Turnbull, 564-4662 Submit In Duplicate BADAMI, ALASKA TO: Mark Sauve FROM: Pat Collins Well Name: B1-14 Main Category: FRAC Sub Category: Frac Peff Operation Date: 9/14/98 B1-14 Frac Perfs Date: I 9/14/'?~ J Reperforated 40 ft with big hole charges for the upcoming frac. Perforated Run 1 11338 - 11358 ft md bkb, 20 ft gun Unable to RIH against 4800 psi WHP. Rigged up jumper line from B1-16 to B1-16 with HB&R 1%" hardline. Bleed WHP to 2500 psi and RIH. Tie in and shoot Run 1. WHSIP had increased to 4000 psi by the time we shot. WHP 4400 psi when OOH. Perforated Run 2 11136 - 11156 ft md bkb, 2x10 ft guns. Bled WHP to 2500 psi to RIH. WHSIP had increased to 3800 by the time we shot.. WHP still 3800 psi when OOH. Comments: The intervals were perforated with deep penetrating charges. Tie in log/date: SBT 8/4/98 TD Tag: TD not tagged Charge Type: Big hole charges ....... Interval Measured Depth ......... Top Ff. Base Ft. Gun Dia. Shot Density Orientation Phasing 11136 11156 2 3/,,, 6 spt random 60 degrees 11338 11358 2 ~" 6 spt random 60 degrees Page I '- BP EXPLORATION (ALASKA)INC. Badami TO: Mark Sauve FROM: Pat Collins DATE: September 19, 1998 RE: B1-14 FRAC SERVICE CO'S.: Dowell, Halliburton, Peak, HB&R JOB SUMMARY Pumped a 400 bbl data frac. Analysis gave a leakoff of .0028. The job was redesigned for 140 Mlbs 20/40 CL. Pumped 101 Mlbs to the formation, left 1 Mlbs in the tubing. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 20 100 20 4600 3400 180 .77 DATA FRAC Bbls Bbls XL gel Time XL gel Final STP, ISIP, psi NWB Treat grad, Pumped to Perfs on perfs psi friction, psi psi/ft 400 400 20 4500 3480 0 .77 DATE/TIME OPERATIONS SUMMARY 9/18/98 07:00 Haul and heat seawater. Repair additives meter pickups. Repair turbine motor. Load sand. Rig tree saver from B1-16 to B1-14. 9/19/98 05:30 Hold PJSM 06:00 Check area. 06:30 Test fluids. 07:45 Prime turbines. Page 2 "- --' TIME RATE BPM PUMPING SUMMARY COMMENTS ANNP WHP STAGE CUM J PSIG PSIG BBL BBL I INJECTIVITY TEST DISPLACEMENT = 200 BBLS 07:45 0 2500 0 0 0 Pressure test to 11,000 psi. Prime turbines. 08:31 10 " 4550 0 Open well. $1WHP 4550 psi. Displace the tubing to seawater at 10 bpm. .... 5820 10 " 6250 25 " 5720 50 " 3800 5350 75 Annulus pressure rising quickly. Up to 3800 psi. " 4070 4870 100 " 4160 4500 125 " 4260 4130 150 Drop back rate to between 0 and 3 bpm. Set tree saver. 08:54 3 170/0 Well displaced to perfs. Start xiinked fluid at 10 bpm. 10 3910 25 " 3860 60 Xlink time 4 mins. Gel looks good. " 3890 10 X link 4 mins. " 4350 100/0 Switch to linear gel. Annulus pressure starting to fall. " 3000 4340 25 Annulus down to 2600 psi. Bump up to 3000 psi. 30/0 Switch to seawater 09:08 5 2560 4175 10 Slow rate to 5 bpm. Annulus down again. Ice plug? 20 4900 40 Increase rate to 20 bpm " 2690 4880 70 " 2750 4860 95 " 2790 4720 120 09:19 " 2750 4600 148 448 Xlinked overdisplaced to perfs. Shut down. I$1P 3400 psi. NWBF 180 psi. Monitor decline. 09:50 Investigate annulus behaviour. The speed with the pressure rose on initial pumping of warm fluid implied a small annulus volume open, suggesting an ice plug. This would also explain the sudden drop and the nudges. No communication between tubing and annulus. Check all surface valves. There was some leakpast of the popff, but not near enough to explain the magnitude of the drop. Bleed back and pressure up to check volumes (3.5 bbls to 4000 psi). Go up to 5500 psi and do annulus MIT. All seems OK. 12:30 Prime turbines. Isolate popoff from annulus. . Page 3 - '---~ DATA FRAC 12:30 0 2500 2210 0 0 Prime up pumps. SIWHP 2210 psi. HB&R pressure annulus to 2500 psi. 12:47 10 " Start xlink at 10 bpm. Activator added at 4 gptg. " 3990 50 X link 5 mins. Gel looks good " 4370 100 X link 5 mins 5 4750 140 Slow to 5 bpm. 13:07 20 3500 5220 170 Annulus has increased to 3500 psi. Gel at perfs. Bring rate up to 20 bpm " 5450 200 " 5230 250 " 3600 4840 300 Annulus steady at 3600 psi. " 4940 400/0 Switch to linear gel " 30/0 Switch to seawater " 3600 4950 20 Annulus steady " 4890 70 " 4650 120 13:27 " 3600 4500 148 578 Data frac overdisplaced to perfs. Shut down. ISIP 3480 psi. Monitor decline. Page 4 ...... ' .... FRAC 19:00 Data frac gave a leakoff of .0028. Redesigned job for 240 bbl pad and 140 MIbs proppant. Transfer extra fluids. 20:00 Prime pumps 20:10 10 2400 2010 0 0 $1WHP 2010 psi. Start pad down tubing at 10 bpm. " 2580 3950 50 Xlink time 4 mins. Good gel " 3220 4440 100 Xlink time 4 mins. Annulus pressure rising as expected. " 3090 4720 150 Annulus pressure dropped from 3500 to 2700 psi quickly. Ice plug again? Bring it up to 4000 psi. 20:26 20 4050 4880 170 Pad on perfs. Increase rate to 20 bpm. " 3980 5250 200 " 4000 5450 240/0 Start 1 ppg stage " 5420 50 " 5630 100 " 5710 150 Still building WHP. " 5700 170 1 ppg on perfs. Bring annulus to 5000 psi. " 4510 5680 200 WHP turning down. " 5000 5630 240/0 Start 2 ppg stage " 5610 31/0 Start 3 ppg stage " 5510 47/0 Start 4 ppg stage " 5080 5279 59/0 Start 5 ppg stage " 5030 5030 50 " 5040 4930 73/0 Start 6 ppg stage " 4810 50 " 5060 4810 78/0 Start 7 ppg stage " 4730 50 " 4710 87/0 Start 8 ppg stage " 5020 4630 50 " 4530 95/0 Start 9 ppg stage " 4320 50 " 4210 101/0 Start 10 ppg stage 21:13 " 4240 52/0 Start flush. WHP starting to turn. 141.4 Mlbs away. Start to slipstream diesel. " 5040 4820 50 " 5050 5200 100 " 4890 5450 165 Proppant underdisplaced 5 bbls to top perfs. SD. I$1P 3800 psi. Monitor decline. Closure at 3450 psi. 23:00 " 1268 Secure area for the night. Page 6 OPERATIONAL PROBLEMS PCM was a great asset. Annulus behaved as if there were an ice plug moving down spasmodically. Spent several hours trouble shooting. Watch this annulus carefully during flowback and injection. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 1026 bbls TOTAL: 1268 bbls ADDITIVES Base water seawater was seawater with 17,000 ppi Chlorides J877 (liquid gelling agent) 11.2 gptg J899 (activator) 4 gptg F75N (Surfactant) 1 gptg L10 (Boric acid XL) 2.2 gptg M 275 (bacteriacide) Adomite regain 40 ppt Breker: None in pad J218 0.1 ppt in slurry stages J475 0.5 ppt in 1 - 4 ppg stages in injectivity, data frac and pad 1.0 ppt in 5 -10 ppg stages STATE OF ALASKA ALASKA ~__~ AND GAS CONSERVATION COb~,v'llSSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate . Name of Operator BP Exploration (Alaska)Inc. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 1670' NSL, 73' WEL, SEC. 5, T9N, R20E, UM At effective depth 2087' NSL, 152' WEL, SEC. 5, T9N, R20E, UM At total depth 2137' NSL, 162' WEL, SEC. 5, T9N, R20E, UM Type of well: ¢] Development ~ Exploratory ~l Stratigraphic /~Service 6. Datum Elevation (DF or KB) KBE = 54.2' 7. Unit or Property Name Badami Unit 8. Well Number B1-14 9. Permit Number 98-63 10. APl Number 50-029-22874 11. Field and Pool Badami Field / Badami Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11525 feet Plugs (measured) 10490 feet 11440 feet Junk (measured) 10422 feet ORIGINAL Length Size Cemented Structural Conductor 80' 20" 260 sx Arcticset I (Approx) Surface 4498' 9-5/8" 3870 sx PF 'E', 340 sx Class 'G' Intermediate 10000' 7" 200 sx Class 'G' Production Liner 1666' 4-1/2" 220 sx Class 'G' MD TVD 110' 110' 4533' 4523' 10033' 9334' 9848'-11525' 9168'-10490' Perforation depth: measured 11122'- 11160', 11312'- 11362' true vertical 10174' - 10203', 10321' - 10360' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 to 9680' Anchorage Packers and SSSV (type and measured depth) 7" x 4-1/2" HES TNT Packer at 9651 '; HES HXO SSSV landing nipple at 2188' 13. Attachments [] Description summary of proposal [] Detailed operations pro~lram ~' [] BOP sketch 14. Estimated date for commencing operation September 19, 1998 16. If proposal was ve.rbally approved Name of apl)rover Date approved Contact Engineer Name/Number: Bill Turnbull, 564-4662 15. Status of well classifications as: FL~ Oil [] Gas [~ Suspended Service L~ Titl6 j Prepared By Name/Number: Bill Turnbull, 564-4662 17. I hereby certify that Signed Bill Turnbull true and correct to the best of my knowledge ~ Sr. Petroleum En¢lineer, ENS Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test Apl)roved by order of the Commission ORIGINAL SIGNED BY' ~,9'9.,,,~¢'~~ ~.,~ommissioner Form 10-403 Rev. 06/15/88 }Approval No. j ~.~/~ ? Submit In Triplicate ~ . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REVISED 10/27/98 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-63 398-090 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22874 4. Location of well at surface ............ - - 9. Unit or Lease Name 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UMi:' .................... rW,:~,L:Tm,.',; ~ .; ~.-._-,~-~¢~,,~¢~'-'~'~"'~ ~ Badami Unit At top of productive interval , i -¢/¢¢;~_~ ! ~, ..... ~~[ 10. Well Number ' ,~-.--~. -~~ i [ B1-14 1956' NSL, 131 WEL, SEC. 5, T9N R20E, UM ~ At total depth !----~ ----' -~-_'_u v~;--"' :?~ i (~;' i 11. Field and Pool 2137' NSL, 162' WEL, SEC. 5, T9N, R20E, UM. '*~'~-, '~- ...... ""*'"*-~"' Badami 5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. KBE = 54.2'I ADL 367011 12. Date Spudded4/5/98 113' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 116' N°' °f C°mpleti°ns4/26/98 8/5/98 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11525 10490 FT 11440 10422 FTI [~Yes []No (nipple) 2188' MD 1900' (Approx.) 22. Type Electric or Other Logs Run Star II/CR/CHT, CBL, GR/CCL, MWD, ESS, DIL/BHC, GR, HDIL/MAC/GL, ZDL/CN/GR/CHT 23. CASlNG~ 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 36' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 4533' 12-1/4" 3870 sx PF 'E', 340 sx Class 'G' ~'~ ~.~ ,~..~. _'.¢~ ~ -¥ L_.. ~/' 7" 29# USS-95 33' 10033' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6# L-80 9848' 11525' 6" 220 sx Class 'G' 124. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S,ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" gun diameter, 6 spf 4-1/2", 12.6#, L-80 9680' 9651' MD TVD MD TVD 11312'- 11362' 10321'- 10361' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 140 bbls diesel r"' ! I1"~1 I ~ /t,-1-1-, 27. PRODUCTION TESTI. L) h'! I [./A I h !Date First Production I Method of Operation (Flowing, gas lift, etc.) September 30, 1998I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL 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. 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 Badami Sand A1 10570' 9766' Bottom Badami Sand A1 10780' 9917' Top Badami Sand A5 11225' 10253' Bottom Badami Sand A5 11365' 10363' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledget.,-~ /...' "/" ~'/~ Signed r~,~,~ Mike E. Mille Title Badami Drilling Team Leader Date B1-14 98-63 398-090 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. INSTRUCTIONS GEN£RAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24.' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 -Well Compliance- port File on Left side of folder 198-063-0 MD 1 1525 TVD 10490 _ _ Microfilm Roll / - BADAMI UNIT Bl-14 50- 029-22874-00 BP EXPLORATION (ALASK Completion Date: /5/98 Completed Status: 1-OIL Current: 1GINJ Roll 2 ! -- Name Interval Sent Received T/C/D D 8471 (,_~'/"~' BP STAR OH 6/4/98 6/4/98 D 8850 ~- ATLAS MAC OH 1/20/99 1/21/99 L CDL/CN/GR ~INAL 99~ c~ ~ ~-~ ]~ ~ t~72 Z OH 5/26/98 5/27/98 , L CET FINAL 9300-9840 CH 5 7/21/98 7/24/98 L G~CCL f 11050-11200 [~1 5~Y ~ CH 5 10/5/98 10/6/98 L HDI/MAC ~AL 9920-11523 ~/57 OH 5/26/98 5/27/98 L HDI/MAC-SSTVD ~AL 9929-11523 / OH 5/26/98 5/27/98 L HDI/MAC-TVD reNAL 9929-11523 ~ OH 5/26/98 5/27/98 L MAC ~' BL(C) 9915.11546.5 ~f~ OH 5 5/26/98 5/27/98 L NGP/DG~EWR4-MD ~NAL 4586-11525 ~/l~/~' ~f~?~ OH 5/26/98 5/27/98 L NGP/DG~EWR4-TVD ~L 4576-10490 ~ OH 5/26/98~' }/27/98 L PFC-GR/CCL ~NAL 11170-11410 Il ~.~iq<f cu 5 8/31/98 9/2/98 L PFC-G~CCL ~INAL 11050-11200 Iq ~-~-?*Ig CH 5 8/3~/98 9/2/98 L RST ~AL 7400-7928 8/29/99 CH 5 10/21/99 10/27/99 C _. L SBT ~NAE 8710-10032 ~ ~[5~-}~ g ~{~5- CH 5 5/26/98 5/27/98 L SBT ~INAL 9600-11400 ~ ~¢] ~ CH 5 8/31/98 9/2/98 L STAT PRES SRVY ~ 11150-11312 ~l ~~ CH 5 10/5/98 10/6/98 R SRVY RPT ~RY 0-~1525. O 6/15/98 6/15/98 ,. Z 8461 ~ HDUSBT/ZDL OH 5/26/98 5/27/98 DailyWellOps~fi' '~ ~[t//~[0 Are Dry Ditch Samples Required? yes~ AndRece~--- Was the well cored? yes ~ .... Analysis Description Received~'es--~~'~Sample Set ~- Comments: Tuesday, August 01, 2000 Page 1 of 1 B1-14 '~ DESCRIPTION OF WORK COMPLETED Initial Perforation 08/05/98 SUMMARY The following initial interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 11312' - 11362' MD ADDPERF 08/19/98 SUMMARY The following additional interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 11122' -11140' MD 11140' -11160' MD ADDPERF 09/14/98 SUMMARY The following additional interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 11136' -11156' MD 11338' -11358' MD Performance Enquiry Report Operator BP Exploration Date 23:31, 09 Jun 98 Page The analysis is from - 02:00, 11 Apr 98 - to - 06:00, 22 Apr 98 Programs in Result Table: B 1-14 Well Type Bl-14 Event Bl-14 Event Time From Time To Duration Description E.M.W.(equivalent mud weight) 02:00, 11 Apr 98 02:00, 11 Apr 98 0 hr 0 min Obtained leak off 12.3 06:00, 22 Apr 98 06:00, 22 Apr 98 0 hr 0 min Obtained required level of integrity 14.0 Hole Size MDR 8-1/2 6 Progress Report Facility Badami CPF Well Bl-14 Rig Nabors 28E Page 1 Date 09 June 98 Date/Time 03 Apr 98 04 Apr 98 05 Apr 98 06 Apr 98 07 Apr 98 08 Apr 98 09 Apr 98 10 Apr 98 11 Apr 98 12 Apr 98 13 Apr 98 21:00-06:00 06:00-15:00 15:00-01:00 01:00-05:00 05:00-06:00 06:00-06:00 06:00-06:00 06:00-14:00 14:00-15:00 15:00-18:00 18:00-20:00 20:00-21:30 21:30-22:00 22:00-04:00 04:00-06:00 06:00-13:30 13:30-17:30 17:30-19:30 19:30-21:00 21:00-21:30 21:30-22:00 22:00-01:00 01:00-05:00 05:00-06:00 06:00-09:00 09:00-09:30 09:30-15:00 15:00-19:00 19:00-02:00 02:00-03:30 03:30-06:00 06:00-07:00 07:00-12:30 12:30-13:00 13:00-17:00 17:00-18:00 18:00-19:00 19:00-20:00 20:00-21:00 21:00-23:00 23:00-23:30 23:30-00:00 00:00-02:00 02:00-06:00 06:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-12:00 12:00-12:30 12:30-15:00 15:00-05:00 05:00-06:00 06:00-08:30 Duration 9hr 9hr 10hr 4hr 1 hr 24 hr 24 hr 8 hr lhr 3 hr 2hr 1-1/2 hr 1/2 hr 6 hr 2hr 7-1/2 hr 4 hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 3 hr 4 hr lhr 3 hr 1/2 hr 5-1/2 hr 4hr 7 hr 1-1/2 hr 2-1/2 hr 1 hr 5-1/2 hr 1/2 hr 4 hr 1 hr 1 hr lhr lhr 2hr 1/2 hr 1/2 hr 2hr 4 hr 24 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 1/2 hr 2-1/2 hr 14 hr lhr 2-1/2 hr Activity Rig moved 30.00 % Rig moved 100.00 % (cont...) Commissioned Additional services Made up BHA no. 1 Circulated at 110.0 ft Drilled to 1825.0 ft Drilled to 4010.0 ft (cont...) Drilled to 4586.0 ft (cont...) Circulated at 4586.0 ft Pulled out of hole to 651.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 2520.0 ft (9-5/8in OD) Circulated at 2520.0 ft Ran Casing to 4564.0 ft (9-5/8in OD) Laid down 40.0 ft of Casing Circulated at 4533.0 ft Mixed and pumped slurry - 206.000 bbl Displaced slurry - 343.000 bbl Functioned DV collar Circulated at 2138.0 ft Mixed and pumped slurry - 1160.000 bbl Displaced slurry - 164.000 bbl Rigged down Divertor Held safety meeting Functioned Tubing Mixed and pumped slurry - 200.000 bbl Rigged up BOP stack Tested BOP stack Serviced BOP stack Rigged up BOP stack Tested Well control Rigged up Wear bushing Made up BHA no. 2 Drilled installed equipment - DV collar R.I.H. to 4431.0 ft Circulated at 4431.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Float shoe Drilled to 4616.0 ft Circulated at 4616.0 ft Performed formation integrity test Drilled to 4850.0 ft Drilled to 5845.0 ft Drilled to 5850.0 ft Circulated at 5850.0 ft Pulled out of hole to 2118.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 5850.0 ft Drilled to 6453.0 ft Circulated at 6453.0 ft Pulled out of hole to 2118.0 ft Progress Report Facility Badami CPF Well Bl-14 Rig Nabors 28E Page 2 Date 09 June 98 Date/Time 08:30-09:30 09:30-10:00 10:00-14:00 14:00-06:00 14 Apr 98 06:00-06:00 15 Apr 98 06:00-06:30 06:30-07:20 07:20-07:30 07:30-11:00 11:00-12:00 12:00-13:00 13:00-16:00 16:00-17:00 17:00-19:00 19:00-19:30 19:30-06:00 16 Apr 98 06:00-02:00 17 Apr 98 02:00-04:30 04:30-06:00 06:00-07:30 07:30-12:30 12:30-13:00 13:00-13:45 13:45-14:15 14:15-15:00 15:00-21:00 21:00-21:30 21:30-01:30 18 Apr 98 01:30-02:00 02:00-03:00 03:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-15:00 15:00-16:00 16:00-17:00 17:00-21:30 21:30-23:00 23:00-00:30 19 Apr 98 00:30-01:00 01:00-06:00 06:00-07:00 07:00-18:00 18:00-00:30 20 Apr 98 00:30-00:45 00:45-01:30 01:30-02:00 02:00-02:45 02:45-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-09:00 Duration lhr 1/2 hr 4 hr 16hr 24 hr 1/2 hr 3/4 hr 0hr 3-1/2 hr 1 hr lhr 3hr 1 hr 2 hr 1/2 hr 10-1/2 hr 20 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 5hr 1/2 hr 3/4 hr 1/2 hr 3/4 hr 6hr 1/2 hr 4 hr 1/2 hr lhr 3hr 1/2 hr 4-1/2 hr 1 hr 3 hr 1 hr lhr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 5hr lhr llhr 6-1/2 hr 1/4 hr 3/4 hr 1/2 hr 3/4 hr 1-1/4 hr 1 hr lhr lhr 2hr Activity Pulled BHA Serviced Wear bushing R.I.H. to 6453.0 ft Drilled to 7550.0 ft Drilled to 8725.0 ft Drilled to 8725.0 ft Circulated at 8725.0 ft Flow check Pulled out of hole to 500.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 4533.0 ft Serviced Block line R.I.H. to 8609.0 ft Washed to 8725.0 ft Drilled to 9282.0 ft Drilled to 9966.0 ft Circulated at 9966.0 ft Drilled to 9991.0 ft Drilled to 10042.0 ft (cont...) Circulated at 10042.0 ft Flow check Pulled out of hole to 9445.0 ft R.I.H. to 10042.0 ft Circulated at 10042.0 ft Circulated at 10042.0 ft Flow check Pulled out of hole to 4500.0 ft Flow check Serviced Block line R.I.H. to 9325.0 ft R.I.H. to 10042.0 ft (cont...) Circulated at 10042.0 ft Flow check Pulled out of hole to 4520.0 ft Flow check Pulled out of hole to 837.0 ft Serviced Top ram Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 4500.0 ft (7in OD) Circulated at 4500.0 ft Ran Casing to 10033.0 ft (7in OD) Circulated at 10033.0 ft Held safety meeting Pumped Water spacers - volume 53.000 bbl Mixed and pumped slurry - 41.000 bbl Displaced slurry - 369.400 bbl Cleared Cement head Installed Seal assembly Rigged up Pipe ram Rigged up Pipe ram (cont...) Laid out BI-lA from derrick Progress Report Facility Badami CPF Well Bl-14 Rig Nabors 28E Page 3 Date 09 June 98 Date/Time 09:00-17:00 17:00-18:30 18:30-23:00 23:00-01:00 21 Apr 98 01:00-05:00 05:00-06:00 06:00-15:30 15:30-16:00 16:00-19:00 19:00-20:00 20:00-20:30 20:30-22:00 22:00-23:00 23:00-00:30 22 Apr 98 00:30-01:30 01:30-03:30 03:30-05:00 05:00-06:00 06:00-06:00 23 Apr 98 06:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-01:30 24 Apr 98 01:30-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-11:30 11:30-12:00 12:00-06:00 25 Apr 98 06:00-18:00 18:00-18:30 18:30-02:30 26 Apr 98 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-11:30 11:30-13:30 13:30-14:30 14:30-19:30 19:30-23:00 23:00-00:00 27 Apr 98 00:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-08:00 08:00-12:00 Duration 8hr 1-1/2 hr 4-1/2 hr 2 hr 4 hr lhr 9-1/2 hr 1/2 hr 3 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr lhr 2 hr 1-1/2 hr 1 hr 24 hr 10-1/2 hr 1 hr 1/2 hr 1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/2 hr 18hr 12hr 1/2 hr 8hr lhr 1/2 hr lhr 1 hr 1/2 hr 5 hr 2hr 1 hr 5hr 3-1/2 hr 1 hr 3 hr 1 hr 1/2 hr 1-1/2 hr 2 hr 4 hr Activity Laid out 5in drill pipe from derrick Rigged down Drillstring handling equipment Tested BOP stack Installed Wear bushing Made up BHA no. 6 Singled in drill pipe to 1000.0 ft Singled in drill pipe to 9819.0 ft (cont...) Drilled cement to 9946.0 ft Circulated at 9946.0 ft Held drill (Kick (well kill)) Held safety meeting Tested Casing - Via annulus and string Drilled cement to 10015.0 ft Circulated at 10015.0 ft Circulated at 10015.0 ft Drilled to 10062.0 ft Circulated at 10062.0 ft Performed formation integrity test Drilled to 10455.0 ft Drilled to 10633.0 ft Circulated at 10633.0 ft Pulled out of hole to 10.0 ft Flow check Pulled out of hole to 640.0 ft Pulled BHA Removed Bore protector Made up BHA no. 7 R.I.H. to 650.0 ft R.I.H. to 650.0 ft (cont...) R.I.H. to 10033.0 ft Serviced Block line R.I.H. to 10594.0 ft Washed to 10633.0 ft Drilled to 11108.0 ft Drilled to 11327.0 ft Circulated at 11327.0 ft Drilled to 11525.0 ft Circulated at 11525.0 ft Pulled out of hole to 10033.0 ft R.I.H. to 11525.0 ft Circulated at 11525.0 ft Circulated at 11525.0 ft Pulled out of hole to 650.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Made up BHA no. 8 R.I.H. to 10032.0 ft Washed to 10109.0 ft R.I.H. to 11525.0 ft Circulated at 11525.0 ft Circulated at 11525.0 ft Pulled out of hole to 486.0 ft Progress Report Facility Badami CPF Well Bl-14 Rig Nabors 28E Page 4 Date 09 June 98 Date/Time 12:00-12:30 12:30-13:00 13:00-15:30 15:30-16:30 16:30-21:30 21:30-01:30 28 Apr 98 01:30-02:00 02:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-13:00 13:00-13:30 13:30-16:30 16:30-21:00 21:00-21:15 21:15-23:30 23:30-23:45 23:45-02:30 29 Apr 98 02:30-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-14:30 14:30-15:00 15:00-16:00 16:00-16:15 16:15-16:45 16:45-18:00 18:00-18:30 18:30-20:30 20:30-01:30 30 Apr 98 01:30-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-14:00 14:00-16:00 16:00-16:30 16:30-00:30 01 May 98 00:30-02:00 02:00-06:00 06:00-06:30 06:30-08:30 08:30-11:30 11:30-13:00 13:00-14:30 14:30-16:30 16:30-19:30 19:30-00:00 Duration 1/2 hr 1/2 hr 2-1/2 hr lhr 5 hr 4hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 3-1/2 hr lhr 1/2 hr 3 hr 4-1/2 hr 1/4 hr 2-1/4 hr 1/4 hr 2-3/4 hr 3-1/2 hr 4 hr lhr lhr 2-1/2 hr 1/2 hr 1 hr 1/4 hr 1/2 hr 1-1/4 hr 1/2 hr 2 hr 5hr 2hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr 2 hr 1/2 hr 8hr 1-1/2 hr 4 hr 1/2 hr 2hr 3 hr 1-1/2 hr 1-1/2 hr 2hr 3 hr 4-1/2 hr Activity Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Tested BOP stack Made up BHA no. 9 R.I.H. to 8814.0 ft Serviced SCR R.I.H. to 10033.0 ft R.I.H. to 11525.0 ft Circulated at 11525.0 ft Pulled out of hole to 486.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Held safety meeting Ran Liner to 1639.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 1540.0 ft (2-7/8in OD) Ran Drillpipe in stands to 5500.0 ft Ran Drillpipe in stands to 10033.0 ft Circulated at 10033.0 ft Ran Drillpipe in stands to 11525.0 ft Circulated at 11525.0 ft Held safety meeting Pumped Water spacers - volume 65.000 bbl Mixed and pumped slurry - 43.000 bbl Displaced slurry - 88.000 bbl Circulated at 11414.0 ft Tested Liner Fill pits with Water Circulated at 11414.0 ft Tested Liner Laid down Drillpipe of 2000.0 ft Laid down 3271.0 ft of Drillpipe (cont...) Ran Drillpipe in stands to 9267.0 ft Laid down 1730.0 ft of 4in OD drill pipe Laid down 5994.0 ft of 3-1/2in OD drill pipe Laid down 1533.0 ft of Tubing Serviced Wear bushing Ran Tubing to 9680.0 ft (4-1/2in OD) Installed Tubing hanger Removed BOP stack Removed BOP stack Installed Tubing on landing string Installed Chicksan lines Mixed and pumped 130.000 bbl of treatment Freeze protect well - 75.000 bbl of Diesel Freeze protect well - 65.000 bbl of Diesel Set Permanent packer at 9651.0 ft with 5000.0 psi Rig moved 5.00 % B1-14 Initial Perforation 04/06/98 Badami Sands SUMMARY The following initial interval were perforated using 3 3/8" guns, 6 SPF, zero orientation and 120° phasing. 10660' - 10680' MD Badami Alaska State Plane Zone 3 Badami CPF B1-14 BPXA PDC ORt. GINAL CO:NFIDENTIAL S UR VE¥ REPORT May, 1998 Your Reft AP1-500292287400 Last Survey 26-April-98 Job # AKVC80180 KBE- 54.20' DRILLING C;ERVICE=; ,~, DIVISION or DI~S£~ I~OUST~tlICS, InC. Survey Reft svy171 Badami Measured Depth (ft) 0.00 35.30 110.00 190.50 262.60 371.45 460.93 558.03 642.09 734.37 825.46 918.37 1009.52 1102.12 1193.43 1284.96 1376.96 1468.67 1560.77 1654.24 1745.46 1837.05 1929.53 2021.67 2115.68 2211.68 2305.76 2400.45 2496.38 2591.29 0.000 0.000 0.180 0.280 0.180 0.750 1.800 3.400 5'.600 6.900 7.000 7.000 7.000 7.100 7.700 7.200 7.600 7.500 6.600 5.300 4.900 4.900 4.400 3.500 2.400 1.100 0.300 0.600 0.800 0.400 0.000 0.000 241.900 241.900 325.800 344.3O0 349.4O0 1.400 358.200 0.000 359.1 O0 0.300 5.100 6.600 3.500 1.900 1.500 3.800 1.600 355.300 354.000 357.700 0.200 0.500 2.100 22.600 166.300 193.100 171.100 338.800 Sub-Sea Depth (ft) -54.20 -18.90 55.80 136.30 228.40 317.25 406.70 503.70 587.50 679.23 769.65 861.86 952.33 1044.23 1134.78 1225.54 1316.77 1407.69 1499.09 1592.06 1682.92 1774.17 1866.35 1958.27 2052.15 2148.11 2242.18 2336.87 2432.79 2527.70 Vertical Depth (ft) 0.00 35.30 110.00 190.50 282.60 371.45 460.90 557.90 641.70 733.43 823.85 916.06 1006.53 1098.43 1188.98 1279.74 1370.97 1461.89 1553.29 1646.26 1737.12 1828.37 1920.55 2012.47 2106.35 2202.31 2296.38 2391.07 2486.99 2581.90 Sperry-Sun Drilling Services Survey Report for Bl-14 Your Ref: API-500292287400 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 N 0.00 E 5906424.99 N 363885.84 E 0.00 0.00 N 0.00 E 5906424.99 N 363885.84 E 0.000 0.00 0.06 S 0.10 W 5906424.94 N 363885.74 E 0.241 -0.05 0.21 S 0.39 W 5906424.79 N 363885.45 E 0.124 -0.19 0.19 S 0.67 W 5906424,81 N 363885.17 E 0.344 -0.17 0.48 N 0.90 W 5906425.49 N 363884.94 E 0.655 0.51 2.43 N 1.32 W 5906427.44 N 363884.56 E 1.179 2.47 6.80 N 1.53 W 5906431.82 N 363884.43 E 1.732 6.85 13.40 N 1.60 W 5906438.41 N 363884.48 E 2.633 13.44 23.44 N 1.74 W 5906448.46 N 363884.52 E 1.424 23.48 34.46 N 1.83 W 5906459.48 N 363884.63 E 0.162 34.50 45.78 N 1.89 W 5906470.80 N 363884.78 E 0.157 45.82 56.87 N 1.36 W 5906481.88 N 363885.50 E 0.642 56.88 68.18 N 0.21 W 5906493.16 N 363886.86 E 0.226 68.15 79.89 N 0.82 E 5906504.85 N 363888.09 E 0.789 79.82 91.74 N 1.38 E 5906516.69 N 363888.87 E 0.591 91.65 103.58 N 1.73 E 5906528.53 N 363889.43 E 0.438 103.47 115.62 N 2.29 E 5906540.55 N 363890.20 E 0.347 115.48 126.91 N 2.83 E 5906551.83 N 363890.95 E 1.020 126.75 136,58 N 2.63 E 5906561.50 N 363890.92 E 1.554 136.42 144.65 N 1.88 E 5906569.59 N 363890.32 E 0.456 144.51 152.45 N 1.31 E 5906577.39 N 363889.89 E 0.345 152.33 159.95 N 1.17 E 5906584.89 N 363889.88 E 0.583 159.82 166.29 N 1.20 E 5906591.23 N 363890.03 E 0.977 166.16 171.13 N 1.30 E 5906596.07 N 363890.21 E 1.173 170.99 173.99 N 1.73 E 5906598.92 N 363890.69 E 1.482 173.84 174.58 N 2.13 E 5906599.51 N 363891.11 E 1.439 174.42 173.86 N 2.08 E 5906598.78 N 363891.04 E 0.379 173.70 172.71 N 2.07 E 5906597.63 N 363891.01 E 0.346 172.55 172.36 N 2.05 E 5906597.29 N 363890.99 E 1.258 172.20 'Comment Alaska State Plane Zone 3 Badami CPF Continued... 12 May, 1998 - 16:06 - 2 - DrillQuest Badami Measured Depth (ft) 2687.63 2782.84 2879.49 2974.95 3070.52 3165.92 3261.44 3357.11 3453.09 3548.65 3643.94 3739.39 3835.44 3930,51 4025.59 41:21.11 4217.61 4313.24 4407.07 4502.83 4576.05 4671.26 4766.62 4862.52 4957.78 5052.86 5149.29 5244.80 5340.39 5435.56 Incl. 0.700 0.800 0.100 0,200 0,500 0.9O0 0.900 1.000 1.200 0.900 2.100 1.000 0.800 0,700 0.700 0.900 0.700 0.600 0.700 0.600 0.900 0,400 3,200 5.800 10.00o 11.800 15,300 18,700 17,400 16,300 Azim. 357.000 5.700 358.800 103.400 117.900 98.500 107.500 101.200 108.3o0 219.400 239.000 219.700 190.100 184.700 193.400 197,700 205,400 210.000 186.300 203.200 182.200 48.100 23,900 11,800 16,700 24,700 30.000 30.300 23.200 14.800 Sub-Sea Depth (ft) 2624.03 2719.24 2815.88 2911.34 3006.91 3102.30 3197.81 3293.47 3389.43 3484.98 3580.24 3675.65 3771.69 3866.75 3961.83 4057.34 4153.83 4249.45 4343.27 4439.03 4512.24 4607.45 4702.75 4798.35 4892.69 4986.05 5079.79 5171.11 5262.01 5353.10 Vertical Depth (ft) 2678,23 2773.44 2870.08 2965.54 3061.11 3156.50 3252.01 3347.67 3443.63 3539.18 3634.44 3729.85 3825.89 3920.95 4016.03 4111.54 4208.03 4303.65 4397.47 4493.23 4566.44 4661.65 4756.95 4852.55 4946.89 5040.25 5133.99 5225.31 5316.21 5407.30 Sperry-Sun Drilling Services Survey Report for B1-14 Your Ref: API-500292287400 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 173.26 N 1.90 E 5906598.19 N 363890.85 E 0.357 173.11 174.51 N 1.93 E 5906599.43 N 363890.91 E 0.159 174.35 175.26 N 2.00 E 5906600.19 N 363890.99 E 0.725 175.10 175.31 N 2.16 E 5906600.23 N 363891.15 E 0.257 175.14 175.07 N 2.69 E 5906599.99 N 363891.68 E 0.325 174.89 174.77 N 3.80 E 5906599.66 N 363892.78 E 0.482 174.55 174.43 N 5.26 E 5906599.30 N 363894.23 E 0,148 174.16 174.04 N 6.79 E 5906598.88 N 363895.76 E 0.151 173.73 173.56 N 8.57 E 5906598.37 N 363897.53 E 0.252 173.19 172.67 N 9.04 E 5906597.47 N 363897.98 E 1.821 172.28 171.19 N 7.07 E 5906596.03 N 363895.99 E 1.352 170.87 169.65 N 5.04 E 5906594.52 N 363893.93 E 1,260 169.39 168.35 N 4.39 E 5906593.23 N 363893.25 E 0.519 168.11 167.11N 4.22 E 5906592.00 N 363893.06 E 0.129 166.89 165.97 N 4.04 E 5906590.86 N 363892.86 E 0.112 165.75 164.69 N 3.68 E 5906589.59 N 363892.48 E 0.218 164.48 163.43 N 3.19 E 5906588.34 N 363891.97 E 0.235 163.24 162.47 N 2.69 E 5906587.39 N 363891.45 E 0,118 162.30 161.48 N 2.38 E 5906586.40 N 363891.13 E 0.303 161.31 160.43 N 2.12 E 5906585.36 N 363890.84E 0.225 160.28 159.51N 1.95 E 5906584.44N 363890.66 E 0.549 159.36 158.98 N 2.17 E 5906583.91 N 363890.86 E 1.274 158.83 161.64N 3.49 E 5906586.54N 363892.24 E 2.978 161.44 168.83 N 5.57 E 5906593.69 N 363894.44E 2,871 168.56 181.47 N 8.93 E 5906606.27 N 363898.03 E 4,461 181.08 198.21 N 15.37 E 5906622.89 N 363904.77 E 2.469 197.60 218.19 N 25.85 E 5906642.68 N 363915,61E 3.848 217,23 242.33 N 39.88 E 5906666.57 N 363930.07 E 3.561 240.90 268.71 N 53.25 E 5906692.70 N 363943,91 E 2,671 266.81 294.70 N 62.27 E 5906718.53 N 363953.39 E 2,804 292.50 Comment Alaska State Plane Zone 3 Badami CPF Continued... 12 May, 1998 - 16:06 - 3 - DrillQuest Badami Measured Depth (ft) '\ .~' 5530.48 5625.99 5720.99 5815.49 5911.68 6007.14 6100,40 6196.49 6291.02 6386.01 6482.90 6577.93 6673.72 6788.73 6864.17 6959.97 7055.97 7151.10 7246.63 7342.21 7437.36 7533.51 7628.58 7724.24 7819.73 7915.32 8012.90 8106.15 8201.66 8297.36 Incl. 16.800 16.800 19.600 24.300 26.400 28.100 30.300 32.300 33.100 35.000 34.800 34.800 34.400 34.200 33.700 35.000 34.600 35.200 35.300 35.500 36.300 36.400 35.900 35.200 35.500 35.100 35.200 34.400 34.100 33.500 9.300 8.000 4.700 3.300 2.300 1.800 2.700 5.700 5.600 6.900 5.600 4.600 4.400 5.200 5.100 7.400 7.600 6.300 6.900 5.200 3.800 2.800 3.600 4.200 5.300 4.400 3.700 2.200 2.900 2.500 Sub-Sea Depth (ft) 5444.10 5535.53 5625.77 5713.40 5800.32 5885.18 5966.59 6O48.69 6128.24 62O6.94 6286.41 6364.44 6443.29 6521.78 6600.95 6680.04 6758.87 6836.89 6914,91 6992.82 7O69.89 7147.34 7224.10 7301.93 7379.82 7457.83 7537.62 7614.19 7693.14 7772.66 Vertical Depth (ft) 5498.3O 5589.73 5679.97 5767.60 5854.52 5939.38 6020.79 6102.89 6182.44 6261.14 6340.61 6418.64 6497.49 6575.98 6655.15 6734.24 6813:07 6891.09 6969.11 7047.02 7124.09 7201.54 7278.3O 7356.13 7434.02 7512.03 7591.82 7668.39 7747.34 7826.86 Sperry-Sun Drilling Services Survey Report for Bl-14 Your Ref: API-500292287400 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 321.12 N 67.89 E 5906744.84 N 363959.48 E 1.732 318.72 348.41 N 72.04 E 5906772.05 N 363964.13 E 0.393 345.86 377.89 N 75.25 E 5906801.47 N 363967.87 E 3.140 375.22 413.12 N 77.67 E 5906836.65 N 363970.92 E 5.004 410.35 454.25 N 79.67 E 5906877.74 N 363973.66 E 2.228 451.39 497.93 N 81.23 E 5906921.38 N 363976.00 E 1.797 495.00 543.39 N 83.03 E 5906966.80 N 363978.62 E 2.405 540.37 593.16 N 86.72 E 5907016.49 N 363983.20 E 2.638 589.99 643.98 N 91.75 E 5907067.21N 363989.14 E 0.848 640.62 696.84 N 97.55 E 5907119.96 N 363995.90 E 2.142 693.26 751.94 N 103.59 E 5907174.95 N 364002.92 E 0.795 748.14 805,96 N 108.41 E 5907228.87 N 364008.71 E 0.601 801.97 860.19 N 112.68 E 5907283.01 N 364013.95 E 0.434 856.03 913.54 N 117.16 E 5907336.28 N 364019.39 E 0.519 909.20 966.62 N 121.94 E 5907389.27 N 364025.13 E 0.527 962.10 1020.35 N 127.84E 5907442.87 N 364032.00 E 1.917 1015.60 1074.67 N 134.99 E 5907497.06 N 364040.12 E 0,433 1069.66 1128.69 N 141.57 E 5907550.96 N 364047.67 E 1,005 1123.44 1183.46 N 147.91 E 5907605.60 N 364054.99 E 0.377 1177.97 1238.51N 153.74 E 5907660.54 N 364061.81E 1.051 1232.80 1294.13 N 158.12 E 5907716.07 N 364067.18 E 1.205 1288.25 1351.03 N 161.40 E 5907772.90 N 364071.48 E 0.625 1345.00 1407.02 N 164.52 E 5907828.83 N 364075.62 E 0.723 1400.87 1462.51N 168.30 E 5907884.24 N 364080.39 E 0,818 1456.20 1517.56 N 172.88 E 5907939.20 N 364085.96 E 0.737 1511.08 1572.60 N 177.55 E 5907994.15 N 364091.62 E 0.686 1565.93 1628,64N 181.52 E 5908050.11N 364096.59 E 0.426 1621.81 1681.78 N 184.27 E 5908103.19 N 364100.29 E 1,256 1674.83 1735,48 N 186.66 E 5908156.84N 364103.65 E 0.518 1728.43 1788.66 N 189.17 E 5908209.96 N 364107.11 E 0.669 1781.49 Comment Alaska State Plane Zone 3 Badami CPF Continued... 12 May, 1998 - 16:06 - 4 - DrillQuest Badami Measured Depth (ft) 8393.06 8488.44 8584.07 8679.70 8776.00 8870.39 8964.39 9059.81 9155.48 9251.27 9346.30 9441.83 9537.42 9633.07 9729.11 9824.70 9920.52 9974.76 10057.31 10089.46 10120.86 10152.29 10183.77 10215.89 10246.77 10278.10 10372.55 10466.57 10560.07 10635.96 Incl. 32.900 33,000 32.500 32.100 32.00O 31.600 31.100 30.200 30,000 28.800 28.800 28.300 28.000 27.600 26.200 25.100 25.900 26.300 26,300 28.200 29.900 31.100 32.600 34.000 35.200 36.200 38.600 41.700 44.000 44.900 Azim. 2.400 2.000 1.800 359.700 359.600 359.100 359.300 357.600 357.800 355.700 354.400 354.100 352.600 351.700 348.900 348.000 346.500 346.200 347.500 347.800 348.900 349.300 348.600 349.000 350.000 350.700 351.200 351.600 350.700 349,700 Sub-Sea Depth (ft) 7852.74 7932.78 8013.21 8094.04 8175.67 8255.89 8336.16 8418.25 8501.02 8584.48 8667.75 8751.67 8835.95 8920.56 9006.21 9092.38 9178.87 9227.58 9301.58 9330.16 9357.61 9384.69 9411.43 9438.28 9463.69 9489.14 9564.16 9636.02 9704.56 9758.74 Vertical Depth (ft) 7906.94 7986.98 8067.41 8148.24 8229.87 8310.09 8390.36 8472.45 8555.22 8638.68 8721.95 8805.87 8890.15 8974.76 9060.41 9146.58 9233.07 9281.78 9355.78 9384.36 9411.81 9438.89 9465.63 9492.48 9517.89 9543.34 9618.36 9690.22 9758.76 9812.94 Sperry-Sun Drilling Services Survey Report for Bl-14 Your Ref: API-500292287400 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/'~OOft) (ft) 1841.01 N 191.41 E 5908262.27 N 364110.29 E 0,630 1833.74 1892.85 N 193.40 E 5908314.06 N 364113,22 E 0.251 1885.49 1944.56 N 195.11 E 5908365.73 N 364115.86 E 0.535 1937.11 1995.65 N 195.79 E 5908416.80 N 364117.45 E 1.246 1988.15 2046.75 N 195,47 E 5908467.90 N 364118.06 E 0.118 2039.23 2096.48 N 194.91 E 5908517.63 N 364118.39 E 0,507 2088.96 2145.38 N 194.23 E 5908566.54 N 364118.58 E 0.543 2137.86 2194.01 N 192.92 E 5908615.18 N 364118.15 E 1.309 2186.50 2241.95 N 191.00 E 5908663.14 N 364117.09 E 0.234 2234.47 2288.89 N 188.35 E 5908710.12 N 364115.28 E 1.651 2281.48 2334.50 N 184.40 E 5908755.80 N 364112.15 E 0.659 2327.19 2379.92 N 179.82 E 5908801.30 N 364108.40 E 0.544 2372.74 2424.71 N 174,60 E 5908846.18 N 364103.98 E 0.804 2417.68 2468.90 N 168.51 E 5908890.47 N 364098.69 E 0,606 2462.05 2511.73 N 161.22 E 5908933.42 N 364092.16 E 1.966 2505.09 2552.27 N 152.94 E 5908974.10 N 364084.62 E 1,221 2545.88 2592.50 N 143,83 E 5909014.48 N 364076.23 E 1.073 2586.38 2615.69 N 138.20 E 5909037.77 N 364071.02 E 0.777 2609.74 2651.30 N 129.88 E 5909073.53 N 364063.34 E 0.698 2645.61 2665.68 N 126.73 E 5909087.96 N 364060.45 E 5.925 2660.09 2680.61N 123.66 E 5909102.95 N 364057.64E 5.675 2675.11 2696.28 N 120.64 E 5909118.66 N 364054.91 E 3.872 2690.87 2712.58 N 117.46 E 5909135.02 N 364052.02 E 4.907 2707.27 2729.88 N 114.03 E 5909152.38 N 364048.90 E 4.412 2724.67 2747.12 N 110.84E 5909169.67 N 364046.02 E 4.299 2742.00 2765.14 N 107.77 E 5909187.75 N 364043.28 E 3.448 2760.12 2821.79 N 98.76 E 5909244.55 N 364035.28 E 2.561 2817.03 2881.73 N 89.70 E 5909304.64N 364027.31E 3.309 2877.23 2944.55 N 79.91 E 5909367.63 N 364018.64E 2.545 2940.34 2996.92 N 70.86 E 5909420.15 N 364010.54 E 1.503 2992.98 Comment Alaska State Plane Zone 3 Badami CPF Continued... 12 May, 1998 - 16:06 - 5 - DriilQuest Sperry-Sun Drilling Services Survey Report for B'I-14 Your Ref: API-500292287400 Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 10730.49 43.900 349.500 9826.28 9880.48 3061.97 N 58.92 E 5909485.40 N 363999.77 E 1.068 3058,39 10824.81 42.700 350.500 9894.92 9949.12 3125.67 N 47.68 E 5909549.30 N 363989.68 E 1.465 3122,42 10919.27 41.500 350.300 9965.01 10019.21 3188.11 N 37.12 E 5909611.92 N 363980.24 E 1.278 3185.17 11013.25 40.300 350.200 10036.04 10090.24 3248.75 N 26.70 E 5909672.74 N 363970.91 E 1.279 3246.13 11107.62 39.600 349.200 10108.39 10162.59 3308.37 N 15.87 E 5909732.54 N 363961.16 E 1.007 3306.07 11202.53 39.200 348.800 10181.73 10235.93 3367.50' N 4.38 E 5909791.87 N 363950.73 E 0.499 3365.55 11296.38 38.700 347.600 10254.71 10308.91 3425.25 N 7.68 W 5909849.83 N 363939.70 E 0.964 3423.66 11391.51 37.600 348.800 10329.52 10383.72 3482.77 N 19.71 W 5909907.55 N 363928.72 E 1.394 3481.54 11464.11 37.100 348.100 10387.24 10441.44 3525.92 N 28.52 W 5909950.86 N 363920.68 E 0.904 3524.96 11525.00 37.100 348.100 10435.80 10490.00 3561.86 N 36.10 W 5909986.93 N 363913.75 E 0.000 3561.13 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. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 358.120° (True). qased upon Minimum Curvature type calculations, at a Measured Depth of 11525.00ft., ,- .ne Bottom Hole Displacement is 3562.05ft., in the Direction of 359.419° (True). Comment Projected Survey Alaska State Plane Zone 3 Badami CPF 12 May, 1998 - 16:06 - 6 - DrillQuest STATE OF ALASKA ALASKA .....~iL AND GAS CONSERVATION CO~¢llSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown I~] Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 1670' NSL, 73' WEL, SEC 5, T9N, R20E, UM At effective depth 3192' NSL, 2990' WEL, SEC 3, T9N, R4E, At total depth 2137' NSL, 162' WEL, SEC 5, T9N, R20E, UM [] Stimulate [] Plugging [] Perforate [~]Alter Casing [] Repair Well [--]Other 15.,~,~e of well: [~ Development [] Exploratory I~1Stratigraphic v[~[,,Service 6. Datum Elevation (DF or KB) KBE = 54.2 7. Unit or Property Name Badami 8. Well Number B1-14 9. PermitNumber / A3~INo~] 98-63 10. APl Number 50-029-22874 11. Field and Pool Badami Field/Badami Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11525' feet 10490' feet 11440' feet 10422' feet Length Size Structural Conductor 74' 20" Surface 4499' 9-5/8" Intermediate 10000' 7" Production Liner 1677' 4-1/2" Plugs (measured) Junk (measured) Cemented 260 sx Arctiset 3870 sx PF 'E', 340 sx Class 'G' 200 sx Class 'G' 220 sx Class 'G' MD 110' 4533' 10033' 11525' TVD 110' 4523' 9334' 10490' Perforation depth: measured 11122'-11160'; 11312'-11362' true vertical 10119-10149'; 10267'-10306' Tubing (size, grade, and measured depth) 4-1/2' 12.6# L-80 @ 9681' Packers and SSSV (type and measured depth) Packer @ 9651' SSSV @ 2188' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure Oil & Gas Cons. 6ommiss[o~ Anchorage 14. Prior to well operation: Subsequent t° operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 116. Status of well classifications as: {--]Copies of Logs and Surveys run I [~Oil []Gas i-]Suspended [] Daily Report of Well Operations ~ 17. I hereby certify t~ thCforeg~)t(g is true ap? correct to the best of my knowledge Signed '/'~M ~~W~~.~~/,~~. Title Technical Assistant IV Prepared By Name/Number: Service Form 10-404 Rev. 06/15/88 Date ~:~/~/'~~'~ ]/¢~ Submit In Duplicat~ B1-14 '~ DESCRIPTION OF WORK COMPLETED Initial Perforation 04/06/98 SUMMARY The following initial interval were perforated using 3 3/8" guns, 6 SPF, zero orientation and 120° phasing. 10660' - 10680' MD ADDPERF 09/14/98 SUMMARY The following additional interval were perforated using 2 3/4" guns, 6 SPF, random orientation and 60° phasing. 11136' -11156' MD 11338' -11358' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL [~ Abandon' - [] 8u~nd [] I~lugglng ~-~ l'lm~ Extension [~ berforate ' - 1. Type of Request: L3 Alter Oaring ~ Repair Well E~ Puff Tubing FL~ V~anca ~_J Other [,~ Change Approved Program L~ Oparntion shutdown [] Re-Enter Suspended Wall .~$timulate FRAC Pro.gramme .2. Name of Operator BP Exploration (Alaska) Inc. 3. Address , P.O. Box 196612, Anchorage, Alaska 99519-6612 I4. Location of well at surface 3855' NSL, 128' WEL, SEC. 8, TgN, R20E, UM At top of productive Interval 1670' NSL, 73' WEL, SEC 5, TgN, R20E, UM At effective depth 3192' NSL, 2990' WEL, SEC 3, TgN, R4E, At total depth 2137' NSL,.162' WEL, SEC 5, TgN: R20E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 1.~25' feet 0490' feet 1440' feet 0422' feet 5. Ty~ of we¢l: Development ~ Exploratory f'~ Stratigraphic [~Service RECEIVED SEP 15 1998 AI~sM Oil a Gas 6u,i~. ~ ............ Anchorage Plugs (measured) Junk (measured) 6. Datum Elevation (DF or KB) KBE -- 54.2 7. Unit or'ProPerty Name Badami 8:-W~li N~mb'er B1-14 9.' Permit Number 96-63 10. APl Number 50-029-22874 '11. Field and Pool Badami Field/Badami O11 Pool Length Size Cemented M D 'rVD Structural Conductor 74' 20" 260 sx Arctiset 110' 110' Surface 4499' 9-5/8" 3870 sx PF 'E', 340 sx Class 'G' 4533' 4523' Intermediate 10000' 7" 200 sx Class 'G' 10033' 9334' Production Liner 1677' 4-1/2' 220 sx Class 'G' 11525' 10490' Perforation depth: measured 11122'-1,, 60'; 11312'-11362' true ve~lcal 10119-10149; 10267 -10306 Tubing ,size, grade, and measured depth) Nme of ~pprover contact Engkloer Name/Number: pt'~.oarecl By Name/Number; 17. l hereby certl.~t~j~ fo~..~lng i_s ~ue ~nd correct tO the best of my knowledge Signed .,LL~.:~"~ ~t~-" 4// '"~ Tille Subs~JrfaceMana,-qer, Badami Commission Use Only Conditions of Approval: Notify Commission so representative may witness L Plug integrity _ _ BOP Test ~ Location clearance o~"J Mechanical Integrity Test ~ Subsequent form required 10~~O N T '] CTRf~ Michael Memor~rtdum To: P. Collins/J. P ow ers/M. G oodwin Date: Sep 14, 1998 From: P.Collins AND PE Subject: BADAMI B1-14 Frac Programm~e B1-14 was completed with a 4 ~,~" cemented liner and 41/~,, tubing. Frac equipment will be barged from West Dock to Badami. Seawater will be drawn from the Badami dock and heated by a hot oil truck. The CTU will be barged out after this and B1-16 fracs are done if cleanouts are necessary. PTS frac separator is on location ready for flowback. 1. Reperforate 11338 - 11358 ft md bkb 11136 - 11156 ft md bkb with big hole charges 2. Pump a 300 bbl data frac. 3. Redesign and pump the frac. initial calculations give 150,000 lbs 16/20 proppant. 4. Conduct a CTU cleanout if necessary. 5. Flow the well back through the PTS flowback separator to dean up proppant. The Deviation across the perforated interval is 40°, at an azimuth of 350°. Attachments to this program include: Well completion diagram. Detailed data frac and propped frac program_ Tubing Movement Calculations for Wetl B1-14. RECEIVED ]998 Badami B1-14 Frac proceedure Attention' Bob Thayer /Wes Wilder DO NOT EXCEED 8,400 surface pressure. Pre - Frac Treatment RECEIVED 1. Reperforate 113,38 - 115§@ It md bkb 11136 - 11156 ft md bkb Alaska 0il & (~as Cons. Commission Anchorage Shoot the guns on balance. Perforation should be with 2 ~,4" guns, 6 spf, 60 degree phasing, big hole charges. 2. Pressure test annulus to 5,000 psi. 3. Equipment will be brought out by barge from West Dock. Berm in and rig up equipment. 4. Seawater will be taken from the Badami dock by vac truck. The water should be · pumped into DS tiger tanks via a 3 mm filter and heated by hot oiler to 100 degrees F. Hydraulic Fracturing Procedure Badami A5 & F5 Objective: To create a frac of 250 feet Xfin the Badami A5 and F5 sands. Pump injectivity test and datafrac followed by the main fracture treatment. Rig up and stab tree saver, (4" Cameron tree, 4 1/2" L-80 tubing). The surface pressure is estimated to be 5,000 psi for pad. Azimuth = 350° Deviation = 40° 2,) Pressure test surface lines to 10,000 psi. Expected treating pressure is between 5,000 and 8,000 psi. Observe trip-out of each pump, After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 8,400 psi. 3) Perform injectivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. With gel at the perfs, bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50# linear gel followed by seawater. Over displace all crosslinked fluid into the perfs by 5 bbls. Shut down and monitor the surface pressure for at least 15 minutes. If the near wellbore friction is > 1,000 psi pump a large fluid slug - 50 bbls and flush. Monitor the decline, if near wellbore friction still high, repeat the procedure. Look at both the value and the rate of change of the near wellbore friction, if, required a proppant slug will then be pumped_ Once near weiibore friction is ,-- 500 psi proceed to Datafrac, 4) Perform 300 bbl Data frac with crosslinked fluid: Pump data frac down to perforations at 5 bpm. With gel at the perfs, bring up rate as quickly as possible to 20 bpm. Over displace data frac by 5 bbls. Displace the data frac with 30 bbl 50 # linear gel followed by seawater. Stop pumping and monitor the pressure decline, Transmit the data to Anchorage for interpretation, Discuss closures and leakoff with town, Redesign the TSO, Pump 150,000 lbs fracture treatment at 20 bpm per modified ramp. 7) Freeze protect the tubing with 30 bbls diesel. Table 1 Volumes Volume to Top Perfs Under Flush 172 bbls 5.0 bbls Flush 167 bbls Post -Frac Treatment 1. Determine proppant top with slickline if necessary. 2. If a clean out is necessary, it will be done once B1-16 is also fracced and the frac equipment out of the way, A CTU will be barged from West Dock. Clean out Carbolite per established procedure. An additional programme will be prepared if the operation is necessary. 3, A PTS flowback separator is on location. Flow the well through the separator initially to clean up proppant. RECEIVED Naska Oil & ~as Cons. Commission, Anchorage Tubing Movement Calculations for Well 81-14 Anchored LB0 Tubing 2 Strings Vet 3.2d Pist_~on & Plug Effec_t Balloon/hq Effect ~nt: Total Len b Chon e: 'L_pr = -82,24 inches -L be1 = 16.~2 inches --'-~-~== -5244 psLa (ul~) [ 0 inches -F_pr = -76714 lbs -F_-bal = -15040 lbs 0.0 feet =res.~ure IBucklin~q Temperature Effect F_tp = -86893 lbs (up) tubing -> packer force L hb 0.00 inches L trap -- -27.04 inches F pc = .182546 lbs (up) packer -:> casing force = 1.50 VME St~ing 1 - n = 0 feet F-trnp = 252t8 lbs Minimum Design Factor: Input. all strings (Go to botto-m lot Instructions) Options: ("X" to select) 90 Fin la Surface Temp. (_°F) , -, lied Tubin Y~essure [ps~ -x ~,,v. ...... 00 Final A plied Annular t-ressure Ipsll 50P - - ,o-, 50 Initial Surface ~emperature I r~ I iai A 1,ed Tbg Pressure [psi) ] J 5000 Init' pP' · h I · i~l A lied Ann Pressure [psi) II ' 0 Ifil, PP ,: .... Il ~;,~,';~'~--a~;~ ..... P below plug['----~psia kr setL.~.~ 3.875 Packer seal bore o~ameter [,n~ I · 0 Slackoff (lbs) -Compress., +Tension| Pinned at ] I Lbs [Leave blank for Free Mevemen~ String 2 2: Design Factors at Top and Bottom of Each Stdng 9650 VlD bottom {ft) Anchmed Tubln Floafln 8940 TVD bottom [ft) ns ~,.69 Tens 1.98 Tens 3.45 Tens 4.94 3.958 Tbg I.D. (inl 'st 2.48 Burst 2.12 Burst 2.48 Burst 2.12 4.5 Tbg 0.9. {in} Collop NtA Co/rap N/A Collap N/A Collop N/A 80000 TbgYield (psi) VME 1.50 VME 1,62 VME 2.33 VME 2.24 12.6 Tbg Weight ribs/It) Tens 1.98 Tens 4.99 4.94 Comp 9.87 6.184 Casing I.D. {in] Burst 2.12 ~rst I ,61 zrst 2.1 2 Burst 1.61 12.1 Final lbs/gal tbg Co[hap N/A ~'ollap N/A ~ollap N/A Collop NIh 8.7 1nit/al lbs/gal tbg VME ~.62 VME 1.73 VME 2,24 VME 1.49 8.6 Final lbs/gal ann ,ns I'ens Comp Comp Burst Burst Burst 8.7 Initial lbs/gal ann Bl~rst iCg[lap 110 Final bot Temp [°1:) Collop Collop Collop 184 Initial hot Temp /.°Fi VME VME VME VME 0 -P friction (psitMft) Bottom To p Bottom 0 (etlO0 ltl ~ Denotes Design Factors Below BP's Suggested Minimum ~imums (sweet ;nsion ca Load Compression 1.20 Loed capacity Burst 1,30 VME (sour service) ment calculations are from the BP Completion Desigr~ Manual Volume II Na~e~ Tubing move ............. ^_.k... c..~l, keen Tensio~ anc~ VNtE [actors abDve minimun~ '~l~[~'~'f~r ~knf~1-1orec~l tubin~ weak link IS Top Ol I:UOH~I u~ ~,,~,,,, ...... ~- ........ '2' ~; F' ;'~;ting sea, aS'~'embly over slipstick: Keep Total negative Length Change < <: 51ipst, cK LencJ[- ~,)~"~O~ Pinned seal assembly over slipstick, pi~s wilt shear and tL~bin9 w/Ir move if'. IF tp] > Pin Strength i ! · i ii iI · ,~ ' I I k H4OConduo~r ,2,0,000 19.124 91.1 115 61 0 ~ L-80 N$CT Produc~n T~h~g 4. S00 3.958 12,6 , I ,~ HES '~ Cm~ V~v~ ~lna ~ 4~500 ~,81~ 218~ ¢124 2 I I I ! I I I 1 ~ ~ HES '~?' Per~m P~ker 5,875 3,958 965t 8936 28 --~ ~ HES"~" ~dln0 ~p~ 9CR 5,010 3,725 g668 8~1 27 I , I~ ~ ~e~ En~ GOde 5.0~ 3.9S8 ~80 S962 27 I ' : ~ ,~ 7"x 4 1~ ~r H~er / P~ker 9054 9119 26 ~, ~ I[ In~C~USSgS 7.000 &184 29 10038 9279 26 ~ ~ 6ap~ 2~"; ~m; 6~ph 11122-11160 10119-10149 ~ ~ 6sp~2W';~m;60~ph 11812-11362 ~03~*-~0~ 89 PSTO ~ 1~ 10368 ~ ~ ~ ~,~d~.c~ 4.~00 8.958 12.6 11525 10~6 Oa~ Re~ ~ Comme~ ,, . ~1~ IB.Tu~II I~1 ~n u~7~ B.Tufflbull A~bu~L ~'~~~~.''~ ......... ' ............... i , m ~ i i I I III I ! I II I III II I I _ B1 1~ I II I I I . I II I I I ' -- I BP EXPLOR~'ION Memorandum To: P. Colli n s/J. Powe rs/M. G oodwin Date: Sep 14, 1998 From: P.Collins AND PE Subject: BADAMI B1-14 Frac Programme B1-14 was completed with a 4 1/~,,, cemented liner and 4 1/2" tubing. Frac equipment will be barged from West Dock to Badami. Seawater will be drawn from the Badami dock and heated by a hot oil truck. The CTU will be barged out after this and B1-16 fracs are done if cleanouts are necessary. PTS frac separator is on location ready for flowback. 1. Reperforate 11338 - 11358 ft md bkb 11136 - 13156 ft md bkb with big hole charges 2. Pump a 300 bbl data frac. 3. Redesign and pump the frac. Initial calculations give 150,000 lbs 16/20 proppant. 4. Conduct a CTU cleanout if necessary. 5. Flow the well back through the PTS flowback separator to clean up proppant. The Deviation across the perforated interval is 40°, at an azimuth of 350°. Attachments to this program include: · Well completion diagram. · Detailed data frac and propped frac program. · Tubing Movement Calculations for Well B1-14. Badami B1-14 Frac proceedure Attention: Bob Thayer /Wes Wilder DO NOT EXCEED 8,400 surface pressure. Pre - Frac Treatment 1. Reperforate 11338 - 11358 ft md bkb 13136- 13156 ft md bkb , Shoot the guns on balance. Perforation should be with 2 ~A" guns, 6 spf, 60 degree phasing, big hole charges. Pressure test annulus to 5,000 psi. Equipment will be brought out by barge from West Dock. Berm in and rig up equipment. Seawater will be taken from the Badami dock by vac truck. The water should be pumped into DS tiger tanks via a 3 mm filter and heated by hot oiler to 100 degrees F. Hydraulic Fracturing Procedure Badami A5 & F5 Objective: To create a frac of 250 feet X~in the Badami A5 and F5 sands. Pump injectivity test and datafrac followed by the main fracture treatment. Rig up and stab tree saver, (4" Cameron tree, 4 1/:,,, L-80 tubing). The surface pressure is estimated to be 5,000 psi for pad. Azimuth - 350° Deviation - 40° Pressure test surface lines to 10,000 psi. Expected treating pressure is between 5,000 and 8,000 psi. Observe trip-out of each pump. After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 8,400 psi. Perform injectivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. With gel at the perfs, bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50# linear gel followed by seawater. Over displace all crosslinked fluid into the perfs by 5 bbls. Shut down and monitor the surface pressure for at least 15 minutes. If the near wellbore friction is > 1,000 psi pump a large fluid slug - 50 bbls and flush. Monitor the decline, if near wellbore friction still high, repeat the procedure. Look at both the value and the rate of change of the near wellbore friction. If, required a proppant slug will then be pumped. Once near wellbore friction is ,--, 500 psi proceed to Datafrac. 4) Perform 300 bbl Data frac with crosslinked fluid: Pump data frac down to perforations at 5 bpm. With gel at the perfs, bring up rate as quickly as possible to 20 bpm. Over displace data frac by 5 bbls. Displace the data frac with 30 bbl 50 Cf linear gel followed by seawater. Stop pumping and monitor the pressure decline. Transmit the data to Anchorage for interpretation. $) Discuss closures and leakoff with town. Redesign the TSO. Pump 150,000 lbs fracture treatment at 20 bpm per modified ramp. ?) Freeze protect the tubing with 30 bbls diesel. Table 1 Volumes Volume to Top Perfs 172 bbls Under Flush 5.0 bbls Flush 167 bbls Post- Frac Treatment 1. Determine proppant top with slickline if necessary. 2. If a clean out is necessary, it will be done once B1-16 is also fracced and the frac equipment out of the way. A CTU will be barged from West Dock. Clean out Carbolite per established procedure. An additional programme will be prepared if the operation is necessary. 3. A PTS flowback separator is on location. Flow the well through the separator initially to clean up proppant. BP EXPLORATION, Alaska Date: 08-31-98 Trans# 89478 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type Rec Type Rec Date Comments B1-15L1 MAC OH 14-Jul-98 MULTIPOLE ARRAY. ACOUSTILOG B1-14 SBL CH 04-Aug-98 GAMMA RAY LOG/CCL B1-14 PFC CH 11-Aug-98 GAMMA RAY LOG/CCL B1-14 PFC CH 19-Aug-98 GAMMA RAY LOG/CCL B1-16 PFC CH 09-Aug-98 GAMMA RAY LOG/CCL B1-16 SBL CH 05-Aug-98 SEGMENTED BOND TOOL GR/CCL B1-16 STATIC CH 16-Aug-98 PRODUCTION LOGGING SERVICES/STATIC PRESSURE B1-21 PFC CH 06-Aug-98 GAMMA RAY / CCL B1-21 PFC CH 16-Aug-98 GAMMA RAY / CCL q"=&' O'ZO Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disldl blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR- I disk/1 blueline BP - - 1 blueline BP --1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 JUJ.,, /.~-, ,:JU0 ~ ' ULrtVl STATE OF ALASKA ---~- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL I. 6 2, Nome at Operator BP £xploraflon (Ak~ka) Inc. 3, Address P.O. Box 196612, Anchorage, Alaska 99B16-6612 Location of well at surface 3855' NSL 126' WC:L SEC 8, T9N, R26~, UM At fop of productive [nterval 1670" NSL 73" WEL SEC 5, TON, R2C~, UM At ofleotlve depth At total depth 2137' NSL 162' WEb SEC 5, TNe, r4206, UM 12, Present well condlfi~3n summary Total depth; meosu.ed 11525 feet true vertlc~t 10ag0 feet Effective depth: measured 11440 feet true vertical 10422 feet ,5, Type ot' well: JX~Developrnenf r--JExploratory E]straflgrophic Flse~lce 6. Oatum Elevation (DF or KB) KBE [] 54.2' 7. Unit or Property Nome BADAMI 8. Well Number BI-14 ;). Permit Number 98-63 10, APl Number 50-02¢-22874 11',' Field and Pool Badaml Field / Bc~clami Oil Pool Plugs (measured) Junk (measured) Ca~lng Length Size Structural Conductor 74' 20" Surface ,fl4¢9' 9-5/8" Intermediate 10000' 7" Production Liner 1677' 41/2" Cemented MD TVD 2~ sx Arotlset 110' 3870 sx PF 'E', 340 sx Class 'G' 4533' 20O sx Class 'G' 10033' 220~C1o~' 11525' Perforation depth: meosured true vertical Tubing (size, grc~e, and measured depth) Packers and .~$V (type and measured depth) 4 1/Z'12,6# L-SO at 9681'MD HES TINT packer crt 9652'MD JUL 2 4 1998 Alaska Oil & Gas C0ns. Comm~i0n I-lES HXO SSSV landing nipple ¢ 218gWID 13, Attachments F]Descrlptlon summary of proposal [~]Oetailed operations progrcrn 14, Estimated date i'or commencing operatiOnoa/01/9B J 15, 6, If propos~ was venally approved J ~Oll Name of ~prover Dote apFov~J 8eNIce C~f ~eer No~ / ~ber: Pat Collins ~4363 ~ ~y N~¢/~¢~ [--1BOP sketch [suDended Pot Collins 564-4363 tO C0ta~d.~.t. on u,~ Ov,'ly Conditions of Approval: Notify Commlsslon so representative may witness Plug Integrity. BOP Test ~ Location ctearanoe Mechanloal Integrity fest~ Subsequent form required 10- /1/'..O '~. ORI61NAL $1~N~DJ~ ~_Dproved by order of the commission D,,~,,~,e IM ~hri~t~ft~"t¢l Commis~oner Form 10-403 Rev. 06115/88 ........................ Date Sub"nlt In Triplicate Memorandum To: S,Benoit ~rom: Subject: P.Collins AND PE BADAMI B1-14 Pre Startup Progr__ra. mme July 20, 1998 B1-14 was completed on 5/1/98. The well is completed with a 10M tree and will be the initial gas injector. 1. Pull the ball and rod. 2, Run a cement bond log. 3. Perforate the A5 sands. Thermally frac the A5 with cold seawater. Set a bridge plug above the AS. 4. Perforate the F5 sands. Thermally frac the F5 with cold seawater. Pull the bridge plug. 5. Run and set a check valve in the X safety valve landing nipple. Leave the well freeze protected, Perforation should be with 2 3A" guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. The Deviation across the perforated interval is 40°, at an azimuth of 100°. PBTD is at 11440 ft M D bkb. Detailed procedures are attached, Attachments to this program include: · Well completion diagram · Miniiog PC cc L Koenn, Atlas Wellfile B1-14 Pre start up Proceedure B1-14 will be the initial gas injector. Gas injection will be into two zones, the A5 and F5 sands. To enhance injectivity, both sands will be thermally fracced. This involves breaking down the formation with water and creating a fracture. Injecting enough cold water will ensure that the formation cools down and stays cool such that the frac will remain open, unpropped, for the first several months of the wells life. Calculations indicate that 20,000 bbls of water will need to be injected into each zone, The lower zone will be perfed and 20,000 bbls injected into it, An inflatable bridge plug will be set to isolate it. The upper zone will be perfed and 20,000 bbls injected into it. Then the bridge plug will be pulled to open both zones to injection at startup. 1. Pull the BPV. Rig up slickline and pull the ball and rod. 2. Run a cement bond log over the 4 1/2" liner. Do not bleed off WHP as the tool is RIH, to increase the wellbore pressure and run the log under pressure. 3. Perforate 11310- 11362 ft md bkb (52') A5 sands Adjust WHP to 1200 psi to give a 500 psi underbalance at the perfs for the first gun run, Perforate the rest on balance. 4. Anchor the AIC barge on lhe beach closest to the pad. Rig up a tiger tank close to the well and run 3" hose from the barge to the tank, Berm in the tiger tank. The barge will use it's charge pump to suck seawater and send it to the tank, which will act as buffer storage. Use a coarse filter on the suction line. The treatment pump will take suction from the tank. 5~ Rig up the treatment pump on the well. Either a DS turbine pump or two Halliburton pumps will be used, depending on availability of the DS equipment. Pressure test the treatment line to 7000 psi. 6. Hold a pre job meeting with all personnel involved. Check radio communication between the barge and the pump. Fill the tiger tank. 7. Start pumping the treatment. The formation should breakdown at about 6000 psi WHP. Thereafter pumping should proceed at about 4000 psi. The DS pump close to 10 BPM, the Halliburton pumps about 6 BPM, Continue pumping until 20,000 bbls have been injected. If the pump needs to be shut down it is not a problem. The objective is to get the volume into the formation to cool it down, the pumping rate or time taken to inject that volume are not important. Maintain a watch on the tank and a tally on volumes pumped from both the charge and treatment pumps to ensure that the tank is not overfilled. If the well is shut in for more than 24 hours, pump 30 bbls diesel to freeze protect. 8. Rig up Atlas. Run a Baker inflatable bridge plug and set it at 11280 ff md. 2 998 9. Perforate 11122 - 11180 ft md bkb (58') F5 sands Perforate on balance. 10. Pump 20,000 bbls seawater as in steps 6 and 7, Pump 30 bbls diesel at the end to leave the well freeze protected, 11. Rig up slickline and pull the inflatable bridge plug, 12. Set the injection valve in the safety valve landing nipple at 2189 ff. JUL. Z4, :MMU l'Udt~ z~v. ou~'~ z, u Kelly i3tlSh~n~ to Wellhead Wellhea(~ Io sea ,.. Ha0 Conducfor 20.000 19.124 91.1 115.0 60.8 _-80 NSCT Production Tublrig 4,500 3.955 12.6 HE~ 'X" Safety Valve Landing Nipple 4,500 3,813 2189.0 2125.~ Su~ace Casing LB0 g,625 8,681 40 4563.0 4499.2 HES q-FIT' Permanent Pad(er 5.875 3,958 9{~52.0 89375 HE$ "XN' Landing Nipple 9CR 5,010 3.725 9668.9 1~952,~ Wlrellne Enlry Guide 5,000 3.958 9581,2 8963,5 7"x4 1/2" Liner Hanger / Packer 9854.0 9i73.2 In[errnedlate Casing USS g$ 7.000 6.11~1 29 10032.0 9279.S PBTD 11440.0 1O367.9 Producllon Casing 4,500 3.958 12.6 11525,0 10435.8 ,. ~Dale Rev by Commenls ! ~o~ EkTurnbull Initial design ~7/o~,~ B,Turnbull Aa bul~. .. B1 14 UL, ~, ~UUO HV, OU 'E- [, 0 Memorandum To: $.Benoit From: Subject: P.Collins AND PE BADAMI B1-14 Post Startup Perforating Oatm: July 23, 1998 B1-14 was completed on 5/1/98, The well is completed with a 10M tree and will be the initial gas injector. A programme to perforate and thermally frac two intervals is on the slope. This programme is for additional perforations after startup when steady gas injection conditions have been established. 1. Perforate 11270 - 11310 ft md bkb 40' A5 interbedded. 2. Measure gas injectivity under a minimum of 24 hours steady injection rate. 3. Perforate 11070 - 11110 ft md bkb .40' F5 interbedded. Perforation should be with 2 3,4" guns, 6 spf, 60/180~ phasing, Predator deep penetrating charges. The Deviation across the perforated interval is 40°, at an azimuth o1 100°. PBTD is at 11440 ft MD bkb. Attachments to this program include: · Well completion diagram · Minilog PC cc L Koenn, Atlas Wellfile B1 1~ Kelly bu~l.g to welll~ead Wellhead to H40 Conductor 20.000 1g.1~ 91 .t 11~,0 ~.6 L-~ NS~ Pr~dlon T~lng 4~ ~ 12.6 HE$ 'X' S~e~ V~ L~dlng N~ 4,5~ 3,~13 2189.0 2125,5 Su~ce C~ LBO 9_~ 8.681 40 ~.O ~99~ HE$ W~' Pe~anenl P~er 5,875 3,9~ ~,0 8937.~ HES ~N' ~n~ng H~le 9CR 5,0~ 0 3.72S ~66~,9 ~952.S ~mlrne E~ Gb~ 5.~0 3.eS8 ~1,2 8963.5 7" x 4 1~" L~sr H~gef/P~ef 98~.o 9173,2 Inferable C~ng USS gs 7.000 6.t~ 29 10~2.0 9~79,5 PBTD 11~0.0 10367,9 P~dron c=~ 4~00 3.956 12.6 ~ 1~25.0 1~3S.e . Rev by Comments · ~o/o3~e B.Tumbull Inlllai design 17~ B.Tumbull &~ I~U~, ,,. are'd rvlces rilling Alaska 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 July 22, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Steve McMains Steve: The attached completion report for well number B1-14 has been revised to correct an error. A previous completion report submitted on June 18, 1998 indicated we had perforated this well. We indeed, have not perforated this well and expect to perform the task sometime in August. The data submitted to you indicating perforations had taken place was a typographical error which has now been remedied by the Badami Asset Group. Please accept my apology and any inconvenience this may cause. Please contact me if you have questions. Sincerely, Carol L, Withey Technical Assistant III Shared Services Drilling Attachments cc: Badami Asset Group File B1-14 BP EXPLORATION, Alaska Date: 06-04-98 Trans# 89133 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type Rec Type Rec Date Meas Depth Top Meas Depth Base Comments B1-14 STAR TAPE 05-May- 10,500. 11,434. STAR 98 Please sign and return one copy of this transmittal to: Nadene Reicherl: ~~-----~ Petrotechnical Data Center LOG DATA AOGCC- I disk/1 blueline/1 sepia PETROFINA- I disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP-- 1 blueline BP ---1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd .~.~,,~. \ Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 05-26-98 Trans# 89133 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166 Sw Name Log Type Rec Type Rec Date MD Top MD Base Comments B1-14 DIL DISK 21-May-98 9,915.1 11,546. HIGH DEFINITION INDUCTION LOG B1-14 SBL DISK 21-May-98 8,701 ~ 10,051. SEGMENTED BOND TOOL B1-14 Z-DENSILOG DISK 21 -May-98 9,981. 11,540. COMPENSATED Z-DENSILOG B1-14 MAC DISK 05-May-98 9,908. 11,553. MULTIPOLE ARRAY ACOUSTILOG - LAS FORMAT '1~1-14 MAC OH 05-May-98 9,908. 11,500. MULTIPOLE ARRAY ACOUSTILOG B1-14 MWD . OH 26-Apr-98 4,586. 11,525.! MWD ROP NGP DGR EWR4 DGR/EWR B1-14 MWD OH 26-Apr-98 4,576. 10,490. TVD - MWD ROP NGP DGR EWR4 DGR/EWR B1-14 MAC OH 26-Apr-98 9,929. 11,523. HIGH DEFINITION INDUCTION LOG MULTIPOLE ARRAY ACOUSTILOG GAMMA RAY LOG B1-14 Z-DENSILOG OH 27-Apr-98 9,995. 11,522. COMPENSATED Z-DENSILOG COMPENSATED NEUTRON LOG GAMMA RAY LOG B1-14 MAC OH 26-Apr-98 9,929. 11,523. TVD- HIGH DEFINITION INDUCTION LOG MULTIPOLE ARRAY ACOUSTILOG/GR LOG ~B1-14 SS TVD OH 26-Apr-98 9,929. 11,523. HIGH DEFINITION INDUCTION LOG iMULTIPOLE ARRAY ACOUSTILOG/GR LOG SUB SEA TRUE VERTICLE DEPTH B1-14 SBL CH 28-Apr-98! 8,710. 10,032. SEGMENTED BOND TOOL/GAMMA RAY LOG/CCL z,p b Please sign and return one copy of this transmittal to: Nad erie Reichert Petrotechnical Data Center _ _ LOG DATA AOGCC- I disk/1 blueline/1 sepia PETROFINA- I disk/1 blueline/1 sepia DNR - 1 disk/1 blueline BP - - 1 blueline BP ---1 correlation log blueline Howard Oakland Mike Engle Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 MEMORANDUM State of Alaska TO: David Joh~ Chairman Alaska Oil and Gas Conservation Commission DATE: April 10, 1998 THRU: Blair Wondzell, ~ FROM: Lou Grimald',~. SUBJECT: Petroleum InSpector FILE NO: A7RJDJFE.DOC BOP Test, Nabors 28E BPX B1-14 Badami Field PTD #98-0063 Friday, April 10, 1998; I witnessed the initial BOP test on Nabors rig #28E drilling BPX well B 1 - 14 in the Badami Field. I was already on location due to a casing top cement job that I had witnessed on the previous day. I made a cursory tour of the rig and its surrounding area and found all to be in good shape. The test was delayed by a leak at the base flange of the BOP's which necessitated changing out the APl ring. The test went very well with all BOPE testing out with no failures observed. Chris Page (Nabors toolpusher) was on hand during most of the test and seems dedicated to providing his crews with the proper equipment and promoting good drilling practices. SUMMARY: The initial/weekly BOPE test I witnessed on Nabors rig #28E revealed the following; Test time 4 hours, No Failures. Attachments: A7RJDJFE.XLS CC; Mike Miller (Shared Services Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initia X Workover: Nabors BPX B1-14 Set @ Weekly Rig No. 28-E PTD# Rep.: Rig Rep.: 4,533 Location: Sec.~ Other TEST: DATA 98-63 DATE: 4/10/98 Rig Ph.# 659-1201/1212 Nick Scales/Dick Maskefl Chris Page~Bill Bixby 8 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 250/3500 P f 250/5,000 P I 250/5,000 P I 250/5,000 P f 250/5,000 P 2 250/5,000 P f 250/5,000 P N/A 250/5,000 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 1 250/5,000 P 250/5, 000 P 250/5,000 P 250/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 18 250/5,000 P 42 250/5,000 P 2 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Eight Bottles 2000 Average 2,950 P 1,600 P minutes 31 sec. minutes 46 sec. P Remote: P Psig. Number of Failures: 0 ,Test Time:,/' 4.0 ;Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within N/A ~ otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-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: Louis R. Grimaidi FI-021L (Rev.12/94) A7rjdjfe.xls Mik~u~ TMqU~ ~ .. Folk~ wi~ fteeb water:I0 ~4s. D~op ~l~g. D,5¢,~ w~n _,_1~ ,b~ Float ~1 ~? y Tn ClL']W,-I BOIJBO BdOqS DDg09 /_.T/_~;BqgY_OB ~;O:T~; BBBT/BO/PO Casi~9/i.inlr Ce~w. nMng 8~mmy ~ ;Jl on Jm Nonl ~a IIqL9 ~R'qr FL.OAT L~ TG~ Packer ~ "__ rm BI~ ~anGion. Li~gl~ GE~T O~ o~ ~ at ~HRS, frGm p~n a~er~: ~~hbll .... . ..... i ' Ml~nufa~r · Ic~10~1~;:. TOP O~ dT ~ t ~Ipnv~ft~t~M' 448e Pumpe~ prdJuih: beaaL of SX C~menl Rgd~: ~ UnO. dive ~o~nt Set flsng.r w ~ ~~i. ~el ifle~ top pa~( F~d ~enl t.~ tip at ~~~ ~: Pu~~e ~6P~ .... 12 ~BPM ~ 1~ BP EXPLORATION gOO Ea,~ ~en~n FO, Box 19~6'12 DAT~:~ TO: TELECOPy Location: Fax Ntrrnber: FROM: Name: ~'.~~ Department: Location: Fax Number: RECEIVED /-'.PR ©5 1998 Alaska 0ii 8, Gas Oons. Commissior, Anchorage STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL · Type of Request: ~Abandon [] Alter Casing [] Change Approved Program [] Suspend [~ Plugging F-~'lTme Ex'~ension [] Repair Well [] Pull Tubing [] Variance [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Diverter Waiver 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3855' NSL, 126' WEL, SEC_ 8, T9N, R20E, UM At top of productive interval 2008' NSL, 160' WEL, SE(3.5, TgN, R20E, UM (Planned) At effective depth N/A At total depth _2_225' NSL~ 234' WEL, SEC. 5,_TgN, R20E, UM (Planned) 12. Present well condition summary Type of well: ['-I Development BExploratory Stratigraphic ~]Service 6. Datum Elevation (DF or KB) Plan KBE = 54,2' 7, Unit or Property Name Badami Unit 8, Well Number B1-14 9, Permit Number 98-05 10. APl Number 50- 029-22.874 1_ Field and Pool Badami Total depth: measured 116' feet true vertical 116' feet Effective depth: measured feet true vertical feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 20" Cemented MD TVD 260 sx Arctlcset I (Approx) 116' 116' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) N/A ORIGINAL Packers and SSSV (type and measured depth) N/A 13. Attachments [~ Description summary of propose] ~ Detailed operations program [] BOP sketch 14. Estimated date for commencing operation J 15, Status of well classifications as: April 4, 1998 16. If propo~t'was verbally approved _ , ! C-]Oil [-IGas E~Suspended Name of approver Date. approved ! Service Water & Gas Injector Confact Engineer Narne/Numl~ert Mike Miller, 5~4-8066 Prepared By Name/Number: Kathy Campoamor, ~84-8122 17. I hereby certify that the foregoing ls true and correct to the best of my knowledge Signed ~~ Mike Mil:~r __ _ Tltle Badarni Drilling Team Leader Collision Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10 Original Approved b}, order of the Commission David W. Johnston Form 10-403 Rev. 06/15/88 Approved Copy I Approval No. 3~ Commissioner 05 998 Alask~ 0il & Gas Cons, 60mmisst0n Ane, h0ra_~e SSD RISK ASSESSMENT WORKSHEET Subject: Risk of no Diverter on Badami DevelOpment wells 1. Brief description of the risk: The removal of the divcrtcr systcm Hydril 2M MSP for tl~e surface hole sections for Badami development wells could increase tho risk of a fire in a shallow zone well blowout scenario over that of an alternate scenario with a diverter systcrn installed. 2. What are the identified hazards? Health and Safety: Without the use of the diverter an unloading of the wellbore could cause a bridging condition in the openhole annulus and result in a broaching condition of wellbore fluids/gases to surface via the out~ide of the 20" conductor casing. Due to the inability to divert wellbore fluids/gases a significant concentration of gas could accumulate in tho rigs substructure and periphery and potentially reach combustible levels without adequate time to vacate the rig modules and locate personnel at a safe distance, Emtironment: Any diverted or undiverted blowout would cause serious environmental damage to the North Slope - this hazard is prevalent in any case. Facilities: Without a divcrter, in a blowout broaching scenario in a surface hole section, gas brought to the surface would most likely remain within the rig structure. This increases the hazard an explosion damaging the rig and subsequent production facilities_ Financial: Any type of blowout would result in a financial loss. Reputation: A blowout on the North Slope would jeopardize om- 'license to operate'. However, this could result with a diverted surface flow as well as one without a diverter system_ 3. What are the causes for each hazard identified? The main additional hazard identified above is the possibility of an immediate fire occurring as a remit of gas igniting while the well is flowing into the rig. This would increa.~e the safety hazard to rig personnel as well a_s potentially increase the damage to the fig. This assumes that the gas would find an easier ignition source than if the well is diverted. However, if the wind was blowing into the rig or the diverter flow was blown into another ignition source, the same hazards would exist. 4. What are the consequences? (as per the attached worksheet) The consequence severity is ranked as 'Catastrophic' in the event an undiverted blowout caused an explosion that prevented the evacuation of rig personnel. $SD Risk Assessment System V1.1 SIRS Last Revised: March 31, 1995 Page 1/2 RECEIVED Alaska Oil & Gas Cons. C0mmissi0r~ Anchorage Consequence Probability Health and Safety: II D 4 Envkonment: I D 3 Facilities: II D 4 Financial: I D 3 Rcputation: li D 4 Result 5, What are the probabilities? (as per the attached worksheet) ,,=.......-.--- Thc probability of the above mentioned incident occurring is (D) unlikely to ever occur based on experiencc gained through drilling the Badami exploratory wells and subsequent development wells, These wells have never encountered either signs of overpressure or signs of shallow hydrocarbons. 6. Risk Ranking Assessment score and required Safeguards: Using the Boston Square Matrix, thc score is 3 or medium risk that requires at least 2 safcguard categories including the physical safcguard. For the physical safeguard, flow and pit volttmc alarms arc used throughout the drilling of all surface holes. Since a diverter system would not contain a well control situation, reacting to warning sigxts early as well as having an adequate mud weight as physical safeguards are critical, The human element of constantly monitoring thc fluid levels in the hole wMle drilling and tripping meets the second required safeguard. By performing drills on a daily basis, the fig crew is trained to prevent early indications of a kick. SSD Risk Assessment System Vl. 1 SRS Last Revised: March 31, 1995 Page ~ Badami Diverter Waiver Procedure 1. MIRU Nabors 28 E, build 12-1/4" surface hole spud mud, P/U 12-I/4" BHA. Calibrate Driltech 1000 total gas sensor. Note: A divener spool may be installed to facilitate operational handling of surface hole cement returns. The annular element will be closed and the cement returns diverted to outside tanks. 2. RIH w/12-1/4" BHA. Drill ahead while monitoring Driltech gas sensor total gas counts on rig floor display_ Ensure ail Driltech total gas monitors are properly calibrated and functional in mud pit room Drilling Supervisors and Toolpushers office. 3. In the event that total gas counts are trending upwards and reach unacceptable levels or if free gas is detected at surface, the procedure will be to: stop rotary & pick up drill string off bottom, stop pumps and observe well. 4. Circulate annulus at a minimum of 200% open hole annular volume, Perform mud weight checks during the annular displacement to determine the extent of gas cutting. 5. Initiate barite additions to drilling mud active system so that total gas counts are reduced to acceptable levels. Perform mud weight checks to ensure mud densities "in" and "out" are within acceptable limits (0.1 - 0.1+ ppg). 6. Drill ahead at controlled drilling rate ( 30 fi/hr ) monitoring gas returns and PVT system. Do not allow Iluid transfers within the active system while control drilling ahead and monitoring total gas counts. 7. Resume normal drilling parameters: WOB,RPM,SPM with evidence that the total gas counts are remaining at acceptable levels. In the event that the total gas count trend increases to unacceptable levels, repeat steps ~5 thru #8. Badami Diverter Waiver Procedure ,,,. no '~ Alaska 0ii & Gas Cons. Commissior~ Anchorage TONY KNOWLE$, GOVERNOR ~LASi~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 26. 1998 Mikc Miller Badami Driiline Tcam Lcadcr BP Exploration (Alaska). Inc. PO Box 196612 Anchorage. ,AK 90519-6612 BadamiUnit BI-14 BP Exploration (Alaska). Inc. Permit No. 98-63 Sur. Loc 3855'NSL. 126'WEL. SEC. 08. T09N. R20E. UM Btmholc Loc. 2225'NSL. 234'WEL. SEC. 05. T09N. R20E. UM Dcar Mr. Miller' Encloscd is thc approved application f`or permit to drill thc abovc rcfcrcnccd xvcll. Thc permit to drill docs not exempt you from obtaining additional permits rcquircd by law from othcr governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Plcasc note that injcction may not commcncc in this xx-cll until all Area Injection Ordcr is issued for thc Badami Field. Thc bloxvout prevention cquipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035: and thc mechanical integrity (MI) of' thc injection wells must bc demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI test before operation, and of thc BOPE test pcrformcd before drilling below thc surfhcc casing shoe. must be givcn so that a rcprcscntativc of thc Commission nmv xvitncss thc tests. Notice may bc givcn by - ...,/ ctor on thc North Slopc pager at 6>9-..,607. · David W. Joh'~on ~ Chairman BY ORDER OF TIlE COMMISSION dlf/Enclosurc cc: Department of Fish & Game. Habitat Scction xv/o (2Ilcl. Dcpanlncnt of Environmcntal Conservation vdo cncl. STATE OF ALASKA ., ALAS~-:~ OIL AND GAS CONSERVATION CToMMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork [~i;;~Drill DRedrill Ilb. Typeofwell DExploratory l--IStratigraphicTest I--1DevelopmentOil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 15. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 54.2' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 367011 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3855' NSL, 126' WEL, SEC. 8, T9N, R20E, UM Badami Unit At top of productive interval 8. Well Number Number 2S100302630-277 2008' NSL, 160' WEL, SEC. 5, T9N, R20E, UM B1-14 At total depth 9. Approximate spud date Amount $200,000.00 2225' NSL, 234' WEL, SEC. 5, T9N, R20E, UM 03/30/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 365533, 234'I B1-11,30.77' at 400' MD 2533 11591' MD / 10499' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 53.5° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Setting Depth Size Specifications 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.) 12-1/4" 9-5/8" 40# L-80 BTC 4528' 35' 35' 4563' 4500' 2850 sx PF 'E', 350 sx Class 'G' 8-1/2" 7" 29# USS-95 BTC-Mod 9648' 33' 33' 9681' 9028' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 2060' 9531' 8898' 11591' 10445' 350 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 MD TVD Structural sC~r~adcUeCt°r R E C ElY E D Intermediate Production LinerBAR 2. 4 !998 Naska Oil & Gas Cons. CommiSsion Anchorage Perforation depth: measuredORIGINAL true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mike Miller, 564-5066 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 ~ { ~/ Mike Miller ~'~ ,~--~ . Title Badami Drilling Team Leader Date '2~ ~. ~>~' Commission Use Only Permit Number APl Number I Ap~rovalDate I See cover letter ,~-~:>--~'.~ 50-~::~,-~ ,¢'-" ,,Z, ~ ~',~/ ~,~~ for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes 'l~ No Hydrogen Sulfide Measures []Yes ,~No Directional Survey Required [~Yes I--INo Required Working/Pressure fo~r DOPE []2M; []3M; []5M; [~r'10M; [] 15M Other: ~O ~-~'" "~,i '/"~"~, ,.-,, ,.,¢~,ACr.. ~4',,.,..,., -'""-.r '~'~'' Original Signed, BYomm,ss,oner by order of ~ Approved By 0avid W..mhnst0~ ' ' the commission Date Form 10-401 Rev. 12-01-85 Subm~ iplicate Shared Services Drilling Contact: I Well Name: B 1-14 Injector PERMIT Mike Miller I B1-14 Well Plan Summary Type of Well (producer or injector): I lnject°r I 564-5066 I Surface Location' 3855' FSL 126' FEL SEC 8, T9N, R20E, UM, AK Badami Sand A5 Primary 2008'FSL 160' FEL SEC 5, T9N, R20E, UM, AK target Bottom Hole Location (TD) 2225' FSL 234' FEL SEC 5, T9N, R20E, UM AK I AFE Number: I 880454 I Rig: I Nabors28E Estimated Start Date: IMarch 30, I I Operating days to complete: 22 1998 IMD: 111591'I ITVD: 10499' I KBE: BRT I AMSL 54.2 J Well Design: Ultra slimhole Formation Markers: Formation Tops MD TVD (bkb) Remarks base permafrost 1993 1984 Base West Sak 8829 8294 Shallowest Badami Sand 9921 9228 Badami Sand K2 10246 9507 Badami Sand J2 10462 9693 Badami Sand F3 10583 9798 Badami Sand F5 11031 10149 Badami Sand A5 11327 10338 Primary Sand Total Depth 11591 10499 Casin[F'l'ubin9 Pro~lram: Hole ~ize - Csg~ WEFt Grade Conn Length Top Btm Tb[I O.D. . MD/TVD MD/TVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 4528 35/35 4563/4500 8-1/2" 7" 29# USS95 BTC 9648 33/33 9681/9028 mod 6" 4-1/2" 12.6# L-80 BTC 2060' (150' 9531/8898 11591/10445 mod lap into 7") Tubing 4-1/2" 12.6# L-80 NSCT 9331 33/33 9331/8726 Internal yield pressure of the 7" 29#/ft USS95 casing is 9690 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 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. B 1-14 Injector PERMIT Logging Pro~lram: , Open H~le L(~gs: Surface None Intermediate MWD/GR on last bit trip Production Hole run 1: HIDL/ZDL/CN/MAC run 2: MRIL run 3: 5" STAR run 4: RFT'S MWD/GR/RESISTIVITY last bit trip RFT 2 fluid samples, one in F5 and one in the A5. 10 pressure samples Cased Hole Logs: · SBT required on intermediate and production casing. Mud Program: I Special design considerations I None 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 9.8 300 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 12.6 55 15 10 20 9.5 4-5 Well Control (Secondary): Well control equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file. Directional: IKOP: Ilsd. 300' MD 2nci. 1500'md,1493' tvd 3r°: 4843'md, 4634' tvd 4th: 10590'md, 9812' tvd Maximum Hole Angle: 53.5° Close Approach Well: B1-01: 130' @ 600' md, B1-11: 30.77' @ 400' md & 82' @ 3428' md B1-21:66' @ 598' md. 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. Annular Injection: No annular injection is planned at this time. B 1-14 Injector ...... PERMIT Badami B1-14 Injector Proposed Summary of Operations 1. The 20" conductor and cellar are already installed (all cellars and conductors were installed in winter 1997). Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 28E drilling rig. Install 21-1/4" Hydril MSP annuluar preventer. Note: Diverter waiver does not require the installation of the 16" diverter line. 4. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD. 6. Run 9-5/8" casing and cement to surface in two stages. Insure a minimum of 2500 sxs of Permafrost "E" cement is available for the 2nd stage displacement. 7. ND 21-1/4" diverter and NU 13-5/8" 10M BOPE. Test BOPE to 5000 psi minimum. . Pick up BHA. RIH, test casing to 3000 psi. Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST as per SSD Standard Operating Procedure. Contact Badami Team Leader or SSD Superintendent with LOT results before drilling ahead. 9. Drill 8-1/2" hole to intermediate TD @ 200' tvd above shallowest Badami sand with MWD directional surveys. Plan to have MWD/GR picked up on last bit run prior to TD of 8-1/2" intermediate hole section. 10. Run 7" 29# BTC mod USS95 intermediate casing. Cement as per Cement Basis of Design. 11. RIH w/6" drilling BHA, clean out cement to landing collar, circ annulus 200% & test intermediate 7" 29# BTC mod casing to 5500 psig for 30 min. 12. Drill out float joints,shoe and drill 15-20md below intermediate shoe depth. Treat cement contamination. Change out mud system to 2% KCL LSND. Perform a FIT to 15.5 ppg. 13. Drill to TD as per directional plan with MWD directional tool. Plan to P/U MWD/GR/Resistivity on last bit trip. 14. Run open hole logs as per plan. 15. Run and cement 4-1/2" 12.6# L80 production liner with 2-7/8" VAM inner string, displace cement with drilling fluid. Set liner hanger and liner top packer. Release off of 4-1/2" 12.6# L80 BTCmod production liner, pick up and clear top of tieback extension and circulate excess cement/contaminated mud to surface the Iongway. 16. Test 4-1/2" 12.6# BTC mod production liner and 7" 29# BTC mod casing to 3500 psi for 30 minutes to confirm liner and lap pressure integrity. Circulate well to completion fluid (fresh water) with 25gals/100 bbl of 7726 Corexit corrosion inhibitor. Re-test 4-1/2" production liner and 7" intermediate csg. to 5500 psi for 30 minutes. 17. Run Atlas Wireline SBT cased hole cement evaluation log. Run SBT with 0 psi gauge pressure and with minimum of 1000 psi surface pressure. 18. Run 4-1/2"12.6# L80 NSCT tubing per completion procedure. Set two way check in FMC 4-1/2" tubing hanger. Note: B1-14 will require a Cameron 11"10M x 4-1/16" 10M tubing head adaptor and 4-1/16" 10M Cameron tree. 19. ND 13-5/8" 10M Hydril BOPE, NU 11" 10M x 4-1/16" 10MFMC tubing head adapter and 4-1/16" 10M Cameron tree and test tree to 5500 psi. Pull two way check. B 1-14 Injector ...... " PERlVIIT 20. 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 tubing head isolation gate valve. Freeze protect 7"x 9~5/8" annulus to 2200' tvd. 21. 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 10M FMC tubing hanger. 22. Rig down and move rig to next well. DRILLING HAZARDS AND RISKS: B 1-14 Injector PERMIT Nearest offset wellbore - [ B1-01' 130' @ 600' md, B1-11' 30.77' @ 400' md & 82' @ 3428' md B1-21' 66' @ 598' md. I Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Well Control- Badami sands are overpressured- mud weight of 12.4 ppg will be required prior to drilling shallowest Badami sand (F2) at 9921' md 9228' tvd. Maintain 6" production hole section circulation rates @ 190 gpm to prevent loss circulation problems while drilling the Badami reservoir. - ,. a ....... ~,~ ~. ~ Mna ~7 ~OP'.Sta~O{rO0,O~'/1~:~.~.~.~ ~ : : -En~ Dlr, Sail ~ 6.~': 11 ~.~ MD, 1007.~ ~D i~ L~ ~ Id~Jl I II~ N 0.~ E I I i.~7 0.~ 19~.~ '- zJoo.oo ~ ~End DIr, SGII O 0,0~': 23~.~ MD, ~.glfl ~D ~0 - ,.oo.oo "' pr~l Tar~umma~ - _~ ~ · ,,,,, ~ Nt~ ~ ~ W~ ~: Gh~ Cm: nooo.~ ' BI,Id TI ~) · ~ 10~91 !~.11 3M3,~2 N, ILNI w ~NT~.tK) N. ~3933.~ g -~=.~.- ~- , ..... . = .~ =_,~ 34D~ ~ 3~ -- ~'~ [_ SU~E L~A~N {PLOT DA~ ~'- DA~ = 9 5/8" Casing- 468a.29 MD, 4564.20 ~D ~~' ~%~ ~, .................. ' . l/ 4~- , ' ~~X ................. ~ ' '~' ~ ~ ~ 7" Casing - ~70.~ MD, 8~4.R ~ S~a~ DIr ~ 4.~'/1~: 1~.9~ ~, ~12,3~ ~ I { "l ..... I 0 1 aO0 I~ ~ ..... i , ,, , ,,, i .. ,. i · , Shared Servlc:m Drilling Well: BI-14 Wp7 DrillQuest' 8©41®1 ll.oh · /02,~7, ! I 1/2" Liner- 11800, ~/1 ~ I~pfh; 11eOO,$~ft MD 1. ,~....~.~ ~ I:.~1 Circl* 1-14 T1 (F~), fin~ DI¢, 8 ~ ~ ~ 8~fl DIr · 4.~ t ~ r ~ Ca~ing , ?~~.~ lac ).~ , ~HA T~n~ ~ O~ 4~ - .oo. / _- ~a~ DIr ~ ~.~'~C~ le~.~ -- -Sled DIr · 1,~*/1~ 18 ~OP: Sta~ ~r · I.~' '10 I I MD, 10500.00 TVD BI-I~ T~ (AS). / 04.t ~. 2 0 104~ 2~ 3~00 3000 t I~00 4600 1000 1000 : 0003.21~ MD, 6~1~,7~t1TVD 800 8~ '~,,~.20 TVD 1~,~ MD, 1~,51h ~ 1~,~fl MD, 10~7.~ ~ 0 o ~ Sailer llfloh - 8~ R~nee Ii ~ N~h Beating. Sperry-Sun Drilling Services Proposal Report for B 1-14 Wp7 Badami Measured Depth fit) Incl, Azirn. Vertical De~h 0.00 0.000 0.000 -5420 0.00 100.00 0.000 0.4300 45,80 100.00 200.00 0.000 0.000 145J~0 20~.00 300.00 0.000 0.O00 245J~0 300.00 400.00 1.000 0.00lO 345.79 399.99 500.00 2.000 0.000 445.76 499.96 600.00 3.000 0,OC}O 545.66 599.86 700.00 4.000 0.(XX) 645.48 699.68 800.00 5.000 0.00O 745.17 799.37 9(X).00 6.000 0.000 844.70 898.90 1000,00 7.000 0.000 944.06 996.26 1100.00 8.000 0.000 1043.20 1097.40 ! .2~..,0Q 8.lX}O 0.0O0 1142,23 1196.43 1300.00 8.000 0.000 124126 1295.46 1400.00 8.000 0.000 t340.28 1394.48 1500,00 8.000 0,000 1439.31 1493,51 1600.00 7.000 O.OOO 1538.45 1592.65 1700.00 6.000 0.000 1637.81 1692.01 1800.00 5.000 0.000 1737~5 1791.55 1900.00 4.000 0.000 1637.04 1891.24 199G, 14 3.069 0.OOO 19130.00 1984.20 2000,00 3.000 0,000 1936.86 1991.05 2100,00 2.000 0.O00 2036.75 2090.95 2200.00 1.000 0JXiO 2136.72 21g0.92 2300,00 0.000 0.0gO 2236.71 2290.91 2400.1)0 0.000 0.000 2336.71 2390.91 2500.00 0.000 0.000 2436.71 2490.91 2600.00 0.1300 0.000 2536.71 2590.91 2700.00 0.000 0.000 2636.71 2690.91 2800.00 0.000 0,000 2736.71 2790.91 Local Coorc~mMes Northings Easlings (lq (n) 0,00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.87 N 0.00 E 3.49 N 0.00 E 7.85 N 0.00 E 13,96 N 0.00 E 21.B0 N 0.00 E 31~39 N 0.00 E 42.71 N 0.00 E 55,76 N 0.00 E 6e~a N 0.00 E 8359 N 0.0o E 97,51 N 0.00 E 111.43 N 0.00E 124.48 N 0.00 E t35~0 N 0.00 E 145~q9 N 0.00 E 153.23 N 0.00 E 156.97 N 0.00 E 15e,34 N 0.00 E 163.7O N 0.~0 E 166.32 N 0.00 E 167,19 N 0.00E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E Global Coordinates Dogleg Vertical Northings Eas~ings Rate Section fit) (n) (',qooft) (ft) 590~424.99 N 363885.84 E 0.00 5906424,99 N 363885.84 E 0.000 0.00 5,906424.99 N 363885.84 E 0.000 0.00 5906424.9g N 363885.84 E 0.(X}O 0.4)0 5906425~86 N 363885.86 E 1,000 0.87 5906428.48 N 363885.90 E 1.000 3.49 5906432.84 N 363885.98 E 1.000 7.85 5906438.94 N 363886.09 E 1.000 13.95 5906446.79 N 36388623 E 1.000 21.79 5906456.37 N 363886.40 E 1.000 31.37 5906467.69 N 363886.61 E 1.000 42.68 5906480.74 N 3636ZI6.84 E 1.000 55.73 5906464.66 N 3838a7..0~ E 0.000 69.84 5906508.9 Iq .363887.34 E 0.000 83.55 ~.49 N :~x3887..59 E 0.000 97.4~ ~.40 N 363887.84 E 0.0IX) 111.3'7 5906549.~ N 363888.08 E 1.0B0 124.41 5~06560.~ N 36.-___~J888__.28 E 1.060 135.73 5~,570.35 N 363888.5 E 1.000 145.31 5806578~3 N 3638~8.59 E 1.0OD 153.15 5906583J)4 N ~,70 E 1.1X)0 158.89 5906584~ N 363888.70 E 1.000 15e.25 5906588.~ N 363888,78 E 1.000 163.61 5906591.28 N 363888.83 E 1,000 166.23 5996592. I 5 N 363888,84 E 1.000 167.10 5906592.15 N 36-__3888_ .84 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 167.10 5906592.15 N 363868,84 E 0.0130 167.10 5906592.15 N 36384~,84 E 0.000 167.10 Alaska State Plane Zone 3 Badami CPF Cornrltent KOP: ~ [:)ir 0 1.000°/100It: 300.004t MO, 300.001t TVD St~l~ Dk' ~' 1,0(X)"/lO0ft: 15(X).(X)4t MD, 1483.$1ft TVD Base Pen,n,aYost End DE, Sail Q 0.000~: 2300.00fl MD, 2290.9111TVD 20 !~ I998- 16'.21 Sperry-Sun Drilling Services Proposal Report for B1-14 Wp7 Bedami Measured Deplh (~t) Incl. Sub-Sea (ft) Vertical Local Coordinates De~h Northings Eastings (fi) (ft) (n) 2900.00 0.0(X) 0.(X)0 2836.71 2890.91 3000.00 0.000 0.000 2936.71 2990.91 31(X).00 0.000 0.000 3036.7'1 3090.91 3200.00 0.000 0.000 3136.71 3190.91 3300.00 0.000 0.000 3236.7'1 3290.gl 3400.00 0.000 0.000 3336.71 3390.91 3500.00 0.000 0.000 3436.71 3490.91 3600.00 0.000 0.000 3536.71 3590.91 3700.00 0.000 0.000 3636.71 3690.91 3800.00 0.000 0.000 3736.71 3790.91 3900.00 0.000 0.00~ 3836.71 3890.91 40(X).00 O.0(X) 0.000 3936.71 3990.91 41 .00.0O 0.0O0 0.000 4036.71 40~0.91 42lX).00 0.0430 0.000 4136.71' 41g0.91 4300.00 0.000 0.000 4236.71 4290.91 4400.00 0.000 0.000 4336.71 4390.91 4563.29 0.000 0.000 4500.00 4554.20 4600.00 0.000 0.000 4536.71 4690.91 464329 0.000 0.000 4580.00 4634.20 4700,00 1,418 10.066 4636.71 4690.91 4800.00 3.918 10.066 4736.59 4790.79 4900.(X) 6.418 10.066 4836,18 4690.38 5000.{10 8.918 10.066 4935.27 498g.47 5100.00 ! 1.418 10.066 5033.70 5087.90 5200.00 13.918 10.066 5131~-5 5185.45 5300.00 16.4 ! 8 ! 0.066 5227.76 5281.96 5400.00 18.918 10.066 5323.04 5377.24 5500.00 21.418 10.066 5416.90 5471.10 5600.00 23.918 10.066 5509.17 5563.37 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.0~ E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19.N 0.00 E 167.19 N 0.00 E 167.19 N 0.00 E 167.19 N 0.OO E 167.88 N 0.12 E 172.4.6 N 0.g4 E 181.33 N 2.51 E 194.47 N 4.84 E 211.85 N 7.93 E 233.44 N 11.76 E 259.20 N 16.33 E 289.06 N 21.64 E 323.02 N 27.66 E 360.96 N 34.40 E Global Coordin~tes Dogleg Vertical Northings Eastings Rate Section (ft) (lq ("/lOOft) (ft) 5906S92.15 N 36,.~.84 E 0.000 167.10 5906,.~)2.15 N 3638~8.84 E 0.000 167.10 5906592.15 N 363888.84 E 0.OIX) 167.10 5906&:x92.15 N 36388~84 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 167.10 5906592.15 N 36388~84 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 t67.10 5906592.15 N 363888.84 E 0.000 167.10 5906592.15 N 36388&84 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 167.10 5906592.15 N 383888.84 E 0.000 167.10 5906592.15 N 363888~ E 0.000 167.10 5906592.15 N 363-_=~.64 E 0.000 167.10 5906592.15 N 363~_~-=_-__.~4 E 0.000 167.10 5906592.15 N 363888.84 E 0.000 167.10 ~,15 N 363888.84 E 0.O{~, 167.10 ~.15 N 363888.84 E O. IXIO 167.10 5g06592.15 N 363888.84 E 0.000 167.10 5906592,15 N 363888.84 E 0.(X~ 167,10 59~_~_~_.15 RI 363888.84 E 0.000 167.10 5906~92~ N 363~-_~-_-_96 E 2.500 167.79 5906597.41 N 363889.87 E 2.500 ~172.:34 5g0660B.25 N 363891.61 E 2.5(X) 191.15 5906619,34 N 363894.18 E 2.500 194.2~ 5906636.66 N 363897.57 E 2.500 211.47 5906658.18 N 363901.79 E 2.500 232.93 5906683.85 N 363906.83 E 2.500 258.52 5906713.63 N 363912.67 E 2.500 288.21 5906747.46 N 363919.30 E 2.500 321.94 5906785.28 N 363926.72 E 2.500 359.64 Alaska State Plane Zone 3 Badami CPF Comment Start Dir O 2.500°1100ft: 4643~ MD, 4634.20ft TVD 20 4larch, ~9<J8 . 16'.2I Sperry-Sun Drilling Services Proposal Report for B 1-14 Wp 7 Badami Measured Depth (lit) Incl. Azim, Sub-Sea fit) Vertical Local Coordinates Depth Northings Eastings (fl) (fi) (ft) 5700.00 26.418 10.066 5599.67 5653.87 5800,00 28.918 10-068 5688.23 5742.43 5900.00 31.418 10.066 5774.68 5828.88 6000.00 33.918 10.066 5858.~ 5913.05 6003.29 34.000 10,066 ,5861.58 5915.78 6100.00 33.890 9.69! 5941.81 5996.01 620,0.(X) 33.776 9.300 6024.87 6079.07 6300.00 33.665 8.907 6108.05 6162.25 6400.00 33.554 8.512 6191.33 6245.53 6500.00 33.445 8.115 6274.72 6328.92 6600.00 33.337 7.716 6358.21 6412,41 6700.00 33.230 7.314 6441.81 6496.01 6800,00 33, ! 25. 6.910 _~____ .51 6579.TI 6900.00 33.021 6.503 6609.31 6663,51 7000.00 32.918 6.095 6693.20 6747.40 7100.00 32.816 5.684 6777~ 6831.40 7158.06 . 32.758 5.444 6826.00 6880.20 7200,00 32.716 5.270 6861.29 6915.49 7300.00 32.618 4.855 6945.47 6999.67 7400.00 32.520 4.437 7029.74 7083.94 75{X),00 32.424 4.017 7114. ! ! 7168.31 7573.29 32.3,55 3.768 7176.00 72:30~0 7600.00 32.330 3.595 7198.56 7252,76 7700.00 32.236 3.171 7283,10 7337.::30 7800.00 32.145 2.745 7367.73 7421,93 7900.00 32.054 2.316 7452.45 7506.65 8000.00 31.966 1.885 7537.24 7591.44 8 ! 00.00 31.678 1.453 7622.12 7676.32 8200.00 31.792 ! .018 7707.08 7761.28 8300.00 31.708 0.580 7792.11 7846.31 402.83 N 41.83 E 448~55 N 49.95 E 49~.03 N 58.73 E 551.17 N 68. t6 E 552.97 N 68.48 E 606.18 N 77.75 E 661.09 N 86.93 E 715,91 N 95.72 E 770.62 N 104.10 E 825.23 N 112.08 E 879.74 N 119.66 E 934.15 N 126.84 E 988.45 N 133,61 E 1042.65 N 139.9~ E 10~i.74 N 145.9,6 E 1150.72 N 151.52 E 1182J)1 N 154.57 E 1204.60 N 156.69 E 1258.36 N 161.45 E 1312.01 N 165.81 E 1365.56 N 169.77 E 1404.73 N 172.42 E 1418.99 N 173.33 E 1472.30 N 176.48 E 1525.51 N 179.23 E 1578.59 N 181.57 E 1631.56 N 183.52 E 1684.42 N 185.06 E 1737.15 N 186.20 E 1789,77 N 186.93 E Global Coordinates Dogleg Vertical Northings Eas§ngs RMe Section (fi) (fl) (°/~0efl) (fl) 5906827.01 N 363934.94) E 2.,54X) 401.25 590687257 N 363943.~ E 2,500 446.67 5906921,88 N 363953.51 E 2.560 495.84 5906974.84 N 363963.89 E 2.500 548.64 5906976.65 N 363964.25 E 2.500 550.44 5907029.67 N 363974.47 E 0.245 603.31 5907084.41 N 3631)84.64 E 0.245 657.8,9 5907139.06 N 363994.40 E 0.245 712.39 5907193.62 N 364003.~ E 02.45 766.80 5607248.08 N 364012.73 E 0245 821.12 5907302.44 N 364021.29 E 0.245 875.36 5907356,71 N 364029,44 E 0.245 929,50 594)7410,88 N 364037,19 E 02.45 983,55 5907464.96 N 364044.54 E 0.245 1037.51 5907518.93 N 364051.48 E 0.245 1091,37 5907572,80 N 364058.02 E 02.45 1145,14 5907604.03 I~1 364061,63 E 0.245 ! 176.32 5907626.58 N 3~:A064.15 E 0,245 1198,82 5907680.25 N 364069.88 E 0.245 1252.40 5907733.8! N 364075,20 E 0.245 1305.88 59077~.28 N 364080.12 E 0.245 1359.27 5907826.39 N 364063,47 E 0.245 1398.33 5907640.63 N 364064,64 E 0.245 1412.55 5907893.89 N 36404~,75 E 0.245 1465.74 5907947.03 N 364092.45 E 0,245 1518.82 5908000.07 N 364095.75 E 0,245 .1571.80 59080,52.99 N 364098.64 E 0.245 1624.68 5908105.81 N 364101.13 E 0.245 1677.46 5908158.52 N 364103.22 E 0.245 1730,13 5908211.11 N 364104.90 E 0.245 1782,69 Alaska State Plane Zone 3 Badami CPF Comment BHATer~dency O 0.2.45°/100fl: 6003.29fl MD, 5915.780 TVD Top Mid Bm,oidan ('T'MBi0 Top West Sak 20 ~arch, 1998- I6:21 -3- Badami Measured (n) Incl. Sperry-Sun Drilling Services ..' Sub-Sea Vertical Local Coordinates Oepth Depth Norlhlngs Eastings (fl) (fl) {n) (fl) 8400.00 31.625 0.141 7877.22 7~31.42 8485.44 31.555 359.765 7950.00 8~420 8500.00 31.544 359.700 7962.41 8016.61 8~e00.00 31.464 359.257 8047.67 8101.87 8700.00 31.385 358.812 8133.O0 8187.20 88~).(X) 31.308 358.364 8218.41 8272.61 8~25.27 31.289 :358-251 8240.00 8294.20 8900.00 31.233 357,915 8,.'.'.'.'.'.'.'.'.~ .~8 8358.08 9000.00 31.159 357.464 8389.42 84.43.62 9012.36 31.150 357.408 8400.00 8454.20 9070.77 31.108 357.144 8450.00 8504.20 9100.00 31.067 357.011 8475.03 8529.23 9200.00 31.017 356.556 8560.70 8614.90 9500.00 30.815 355.181 8818.08 8872.28 9,600.00 30.75t 354.719 8903.99 8958.19 9800.00 30.628 353.789 9075.98 9130.18 9913.67 30.560 35~3____=757 9174.00 9228.20 10000.00 30.511 352.854 9248.18 9302.38 10200.00 30.401 351.912 9420.59 9474.79 10300.00 30.349 351.438 9506.86 9561.06 10400.00 30.298 350.963 9593.18 9647.38 1(N53.06 30.272 350.711 9639.00 9693.20 10500.0~ 30.249 350.487 9679.54 9733.74 10573.45 30.255 350.137 9743.00 9797.20 Proposal Report for B 1-14 Wp 7 1842.27 N 187.26 E 1887.02 N 187.22 E 1894.64 N 187.19 E 1946.89 N 186.71 E 1999.02 N 165.83 E 2051.03 N 184,55 E 2064.15 hi 184.17 E 2102.91 N 182.87 E 2154.66 N 180.78 E 2161.05 N 180.49 E 2191.22 N 179.06 E 22O6.29 N 178.29 E ~25'/.79 N 175.,10 E 2309.16 N 172.10E 2360.40 N 168,40 £ 2411.52 N 164.30 E 2462.49 N 159.79 E 2513.34 N 154.89 E 2564.06 N 149.57 E 2814.64 N 143.86 E 2621.64 N 143.04 E 2665.08 N 137.75 E 2715.39 N 131.23 E 276556 N 124.31 E 2784.38 N 121.61 E 2815.59 N 116.99 E 2865.48 N 109.27 E 2891.90 N 105.01 E 2915.24'N 101.14 E 2951.69 N 94.92 E Global Coordinates Dogleg Vertical Northings Eastings Rate Sec~n (Il) (fi) (°/100fi) (It) 590~263.59 N 364106.17 E 0245 1835.15 5908301}.34 N 364106.94 E 0-245 1879.88 5908315.96 N 364t07.04 E 0.245 1887.50 5908368.2.1 N 364107-50 E 0.245 1939.74 5908420.35 N ::364107,56 E 0.245 1991.87 5908472.37 N 364107.22 E 0.245 2043.89 5908485.50 N 364107.06 E 0.245 2067.02 5908524~°7 N 364106.46 E 0.245 2095.79 5908576.06 N 364105.31 E 0.245 2147.59 5908582.45 N 364105.13 E 0.245 2153.99 5~08612.63 N 364104.24 E 0.245 2184.18 s505027.72 N aa410a.74 £ 0.245 21ss~7 5808679~ N 364101.76 E 0.245 .2250.84 ssee781.ss N 36409~.62 E 0.245 2353,5a 5soea3a.18 N 3640~3.44 E 0.245 2404.64 5S0e~4~2 N 364meJ~s E 0.245 2455.94 5908935.14 N 354005J}6 E 0245 2506.92 s,oe~ N 364~1.48 E 0.24~ 2~57.79 ~.52 N ~07S. S~ E 0.245 280&S~ 590S043.64 N 354075.~ E O,245 2815.SS 5909087.16 N 364071.45 E 0.245 2658.14 ssoe137~a N 364055.~ E 0.245 270~.e4 SaOSl~7 N 3840~9,~2 E 0.245 2750.0t 5909206.73 N 364057.46 E 0.245 2778.90 ~.02 N 3640,~.40 E 0.245 2810-25 ~.05 N 364046.58 E 0.245 2860.37 5909~14.54 N 364042.79 E 0245 28~6.92 5909337.94 N 364039.35 E 0.245 2910.37 5909374.50 N 3640~t3.78 E 0.245 2947.00 Comment M90 Bas~ west ,s~ Top Canning 7" Oasing J2 F3 Alaska State Plane Zone 3 Badami CPF 20 Jlarch, 1998- 16:2I -4- ~ ~ Sperry-Sun Drilling Services Proposal Report for B 1-14 Wp 7 Badami Measured Sub-Sea Vertical Local Coordinates De~th Incl. Azim. Depth Depth Northings Eas6ngs (ft) (ti) (fi) fit) fit) Global Coordinates Dogleg Vertical Northings Eastings Rate Seclion ~) (ft) (onooft) (fi) 10587.89 30.208 350.0C~ 9755.48 9809.68 2958.85 N 93.67 E 10590.98 30.208 35~.~ 9758.15 9812.35 2960.38 N 93.40 E 10600.00 30.551 34:9.847 9765.93 9820.13 2964.87 N 92.61 E 10700.00 34.377 34:7.670 98,50.29 9904.49 3017.49 N 82.09 E 10800.00 38.235 345.882 993~.~ 9985.06 3075.11 N 68.51 E 10900.00 42.116 344.377 10007.26 10(}61.46 313'7.44 N 51.93 E 11000.00 46.013 343.083 10079.10 110133.30 3204.17 N 32.42 E 11027.48 47.087 342.757 10096.00 10152.20 3223.24 I~ 26.$6 E 11100.00 49.923 341.948 10146,(~5 10200.25 3275.00 N 10.09 E ! 1191.80 53.522 341.016 1 Q2.02.91 10257.11 3343.31 N 12.81 W 5909381.68 N 364032.66 E 0.245 2954.20 5909383.21 N 364032.42 E 0.000 2955.74 5909387.72 N 3~K}31.70 E 4.000 2960.25 5909440.52 N :364022.14 E 4.000 3013.19 5909498.37 N 364009.59 E 4.000 3071.22 5909560.99 N 363994.13 E 4.000 3134.05 5909628.06 N :363:975.63 E 4.000 3201.40 5909647.2.3 N 36,'.'.'.'.'.'.'.'3~0.31 E 4.000 3220.64 59(19699.28 N 363954.77 E 4.00O 3272.91 5909768.00 N 363933.10 E 4.0{X) :3341.94 11200.00 53.522 341_016 10207.78 10261.98 3349,55 N 14.96'W 11271.02 53.522 341.016 10250.00 1030420 3403.56 N 33,53 W 11300.00 53.522 341.016 10267.23 10321.43 3425.S8 N 41.11 W 11400.00 53.522 341.016 10326.68 10380.88 3501.62 N 67.27 W 11496.41 53.5,22 341.016 101384.00 10438.20 3574.93 N 92.49 W 5909774.27 N 363931.07 E 0.000 3348.24 5909828~ N 363913.47 E 0.000 3402.82 59{~850.76 N ~.28 E 0.0O0 3425.09 59(19827.25 N 383881.50 E 0.000 3501.94 591(X}01 .iX) N 363857.60 E 0.000 3576.04 11500.00 53,522 341.016 1038~.13 10440.33 3577,65 N 93.43 W 11600.00 53.522 341.016 10445.58 10499.78 3653.69 N 119.58 W 11600.36 53.522 341.016 10445.80 1050O.0O 3653.96 N 119.68 W 5910003.74 N 3~o3856.7t E 0.000 3578.79 5910080.24 N 363831.92 E 0.000 3655.64 5910080.51 N 363831.83 E 0.000 3655.92 All data is in feet unless otherwise stated. Directions and coordinates are relative to True Norlh. Vertical depths am relative to We~ Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100lt. Vertical Section is from Well Reference and calculated along an Azimuth of 358.124° (True). Based upon b~mimum Cuwature lype calculations, at a Measured Depth of 11600.36ft., The Bottom Hole Displacement is 3655.92ft., in the Direction of 358.124° (True). Alaska State Plane Zone 3 Badami CPF Comment End Dir, Sa~ O 30.208' ' 10587.Bgft MD, 9809.681t TVD Starl Dir O 4.{X)(Y'/100fl ' 10590.98R MD, 9812.35~t TVD F5 B1-14 TI~F5}, End Dir, Sail O 53.522": 11191.80ft MD, 10257.111t TVD Target: B1'-14T1 (F5), 100.00 Radius., Geological .~ 1-14 :T1~11{.I/~4)jl~ 1496.4 IR MD. 10438.20111'VD ame~ - (~5), 120.0o Radk~.. T th 1164K).36fl MO, 10500.00ft TVD 20 March, 199~- 16:21 - 5- Dr/71Ouest i~I!~1 L I-i N I~" 5631 $11verado Way #G Anchorage, Alaska 99518 (907) 563-32~6 Fax (g07) 563-7252 Shared Services Drilling Mike Cook Mike, Thc above mentioned well has been scanned using standard and-collision methods via DEAP. i I II II II I _ _ II Thc scan was performed with the following parameters: Start Scan Inspection Zeus End Scan Inspection Zone Starting Scan Radius Approved Well Close Approach Review B1-14 Wp6 Rate of Radius Increase (per 1000') 100.00'" : . . . Anti-Collision Scan summary: At the planned KOP thc Starting Scan Raclit~ is 0' larger than DEAP's default settings of 100' Start Scan Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DBAP's defaults would be equal to 100' at the Start Scan inspection Zone as stated above. These numbers are used to produce a final scan radius of 1260,036' which is 580,018' larger than DEAP's default value of 680.01 II I I1_1 I III I - - II II I _ [ '1 III ll I mai I I ii i _ I mini Iii At this enlarged radius the following wells w~re'~letected during the staff (Based on closed'Allowable" ' ' Deviation' "from' Plan'): Note: this list may not include all the wells de ,t?_t?., only those of whlch are of cone, era or m~ effe~t Tolmmee Line drawing! Comps_risen Sub_!ect_W_.¢ll Planne4J_WeH ,Relative ~ ShuSh RemlJlred? (Se_os_ration nOtcs) Status Well_.__.~.' Depth Se er_~ A;ghnuth ~ as Tested BI ,01 $99.84 'MD ! 30.09 ' 262.80 ltl .11 400.22 'MD 30,77 ' 263.80 3428.80 'MD 82,27 ' 265.10 B I-21 598.84 'MD 66.43 ' 100,40 BI-13 500.01 'MD 10,99' 249,60 BI-13 2960,28 'MD 65,98' 259,70 BI-13 5~,01 'MD 10,99 ' 249.60 BI-13 2960.28 'MD 68.98' 259,70 O1-15 499.73 'MD 10,27' 108.50 Bl-15 4704.52 'MD 168.10 '" 176.70 BI-15 6463.16 'MD 182.90' 248,30 124.~:~ ' Yea wall b not molto Minor Minor Minor ... 26,8~ ' Yea war1 i~aeeenli~e~ye~ 56,~ ' 61,42 ' _ y. ,~all h m4 onllau_ yet I,t)9 ' Plumed well ~ddedm scan fornff~eaee _1_ i · MN, or. _ Major Minor Minor ..... 6,1~ ' 130,37 ' ! 15.43 ' _ IL Plznned w~ll added ~o ~ for refit°ace Minor f~inor Minor i · ii Tolerance Plot required: _ i i i -: l · · ~.,11 i s _ _ iii ...... II I _ I __ .... I la YES Close Approach Comments: NOTE: Wells B1-13 and 81-15 are future wells added for re.v.I..e~, pu'q:..m, sea only. ~_ . Close Approach Scan Performed by: Checked by: Approved by: B1-14 Wpe,xla _ AWD Proximity Review 3/19/98 ,]re B~I-01:124 .S.5' allowable dcviatio, at $99.84' MD. (Shut-in Condition) ! BI-I I: 26.88' allowable deviation at 400.22' MD. (S-hut-in Condition) BI-21: 61.42' allowable deviation al 598.84' MD. (Shut-in Condition) _ allowable deviation at $00.01' MD, (Flowing condition) ! · Bl-13: 6,9',,ilowablc deviation at 500.01' MD. (Shut-in Condition) B l-IS: ~.17' allowable deviation at 4~.73' MD, (,Shut,in, Condition), 'Yne I;ieep I~OIo"(zo~Jo · TU) ClOSe apptoftc#~o are eib voile;we · · - - · _ im i mm I I il 11 i m_;i , __ m_ BI-13: Il .41' allowable deviation mt 2900.28' MD. (}qowl'ng'eo'ndlflon) BI-13: 47,95' alh,wablc deviation at 2960.28' MD. (Shut-In Condition) BI-IS: 130.37' allowable deviation at 4704.52' MD. (Shut-in C~. dltlon) B 1-15: I l $.43' a tlow~ble deviation at 6463.16' MD. (Shut-in Condi?ion), 't B1.14 Wp6.xl$ _ AWD Proximity Review 3119/98 Sperry-Sun Drilling Services Proposal Report for B1.14 Wp7 Badaml Alaska State Plane Zone 3 Badami CPF Measured Vertloal Vertical Dogleg Depth Incl. Azlm. Depth Northlngs Earrings Section Rate (ft) (ft) (ft) (fi) (ft) (°/10~) 0.00 0.000 0.000 0.00 0.00 N 0.00 E 0,00 300.00 0.000 0.000 300.00 0,00 N 0,00 E 0.00 0,000 1100,00 8,000 0.000 1097,40 55.76 N 0.00 E 55,73 1.000 1500.00 8,000 0.000 1493.61 111.43 N 0.00 E 111.37 0.000 2300.00 0.000 0,000 2290,91 167,19 N 0.00 E 167.10' 1,000 4-~63.29 0,000 0,000 4554.20 167,10 N 0.00 E 167.10 0.000 4643.29 0.000 0.000 4634,20 167.19 N 0,00 E 167.10 0.000 6003,29 34,000 10.088 5915,78 552.97 N 68.48 E ~50,44 2.500 10587.89 30.208 350.088 9809.68 2958,85 N 93.87 E 2954.20 0,245 10590.98 30.208 350.068 9812.35 2980.38 N 93.40 E 2955,74 0.000 11191.80 53.522 341.016 10267.11 3343.31 N 12,81 W 3341.94 4,000 11496.41 53,522 341.016 10438,20 3574.93 N 92.49 W 3576,04 0.000 11800.36 53.522 341,016 10500.00 3653.96 N 119.88 W 3855,92 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well Reference. Northlngs and Ea~flng$ are relative to Well Reference. The Dogleg Severity is In Degrees per 100ft, Vertical Section is from Well Reference and calculated along an Azimuth of 358,124° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11600,36ft,, The Bottom Hole Displacement Is 3655.92ff., in the Direction of 358.124° (True). Corn men ts Measured Depth 300.00 1100.00 1500.00 2300.00 4643.29 6003.29 10587.89 10590,96 11191.8O 11496.41 11600.38 Station Coordinates TVD Northlngl Eaatlnga (t~) (fi) (ft) 300,00 0,00 N 0,00 E 1097.40 55,76 N 0.00 E 1493.51 111,43 N 0.00 E 2290,91 187,19 N 0,00 E 4634.20 167,19 N 0.00 E 5915,78 552.98 N 68,48 9809,68 2958,86N 93,67 9812.35 2960,38 N 93.40 0257.11 3343.31 N 12,81W 0438.20 3574.93 N 92.49W 0500.00 3653.96N 119.88W Comment KOP: ~tarl Dtr 0 1,000'/10Oft: 300,00ti MD, 300,00ft TVD End DIr, Sa.ti O 8,000"; 1100,0Oft MD, 1097,4011 TVD Stall DIr O 1.000°/lO0ft: lS00.00ft MD, 1493.51ft TVD End DIr, Sari ~ 0.000°: 2300,00ft MO, 2290,9111 TVD Start DIr · 2,500°/10011: 4643.29ft MD, 4634,20ff 'i'VD BHA Te~denc'y ~ 0.245°/100ff: 6003,28ft MD, 5915,7811 TVD End Olr, Sail O 30.208': 10587.89ft MD, 9809,68fl TVD Start DIr · 4,000'/100ft: I0590,98ff MD, 9812.35ff TVD 1- 4 T1 F ) End DIr, Sail O 53,522': 11191,80fl MD, 191-14 T3 (^5): , 1499.41t1 MI:). 1043e.,oft 'rvD Tolat Del3th; 11800,36ft MD, 10600.0011 TVD Formation Tope Measured Ve~lcal 8ub-8ea Depth Depth Depth (~) (~) (~) 1993,14 1984.20 1930,00 7158.05 6880,20 6826.00 7573.29 7230.20 7176,00 8485.44 8004,20 7950.00 8825,27 8294.20 8240,00 9012,36 8454.20 8400,00 9913.87 8228,20 9174.00 10237.58 9507.20 9453,00 10453,06 9693.20 9839.00 10573.45 9797.20 9743,00 11027.48 10152,20 10098,00 11271,02 10304.20 10250.00 No, hinge (h) 158,97 N 1182.01N 1404,73 N 1887,02 N 2064,16 N 2181.05 N 2621,64 N 2784.~8N 2891.90 N 2951.89 N 3223.24N 3403.~5 N Eaetlnge Formation Name (fi) 0,00 E Base Permafrost. 164.57 E Top Mid Brooldan (TMBIO 172,42 E Top West 8ak 187.22 E M~0 184,17 E Ba~a West Sak (M85) 180.48 E Top Canning 143.04 E 8hallowed1 Baclaml 8and (F2) 121,6,1 E K2n 105,01 E J2 94.82 E F3 26,56 E F5 33.53 W A6 Conttnuecl.. , 20 March, 1998 - 16:21 .1 - DrlllQues! DATE I CHECK NO. VENDOR ~LASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 021798 C½021798D 100. O0 100. O0 HANDLING INST: s/h kathy campoamo~ x 512~ rile A~ACHED CHECK IS IN PAYME~ FOR ~US DE~RIBEO A~VE. ~ fl~ ~11 ~ ~ · WELL PERMIT CHECKLIST COMPANY FIELD & POOL O~4:~/' O c..) INIT CLASS WELL NAME~.~/ .... ~ A//% PROGRAM: exp [] dev [] redrl, [] serv/~wellbore seg E ann. disposal para req" OEOb AREA ~"'~'4::~ UNIT# //O.~ O'~ ON/OFF SHORE ~::~,~ ADMINISTRATION ,~R DATE, · , _ 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... N Lease number appropriate ................... N Unique well name and number .................. N Well located in a defined pool .................. N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ N If deviated, is wellbore plat included ............... N Operator only affected party ................... N Operator has appropriate bond in force ............. N Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING APPR D .TE 14. Conductor string provided ................... (~ 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 2~,. 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N ~/.,,'"' 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ...... ,.,,:.... ...... N 26. BOPE press rating appropriate; test to ~ 2>¢:~::' .psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~'~/,Y N ' 31. Data presented on potential overpressure zones ....... Y,,,~ ~,~, 32. Seismic analysis of shallow gas zones .............. -33. Seabed condition survey (if off-shore) ........... L.~__ Y N 34. Contact name/phone for we.eklypro[lress reD?ts .... ,¢¢.'. Y N lexp~ora~ory on~yl REMARKS GEOLOGY: ENGINEERING: COMMISSION: BE~:~/'~5' DWJ ...~../ JDH,(¢~- RNC '__~~ co 6o Commentsllnstructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 12976.tmp created Thu May 21 15:51:27 1998 by CLEANUP V1.0 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 21 MAY 98 ISL Input File Name - 12976 ISL File 1 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 11546.5 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 9915.0 (F) File 1 - Log Header Information LOG HEADER LISTING -- Log Heading: HIGH DEFINITION INDUCTION LOG Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-14 BADAMI NORTH SLOPE ALASKA SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11523.0 11523.0 9929.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: Rge: 20E Drilling Fluid Type: Dens i ty: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 10033.0 0.0 0.0 10032.0 0.0 0.0 0.00 0.00 0.00 0.0 0.0 0.0 KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS ~ MEASURED / MEASURED 0.281 at 71.000 Page 1 -+ RECEIVED 27 1998 Alaska ~ & Gas Cons. Commission Anchorage Rmc: Time Circ. StopDed: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: LoGGinG Unit Location: LoGGinG Company Code: Recorded by: Witnessed by: 0. 214 at 71. 000 0. 499 at 71. 000 11 HOURS 179.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN + .... ISL ......... ISL .... + LOG HEADER LISTING Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. THE HDIL CURVES PRESENTED ARE TRUE VERTICAL RESOLUTION CURVES. THE HDIL TOOL WAS RUN "FREE" (NO STANDOFFS) TO AID IN GETTING THE TOO HOLE. DUE TO THE POSITION OF THE TOOL, THE 10" DEPTH OF INVESTIGATIO RESISTIVITY CURVE WAS ERRATIC AND NOT PRESENTED. Other Services:- ZDL/CN STAR_II Equipment Numbers:- + .... ISL - ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 DT 1 1 TT 1 1 ServID Stat InUnit OutUnit Start Stop LIS 01 ALLO F F 11546.500 9915.000 LIS 01 ALLO US/F US/F -999.250 -999.250 LIS 01 ALLO MS MS -999.250 -999.250 File 1 - Comments Listing File does not contain any c File 2 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 2 LIS File Nbr - 002 Start - Stop Depth : 11546.5 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 9915.0 (F) File 2 - Log Header Information + ......... LOG HEADER LISTING Page 1 -+ Log Heading: HIGH DEFINITION INDUCTION LOG Company: Well: Field: County: State: Nation: Location: Field Location: Sec: 8.000000000000000000 Twp: 9N Latitude: BP EXPLORATION (ALASKA), INC. Bl-14 BADAMI SURFACE: 1257' FNL & 125' FEL Rge: 20E Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. Elevations:- 0.0 KB: 54.2 R.K.B. DF: 53.2 R.K.B. GL: 19.1 Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 11525.0 11523.0 11523.0 9929.0 10033.0 0.0 0.0 10032.0 0.0 0.0 0.00 0.00 0.00 0.0 0.0 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED 0.281 0.214 0.499 11 HOURS / MEASURED at 71.000 at 71.000 at 71.000 179.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN ISL ISL .... + LOG HEADER LISTING Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. THE HDIL CURVES PRESENTED ARE TRUE VERTICAL RESOLUTION CURVES. THE HDIL TOOL WAS RUN "FREE" (NO STANDOFFS) TO AID IN GETTING THE TOO HOLE. DUE TO THE POSITION OF THE TOOL, THE 10" DEPTH OF INVESTIGATIO RESISTIVITY CURVE WAS ERRATIC AND NOT PRESENTED. Other Services:- ZDL/CN STAR_II Equipment Numbers:- + .... ISL ............... ISL .... + File 2 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat InUnit OutUnit Start Stop DEPT 1 1 LIS 01 ALLO F F 11546 CHT 1 1 LIS 01 ALLO LBF LBF -999 DEPT 1 1 LIS 02 ALLO F F 11546 GR 1 1 LIS 01 ALLO GAPI GAPI -999 SP 1 1 LIS 01 ALLO MV MV -999 TEN 1 1 LIS 01 ALLO LBF LBF -999 WTBH 1 1 LIS 01 ALLO DEGF DEGF -999 MOC1 1 1 LIS 01 ALLO MMHO M~HO -999 MOC2 1 1 LIS 01 ALLO MMHO MMHO -999 MOC3 1 1 LIS 01 ALLO MMHO MMHO -999 MOC6 1 1 LIS 01 ALLO MMHO MMHO -999 MOC9 1 1 LIS 01 ALLO MMHO MMHO -999 MOCX 1 1 LIS 01 ALLO MMHO MMHO -999 MOR1 1 1 LIS 01 ALLO OHMM OHMM -999 MOR2 1 1 LIS 01 ALLO OHMM OHMM -999 MOR3 1 1 LIS 01 ALLO OHNIM OHMM -999 MOR6 1 1 LIS 01 ALLO OHMM OHMM -999 MOR9 1 1 LIS 01 ALLO OHMM OH~M -999 MORX 1 1 LIS 01 ALLO OHMM OHM/~ -999 .500 9915 .250 -999 .500 9915 .250 -999 .250 -999 .250 -999 .250 156 .250 -999 .250 -999 .250 -999 .250 -999 .250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 .000 .250 .000 .250 .250 .250 .543 .250 .250 .250 250 250 250 250 250 250 250 250 250 File 2 - Comments Listing File does not contain any c File 3 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 3 LIS File Nbr - 003 Start - Stop Depth : 11547.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File TIDe - Reel Comments - Tape Comments - 11185.5 (F) File 3 - Log Header Information + LOG HEADER LISTING Log Heading: HIGH DEFINITION INDUCTION LOG Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-14 BADAMI SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Rge: 20E Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11523.0 11523.0 9929.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 10033.0 10032.0 0.00 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED 0.281 0.214 0.499 11 HOURS / MEASURED at 71.000 at 71.000 at 71.000 179.0 3880T Page 1 -+ Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: .... ISL 150. 0000000000000000 E. MURPHY MR. D. GOODWIN ISL .... + LOG HEADER LISTING Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. THE HDIL CURVES PRESENTED ARE TRUE VERTICAL RESOLUTION CURVES. THE HDIL TOOL WAS RUN "FREE" (NO STANDOFFS) TO AID IN GETTING THE TOO HOLE. DUE TO THE POSITION OF THE TOOL, THE 10" DEPTH OF INVESTIGATIO RESISTIVITY CURVE WAS ERRATIC AND NOT PRESENTED. Other Services:- ZDL/CN STAR_II Equipment Numbers:- + .... ISL ISL .... + File 3 - Channel Listing Mnem NbrSamp NbrEntry DEPT DT TT ServID Stat InUnit OutUnit Start Stop 1 1 LIS 01 ALLO F F 11547.000 11185.500 1 1 LIS 01 ALLO US/F US/F -999.250 -999.250 1 1 LIS 01 ALLO MS MS -999.250 -999.250 File 3 - Comments Listing File does not contain any c File 4 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 4 LIS File Nbr - 004 Start - Stop Depth : 11547.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 11185.8 (F) File 4 - Log Header Information + LOG HEADER LISTING Log Heading: HIGH DEFINITION INDUCTION LOG Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-14 BADAMI SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11523.0 11523.0 9929.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 10033.0 10032.0 0.00 0.0 0.0 0.0 0.00 0.0 Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 Page 1 -+ Drilling Fluid Type: Dens i ty: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: ISL KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED 0.281 0.214 0.499 11 HOURS / MEASURED at 71.000 at 71.000 at 71.000 179.0 3880T BADAMI 150.0000000000000000 E. MI/RPHY MR. D. GOODWIN ISL .... + LOG HEADER LISTING Page 2 -+ Remarks: - LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. THE HDIL CURVES PRESENTED ARE TRUE VERTICAL RESOLUTION CURVES. THE HDIL TOOL WAS RUN "FREE" (NO STANDOFFS) TO AID IN GETTING THE TOO HOLE. DUE TO THE POSITION OF THE TOOL, THE 10" DEPTH OF INVESTIGATIO RESISTIVITY CURVE WAS ERRATIC AND NOT PRESENTED. Other Services:- ZDL/CN STAR_II Equipment Numbers:- + .... ISL ISL .... + File 4 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat InUnit OutUnit Start Stop DEPT 1 1 LIS 01 ALLO F F 11547.000 MOC1 1 1 LIS 01 ALLO MMHO MMHO -999.250 MOC2 1 1 LIS 01 ALLO MMHO M14HO -999.250 MOC3 1 1 LIS 01 ALLO MMHO MMHO -999.250 MOC6 1 1 LIS 01 ALLO MMHO MMHO -999.250 MOC9 1 1 LIS 01 ALLO MMHO MMHO -999.250 MOCX 1 1 LIS 01 ALLO MMHO MMHO -999.250 MOR1 1 1 LIS 01 ALLO OHMM OHMM -999.250 MOR2 1 1 LIS 01 ALLO OHMM OHMM -999.250 MOR3 1 1 LIS 01 ALLO OHUIM OHFiM -999.250 MOR6 1 1 LIS 01 ALLO OHMM OHMM -999.250 MOR9 1 1 LIS 01 ALLO OHMM OHMM -999.250 MORX 1 1 LIS 01 ALLO OHMM OHM14 -999.250 CHT 1 1 LIS 01 ALLO LBF LBF -999.250 DEPT 1 1 LIS 02 ALLO F F -999.250 GR 1 1 LIS 01 ALLO GAPI GAPI -999.250 SP 1 1 LIS 01 ALLO MV MV -999.250 TEN 1 1 LIS 01 ALLO LBF LBF -999.250 WTBH 1 1 LIS 01 ALLO DEGF DEGF -999.250 11185.750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 11185 750 -999 250 -999 250 -999 250 176 630 File 4 - Comments Listing File does not contain any c 12977.tmp created Thu May 21 16:16:21 1998 by CLEANUP Vi. 0 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 21 MAY 98 ISL Input File Name - 12977 ISL File 1 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 10051.5 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 8701.2 (F) File 1 - Log Header Information LOG HEADER LISTING Log Heading: SEGMENTED BOND TOOL Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA), INC. Bl-14 NORTH SLOPE ALASKA SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Rge: 20E Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 Date: Run No: 0/ 0/ 0 2.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 10033.0 10032.0 10032.0 8710.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: KCL-POLYMER (WBM) 12.20 0.00 0.00 0.00 / 0. 000 at 0,000 Page 1 -+ 0.0 0.0 0.00 0.0 RECEIVED MAY 27 199 3 Alaska Oil & Gas Con6. Commission Anchorage Time Circ. Stopped: Time Logger on Bott.: Max. Recorded TemD.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: 0.000 at 0,000 0.000 at 0.000 1600. 000000000000000 0.0 3880T BADAMI 150. 0000000C00000000 E. MURPHY DICK MASKELL + .... ISL ISL .... + LOG HEADER I,ISTING Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAII,ABLE AT TIME OF LOG. INTERVAL NOT PREVIOUSLY LOGGED WITH WIRELINE TOOLS. DEPTH CONTROL WA OF MARKED LINE GAMMA RAY. Other Services:- HDIL/MAC/GR ZDL/CN/GR STAR_II/GR Equipment Numbers:- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 GR 1 1 ServID Stat InUnit OutUnit LIS 01 ALLO F F LIS 01 ALLO GAPI GAPI Start Stop 10051.500 8701.250 -999.250 -999.250 File 1 - Comments Listing File does not contain any c 12978.tmp created Thu May 21 16:05:23 1998 ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 21 MAY 98 ISL Input File Name - 12978 ISL File 1 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth : 11540.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 9981.5 (F) File 1 - Log Header Information LOG HEADER LISTING Log Heading: COMPENSATED Z-DENSILOG Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA), INC. Bl-14 BADAMI NORTH SLOPE ALASKA SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11522.0 11522.0 9995.0 Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 Casing - Driller: 10033.0 0.0 0.0 Casing - Logger: 10032.0 0.0 0.0 Casing: Weight: 0.00 0.00 0.00 Bit Size: Depth: 0.0 0.0 0.0 Drilling Fluid Type: Dens i ty: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED / MEASURED 0.281 at 71.000 Page 1 -+ RECEIVED MAY 27 1998 Alaska Oil & Gas Cons. Commission Anchorage Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: + .... ISL 0. 214 at 71. 000 0. 499 at 71. 000 8 HOURS 168.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN ISL .... + LOG HEADER LISTING Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. CNC IS CALIPER AND SALINITY CORRECTED. CL = 18000 PPM. EQUIVALENT NACL = 29610 PPM. BVOL = TOTAL BOREHOLE VOLUME = 325 CU. FT. CVOL = ANNULAR VOLUME COMPUTED FOR 4.5" CASING = 160 CU. FT. REPEAT SECTION WAS RECORDED AT 8 SAMPLES/FT. Page 2 -+ Other Services:- HDIL/MAC STAR_II Equipment Numbers:- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry DEPT CAL CHT CNC DEPT GR PE PORZ TEN ServID Stat InUnit OutUnit Start 1 1 LIS 01 ALLO F F 11540.000 1 1 LIS 01 ALLO IN IN -999.250 1 1 LIS 01 ALLO LBF LBF -999.250 1 1 LIS 01 ALLO PU PU -999.250 1 1 LIS 02 ALLO F F 11540.000 1 1 LIS 01 ALLO GAPI GAPI -999.250 1 1 LIS 01 ALLO B/E B/E -999.250 1 1 LIS 01 ALLO PU PU -999.250 1 1 LIS 01 ALLO LBF LBF -999.250 Stop 9981.500 -999.250 -999.250 -999.250 9981.500 -999.250 -999.250 -999.250 -999.250 - WTBH ZCOR ZDEN 1 1 LIS 1 1 LIS 1 1 LIS 01 ALLO DEGF DEGF -999. 250 150. 944 01 ALLO G/C3 G/C3 -999. 250 -999. 250 01 ALLO G/C3 G/C3 -999.250 -999.250 File 1 - Comments Listing File does not contain any c File 2 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 2 LIS File Nbr - 002 Start - Stop Depth : 11400.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 11050.5 (F) File 2 - Log Header Information ~- LOG HEADER LISTING Log Heading: Company: Well: Field: County: State: Nation: Location: Field Location: COMPENSATED Z-DENSILOG BP EXPLORATION (ALASKA), INC. Bl-14 SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: O/ O/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 11525.0 11522.0 11522.0 9995.0 10033.0 10032.0 0.00 0.0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: KCL- POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED 0.281 0.214 0.499 / MEASURED at 71.000 at 71.000 at 71.000 Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 Page 1 -+ Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: + .... ISL -- 8 HOURS 168.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN ISL .... + LOG HEADER LISTING ................. Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. CNC IS CALIPER AND SALINITY CORRECTED. CL = 18000 PPM. EQUIVALENT NACL = 29610 PPMo BVOL = TOTAL BOREHOLE VOLUME = 325 CU. FT. CVOL = ANNULAR VOLUME COMPUTED FOR 4.5" CASING = 160 CU. FT. REPEAT SECTION WAS RECORDED AT 8 SAMPLES/FT. Page 2 -+ Other Services:- HDIL/MAC STAR_II Equipment Numbers:- + .... ISL ISL .... + File 2 - Channel Listing Mnem NbrSamp NbrEntry DEPT 1 1 TEN 1 1 ServID Stat InUnit OutUnit LIS 01 ALLO F F LIS 01 ALLO LBF LBF Start 11400.000 -999.250 Stop 11050.500 -999.250 File 2 - Comments Listing File does not contain any c File 3 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 3 LIS File Nbr - 003 Start - Stop Depth : 11400.0 - Service Name - LIS Service Sub Name - ECLIPS Origin of Data - File Type - Reel Comments - Tape Comments - 11050.5 (F) File 3 - Log Header Information + LOG HEADER LISTING --- Page 1 -+ Log Heading: COMPENSATED Z-DENSILOG Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA), INC. Bl-14 BADAMI SURFACE: 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: M.S.L. 0.0 R.K.B. R.K.B. Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525 11522 11522 9995 .0 .0 .0 .0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 10033.0 10032.0 0.00 0.0 0.0 0.0 0.00 0.0 Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: KCL-POLYMER (WBM) 12.20 46.00 8.20 2.40 MUD PITS MEASURED 0.281 0.214 0.499 8 HOURS / MEASURED at 71.000 at 71.000 at 71.000 168.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN + .... ISL ISL .... + LOG HEADER LISTING Page 2 -+ Remarks:- LOG SCALED AND PRESENTED AS PER CUSTOMER REQUEST. N/A MEANS NOT APPLICABLE OR NOT AVAILABLE AT TIME OF LOG. CNC IS CALIPER AND SALINITY CORRECTED. CL = 18000 PPM. EQUIVALENT NACL = 29610 PPM. BVOL = TOTAL BOREHOLE VOLUME = 325 CU. FT. CVOL = ANNULAR VOLUME COMPUTED FOR 4.5" CASING = 160 CU. FT. REPEAT SECTION WAS RECORDED AT 8 SAMPLES/FT. Other Services:- HDIL/MAC STAR_II Equipment Numbers:- + .... ISL ISL .... + File 3 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat InUnit OutUnit Start DEPT 1 1 LIS 01 ALLO F F CAL 1 1 LIS 01 ALLO IN IN CHT 1 1 LIS 01 ALLO LBF LBF CNC 1 1 LIS 01 ALLO PU PU DEPM 1 1 LIS 01 ALLO F F GR 1 1 LIS 01 ALLO GAPI GAPI PE 1 1 LIS 01 ALLO B/E B/E PORZ 1 1 LIS 01 ALLO PU PU WTBH 1 1 LIS 01 ALLO DEGF DEGF ZCOR 1 1 LIS 01 ALLO G/C3 G/C3 ZDEN 1 1 LIS 01 ALLO G/C3 G/C3 11400.000 -999.250 -999 250 -999 250 11398 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 Stop 11050 -999 -999 -999 -999 -999 -999 -999 164 -999 -999 500 250 250 250 250 250 250 250 654 250 250 File 3 - Comments Listing File does not contain any c ISL ISL Summary Listing - version 1.01 ISL ISL Date Processed - 22 MAY 98 ISL Input File Name - bl-14_star ISL File 1 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 1 LIS File Nbr - 001 Start - Stop Depth Service Name - LIS Service Sub Name - Origin of Data - File Type - Reel Comments - Tape Comments - : 10452.0 - 11446.0 (F) File 1 - Log Header Information LOG HEADER LISTING Page 1 -+ Log Heading: SIMULTANEOUS ACOUSTIC AND Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-14 BADAM I NORTH SLOPE ALASKA 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: 0.0 Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11522.0 11434.0 10500.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: ~ Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: KCL-POLYMER (WBM) 12.20 46.00 8.20 0.00 MUD PITS MEASURED 0.281 0.214 0.499 8 HOURS / MEASURED at 71.000 at 71.000 at 71.000 170.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 + .... ISL ISL .... + LOG HEADER LISTING Pa~e 2 -+ Remarks:- ANALYST: MITCH D. PAVLOVIC, GEOLOGIST Other Services:- Equipment Numbers:- + .... ISL ISL .... + File 1 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat InUnit OutUnit Start Stop DEPT 1 1 LIS 01 ALLO F F 10452.000 11446.000 GR 1 1 LIS 01 ALL0 GAPI GAPI -999.250 -999.250 File 1 - Comments Listing File does not contain any comment records File 2 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 2 LIS File Nbr - 002 Start - Stop Depth : 10452.0 - 11446.0 (F) Service Name - LIS Service Sub Name - Origin of Data - File Type - Reel Comments - Tape Comments - File 2 - Log Header Information LOG HEADER LISTING -- Page 1 -+ Log Heading: Company: Well: Field: County: State: Nation: Location: Field Location: SIMULTANEOUS ACOUSTIC AND BP EXPLORATION (ALASKA), INC. Bl-14 BADAMI 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: 0.0 Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 11525.0 11522.0 11434.0 10500.0 0.0 0.0 0.00 0.0 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: ~ Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: KCL-POLYMER (WBM) 12.20 46.00 8.20 0.00 MUD PITS MEASURED 0.281 0.214 0.499 8 HOURS / MEASURED at 71.000 at 71.000 at 71.000 170.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 + .... ISL ISL .... + + ......... LOG HEADER LISTING Remarks:- ANALYST: MITCH D. PAVLOVIC, GEOLOGIST Page 2 -+ Other Services:- Equipment Numbers:- + .... ISL ISL .... + File 2 - Channel Listing Mnem NbrSamp NbrEntry ServID Stat InUnit OutUnit Start Stop DEPT 1 1 LIS 01 ALLO F F 10452.000 AZ 1 1 LIS 01 ALLO DEG DEG -999.250 DAZ 1 1 LIS 01 ALLO DEG DEG -999.250 DEV 1 1 LIS 01 ALLO DEG DEG -999.250 ETMD 1 1 LIS 01 ALLO MS MS -999.250 GAZF 1 1 LIS 01 ALLO G'S G'S -999.250 QA 1 1 LIS 01 ALLO MG'S MG'S -999.250 QB 1 1 LIS 01 ALLO GAMM GAMM -999.250 QM 1 1 LIS 01 ALLO DEG DEG -999.250 RAZ 1 1 LIS 01 ALLO MV MV -999.250 RB 1 1 LIS 01 ALLO DEG DEG -999.250 RBOF 1 1 LIS 01 ALLO DEG DEG -999.250 ZACC 1 1 LIS 01 ALLO G'S G'S -999.250 ETMC 1 1 LIS 01 ALLO MS MS -999.250 DEPC 1 1 LIS 01 ALLO F F -999.250 DEPF 1 1 LIS 01 ALLO F F -999.250 QDC 1 1 LIS 01 ALLO F/M~ F/MN -999.250 QDEP 1 1 LIS 01 ALLO F/MN F/MN -999.250 DBDC 1 1 LIS 01 ALLO F F -999.250 DBDF 1 1 LIS 01 ALLO F F -999.250 11446.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 File 2 - Comments Listing File does not contain any comment records File 3 - File Header Information Reel Nbr - 1 Tape Nbr - 1 File Nbr - 3 LIS File Nbr - 003 Start - Stop Depth Service Name - LIS Service Sub Name - Origin of Data - File Type - Reel Comments - Tape Comments - 10452.0 - 11446.0 (F) File 3 - Log Header Information LOG HEADER LISTING Page 1 -+ Log Heading: SIMULTANEOUS ACOUSTIC AND Company: Well: Field: County: State: Nation: Location: Field Location: BP EXPLORATION (ALASKA) , INC. Bl-14 BADANI 1257' FNL & 125' FEL Sec: 8.000000000000000000 Twp: 9N Latitude: Longitude: Permanent Datum: Elevation of Permanent Datum: Log Measured From: Drilling Measured From: 0.0 Date: Run No: 0/ 0/ 0 1.000000000000000000 Depth - Driller: Depth - Logger: Bottom Log Interval: Top Log Interval: 11525.0 11522.0 11434.0 10500.0 Casing - Driller: Casing - Logger: Casing: Weight: Bit Size: Depth: 0.0 0.0 0.00 0.0 0.0 0.0 0.00 0.0 Rge: 20E Elevations:- KB: 54.2 DF: 53.2 GL: 19.1 0.0 0.0 0.00 0.0 Drilling Fluid Type: Density: ~ Viscosity: Ph: Fluid Loss: Source of Sample: Source Rmf/Rms: Rm: Rmf: Rmc: Time Circ. Stopped: Time Logger on Bott.: Max. Recorded Temp.: Logging Unit Number: Logging Unit Location: Logging Company Code: Recorded by: Witnessed by: KCL-POLYMER (WBM) 12.20 46.00 8.20 0.00 MUD PITS MEASURED 0.281 0.214 0.499 8 HOURS / MEASURED at 71.000 at 71.000 at 71.000 170.0 3880T BADAMI 150.0000000000000000 E. MURPHY MR. D. GOODWIN + .... ISL .... ISL .... + LOG HEADER LISTING Remarks:- ANALYST: MITCH D. PAVLOVIC, GEOLOGIST Page 2 -+ Other Services:- Equipment Numbers:- + .... 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