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Home My WebLink About205-0637. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NK-65A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-063 50-029-22869-01-00 14208 Conductor Surface Intermediate Production Liner 9991 80 6217 8487 5866 13827 20" 9-5/8" 7" 4-1/2" 9620 28 - 108 27 - 6244 26 - 8513 8342 - 14208 28 - 108 27 - 5163 26 - 6697 6579 - 9991 None 1500 3090 5410 7500 13827, 13860, 14010 3060 5750 7240 8430 13727 - 14134 4-1/2" 12.6# L-80 25 - 8357 9522 - 9919 Structural 4-1/2" Baker S-3 Packer 2105, 2099 8300 6549 Bo York Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-930-5990 PRUDHOE BAY, Raven Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034630, 0034635 25 - 6589 N/A N/A 4 1 4114 102 1947 120 1402 1256 536 526 N/A 13b. Pools active after work: Raven Oil 4-1/2" BBE SSSV 8300, 6549 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 12:32 pm, Jun 20, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.17 16:10:10 - 08'00' Bo York (1248) JJL 6/30/25 DSR-6/23/25 RBDMS JSB 062725 ACTIVITY DATE SUMMARY 5/24/2025 ***WELL S/I ON ARRIVAL*** TAGGED BBE @ 2,105' MD PULLED BBE @ 2,105' MD TAGGED CIBP @ 13,860' MD ***COTINUE ON 5/25/25*** 5/25/2025 ***CONTINUED FROM 5/24/25*** RIG DOWN ***WELL LEFT S/I*** 5/29/2025 ***WELL SHUT IN ON ARRIVAL*** (PLUG SET) RIG UP AK E-LINE (SET CIBP) PT 250L 3000H, FUNCTION TEST WLV'S TIE INTO HES PERF RECORD DATED 17-OCT-2021 SET 3.50" CIBP @ 13827' CCL STOP DEPTH=13815.9 (CCL-ME=11.1'), TAG AFTER SET ***WELL SHUT IN ON DEPARTUREP*** JOB COMPLETE 5/29/2025 *** WELL S/I ON ARRIVAL *** BRUSHED SSSV NIP @ 2105'MD TAGGED SSSV NIP w/3.85'' G-RING ATTEMPTED TO CHANGE PACKING STACK ON SSSV BUT FOUND DAMAGED THREADS, RIG DOWN ***WELL LEFT S/I ON ARRIVAL*** 6/2/2025 ***WELL S/I ON ARRIVAL*** BRUSHED SVLN @ 2105' MD SET 4-1/2" BBE IN SVLN PERFORMED A GOOD DDT ON BBE ***WSR CONT ON 6/3*** 6/3/2025 *** WSR CONT FROM 6/2 *** POLLARD #63 RIG DOWN *** WELL LEFT S/I ON DEPARTURE *** Daily Report of Well Operations PBU NK-65A 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NK-65A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-063 50-029-22869-01-00 ADL 0034630 , 0034635 14208 Conductor Surface Intermediate Production Liner 9991 80 6205 8487 5866 13860 20" 9-5/8" 7" 4-1/2" 9652 28 - 108 27 - 6244 26 - 8513 8362 - 14208 3440 28 - 108 27 - 5163 26 - 6697 6579 - 9991 none 1500 3090 5410 7500 13860 , 14010 3060 5750 7240 8430 13727 - 14134 4-1/2" 12.6# L-80 25 - 83579522 - 9919 Structural 4-1/2" Baker S-3 Perm , 8300 , 6549 4-1/2" BBE 2106 2099 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY 4-6-24 Current Pools: RAVEN OIL Proposed Pools: BROOKIAN UNDEFINED OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:24 am, Mar 22, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.21 18:54:03 - 08'00' Bo York (1248) 3440 DSR-3/29/24MGR29MAR24 10-404 * AOGCC to witness slickine tag (TOC ~ 13,625' MD) and pressure test (to 3000 psi) of cement plug. SFD 3/27/2024JLC 4/1/2024 NK-65A : Brookian Recomplete PTD: 205063 Page 1 of 10 Well Name:NK-65A API Number:50-029-22869-01 Current Status:Operable, Shut in Permit to Drill Number:205063 Estimated Start Date:April 2024 Rig:CT/SL/EL Regulatory Contact:Carrie Janowski Estimated Duration:5 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Brief Well Summary: NK-65A was originally drilled as a Raven injector at Niakuk. In November 2021 it was converted from an injector to a producer in the Raven pool. In September 2022, a plug was set to isolate the Ivishak, and perforations were added in the Sag C and D targeting rich gas, but this production eventually became high GOR and not competitive. With the Raven pools uncompetitive production, the opportunity exists to test the potential of the Brookian formation at Niakuk. Objective: Abandon Niakuk Raven Pool. Perforate and test Brookian Undefined Pool (640132). Current Bottom Hole Pressure (Raven):4,491 psi at 9,850 TVDss Estimated Bottom Hole Pressure (Brookian):4,322 psi at 8,820 TVDss Max. Anticipated Surface Pressure:3,440 psi 0.1psi/ft gas gradient to surface Last Shut-in WHP:1,300 psi WSR 8/15/23 Min. ID:3.725 Max. Deviation:65.5 deg at 12,125 H2S Concentration:3 PPM 1/15/23 Existing Casing/Tubing Program: String Pipe #/ft Grade Connection Top Bottom Surface Csg. 9-5/8 40 L-80 BTC Surface 6,244 Int. Csg. 7 26 L-80 BTC-Mod Surface 8,513 (MOW) Prod. Lnr. 4-1/2 12.6 L-80 Hydril 521 8,362 14,208 Tbg. 4-1/2 12.6 L-80 IBT-M Surface 8,357 4-1/2 Production Liner Cement: Eline performed a cement bond log on July 5, 2005 (Schlumberger SCMT 05-JULY-2005). The top of cement in the 4-1/2 production liner was logged at 8,506. The log shows quality cement across the Brookian, Sag, and Ivishak, along with good cement in between pools. See attachment section of the program for sections of the log. NK-65A : Brookian Recomplete PTD: 205063 Page 2 of 10 Wellwork Procedure: Slickline: 1. Pull SSSV from safety valve landing nipple at 2,105. 2. Load the IA with diesel and dummy all gas lift mandrels. IA volume to STA 1 = 153 bbl. 3. Drift for eline bridge plug, target plug set depth 13,700. Eline: 4. Load the TBG with crude. TBG volume to top perf = 202 bbl. 5. Set 4-1/2 CIBP at 13,700. a. Bridge plug must be set within 50 of the top of the existing perforated interval. 6. MIT-T to 3,000 psi to ensure plug is holding. Hold 1,500 psi on the IA during test. Coiled Tubing: 7. RIH to CIBP with cementing nozzle. 8. Circulate the well to 1% KCl or Seawater. 9. Lay in 4 bbl (263ft) of 15.8ppg Class G cement. a. Minimum acceptable TOC = 13,625. b. 4 bbl of cement would put TOC at 13,437. 10. Circulate the wellbore to diesel before RDMO. Slickline: 11. Tag TOC with AOGCC witness. Provide at least 24hr notice for witness. 12. MIT-T to 3,000psi to test cement plug with AOGCC witness. Hold 1,500 psi on the IA during test. Provide at least 24hr notice for witness. 13. Drift for eline perforating runs. Eline: 14. Perforate Brookian target interval from 13,056 13,200 with 2-3/4 perforating guns. a. Perforating runs are limited to +/- 30. All runs will be lubricated. Slickline: 15. Set kickoff gas lift design. 16. Set SSSV in safety valve landing nipple at 2,105. Operations: 17. Perform SVS testing within 5 days of putting on production. NK-65A : Brookian Recomplete PTD: 205063 Page 3 of 10 Attachments: - Current Wellbore Schematic - Proposed Wellbore Schematic - Reference log of target interval - Cement bond log - Sundry change form NK-65A : Brookian Recomplete PTD: 205063 Page 4 of 10 Wellbore Schematic: NK-65A : Brookian Recomplete PTD: 205063 Page 5 of 10 Proposed Wellbore Schematic: NK-65A : Brookian Recomplete PTD: 205063 Page 6 of 10 Reference log of target interval: Ad d P e r f NK-65A : Brookian Recomplete PTD: 205063 Page 7 of 10 Cement bond log SLB SCMT 05-JULY-2005: NK-65A : Brookian Recomplete PTD: 205063 Page 8 of 10 Cement bond log SLB SCMT 05-JULY-2005 Log scale: NK-65A : Brookian Recomplete PTD: 205063 Page 9 of 10 Cement bond log SLB SCMT 05-JULY-2005 Log at Brookian interval: NK-65A : Brookian Recomplete PTD: 205063 Page 10 of 10 Sundry change form Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the first call engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NK-65A Pulled Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-063 50-029-22869-01-00 14208 Conductor Surface Intermediate Production Liner 9991 80 6205 8487 5866 13860 20" 9-5/8" 7" 4-1/2" 9652 28 - 108 27 - 6244 26 - 8513 8342 - 14208 28 - 108 27 - 5163 26 - 6697 6579 - 9991 none 1500 3090 5410 7500 13860 , 14010 3060 5750 7240 8430 13727 - 14134 4-1/2" 12.6# L-80 25 - 8357 9522 - 9919 Structural 4-1/2" Baker S-3 Perm , 8300 , 6549 4-1/2" BBE, 2106 , 2099 8300 6549 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY, RAVEN OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034630, 0034635 25 - 6589 160 48 12291 5036 76 3380 0 0 580 569 N/A 13b. Pools active after work:RAVEN OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:25 pm, Sep 08, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.09.06 07:03:01 -08'00' WCB 3-13-2024 DSR-9/12/23 RBDMS JSB 091123 ACTIVITYDATE SUMMARY 8/15/2023 T/I/O = 1530/679/29 LRS 72 Assist Slickline as Directed (PROFILE MODIFICATION) ***Job Continued to 08-16-2023*** 8/15/2023 ***WELL S/I ON ARRIVAL*** (Profile modification) DRIFTED w/ 3.83" GAUGE RING TO BBE AT 2,106' MD PULLED BBE FROM 2,106' MD ATTEMPTED TO PULL JUNK CATCHER AT 13,827' MD WITH GR (currently stuck, shear) ***CONTINUED ON 8/16/23 WSR*** 8/16/2023 ***Continue Job from 08-15-2023*** Assist Slickline as Directed (PROFILE MODIFICATION) Pumped 162 bbls Crude into the TBG. 8/16/2023 ***Continue Job from 08-15-2023*** Assist Slickline as Directed (PROFILE MODIFICATION) Pumped 162 bbls Crude into the TBG. 8/16/2023 ***CONTINUED FROM 8/15/23 WSR*** TB PUMPED 162 BBLS CRUDE GET FREE FROM STUCK JUNK CATCHER RAN DOGLESS 4-1/2" GS TO JUNK CATCHER AT 13,827' MD (Sheared) PULLED JUNK CATCHER RAN DOGLESS 2-3/8" GR TO 4-1/2" EVO TRIEVE AT 13,827' MD (Unable to shear, no sign of eq) RAN MULTIPLE BAILERS TO EVO TRIEVE (recovering fine sand & small pieces of metal) ***CONTINUED ON 8/17/23 WSR*** 8/17/2023 ***Continue Job from 08-16-2023*** Assist Slickline as Directed. No additional fluids pumped, FWHP=50/650/24 S-Line on location upon departure 8/17/2023 ***CONTINUED FROM 8/16/23 WSR***(Profile modification) BAILED SAND OFF TOP OF EVOTRIEVE PLUG @ 13827' MD EQUALIZED & PULLED EVOTRIEVE PLUG @ 13827' MD (element intact) DRIFT TBG TO NS CIBP @ 13860' MD w/ 2.69" CENT & 2.5" SAMPLE BAILER (recovered sand in bailer) BRUSHED HXO NIP @ 2105' MD w/ FULL BORE BRUSH & 3.78" G-RING MAKE MULTIPLE ATTEMPTS TO SET 4-1/2" HES BBE AT 2,105' MD ***CONTINUE ON 8/18/23 WSR*** 8/18/2023 ***CONTINUED FROM 8/17/23 WSR*** (Profile modification) PULLED 4-1/2" HES BBE AT 2,105' MD RAN 4-1/2" BRUSH & 3.80" G. RING TO 2,105' MD SET 4-1/2" HES BBE (sn: H-6) AT 2,105' MD PERFORMED SUCCESSFUL DRAW DOWN TEST ***WELL S/I ON DEPARTURE*** 8/19/2023 T/I/O = 620/740/430. Temp = 118°. Bleed OAP (eval TxIA). No AL. OA FL near surface. Bled OAP to BT to 20 psi in 3 min (0.2 bbl). Monitored for 30 min. OAP increased 50 psi. Final WHPs = 620/740/70. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 Daily Report of Well Operations PBU NK-65A () BAILED SAND OFF TOP OF EVOTRIEVE PLUG @ 13827' MD EQUALIZED & PULLED EVOTRIEVE PLUG @ 13827' MD (element intact) @ 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NK-65A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-063 50-029-22869-01-00 14208 Conductor Surface Intermediate Production Liner 9991 80 6205 8487 5866 13827 20" 9-5/8" 7" 4-1/2" 9620 28 - 108 27 - 6244 26 - 8513 8342 - 14208 28 - 108 27 - 5163 26 - 6697 6579 - 9991 none 1500 3090 5410 7500 13827 , 13860 , 14010 3060 5750 7240 8430 13727 - 14134 4-1/2" 12.6# L-80 25 - 8357 9522 - 9919 Structural 4-1/2" Baker S-3 Perm , 8300 , 6549 4-1/2" BBE, 2106 , 2099 8300 6549 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY, RAVEN OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034630, 0034635 25 - 6589 208 586 14613 16892 2110 161 0 0 594 895 N/A 13b. Pools active after work:RAVEN OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:27 am, Jun 09, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.06.08 16:14:51 -08'00' WCB 1-18-2024 RBDMS JSB 071723 DSR-6/12/23 ACTIVITYDATE SUMMARY 4/20/2023 ***WELL FLOWING ON ARRIVAL***(perforating) TAGGED 4-1/2" HES BBE SSSV @ 2105' MD W/ 3.81" GAUGE RING. PULLED 4-1/2" HES BBE SSSV(Ser#0650153) FROM SVLN @ 2105' MD.(missing packing) RAN 4-1/2" BRUSH & 3.50" GAUGE RING, TOOLS S/D @ 13,876' SLM.(recovered 2.5 pieces of packing/springs) DRIFTED TBG W/ 10' x 3.70" DUMMY WHIPSTOCK & SAMPLE BAILER TO 13,878' SLM.(see log, no sample) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 4/20/2023 T/I/O= 1850/950/200 Assist SL FP FL and TBG. Pumped 5 bbls 60/40 down FL. Pumped 3 bbls 60/40 down TBG. Pumped 36 bbls crude down TBG. Upon departure secured well SV,WV=Closed SSV,MV,IA,OA=Closed Left well in Slicklines control. 4/30/2023 T/I/O = 2100/1380/0+. Temp = SI. T FL (eline req). No AL. T FL @ 8211' (sta #1 SO). SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 5/6/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3500HP PERF FROM 13739' - 13757' MD WITH 6 SPF, 60 DEG PHASED 2-3/4" RAZOR CHARGES. CCL STOP DEPTH=13732' MD, CCL TO TS=7' PERF FROM 13727' - 13739' MD WITH 6 SPF, 60 DEG PHASED 2-3/4" RAZOR CHARGES. CCL STOP DEPHT=13714.2' MD, CCL TO TS=12.8' LOG TIED INTO HES PERFORATING RECORD DATED 17-OCT-2021. ***CONTINUED ON 5-7-2023 WSR*** 5/7/2023 ***CONTINUED FROM 5/6/2023 WSR*** SET HES 3.66" EVOTRIEVE AT 13827' MD, CCL TO ME=29', CCL STOP DEPTH=13798' MD. CORRELATED TO HES 17-0CT-2021 PERFORATING RECORD. TOOLS HUNG UP AT 10840' MD WHILE PULLING OUT OF HOLE. 20 MINS OF JARRING TO FREE FROM PERF DEBRIS. POOH AND RECOVERED SETTING TOOL STRING. EVOTRIEVE SET. NOTE: DECISION MADE NOT TO RUN CATCHER ON TOP OF EVOTRIEVE ***WELL LEFT S/I & READY FOR PRODUCTION TO POP*** 5/21/2023 ***WELL FLOWING ON ARRIVAL*** (perforating) SET 3.70" JUNK CATCHER ON TOP OF EVOTRIEVE PLUG @ 13827' MD (67" oal) SET 4 1/5" BBE AT 2105' MD(lost control line integrity during toolchange) RAN 4 1/2" CHECKSET TO BBE(Sheared) PULLED BBE(All packing stacks damaged) BRUSHED HXO NIP w/ 4 1/2" BLB & 3.79" GAUGE RING. ***CONTINUED ON 5/22/23 WSR*** 5/22/2023 ***CONTINUED FROM 5/21/23 WSR*** (Perforating) SET 4 1/2" BBE(sn; hbb4-49, oversized sandwich) AT 2105' MD RAN 4 1/2" CHECK SET TO BBE(Sheared) (600 psi drawdown test) ***WELL S/I ON DEPARTURE*** 5/23/2023 State Tested post-SSSV reinstall, PPP, witness waived by Sean Sullivan Daily Report of Well Operations PBU NK-65A SET HES 3.66" EVOTRIEVE AT 13827' MD PERF FROM 13739' - 13757' MD The adperfs and Evotrieve plug are correctly shown on the new WBS, below. -WCB PERF FROM 13727' - 13739' MD gg) DRIFTED TBG W / 10' x 3.70" 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Exploratory Development Service 5 Permit to Drill Number:205-063 6.API Number:50-029-22869-01-00 PRUDHOE BAY, RAVEN OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0034635 Property Designation (Lease Number):10. 341H 8. PBU NK-65A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown INJ to Prod Conversion Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 14208 Effective Depth MD: L-80 11. 8/15/2021 Commission Representative: 15. Suspended Contact Name: Kirsty Glasheen Contact Email: kirsty.glasheen@hilcorp.com Authorized Name: Bo York Authorized Title:Sr Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" MCX I-SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9991 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8300, 6550 2105, 2099 Date: Liner 5866 4-1/2"8341 - 14207 6578 - 9991 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 27 - 6232 27 - 5155 14. Estimated Date for Commencing Operations: BOP Sketch 28 - 108 Structural 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 14087 - 14107 9873 - 9893 4-1/2" 12.6# L-80 24 - 8356 Production 14175 9959 None None 28 - 108 1500 9-5/8" 7" Contact Phone:(907)564-5258 Date: 5410 80 306020"Conductor 3090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 6205 5750 Intermediate 8487 26 - 8513 26 - 6697 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3506 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 10:32 am, Jul 29, 2021 321-375 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), c=US, o=Hilcorp North Slope, LLC, ou=Prudhoe Bay East, email=Torin.Roschinger@hilcorp.com Date: 2021.07.29 10:11:12 -08'00' Torin Roschinger (4662) X DLB07/29/2021MGR29JUL21 10-404 DSR-10/5/21 ; ADL0034630 DLB dts 10/6/2021 JLC 10/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.06 11:14:34 -08'00' RBDMS HEW 10/7/2021 CIBP/AddPerf/Flowback Well: NK-65A Date: 07/22/21 1 Well Name:NK-65A API Number:50-029-22869-01 Current Status:SI Injector Rig:N/A Reg.Approval Req’d?10-403, 10-404 Date Reg. Approval Rec’vd: TBD Regulatory Contact:Jerimiah Galloway Permit to Drill Number:2050630 First Call Engineer:Kirsty Schultz Contact:907-350-4310 AFE Number:TBD Job Type:Conversion from injector to producer Current Bottom Hole Pressure:4491 psi @ 9850’ TVD (SBHP Survey 10/19/2021) MPSP:3506 psi (BHP- .1psi/ft gas gradient) Recent SITP:564 psi 7/18/18 after five day SI Max Dev:65 deg At 10,766’ MD Min ID:3.68” ID milled out cement at 13,989’ MD Brief Well Summary: NK-65A is a Raven water injector that was SI due to failed surface kit. Surveillance data in offset well, NK-38B, indicated NK-65A injection is no longer needed, so the well has remained SI. We would like to convert NK-65A from a water injector to a rich gas producer. Before the conversion can take place, in accordance with 20 AAC 25.240(c), a GOR waiver must be obtained. Objective: Convert NK-65A from SWI to a producer by isolating existing perforations and adding up hole perforations in the Ivishak. There are contingent add perfs in the Sag and a contingent CIBP to be set pending the results of the Ivishak perforations. Procedural Steps (not to commence before GOR wavier has been obtained in accordance with 20 AAC 25.240(c)): E-line: 1. Set CIBP at ~14010’ MD. 2. Add Perfs from 13870-13920’ MD Slickline: 1. Install kick off gas lift design 2. Install SC-SSSV at 2106’ MD. Well Testing: 1. Flowback well via hardline to confirm competitiveness. o If well tests indicate a competitive well, work below will be pursued. o If well tests indicate an uncompetitive well, a CIBP will be set to isolate the Ivishak at ~13860’ MD and Sag perforations will be added from ~13726-13788’ MD. o If the Ivishak is competitive, but low rate, we will add Sag perforations at 13726-13788’ MD. Ivishak and Sag perfs will flow commingled. Well Tie-In: 1. Complete permanent tie in utilizing NK-19A surface kit DLB -00 CIBP/AddPerf/Flowback Well: NK-65A Date: 07/22/21 2 Figure 1: NK-65A Existing WBS CIBP/AddPerf/Flowback Well: NK-65A Date: 07/22/21 3 Figure 2: NK-65A Proposed WBS CIBP ~14010’ MD Adprf 13870-13920’ MD 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Thursday, September 23, 2021 11:23 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector NK-65A (PTD #205063) Lapse 4 year AOGCC MIT-IA From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, September 23, 2021 9:27 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com> Subject: NOT OPERABLE: Injector NK‐65A (PTD #205063) Lapse 4 year AOGCC MIT‐IA Mr. Wallace Injector NK‐65A (PTD #205063) is due this month for a 4 year AOGCC MIT‐IA. There are no immediate plans to resume injection. The well is now classified as NOT OPERABLE for tracking purposes and will remain shut in. Please call with any questions or concerns. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. T4 • OF ,s>. THE STATE Alaska Oil and Gas r:Z^'d�►I Uf�LAsKA Consel vation Commission __ 333 West Seventh Avenue ` GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Kirsten L. Shultz PE BP Exploration(Alaska)Inc. %AM '‘; t 1 P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Raven Oil Pool, PBU NK-65A Permit to Drill Number: 205-063 Sundry Number: 318-072 Dear Ms. Shultz : Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, LUD—XJ\ Hollis S. French Chair DATED this Jday of March,2018. s �� 2E k*f` n -kL � , fl STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMM! FEB 2 1 201$ APPLICATION FOR SUNDRY APPROVV 20 AAC 25.280 �j .3 ! t /! S ti 1. Type of Request: Abandon 0 PlugPerforations Fracture Stimulate 0r `'_ . . YP q 8Repair Well 0 Suspend 0 Perforate RI • Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 205-063 ` 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development o 99519-6612 Stratigraphic 0 Service D• 6. API Number 50-029-22869-01-00• 7. If perforating: (',U S 7i✓ / t�r Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? ` a" Will planned perforations require a spacing exception? Yes 0 No RI . PBU NK-65A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 034630&034635 PRUDHOE BAY,RAVEN OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 14208 • 9991 • 14175 9959 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 28-108 28-108 3060 1500 Surface 6205 9-5/8" 27-6232 27-5155 5750 3090 Intermediate 8486 7" 26-8513 26-6697 7240 5410 Production Liner 5866 4-1/2" 8341-14207 6578-9991 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 14070-14107 9856-9893 4-1/2"12.6# L-80 24-8356 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 8300/6550 4-1/2"MCX NM-22 SSSV 2105/2099 12.Attachments: Proposal Summary ® Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service m 14.Estimated Date for Commencing Operations: March 15,2018 15. Well Status after proposed work: Oil 0 WINJ IZI ' WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Schultz,Kirsten L be deviated from without prior written approval. Contact Email: Kirsten.Schultz@bp.com Authorized Name: Schultz,Kirsten L Contact Phone: +1 907 564 5105 Authorized Title: PE � Authorized Signature: ,71(1 Date: (lam/a•1 G I Cl COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 4I 1 2 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 O Other: Post Initial Injection MIT Req'd? Yes 0 No 137 Spacing Exception Required? Yes 0 No Subsequent Form Required: /0 — 14 0 ,- a2DC1\ -- APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 3 It ilt., VT--z_ z/2 s/1 5c ORIGINAL RtN,F tv'.P: - L2018.44 , Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • NK-65A Add Perf and Profile Modification Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Kirsty Schultz (907) 564-5105 History NK-65 was originally completed in 1998 as an injector. It was sidetracked to its current location in 2005 to provide pressure support and waterflood sweep of the Ivishak (Raven) accumulation to producer NK-38A. NK-38A was sidetracked to the NK-38B location in 2016. NK-15Ai is currently being drilled to support NK-38B and is expected to be put on injection in March 2018. NK-65A will be SI with no remaining injection value once NK-15A is put online. NK-65A is currently operable, and has unperforated Sag rich gas potential. Objective This intervention will use a CIBP to isolate the current Ivishak perforations, and perforations will be shot in the Sag. The well will then be flowed back for<30 days to confirm Sag potential in the area. If deemed viable/economic, the well will have a full surface conversion to enable production of the Sag. Expected Start Date: 1Q 2018 Procedural steps Slickline 1. Set kick off gas lift design. E-line 1. Set 4-1/2" CIBP at 13900' MD. 2. Add Sag perforations from 13730-13776' MD. Test Separator 1. Flowback and test • • 4-1'81(AV NK-6 5A sAsErte trarEs WELL REQUIRES A SSSV 48 I3ii;am— 2"• . ',tax-it'....41.-- 654167i;.1 Ea 105" , 4'211*--SHXOSV124.D).3.8131 I 131,1in MO. -- i•E,.... 1.0. al2AS L-FT MANCIRe..5 S1. 1.L1-1'42 A7d- roe. VIN LATCH FO441' R! 3 4337 ow 44, KL4C. WY 8,0( 2 6763 5441 '- KV.,- WY D. • 444' .:4 ... -AV E" I ..,,8435' -I- 6244' 1-40 827.9' 4-1121 t-€S.A.143 I.).3,8131 I Minimum ID= 3.68"a. 13989' T14 pzi7„---1-330,-7-1-1-x 4-'2*0101S-3 FKR..0.38"* I TOP OF CEMENT MILLED OUT 5324 i '..'-E. 8342' :T86 12'4' - H 835r I 1 -- 8345 1 II- "f":II' IIII II_I r1111111:, , I 5344 -,.....14., . ,,.. I 8374' H5*X 4-1 , 441LLOUT WHDOW•NIC-6.54' I1' " ,,,..._.,.11 a5'', 1 ',,,..,. &Sir-432$ A 2,1.1. 2 21 t ,-.1 85:- 1 - il------ 1311Cr 4-1211-ES V141441 V 2111 'MDR SD( ' ananil ''''.'" "----E'' \, '11,111,1„ L-80 D.4.21,. 124#4.' 1 '''''. „ A c.368' ,.... 1' A31D.04W.11... llEgal __,..OD '-.1 .-&05123kv, ANKLEA 1'OP PEP* 12.14010 1'--e)°STD{Xg1SD6) K14175"CTM .,r,,. ,,,,,,,,,r,0,0,:tvo-,.:..ve fy-s-p---, " sizi,.. - 334- EVIER.' I - - . • - *I.521 0'52 f C).3.9f$1........H 'D 44" 3 '- 6 '1059-14` - .5 * 7O-14O7 _ 3 ,18-14134 1 _ -REV eV (-12VW.te, WALK UN '...38 OR30114.4... V 3- k'% - . M11.21-1 LIFr...C.aRAF'.1.1242.3.3.2... .. Wei T.E.,,,,,, — os we SOETRAC 8 33 A , CSI P.X., "1,,...V MO DA1L-031 I I 04203 5 '034i 13% %133.AV 0221 1" A.4.4i)SSS V"„,,,,4"P"'""44.,"8 I ""." a?Explerm ion(A14,0,4) FIGURE 1:CURRENT WBS • • '/0:E. 1.-•5" 6.5+ WE-1*A.). °•" Al f-MC,,,, ,,5 NI K-65A SAFETY NOTES was.REQUIRES A$S$V. ,V...A.14'.:*- BAKE?' ef EL.e. Ma.A5,46+- 55.45 6,"55 11311 II 4•'.'"HES H60 Sy.."4,,,) .1-5 Ma NikRic,..5 77c V.:, ,J,"(14 PORT alni 3 45+31 4.6.5.1 45 8...6(62 2 t,t63 5497 48 62'' 8476 47 KaG2 LIMY 86 0 55.'6,6 I 96 r csc,40a L-ao ti.8 845" — 6244 1-41 8279' Minimum ID= 3.68"@ 13989' ,..... , 111 kJ. 8300' m X 4-'1 8A1-S-3 1404 0.3 87,fi' I TOP OF CEMENT,MLLE D OUT i III 8324' 4-r rzr 1-Es x.4)t).31.3`3"I VIIIWjll r x 5'8.86.XP-411"1.)4+146R a `tE.45.6.+S.+, &PE/0.08 11) 4-'."'58,.., '2 As.-&„, --1 8352* I 8345' 4-'?HES X•48.0-3 6' 'faa.:V 0-3 kk* III — ':Tillai 4-',..'4-faC, (,)-a 41,4' • r111=1111avo AT. r NI 7.8)r- ...rs,7,-.k...x:XI(...,,,V 4,‘„...„P f.) 4 4.k' 1 83 ( 5'x 4"235 E.)-3 4.,'T MIL LOUT WIFOOVV 41.444544) I+++V 4,S.+.0c.,)5048.6+ 8513' to 8513"-SSZS' . jEc'S'a,1,7,,,,,C,E4.)04fa J 1314,8 8531' —.....--- 4, ...,.. 1 10' 4... 1,...,„8N,4,U 4 3 4.'S' ,"vr ti Ng-00 IIM...3' a, Et,,,EJ•,,,o) I ',":be ,.tkf,0-3.',,,W H 12580" -----11 '' alirEall 84.4.-4t...E.,1 -6S'a 2N7 ,..-6a6 LI•7 ',' 12800r I"7\ ^ 4,„. 7\ 0 • ',., 0 3 6e 4^2"-Mt '25a.48 I..)•3 858" 13840' VAIPAIPAI 4)...," ,--- nr ,.. , ... • ^) ,... s, ... I. Pfsfik014,4,TON SUIMARY s ela tinr-M•18"2i,,,+4,1481'46.,,, =gm 's•,... AV PEF a.OG 7 7,7),OiXi DS',t2 S 06,23a0fi • 644,1,4,‘,4 s 4,'tt‘1,1 k 4 ob ANCLEAT TOP F1ERF •/it'4J'..7 Mt,..el Ix-,TD 067604-) 14175'CTM •Iiiiii.„1, •Ve#444.,la P5octmeicr L8/lw 54-o+-ca c.+4 Eni, 'Am • SILE S4a SPUN a. Das S++•• DA'S. J4'‘'"_NIK' ,1. ,Y)'it....**„.52' S2)c4 0 a 394-10 H 1420$' 2-78' 6 '4069-14107 S "4 2 7 a' A '4070-14107 0 7%1 2-78. 14108-14134 S ,.,'A k 047-E -alei B• +.,8.14.£6, S 0476 REV 86 ,21,410,EY'S MA 4516 UM 0S/18d98 ORIGINAL COM PIET ION *.,,S..),.. T.S, -ti JR...,..,-VA F,'CORfle,T K.44S WE...... 0920,05. WES SIDETRACK(14K-85A1 9 ,,,..,..• ..:S.P8, nw.V 1,0..0,11.0.1,S.6.8CREC,ON PERw Nt) .6,2%.6 1484.4,3C,....ad GO -8._,/,+1_0 .44,Oa* 6.8.1+4.4+14.'UN A M,48 855,12,22856 ° ‘6,P"X> AA VT,..ti 'A,.SHOE J064' Et,,,,j,,aj „Q.,2.*° A t.)F.)S.S...S.`, FA-4-TY 743' tS......3t, "2"4 R"St,'4,',/'-4--j.&82,81-e. , , .)S'4,184 5 -41JC CEMEN6&%Ls ex 24 A._61+8341.6.; A..41Eft,5 FP Ezploration(Altisk44 FIGURE 2:PLANNED CIBP AND PERFORATIONS • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg C I DATE: Tuesday,September 26,2017 P.I.Supervisor (7.51 61 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. NK-65A FROM: Bob Noble PRUDHOE BAY UN NIA NK-65A Petroleum Inspector Src: Inspector Reviewed B P.I.Supry J ge- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN NIA NK-65A API Well Number 50-029-22869-01-00 Inspector Name: Bob Noble Permit Number: 205-063-0 Inspection Date: 9/22/2017 ✓ Insp Num: mitRCN170922152933 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NK-65A - jType Inj W 'TVD 6536 - Tubing 1565 - 1547 - 1552 - 1557• PTD 2050630 Type Test SPT Test psi 1634 - IA 19 2098 2066 - 2060 - BBL Pumped: 1.7 BBL Returned: 1.7 OA 32 , 56 56 56 _ Interval 4YRTST P/F P Notes: SCANNED Lb Li 4 20 8 Tuesday,September 26,2017 Page 1 of 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- ~ ~03 Well History File Identifier Organizing (done) ^ Two-sided III II~IIIIIIII IIIII ^ Rescan Needed Ill 1111I11I11 Illlll RESCAN DIGITAL DATA OVERSIZED (Scannable) (Color Items: ~iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ Project Proofing Ill IIIIIIIIIII lI Ill BY: Maria Date: ~ /s/ Scanning Preparation !~ x 30 = ~ + =TOTAL PAGES 'n v Count does not i clude co er shee BY: Maria Date: ~, ~ 3'tJ 17 Is! Production Scanning lilllflllllllllllll Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanni g Pr partition: ~ YES NO BY: Maria Date: `a-. 3 ~ ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I111111II I lI II I I III ReScanned flI11IIIIIIIII tllll BY: Maria Date: /s/ Comments about this file: o~,~„«,~~ iuuiiiiiiiuiiiii 10/6/2005 well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,September 12,2013 TO: Jim Regg P.I.Supervisor (—�1� Si 7I i 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NK-65A FROM: Jeff Turkington PRUDHOE BAY UN NIA NK-65A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,j& -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN NIA NK-65A API Well Number 50-029-22869-01-00 Inspector Name: Jeff Turkington Permit Number: 205-063-0 Inspection Date: 9/7/2013 Insp Num: mitJAT130907124842 Rel Iisp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NK-65A T e In +W 1ITVD T 6536 - IA 1 798 2500 2470 . 2463 � Type J I PTD 2050630 Type Test'SPT Test psi 1634 OA 324 532 1- 527 , 522 Interval Ii4YRTST IP/F i- P rTubing 1226 - 1228 1226 1226 Notes: 126 bbl methanol to fill. SCANNED " f ;. -• n r. Thursday,September 12,2013 Page 1 of 1 • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 July 6, 2011 JUL s 20V1 Mr. Tom Maunder 0(03 Alaska Oil and Gas Conservation Commission 9\0,5 333 West 7 Avenue to6 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na pal NK -01A 1760280 500292015601 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -05 1850270 500292129000 P&A 4/15/96 NA NA NA NA NA NK-06 1852760 500292148800 P&A 4/15/96 NA NA NA NA NA NK -07A 2010630 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 500292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1961340 600292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2080310 600292268801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1961850 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/6/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/6/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 600292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970680 500292278000 2.5 NA 2.5 NA 15.3 6/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1980930 500292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/6/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK -42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-61A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK -82A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 / NK-85A 2050830 500292288901 1 NA 1 NA 8.5 5/6/2011 • • BP closes site over loss in Slope rent dispute t ick\ -.i \,.rcpt \' C=■ \.Q. HEALD POINT: Oengas fight oil giant over rent for use of their land. By ELIZABETH BLUEMINK NVL 3cts N DOy a 3 4 ebluemink @adn.com _---* �rL^ coS N a os _ o (03) Published: January 4th, 2011 10:09 PM \ -- Lk 3 a o k - C0 0 Last Modified: January 4th, 201 1 10:09 PM N V.... 2 0 \ BP shut down a small portion of the Prudhoe Bay oil field last week after a judge ruled that federal regulators failed for years to get approval from the Inupiat Eskimo family that owns the land. C-0 S p.\0 \ fit, Loolim of AIWA tistwre r- `L Y Photo courtesy of BP Exploration (Alaska) Inc. Heald Point drill pad at Prudhoe Bay has been used to access oil from several oil pools, including Raven. The BIA told BP to suspend Raven production in late December due to a court ruling. Read more: http://www.adn.com/ 2011 /01 /04 /v- gallery /1631936/bp- closes- site - over - loss- in- rent.html #ixzz l AB7r0Irl • The shutdown affects less than 1 percent of production from the nation's largest oil field, but so far it's the most visible consequence of a significant legal victory for the Native family, which has battled lawyers for the federal Bureau of Indian Affairs and BP in federal court over the oil production from its land. Federal claims court judge Nancy Firestone ruled this fall that the Oenga family is owed millions in unpaid rent because the BIA improperly allowed BP to tap three offshore oil deposits from the family's allotment on the northern edge of the vast Prudhoe oil field. The BIA approved BP's expanded use of the allotment without the family's consent, in violation of the family's contract with BP, Firestone said in her 168 - page ruling on Nov. 22. A week ago, the BIA told BP to shut down production from Prudhoe's Raven unit, the only one of the three disputed offshore deposits that BP was still accessing from the allotment. BP shut down Raven, which produced about 25,000 barrels of oil in November, on Friday. BP is still legally tapping the Niakuk field from the allotment. The battle over unpaid rent and unauthorized land use involves a nondescript finger of land called Heald Point that extends into the Beaufort Sea. The Oenga family acquired its 40 -acre allotment at Heald Point decades ago for subsistence hunting. But in 1989, the family patriarch, Andrew Oenga, signed a contract with BP allowing the oil giant to use Heald Point as a right of way. Years later, believing that BP was giving the family annual rent payments much lower than the land's true value, eight of Oenga's heirs -- including two children, his grandchildren and great- grandchildren -- sued the BIA in 2005. The family said it had to go to court because it was unable to persuade the agency, which is in charge of collecting the family's rent from BP, to take action on its behalf. In an eight -day Lower 48 trial last July, the agency and the oil giant defended themselves against the Oengas' claims. BP argued in court filings that no additional money was owed to the family. The BIA argued that the family's claims for unpaid rent were exorbitant. • • The judge ruled for the family, saying the BIA owes it roughly $5 million for the unauthorized use of the land, but she also said that BP is paying too little for the land it is authorized to use. The judge is still taking briefings on the exact amount owed but it will be far below the $200 million the Oengas originally sought. BP Alaska spokesman Steve Rinehart said Tuesday the company is evaluating its best path forward on a potential appeal. He emphasized that Raven represented a fraction of Prudhoe's output. BIA's acting director in Alaska did not return a call for comment on Tuesday. In a written statement late week, Oenga family member Tony Delia said the family is willing to end the matter. "Earlier this month we made BP a fair offer -- pay what is owed and we will renegotiate the lease so they can use our land to produce from Raven and wherever else they want to drill. They haven't responded," he said. According to a written statement from the family's attorney, Ray Givens, the total amount owed the family is $15 million. That figure includes the Oenga family's calculation of how much additional money it is owed in unpaid rent for BP's authorized use of the land, which was not part of the this lawsuit. In her ruling, Firestone said evidence from the trial showed that BP withheld critical information about Heald Point's strategic value for oil development when it negotiated a contract with the family to use the land. "Clearly, (BP) did not wish to share much with the plaintiffs," she wrote. Find Elizabeth Bluemink online at adn.com/contact /ebluemink or call 257 -4317. Read more: http://www.adn.com/ 2011 /01/04/1631936/bp- closes- site - over - loss - in - rent.html #ixzz l AB73YsM3 12/17/10 Sit Mawr NO. 5667 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shadier ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD (P?' NK-65A G-09B 0-298 BCRD-00064 RST r;1015 42,3 11649989 MCNL (REDO ",(1" —It (*) 09/11/07 4- 1 BCRD-00068 RST " .S — flq BCRD-00063 RST AWJI-00113 MCNL 10/29/10 1 6 :IV 10/21/10 .., , 1 ...._ , 06-24A 1 11/12/10 Illt . 614 01-06A 10/06/10 1 t 1 W-37A BD88-00048 MCNL ' — 09/12/10 ' 0 0 1 05-07 BBKA-00077 LDL — • 1 ...$ 11/24/10 C./ 1 12-29 B5JN-00067 USIT i fr .-- , _ 10/13/10 ..„,_„i 1 1 K-128 BL65-00002 MEM PROD PROFILE Of ...` -- 11/21/10 4. nen / 'S 1 17-16 BBSK-00036 PROD PROFILE J 4 — e ■ 11/12/10 1. , 1 K-128 BCUE-00094 MEM PROD PROFILE n --iy, 11/22/10 , („ 1 K-128 BCUE-00094 MEM PROD PROFILE ' —"/ 416" 11/23/10 p pe" q 1 • 12-04A B5JN-00069 USIT , — , 11/02/10 _ „_0 _ 1 1 09-25 AV1H-00048 INJECTION P - 0 ILE iFwilrgMS''Zjrael 1 06-02 BBKA-00075 SCMT j .-- • 11/19/10 re 66 ki 1 1 18-138 BC22-00028 SCMT 001 ... 11/07/10 00 4„, i 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Retrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503-2838 , . . • 1 1 0. • i. \ \ 12/10/10 Scbbaaberger NO. 5658 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPF -13 BDAD -00024 USIT I / S -- 0:.) 09/29/10 1 1 4,,, / NK -65A BCRD -00064 INJ PROFILE/RST/WFL :10 - O(p3 1 F n / -.� J r A �` S-41A BCRD -00058 USIT 1-15/P-25 B .000 2 BGZ7-00012 USIT SCMT _ S (� ° ® ®km • • W-219 BGZ7 -00012 USIT • — • — r 09 -09 - . r . RST 01.02 - r ��.. RST / —II BC 05 ., �' 05 -33B MCNL i 1 A - /�� _ � OHMWD /LWDEDIT /tl� '� ` 05 -31B i ii i • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 MAR 1 4 2 U 1 `fl tik 9 - 0 04 i Ica � 2 Pad Pave' 1 AOGCC MITIAs for NK-15 (#~0320), NK-18 (#1931170), P-03A (#1~2280), R-02 (... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~i ~~~1~~~~~ Sent: Monday, October 05, 2009 10:21 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Fleckenstein, Robert J(DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer Subject: AOGCC MITIAs for NK-15 (#1970320), NK-18 (#1931170), P-03A (#1972280), R-02 (#1781000), U-05A (#2090700), W-35 (#1880330), 14-21A (#2051070), NK-65A (#2050630) Attachments: MIT PBU NK-15 NK-18 09-17-09.x1s; MIT PBU P-03A 09-12-09.x1s; MIT PBU R-02 09-12- 09.x1s; MIT PBU U-05A 09-12-09.x1s; MIT PBU W-35 09-12-09.x1s; MIT PBU 14-21A 09-21- 09.xis; MIT PBU NK-65A 09-21-09.x1s Jim, Tom, and Bob, Please find the attached MITIA forms for the following wells: NK-15 (#1970320) NK-18 (#1931170) P-03A (#1972280) R-02 (#1781000) U-05A (#2090700) W-35 (#1880330) 14-21A (#2051070) ~K-65A (#2050630 ~...~-- ;~~"~~~~~-~ ~~~ ~1 :I_ t; ~LIG~; «MIT PBU NK-15 NK-18 09-17-09.x1s» «MIT PBU P-03A 09-12-09.x1s» «MIT PBU R-02 09-12-09.x1s» «MIT PBU U-05A 09-12-09.x1s» «MIT PBU W-35 09-12-09.xis» «MIT PBU 14-21A 09-21-09.x1s» «MIT PBU NK-65A 09-21-09.x1s» Please let us know if you have any questions. Thank you, Anna ~Dude, ~.~. ~alt Torin Roschinger) WeEI Integrity C~ordinatar GPB VVells Gra~a~ F~hone. ~9Q7j 658-5102 Pager: {807) 659-5100 x1154 10/15/2009 -__J Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / Niakuk 09/21 /09 Torin Roschinger ~ Packer Depth Pretest Initial 15 Min. 30 Min. Well NK-65A Type Inj. N ND 6,536' Tubing 490 470 470 470 Interval 4 P.T.D. 2050630 Type test P Test psi ' 1634 Casing 0 '2,200 2,160 2,140 ' P/F P= Notes: AOGCC 4-yr MITIA. Plant was shut-down during OA 30 120 120 120 test. AOGCC witnessed declined to witness. Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj, TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. ND 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 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 O = Other (describe in notes) MIT Report Form BFL 11/27/07 2009-0921_MIT_PBU_NK-65A.xls ~J ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMtSStON Mechanical Inbegrity Test Email to:jim.regg~alaska.gov; tom.maunder~alas6ca.gonr;bob_~ecicenstein@alaska.gov;doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FtELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Explaration (Ala.ska), Inc~ Prudhoe Bay f PBU ! Niaku~c Q9/21109 Torin Roschinger Paclcer P-etesi In~ia6 15 Min. 30 Min. Wel1 NK~SA T In'. N NQ C,53fi" T' ~t 4~'Q 470 470 Interval 4 P.T.D. 2050630 T test P Test ` 1634 C` 0 2,2UQ 2,160 2,140 PIF P Notes: AOGCC 4yr MITIA. Ptarat w~as sht~t-c#ow~rr c#~rririg £7,4 3€3 7~ 42K} 420 test. AOGCC witnessed dedir~d do w~i'traess. Weli T !n'. i'1~+~3 ~ ~ Interval P.T.D. T test Te~ " P/F Notes: OA Well T In . TV~ Tu ' Ir~terval P.T.D. T test T~ ~ Casi P/F Notes: t)A Well T 1n'. T1~~ ~" I~erval P.T.D. T test T~ ' PIF Notes: OA Well T !n'. NE7 T' Interval P.T.D. T test T~ ' P/F Notes: t>A TYPE INJ Codes D = Driiling Waste G = Gas I = Industrial Wastewater N = Not lnjecting W = Water TYPE'FEST Gcdes M = Annul~s Manitairrg P = StandaeTf Peess~~e- T~.s4 R = lMernaf " T€~er Suewey R = T S~nrey D = Di ' '~ Test ~ ~' ~ ~ ~~.~~~~,~: tti~:' ~_ <> Zf1~~ ~~ ~~ ~~ ~ ~~ ~~ INTERVAL Codes I =lnitial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU NK-65A 09-21-09.x1s 03/20/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WaII .Inh ff VV r,~ ~~ ~~~ .~_ (~sf~ ~~i~Dlibil~~ lYlF~tl ~ ~ Z~i€[~ 1 nn naeerintinn naro NO. 4633 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Niakuk RI r_ntnr r_n Z-20 11963084 MEM PPROF ,/ p st O 03/15/08 1 1 J-12 12031462 LDL 03!10/08 1 1 NK-65A 12017488 PRIMARY DEPTH CONTROL 03/17/08 1 1 09-42A 12014004 USIT 03/19/08 1 1 O-05B 40016311 OH MWD EDIT -. ~ # ~ 01/30/08 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~ y« -= g ~"° r '~. Petrotechnical Data Center LR2-1 "~' _,~ ~ ~a 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: e i;~,(~ ,'-", ~~ ~r`3~`)~ Alaska Data & Consulting Services 2525 Gambell Street, Suit 4 Anchorage, AK 99503-2 ATTN: Beth Received by: gyro at~ Gyrodata Incorporated 1682 W. Sam Houston Pktn~y. N. Houston, Texas 77043 713,'461-3146 Fax:713l461-0920 ~~,~ APR ~ 4 2008 SURVEY REPORT BP Niakuk #NK-65A Prudhoe Bay, AK AK0308G_115 17 Mar 2008 • Serving the VVordv~^de Frerq~~ Inr~ustr~~ with Precision ~ur~~ev .n>ir:~r!1er?taiicn ~,20~-063 gyrodat~ Gyrodata incorporated 1682 l~?~. Sam Houston Pkwy. N. Houston. Texas 77043 713;461-3146 Fax 713/461-0920 April 3, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Niakuk, Well #NK-65A Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, n ~r ~ -~` .~ Rob Shoup ''~ North American Regional Manager RS:tf Servnlg the Worldwide Energy Industry with Precisi<;n Strr~iey insi~u,r.er~tiien A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlurnberger Crane,5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 Run Date: 17 Mar 2008 Surveyor: Henry Drew Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.347611 deg. N Longitude: 148.200028 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North • Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 0.00 0.00 0.00 ----- N -------- 0 ------ 0 E ------------ 0.00 0.00 0.0 0.0 0.00 N 0.00 E 0 - 14154.95 FT . RATE GYROSCOPIC CO ----------------------------------------------- NTINUOUS SURVEY RUN INSIDE 4-1/2" TUBING -------------- -------------- ----- ----------------- ----------------- ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO ORIGINAL RIG ROTARY TABLE (+26.60 ABOVE B. F.) 48.3 FT A MSL 100.00 0.70 42.47 N 42 28 E 0.18 100.00 0.6 42.5 0.45 N 0 42 E 200.00 1.41 84.95 N 84 57 E 0.25 199.98 2.3 63.7 1 02 N . 2 05 E 300.00 1.27 63.59 N 63 35 E 0.13 299.95 4.6 69.3 . 1.62 N . 4 27 E 400.00 1.13 42.23 N 42 14 E 0.12 399.93 6.6 64.4 2.84 N . 5 93 E 500.00 2.50 0.13 N 0 8 E 0.46 499.88 8.8 48.9 5.76 N . 6.60 E 600.00 3.87 318.04 N 41 58 W 0.65 599.74 11.3 22.6 10 45 N 4 35 E 700.00 4.30 313.73 N 46 16 W 0.13 699.49 15.6 357.7 . 15.55 N . 0 61 W 800.00 4.72 309.41 N 50 35 W 0.14 799.18 21.7 342.6 20.75 N . 6 50 W 900.00 4.06 314.85 N 45 9 W 0.20 898,88 28.6 334.8 25 86 N . 12 19 W 1000.00 3.39 320.28 N 39 43 W 0.19 998.67 34.8 331.6 . 30.63 N . 16.59 W 1100.00 3.15 325.07 N 34 56 W 0.09 1098.51 40.5 330.3 35.16 N 20 05 W 1200.00 2.92 329.86 N 30 8 W 0.09 1198.37 45.8 330.0 39.61 N . 22 90 W 1300.00 2.94 334.89 N 25 6 W 0.06 1298.24 50.9 330.2 44.14 N . 25 27 W 1400.00 2.97 339.92 N 20 5 W 0.07 1398.10 56.0 330.9 48.90 N . 27 25 W 1500.00 3.17 359.70 N 0 18 W 0.27 1497.96 61.0 332.5 54.10 N . 28.15 W 1600.00 3.37 19.49 N 19 29 E 0.29 1597.80 65.5 335.5 59.64 N 27 19 W 1700.00 4.08 22.21 N 22 13 E 0.18 1697,59 70.3 339.3 65.70 N . 24 86 W 1800.00 4.78 24.94 N 24 57 E 0.18 1797.29 76.0 343.4 72.77 N . 21 76 W 1900.00 7.10 26.17 N 26 10 E 0.58 1896.75 83.9 348.1 82.10 N . 17 28 W 2000.00 9.42 27.40 N 27 24 E 0.58 1995.71 95.5 353.5 94.91 N . 10.79 W A Gyrodata Directional Survey A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 2100.00 10,86 37.20 N 37 12 E 0.56 2094.15 109.7 359.3 109.68 N 1 32 W 2200.00 13.27 42.00 N 42 0 E 0.65 2191.93 126.3 5.5 125.72 N . 12.06 E 2225.00 14.16 37.16 N 37 9 E 1.45 2216.22 131.2 6.9 130.29 N 15.82 E 2250.00 14.78 37.50 N 37 30 E 0.63 2240.43 136.7 8.3 135.26 N 19 61 E 2275.00 15.53 36.68 N 36 41 E 0.78 2264.56 142.4 9.5 140.47 N . 23.55 E 2300.00 15.71 35.72 N 35 43 E 0.32 2288.64 148.5 10.7 145.90 N 27 53 E 2325.00 16.62 34.57 N 34 34 E 0.96 2312.65 154.8 11.7 151.59 N . 31 53 E 2350.00 16.93 32.83 N 32 50 E 0.59 2336.59 161.5 12.7 157.59 N . 35 53 E 2375.00 17.79 33.19 N 33 11 E 0.87 2360.45 168.6 13.6 163.85 N . 39 59 E 2400.00 18.17 31.79 N 31 48 E 0.57 2384.23 175.9 14.4 170.36 N . 43.74 E 2425.00 18.50 31.64 N 31 38 E 0.34 2407.95 183.4 15.1 177.05 N 47 87 E 2450.00 19.46 29.76 N 29 45 E 1.13 2431.60 191.2 15.8 184.04 N . 52 02 E 2475.00 19.88 27.83 N 27 50 E 0.77 2455.14 199.5 16.3 191.41 N . 56 07 E 2500.00 20.28 27.36 N 27 22 E 0.43 2478.62 207.9 16.8 199.02 N . 60 05 E 2525.00 21.26 26.41 N 26 25 E 1.04 2501.99 216.6 17.2 206.93 N . 64.06 E 2550.00 21.93 25.63 N 25 38 E 0.72 2525.24 225.7 17.6 215.20 N 68.09E 2575.00 22.43 25.33 N 25 20 E 0.51 2548.39 235.1 17.9 223.71 N 72 15 E 2600.00 23.25 24.57 N 24 34 E 0.87 2571.43 244.7 18.2 232.51 N . 76 24 E 2625.00 24.07 23.87 N 23 52 E 0.87 2594.33 254.7 18.4 241.66 N . 80 36 E 2650.00 24.50 23.89 N 23 53 E 0.42 2617.11 264.9 18.6 251.07 N . 84.52 E 2675.00 25.13 23.91 N 23 55 E 0.63 2639.81 275.4 18.8 260.66 N 88 77 E 2700.00 25.71 24.11 N 24 7 E 0.59 2662.39 286.0 19.0 270.46 N . 93.14 E 2725.00 26.41 24.50 N 24 30 E 0.72 2584.84 297.0 19.2 280.47 N 97 66 E 2750.00 27.11 24.76 N 24 46 E 0.71 2707.17 308.2 19.4 290.70 N . 102.35 E BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 2775.00 27.76 25.01 N 25 1 E 0.66 2729.36 319.7 19.6 301.15 N 107.20 E 2800.00 28.65 25.28 N 25 17 E 0.90 2751.39 331.4 19.8 311 84 N 112 22 E 2825.00 29.24 25.34 N 25 20 E 0.60 2773.26 343.5 20.0 . 322.78 N . 117 39 E 2850.00 29.94 25.39 N 25 23 E 0.69 2795.00 355.8 20.2 333.94 N . 122 68 E 2875.00 30.57 25.25 N 25 15 E 0.63 2816.60 368.3 20.3 345 32 N . 128 07 E 2900.00 31.14 25.24 N 25 15 E 0.58 2838.06 381.1 20.5 . 356.92 N . 133.54 E 2925.00 31.83 25.28 N 25 17 E 0.68 2859.38 394.1 20.7 368.73 N 139 11 E 2950.00 32.27 25.47 N 25 28 E 0.46 2880.57 407.3 20.8 380.71 N . 144 79 E 2975.00 33.02 25.89 N 25 54 E 0.78 2901.62 420.8 21.0 392 87 N . 150 64 E 3000.00 33.87 26.27 N 26 16 E 0.87 2922.48 434.5 21.1 . 405.24 N . 156 70 E 3025.00 34.53 26.51 N 26 31 E 0.68 2943.16 448.5 21.3 417.83 N , 162.94 E 3050.00 35.44 26.74 N 26 45 E 0.93 2963.64 462.7 21.5 430.64 N 169 37 E 3075.00 36.22 26.82 N 26 49 E 0.78 2983.91 477.3 21.6 443.71 N . 175 96 E 3100.00 37.18 26.87 N 26 S2 E 0.97 3003.95 492.2 21.8 457.04 N . 182 71 E 3125.00 38.06 26.77 N 26 46 E 0.88 3023.75 507.4 21.9 470.66 N . 189 60 E 3150.00 38.53 26.70 N 26 42 E 0.47 3043.37 522.8 22.1 484.49 N . 196.57 E 3175.00 39.25 26.59 N 26 36 E 0.72 3062.83 538.5 22.2 498.52 N 203 61 E 3200.00 39.60 26.57 N 26 34 E 0.35 3082.15 554.3 22.3 512.72 N . 210 71 E 3225.00 40.02 26.54 N 26 32 E 0.42 3101.35 570.3 22.5 527.03 N . 217 86 E 3250.00 40.73 26.60 N 26 36 E 0.72 3120.40 586.4 22.6 541.52 N . 225 11 E 3275.00 41.35 26.65 N 26 39 E 0.62 3139.25 602.8 22.7 556.19 N . 232.46 E 3300.00 42.07 26.67 N 26 40 E 0.72 3157.92 619.4 22.8 571.06 N 239 93 E 3325.00 42.67 26.76 N 26 46 E 0.60 3176.38 636.2 22.9 586.11 N . 247 50 E 3350.00 43.48 26.91 N 26 55 E 0.81 3194.65 653.3 23.0 601.34 N . 255.21 E A Gyrodata Directional Survey • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 3375.00 44.54 27.16 N 27 10 E 1.08 3212.63 670.6 23.1 616.81 N 263 11 E 3400.00 45.24 27.28 N 27 17 E 0.70 3230.34 688.2 23.2 632.50 N . 271.18 E 3425.00 46.01 27.25 N 27 15 E 0.77 3247.82 706.0 23.3 648.39 N 279 37 E 3450.00 46.60 27.13 N 27 8 E 0.60 3265.09 724.0 23.4 664.46 N . 287 63 E 3475.00 47.18 27.03 N 27 2 E 0.58 3282.18 742.3 23.5 680.71 N . 295 94 E 3500.00 47.44 27.03 N 27 2 E 0.26 3299.13 760.6 23.6 697.08 N . 304 29 E 3525.00 47.57 27.19 N 27 11 E 0.18 3316.02 779.0 23.7 713.49 N . 312.68 E 3550.00 47.57 27.49 N 27 30 E 0.22 3332.88 797.4 23.8 729.88 N 321 16 E 3575.00 47.61 27.68 N 27 41 E 0.15 3349.75 815.8 23.8 746.24 N . 329 71 E 3600.00 47.71 27.91 N 27 55 E 0.19 3366.58 834.3 23.9 762.59 N . 338 33 E 3625.00 47.66 28.28 N 28 17 E 0.27 3383,41 852.7 24.0 778.89 N . 347 03 E 3650.00 47.84 28.49 N 28 29 E 0.23 3400.22 871.2 24.1 795.18 N . 355.83 E 3675.00 47.93 28.83 N 28 50 E 0.27 3416.99 889.6 24.2 811.45 N 364 72 E 3700.00 47.97 28.95 N 28 57 E 0.10 3433.73 908.1 24.3 827.70 N , 373 69 E 3725.00 48.03 29.16 N 29 10 E 0.17 3450.46 926.7 24.4 843.94 N . 382 71 E 3750.00 47.98 29.45 N 29 27 E 0.22 3467.19 945.2 24.5 860.14 N . 391 81 E 3775.00 48.14 29.56 N 29 34 E 0.18 3483.90 963.7 24.6 876.32 N . 400.97 E 3800.00 48.12 29.85 N 29 51 E 0.21 3500.59 982.2 24.7 892.50 N 410 19 E 3825.00 48.14 30.05 N 30 3 E 0.16 3517.27 1000.8 24.8 908.63 N . 419 48 E 3850.00 48.27 30.18 1V 30 I1 E 0.16 3533.93 1019.3 24.9 924.75 N , 428 84 E 3875.00 48.31 30.40 N 30 24 E 0.17 3550.57 1037.9 25.0 940.86 N , 438 25 E 3900.00 48.42 30.49 N 30 29 E 0.14 3567. ] 8 1056.5 25.1 956.97 N , 447.72 E 3925.00 48.37 30.80 N 30 48 E 0.24 3583.78 1075.1 25.2 973.06 N 457 25 E 3950.00 48.33 30.79 N 30 47 E 0.04 3600.39 1093.7 25.3 989.10 N , 466.81 E A Gyrodata Directional Survey • • BP Exploration (Alaska) Lease; Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg, min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 3975.00 48.31 30.83 N 30 50 E 0.04 3617.02 1112.3 25.4 1005.14 N 476 37 E 4000.00 47.37 30.38 N 30 23 E 0.99 3633.80 1130.8 25.4 1021.09 N . 485 81 E 4025.00 47.04 30.14 N 30 8 E 0.38 3650.78 1149.0 25.5 1036.93 N . 495.05 E 4050.00 46.84 29.82 N 29 49 E 0.30 3667.85 1167.3 25.6 1052.75 N 504 18 E 4075.00 46.68 29.44 N 29 26 E 0.32 3684.98 1185.4 25.7 1068.59 N . 513 18 E 4100.00 46.40 28.79 N 28 47 E 0.55 3702.17 1203.5 25.7 1084.44 N . 522 01 E 4125.00 45.78 27.67 N 27 40 E 1.01 3719.51 1221.5 25.7 1100.31 N . 530 53 E 4150.00 45.75 27.30 N 27 18 E 0.27 3736.95 1239.4 25.8 1116.19 N . 538.80 E 4175.00 45.48 27.09 N 27 5 E 0.31 3754.44 1257.3 25.8 1132.09 N 546 96 E 4200.00 45.35 27.24 N 27 14 E 0.17 3771.99 1275.1 25.8 1147.93 N . 555 09 E 4225.00 45.46 27.37 N 27 22 E 0.15 3789.54 1292.9 25.8 1163 75 N . 563 26 E 4250.00 45.34 27.51 N 27 30 E 0.16 3807.09 1310.7 25.8 . 1179.55 N . 571 46 E 4275.00 45.52 27.55 N 27 33 E 0.18 3824.64 1328.5 25.9 1195.34 N . 579.69 E 4300.00 45.47 27.66 N 27 40 E 0.09 3842.16 1346.3 25.9 1211.14 N 587 95 E 4325.00 45.54 27.69 N 27 41 E 0.07 3859.68 1364.1 25.9 1226.93 N . 596 24 E 4350.00 45.67 27.58 N 27 35 E 0.16 3877.18 1382.0 25.9 1242.76 N . 604 52 E 4375.00 45.29 26.84 N 26 51 E 0.65 3894.70 1399.8 26.0 1258.61 N . 612 67 E 4400.00 44.87 26.03 N 26 2 E 0:72 3912.36 1417.5 26.0 1274.46 N . 620.55 E 4425.00 44.52 25.18 N 25 11 E 0.69 3930.13 1435.1 26.0 1290.32 N 628 15 E 4450.00 44.37 25.09 N 25 6 E 0.16 3947.98 1452.6 25.9 1306.17 N . 635 59 E 4475.00 44.35 24.98 N 24 59 E 0.08 3965.85 1470.1 25.9 1322.00 N . 642 98 E 4500.00 44.11 24.86 N 24 51 E 0.26 3983.77 1487.5 25.9 1337.82 N . 650 33 E 4525.00 44.29 24.84 N 24 50 E 0.19 4001.69 1504.9 25.9 1353.63 N . 657.65 E 4550.00 44.92 24.54 N 24 32 E 0.66 4019.49 1522.5 25.9 1369.58 N 664.98 E A Gyrodata Directional Survey .J • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 4575.00 4600 00 45.09 46 07 24.29 N 24 17 E 0.25 4037.16 1540.2 25.9 1385.68 N 672.29 E . 4625 00 . 46 57 24.29 24 21 N 24 17 E 0.98 4054.66 1558.0 25.9 1401.96 N 679.64 E . 4650.00 . 46.92 . 24 12 N N 24 24 12 7 E E 0.51 4071.93 1576.1 25.8 1418.44 N 687.06 E . 0.35 4089.06 1594.3 25.8 1435.06 N 694.51 E 4675.00 47.30 24.17 N 24 10 E 0.38 4106.07 1612.6 25.8 1451 77 N 702 01 E 4700.00 47.59 24.17 N 24 10 E 0.29 4122.98 1631.0 25.8 . 1468 57 N . 709 55 E 4725.00 4750 00 47.54 47 48 24.20 N 24 12 E 0.06 4139.85 1649.4 25.8 . 1485.40 N . 717.11 E . 4775.00 . 47 26 24.26 24 46 N N 24 24 16 27 E 0.08 4156.73 1667.9 25.8 1502.21 N 724.67 E . . E 0.26 4173.67 1686.3 25.7 1518.97 N 732.26 E 4800.00 47.41 24.55 N 24 33 E 0.17 4190.61 1704.6 25.7 1535 70 N 739 88 E 4825.00 4850 00 47.24 47 14 24.70 N 24 42 E 0.21 4207.56 1723.0 25.7 . 1552.41 N . 747.54 E . 4875 00 . 47 14 24.69 24 70 N N 24 24 41 E 0.10 4224.55 1741.4 25.7 1569.07 N 755.20 E . 4900.00 . 46.95 . 24 77 N 24 42 46 E E 0.01 4241.55 1759.7 25.7 1585.72 N 762,86 E . 0.19 4258.59 1778.0 25.7 1602.33 N 770.51 E 4925.00 47.04 24.85 N 24 51 E 0.11 4275.64 1796.2 25.7 1618 93 N 778 19 E 4950.00 46.77 24.89 N 24 54 E 0.27 4292.72 1814.5 25.7 . 1635 49 N . 785 86 E 4975.00 46.54 25.03 N 25 2 E 0.26 4309.88 1832.7 25.7 . 1651 97 N . 793 54 E 5000.00 46.55 25.18 N 25 11 E 0.11 4327.07 1850.8 25.7 . 1668 41 N . 801 24 E 5025.00 46.60 25.61 N 25 36 E 0.31 4344.26 1869.0 25.6 . 1684.81 N . 809.02 E 5050.00 5075 00 46.92 47 10 25.76 N 25 46 E 0.34 4361.39 1887.2 25.7 1701.22 N 816.92 E . 5100.00 . 47 20 25.96 26 13 N N 25 26 58 8 E 0.24 4378.43 1905.5 25.7 1717.68 N 824.89 E 5125.00 . 47.45 . 26.22 N 26 13 E E 0.15 0 25 4395.44 1923.8 25.7 1734.14 N 832.94 E 5150.00 47.31 26.23 N 26 14 E . 0 13 4412.38 1942.2 25.7 1750.64 N 841.05 E . 4429,31 1960.6 25.7 1767.14 N 849.17 E A Gyrodata Directional Survey A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet _ feet deg. feet 25 ft. 5175.00 47.53 26.32 N 26 19 ' E 0.23 4446.23 1979.0 25.7 1783.65 N 857 32 E 5200.00 47.62 26.44 N 26 26 E 0.13 4463.09 1997.4 25.7 1800.18 N . 865 52 E 5225.00 47.46 26.56 N 26 33 E 0.18 4479.9 7 2015.9 25.7 1816.69 N . 873 75 E 5250.00 47.65 26.58 N 26 35 E 0.19 4496.84 2034.3 25.7 1833.19 N . 882 00 E 5275.00 47.78 26.53 N 26 32 E 0.14 4513.66. 2052.8 25.7 1849.73 N . 890.27 E 5300.00 47.87 26.61 N 26 37 E 0.11 4530.44 2071.4 25.7 1866.30 N 898 56 E 5325.00 47.75 26.62 N 26 37 E 0.12 4547.23 2089.9 25.7 1882.87 N . 906 86 E 5350.00 47.63 26.67 N 26 40 E 0.13 4564.06 2108.4 25.7 1899.39 N . 915 15 E 5375.00 47.79 26.73 N 26 44 E 0.16 4580.88 2126.9 25.7 1915.91 N . 923 46 E 5400.00 47.52 26.73 N 26 44 E 0.27 4597.72 2145.3 25.7 1932.42 N . 931.77 E 5425.00 47.62 26.71 N 26 43 E 0.10 4614.59 2163.8 25.8 1948.90 N 940 07 E 5450.00 47.58 26.77 N 26 46 E 0.06 4631.45 2182.2 25.8 1965.38 N . 948 38 E 5475.00 47.40 26.78 N 26 47 E 0.18 4648.34 2200.7 25.8 1981.84 N . 956 68 E 5500.00 47.46 26.88 N 26 53 E 0.09 4665.25 2219.1 25.8 1998.27 N . 964 99 E 5525.00 47.42 26.66 N 26 40 E 0.17 4682.16 2237.5 25.8 2014.71 N . 973.28 E 5550.00 47.64 26.72 N 26 43 E 0.23 4699.04 2255.9 25.8 2031.18 N 981 56 E 5575.00 47.75 26.77 N 26 46 E 0.11 4715.87 2274.4 25.8 2047.70 N . 989 88 E 5600.00 47.62 26.64 N 26 38 E 0.16 4732.70 2292.9 25.8 2064.21 N . 998 19 E 5625.00 47.87 26.57 N 26 34 E 0.25 4749.51 2311.4 25.8 2080.75 N . 1006 48 E 5650.00 47.83 26.47 N 26 28 E 0.08 4766.29 2329.9 25.8 2097.34 N . 1014.75 E 5675.00 47.95 26.50 N 26 30 E 0.13 4783.05 2348.5 25.8 2113.94 N 1023 02 E 5700.00 47.89 26.45 N 26 27 E 0.07 4799.80 2367.0 25.8 2130.55 N . 1031 30 E 5725.00 47.75 26.22 N 26 13 E 0.22 4816.59 2385.6 25.8 2147.15 N . 1039 52 E S7S0.00 47.93 26.19 N 26 11 E 0.18 4833.37 2404.1 25.8 2163.78 N . 1047 70 E 5775.00 47.70 26.20 N 26 12 E 0.24 4850.15 2422.6 25.8 2180.40 N . lOS5.88 E BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 11 S MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 5800.00 47.75 26.07 N 26 4 E 0.11 4866.97 2441.1 25.8 2197.01 N 1064 03 E 5825.00 47.70 25.84 N 25 50 E 0.18 4883.79 2459.6 25.8 2213.64 N . 1072.12 E 5850.00 47.50 25.94 N 25 56 E 0.21 4900.65 2478.1 25.8 2230.25 N 1080.18 E 5875.00 47.78 26.33 N 26 20 E 0.40 4917.49 2496.5 25.8 2246.84 N 1088 32 E 5900.00 48.16 26.73 N 26 44 E 0.48 4934.23 2515.1 25.8 2263.45 N . 1096.61 E 5925.00 48.29 27.01 N 27 1 E 0.25 4950.88 2533.7 25.9 2280.08 N 1105 04 E 5950.00 48.59 27.35 N 27 21 E 0.39 4967.47 2552.5 25.9 2296.72 N . 1113 58 E 5975.00 48.51 27.93 N 27 56 E 0.45 4984.02 2571.2 25.9 2313.33 N . 1122 27 E 6000.00 48.70 28.18 N 28 11 E 0.26 5000.55 2589.9 25.9 2329.88 N . 1131 10 E 6025.00 48.61 28.31 N 28 18 E 0.13 5017.06 2608.7 25.9 2346.41 N . 1139.98 E 6050.00 48.49 28.27 N 28 16 E 0.12 5033.61 2627.4 25.9 2362.91 N 1148 86 E 6075.00 48.55 28.23 N 28 14 E 0.07 5050.17 2646.1 25.9 2379.41 N . 1157 72 E 6100.00 48.38 28.06 N 28 4 E 0.21 5066.75 2664.8 26.0 2395.91 N . 1166 55 E 6125.00 48.41 28.12 N 28 7 E 0.05 5083.35 2683.5 26.0 2412.40 N . 1175.35 E 6150.00 48.22 27.95 N 27 57 E 0.23 5099.97 2702.2 26.0 2428.88 N 1184.13 E 6175.00 48.05 27.95 N 27 57 E 0,17 S 116.66 2720.8 26.0 2445.33 N 1192 85 E 6200.00 48.19 27.82 N 27 49 E 0.17 5133.34 2739.4 26.0 2461.78 N . 1201.56 E 6225.00 48.00 27.78 N 27 47 E 0.20 S 150.04 2758.0 26.0 2478.24 N 1210 24 E 6250.00 47.81 27.59 N 27 36 E 0.23 5166.80 2776.5 26.0 2494.67 N . 1218.86 E 6275.00 47.90 27.49 N 27 29 E 0.12 5183.57 2795.0 26.0 2511.10 N 1227.43 E 6300.00 47.97 27.38 N 27 23 E 0.10 5200.32 2813.6 26.1 2527.58 N 1235.98 E 6325.00 48.15 27.27 N 27 16 E 0.20 5217.03 2832.2 26.1 2544.10 N 1244.52 E 6350.00 47.95 27.14 N 27 9 E 0.22 5233.74 2850.8 26.1 2560.63 N 1253.02 E 6375.00 48.26 27.79 N 27 47 E 0.57 5250.44 2869.4 26.1 2577.15 N 1261.60 E A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 6400.00 47.93 29.58 N 29 35 E 1.37 5267.14 2888.0 26.1 2593.47 N 1270.53 E 6425.00 6450 00 48.00 48 22 29.90 N 29 54 E 0.24 5283.88 2906.5 26.1 2609.59 N 1279.74 E . 6475.00 . 48 05 29.79 65 29 N N 29 29 48 39 E 0.24 5300.57 2925.1 26.1 2625.73 N 1289.00 E 6500.00 . 47.86 . 06 30 N 30 4 E E 0.20 5317.25 2943.6 26.2 2641.90 N 1298.23 E 6525.00 47.23 . 31.40 N 31 24 E 0.36 1 18 5333.99 2962.2 26.2 2658.01 N 1307.48 E . 5350.87 2980.6 26.2 2673.86 N 1316.90 E 6550.00 6575 00 47.49 47 62 31.87 N 31 52 E 0.43 5367.81 2998.9 26.3 2689.52 N 1326.55 E . 6600 00 . 47 80 32.24 32 49 N N 32 32 14 E 0.30 5384.68 3017.2 26.3 2705.15 N 1336.34 E . 6625.00 . 47.96 . 32 97 N 32 29 58 E E 0.26 5401.50 3035.6 26.3 2720.77 N 1346.24 E 6650.00 47.93 . 33 73 N 33 44 E 0.39 5418.26 3054.0 26.4 2736.37 N 1356.26 E . 0.57 5435.01 3072.5 26.4 2751.88 N 1366.47 E 6675.00 6700 00 48.01 48 26 33.85 N 33 51 E 0.12 5451.75 3090.9 26.5 2767.31 N 1376.80 E . 6725.00 . 48 27 33.84 34 01 N N 33 34 51 1 E E 0.25 5468.43 3109.4 26.5 2782.78 N 1387.17 E 6750.00 . 48.26 . 34.27 N 34 16 E 0.13 0 20 5485.08 3127.9 26.5 2798.25 N 1397.58 E 6775.00 48.19 34.69 N 34 42 E . 0 32 5501.72 3146.3 26.6 2813.69 N 1408.05 E . 5518.37 3164.8 26.6 2829.06 N 1418.61 E 6800.00 6825 00 48.10 47 98 34.80 N 34 48 E 0.12 5535.05 3183.2 26.7 2844.36 N 1429.22 E . 6850 00 . 48 11 34.76 34 90 N N 34 34 46 E 0.12 5551.77 3201.7 26.7 2859.63 N 1439.83 E . 6875.00 . 48.02 . 35 09 N 35 54 5 E E 0.16 5568.48 3220.1 26.8 2874,90 N 1450.45 E 6900.00 48.35 . 35.23 N 35 14 E 0.17 0 35 5585.19 3238.5 26.8 2890.13 N 1461.11 E . 5601.86 3256.9 26.9 2905.36 N 1471.84 E 6925.00 6950 00 48.27 48 38 35.47 N 35 28 E 0.19 5618.48 3275.4 26.9 2920.59 N 1482.64 E . 6975 00 . 48 10 35.28 34 38 N N 35 34 17 23 E 0.18 5635.10 3293.8 27.0 2935.82 N 1493.45 E . . . E 0.73 5651.75 3312.3 27.0 2951.12 N 1504.11 E A Gyrodata Directional Survey • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 7000.00 47.75 33.57 N 33 34 E 0.70 5668.51 3330.7 27.0 2966.51 N 1514 48 E 7025.00 47.87 33.50 N 33 30 E 0.14 5685.30 3349.1 27.1 2981.95 N . 1524.71 E 7050.00 47.67 33.77 N 33 46 E 0.29 5702.10 3367.5 27.1 2997.36 N 1534 96 E 7075.00 47.95 33.99 N 33 59 E 0.32 5718.89 3385.9 27.2 3012.74 N . 1545 29 E 7100.00 48.31 34.27 N 34 16 E 0.41 5735.58 3404.4 27.2 3028.15 N . 1555 74 E 7125.00 48.37 33.96 N 33 57 E 0.25 5752.19 3423.0 27.2 3043.61 N . 1566 21 E 7150.00 48.52 33.59 N 33 35 E 0.31 5768.78 3441.5 27.3 3059.16 N . 1576.61 E 7175.00 48.48 33.58 N 33 35 E 0.04 5785.34 3460.1 27.3 3074.76 N 1586 97 E 7200.00 48.52 33.77 N 33 46 E 0.15 5801.91 3478.8 27.3 3090.34 N . 1597 35 E 7225.00 48.35 34.18 N 34 11 E 0.34 5818.49 3497.3 27.4 3105.86 N . 1607 80 E 7250.00 48.27 34.30 N 34 18 E 0.12 5835.12 3515.9 27.4 3121.29 N . 1618 31 E 7275.00 48.39 34.29 N 34 17 E 0.12 5851.74 3534.4 27.4 3136.72 N . 1628.83 E 7300.00 48.19 34.18 N 34 11 E 0.21 5868.38 3552.9 27.5 3152.15 N 1639 33 E 7325.00 47.70 33.23 N 33 14 E 0.86 5885.13 3571.4 27.5 3167.59 N . 1649 63 E 7350.00 47.36 32.42 N 32 25 E 0.69 5902.01 3589.8 27.5 3183.08 N . 1659 62 E 7375.00 47.41 32.35 N 32 21 E 0.07 5918.93 3608.1 27.6 3198.62 N . 1669 48 E 7400.00 47.09 32.72 N 32 43 E 0.43 5935.90 3626.4 27.6 3214.10 N . 1679.35 E 7425.00 46.73 33.00 N 33 0 E 0.41 5952.98 3644.6 27.6 3229.43 N 1689 26 E 7450.00 46.86 33.10 N 33 6 E 0.15 5970.10 3662.7 27.6 3244.71 N . 1699 20 E 7475.00 46.54 33.45 N 33 27 E 0.41 5987.24 3680.8 27.7 3259.92 N . 1709 18 E 7500.00 46.47 33.65 N 33 39 E 0.16 6004.45 3698.8 27.7 3275.03 N . 1719 20 E 7525.00 46.67 33.46 N 33 28 E 0.24 6021.64 3716.9 27.7 3290.16 N . 1729.24 E 7550.00 46.57 33.69 N 33 42 E 0.20 6038.81 3735.0 27.8 3305.30 N 1739 29 E 7575.00 46.72 33.87 N 33 52 E 0.20 6055.97 3753.1 27.8 3320.41 N . 1749.39 E A Gyrodata Directional Survey • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 7600.00 47.00 34.01 N 34 1 E 0.30 6073.06 3771.2 27.8 3335.54 N 1759 58 E 7625.00 47.27 34.43 N 34 26 E 0.41 6090.07 3789.4 27.8 3350.70 N . 1769 89 E 7650.00 47.49 34.68 N 34 41 E 0.29 6107.00 3807.7 27.9 3365.85 N . 1780.32 E 7675.00 47.71 34.97 N 34 58 E 0.30 6123.85 3826.0 27.9 3381.00 N 1790 86 E 7700.00 47.46 35.44 N 35 26 E 0.43 6140.72 3844.3 27.9 3396.08 N . 1801.50 E 7725.00 47.49 35.27 N 35 16 E 0.12 6157.61 3862.6 28.0 3411.11 N 1812 16 E 7750.00 47.49 35.30 N 35 18 E 0.02 6174.51 3880.9 28.0 3426.15 N . 1822 81 E 7775.00 47.22 35.02 N 35 1 E 0.34 6191.45 3899.1 28.0 3441.19 N . 1833.40 E 7800.00 46.59 33.92 N 33 55 E 1.02 6208.53 3917.3 28.1 3456.23 N 1843 73 E 7825.00 46.68 33.60 N 33 36 E 0.25 6225.69 3935.3 28.1 3471.35 N . 1853 83 E 7850.00 46.43 33.69 N 33 42 E 0.26 6242.88 3953.4 28.1 3486.46 N . 1863 89 E 7875.00 46.57 33.87 N 33 52 E 0.18 6260.09 3971.5 28.2 3501.53 N . 1873 97 E 7900.00 46.54 33.92 N 33 55 E 0.05 6277.29 3989.5 28.2 3516.59 N . 1884.09 E 7925.00 46.60 34.14 N 34 8 E 0.17 6294.47 4007.6 28.2 3531.64 N 1894 25 E 7950.00 46.71 34.21 N 34 12 E 0.12 6311.63 4025.7 28.2 3546.68 N . 1904 46 E 7975.00 46.70 33.54 N 33 32 E 0.48 6328.78 4043.8 28.3 3561.79 N . 1914 60 E 8000.00 46.73 32.87 N 32 52 E 0.49 6345.92 4061.9 28.3 3577.01 N . 1924 57 E 8025.00 46.98 32.64 N 32 38 E 0.31 6363.02 4080.1 28.3 3592.35 N . 1934.44 E 8050.00 46.89 32.45 N 32 27 E 0.16 6380.09 4098.3 28.3 3607.75 N 1944.26 E 8075.00 47.10 32.58 N 32 35 E 0.22 6397.14 4116.5 28.3 3623.17 N 1954.09 E 8100.00 47.28 32.89 N 32 53 E 0.29 6414.13 4134.8 28.4 3638.60 N 1964 01 E 8125.00 47.45 32.95 N 32 57 E 0.17 6431.06 4153.2 28.4 3654.03 N . 1974.00 E 8150.00 47.43 33.11 N 33 7 E 0.12 6447.97 4171.5 28.4 3669.47 N 1984.04 E 8175.00 47.48 33.31 N 33 19 E 0.15 6464.87 4189.9 28.4 3684.88 N 1994.13 E A Gyrodata Directional Survey • L` BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL. CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 8200.00 47.51 33.51 N 33 31 E 0.15 6481,77 4208.2 28.4 3700.27 N 2004 28 E 8225.00 47.15 33.15 N 33 9 E 0.45 6498.71 4226.5 28.5 3715 62 N . 2014 38 E 8250.00 46.82 33.27 N 33 16 E 0.34 6515.76 4244.7 28.5 . 3730.92 N . 2024 39 E 8275.00 47.05 33.17 N 33 10 E 0.24 6532.84 4263.0 28.5 3746.20 N . 2034.39 E 8300.00 46.86 33.06 N 33 4 E 0.20 6549.90 4281.2 28.5 3761.50 N 2044 38 E 8325.00 46.69 32.91 N 32 55 E 0.21 6567.02 4299.3 28.5 3776.78 N . 2054 29 E 8350.00 46.70 32.79 N 32 47 E 0.09 6584.17 4317.5 28.6 3792.06 N . 2064 16 E 8375.00 46.22 32.51 N 32 30 E 0.52 6601.39 4335.5 28.6 3807.32 N . 2073 94 E 8400.00 46.10 32.44 N 32 26 E 0.13 6618.71 4353.5 28.6 3822.54 N . 2083.62 E 8425.00 46.30 32.37 N 32 22 E 0.21 6636.01 4371.5 28.6 3837.77 N 2093 29 E 8450.00 46.16 32.29 N 32 18 E 0.16 6653.30 4389.6 28.6 3853.03 N . 2102 94 E 8475.00 45.72 32.15 N 32 9 E 0.45 6670.69 4407.5 28.6 3868.22 N . 2112 52 E 8500.00 45.69 32.02 N 32 1 E 0.10 6688.15 4425.3 28.7 3883.39 N . 2122 03 E 8525.00 46.65 31.16 N 31 10 E 1.14 6705.46 4443.4 28.7 3898.75 N . 2131.48 E 8550.00 47.00 30.15 N 30 9 E 0.81 6722.56 4461.6 28.7 3914.43 N 2140 77 E 8575.00 48.72 27.97 N 27 S8 E 2.37 6739.34 4480.1 28.7 3930.64 N . 2149 77 E 8600.00 50.64 26.73 N 26 44 E 2.13 6755.51 4499.2 28.7 3947.57 N . 2158 52 E 8625.00 53.33 25.51 N 25 31 E 2.86 6770.91 4518.8 28.7 3965.25 N . 2167 19 E 8650.00 54.97 25.15 N 25 9 E 1.67 6785.55 4539.1 28.6 3983.57 N . 2175.86 E 8675.00 56.39 24.82 N 24 49 E 1.45 6799.64 4559.7 28.6 4002.28 N 2184 58 E 8700.00 57.61 24.80 N 24 48 E 1.22 6813.26 4580.6 28.6 4021.31 N . 2193 38 E 8725.00 58.83 25.55 N 25 33 E 1.38 6826.42 4601.8 28.6 4040.55 N . 2202 42 E 8750.00 60.11 25.83 N 25 50 E 1.30 6839.12 4623.3 28.6 4059.95 N . 2211 76 E 8775.00 60.92 26.05 N 26 3 E 0.83 6851.43 4645.1 28.6 4079.52 N . 2221.28 E A Gyrodata Directional Survey • • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 11S MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 8800.00 61.78 27.21 N 27 12 E 1.33 6863.41 4667.0 28.6 4099 13 N 2231 11 E 8825.00 62.26 28.23 N 28 14 E 1.02 6875.14 4689.1 28.6 . 4118 68 N . 2241 38 E 8850.00 62.57 28.71 N 28 42 E 0.52 6886.72 4711.2 28.6 . 4138 16 N . 2251 94 E 8875.00 62.66 29.20 N 29 12 E 0.45 6898.22 4733.4 28.6 . 4157 58 N . 2262 69 E 8900.00 62.30 29.27 N 29 16 E 0.37 6909.77 4755.6 28.6 . 4176.93 N . 2273.52 E 8925.00 62.58 29.23 N 29 14 E 0.28 6921.34 4777.7 28.6 4196.26 N 2284 35 E 8950.00 62.64 29.18 N 29 11 E 0.08 6932.84 4799.9 28.6 4215 64 N . 2295 18 E 8975.00 62.44 29.12 N 29 7 E 0.20 6944.37 4822.1 28.6 . 4235 01 N . 2305 98 E 9000.00 62.50 29.04 N 29 2 E 0.09 6955.92 4844.3 28.6 . 4254 39 N . 2316 76 E 9025.00 61.95 28.81 N 28 48 E 0.58 6967.57 4866.4 28.6 . 4273.75 N . 2327.46 E 9050.00 62.21 28.80 N 28 48 E 0.25 6979.28 4888.5 28.6 4293 10 N 2338 10 E 9075.00 62.44 28.63 N 28 38 E 0.28 6990.89 4910.6 28.6 . 4312 52 N . 2348 74 E 9100.00 62.81 28.35 N 28 21 E 0.44 7002.38 4932.8 28.6 . 4332 03 N . 2359 33 E 9125.00 62.90 28.09 N 28 6 E 0.25 7013.79 4955.1 28.6 . 4351 63 N . 2369 85 E 9150.00 62.78 27.84 N 27 50 E 0.26 7025.20 4977.3 28.6 . 4371.28 N . 2380.28 E 9175.00 62.99 27.28 N 27 17 E 0.54 7036.59 4999.6 28.6 4391 01 N 2390 57 E 9200.00 63.00 26.02 N 26 1 E 1.12 7047.95 5021.8 28.6 . 4410.92 N . 2400 57 E 9225.00 62.93 25.08 N 25 5 E 0.84 7059.31 5044.1 28.5 4431 01 N . 2410 17 E 9250.00 63.10 24.49 N 24 29 E 0.55 7070.65 5066.3 28.5 . 4451 23 N . 2419 51 E 9275.00 63.17 23.35 N 23 21 E 1.02 7081.95 5088.5 28.5 . 4471.62 N . 2428.55 E 9300.00 63.29 21.72 N 21 43 E 1.46 7093.21 S 110.7 28.5 4492.23 N 2437 11 E 9325.00 63.37 21.27 N 21 16 E 0.41 7104.43 5132.9 28.5 4513 02 N . 2445 29 E 9350.00 63.23 20.94 N 20 S7 E 0.32 7115.67 S 155.1 28.4 . 4533 85 N . 2453 33 E 9375.00 63.18 19.84 N 19 50 E 0.99 7126.94 5177.2 28.4 . 4554 77 N . 2461 11 E 9400.00 62.96 18.29 N 18 18 E 1.40 7138.26 5199.2 28.3 . 4575.84 N . 2468.39 E A Gyrodata Directional Survey • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg, deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 9425.00 62.91 17.82 N 17 49 E 0.42 7149.64 5221.1 28.3 4597.00 N 2475 29E • 9450.00 63.10 17.40 N 17 24 E 0.43 7160.98 5243.0 28.3 4618.23 N . 2482.03 E 9475.00 63.34 16.03 N 16 2 E 1.24 7172.25 5264.8 28.2 4639.61 N 2488.45 E 9500.00 63.11 14.45 N 14 27 E 1.43 7183.51 5286.6 28.2 4661.14 N 2494 32 E 9525.00 63.21 13.90 N 13 54 E 0.49 7194.80 5308.2 28.1 4682.77 N . 2499.78 E 9550.00 63.28 12.93 N 12 56 E 0.88 7206.05 5329.8 28.0 4704.48 N 2504 96 E 9575.00 63.21 11.15 N 11 9 E 1.59 7217.31 5351.3 28.0 4726.32 N . 2509 61 E 9600.00 63.08 10.03 N 10 2 E 1.00 7228.60 5372.6 27.9 4748.24 N . 2513.71 E 9625.00 63.00 9.52 N 9 31 E 0.47 7239.94 5393.8 27.8 4770.20 N 2517.49 E 9650.00 63.05 8.78 N 8 47 E 0..66 7251.28 5414.9 27.7 4792.20 N 2521.04 E 9675.00 62.52 6.75 N 6 45 E 1.88 7262.71 5435.8 27.7 4814.22 N 2524 04 E 9700.00 62.76 6.32 N 6 19 E 0.45 7274.20 5456.5 27.6 4836.28 N . 2526.56 E 9725.00 62.66 6.01 N 6 0 E 0.29 7285.66 5477.2 27.5 4858.37 N 2528.95 E 9750.00 62.88 5.91 N 5 54 E 0.24 7297.10 5497.8 27.4 4880.48 N 2531.26 E 9775.00 62.72 5.51 N 5 31 E 0.39 7308.53 5518.5 27.3 4902..61 N 2533.47 E 9800.00 62.57 5.40 N 5 24 E 0.18 7320.01 5539.1 27.2 4924.71 N 2535.58E • 9825.00 62.56 4.89 N 4 53 E 0.45 7331.53 5559.7 27.2 4946.81 N 2537.57 E 9850.00 62.09 3.65 N 3 39 E 1.19 7343.14 5580.1 27.1 4968.89 N 2539.21 E 9875.00 61.99 3.62 N 3 37 E 0.10 7354.86 5600.4 27.0 4990.93 N 2540,61 E 9900.00 62.12 3.63 N 3 38 E 0.13 7366.58 5620.6 26.9 5012.97 N 2542.01 E 4925.00 62.12 3.55 N 3 33 E 0.07 7378.27 5640.9 26.8 5035.02 N 2543.40 E 9950.00 62.00 3.36 N 3 22 E 0.21 7389.98 5661.2 26.7 5057.07 N 2544.73 E 9975.00 62.25 3.28 N 3 17 E 0.26 7401.67 5681.5 26.6 5079.13 N 2546.01 E 10000.00 62.85 3.02 N 3 1 E 0.64 7413.19 5701.9 26.5 5101.28 N 2547.23 E A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 10025.00 63.59 2.72 N 2 43 E 0.78 7424.46 5722.3 26.4 5123.57 N 2548.35 E 10050.00 10075 00 63.90 64 01 2.62 N 2 37 E 0.33 7435.51 5742.9 26.4 5145.97 N 2549.39 E . 10100.00 . 64.13 2.45 2 42 N N 2 2 27 25 E E 0.18 7446.49 5763.4 26.3 5168.41 N 2550.38 E 10125.00 64.16 . 2 30 N 2 18 E 0.13 7457.42 5784.0 26.2 5190.87 N 2551.34 E 10150.00 64.00 . 2 18 N 2 11 E 0.11 7468.32 5804.6 26.1 5213.35 N 2552.27 E . 0.20 7479.25 5825.1 26.0 5235.82 N 2553.15 E 10175.00 10200 00 64.07 63 88 2.03 1 87 N 2 2 E 0.15 7490.20 5845.7 25.9 5258.28 N 2553.97 E . 10225.00 . 63.72 . 1 76 N N 1 1 52 46 E E 0.24 7501.17 5866.2 25.8 5280.73 N 2554.73 E 10250.00 63.68 . 1 75 N 1 45 E 0.18 7512.20 5886.7 25.7 5303.15 N 2555.44 E 10275.00 63.80 . 1 71 N 1 43 E 0.04 7523.28 5907.2 25.6 5325.56 N 2556.13 E . 0.13 7534.34 5927.7 25.6 5347.97 N 2556.81 E 10300.00 10325 00 63.73 63 50 1.76 1 69 N 1 46 E 0.09 7545.39 5948.3 25.5 5370.38 N 2557.49 E . 10350.00 . 63.65 . 1 53 N N 1 1 41 32 E E 0.24 7556.50 5968.8 25.4 5392.77 N 2558.16 E 10375.00 63.94 . 1 42 N 1 25 E 0.21 7567.63 5989.3 25.3 5415.15 N 2558.79 E 10400.00 64.37 . 1 22 N 1 13 E 0.30 7578.66 6009.8 25.2 5437.57 N 2559.36 E . 0.47 7589.56. 6030.4 25.1 5460.06 N 2559.88 E 10425.00 10450 00 64.49 63 97 1.10 0 88 N 1 6 E 0.16 7600.36 6051.0 25.0 5482.61 N 2560.34 E . 10475.00 . 64.01 . 0 71 N N 0 0 53 42 E E 0.56 7611.22 6071.5 24.9 5505.12 N 2560.73 E 10500.00 64.1b . 0 55 N p 33 E 0.16 7622.19 6092.1 24.9 5527.58 N 2561.04 E 10525.00 64.19 . 0 48 N 0 29 E 0.21 7633.12 6112.6 24.8 5550.07 N 2561.29 E . 0.07 7644.01 6133.1 24.7 5572.57 N 2561.49 E 10550.00 10575 00 64.14 63 76 0.34 0 20 N 0 20 E 0.14 7654.90 6153.6 24.6 5595.07 N 2561.65 E . 10600.00 . 63.83 . 0 12 N N 0 0 12 7 E E 0.40 7665.88 6174.1 24.5 5617.53 N 2561.75 E . 0.10 7676.92 6194.5 24.4 5639.96 N 2561.82 E A Gyrodata Directional Survey • • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg.! 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 10625.00 10650 00 63.68 63 97 0.25 N 0 15 E 0.18 7687.97 6215.0 24.3 5662.38 N 2561.89 E . . 0.55 N 0 33 E 0.39 7699.00 6235.5 24.3 5684.82 N 2562.05 E 10675.00 10700 00 64.53 64 80 0.97 N 0 58 E 0.67 7709.86 6256.1 24.2 5707.33 N 2562.34 E . 10725.00 . 64.83 1.33 1 53 N N 1 1 20 32 E E 0.43 7720.56 6276.9 24.1 5729.92 N 2562.80 E 10750.00 65.03 . 1 78 N 1 47 E 0.18 7731.20 6297.8 24.0 5752.54 N 2563.36 E 10775.00 65.33 . 2 25 N 2 15 E 0.30 7741.80 6318.8 23.9 5775.17 N 2564.02 E . 0.52 7752.29 6339.8 23.9 5797.85 N 2564.82 E 10800.00 10825 00 65.28 65 14 2.66 N 2 39 E 0.38 7762.74 6361.0 23.8 5820.54 N 2565.79 E . 10850.00 . 65.11 2.69 2 70 N N 2 2 41 42 E E 0.14 7773.22 6382.2 23.7 5843.22 N 2566.85 E 10875.00 65.02 . 2 65 N 2 39 E 0.03 7783.73 6403.3 23.6 5865.87 N 2567.91 E 10900.00 64.96 . 2 67 N 2 40 E 0.10 7794.27 6424.5 23.6 5888.52 N 2568.97 E . 0.06 7804.84 6445.7 23.5 5911.15 N 2570.02 E 10925.00 10950 00 64.88 64 88 3.03 N 3 2 E 0.34 7815.44 6466.9 23.4 5933.76 N 2571.15 E . 10975.00 . 64 86 3.81 4 44 N N 3 4 48 26 E 0.70 7826.06 6488.1 23.4 5956.36 N 2572.50 E 11000.00 . 64.91 . 4 63 N 4 38 E E 0.58 7836.67 6509.5 23.3 5978.93 N 2574.12 E 11025.00 64.81 . 4 59 N 4 36 E 0.18 7847.28 6530.9 23.2 6001.50 N 2575.91 E . 0.11 7857.90 6552.4 23.2 6024.06 N 2577.73 E 11050.00 11075 00 64.66 4.44 N 4 26 E 0.20 7868.57 6573.8 23.1 6046.60 N 2579.51 E . 11100 00 64.42 64 35 4.31 4 16 N N 4 4 19 E 0.26 7879.32 6595.2 23.0 6069.10 N 25$1.23 E . 11125.00 . 64.31 . 4 13 N 4 9 8 E E 0.16 7890.13 6616.6 23.0 6091.58 N 2582.90 E 11150.00 64.20 . 4 12 N 4 7 E 0.04 7900.96 6637.9 22.9 6114.06 N 2584.53 E . 0.11 7911.81 6659.2 22.9 6136.52 N 2586.15 E 11175.00 11200 00 64.10 63 97 4.12 4 11 N 4 7 E 0.11 7922.71 6680.5 22.8 6158.96 N 2587.76 E . . . N 4 7 E 0.13 7933.66 6701.8 22.7 6181.38 N 2589.38 E A Gyrodata Directional Survey • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 11225.00 63.97 4.19 N 4 11 E 0.07 7944.63 6723.1 22.7 6203.78 N 2591 00 E 11250.00 63.87 4.12 N 4 7 E 0.12 7955.62 6744.4 22.6 6226.18 N . 2592 63 E 11275.00 63.80 4.17 N 4 10 ' E 0.09 7966.65 6765.7 22.5 6248.56 N . 2594.25 E 11300.00 63.44 4.29 N 4 17 E 0.37 7977.75 6787.0 22.5 6270.89 N 2595 90 E 11325.00 63.42 4.24 N 4 15 E 0.05 7988.94 6808.2 22.4 6293.19 N . 2597 56 E 11350.00 63.19 4.22 N 4 13 E 0.22 8000.1.7 6829.4 22.4 6315.46 N . 2599 21 E 11375.00 62.91 4.18 N 4 11 E 0.29 8011.50 6850.6 22.3 6337.69 N . 2600 84 E 11400.00 62.86 4.24 N 4 14 E 0.07 8022.89 6871.8 22.3 6359.88 N . 2602.47 E 11425.00 62.68 4.22 N 4 13 E 0.18 8034.33 6892.9 22.2 6382.05 N 2604 11 E 11450.00 62.61 4.28 N 4 17 E 0.09 8045.82 6914.0 22.1 6404.19 N . 2605 76 E 11475.00 62.59 4.34 N 4 21 E 0.06 8057.32 6935.2 22.1 6426.33 N . 2607 43 E 11500.00 62.38 4.21 N 4 13 E 0.24 8068.88 6956.3 22.0 6448.44 N . 2609 08 E 11525.00 62.75 4.17 N 4 10 E 0.38 8080.39 6977.4 22.0 6470.57 N . 2610,71 E 11550.00 62.52 4.11 N 4 6 E 0.24 8091.88 6998.5 21.9 6492.71 N 2612 31 E 11575.00 b2.52 3.94 N 3 56 E 0.15 8103.42 7019.6 21.9 6514.83 N . 2613 86 E 11600.00 62.88 3.90 N 3 54 E 0.36 8114.89 7040.8 21.8 6537.00 N . 2615 38 E 11625.00 63.54 3.84 N 3 50 E 0.66 8126.16 7062.0 21.8 6559.26 N . 2616 89 E 11650.00 64.04 3.87 N 3 52 E 0.50 8137.20 7083.4 21.7 6581.64 N . 2618.39 E 11675.00 63.86 3.76 N 3 46 E 0.20 8148.18 7104.7 21.6 6604.05 N 2619 89 E 11700.00 64.08 3.75 N 3 45 E 0.22 8159.15 7126.1 21.6 6626.47 N . 2621.36 E 11725.00 64.36 3.83 N 3 50 E 0.28 8170.02 7147.6 21.5 6648.93 N 2622 85 E 11750.00 64.24 3.83 N 3 50 E 0.11 8180.86 7169.0 21.5 6671.41 N . 2624 35 E 11775.00 64.29 3.85 N 3 51 E 0.05 8191.72 7190.5 21.4 6693.88 N . 2625.$6 E 11800.00 63.92 3.78 N 3 47 E 0.38 8202.64 7211.9 21.4 6716.32 N 2627.35 E A Gyrodata Directional Survey .J • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-112" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 11825.00 63.95 3.70 N 3 42 E 0.07 8213.62 7233.3 21.3 6738.73 N 2628 82 E 11850.00 63.71 3.52 N 3 31 E 0.29 8224.65 7254.7 21.3 6761.12 N . 2630 23 E 11875.00 63.72. 3.44 N 3 27 E 0.07 8235.72 7276.1 21.2 6783.49 N . 2631 59 E 11900.00 63.58 3.41 N 3 24 E 0.13 8246.82 7297.4 21.1 6805.85 N . 2632.93 E 11925.00 63.33 3.46 N 3 27 E 0.25 8257.99 7318.7 21.1 6828.18 N 2634 27 E 11950.00 63.28 3.44 N 3 26 E 0.05 8269.22 7340.0 21.0 6850.47 N . 2635 61 E 11975.00 63.49 3.44 N 3 26 E 0.21 8280.42 7361.3 21.0 6872.79 N . 2636 95 E 12000.00 64.24 3.46 N 3 28 E 0.74 8291.43 7382.7 20.9 6895.19 N . 2638 30 E 12025.00 64.68 3.54 N 3 33 E 0.45 8302.21 7404.2 20.9 6917.70 N . 2639.68 E 12050.00 64.36 3.63 N 3 38 E 0.33 8312.96 7425.8 20.8 6940.23 N 2641 09 E 12075.00 64,69 4.00 N 4 0 E 0.47 8323.71 7447.4 20.8 6962.75 N , 2642 60 E 12100.00 65.34 4.63 N 4 38 E 0.86 8334.27 7469.1 20.7 6985.34 N . 2644 30 E 12125.00 65.50 4.97 N 4 58 E 0.35 8344.67 7491.0 20.7 7008.00 N . 2646 20 E 12150.00 65.24 4.93 N 4 S6 E 0.26 8355.09 7512.8 20.6 7030.64 N . 2648.16 E 12175.00 65.25 4.86 N 4 51 E 0.07 8365.56 7534.7 20.6 7053.26 N 2650 10 E 12200.00 65.09 4.73 N 4 44 E 0.20 8376.06 7556.5 20.5 7075.87 N . 2652 00 E 12225.00 64.98 4.76 N 4 46 E 0.12 8386.61 7578.3 20.5 7098.45 N . 2653 87 E 12250.00 64.75 4.74 N 4 44 E 0.22 8397.23 7600.1 20.5 7121.01 N . 2655 75 E 12275.00 64.54 4.78 N 4 47 E 0.22 8407.94 7621.9 20.4 7143.52 N . 2657.62 E 12300.00 64.53 4.75 N 4 45 E 0.02 8418.69 7643.6 20.4 7166.02 N 2659 50 E 12325.00 64.08 4.73 N 4 44 E 0.46 8429.53 7665.3 20.3 7188.47 N . 2661 36 E 12350.00 64.05 4.69 N 4 41 E 0.05 8440.46 7687.0 20.3 7210.87 N . 2663 20 E 12375.00 63.94 4.63 N 4 38 E 0.13 8451.42 7708.6 20.2 7233.27 N . 2665 03 E 12400.00 64.02 4.56 N 4 33 E 0.10 8462.39 7730.2 20,2 7255.66 N . 2666.82 E A Gyrodata Directional Survey • • BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG SEVERITY deg./ 25 ft. VERTICAL, CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 12425.00 63.76 4.56 N 4 33 E 0.26 8473.39 7751.9 20.1 7278.04 N 2668 61 E 12450.00 63.77 4.52 N 4 31 E 0.03 8484.44 7773.5 20.1 7300.39 N . 2670 38 E 12475.00 63.73 4.49 N 4 29 E 0.06 8495.50 7795.1 20.0 7322.75 N . 2672 14 E 12500.00 63.40 4.36 N 4 22 E 0.34 8506.63 7816.6 20.0 7345.06 N . 2673 87 E 12525.00 63.23 4.26 N 4 16 E 0.19 8517.86 7838.1 20.0 7367.34 N . 2675.55 E 12550.00 63.17 4.21 N 4 12 E 0.08 8529.13 7859.6 19.9 7389 59 N 2677 20 E 12575.00 63.06 4.17 N 4 10 E 0.12 8540.43 7881.1 19.9 . 7411 83 N . 2678 82 E 12600.00 63.06 4.15 N 4 9 E 0.02 8551.76 7902.5 19.8 . 7434 06 N . 2680 44 E 12625.00 62.57 4.25 N 4 15 E 0.49 8563.18 7924.0 19.8 . 7456.24 N . 2682 07 E 12650.00 61.1$ 4.77 N 4 46 E 1.47 8574.96 7945.2 19.7 7478.22 N . 2683.80 E 12675.00 58.90 5.32 N 5 19 E 2.33 8587.45 7966.2 19.7 7499 79 N 2685 71 E 12700.00 56.49 6.08 N 6 5 E 2.49 8600.81 7986.7 19.7 . 7520 82 N . 2687 80 E 12725.00 54.64 6.59 N 6 35 E 1.90 8614.94 8006.7 19.6 . 7541 31 N . 2690 08 E 12750.00 52.30 7.33 N 7 20 E 2.42 8629.82 8026.3 19.6 . 7561 25 N . 2692 51 E 12775.00 49.26 8.09 N 8 5 E 3.10 8645.63 8045.3 19.6 . 7580.44 N . 2695.10 E 12800.00 46.73 8.54 N 8 32 E 2.55 8662.36 8063.5 19.5 7598 82 N 2697 79 E 12825.00 44.77 9.09 N 9 5 E 2.01 8679.80 8081.1 19.5 . 7616 52 N . 2700 53 E 12850.00 42.67 9.46 N 9 27 E 2.11 8697.87 8098.1 19.5 . 7633 57 N . 2703 31 E 12875.00 40.13 9.74 N 9 45 ' E 2.54 8716.62 8114.4 19.5 . 7649 87 N . 2706 07 E 12900.00 37.80 10.19 N 10 11 E 2.35 8736.06 8129.9 19.5 . 7665.35 N . 2708.79 E 12925.00 35.43 9.70 N 9 42 E 2.39 8756.12 8144.6 19.4 7680 04 N 2711 36 E 12950.00 33.01 8.79 N 8 47 E 2.47 8776.79 8158.4 19.4 . 7693 91 N . 2713 62 E 12975.00 30.78 6.88 N 6 53 E 2.45 8798.01 8171.4 19.4 . 7707 00 N . 2715 43 E 13000.00 28.$2 5.46 N 5 28 E 2.08 8819.71 8183.5 19.4 . 7719.35 N . 2716 77 E 13025.00 26.78 4.99 N 5 0 E 2.05 8841.82 8194.8 19.4 7730.96 N . 2717.84 E A Gyrodata Directional Survey A Gyrodata Directional Survey BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 25 ft. 13050.00 23.47 4.94 N 4 56 E 3.31 8864.45 8205.1 19.4 7741.53 N 2718 75 E • 13075.00 20.18 4.60 N 4 36 E 3.29 8887.66 8214.1 19.3 7750.79 N . 2719 53 E 13100.00 18.70 4.25 N 4 15 E 1.48 8911.23 8222.1 19.3 7759.09 N . 2720 17 E 13125.00 17.19 5.69 N 5 42 E 1.58 8935.02 8229.6 19.3 7766.76 N . 2720 84 E 13150.00 15.32 9.31 N 9 19 E 2.12 8959.02 8236.4 19.3 7773.69 N . 2721.74 E 13175.00 14.32 11.34 N 11 21 E 1.12 8983.18 8242.7 19.3 7779.98 N 2722 88 E 13200.00 13.71 11.52 N 11 31 E 0.61 9007.44 8248.7 19.3 7785.92 N . 2724 08 E 13225.00 13.44 11.59 N 11 35 E 0.28 9031.74 8254.5 19.3 7791.67 N . 2725 25 E 13250.00 13.08 11.25 N 11 15 E 0.36 9056.07 8260.2 19.3 7797.29 N . 2726 39 E 13275.00 12.48 12.27 N 12 16 E 0.65 9080.46 8265.7 19.3 7802.70 N . 2727.52 E 13300.00 12.63 12.17 N 12 10 E 0.15 9104.86 8271.1 19.3 7808.01 N 2728 67 E 13325.00 12.59 12.13 N 12 8 E 0.04 9129.25 8276.5 19.3 7813.35 N . 2729 81 E 13350.00 12.54 12.10 N 12 6 E 0.04 9153.66 8281.9 19.3 7818.66 N . 2730 96 E 13375.00 12.50 12.08 N 12 5 E 0.04 9178.06 8287.3 19.2 7823.96 N . 2732 09 E 13400.00 12.46 12.05 N 12 3 E 0.04 9202.47 8292.6 19.2 7829.25 N . 2733.22 E 13425.00 12.41 12.03 N 12 2 E 0.04 9226.88 8298.0 19.2 7834.51 N 2734 34 E • 13450.00 12.37 12.01 N 12 0 E 0.04 9251.30 8303.3 19.2 7839.76 N . 2735 46 E 13475.00 12.33 11.98 N 11 59 E 0.04 9275.72 8308.6 19.2 7844.99 N . 2736 57 E 13500.00 12.28 11.96 N 11 57 E 0.04 9300.15 8313.9 19.2 7850.20 N . 2737 68 E 13525.00 12.24 11.93 N 11 56 E 0.04 9324.58 8319.1 19,2 7855.39 N . 2738.77 E 13550.00 12.20 11.91 N 11 54 E 0.04 9349.01 8324.4 19.2 7860.57 N 2739 87 E 13575.00 12.15 11.88 N 11 53 E 0.04 9373.45 8329.6 19.2 7865.73 N . 2740 95 E 13600.00 12.11 11.86 N 11 52 E 0.04 9397.89 8334.8 19.2 7870.87 N . 2742 04 E 13625.00 11.71 12.04 N 12 3 E 0.40 9422.35 8339.9 19.2 7875.92 N . 2743.10 E BP Exploration (Alaska) Lease: Niakuk Well: NK-65A, 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska Job Number: AK0308G 115 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. 13650.00 11.31 12.23 N 12 14 E 13675.00 10.91 12.41 N 12 25 E 13700.00 10.52 12.60 N 12 36 E 13725.00 11.17 14.03 N 14 2 E 13750.00 11.84 15.47 N 15 28 E 13775.00 12.50 16.91 N 16 55 E 13800.00 13.16 18.35 N 18 21 E 13825.00 13.28 17.04 N 17 3 E 13850.00 13.40 15.71 N 15 42 E 13875.00 13.51 14.37 N 14 22 E 13900.00 13.63 13.04 N 13 2 E 13925.00 13.62 13.24 N 13 14 E 13950.00 13.61 13.45 N 13 27 E 13975.00 13.60 13.66 N 13 39 E 14000.00 13.59 13.87 N 13 52 E 14025.00 13.36 12.62 N 12 37 E 14050.00 13.12 11.36 N 11 22 E 14075.00 12.88 10.10 N 10 6 E 14100.00 12.65 8.84 N 8 51 E 14125.00 12.24 9.77 N 9 46 E 14150.00 11.83 10.73 N 10 44 E 14154.95 11.75 10.92 N 10 55 E Final Station Closure: Distance: 8455.23 ft Az: 19.12 deg A Gyrodata Directional Survey DOGLEG SEVERITY deg./ 25 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 0.40 9446.85 8344.9 19.2 7880.79 N 2744.15 E 0.40 9471.38 8349.7 19.2 7885.50 N 2745.18 E 0.40 9495.95 8354.3 19.2 7890.04 N 2746.19 E 0.71 9520.50 8359.0 19.2 7894.62 N 2747.27 E 0.72 9545.00 8363.9 19.2 7899.44 N 2748.54 E 0.73 9569.44 8369.2 19.2 7904.50 N 2750.01 E 0.74 9593.81 8374.8 19.2 7909.79 N 2751.70 E 0.32 9618.15 8380.5 19.2 7915.23 N 2753.43 E 0.33 9642.48 8386.2 19.2 7920.77 N 2755.06 E 0.33 9666.79 8392.0 19.2 7926.38 N 2756.57 E 0.33 9691.09 8397.9 19.2 7932.08 N 2757.96 E 0.05 9715.39. 8403.7 19.2 7937.82 N 2759.30 E 0.05 9739.68 8409.6 19.2 7943.55 N 2760.65 E 0.05 9763.98 8415.4 19.2 7949.26 N 2762.03 E 0.05 9788.28 8421.3 19.2 7954.97 N 2763.43 E 0.37 9812.59 8427.1 19.2 7960.64 N 2764.77 E 0.37 9836.93 8432.8 19.1 7966.24 N 2765.96 E 0.37 9861.29 8438.3 19.1 7971.76 N 2767.00 E 0.36 9885.67 8443.8 19.1. 7977.21 N 2767.91 E 0.46 9910.08 8449.1 19.1 7982.53 N 2768.78 E 0.46 9934.54 8454.2 19.1 7987.66 N 2769.71 E 0.46 9939.38 8455.2 19.1 7988.65 N 2769.90 E • BP Exploration (Alaska) Well: Niakuk NK-65A 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska 8000 - --- - 7000 6000 5000 z 4000 O z 3000 BOTTOMII HOLE tOCATE6 ---.-- MD: 14.54.95 :7 • 2000 1000 Interp Inrun Gyrodata AK0308G_115 DEFINITIVE u 5uu 1uuU 1500 2000 2500 FASTING (ft) BP Exploration (Alaska) Well: Niakuk NK-65A 4-1/2" Casing Location: Schlumberger Crane 5083, Prudhoe Bay, Alaska 1C 9 8 7 .~. w N v 6 a~ -~ ., ~ 5 w w C7 ~ 4 O 3 2 1 0 Interp Inrun Gyrodata AK0308G_115 DEFINITIVE • • v ~uuu 4uuu buUU 13000 10000 12000 14000 16000 MEASURED DEPTH (ft) BP Exploration (Alaska) n~ 6C 5~ 5G 45 40 z 0 F- z 35 J U 30 25 20 15 10 5 Interp Inrun Gyrodata AK0308G 1151~FFTNTTT\/F • • BOTTOM HOl LOCATED MD: 14154.9 ~; , ~ '. i ~~~~ ~~~~ ~ruuu vuuu uuuu lUUUU 12000 14000 160 MEASURED DEPTH (ft) Survey QC - RGS-CT~cification Sheet SURVEY QUALITY CONTROL -SPECIFICATION DATA INITIALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs (ERMeas-ERrneo) 15 13.29 39.18 0.0166 17 13.29 38.88 0.0153 20 13.29 38.79 0.0155 21 13.29 39.06 0.014E 23 13.29 38.81 0.0358 24 13.29 38.88 0.0102 Average 13.29 38.93 0.0180 Tolerance on Average* 0.0842 Standard Deviation 0.00 0.14 0.0082 Tolerance on St. Dev.** 0.1~ 0.2~ 0.0411 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance = TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cost) * v[(CosA `Sinl*0.1)Z+fLORZ~ihr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosh *e[(l:OSA*Sinl*0.1)Z+(0.052/(n-1))] ~/hr DRIFT TUNES Drift Tune Number Ending Time Ending Depth Ending Inclination Ending Azimuth Residual Gx Bias Residual Gy Bias Start End Start End 1 1487.97 4200.18 45.60 27.24 -0.000 -0.001 0.000 -0.000 2 607.58 4575.66 45.12 24.29 0.001 -0.001 0.000 0.000 3 1336.06 6700.14 48.25 33.85 0.000 -0.001 -0.001 0.002 4 1032.64 8100.10 47.26 32.88 -0.000 -0.000 0.002 -0.001 5 1396.64 9800.18 62.62 5.40 -0.000 -0.000 0.000 -0.000 6 1412.05 12200.35 65.04 4.73 0.000 -0.001 -0.000 0.001 7 911.03 13300.20 12.62 12.16 -0.000 -0.001 0.000 0.000 8 440.91 14130.14 11.97 9.28 0.000 0.000 -0.002 0.002 9 1487.80 13300.35 12.16 11.02 0.000 -0.001 0.003 -0.003 10 1457.47 11500.11- 62.55 4.34 0.000 0.000 0.000 0.000 11 1017.42 10600.31 63.69 0.22 -0.003 0.003 -0.000 0.001 12 1442.33 8600.43 51.97 25.90 0.000 -0.000 0.000 0.001 13 759.41 8100.40 47.40 32.86 0.001 -0.001 -0.000 0.002 14 516.66 7800.41 46.76 33.62 -0.001 0.001 0.000 0,001 15 1442.33 6000.69 48.51 28.13 -0.001 0.002 0.000 0.002 16 1457.42 4000.48 47.09 30.40 0.001 0.000 -0.000 0.002 17 1533.20 2200.74 13.97 37.14 0.000 -0.002 0.000 -0.002 Average -0.000 -0.000 0.000 0.000 Standard Deviation 0.001 0.001 0.001 0.001 Tolerance for both the Average and the Standard Deviation 0.033/hr 0.033/hr 0.033/hr 0.033Q/hr SURV-Q167 (OPS SUR-MA-003) 19~" Nov 03 /Rev 15 Page 1 of 13 AK0308G 115 Survey QC - RGS-CT~cification Sheet . INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * Outrun * Difference Inrun * Outrun * Difference 100.00 0.70 0.67 0.04 42.47 105.01 -62.54 200.00 1.41 1.37 0.04 84.95 89.89 -4.94 300.00 1.27 1.41 -0.14 63.59 81.95 -18.36 400.00 1.13 1.17 -0.04 42.23 39.21 3.02 500.00 2.50 2.10 0.41 0.13 344.46 15.67 600.00 3.87 4.15 -0.28 318.04 317.17 0.87 700.00 4.30 4.88 -0.59 313.73 311.73 1.99 800.00 4.72 4.77 -0.05 309.41 308.74 0.67 900.00 4.06 4.18 -0.12 314.85 313.00 1.85 1000.00 3.39 3.32 0.07 320.28 320.58 -0.30 1100.00 3.15 2.94 0.21 325.07 328.18 -3.11 1200.00 2.92 2.94 -0.02 329.86 329.63 0.24 1300.00 2.94 2.97 -0.03 334.89 330.40 4.49 1400.00 2.97 3.02 -0.05 339.92 340.58 -0.66 1500.00 3.17 3.13 0.04 359.70 359.48 0.22 1600.00 3.37. 3.40 -0.03 19.49 20.09 -0.60 1700.00 4.08 3.77 0.31 22.21 22.90 -0.69 1800.00 4.78 4.91 -0.13 24.94 24.11 0.83 1900.00 7.10 7.11 -0.01 26.17 26.69 -0.52 2000.00 9.42 9.42 0.00 27.40 29.16 -1.76 2100.00 10.86 11.08 -0.22 37.20 37.19 0.01 2200.00 13.27 13.49 -0.22 42.00 37.25 4.75 2225.00 14.16 13.91 0.25 37.16 37.56 -0.41 2250.00 14.78 14.78 -0.00 37.50 37.10 0.40 2275.00 15.53 15.15 0.38 36.68 36.93 -0.25 2300.00 15.71 15.72 -0.02 35.72 35.82 -0.10 2325.00 16.62 16.45 0.17 34.57 34.28 0.29 2350.00 16.93 16.91 0.02 32.83 33.57 -0.74 2375.00 17.79 17.54 0.25 33.19 32.91 0.27 2400.00 18.17 17.94 0.22 31.79 32.42 -0.62 2425.00 18.50 18.56 -0.06 - 31.64 31.25 0.38 2450.00 19.46 19.24 0.21 29.76 29.40 0.36 2475.00 19.88 19.68 0.20 27.83 28.53 -0.69 2500.00 20.28 20.44 -0.15 27.36 27.04 0.32 2525.00 21.26 21.08 0.18 26.41 26.13 0.28 2550.00 21.93 21.70 0.23 25.63 25.77 -0.13 2575.00 22.43 22.35 0.07 25.33 25.23 0.10 2600.00 23.25 23.19 0.07 24.57 24.43 0.14 2625.00 24.07 23.91 0.16 23.87 23.93 -0.06 2650.00 24.50 24.34 0.16 23.89 23.89 0.00 2675.00 25.13 24.94 0.18 23.91 23.98 -0.07 2700.00 25.71 25.70 0.02 24.11 24.27 -0.16 2725.00 26.41 26.24 0.17 24.50 24.55 -0.05 SURV-Q167 (OPS S UR-MA-003) 19~" Nov 03 /Rev 15 Page 2 of 13 AK0306G 115 Survey QC - RGS-CT ~cification Sheet • 2750.00 27.11 27.01 0.10 24.76 24.86 -0.10 2775.00 27.76 27.65 0.11 25.01 25.14 -0.12 2800.00 28.65 28.47 0.18 25.28 25.37 -0.09 2825.00 29.24 29.20 0.04 25.34 25.28 0.06 2850.00 29.94 29.76 0.18 25.39 25.28 0.12 2875.00 30.57 30.45 0.12 25.25 25.22 0.03 2900.00 31.14 31.06 0.09 25.24 25.31 -0.07 2925.00 31.83 31.62 0.21 25.28 25.38 -0.09 2950.00 32.27 32.26 0.01 25.47 25.65 -0.18 2975.00 33.02 32.93 0.09 25.89 26.00 -0.10 3000.00 33.87 33.83 0.04 26.27 26.36 -0.09 3025.00 34.53 34.51 0.02 26.51 26.58 -0.07 3050.00 35.44 35.38 0.07 26.74 26.83 -0.09 3075.00 36.22 36.32 -0.10 26.82 26.88 -0.06 3100.00 37.18 37.14 0.05 26.87 26.93 -0.06 3125.00 38.06 37.99 0.07 26.77 26.86 -0.09 3150.00 38.53 38.52 0.01 26.70 26.79 -0.09 3175.00 39.25 39.10 0.15 26.59 26.72 -0.13 3200.00 39.60 39.53 0.07 26.57 26.61 -0.05 3225.00 40.02 39.92 0.10 26.54 26.63 -0.09 3250.00 40.73 40.67 0.07 26.60 26.71 -0.11 3275.00 41.35 41.35 -0.00 26.65 26.76 -0.11 3300.00 42.07 41.98 0.09 26.67 26.78 -0.10 3325.00 42.67 42.77 -0.10 26.76 26.93 -0.17 3350.00 43.48 43.51 -0.03 26.91 27.10 -0.19 3375.00 44.54 44.59 -0.05 27.16 27.32 -0.16 3400.00 45.24 45.28 -0.05 27.28 27.43 -0.15 3425.00 46.01 45.91 0.10 27.25 27.38 -0.14 3450.00 46.60 46.74 -0.13 27.13 27.17 -0.04 3475.00 47.18 47.10 0.08 27.03 27.20 -0.17 3500.00 47.44 47.33 0.11 27.03 27.24 -0.21 3525.00 47.57 47.42 0.15 27.19 27.41 -0.22 3550.00 47.57 47.44 0.13 27.49 27.71 _ -0.22 3575.00 47.61 47.48 0.13 27.68 28.00 -0.31 3600.00 47.71 47.62 0.09 27.91 28.17 -0.25 3625.00 47.66 47.62 0.04 28.28 28.49 -0.21 3650.00 47.84 47.74 0.10 28.49 28.79 -0.30 3675.00 47.93 47.90 0.03 28.83 29.03 -0.20 3700.00 47.97 47.84 0.12 28.95 29.30 -0.35 3725.00 48.03 47.92 0.10 29.16 29.34 -0.18 3750.00 47.98 47.91 0.07 29.45 29.72 -0.27 3775.00 48.14 48.03 0.11 29.56 29.85 -0.29 3800.00 48.12 48.06 0.06 29.85 30.07 -0.23 3825.00 48.14 48.03 0.11 30.05 30.30 -0.24 3850.00 48.27 48.22 0.05 30.18 30.41 -0.23 SURV-Qi67 (OPS SUR-MA-003) 19~" N ov 03 /Rev 15 Page 3 of 13 AK0308G 115 Survey QC - RGS-CT cification Sheet .r.. 3875.00 48.31 48.24 0.06 30.40 30.62 -0.22 3900.00 48.42 48.32 0.11 30.49 30.79 -0.30 3925.00 48.37 48.35 0.02 30.80 31.01 -0.21 3950.00 48.33 48.21 0.12 30.79 31.05 -0.26 3975.00 48.31 48.17 0.14 30.83 30.96 -0.12 4000.00 47.37 47.17 0.20 30.38 30.45 -0.07 4025.00 47.04 46.83 0.21 30.14 30.19 -0.05 4050.00 46.84 46.79 0.05 29.82 30.00 -0.18 4075.00 46.68 46.47 0.21 29.44 29.43 0.01 4100.00 46.40 46.22 0.18 28.79 28.75 0.03 4125.00 45.78 45.70 0.07 27.67 27.69 -0.02 4150.00 45.75 45.54 0.21 27.30 27.43 -0.13 4175.00 45.48 45.50 -0.02 27.09 27.32 -0.23 4200.00 45.35 45.26 0.09 27.24 27.54 -0.30 4225.00 45.46 45.43 0.04 27.37 27.59 -0.22 4250.00 45.34 45.36 -0.02 27.51 27.72 -0.22 .4275.00 45.52 45.38 0.14 27.55 27.80 -0.25 4300.00 45.47 45.49 -0.02 27.66 27.83 -C.17 4325.00 45.54 45.48 0.06 27.69 27.88 -0.19 4350.00 45.67 45.56 0.11 27.58 27.69 -0.11 4375.00 45.29 45.16 0.13 26.84 26.81 0.03 4400.00 44.87 44.65 0.22 26.03 25.93 0.10 4425.00 44.52 44.54 -0.02 25.18 25.34 -0.17 4450.00 44.37 44.23 0.13 25.09 25.25 -0.16 4475.00 44.35 44.34 0.01 24.98 25.24 -0.26 4500.00 44.11 44.14 -0.04 24.86 25.07 -0.21 4525.00 44.29 44.37 -0.08 24.84 25.04 -0.21 4550.00 44.92 44.82 0.10 24.54 24.61 -0.07 4575.00 45.09 45.50 -0.41 24.29 24.31 -0.02 4600.00 46.07 46.14 -0.07 24.29 23.97 0.31 4625.00 46.57 46.58 -0.00 24.21 24.00 0.21 4650.00 46.92 46.99 -0.07 24.12 23.93 0.19 4675.00 47.30 47.31 -0.00 24.17 23.92 0.24 4700.00 47.59 47.60 -0.01 24.17 23.95 0.21 4725.00 47.54 47.33 0.20 24.20 24.05 0.15 4750.00 47.48 47.43 0.04 24.26 24.11 0.15 4775.00 47.26 47.20 0.05 24.46 24.34 0.12 4800.00 47.41 47.24 0.18 24.55 24.40 0.15 4825.00 47.24 47.26 -0.02 24.70 24.49 0.21 4850.00 47.14 46.96 0.17 24.69 24.51 0.18 4875.00 47.14 47.11 0.02 24.70 24.54 0.16 4900.00 46.95 46.92 0.03 24.77 24.64 0.13 4925.00 47.04 46.76 0.27 24.85 24.77 0.08 4950.00 46.77 46.79 -0.01 24.89 24.84 0.05 4975.00 46.54 46.45 0.09 25.03 24.91 0.13 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 4 of 13 AK0308G 115 Survey QC - RGS-CT~ecification Sheet 5000.00 46.55 46.54 0.02 25.18 25.11 0.07 5025.00 46.60 46.62 -0.02 25.61 25.38 0.22 5050.00 46.92 46.89 0.02 25.76 25.68 0.08 5075.00 47.10 47.20 -0.09 25.96 25.82 0.14 5100.00 47.20 47.18 0.02 26.13 26.02 0.10 5125.00 47.45 47.37 0.08 26.22 26.09 0.13 5150.00 47.31 47.32 -0.01 26.23 26.11 0.11 5175.00 47.53 47.43 0.09 26.32 26.18 0.14 5200.00 47.62 47.64 -0.02 26.44 26.32 0.11 5225.00 47.46 47.39 0.07 26.56 26.43 0.13 5250.00 47.65 47.65 0.00 26.58 26.39 0.19 5275.00 47.78 47.82 -0.04 26.53 26.38 0.15 5300.00 47.87 47.67 0.20 26.61 26.49 0.12 5325.00 47.75 47.79 -0.04 26.62 26.50 0.12 5350.00 47.63 47.59 0.04 26.67 26.55 0.12 5375.00 47.79 47.69 0.10 26.73 26.60 0.13 5400.00 47.52 47.57 -0.05 26.73 26.58 0.16 5425.00 .47.62 47.44 0.18 26.71 26.53 0.18 5450.00 47.58 47.58 -0.00 26.77 26.55 0.22 5475.00 47.40 47.35 0.05 26.78 26.66 0.12 5500.00 47.46 47.40 0.05 26.88 26.73 0.15 5525.00 47.42 47.49 -0.07 26.66 26.55 0.11 5550.00 47.64 47.57 0.08 26.72 26.60 0.12 5575.00 47.75 47.76 -0.01 26.77 26.63 0.14 5600.00 47.62 47.59 0.03 26.64 26.50 0.14 5625.00 47.87 47.85 0.02 26.57 26.39 0.18 5650.00 47.83 47.92 -0.09 26.47 26.31 0.16 5675.00 47.95 47.76 0.20 26.50 26.30 0.20 5700.00 47.89 47.93 -0.03 26.45 26.29 0.16 5725.00 47.75 47.75 0.00 26.22 26.03 0.19 5750.00 47.93 47.77 0.17 26.19 26.05 0.14 5775.00 47.70 47.73 -0.04 26.20 25.98 0.22 5800.00 47.75 47.58 0.17 26.07 25.88 0.19 5825.00 47.70 47.65 0.04 25.84 25.71 0.13 5850.00 47.50 47.53 -0.03 25.94 25.80 0.14 5875.00 47.78 47.81 -0.03 26.33 26.33 -0.00 5900.00 48.16 48.27 -0.10 26.73 26.70 0.02 5925.00 48.29 48.29 -0.00 27.01 26.95 0..06 5950.00 48.59 48.58 0.01 27.35 27.31 0.04 5975.00 48.51 48.58 -0.07 27.93 27.92 0.01 6000.00 48.70 48.63 0.07 28.18 28.07 0.11 6025.00 48.61 48.60 0.01 28.31 28.17 0.13 6050.00 48.49 48.43 0.07 28.27 28.10 0.17 6075.00 48.55 48.45 0.10 28.23 28.06 0.16 6100.00 48.38 48.34 0.05 28.06 27.87 0.19 SURV-Q 167 (OPS SU R-MA-003) 19`" Nov 03 /Rev 1S Page 5 of 13 AK0308G 115 Survey QC - RGS-CT.ecification Sheet b115.UO 48.41 48.24 0.17 28.12 27.88 0.24 6150.00 48.22 48.15 0.07 27.95 27.79 0.15 6175.00 48.05 47.94 0.12 27.95 27.75 0.20 6200.00 48.19 48.13 0.06 27.82 27.64 0.18 6225.00 48.00 47.95 0.05 27.78 27.61 0.17 6250.00 47.81 47.80 0.01 27.59 27.38 0.21 6275.00 47.90 47.91 -0.01 27.49 27.27 0.22 6300.00 47.97 47.99 -0.02 27.38 27.24 0.15 6325.00 48.15 48.10 0.05 27.27 27.12 0.15 6350.00 47.95 48.01 -0.05 27.14 27.07 0.07 6375.00 48.26 48.11 0.15 27.79 28.25 -0.46 6400.00 47.93 47.91 0.03 29.58 29.60 -0.02 6425.00 48.00 47.93 0.06 29.90 29.74 0.15 6450.00 48.22 48.24 -0.02 29.79 29.67 0.13 6475.00 48.05 48.07 -0.01 29.65 29.48 0.17 6500.00 47.86 47.53 0.33 30.06 30.35 -0.29 6525.00 47.23 47.20 0.02 31.40 31.51 -0.11 6550.00 47.49 47.54 -0.06 31.87 31.83 0.04 6575.00 47.62 47.64 -0.01 32.24 32.15 0.09 6600.00 47.80 47.79 0.01 32.49 32.48 0.01 6625.00 47.96 47.84 0.13 32.97 33.01 -0.04 6650.00 47.93 47.97 -0.04 33.73 33.64 0.09 6675.00 48.01 47.96 0.05 33.85 33.69 0.16 6700.00 48.26 48.23 0.03 33.84 33.71 0.14 6725.00 48.27 48.18 0.09 34.01 33.91 0.11 6750.00 48.26 48.10 0.16 34.27 34.21 0.06 6775.00 48.19 48.14 0.05 34.69 34.58 0.11 6800.00 48.10 48.15 -0.05 34.80 34.69 0.12 6825.00 47.98 47.90 0.08 34.76 34.71 0.05 6850.00 48.11 48.11 0.01 34.90 34.80 0.10 6875.00 48.02 48.09 -0.08 35.09 34.98 0.11 6900.00 48.35 48.26 0.09 35.23 35.25 -0.01 6925.00 48.27 48.25 0.02 35.47 35-.32 0.15 6950.00 48.38 48.29 0.09 35.28 34.98 0.31 6975.00 48.10 47.96 0.14 34.38 33.98 0.41 7000.00 47.75 47.71 0.04 33.57 33.35 0.22 7025.00 47.87 47.74 0.13 33.50 33.48 0.02 7050.00 47.67 47.74 -0.08 33.77 33.71 0.06 7075.00 47.95 47.86 0.09 33.99 33.99 0.00 7100.00 48.31 48.36 -0.05 34.27 34.13 0.14 7125.00 48.37 48.32 0.05 33.96 33.69 0.26 7150.00 48.52 48.48 0.04 33.59 33.44 0.15 7175.00 48.48 48.47 0.01 33.58 33.48 0.10 7200.00 48.52 48.36 0.16 33.77 33.80 -0.03 7225.00 48.35 48.30 0.05 34.18 34.17 0.01 SURV-Q767 (OPS SUR-MA-003) 19`" Nav 03 /Rev 15 Page 6 of 13 AK0308G 115 Survey QC - RGS-CT~cification Sheet /t5U.U0 48.27 48.21 0.06 34.30 34.18 0 12 7275.00 48.39 48.37 0.01 34.29 34.18 . 0.10 7300.00 48.19 48.13 0.06 34.18 33.87 0.31 7325.00 47.70 47.44 0.25 33.23 32.90 0.34 7350.00 47.36 47.37 -0.01 32.42 32.28 0.14 7375.00 47.41 47.32 0.09 32.35 32.23 0.12 7400.00 47.09 46.86 0.23 32.72 32.71 0.01 7425.00 46.73 46.84 -0.10 33.00 32.91 0.09 7450.00 46.86 46.69 0.17 33.10 33.04 0.06 7475.00 46.54 46.46 0.08 33.45 33.49 -0.03 7500.00 46.47 46.43 0.04 33.65 33.50 0.14 7525.00 46.67 46.62 0.05 33.46 33.38 0.09 7550.00 46.57 46.53 0.03 33.69 33.65 0.04 7575.00 46.72 46.67 0.05 33.87 33.73 0.13 7600.00 47.00 47.04 -0.04 34.01 33.96 0.05 7625.00 47.27 47.25 0.02 34.43 34.37 0.06 7650.00 47.49 47.49 0.00 34.68 34.63 0.05 7675.00 47.71 47.63 0.08 34.97 34.97 -0.01 7700.00 47.46 47.40 0.06 35.44 35.32 0.11 7725.00 47.49 47.47 0.01 35.27 35.18 0.09 7750.00 47.49 47.41 0.08 35.30 35.17 0.13 7775.00 47.22 47.04 0.18 35.02 34.68 0.33 7800.00 46.59 46.60 -0.01 33.92 33.75 0.17 7825.00 46.68 46.43 0.26 33.60 33.54 0.07 7850.00 46.43 46.51 -0.07 33.69 33.67 0.02 7875.00 46.57 46.51 0.06 33.87 33.87 -0.00 7900.00 46.54 46.50 0.04 33.92 33.85 0.07 7925.00 46.60 46.59 0.01 34.14 34.08 0.06 7950.00 46.71 46.62 0.09 34.21 33.99 0.21 7975.00 46.70 46.65 0.05 33.54 33.15 0.39 8000.00 46.73 46.72 0.01 32.87 32.66 0.21 8025.00 46.98 47.02 -0.04 32.64 32.54 0.10 8050.00 46.89 - 46.89 0.01 32.45 32.37 0.08 8075.00 47.10 47.07 0.02 32.58 32.54 0.03 8100.00 47.28 47.32 -0.04 32.89 32.85 0.04 8125.00 47.45 47.37 0.08 32.95 32.88 0.07 8150.00 47.43 47.37 0.07 33.11 33.07 0.05 8175.00 47.48 47.42 0.05 33.31 33.25 0.06 8200.00 47.51 47.47 0.04 33.51 33.45 0.06 8225.00 47.15 47.07 0.08 33.15 33.12 0.02 8250.00 46.82 46.76 0.05 33.27 33.19 0.07 8275.00 47.05 46.99 0.06 33.17 33.11 0.06 8300.00 46.86 46.88 -0.02 33.06 33.00 0.07 8325.00 46.69 46.63 0.06 32.91 32.90 0.01 8350.00 46.70 46.66 0.04 32.79 32.75 0.04 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 7 of 13 AK0308G 115 Survey QC - RGS-CT~cification Sheet 8375.00 46.22 46.42 -0.20 32.51 32.59 -0.08 8400.00 46.10 46.01 0.09 32.44 32.39 0.05 8425.00 46.30 46.19 0.11 32.37 32.31 0.06 8450.00 46.16 46.14 0.01 32.29 32.18 0.11 8475.00 45.72 45.84 -0.12 32.15 32.07 0.08 8500.00 45.69 45.67 0.03 32.02 31.97 0.04 8525.00 46.65 46.04 0.62 31.16 31.58 -0.42 8550.00 47.00 46.75 0.25 30.15 30.63 -0.47 8575.00 48.72 47.99 0.74 27.97 28.60 -0.64 8600.00 50.64 50.02 0.61 26.73 26.89 -0.16 8625.00 53.33 52.70 0.63 25.51 25.56 -0.04 8650.00 54.97 54.53 0.44 25.15 25.14 0.01 8675.00 56.39 55.79 0.60 24.82 24.86 -0.04 8700.00 57.61 57.39 0.22 24.80 24.72 0.08 8725.00 58.83 58.53 0.30 25.55 25.42 0.13 8750.00 60.11 59.85 0.27 25.83 25.71 0.12 8775.00 60.92 60.60 0.32 26.05 25.95 0.10 8800.00 61,78 61.43 0.35 27.21 26.65 0.56 8825.00 62.26 62.09 0.17 28.23 28.09 0.15 8850.00 62.57 62.47 0.10 28.71 28.55 0.15 8875.00 62.66 62.65 0.02 29.20 29.14 0.06 8900.00 62.30 62.37 -0.07 29.27 29.30 -0.02 8925.00 62.58 62.49 0.09 29.23 29.26 -0.03 8950.00 62.64 62.61 0.03 29.18 29.19 -0.01 8975.00 62.44 62.53 -0.09 29.12 29.17 -0.04 9000.00 62.50 62.43 0.06 29.04 29.05 -0.02 9025.00 61.95 62.09 -0.13 28.81 28.94 -0.13 9050.00 62.21 62.09 0.12 28.80 28.79 0.01 9075.00 62.44 62.34 0.10 28.63 28.65 -0.02 9100.00 62.81 62.71 0.10 28.35 28.48 -0.13 9125.00 62.90 62.97 -0.07 28.09 28.17 -0.08 9150.00 62.78 62.71 0.08 27.84 27.84 0.00 9175.00 62.99 62.94 0.05 27.28 27.51 -0.23 9200.00 63.00 62.96 0.04 26.02 26.29 -0.27 9225.00 62.93 62.94 -0.00 25.08 25.29 -0.21 9250.00 63.10 63.01 0.09 24.49 24.71 -0.22 9275.00 63.17 63.09 0.08 23.35 23.84 -0.49 9300.00 63.29 63.24 0.05 21.72 21.96 -0.24 9325.00 63.37 63.31 0.06 21.27 21.37 -0.10 9350.00 63.23 63.18 0.05 20.94 21.01 -0.07 9375.00 63.18 63.24 -0.06 19.84 20.31 -0.47 9400.00 62.96 62.92 0.04 18.29 18.46 -0.17 9425.00 62.91 62.91 -0.01 17.82 17.96 -0.14 9450.00 63.10 63.07 0.03 17.40 17.53 -0.13 9475.00 63.34 63.26 0.08 16.03 16.32 -0.28 SURV-Q767 (OPS SU R-MA-003) 19`" Nov 03 /Rev 15 Page 8 of 13 AK0308G 115 Survey QC - RGS-CT•ecification Sheet ®..®. 9500.00 63.11 63.22 -0.11 14.45 14.80 -0.35 9525.00 63.21 63.18 0.03 13.90 14.07 -0.17 9550.00 63.28 63.27 0.01 12.93 13.32 -0.40 9575.00 63.21 63.20 0.01 11.15 11.36 -0.21 9600.00 63.08 63.01 0.07 10.03 10.19 -0.16 9625.00 63.00 63.02 -0.01 9.52 9.65 -0.14 9650.00 63.05 63.12 -0.07 8.78 9.10 -0.32 9675.00 62.52 62.47 0.05 6.75 6.97 -0.22 9700.00 62.76 62.72 0.04 6.32 6.41 -0.09 9725.00 62.66 62.72 -0.06 6.01 6.06 -0.05 9750.00 62.88 62.83 0.06 5.91 5.98 -0.07 9775.00 62.72 62.80 -0.07 5.51 5.67 -0.16 9800.00 62.57 62.58 -0.01 5.40 5.47 -0.07 9825.00 62.56 62.60 -0.04 4.89 5.15 -0.27 9850.00 62.09 62.16 -0.06 3.65 3.83 -0.19 9875.00 61.99 62.03 -0.04 3.62 3.69 -0.06 9900.00 62.12 62.09 0.03 3.63 3.71 -0.08 9925.00 62.12 62.13 -0.01 3.55 3.68 -0.12 9950.00 62.00 61.96 0.04 3.36 3.44 -0.08 9975.00 62.25 62.15 0.10 3.28 3.35 -0.07 10000.00 62.85 62.68 0.17 3.02 3.18 -0.15 10025.00 63.59 63.46 0.13 2.72 2.81 -0.08 10050.00 63.90 63.85 0.05 2.62 2.67 -0.05 10075.00 64.01 63.96 0.05 2.45 2.54 -0.08 10100.00 64.13 64.08 0.05 2.42 2.53 -0.11 10125.00 64.16 64.10 0.06 2.30 2.42 -0.11 10150.00 64.00 64.01 -0.01 2.18 2.29 -0.11 10175.00 64.07 64.02 0.06 2.03 2.13 -0.10 10200.00 63.88 63.90 -0.02 1.87 1.99 -0.12 10225.00 63.72. 63.69 0.03 1.76 1.83 -0.07 10250.00 63.68 63.64 0.04 1.75 1.81 -0.06 10275.00 63.80 63.75 0.06 1.71 1.83 -0.12 - 10300.00 63.73 63.70 0.03 1.76 - 1.83 -0.07 10325.00 63.50 63.49 0.01 1.69 1.79 -0.11 10350.00 63.65 63.59 0.06 1.53 1.64 -0.11 10375.00 63.94 63.86 0.08 1.42 1.52 -0.09 10400.00 64.37 64.27 0.10 1.22 1.30 -0.08 10425.00 64.49 64.48 0.01 1.10 1.20 -0.10 10450.00 63.97 63.94 0.03 0.88 1.00 -0.12 10475.00 64.01 63.97 0.04 0.71 0.82 -0.11 10500.00 64.16 64.12 0.04 0.55 0.69 -0.14 10525.00 64.19 64.16 0.03 0.48 0.61 -0.14 10550.00 64.14 64.10 0.04 0.34 0.47 -0.13 10575.00 63.76 63.73 0.03 0.20 0.31 -0.11 10600.00 63.83 63.77 0.06 0.12 0.20 -0.08 SURV-Q 167 (OPS SU R-MA-003) 19`" Nov 03 /Rev 15 Page 9 of 13 AK0308G 115 Survey QC - RGS-CT•ecification Sheet ~..~. 1UbL5.UU 63.68 63.62 0.07 0.25 0.29 -0 04 10650.00 63.97 63.80 0.16 0.55 0.57 . -0.02 10675.00 64.53 64.36 0.17 0.97 0.97 -0.01 10700.00 64.80 64.70 0.10 1.33 1.43 -0.10 10725.00 64.83 64.70 0.13 1.53 1,60 -0.06 10750.00 65.03 64.91 0.12 1.78 1.81 -0.03 10775.00 65.33 65.24 0.09 2.25 2.29 -0.04 10800.00 65.28 65.20 0.08 2.66 2.72 -0.06 10825.00 65.14 65.09 0.05 2.69 2.79 -0.11 10850.00 65.11 65.04 0.07 2.70 2.78 -0.09 10875.00 65.02 64.94 0.08 2.65 2.75 -0.10 10900.00 64.96 64.89 0.07 2.67 2.75 -0.09 10925.00 64.8$ 64.80 0.07 3.03 3.06 -0.03 10950.00 64.88 64.82 0.06 3.81 3.80 0.01 10975.00 64.86 64.83 0.03 4.44 4.46 -0.02 11000.00 64.91 64.84 0.07 4.63 4.72 -0.09 11025.00 64.81 64.77 0.04 4.59 4.71 -0.11 11050.00 64.66 64.64 0.02 4.44 4.57 -0.13 11075.00 64.42 64.37 0.05 4.31 4.45 -0.14 11100.00 64.35 64.31 0.03 4.16 4.30 -0.15 11125.00 64.31 64.27 0.05 4.13 4.27 -0.14 11150.00 64.20 64.13 0.07 4.12 4.26 -0.14 11175.00 64.10 64.11 -0.01 4.12 4.24 -0.12 11200.00 63.97 63.93 0.03 4.11 4.23 -0.12 11225.00 63.97 63.93 0.05 4.19 4.29 -0.11 11250.00 63.87 63.81 0.06 4.12 4.22 -0.10 11275.00 63.80 63.73 0.06 4.17 4.28 -0.10 11300.00 63.44 63.43 0.01 4.29 4.39 -0.10 11325.00 63.42 63.36 0.05 4.24 4.36 -0.12 11350.00 63.19 63.17 0.02 4.22 4.35 -0.13 11375.00 62.91 62.88 0.03 4.18 4.33 -0.15 11400.00 62.86 62.88 -0.02 4.24 4.37 -0.13 11425.00 62.68 62.65 0.04 4.22 4.34 -0.12 11450.00 62.61 62.58 0.02 4.28 4.41 -0.13 11475.00 62.59 62.55 0.04 4.34 4.49 -0.15 11500.00 62.38 62.31 0.06 4.21 4.34 -0.13 11525.00 62.75 62.70 0.05 4.17 4.27 -0.10 11550.00 62.52 62.47 0.05 4.11 4.26 -0.16 11575.00 62.52 62.47 0.05 3.94 4.06 -0.12 11600.00 62.88 62.80 0.08 3.90 4.04 -0.14 11625.00 63.54 63.46 0.07 3.84 3.99 -0.15 11650.00 64.04 63.95 0.09 3.87 3.99 -0.12 11675.00 63.86 63.78 0.08 3.76 3.90 -0.13 11700.00 64.08 64.02 0.06 3.75 3.87 -0.13 11725.00 64.36 64.31 0.05 3.83 3.95 -0.12 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 10 of 13 AK030SG_315 Survey QC - RGS-CT~cification Sheet ~.o.®.®~ tli5u.w 64.24 64.21 0.03 3.83 3.96 -0.14 11775.00 64.29 64.26 0.03 3.85 3.98 -0.13 11$00.00 63.92 63.88 0.04 3.78 3.92 -0.14 11825.00 63.95 63.92 0.03 3.70 3.86 -0.16 11850.00 63.71 63.68 0.03 3.52 3.68 -0.16 11875.00 63.72 63.70 0.01 3.44 3.58 -0.14 11900.00 63.58 63.55 0.03 3.41 3.53 -0.12 11925.00 63.33 63.31 0.02 3.46 3.61 -0.15 11950.00 63.28 63.23 0.05 3.44 3.56 -0.12 11975.00 63.49 63.44 0.05 3.44 3.56 -0.13 12000.00 64.24 64.19 0.05 3.46 3.62 -0.16 12025.00 64.68 64.67 0.02 3.54 3.70 -0.15 12050.00 64.36 64.32 0.04 3.63 3.75 -0.12 12075.00 64.69 64.65 0.04 4.00 4.13 -0.14 12100.00 65.34 65.33 0.01 4.63 4.80 -0.17 12125.00 65.50 65.50 -0.00 4.97 5.15 -0.17 12150.00 65.24 65.22 0.01 4.93 5.06 -0.13 12175.00 65.25 65.23 0.02 4.86 5.01 -0.15 12200.00 65.09 65.04 0.05 4.73 4.87 -0.14 12225.00 64.98 64.94 0.04 4.76 4.92 -0.16 12250.00 64.75 64.73 0.03 4.74 4.90 -0.16 12275.00 64.54 64.52 0.02 4.78 4.94 -0.17 12300.00 64.53 64.49 0.05 4.75 4.86 -0.11 12325.00 64.08 64.03 0.05 4.73 4.85 -0.12 12350.00 64.05 64.04 0.01 4.69 4.85 -0.17 12375.00 63.94 63.91 0.03 4.63 4.76 -0.13 12400.00 64.02 63.98 0.04 4.56 4.66 -0.10 12425.00 63.76 63.73 0.02 4.56 4.70 -0.15 12450.00 63.77 63.74 0.03 4.52 4.65 -0.13 12475.00 63.73 63.69 0.04 4.49 4.59 -0.10 12500.00 63.40 63.35 0.05 4.36 4.49 -0.13 12525.00 63.23 63.21 0.02 4.26 4.41 -0.15 12550.00 63.17 63.15 0.02 4.21 4.33 -0.13 12575.00 63.06 63.04 0.02 4.17 4.32 -0.15 12600.00 63.06 63.03 0.03 4.15 4.27 -0.13 12625.00 62.57 62.54 0.03 4.25 4.43 -0.18 12650.00 61.18 61.13 0.05 4.77 4.98 -0.20 12675.00 58.90 58.87 0.03 5.32 5.55 -0.22 12700.00 56.49 56.50 -0.01 6.08 6.28 -0.21 12725.00 54.64 54.66 -0.02 6.59 6.77 -0.18 12750.00 52.30 52.32 -0.02 7.33 7.45 -0.13 12775.00 49.26 49.34 -0.09 8.09 8.25 -0.16 12800.00 46.73 46.79 -0.05 8.54 8.66 -0.12 12825.00 44.77 44.82 -0.06 9.09 9.21 -0.12 12850.00 42.67 42.75 -0.08 9.46 9.58 -0.12 SURV-Q367 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 11 of 13 AK0308G 115 Survey QC - RGS-CT•ecification Sheet • 1LZ5/J.UU 4U.l.i 40.16 -0.03 9.74 9.83 -0 08 12900.00 37.80 37.82 -0.01 10.19 10.29 . -0.10 12925.00 35.43 35.45 -0.02 9.70 9.79 -0 09 12950.00 33.01 33.00 0.01 8.79 8.83 . -0 04 12975.00 30.78 30.78 0.00 6.88 6.99 . -0 10 13000.00 28.82 28.80 0.03 5.46 5.49 . -0 03 13025.00 26.78 26.74 0.04 4.99 5.12 . -0.13 13050.00 23.47 23.43 0.04 4.94 5.09 -0.15 13075.00 20.18 20.10 0.07 4.60 4.68 -0 07 13100.00 18.70 18.61 0.09 4.25 4.21 . 0.04 13125.00 17.19 17.14 0.05 5.69 6.07 -0 37 13150.00 15.32 15.23 0.09 9.31 8.91 . 0.40 13175.00 14.32 14.36 -0.03 11.34 11.89 -0.54 13200.00 13.71 13.63 0.08 11.52 11.20 0.32 13225.00 13.44 13.76 -0.32 11.59 11.36 0.23 13250.00 13.08 13.17 -0.09 11.25 12.34 -1.08 13275.00 12.48 12.80 -0.32 12.27 11.38 0.89 13300.00 12.63 12.96 -0.33 12.17 11.51 0.66 13325.00 12.59 12.28 0.31 12.13 12.26 -0.14 13350.00 12.54 11.91 0.63 12.10 10.70 1.40 13375.00 12.50 11.72 0.78 12.08 11.74 0.34 13400.00 12.46 10.95 1.50 12.05 11.13 0.92 13425.00 12.41 11.02 1.39 12.03 9.95 2.08 13450.00 12.37 10.81 1.56 12.01 12.35 -0.34 13475.00 12.33 11.17 1.16 11.98 11.06 0.92 13500.00 12.28 12.17 0.12 11.96 11.58 0.38 13525.00 12.24 11.99 0.25 11.93 11.96 -0.02 13550.00 12.20 12.25 -0.05 11.91 12.16 -0.25 13575.00 12.15 11.89 0.26 11.88 13.69 -1.81 13600.00 12.11 12.35 -0.24 11.86 13.21 -1.35 13625.00 11.71 11.72 -0.01 12.04 14.04 -2.00 13650.00 11.31 11.47 -0.15 12.23 14.64 -2.41 13675.00 10.91 10.66 0.26 12.41- 14.04 -1.63 13700.00 10.52 10.42 0.09 12.60 15.38 -2.78 13725.00 11.17 10.46 0.71 14.03 15.37 -1.34 13750.00 11.84 9.83 2.00 15.47 14.05 1.42 13775.00 12.50 10.48 2.02 16.91 14.78 2.13 13800.00 13.16 12.43 0.73 18.35 14.95 3.40 13825.00 13.28 13.42 -0.14 17.04 15.01 2.03 13850.00 13.40 13.81 -0.41 15.71 16.19 -0.48 13875.00 13.51 13.72 -0.21 14.37 16.52 -2.15 13900.00 13.63 13.50 0.13 13.04 15.99 -2.95 13925.00 13.62 13.43 0.19 13.24 14.93 -1.69 13950.00 13.61 13.23 0.38 13.45 14.06 -0.61 13975.00 13.60 13.28 0.32 13.66 13.73 -0.07 SURV-Q167 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 12 of 13 AK0308G 115 Survey QC - RGS-CT~ecification Sheet • ~ 14000.00 13.59 13.34 0.24 13.87 13.65 0.22 14025.00 13.36 13.35 0.01 12.62 13.95 -1.33 14050.00 13.12 13.31 -0.19 11.36 13.40 -2.04 14075.00 12.88 12.79 0.09 10.10 10.28 -0.18 14100.00 12.65 12.54 0.10 8.84 11.93 -3.09 14125.00 12.24 12.29 -0.05 9.77 11.40 -1.63 14150.00 11.83 12.10 -0.27 10.73 10.10 0.63 14168.19 11.66 11.66 0.00 9.12 9.12 0.00 Average 0.0746 -0.0350 Standard Deviation 0.2191 0.1700 Tolerance for both the Average and the Standard Casing 0.3° Casing 0.5° Deviation -k T...-i:..,t:.... ,...J n Drill i e 0.3° Drill i e 0.75° - __. ____ .._....__.. ...-... '..,......... ~., .,........ ~....N ono uo ~nvvv n. SURV-Q767 (OPS SUR-MA-003) 19`" Nov 03 /Rev 15 Page 13 of 13 AK0308G 115 Survey QC - RGS-CT~alysis Sheet • ~I..v..®.L~.....~.~.~ SURVEY QUALITY CONTROL -DATA ANALYSIS REFFRFN!'F CVCTCMc Grid S stem Grid Correction 0.00 Azimuth reference: Grid /True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB 48.3ftAMSL If other ive details TIE ON DATA De th Northin s 0.00 0.00 Inclination Eastin s 0.00 0.00 Azimuth Latitude 0.00 TVD 0.00 70.3476 Az. Ref: Grid/True Grid Corrected Y/N? Descri tion CALIBRATION ~ Tool Number ~ 6007 Calibration Date 31 Jul 2007 OPERATING TEMPERATURE Calibration ran e From 47.31 To 120.39 G ro o eratin ran e From 70.52 To 96.75. Spec' -Within calibration range FIEL6 ROI [ TFCT lhnl~. ~1~~ ., f~.,,,.~ .-f~ r~_ Cal value --- -- --- Pre ob offset -~--~ --••~-•• ••~. Post ob offset .....+~.. •., r~~ u~ rvrr Abs dif.cal. ost ~c.~~ uuw CrIVIIIiCU Abs dif. re. ost OI ICI ICLUiII LU UasC Sec' Accel Scale 0.000000 0.000000 N A Cal/Post - 0.00015 Mass Unbalance 0.00 0.00 N/A Pre/Post - 0.4°/hr INITTAITCATTAN De th A rox 2200.66 No of stns 6 Sec' -Min No. - 6 Azimuth Mean 38.93 Std deviation 0.14 Sec' - Azi SD 0 2° Inclination Mean 13.29 Std deviation 0.00 . Sec' -Inc SD 0.1° Earth Horizontal Rate Mean Abs meas-theor 0.02 Std deviation 0.01 Sec' -See 167 DRIFT TUNE Residual x ro bias Mean -0.000 Std dev' 0.001 Sec's -Mean and SD - 0.333~/hr Residual ro bias Mean 0.000 Std dev' 0.001 Spec's -Mean and SD - 0.333°/hr TOOLFACE RATE Maximum too{face rate 8.15 Sec' - 400°/sec IN/OUT COMPARTCnN /A77' Wile Tc rn~r~ ~~co~ Inclination Difference Mean 0.07 - Std dev' 0.22 Sec`s -Casin 0,3°/Drill i e 0.3° Azimuth Difference Mean -0.03 Std dev' 0.17 Sec's -Casin 0.5° Drill i e 0.75° Lateral Diver ence/1000 0.46 Sec - 5.0/1000 Vertical Diver ence/1000 0.64 Sec' - 2.0/1000 DEPTH CONTROI Wireline Com an Schlumber er Line e 13/32 Encoder SF Schlumber er Max De th TD 14155 CCL Corrected No Zero De th Ri u Base Flan e +27ft Rezero De th -7 Given u "oint de th Na Measured PJ Na Strech cor. At TD divided b TD/1000 .76 Sec' - 1.5/1000 Dif. Between ri u and rezero de the divided b TD/1000 .64 Sec' - 2.0/1000 Dif. Between iven and meas de th divided b meas/1000 na Sec' - 2.0/1000 SURV-Q 165 (OPS SUR-MA-010) 22n° Jan 2004 /Revision 20 Page 1 of 1 AK030SG 115 e Survey QC - RGS-C~ceptance Sheet ~~ FIELD AND SURVEY INFC~RMarrnni Operator BP ALASKA Field /Platform SCHLUMBERGER CRANE 5083 Well Number NIAKUK NK-65A Survey section From 2200.66 ft. to 14154.24 ft. Date 4/2/2008 Gyrodata Job No AK0308G_l15 Gyrodata Surveyors HENRY DREW Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE in Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey 'Hot' section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurve with backu tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurve with backu tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investi ate and comment if effects are ne li ibfe Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurve with backu tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other C arameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q366 (OPS SUR-MA-003) 13`h Nov 03 /Revision 12 Page 1 of i AK030SG 115 ~-e~~ 7 DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050630 Well Name/No. PRUDHOE BAY UN NIA NK-65A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22869-01-00 MD 14208 TVD 9983 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run; DIR / GR /RES /NEU, DIR / GR /RES /NEU, USIT, RST, Temp, Stat Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Ty pe Med/Frmt Number Name Scale Media No I ~ ti~~ D D Asc Directional Survey // 'AED C Las 13817 Injection Profile 5 1 '~ og Las Injection Profile 5 Blu 1 I Rpt LIS Verification IUD C Lis -~ 13939 ~'L1$-~deFi€~tiot~- 1.,~ ~~,~;,.~~~ :-°:~~, 2-4 ~D C Pdf,,,_- 13939 Induction/Resistivity 2 1-4 /fD C Pdf ~` 13939 Induction/Resistivity 2 1-4 'I.ED C Pdf ,- 13939 Neutron 1-4 ,ED C Pdf 13939 Neutron 1-4 'COg Cement Evaluation 5 CoI 1 Co 13953 Reservoir Saturation 5 Blu 1 g ~ED i C Pds 13953 Reservoir Saturation 5 1 14049 Induction/Resistivity Well Cores/Samples Information: Completion Date 8/8/2005 Completion Status 1WINJ Current Status 1WINJ UIC Y Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 8454 _ 14208 7l14(2005i Definitive 13640 14113 Case PRES/CCUGR/ILSIfEMP/ SPIN 17-Jan-2006 13640 14113 Case PRES/CCUGR/ILS/TEMP/ SPIN 17-Jan-2006 0 0 Open 5/10/2006 LIS 8003 14157 6/8/2006 GR, ROP, NCNT, NPHI, RHOB 8513 14208 6/8!2006 ROP, DGR, EWR 4-May- 2005 6697 9982 6/8/2006 DGR, EWR 4-May-2005 8532 14208 6/8/2006 DGR, ALD, CTN 4-May- 2005 6697 9982 6/8/2006 DGR, ALD, CTN 4-May- 2005 2900 14180 Case 6/8/2006 SCMT-CB, PBMS-A 05-Jul- 2005 13700 14162 6/14/2006 RST Sigma- Borax Log 24- Feb-2006 13700 14162 6/14/2006 RST Sigma- Borax Log 24- Feb-2006 8003 14179 Open GR, ROP, FET, NPHI, RHOB Res 25-Apr-2006 Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050630 Well Name/No. PRUDHOE BAY UN NIA NK-65A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22869-01-00 MD 14208 TVD 9983 ADDITIONAL INFORMATION Well Cored? Y /~' Chips Received? Y,! pL._.. Analysis Yom- Received? Comments: Compliance Reviewed By: Completion Date 8/8/2005 Completion Status 1WINJ Current Status 1WINJ UIC Y Daily History Received? ~ N Formation Tops ~~ N Date: 7 ~ SEP 1 4 2006 STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION s Cons. Commission G ii & a REPORT OF SUNDRY WELL OPERATIC Anchorage 1. Operations Performed: Abandon^ Repair Well^X Plug Perforations^ Stimulate X^ Other^ Alter Casing^ Pull Tubing^ Perforate New Pool^ Waiver^ Time Extension^ Change Approved Program^ Operation Shutdown^ Perforate X^ Re-enter Suspended Well^ 2. Operator gp Exploration (Alaska) Inc. 4. Current Well Class: 5. Permit to Drill Number: , Name: Development ^ Exploratory^ 05-0 0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic^ Service^X 50-029-22869-01-00 7. KB Elevation (ff): 9. Well Name and Number: 48.30 N K-65A 8. Property Designation: 10. Field/Pool(s): ADL-034635 Prudhoe Bay Field I Niakuk Pool 11. Present Well Condition Summary: Total Depth measured 14208 feet true vertical 9983.0 feet Plugs (measured) None Effective Depth measured 14175 feet Junk (measured) None true vertical 9950.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20" 133# H-40 40 - 115 40.0 - 115.0 3060 1500 SURFACE 2659 9-5/8" 40# L-80 39 - 6244 39.0 - 5149.0 5750 3090 PRODUCTION 8477 7" 26# L-80 36 - 8513 36.0 - 6684.0 7240 5410 LINER 5866 4-1/2" 12.6# L-80 8342 - 14208 6565.0 - 9983.0 8430 7500 Perforation depth: Measured depth: 14070-14107 True vertical depth: 9848-9884 Tubing (size, grade, and measured depth): 4-112" 12.6# L-80 @ 35 - 8357 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 8300 4-1/2" HES HXO SVLN @ 2105 12. Stimulation or cement squeeze summary: ~ ~~~ ~~~ ~ ~ ~~D~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Rearesentative Daily Averaoe Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: --- --- 10,081 --- 1372 Subsequent to operation: --- --- 5,991 --- 2320 14. Attachments: 15. Well Class after proposed work: Exploratory^ Development^ Service^X Copies of Logs and Surveys run , 16. Well Status after proposed work: Daily Report of Well Operations _ X Oil^ Gas^ WAG ^ GINJ^ WINJ^X WDSPL^ Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 9!11/06 Form 10-404 Revised 4/2004 • ! NK-65A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/26/2006 *** WELL SHUT 1N ON ARRIVAL *** (SBHP) TAGGED TD @ 14,074' SLM SO MADE ADJUSTMENTS TO STOPS @ 13,917' MD , 13,841' MD , 13,714' MD , 13,841' MD - GOOD DATA RECOVERED-DRIFT W/ 2.50" CENT.& S/B TO 14074' SLM, S/B CAME BACK EMPTY ***WELL LEFT S/I, DSO NOTIFIED*** 06/10/2006 CTU #5, FCO Acid; RU CTU in progress. RIH w/2.5"JSN. Tag TD @ 14177' ctmd. PU @ 14171' ctmd. Pump Biozan sweeps off bottom. Short trip to 7850', getting 1 for 1 returns. No solids seen in returns. RBIH to TD. Circulate well over to 3% NH4CI. Wait on availability of acid. Spear 3% NH4CI ahead of acid. Re- establish circulation. Pump 25 bbls of 12% DAD acid to nozzle. Close choke. Reciprocate jetting acid across perfs. Perfs broke down at 2240 psi WHP after one pass. Continue injecting/jetting perfs with remaining acid. Infectivity 1.5 bpm @ 1310 psi WHP. POOH filling coil voidage. Cap well with 10 bbls 50150 methanol. Final infectivity = 2.5 bpm @ 1250 psig WHP. Secure well. Notify DSO to put well on injection. RD CTU #5. *** Job Complete *** 05/24/2006 RAN 2.70 CENT AND DUAL STATIC GAUGE. MADE FOUR 15 MIN STOP @ 13,865 MD, 13,968 MD, 14,071 MD AND 13,968' MD.PETRADAT REPORTED TEMPERATURE ANOMALIES. (PRESSURE @ 9700' TVDss 4349.1/TEMP 141.2} RAN SECOND SET OF GAUGES RIH W/ 2.70 CENT. TANDAM PETRADAT GAUGES. MADE 15 MIN STOPS @ 9600'/ 9700' /9800 'TVDss ***LEFT WELL S/I*** DSO NOTIFIED 05/23/2006 ***** WELL SHUT IN ON ARRIVAL *** PERFORATE 2-7/8" POWERJETS WITH GR CCL 14070-14087 6 SPF. RIG UP, RIH W/ 2.70 CENT AND DUEL STATIC GAUGES. 05/22/2006 CORRELATED TO SWS SCMT LOG DATED 5-JULY-05, PERFORATED 14087'-14107' WITH 2 7/8" 2906 PJ 6 SPF, 27.7" PENE, 0.36" EH, 15 GMS. WELL SHUT IN 05/21/2006 **** WELL SHUT IN ON ARRIVAL *** DRIFT W/ 10' * 2 7/8" DUMMY GUN AND SB TO @ 14,142' (SLM) RKB +28' =14,170' MD, 36' OF RAT HOLE. (NO SAMPLE) *** WELL LFT SHUT IN AND TURNED OVER TO DSO *** 05/19/2006 CTU #9 w/1.75" CT. Tag up at surface with WFD MHA and mill, break off MHA, inspected bit, appears to have normal wear. Recovered a small amount of fine metal shavings from the neck of jars. Cut 100' of coil, MU 1.9" OD NO GO CRC, dual checks, 2 stingers, 1.75" JSN (SLICK, OAL of BHA is 11.29') RIH, dry tag gently at 14141' up weight. Clean weight checks to TD and picking up off bottorn. POOH to 13800' and wash down to 14148' with flo pro out the nozzle when tagging and chase out of hole to surface at 62%. Freeze protect coil and well to 2500' with 60/40 meth~~nol water. Attempt to MIT squeeze to 2000 psi - FAIL. Lost 769 psi in 15 minutes, lost Total of 945 psi in 30 minutes. Did not attempt to establish Peak rate above 2000 psi as i~ressure would still build at 0.2 BPM. Discuss w/APE & WSO. Call operator with well status. Hang freeze protect tags, phone in straps, release equipment. *** JOB COMPLETE *** Page 1 • ~ NK-65A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/18/2006 CTU #9 w/1.75" CT. RIH with WFD 2 7/8" MHA and 3.68" OD mill. Tag at 13,833' ,pick up, start motor turning and R1H at .5' fpm. Worked past tag depth of 13,833' with no indication of motor work.Saw good motor work at 14,025', continue milling at .5 fpm. Stalled motor at 14,049', pick up and run back to 14,041' stalled motor again, had to jar up twice to get free, increase pump rate to 2.7 bpm and RBIH and tagged at 14046' lightly. PUH 500' at 2.7 bpm making short trip. Very sticky coming off bottom. pump flo pro sweep and condition hole, RBIH and start milling. Encounter hard cement at 14,050 to 14,056, 14,072', 14,115', and 14,138' ctm. Stalled at 14,138' PUH and RBIH and stall at 14,127'. PUH and RBIH milling at 0.4 ft/min and stall at 14,130 w/5 bbls of final sweep out the bit. PUH and hung up at 14,118' ctm. Work pipe while making nine jar licks up and two down, pumping, not pumping, all without success. Continue to circulate final flo pro sweep OOH until clean returns seen at surface. Made return check to gauge tank -getting 1:1 returns. Can move pipe down slightly but can't POOH. Appears mechanical. Pumped 16 bbl's 15% HCL acid, with 5 bbl's out the bit came off the coil pump and isolated well to let the acid soak for 10 minutes. RIH-to cock the jars and the coil moved freely, POOH and coil was moving without any overpull, came online with coil pump at max rate and continued to POOH. RBIH in 5' increments to jet out acid, gettting good weight checks while POOH 100' each time. Final depth was 14,125' CTM and a small amount of motor work was observed, stop RIH at this point and POOH per WOS, chasing acid to surface. 05/17/2006 CTU #9 w/1.75" CT. End weather standby to PT cement plug. MIT-T to 2000 PSI for 15 min.- Passing MIT-T. (see test results under data tab) RU CTU #9 to mill out cement. MU WFD 2 7/8" MHA consisting of, slip on CTC, DBPV, disco, circ sub, 31/8" Bailey dual action jars, PDM motor and a 3.68" three blade junk mill. (OAL of MHA is 22.71' with a max OD of 05/17/2006 Continue RD, post squeeze. Wind speed too high to lower mast (+30 mph). 05/17/2006 Freeze protect flowline (Post Coil) Pumped 15 bbls 60/40 meth water. 05/16/2006 RIH w/ 2.3" BDN. We{I is on reduced injection from SIP. Pump cold KCL down CT from 400'. Bleed/pressure IA to 1500 psi. Dry tag TD. Reset depth to prior E-line tag. Flag CT 10' off TD @ 14166'. Cool sump/cement interval @ 1.5 bpm. Increase SIP injection to 8-11 k bwpd. Injected a total of 4043 bbl from SIP. Pumped 26 bbls of Class G cement laid in from 14163' ctm. Laid in 4 bbls across perfs and close choke. After 14 bbls went behind pipe with chokes closed, observed slow pressure ramp. At 20 bbls into formation, laid remainder in wellbore. Once laid in, hesitated for 15 minutes before attempting to ramp pressure. Broke back at 300 psi over static pressure and appeared to take another barrel. Hesitated again for 20 minutes prior to ramp. Attempt to ramp pressure 2 more times with pressure break backs. After pumping 4 additional bbls into wellbore attempting to ramp, injection pressure at 1510 psi @ 0.3 bpm. Dropped ball and contaminated at 2:1 with 1.5ppb Biozan. Tagged hard cement at 13989' ctm. Total cement left in wellbore is 3 bbls, total cement behind pipe is 23 bbls. Washed pipe from WCTOC to top of cement with 2 passes at 3 bpm with 1 % XS KCI. Chase out @ 70% making repeat slow passes across GLM's and jewelry. Freeze protect wellbore from 2500' w/ water/meth. Trap 550 psi WHP. RDMO. Note: LRS to FP flowline. RDMO in progress. Page 2 ! • N K-65A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/15/2006 CTU #9. Cement Squeeze. M1RU CTU. Well SI upon arrival. Waited on proper temperature water to load well. Waiting on S1P to come up. Resume reduced injection via SIP. MU/RIH w/ 2.3" BDN. 04/09/2006 **"WELL INJECTING ON ARRIVAL *** (pre sqz) RAN PDS LOGGING TOOLS WITH WELL ON INJECTION. TAGGED TD @ 14,158' SLM. LOGGED UP HOLE @ 35 FPM TO 13,700' SLM. POOH GOOD DATA. RDMO *** DSO NOTIFIED, WELL INJECTING ON DEPARTURE *** 02/24/2006 Depth correlated to Cement Bond Log, Run 1, dated 05-July-2005 RST Baseline passes recorded with well injecting 5000 BWPD, 550 psi on tubing RST Borax passes recorded with Hot Oil pumping 0.5 bpm, four passes with 60, 110, 120, 130 bbl in formation All Borax entering perforations, no channel detected above or below perforation top at 14059' 02/24/2006 T/I/0=550/380!260 Assist E-line as directed with RST Logging. Pumped down tbg, 5 bbls methanol, 615 bbls Borax, 5 bbls methanol cap, DSO to POI. FWHP=500/8601800 FLUIDS PUMPED BBLS 5 PT Surface E ui ment 10 Neat Methanol 306 60/40 Methanol Water 10 50/50 Methanol Water 786 1 %KCL Water 3169 XS 1 %KCL Water 80 Fresh Water 26 15.8 PPG Class G Cement 115 1.5 PPB Biozan 180 150,000 LSRV FloPro 16 15% HCL Acid 338 NH4CL 25 12%DAD Acid 615 Borax Water 5681 TOTAL Page 3 TRH _ 4-1/R" rnni WaLHFAD = 11" - 5M FMC GEN. 5 ACTUATOR= T^ BAKER KB. ELEV - 60.26' BF. ELEV = 26.46' KOP = 2000' Max Angle = 65 @ 10766' Datum MD = 14122' Datum TV D = 9850' SS ~ 9-5/8" CSG, 40#, L-80, ID = 8.835" ~-i 6244' Minimum !D =3.68" @ 13989' TOP OF CEMENT, MILLED OUT 4-112" TBG, 12.6#, L-80, ~ 8357' .0152 bpf, ID = 3.958" WHIPSTOCK (05104106) ~-{ 8513' EZSV (TAGGED DIMS 05104106) ~-~ 8531' 4-112" HES HXO SVLN, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4537 4003 45 KBG2 DMY BK 0 05/25/05 2 6763 5497 48 KBG2 DMY BK 0 05/19106 1 8211 6476 47 KBG2 DMY BK 0 05119106 8279' '-j4-112" HES X NIP, ID = 3.813"' 8300' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8324' 4-1/2" HES X NIP, ID = 3.813" 1 8342' 7" X 5" BKR ZXP LNR TOP PKR w / TIEBACK SLV (& RS PO NIP), ID = 4.250" 8345' 4-1/2" HES X NIP, ID = 3.813" 8357' 4-1/2" WLEG, ID = 3.958" 8344' ELMD TT LOGGED 07/05/05 8364' 7" X 5" BKR FLEX-LOCK LNR HNGR, ID = 4.430" 8374' --~" X 4-1 /2" XO, ID = 3.920" MILLOUT WINDOW (NK-65A) 8513' - 8525' 4-1 /Z" HES XN NIP, ID = 3.725" (WITH NOGO) 4-1/2" TBG, 12.6#, L-80, ID = 3.958" ~-{ 12580' 7" CSG, 26#, L-80, ID = 6.276" f 12800' 1/Z" LNR, 12.6#, L-80, ID = 3.958" 13840' NK-65A PERFORATION SUMMARY REF LOG: ?????? ON 05/22 & 05123106 ANGLE AT TOP PERF: 12 @ 14070' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 6 14059 - 14107 S 05119(06 2-7/8" 6 14070 - 14107 O 05/23/06 2-7/8" 6 14108 - 14134 S 05/19/06 13989' TOC, MILLED THRU 05/19106, ID = 3.68" 14141' Boc, MILLED OUT 05/19/06. ID = 3.68" MILLED PBTD (ORIGINAL) ~-j 14144' ~---~ MILLED PBTD (05(19/06) 14175' CTM 4-112" LNR 12.6#, L-80 HYDRIL 521, .0152 bpf, ID = 3.958" 14208' DATE REV BY COMMENTS DATE REV BY COMMENTS 05!18198 ORIGINAL COMPLETION 05!19!06 KCF/PJC CEMENT & MILL 05/20/05 N2ES SIDETRACK(NK-65A) 05/23/06 RRD/PJC ADPERFS 05/25/05 RWUPJC GLV GO 06/18/06 CS/TLH DRLG DRAFT CORRECTIONS 06107!05 JARTLH MILL SHOE JOINT 09/08/06 CS/ PJC TV D/ MD DATUM CORRECTION 08108/05 NBF/PJC ADPERFS 09/21/05 RWL/TLH ADPERFS NIAKUK UNIT WELL: NK-65A PERMff No: 2050630 API No: 50-029-22869-01 SEC 36, T12N, R15E, 1429' FSL & 823' FEL BP Exploration (Alaska) • ~~~ ~ 3 -~ ~e V .~. Se~~erger 4~~.lN ~. ~ ZOI~fi ~ ~~~ N0.3843 Alaska Data 8~ Coneulting Se ~#~ ~3SS ~° ~ITt~11S51(N1 Company: State of Alaska 2525 Gambell Street, Suite 400 ~ Alaska Oi{ & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Mahnken AT7N: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Fietd: Prudhoe Bay 06/09/06 Well Job # Lo Descri tion Date BL Color CD 15-20B 10669980 MCNL 10/12/03 1 G-32A 10942216 MCNL 05131105 1 NK-65A 11221850 RST 02123106 1 1 L2-28 ~ N/A RST 11104/05 1 1 L2-28 ~ 11225951 RST 04107106 1 1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ~'~ ,. s , ~.~_~T_~_ i °. ~, C.(:~~J~ ~~~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • • sch Inmgerger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ „r, ..,~ ~ -^~ Anchorage, AK 99503-2838 ~'~"'~ ~` ~ 4^ ~~ ~~~' v~;iT?t1?!S$i~."{~ ATTN: Beth ~r~f c.'~ weu ~.,ti e N0.3835 Company: State of Alaska Alaska O!I & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 06/05-06/06 17-13A 11001218 USIT - _ - _~- ~ 04/04/05 v iv NK-65A ~^' _ 11084270 SCMT 07105!05 1 02=106 ~ - 1, C 10964140 LDL 04/06105 1 01-11 11051039 INJECTION PROFILE ~ -. ~~ _ . r .l 04/29/05 1 01-09A ~ 4 _ ~ 10559825 INJECTION PROFILE 07/31/03 1 01-11 ~ _ ~~ 10662950 INJECTION PROFILE LC ,/ - ~2`Cty~ ~ /a~iL 09/16/03 1 11-34 ~ - 10687720 1 LDL 1 1 12/31/04 1 A-07 _ v~j/ 9153241 PRODUCTION'PROFILE r , _ r , ~ 02/04/03 1 B-36 - (~,~ ` 10563182 LDL ~ _ ~ ~ 1 07/09!03 1 01=20 ~ ~ _ 10687694 PRODUCTI N PROFILE 07/16/04 1 K-01 - 11211415 SCMT 06/01/06 1 H-30 _ - 11217253 USIT 06/01/06 1 D.S.'09-06 11258699 USIT 04/13/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. r. Anchorage, Alaska 99508 r, ~~ • l,, t /~ __ HiasKa uata cs< t;onsumng ~ernces 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • • WELL LOG TRANSMITTAL To: State of Alaska May 15, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : NK-65A, AK-MW-3694493 NK-65A: Digital Log Images 50-029,33$f~-O1 as X69 1 CD Rorn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. l'~sl x9518 JIJN 0 8 ZU06 ~1as1~i~~~ ra~t',cns, Ganmission Anchorage BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ ~~ ~~ vTC ~a5 -6b3 ~~3`33`~ • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7"' Avenue, Suite 100 Anchorage, Alaska dos-c~~3 Apri126, 2006 RE: MWD Formation Evaluation Logs NK-65A, AK-MW-3694493 1 LDWG formatted Disc with verification listing. API# : 50-029-22869-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: !, ao~ ~a~3 -a~~;~~ -° b ~ ~ p BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 March 20, 2006 Anchorage.. Alaska 99519-6612 (907) 561-5111 Bill Van Dyke, Acting-Director Division of Oil & Gas Department of Natural Resources 550 West 7`h Avenue, Suite 800 Anchorage, AK 99501-3 560 Re: -~-- ADL 034630 - NK-38A Well -Request for Extension of Tract Operations ADL 034635 - NK-43 Well -Request for Extension of Tract Operations -- ADL 034635 - NK-65A Well -Request for Extension of Tract Operations ~~- p(s,3 Prudhoe 13ay Unit Dear Mr. Van Dyke: On September 12, 2005, the Division approved tract operations for BP Exploration (Alaska) Inc. (BPXA) to produce and inject from the Ivishak interval from the NK-38A and NK-65A Wells. This approval is valid until April 1, 2006 to allow production and injection during the Raven Participating Area (RPA) application process. On October 27, 2006, the Division approved tract operations for BPXA to commingle and conduct production from the Sag River and Kuparuk intervals in the NK-43 Well. This approval is valid for 180 days from the date test production from the Sag River interval in the NK-43 wellbore flows into the Lisburne Production Center. Test production commenced on February 3, 2006, and thus this approval extends through August 3, 2006. Ori February 8, 2006, BPXA submitted an application with the Division to approve formation of the RPA. The proposed RPA will encompass the Ivishak and Sag River Formations in this area, including production from the NK-38A and NK-43 Wells. BPXA hus also fled an app?:cation E*,itr +hP d~;l(;(-'(' fiir nnnl nilPC fnr a RaZ~Pn Qil Pnnl, To allow continued production and injection for the NK-38A, NK-43 and NK-65A Wells while the Division completes its review and action on the RPA, we request that the above referenced tract operations for each of the wells be extended until September 1, 2006, or the date the RPA becomes effective, whichever occurs first. Please contact Gary Gustafson at 564-5304 if you should have any questions. Thank you. Sincerely yours, l~lJ Mark Weggeland GPB Manager • • CC: Don Ince, ConocoPhillips Alaska Greg Threadgill, ExxonMobil Gary Forsthoff, Chevron Paul Winslow, Forest Oil Gary Benson, BPXA Gary Gustafson, BPXA Art Copoulos, DO&G Jane Williamson, AOGCC ~~~~v STATE OF ALASKA ALASKA LAND GAS CONSERVATION COM »SION Nfl~ 1 Q Z~~~ WELL. COMPLETION OR RECOMPLETION REPORT AND LOG gl~ska Qil & Gas Cons. Commission Revised: 11/0 ,Put on ~~~~~~4dd Perfs 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 2oAAC2s.~os 20AAC25.110 ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ^ pevelopment ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8!8/2005 12. Permit to Drill Number 205-063 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/5/2005 13. API Number 50-029-22869-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/12/2005 14. Well Name and Number: NK-65A 1429 FSL, 823 FEL, SEC. 36, T12N, R15E, UM Top of Productive Horizon: 4094' FSL, 1975' FWL, SEC. 30, T12N, R16E, UM 8. KB Elevation (ft): 48.3' 15. Field /Pool(s): Prudhoe Bay Field / Niakuk Pool Total Depth: 4130' FSL, 1982' FWL, SEC. 30, T12N, R16E, UM 9. Plug Back Depth (MD+TVD) 14144 + 9920 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 721736 y- 5979969 Zone- ASP4 10. Total Depth (MD+TVD) 14208 + 9983 Ft 16. Property Designation: ADL 034635 TPI: x- 724297 y-_5987994 Zone- ASP4 Total Depth: x- 724304 Y- 5988030 Zone- ASP4 11. Depth where SSSV set 2105' MD 17. Land Use Permit: ---"----- ---~---- ---------~-------- "--^------ f f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness o Perma rost 1900' (Approx.) 21. Logs Run: DIR / GR /RES /NEU, DIR / GR /RES /NEU, USIT, RST, Temp, Static 2. CASING, LINER AND EMENTING ECORD CASING ETTINO EPTH MD ETTINO EPTH TVD HOLE MOUNT SIZE WT. PER FT. GRADE OB TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 133# H-40 40' 115' 40' 115' 30" 60 sx Arctic Set A rox. 9-5/8" 40# L-80 39' 6244' 39' 5153' 12-1/4" 2283 sx PF'E', 350 sx Class 'G' 7" 26# L-80 36' 8513' 36' 6688' 8-112" 00 sx Class'G' 4-1 /2" 12.6# L-80 8342' 14208' 6565' 9983' 6-1 /8" 77 sx LiteCrete, 146 sx Class 'G' 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8357' 8300' MD TVD MD ND 14108' - 14134' 9885' - 9910' 14059' - 14130' 9837 - 9906' 25. ACID, FRACTURE,`CEMENT SQUEEZE, ETC. ' DEPTH INTERVAL MD AMOUNT Sc KIND OF MATERIAL USED Freeze Protect w/ 75 Bbls Diesel 2500' (10/07!05) Freeze Protected w/ 60 BBIs of McOH /Water 26• PRODUCTION TEST Date First Production: October 7, 2005 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULAreD 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures., apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~~,~ F~C}~ ~. ~ ?Qf1!~ Form 10-407 Revised 12/20 r'^ ~ ~'O a NTINUED ON REVERSE SIDE ~~~~~~~~ I1 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". HRZ 13188' 8986' None Kuparuk 13379' 9172' LCU 13379' 9172' Kingak 13379' 9172' Sag River 13701' 9488' Shublik 13788' 9573' Sadlerochit 13874' 9657' Zone 2A2 14034' 9813' Zone 2A1 14061' 9839' Zone 1 B 14101' 9878' Kavik 14134' 9910' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. `r ~~ ~ Signed Titl i D t l b T h i l A O e a e s ec n ca ss stant Terrie Hubble NK-65A 205-063 Prepared By Narrre/Number Terrie Hubble, 584-4628 Well Number Permit No. / A COVaI NO. Drilling Engineer: phll Smlth, 564-4897 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and fog on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM $: The Kelly Bushing elevation in feet above mean low {ow water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None°. ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit OriginalAnly C Well: NK-65A Accept: 05!01/05 Field: Prudhoe Bay Unit Spud: 05/05/05 API: 50-029-22869-01-00 Release: 05/20/05 Permit: 205-063 Ria: Nabors 2ES POST RIG WORK 05/24/05 PULLED DUMMY SSSV AT 2085' SLM. 05/25/05 PULL BALL AND ROD AT 8323' SLM. PULL STA #3 AND SET DGLV AT 4520' SLM. PULLED RHC AT 8328' SLM. DRIFTED W ITH 3.25" CENT, SB TO 14134' SLM. 06/04/05 RIH WITH W FD PDM AND 3.625" 5 BLADE MILL. STACK WEIGHT AT GLM AT 4534' CTM. POH AND LD (NO MARKS), PU 3 BLADED 3.625" OD MILL. RIH, STACK WEIGHT AT 9031' (SET DOWN MEASUREMENT). 06/05/05 RBIH W/ 3.625" 3 BLADED BULL NOSE MILL. HUNG-UP AGAIN AT 9015'. PUMP FLO-PRO PILL, WORK FREE. POH LD MILL AND MOTOR (NO UNUSUAL MARKS) RIH W/ 3.125" OD VENTURI W/6' EXTENSION AND U/D JARS. RECIP THROUGH AREA OF 8980' - 9050' SEVERAL TIMES. 4-5 K OVERPULL AND 2K WEIGHT LOSS, RIH THROUGH PROBLEM AREA. RIH CIRCULATING THROUGH VENTURI AND DISPLACING MUD TO OT. TAG BOTTOM AT 14142'. POH W/VENTURI. RECOVERED -1/3 GAL OF LARGE METAL DEBRIS (PACKER SLIPS, SET SCREWS, METAL BANDS). RUN VENTURI AGAIN TO SAME. RECOVERED CUP OF SMALL METAL BITS. RIH WITH U/D JARS, PDM, AND 3.625" 3 BLADED BULL NOSE MILL. MILL ON JUNK. NO PROGRESS. POH TO CHANGE MILLS. 06!06!05 POH LD MHA AND MILL. MILL SHOWS SCARRING AROUND SHANK FROM JUNK. CUT 200' OFF CT. NEW LEGTHN 19,700' -1.75" OD. PU NEW WEATHERFORD BHA 2.875" OD AND 5 BLADED JUNK MILL 3.625" OD OAL= 13.61'. RIH, DRY TAG AT 14146' CTM. MILL DOWN TO 14181' CTM, 5 FLOPRO SWEEPS. CHASE OOH AT 80%. FREEZE PROTECT W ELL TO 2600' WITH 50!50 METH. PT SHOE JOINT TO 2600 PSI. LOST 200 PSI IN 5 MINUTES. MAY WANT TO CONFIRM TEST WITH DHD (LESS SURFACE EQUIP TO TEST) PERFORM WEEKLY BOP TEST. RDMO. 06/12/05 MADE DRIFT RUN TO 8400' SLM WITH 3.80" GAUGE RING. SET 4 1/2" XX PLUG (EIGHT 3/16" EQ. PORTS) AT 8,314' SLM. RAN 4 1/2" CHECK-SET TO 8314' SLM. (CAME BACK SHEARED INDICATIVE OF GOOD SET). 06/16/05 DRIFT TO 13685' W/ 3.80 GAUGE RING UNABLE TO WORK 4 1/2" XN PLUG, PASS 8631' SLM. 06/17/05 UNABLE TO SET "XN" PLUG. SET WEATHERFORD WRP PLUG AT 8550' MD. 06/27/05 RAN JUNK BASKET TO XN NIP AT 13687' SLM, 3 CUPS OF METAL SHAVINGS, RUBBER, AND CLAY LIKE MATERIAL. RAN 4.5" BRAIDED LINE BRUSH AND 3.70" GAUGE RING. BRUSHED TIGHT SPOTS AND XN NIP AT 13687' SLM. RAN JUNK BASKET TO XN NIP AT 13687' SLM, 1-1/2 CUPS OF SAME RETURNS. 06/29/05 FISHED PLUG OUT OF STA #2 AT 6710' SLM, DRIFT W/ 3-3/8" DUMMY GUN AND SAMPLE BAILER TO 14160' SLM. NK-65A, Post Drill Work Page 2 • 07/05/05 LOGGED SCMT PASSES FROM 8100' - 14190' (TD}, RAN REPEAT SECTIONS OVER CEMENT TOP AT 8506', CATCHING LINER TOP IN SAME PASS. ALSO LOGGED REPEAT SECTION OVER PERF INTERVAL FROM 13900' - 14190'. LOGGED GR/CCL FROM 3000 TO TD AS PER PROGRAM. DRILLING ENGINEER REQUESTED TIE-INTO SPERRY SUN MWD LOG DATED 13-MAY-05. USED RUN #4 TO CORRELATE NEAR 14100'. OLD WELL COMPLETION DEPTHS ARE OFF DEPTH WITH TIE-IN TO MWD LOG. 08/08/05 CORRELATED TO SPERRY MWD DGR DATED 12-MAY-2005. PERFORATED 14108' - 14134' WITH 26' OF 2- 7/8" 6 SPF HSD 2906 PJ HMX. 08/09/05 RUN STATIC W- 3.6 CENT. AND PETRADAT DUAL PETRADAT GAUGES, WITH KB. - BF. CORR. OF 28'. MADE STOPS AT 9850', 9750', 9650', 9850', TVDS (DATA FROM GAUGES INCONCLUSIVE). 08/09/05 RUN STATIC W- 3.6 CENT. AND PETRADAT DUAL PETRADAT GAUGES, WITH KB. - BF. CORR. OF 28'. MADE STOPS AT 9850', 9750', 9650', 9850', TVDS (DATA FROM GAUGES INCONCLUSIVE). 08!15/05 RAN DUEL PETREDAT GAUGE, MADE STOPS AT 14122' MD, 14019' MD, 13927' MD AND 14122'. (USED RKB CORRECTION). 09/14/05 DRIFT TUBING W/ 2 7/8" DG, S. BAILER. TAGGED TD AT 14136' SLM, STICKY ON BOTTOM. (RECOVERED SMALL AMOUNT OF F1LL IN S. BAILER.) 09/20/05 USE PURE SYSTEM TO PERFORATE FROM 14107' - 14130'. RUN 1:13' HSD PURE: PERFORATED FROM 14107' - 14120'. RUN 2: 10' HSD PURE PERFORATED FROM 14120' - 14130'. CHARGES USED: 2906 POWERJET HMX 6 SPF 60 DEG PHASED API DATA: PEN = 27.7", EH = 0.36", WT = 15 GM 09/21 /05 CORRELATE TO SWS SCMT LOG DATED 5-JUL-2005. PERFORATE 14059' - 14107' WITH 2-7/8" HSD PJ 2906 HMX 6 SPF. RUN 1: MISRUN. CCL FLOODED, ORINGS FAILED RUN 2: PERFORATE 14087' - 14107', ALL SHOTS FIRED RUN 3: PERFORATE 14067' - 14087', ALL SHOTS FIRED RUN 4: PERFORATE 14059' - 14067', ALL SHOTS FRED NO CHANGE fN PRESSURES NOTED. RELEASED WELL TO DSO TO BE PUT ON INJECTION. 10/05/05 RU AND RIH W/ 2.25" OD JSN TAG TD AT 14175' DN/CTM, 14168' UP/CTM. CHANGE WELL OVER TO NH4CL. PERFORM INJECTIVITY REST - .5 BPM ! 2175 PSI - .7 BPM ! 3000 PSI AND INCREASING. PREP TO PUMP ACID. 10/06/05 JET 10 BBL 90:10 DAD AND 10 BBLS 9:1 MUD ACID FROM 14059' - 14134'. SAW A 600 PSI BREAK DOWN FROM 1950 PSI TO 1350 PSI AS MUD ACID ENTERED PERFS WITH PUMP RATE AT 1 BPM. INCREASED PUMP RATE TO 1.1 BPM, WHP INCREASED TO 2260. LET ACID SOAK, WHP CONTINUED CLIMBING TO 2800 PSI/1.1 BPM. REDUCED RATE TO .4 BPM FOR TOTAL 54 BBL NH4CL OVER FLUSH. FINAL INJECTION NK-65A, Post Drill Work Page 3 • RATE / PRESURES - .4 BPM AT 3350 PSI. CIRCULATE COLD WATER INTO WELL AND INJECT 150 BBLS COLD WATER INTO PERFS AT 0.6 BPM/3000 PSI WHP. POOH. 10/07/05 POOH. BULLHEAD COLD FRESH WATER DOWN BACKSIDE AT AVERAGE RATE OF 0.8 BPM/3400 PSI WHP. THERMAL FRACTURING BEGAN AT 135 BBL PUMPED. STEADY INCREASE IN INJECTIVITY TO PUMP LIMIT OF 4.5 BPM AT 3000 PSI WHP. 300 BBL COLD WATER PUMPED. FREEZE PROTECT TO 2500' W! WATER/METH. PERFORM SRT DURING FREEZE PROTECT. RDMO. WELL IS READY TO PUT ON INJECTION. TREE _ 4" CMJ K-65A Final DRLG DRAFT WELLHEAD = 11" - 5M FMC GEN. 5 ACTUATOR = -- BAKER ---~-~--~------ KB. ELEV = 48.4' BF. ELEV = 19.8' KOP = 2000' Max Angle = 65 Datum MD = 14122' Datum TVD = 9850' SS 2105' i~ 4-1/2" HES HXO NIPPLE 9-5/8" CSG, 40#, L-80, ID = 8.835" 6244' Minimum ID = 3.725" @ 13710' 4-1 /2" XN NIPPLE 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 8357' PERFORATION SUMMARY REF LOG: SWS-ANADR~L MEASURED DEPTH ANGLE AT TOP PERF: 13 @ 14059' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 6 14059 - O 09/21105 2-7/8" 6 14108 - 14134 O 08/08!05 lyl3b 8513' 7" Window Top TOP OF4-1/2"LNR I-{ 1 ~ 7" CSG, 26#, L-80, ID = 6.276" I PBTD 13752' 4 1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13840' f:A S I IFT MA NI~RFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4537 4003 45 KBG2-1 R DMY BEK-2 0 5/25/2005 2 6763 5497 48 KBG2-1 R DMY BK 0 5/25/2005 1 8211 6476 47 KBG2-1R DMY BK 0 5/25/2005 8279' 4-1/2" HES X NIP, ID = 3.813" 8300' 7" X 4-112" BAKER S-3 PKR, ID = 3.875" 8323' 4-1/2" HES X NIP, ID = 3.813" 8344' 4-1/2" HES X NIP, ID = 3.813" 8355' 4-1/2" TUBING TAIL WLEG 8342' ,- 4 112" Liner hanger /packer l •" 4 1/2" XN Nipple, ID = 3.725" 13710' " SHOE JOINT MILLED OUT TO 3.625"; PBTD 14175' CTM ~• 4 1/2" LNR, 12.6#, L-80, ID = 3.958" PBTD 14144' TOP OF LANDING COLLAR 14144' 4 1/1" FLOAT SHOE 14208' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/18/98 ORIGINAL COMPLETION 09/21/05 RWUTLH ADPERFS 05116105 CRM Sidetrack Completion 09/27/05 LK/PJC ADPERF CORRECTIONS 05/25105 RWL/PJC GLV GO 06/07/05 JAF/TLH MILL SHOE JOINT 06!21!05 VF/PJC DATUM TVD/MD CORRECTION l ~ AR~'ERFS NIAKUK UNIT WELL: NK-65A PERMIT No: 205-063 API No: 50-029-22869-01 SEC 36, T12N, R15E, 1429' FSL & 823' FEL BP Exploration (Alaska) MEMORANDUM • TO: Jim Regg 1'_7' ~t{~~~j5 P.I. Supervisor I ~_ 7~d t FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 24, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NK-65A PRUDHOE BAY UN NIA NK-6iA Src: Inspector NON-CONFIDENTIAL ~,~~ Reviewed Sy: P.I. Suprv ~~~ Comm Well Name: PRUDHOE BAY UN NIA NK-65A Insp Num: mitCS051015171901 Rel Insp Num API Well Number Permit Number: 50-029-22869-01-00 205-063-0 Inspector Name: Chuck Scheve Inspection Date: 10/15/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ NK-65A 'j`ype Inj. ! W , TVD 6536 ~ IA 450 ~ 2200 2180 ~ 2180 ~ i :11 t,~~ ~ ~~~~ "I'~ICT~5t SPT ~ Test pSl ~ 1634 ~ OA ~ 180 ~ 400 ~ 400 ~ 400 Interval ~IT~- P/F P Tubing ~ voo I loo I I7oo loo ~ ~ NOtes Pretest pressures observed and found stable. Monday, October 24, 2005 Page 1 of 1 STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~1.~ ~ ~ ~,Q~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 Otta~~ ~~~ GOf1S. QO~;')t{~~;,.:' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time~~zfension ~`tf1~~lL~f 8~@ Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well LLJJ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 205-0630 3. Address: P.O. Box 196612 ~ ~ Stratlgraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22869-01-00 7. KB Elevation (ft): 9. Well Name and Number: 48.3 KB NK-65A 8. Property Designation: 10. Field/Pool(s): ADL-034635 Niakuk Field/ Niakuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14208 feet Plugs (measured) None true vertical 9982.64 feet Junk (measured) None Effective Depth measured 14175 feet true vertical 9950.32 feet Casing Length Size MD TVD Burst Collapse Conductor 75 20" 133# H-40 40 - 115 40 - 115 3060 1500 Surface 6205 9-5/8"40# L-80 39 - 6244 39 - 5149.28 5750 3090 Production 8477 7" 26# L-80 36 - 8513 36 - 6683.89 7240 5410 Liner 5802 4-112" 12.6# L-80 8342 - 14144 6565.19 - 9919.95 8440 7500 Perforation depth: Measured depth: 14059 - 14107 14107 - 14130 14108 - 14134 True Vertical depth: 9836.91 - 9883.75 9883.75 - 9906.25 9884.73 - 9910.16 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 25 - 8357 Packers and SSSV (type and measured depth) 7" ZXP Liner Top Packer 8342 4-1/2" Baker S-3 Packer 8300 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 0 0 180 200 Subsequent to operation: 0 0 0 0 1200 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~' Development Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG GINJ WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Signa~tr~g` ~~~'L~G~'~' Phone 564-4424 Date 10/18/2005 Form 10-404 Revised 04(2004 `~ ' ~ ~p ~' ~ ~ ~ ~ ~ Submit Original Only b <. ~~S EFL- 0 C i~ J 2405 N K-65A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTfVIT.YDATE SUMMARY Add Perf _. 9/20/2005 USE PURE SYSTEM TO PERFORATE FROM 14107 - 14130'. RUN 1:13' HSD PURE: PERFORATED FROM 14107' - 14120'. RUN 2: 10' HSD PURE PERFORATED FROM 14120' - 14130'. CHARGES USED: 2906 POWERJET HMX 6 SPF 60 DEG PHASED API DATA: PEN = 27,7", EH = 0.36", WT = 15 GM TAGGED TD AT 14169'. 9/21/2005 CORRELATE TO SWS SCMT LOG DATED 5-JUL-2005 PERFORATE 14059 - 14107 FT WITH 2-718" HSD PJ 2906 HMX 6 SPF RUN 1: MISRUN. CCL FLOODED, ORINGS FAILED RUN 2: PERFORATE 14087 - 14107 FT. ALL SHOTS FIRED RUN 3: PERFORATE 14067 - 14087 FT. ALL SHOTS FIRED RUN 4: PERFORATE 14059 - 14067 FT. ALL SHOTS FIRED NO CHANGE IN PRESSURES NOTED **RELEASED WELL TO DSO TO BE PUT ON INJECTION** _. _ _d. Acid treatment __. __ __ 10/6/2005 Continued from 10/05/05 WSR. Jet 10 bbl 90:10 DAD and 10 bbls 9:1 Mud Acid from 14059'-14134'. Sawa 600 psi break down from 1950 psi to 1350 psi as Mud acid entered perfs with pump rate at 1 bpm -increased pump rate ' to 1.1 bpm, WHP increased to 2260 - let acid soak, WHP continued climbing to 2800 psi/1.1 bpm -reduced rate to .4 bpm for total 54 bbl NH4CL over flush -Final injection rate / presures - .4 bpm at 3350 psi -Circulate cold water into well and inject 150 bbls cold water into perfs @ 0.6 bpm/3000 psi WHP. POOH. Continued on 10/07/05 WSR. 10/7/2005'Continued from 10/06/05 WSR. POOH. Bullhead cold fresh water down backside @ average rate of 0.8 bpm/3400 psi WHP. Thermal fracturing began t @ 135 bbl pumped. Steady increase in infectivity to pump limit of 4.5 bpm @ ..3000 psi WHP, 300 bbl cold water pumped. Freeze protect to 2500' w/ water/meth. Perform SRT during freeze protect. RDMO. "***Well is ready to put on injection.""* FLUIDS PUMPED BBLS 2 Diesel 66 Meth 116 NH4CL 320 Fresh H2O 10 90:10 DAD acid 10 9:1 Mud acid 524 TOTAL STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMIV~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ®WINJ ^ WDSPL No, of Com letions One p Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/8/2005 ~ 12. Permit to Drill Number 205-063 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/5/2005 ~ 13. API Number 50-029-22869-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/12/2005 ~ 14. Well Name and Number: NK-65A 1429 FSL, 823 FEL, SEC. 36, T12N, R15E, UM Top of Productive Horizon: 4108' FSL, 1978' FWL, SEC. 30, T12N, R16E, UM g, KB Elevation (ft): 48.3' 15. Field /Pool(s): Prudhoe Bay Field / Niakuk Pool Total Depth: 4130' FSL, 1982' FWL, SEC. 30, T12N, R16E, UM 9. Plug Back Depth (MD+TVD) 14144 + 9920 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 721736 ~ y- 5979969' Zone- ASP4 10. Total Depth (MD+TVD) ~ 14208 + gg83 ~ Ft 16. Property Designation: ADL 034635 TPI: x- 724300 y- 5988009 Zone- ASP4 Total Depth: x- 724304 ~ Y- 5988030 ~ Zone- A3P4 11. Depth where SSSV set 2105' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: a DIR / GR /RES /NEU, DIR ! GR !RES !NEU, USIT, RST, Temp, Static cs tiw X35.1 ~ "s!J.i~ . (,~,~~ ,~~ c~, ~ r: ; ~~ ~ 22. ASING, INER AND EMENTING ECORD CASING E7TING EPTH MD ETTING EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 133# H-40 40' 115' 40' 115' 30" 260 sx Arctic Set A rox. 9-5l8" 40# L-80 39' 6244' 39' 5153' 12-1 /4" 2283 sx PF'E', 350 sx Class'G' 7" 26# L-80 36' 8513' 36" 6688' 8-1 /2" 00 sx Class 'G' 4-1/2" 12,6# L-80 8342' 14208' 6565' 9983' 6-1/8" 277 sx LiteCrete, 146 sx Class 'G' 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TuflING RecaRo Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8357' 8300' MD TVD MD TVD 14108' - 14134' 9885' - 9910' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $~ KIND OF MATERIAL USED Freeze Protect w/ 75 Bbls Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~- --- 4, ee r '- 5 None ~r~ ~E~ ~ 7 ~~~rJ .~_cz.~''a.~' z Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~.,. ~w ,:. .i r~ 28. ~ GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". HRZ 13188' 8986' None Kuparuk 13379' 9172' LCU 13379' 9172' Kingak 13379' 9172' Sag River 13701' 9488' Shublik 13788' 9573' Sadlerochit 13874' 9657' Zone 2A2 14034' 9813' Zone 2A1 14061' 9839' Zone 1 B 14101' 9878' Kavik 14134' 9910' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. !!~~ ~~~~ Signed ~ Title Technical Assistant Date ~ O~FJ~t;~ Terrie Hubble NK-65A 205-063 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dri//ingEngineer: phi/ Smith, 564-4897 INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). Irera 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: True vertical thickness. Irma 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Irene 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irene 27: If no cores taken, indicate "None". !Tenn 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 5/23/2005 1:37:14 PM BP EXPLORATION Operations Summary Report Page 1 of 12 Legal Well Name: NK-65 Common W ell Name: NK-65A Spud Date: 4/4!1998 Event Nam e: REENTE R+COM PLET E Start : 4/28!2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: Rig Name: NABOB S 2ES Rig Number: 2ES Date a' From - To ; Hours ! Task ; Code j NPT i Phase ~ Description of Operations 4/28(2005 00:00 - 00:00 24.00 MOB P PRE PJSM: Remove cellar hard lines and prep rig to move off F-34 Pull pits forward Move sub off well. Spot sub on pad. Remove HCR, Choke,Kill & Hydraulic lines Nipple up BOP on stand and secure. Spot sub on double mats to aid with fire removal. Remove spreader beam and walls. Position back wheels for fire removal. Change out tires on drillers side of sub rear. ~ Rig Moved off F-34 and work on fire swap of 4 rear tires. 4/29/2005 00:00 - 08:30 8.50 MOB P PRE Continue working on fire change. Change tires # 5 & 6 (4 tires changed) 02:00 hours Crew reported oil on pad in front of F-10 out from camp and pits. Inspected and call 5700 report discharge. Approximated at less than 1 qt used engine oil on pad, covering 18" square. ACS called back at 02:30 and will came to location to access. Marked with orange cone but did not clean up as directed by ACS. Investigation by ACS found to less than a pint and classified as a leak. Glean up and disposed of as oily waste. Source of leak unknown. 08:30 - 10:00 1.50 MOB P PRE Install spreader beam and wall. 10:00 - 18:00 8.00 MOB P PRE Hang cellar doors and sides. Back over BOP stack and pick up stsck for transport. Make up HCR valve and hydraulic hoseson BOP's. Install cellar mud lines and choke hose. 18:00 - 21:30 3.50 MOB N WAIT PRE Waiting on security for rig move. 21:30 - 00:00 2.50 MOB P PRE Start move. Move sub off F pad onto spine road. 4/30/2005 00:00 - 18:00 i 8.00 MOB P PRE Moving rig substructure module to NK65A. 18:00 - 20:00 2.00 MOB P PRE Start moving camp and pit complex to Niakuk well pad. Lay herculite. Spot and level rig over NK-65A. 20:00 - 21:00 1.00 MOB P PRE PJSM. Raise & pin derrick. 21:00 - 22:00 1.00 MOB P PRE Raise cattle chute and bridle down. 22:00 - 00:00 2.00 RIGU P PRE RU floor and top drive. 5/1/2005 00:00 - 04:30 4.50 RIGU P PRE Rig up on location. Rig up floor and cellar Spot pits, camp and shop. Install berming. 04:30 - 05:00 0.50 WHSUR P DECOMP Make up second annular valve. Rig accept C«~ 04:30 05:00 - 06:00 1.00 WHSUR P DECOMP Rig up drill site maintenance and pull BPV. 06:00 - 07:30 1.50 WHSUR P DECOMP Take on sea water and berm cuttings tank. 07:30 - 08:00 0.50 WHSUR P DECOMP Pre-spud meeting with all personnel in dog house. 08:00 - 09:00 1.00 WHSUR P DECOMP PJSM: Rig up lines to circulate well to sea water. 09:00 - 11:30 2.50 WHSUR P DECOMP Test lines to 1500 psi. Circulate out freeze protect. Circulate well, 6 bpm 800 psi @ tubing cut; 8693' 306 barrels Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Operations Summary Report Page 2 of 12 Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4/4/1998 Event Name: REENTER+COMPLETE Start: 4J28/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date !From - To ~ Hours ~ Task ~' Code i NPT ~'i Phase ~ Description of Operations ~ I ---- ~------~----•---L- - 1 _-- ~- 5/1/2005 09:00 - 11:30 2.50 WHSUR P DECOMP seawater circulated. 11:30 - 12:00 0.50 WHSUR P DECOMP Blow down lines and attempt to dry rod TWC in. Master valve not opening completely and will not allow TWC to pass through. Call valve shop. 12:00 - 14:30 2.50 WHSUR N SFAL DECOMP 14:30 - 18:30 4.00 WHSUR N SFAL DECOMP 18:30 - 00:00 5.50 WHSUR N SFAL DECOMP 5/2/2005 00:00 - 02:00 2.00 WHSUR N SFAL DECOMP 02:00 - 02:30 0.50 W HSUR N SFAL DECOMP 02:30 - 03:00 0.50 WHSUR N SFAL DECOMP 03:00 -04:00 1.00 WHSUR N SFAL DECOMP 04:00 - 05:00 1.00 WHSUR N SFAL DECOMP Trouble with master valve on tree can not get TWC to pass though valve. Valve shop came and attempted to function valve, can not open fully. causing a restriction. Waiting on Schlumberger slick line. Coming from V pad to set plug in X nipple at 2097 feet. PJSM: 18:30 - 21:30 Rig up Schlumberger slick line: 21:30 - 22:30 attempt to pass through with X nipple plug valve with 3.805" OD. Could not pass through the stuck master valve. 22:30 to 24:00 Pull valve and run 3.65" No go profile and can pass right through master valve with no resistance. Hook up 3.805 X nipple plug valve and attempt to pass with plug again. No Go! Sets down and hangs up in master valve. Must bump up with spang-jars to 800# to free. Call out Schlumberger E-line and Baker to set inflatable plug. While waiting on Baker and Eline attempt to swedge open valve with slick line 3.8" swedge. Can not pass through. setting down at 25 feet in master valve. Attempt to swedge open. Attempt to swedge open master valve with slick line 3.80" swedge. No Go! While waiting on E-line Rig down 51ick Line. Rig down Slick Line and rig up E Line. Rig up E line to rig floor and hold pre job safety meeting. Make up running tools and inflatable bridge plug on rig floor. Run in hole with inflatable bridge plug 3.38" OD and attempt to set @ 50 feet +/- Locate collar and pick set point in top full joint above pup joints. Attempt to set. Will not set. Pull inflatable bridge plug and running out and inspect. Nothing found to be wrong. 05:00 - 06:00 1.00 BOPSU N SFAL DECOMP RIH with inflatable bridge plug and running tool on wire line second run. Locate collar and pups. Set packer at 50'. 05:30 to 06:00 test to 1000 psi from below. Holding. Rig down Schlumberger E line and running tools. 06:00 - 08:00 2.00 BOPSU P DECOMP Nipple down tree and adaptor flange. 08:00 - 10:30 2.50 BOPSU P DECOMP Nipple up BOP's 10:30 - 17:30 7.00 BOPSU P DECOMP PJSM: Test BOP's Test witness waived by Chuck Scheve AOGCC Printed: 5!23!2005 1:37:19 PM BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4/4/1998 Event Name: REENTER+COMPLETE Start: 4128!2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date j From - To 1 Hours ~, Task i Code NPT i Phase is Description of Operations ------~----~ ---~ ---~----~--1~--- -------________ 5/2/2005 10:30 - 17:30 7.00 BOPSUF~ P DECOMP I HYDRIL52 OSLOW 3 00 HIGHSI HIGH 17:30 - 18:00 0.50 BOPSU~ P 18:00 - 19:00 1.00 BOPSU P 19:00-20:00 ~ 1.OO~BOPSUF~N 20:00 - 21:00 I 1.00! BOPSUFkP 21:00 - 00:00 I 3.001 BOPSUF# P DECOMP Rig down test joint and blow down surface equipment. DECOMP PJSM: Rig up lubicator & pull TWC. Rig down lubicator. SFAL DECOMP PJSM: Rig up Baker retieving tools and pull inflatable bridge plug at 50'. DECOMP PJSM: Make up landing joint. Engauge tubing hanger pull 120,000# and unseat tubing hanger. Pull hanger to rig floor. and lay down. Monitor well and lay down landing joint. DECOMP Pull and lay down tubing from 8693 to 5740. No control lines. 5 - 00:00 - 04:30 4.50 PULL P I DECOMP Pull and lay down 4 1/2" tubing 208 joint plus 21.62 feet and clean cut. 1 x gas lift mandrel 1 x X nipple 2 x space out pups Tubing looked to be in fair condition. Numerous pins showed signs of corrosion. 04:30 - 05:30 1.00 DHB P DECOMP Clear rig floor and lay down handling equipment. 05:30 - 07:00 1.50 DHB P DECOMP PJSM: Install test plug Test BOP's with 4" test joint Lower and upper rams 250 psi low test and 4500 psi hi test. Hydril 250 psi low: 3500 psi hi test Install wear ring 07:00 - 08:00 1.00 DHB P DECOMP PJSM: Rig up Schlumberger E line 08:00 - 12:00 4.00 DHB P DECOMP RIH on Eline with 6.115 ga ring and junk basket. to 3770 feet set down. Attempt to work through tight spot. No Go! POOH Check junk basket ?Nothing. RIH and work through tight spot. Pass back through tight spot and clean up. RIH to 8600' Pull out of hole nothing at 3770 tight spot. 12:00 - 13:00 1.00 DHB P DECOMP Check junk basket small piece of rubber and small amount of scale. 13:00 - 16:00 I 3.001 DHB { P 16:00 - 17:00 I 1.001 DHB I P 17:00 - 20:00 I 3.001 STWHIPI P DECOMP RIH with 7" bridge plug and set on depth of 8550' WLM Pull out of hole with E line and rig down Schlumberger. DECOMP PJSM: Test casing and EZSV at 8550 feet to 4000 psi chart and hold for 30 minutes Blow down all surface equipment. WEXIT PJSM: Pick up 7" Whip stock, MWD tools and BHA. Surface test MWD 250 gpm = 506 psi with sea water. Blow down surface equipment. Printed: 5/23!2005 1:37:19 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: NK-65 Common Weli Name: NK-65A Spud Date: 4/4!1998 Event Name: REENTER+COMPLETE Start: 4/28/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2E5 Rig Number: 2ES Date j From - To ~ Hours !i Task Code ~~ NPT ~, Phase Description of Operations 513!2005 20:00 - 21:00 1.00 STWHIP P WEXIT Pick up drill collars and HWDP 21:00 - 00:00 3.00 STWHIP P WEXIT RIH picking up singles of drill pipe 1136 to 4260'. Filling pipe and testing MWD every 3000' 5/4/2005 00:00 - 05:00 5.00 STWHIP P WEXIT Run in hole picking up singles 4" drill pipe. Fill pipe every 3000' :float not holding. Pump drill string volume to avoid plugging BHA/Mills. 05:00 - 06:00 1.00 STWHIP P WEXIT PJSM: Service top drive and draw works. Replace stabbing guide on top drive. Install blower hose. 06:00 - 06:30 0.50 STWHIP P WEXIT Break circulation 320 GPM 2100 psi. Orient whip stock to 55 left of high side. Tag EZSV ~ 8531 feet set anchor & shear off. Top of window ~ 8513 Bottom of window @ 8525' Up = 155,000# down = 120,000# i Rotating = 130,000# 06:30 - 07:30 I 1.00 STWHIP P WEXIT Displace well to LSND drilling fluid. 9.6 ppg 320 GPm = 2100 psi. Rotate and recip while displacing. 07:30 - 12:30 ! 5.00 STWHIP P WEXIT Mill window 320 gpm = 2150 psi 100 RPM = 5500 ft# torque Recovered 100# metal total. 80 # while milling and 20# on c{ean up. 12:30 - 13:00 0.50 STWHIP P WEXIT PJSM: pull back into casing and conduct FIT test to 13 ppg. 1200 psi surface pressure @ 6692' TVD with 9.6 ppg mud. 13:00 - 13:30 0.50 STWHIP P WEXIT PJSM: Monitor well slug pipe, blow down surface equipment & remove blower hose. 13:30 - 16:00 2.50 STWHIP P WEXIT Pull out of hole from 8513 to 1118'. 16:00 - 17:00 1.00 STWHIP P WEXIT Stand back 3 1/2" HWDP, in derrick. Lay down 4.75" drill collars. 17:00 - 18:00 1.00 STWHIP P WEXIT PJSM: Stand back MWD tool in derrick. Caliper mills full gauge. Clear rig floor 18:00 - 19:00 1.00 STWHIP P WEXIT PJSM: Pull wear bushing and flush stack. Re-install wear ring. Blow down surface equipment. 19:00 - 21:00 2.00 STWHIP P WEXIT PJSM: Make up BHA, bit and MWD tools. Do offset for correction. Surface test MWD and motor. 21:00 - 00:00 3.00 STWHIP P WEXIT RIH picking up single drill pipe from 830 tp 3000'. Fill pipe and test MWD. 5/5/2005 00:00 - 02:30 2.50 STWHIP P WEXIT Pick up drill pipe 5215 to 6993 feet filling pipe and test MWD every 3000' 02:30 -04:00 1.50 STWHIP P WEXIT PJSM: Slip & cut 88 feet drill line and rig service top drive and draw works. 04:p0 - 04:30 0.50 DRILL P PROD1 Break circulation 310 GPM 2300 psi. Exit window with drilling assembly. Orient Motor 60 left of high side and pass whip stock face without pumps. Tag up ~ 8539' on depth, establish bottom and integrality. Pick up and start pumps. Printed: 5/23(2005 1:37:19 PM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: NK-65 Common W ell Name: NK-65A Spud Date: 4/4!1998 Event Nam e: REENTE R+COM PLET E Start : 4!28/2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: Rig Name: NABOB S 2ES Rig Number: 2ES i Date I From - To i Hours ~~ Task ! Code ! NPT j Phase it Description of Operations -----I -----~ -- -! I 5!5(2005 04:30 - 12:00 7.50 DRILL P PROD1 Drill from 8539 to 8963' 2.34 slide hours 1.74 rotate hours String weight 145,000# up 110,000# down 130,000# rotating RPM while tools on WS = 20 RPM after BHA cleared WS = 70 WOB=3=15K 325 gpm = 2550 on bottom 5 - 6>000# rotating torque. ECD's 11.6 ppg 12:00 - 14:30 2.50 DRILL P PROD1 Drill from 8963 to 9150 feet. EGD's climbing to 1 i.8 ppg String weight 145,000# up 110,000# down 130,000# rotating RPM after BHA cleared WS = 70 ` WOB=3=15K 325 gpm = 2550 on bottom 5 - 6,000# rotating torque. 14:30 - 15:00 0.50 .DRILL. P . PROD1 Pump sweep and circulate to reduce ECD's to < 11.6 ppg 325 gpm 2300 psi off bottom rotating pipe at 90 RPM 15:00 - 00:00 9.00 DRILL P PROD1 Drilled from 9150 to 9825 feet. Last 24 hours drilled 1296 feet in 11.88 drilling hours Slide 543 feet with a sliding average of 73 fph Rotated 754 feet with 135 fph averaged rotating String weight 155,000# up 110,000# down 130,000# rotating RPM = 90 // 5 - 6,000# rotating torque. WOB=3=15K 325 gpm = 2550 on bottom Control drilling at 150 fph as long as ECD's < 11.7ppg ECD's reach 11.7 reduce ROP to 100 fph till ECD's drop. An average ROP of 150 FPM seams maintains an 11.6 ppg ECD Reducing flow to 205 gpm while pipe is in the downward stroke. 5/6/2005 00:00 - 08:30 8.50 DRILL P PRODi Drill to 10457 feet in sail section. Rotate hours = 5.11 Slide hours= .41 325 GPM = 2600 psi. At 03:30 the YP had dropped to 22 and was attempting to raise it, adding polymer. The polymer yielded quickly and shocked the hole and ECD's climbed because of mud properties. No additional cuttings were seen. The stand pipe pressure also increased 260 psi as the thicker mud went around. 03:00 Drilling at 130 - 140 fph ECD's at 11.6 PPG flowing at 320 gpm 04:00 Mud properties change and SSP increased and soon after the ECD's ramped up to 12.2 ppg as the thicker fluid enter the open hole. No additional cutting seen at the shaker. 08:30 - 09:30 1.00 DRILL P PROD1 Pump hi viscosity sweep. Circulate bottoms up. 325 GPM 2900 Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4/4/1998 Event Name: REENTER+COMPLETE Start: 4/28/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To !~ Hours j Task i Gode NPT ~, Phase Description of Operations ----!------1_--- ----- __~__--___----- 5/6/2005 08:30 - 09:30 1.00 DRILL P PROD1 psi. 300 gpm = 11,7 ECD Monitor well /static. 09:30 - 13:00 3.50 DRILL P PRODi Pump and back ream as instructed an short trip. No hole problems seen or additional drag. Pump and back ream out as precaution from 10457 to window at 8590'. Monitor well and blow down top drive. No indication of poor hole condition seen. 13:00 - 13:30 0.50 DRILL P ~ PROD1 Service top drive and lubricate rig. 13:30 - 14:00 0.50 DRILL P PROD1 Run in hole 8513 to 10457'. Hole in good shape and no tight spots seen. 14:00 - 15:00 1.00 DRILL P PRODi Circulate Hi-vis sweep around and check ECD baseline. 275 GPM 11.2 ppg 300 GPM 11.3 ppg 15:00 - 00:00 9.00 DRILL P PROD1 Drill from 10457' to 11018' at controlled rate between 100 - 140 FPM watching ECD's closely. WOB 5 - 8,000# RPM 90 Torque - 6 - 7,000 String weight 165,000# up 140,000# rotating 120,000# down 300 gpm = 2780 After reaching bottom after short trip @ 15:30 Torque 6- 7000 at 90 rpm while drilling. 18:30 300 gpm with lower YP (22) off bottom = 2400psi and on bottom 2650 psi. ECD's 11.4 ppg @ 140 fph 23:00 hrs. 5/7/2005 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P PROD1 Drill from 11018 to 11949' 06:00 @ 140 FPH ECD's 11.4 PPG 300 GPM = 2300 psi off bottom 2650 on bottom RPM 90 Torque = 7000 Drill string: Up = 175,000# Down = 127,000# Rotating 147,000# No problems on connections Rotating hrs = 7.14 Slide = 1.29 PROD1 Drill 11949 to 12511' 225 GPM = 1700 psi off bottom 1950 on bottom ECD= 10.75 ppg ROP = 40 fph till Tuffs at 12400' After 12520 = 22 fph RPM 90 Torque = 8000 Drill string: Up = 185,000# Down =130,000# Rotating 155,000# Some connection starting to be sticky. taking extra time Printed: SJ23/2005 7:37:19 PM BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4!4/1998 Event Name: REENTER+COM PLET E Start : 4/28/2005 End: Contractor Name: NABOBS ALAS KA DRI LLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To ! Hours i Task ~~ Code NPT , Phase Description of Operations 5/7(2005 12:00 -00:00 12.00 DRILL P PROD1 reaming. Drag up starting to increase. Cuttings across shakers are much less and very fine. Rotating hrs =8.37 Slide = .84 5/8/2005 00:00 - 09:30 9.50 DRILL P PROD1 Drilling from 12511 to 12792' ROP 20 - 25 fph rotating through the Tuffs Some spots as fast as 50 fph 225 GPM = 1700 psi off bottom 1950 on bottom (Rotating) ECD= 10.85 ppg ROP = 40 fph in Tuffs (MW = 9.6 ppg) RPM 90 Torque = 8000 to 8500 ft# Running reduced bit weight to conserve bit life at 5 - 7,000# Drill string: Up = 210,000# Down =125,000# Rotating 160,000# Some connection starting to be sticky. Taking extra time reaming. Drag up starting to increase. Cuttings across shakers are much less and very fine. No increase in cutting with sweep at 12600' / 03:30 up. Tough slides and have to increase pumps to 250 to achieve any success. Planned directional work in the Tuffs is difficult. Planning short trip as soon as the bit clears the upper Tuff section and condition can be assessed to be in good shape. 09:30 - 11:00 1.50 DRILL P PROD1 Circulate and condition for short trip. Pump Hi-vis sweep. Increase pump rate and monitor ECD's to increase hole cleaning. Hole seamed to clean up well. 11:00 - 13:30 2.50 DRILL P PROD1 Short trip from 12792 to 10179' No tight spots. Pulled 220,000# off bottom and steady after. No tight spots seen while running in. Run in to 12698` and ream to bottom as precaution. Circulate OH volume and monitor ECD's 13:30 - 00:00 10.50 DRILL P PROD1 Drill from 12791 to 13103' Total daily slide hours =9.92 hrs Total daily rotate hours = 4.96 hrs Began weight up with spike fluid to a 10.5 ppg in two circulations 275 GPM = 2640 psi off bottom 2900 on bottom (Rotating) ECD= 12.0 ppg ROP = 30 - 90 fph rotating. RPM 90 Torque = 8000 to 8500 ft# Drill string: Up = 205,000# Down =120,000# Rotating 160,000# Control drill C~ <100'/hr for ECDs' and shale drilling practices, after 13100 and clear from the Tuffs. WOB - 5 - 8,000# 5/9/2005 00:00 - 15:00 15.00 DRILL P PRODi Drill from 13103' to 13791' 275 gpm = 2700 off 3000 psi on 90 rpm = 9-9500 ft# torque Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4/4/1998 Event Name: REENTER+COMPLETE Start: 4/28/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date 1 From - To NPT ~ i Hours ~! Task j Code ~~ Phase Description of Operations 1 ~ ! I _--------------- 519/2005 00:00 - 15:00 15.00 DRILL P PROD1 String weight 230,000# up 130,000# down 165,000# rotating WOB = 11- 12 in the shale section. Total bit hours 66.25 Daily Slide footage 211 15:00 - 17:00 2.00 DRILL P PRODi Circulate hi-vis sweep around! Rotated and reciprocate while circulating. ~ 275 GPM 2500 psi. 17:00 - 21:30 4.50 DRILL P PROD1 Pull out of hole from 13632 to 8496' Monitor well at window. Up weight 165,000# Drop dart to open cir-sub. Increase circulation to 420 gpm at window after sub open. Circulate bottoms up. No additional cuttings at shakers. ~ Pump dry job and blow down surface equipment. 21:30 - 22:30 .1.00 DRILL P PROD1 Pull out to 8300 feet. MAD PASS 8300 to 8030' for tie-on logs data. 22:30 - 00:00 I 1.501 DRILL I P 5!1012005 ~ 00:00 - 01:30 1.501 DRILL ~ P 01:30 - 03:30 2.001 DRILL P 03:30 - 06:30 I 3.001 DRILL ! P 06:30 - 09:30 I 3.001 DRILL I P 09:30 - 10:30 1.00 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 14:30 ( 3.501 DRILL I P 14:30 - 16:00 I 1.501 DRILL I P 16:00 - 00:00 I 8.001 DRILL I P 5!1112005 100:00 - 13:30 13.50 DRILL I P PROD1 Pull out of hole from 8030 to 5027' Well taking corrcet fill up. 115,000# up / 95,000# down. PROD1 POH from 5027' to BHA @ 831' PROD1 Stand back HWDP & flex drill collars, down load MWD, break & L!D MWD tools, bit & mud motor, PROD1 M/U BHA # 3, P/U mud motor, bit, float sub & stab. P/U MWD tools, upload & pulse test. PJSM. Load nukes. M/U flex drill collars, circ sub & HWDP TO 856'. PROD1 RIH from 856' TO 8425' @ 45 seconds per stand, fill pipe C~3 3000' intervals. PROD1 Cut & slip 110' of drill line. PROD1 Service top drive & crown, fill pipe & test MWD ~ 250 gpm C~3 2300 psi. Install blower hose. PROD1 Pass through window C 8512', R{H @ 60 seconds per stand to 11000', RIH ~ 90 seconds per stand to 7.D. PRODi Circ & condition mud due to high ECDs. Stage pump up to 265 gpm C~ 2930 psi. PROD1 Drill from 13791' to 13922'. AST = 0 hrs, ART = 7.15 hrs. UWT = 235K, DWT = 130K, RWT = 165K. RPM = 90, WOB = 19. Pump @ 280 gpm @ 3050 psi off & 3180 psi on bottom. ECDs = 11.90, torque = 9K off & 10K on bottom. PROD1 Drill 6 1/8" production hole to 13993'. ROP slow at 10-15 fph in Z3 conglomerate and Z26. Samples predominantly chert. ART = 12.30 hrs. UWT = 254K, DWT = 130K, RWT = 170K. Pump ~ 315 gpm ~ 3590 psi, torque on bottom = 10K, off = 9K, RPM = 80, Torque increasing from -9200 to 9800 ft Ibs & ROP slowed further to 6-8 fph. Try varying drilling parameters - no improvement. Watch bit performance for 2 hours with no improvement. Decide to POH. for bit change. Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-65 NK-65A Spud Date: 4/4/1998 REENTER+COMPLETE Start: 4/28/2005 End: NABOBS ALASKA DRILLING I Rig Release: NABOBS 2ES Rig Number: 2ES Date j From - To ~I Hours II Task I Code 5/1112005 113:30 - 14:30 I 1.00 DRILL ~ P 14:30 - 15:00 0.50 DRILL P 15:00 - 17:00 2.00 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 21:00 3.00 DRILL P 21:00 - 23:30 2.50 DRILL P 23:30 - 00:00 0.50 P 5/12/2005 00:00 - 01:00 1.00 DRILL P 01:00 - 08:00 7.00 DRILL P 08:00 - 09:00 1.00 DRILL P 09:00 - 21:30 I 12.501 DRILL P 21:30 - 22:00 22:00 - 00:00 5/13/2005 00:00 - 01:00 01:00 - 04:00 04:00 - 07:00 07:00 - 10:30 10:30 - 11:30 11:30 - 20:30 20:30 - 21:30 21:30 - 00:00 5/14!2005 00:00 - 04:00 04:00 - 06:00 06:00 - 06:15 06:15 - 07:00 07:00 - 07:20 07:20 - 08:05 0.50 DRILL P 2.00 DRILL P 1.00 DRILL P 3.00 DRILL P 3.00 DRILL P 3.50 DRILL P 1.001 CASE ( P 9.00 CASE { P 1.00 CASE P 2.50 CASE P 4.00 CASE P 2.00 CEMT P 0.25 CEMT P 0.75 CEMT P 0.33 CEMT P 0.751 CEMT ( P NPT i Phase i I Description of Operations ! --- --- PROD1 --- _____ ----- ---------- - POH from 14058' to 13000'. Well taking correct amount of fluid. Hole in good shape. PROD1 Pump dry job & blow down top drive. PROD1 POH from 13000' to 8550'. PROD1 MAD PASS from 8550' to 8250' ~ 300 FPH. PROD1 POH from 8250' to 855', change out handling equipment. PROD1 POH with BHA. PJSM remove source from nuke MWD tools, down load & up load. Break bit off. Gauge cutters & otuer row were worn & inner cutters in v. good shape. Bit graded at 2-5-CT-G-E-I-RG-PR. PROD1 M/U bit # 3. Change bend in motor to 0 degrees. PROD1 PJSM. Load source in MWD nuke tools. M/U MWD tools, flex collars & flow test MWD. M/U HW DP & jars to 856' PROD1 RIH from 856' to 13936', 15/20K drag C~1 8730' & 9330'. Hole in good shape. Control running speed to avoid surge pressures on formation. Fill pipe & test MWD C 3000' intervals. PROD1 Break circ, stage pumps up slowly to stay within ECD limits, wash from 13936' to 14058'. No fill on bottom. PROD1 Drill from 14058' to T.D C~3 14208. UWT = 245K, DWT = 130K, RWT = 170K. RPM = 100, WOB = 20K, torque on bottom = 11 K, off bottom = 12K. Pump @ 275 gpm @ 3180 psi. Average ECD while drilling = 11.95. Inital ROP on bottom = 15 to 25 fph, dropping to 8 to 10 fph in the Kavik formation. PROD1 Circ open hole clean, short trip, POH from 14208' to 14030'. RIH to bottom. PROD1 Pump high-vis sweep, CBU, spot liner running pill followed by dry job. Pump pressure = 3120 psi ~ 275 gpm. PROD1 Pump liner running pill in open hole section followed by dry job. PRODi POH from 14208' to 6179', pull ~ controlled rate to avoid swab/surge pressures. UWT = 235K, hole in good shape. PRODi POH LDDP from 6179' to 885'. PRODi UD BHA, flush mud motor &MWD with fresh water. Remove source from nuke MWD tools, down load. UD tools, clear rig floor. RUNPRD Rig up tools to run 4.5" Hydril 521, 12.6#, L-80 solid production Nner. RUNPRD PJ5M. M/U float equipment, check floats held. RIH with 4.5" liner to 5893', fill C 10 joint intervals. M/U liner hanger/packer. Mix gel into packer top & allow to set. RUNPRD M/U drill pipe pups, circ liner volume @ 3 bpm @ 450 psi. RUNPRD RIH with liner on 4" drill pipe. Fill pipe @ 10 stand intervals. Running speed = 75 fpm. RUNPRD RIH through open hole with 4.5", Hydril 521, 12.6#, L-80 solid production liner on drill pipe to 14183'. RUNPRD M/U cement head & lines. Stage pumps up &circ open hole volume X3. Wash through 5' of fill to bottom @ 14208'. RUNPRD Hold PJSM with NAD, Veco, DS, BP, Baker. RUNPRD Continue circulating while batch mixing tail slurry. RUNPRD Pump 2 bbls water & pressure test lines to 4500 psi. Divert water to flowline and pump 25 bbls Mudpush I! at 11.5 PP9• Up wt 220 klbs. Down wt 127 klbs. RUNPRD Switch to cement. Mix & pump 1 i 1 bbls (280 sx) LiteCrete Printed: 5/23/2005 t:37:t9 PM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: NK-65 Common Well Name: NK-65A Spud Date: 4/4!1998 Event Name: REENTER+COMPLETE Start: 4!28/2005 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 2ES Rig Number: 2ES Date From - To ~~, Hours j Task i Code ~ NPT ~~ Phase r Description of Operations -. -_ _~- -. -_ r-. _-_ _ -____1-.- - - -.- - ' L__-_~__-~--- ------------- 5/14/2005 07:20 - 08:05 0.75 CEMT P RUNPRD cement lead slurry at 12.5 ppg. 3.8 bpm @ 700 psi start. 3:8 bpm @ 300 psi at finish. Pump 31.3 bbls (150 sx) Class G GasBlok tail slurry at 15.8 PPg• 3.8 bpm - no wellhead pressure. 08:05 - 09:00 0.92 CEMT P RUNPRD Flush line with water to flowline. Release DP dart - OK. Displace cement with mud. Catch cement -25 bbl displaced - 5 bpm @ 750 psi. Continue displacing at 3.25 bpm keeping pressure below 2000 psi. Slow to 2 bpm and see liner wiper pug at 83.8 bbls away. Continue displacement at 3.5 - 4.5 bpm. Slow to 3 bpm at 1400 psi at 150 bbls away and to 2 bpm - 1150 psi at 160 bbls away. Continue to reciprocate pipe. With 20 bbls of cement in the annulus, getting sticky. Set pipe on bottom. 09:00 - 09:15 0.25 CEMT P RUNPRD Bump plug at 171.9 bbls away (calculated displacement). Cement in place at 09:00 hrs. Pressure up to 4200 psi. Slack off 30 klbs to set hanger slips. Bleed pressure to zero and PU to release from liner hanger Slack off 50 klbs to set ZXP liner top packer and rotate drill string with 50 klbs down on packer. Pressure up to 1100 psi and pull RS seal from RS nipple. Observe pressure loss when seals are clear. 09:15 - 10:00 0.75 CEMT P RUNPRD Circulate at 480 gpm ~ 3700 psi to clear excess cement from liner top. Saw contaminated mud and -2 bbls cement at surface. 10:00 - 10:30 0.50 CEMT P RUNPRD Sreak & UD cement head, circ, clear & clean rig floor. 10:30 - 12:00 1.50 CEMT P RUNPRD Slip & cut drill line. Service top drive. 12:00 - 00:00 12.00 CEMT P RUNPRD Wait on cement to reach a compressive strength of 1000 psi. Drill crew performing rig service & maintanance. Change oil in top drive and inspect same. Welding projects in pits. Clean & paint. 5115!2005 00:00 - 01:00 1.00 CASE P RUNPRD Test 4.5" liner & packer to 4000 psi for 30 mi. OK Oi:00 - 02:00 1.00 CONDH P RUNPRD Displace well to seawater @ 500 gpm C~3 2000 psi. (Slacked off to break top drive out of drill pipe & tagged liner top with stinger from packer running tool.) 02:00 - 07:00 5.00 CASE P RUNPRD POH LDDP from 8342'. UD running tool. (1.5" X 1J2" X 1/4" piece missing from bottom of stinger.) 07:00 - 07:30 0.50 CASE P RUNPRD Pull wear ring, MIU XO to landing joint for landing tubing & UD. Clear rig floor. 07:30 - 08:00 0.50 CASE P RUNPRD R/U to run 4.5" tubing 08:00 - 17:00 9.00 CASE P RUNPRD PJSM. RIH with 4.5" L-80, 12.6#, IBT-M tubing to 6250'. P/U SVLN & R/U dual control line spools & sheave. M/U lines & pressure test to 4000 psi & maintain pressure on control lines. 17:00 - 22:30 5.50 CASE N DPRB RUNPRD RIH W/tubing from 6250' to 6545', UWT = 95K, DWT = 95K. String took 10K down weight ~ 6545'. P/U, string free, slack off & string took 5K down weight @ same spot. P!U & pulled 8K over UWT to 103K. Observe weight drop off to 95K. UD 1 jt of tubing, R/U to reverse circ. pressure up to 300 psi in 3 strokes. R1U to circ down tubing, pressure up in 7 strokes to 300 psi. M/U joint of drill pipe to tubing, pull 170K, tubing string moving up hole. UD drill pipe & change elevators to 125T YCs. Pull 1 joint of tubing C 95K. Attempt to pull next joint, pulled Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Operations Summary Report Legal Well Name: NK-65 Common Well Name: NK-65A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date I From - To i Hours ~, Task', Code NPT li ----------- ---_-_- --I CASE-~ ---'--- 5/15/2005 117:00 - 22:30 I 5.50 1 N I DPRB 22:30 - 00:00 5/16/2005 00:00 - 05:30 05:30 - 10:30 10:30 - 18:30 18:30 - 20:30 1.50 CASE N DPRB 5.50 BUNCO DPRB 5.00 BUNCO DPRB 8.00 BUNCO DPRB 2.001 R 20:30 - 00:00 3.50 R 5117!2005 00:00 - 05:00 5.00 R 05:00 - 09:30 09:30 - 10:00 10:00 - 11:30 11:30 - 12:00 12:00 - 15:00 15:00 - 16:30 16:30 - 18:30 4.501 R 0.50 R 1.50 R 0.50 R 3.00 R 1.50 R 2.00 R 18:30 - 21:30 3.00 R 21:30 - 23:00 1.50 R 23:00 - 00:00 1.00 R 812005 00:00 - 02:30 2.50 R 02:30 - 03:00 I 0.501 R 03:00 - 03:30 03:30 - 04:30 04:30 - 05:30 05:30 - 09:30 09:30 - 10:30 10:30 - 12:00 0.50 R 1.00 R 1.00 R 4.00 R 1.00 R 1.50 R DPRB 'DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB DPRB Start: 4/28/2005 Rig Release: Rig Number: 2ES Page 11 of 12 Spud Date: 4/4/1998 End: Phase I Description of Operations RUNPRD 225K on tubing string, no movement, slack off to 75K, no movement. WLEG ~ 6494'. Drop ball & rod & set packer W/3500 psi. R/D tubing &circ equipment. RUNPRD Wait on slick line unit to pull sleeve from SVLN, packer setting ball & rod & sleeve from "X" nipple. RUNCMP R/U slick line unit. Run # 1, RIH and pull DSSSV from SVLN ~ 241'. Run # 2, retrieve ball & rod ~ 6437'. Run #3 Pull RHC-M plug G 6416'. R/D slick line. RUNCMP R/U E-Line, RIH & cut tubing ~ 6448' ELMD. (Cut in pup joint above packer) POH, R/D E-Line unit. RUNCMP Tubing free, UWT = 95K. POH UD tubing from 6448' to SVLV 6188', RID control line & spoolers. POH, recovered 152 joints of tubing, 3 GLMs, X nipple & cut pup jt. RUNCMP Install test plug & test BOPE to 250 psi low & 4500 psi high. Annular preventer to 3500. Tested choke manifold, top rams, bottom rams, blind rams, annular preventor, HCR valves, koomey unit & valves on top drive. Witness of test waived by AOGCC rep. Jeff Jones. Test witnessed by J. Willingham. RUNCMP P/U packer milling BHA. RUNCMP RIH with packer milling assy picking up drill pipe to top offish` C«? 6442'. RUNCMP Break circulation, tag top of pup(packer C«~ 6442' drill pipe measurment. Mill pup and packer from 6442' to 6448'. Torque off bottom = 3K, on bottom = 6/7K. RUNCMP CBU, 500 gpm @ 2100 psi. RUNCMP RIH PJU drill pipe & push fish to 4.5" liner top C~3 8342' (Top of fish C~? 8295'.) RUNCMP Pump sweep, CBU @ 500 gpm C~ 2100 psi. UWT = 165K, DWT = 120K, RWT = 135K. RUNCMP Pump dry job, POH from 8295' to 1050'. RUNCMP Stand back HWDP & D.C.s, UD mill & junk baskets. MJU circ sub & spear, P/U accelerator jars &RIH with BHA to 1050'. RUNCMP RIH from 1050' to top of fish @ 8295', break circ @ 3 bpm ~ 300 psi. UWT = 160K, DWT = 120K. Engage fish with 15K down weight, observe 10K over pull. Pull up 90' and observe 25K over pull. RUNCMP POH with caution to 1050'. RUNCMP Stand back HWDP & D.C.s, UD accelerator jars & bumper sub. Heat connection with rose bud & break out pup joint below packer. (Connection Baker-Locked) UD packer & pup jt. UD tail pipe assy. RUNCMP P/U polish mill, boot baskets, jars & string magnet &RIH. RUNCMP RIH with liner top polish mill to 8342'. Install top drive blower hose. RUNCMP Polish/dress top of 4.5" liner. Set 10K on mill & allow weight to drill off. UWT = 155K, DWT = 125K, RWT = 138K. Torque off bottom = 4K, on = 5/9K. RPM = 60. RUNCMP Sweep, CBU. Pump @ 500 gpm C 2500 psi. RUNCMP R/U & reverse circulate. Pump ~ 300 gpm @ 1720 psi. RUNCMP Cut & slip drill line. RUNCMP POH LDDP to 1068'. RUNCMP UD HWDP & D.C.s RUNCMP UD polish mill tools, clear rig floor. Printed: 5/23/2005 1:37:19 PM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: NK-65 Common W el{ Name: NK-65A Spud Date: 4/4/1998 Event Nam e: REENTE R+COM PLETE Start : 4/28/2005 End: Contractor Name: NABOB S ALASK A DRILLING I Rig Release: Rig Name: NABOB S 2ES Rig Number: 2ES Date From - To ~~ Hours i Task ~ Code ~ NPT ~~ Phase i Description of Operations 5/18!2005 12:00 - 00:00 12.00 BUNCO DPRB RUNCMP PJSM. R!U Schlumberger Wire Line Service. Run # 1, 6.0 gauge ring, junk basket, tagged liner top C~? 8337' WLM. POH. Recovered approx 1 cup of rubber, metal & scale.. Run # 2, Run 6.0 gauge ring & junk basket, recovered approx 1/4 cup of rubber, metal & scale. Run # 3, 3.8" gauge ring & junk basket to 8390'. 5/19/2005 00:00 - 01:00 1.00 BUNCO DPRB RUNCMP Pull wear ring. R/U to run 4.5" tubing. 01:00 - 07:00 6.00 BUNCO DPRB RUNCMP PJSM. R/U &RIH with 4.5", 12.6#, L-80, IBT-M, tubing to 6262'. 07:00 - 07:30 0.50 BUNCO DPRB RUNCMP R/U control line & spoolers, hook up lines & test to 5000 psi. 07:30 - i 1:30 4.00 BUNCO RUNCMP RIH with tubing. Maintain pressure on control line. HWT = 120K, DWT = 90K. i 1:30 - 15:00 3.50 BUNCO RUNCMP Space out tubing, install pups below last joint of tubing. M/U hanger. Bleed off control line pressure & hook up to hanger. Splice back into control line spools & pressure up to 4000 psi. Land hanger & RILDS. Bleed off control line pressure. 15:00- 16:30 1.50 BUNCO RUNCMP M/U top drive, R/U lines to annulus, Reverse circ 133 bbls of clean seawater followed by 71 bbls of inhibited seawater. Displace with 64 bbls of of clean seawater C~ 3 bpm ~ 250 psi. 16:30 - 18:30 2.00 BUNCO RUNCMP Drop i 7/8" ball & rod ,pump down tubing. Set packer with 4000 psi & hold test for 30 min. Bleed tubing pressure to 1500 psi. Pressure up annulus to 4000 psi & hold test for 30 min. OK. Bleed off tubing & observe DCK in upper GLM shear. Bleed all to 0. 18:30 - 19:00 0.50 BUNCO RUNCMP Break out & L/D landing jt, install TWC & test from below to 1000 psi. 19:00 - 21:00 2.00 BUNCO RUNCMP Blow down lines & nipple down BOPE. 21:00 - 00:00 3.00 BUNCO RUNCMP Prep hanger neck, terminate control lines. Install adaptor flange. 5!20/2005 00:00 - 01:30 1.50 BUNCO RUNCMP N/U tree, install blind flange & test to 5000 psi. 01:30 - 02:00 0.50 BUNCO RUNCMP R/U DSM lubricator & pull two way check valve. 02:00 - 04:00 2.00 BUNCO RUNCMP R/U LRHOS and circ lines, pump 75 bbl diesel freeze protect down annulus & allow to U-tube. 04:00 - 05:00 1.00 BUNCO RUNCMP Secure well. Remove secondary annulus valve. Release rig C~3 05:00 hrs 5/20/2005. Printed: 5/23/2005 1:37:19 PM • Well: NK-65A Accept: 05/01/05 Field: Prudhoe Bay Unit Spud: 05105!05 API: 50-029-22869-01-00 Release: 05120/05 Permit: 205-063 Riq: Nabors 2ES POST RIG WORK 05/24/05 PULLED DUMMY SSSV AT 2085' SLM. 05/25/05 PULL BALL & ROD AT 8323' SLM. PULL STA #3 AND SET DGLV AT 4520' SLM. PULLED RHC AT 8328' SLM. DRIFTED WITH 3.25" CENT, SB TO 14134' SLM. 06/04/05 RIH WITH WFD PDM AND 3.625" 5 BLADE MILL. STACK WEIGHT AT GLM AT 4534' CTM. POH & LD (NO MARKS), PU 3 BLADED 3.625" OD MILL. RIH, STACK W EIGHT AT 9031' (SET DOWN MEASUREMENT). 06/05/05 RBIH W/ 3.625" 3 BLADED BULL NOSE MILL. HUNG-UP AGAIN AT 9015'. PUMP FLO-PRO PILL, WORK FREE. POH LD MILL AND MOTOR (NO UNUSUAL MARKS) RIH W/ 3.125" OD VENTURI W/6' EXTENSION AND U/D JARS. RECIP THROUGH AREA OF 8980' - 9050' SEVERAL TIMES. 4-5 K OVERPULL AND 2K WEIGHT LOSS, RIH THROUGH PROBLEM AREA. RIH CIRCULATING THROUGH VENTURI AND DISPLACING MUD TO OT. TAG BOTTOM AT 14142', POH W/VENTURI. RECOVERED ~1/3 GAL OF LARGE METAL DEBRIS (PACKER SLIPS, SET SCREWS, METAL BANDS). RUN VENTURI AGAIN TO SAME. RECOVERED CUP OF SMALL METAL BITS. RIH WITH U/D JARS, PDM, AND 3.625" 3 BLADED BULL NOSE MILL. MILL ON JUNK. NO PROGRESS. POH TO CHANGE MILLS. 06!06!05 POH LD MHA AND MILL. MILL SHOWS SCARRING AROUND SHANK FROM JUNK. CUT 200' OFF CT. NEW LEGTHN 19,700' -1.75" OD. PU NEW WEATHERFORD BHA 2.875" OD AND 5 BLADED JUNK MILL 3.625" OD OAL= 13.61'. RIH, DRY TAG AT 14146' CTM. MILL DOWN TO 14181' CTM, 5 FLOPRO SWEEPS. CHASE OOH AT 80°!°. FREEZE PROTECT W ELL TO 2600' WITH 50150 METH. PT SHOE JOINT TO 2600 PSI. LOST 200 PSI IN 5 M{NUTES. MAY WANT TO CONFIRM TEST WITH DHD (LESS SURFACE EQUIP TO TEST) PERFORM WEEKLY BOP TEST. RDMO. 06!12/05 MADE DRIFT RUN TO 8400' SLM WITH 3.80" GAUGE RING. SET 4 1/2" XX PLUG (EIGHT 3/16" EO. PORTS) AT 8,314' SLM. RAN 4 1/2" CHECK-SET TO 8314' SLM. (CAME BACK SHEARED INDICATIVE OF GOOD SET). 06/16/05 DRIFT TO 13685' W/ 3.80 GAUGE RING UNABLE TO WORK 4 1/2" XN PLUG, PASS 8631' SLM. 06/17!05 UNABLE TO SET "XN" PLUG. SET WEATHERFORD WRP PLUG AT 8550' MD. 06/27/05 RAN JUNK BASKET TO XN NIP AT 13687' SLM, 3 CUPS OF METAL SHAVINGS, RUBBER, & CLAY LIKE MATERIAL. RAN 4.5" BRAIDED LINE BRUSH AND 3.70" GAUGE RING. BRUSHED TIGHT SPOTS AND XN NIP AT 13687' SLM. RAN JUNK BASKET TO XN NIP AT 13687' SLM, 1-1/2 CUPS OF SAME RETURNS. 06/29/05 FISHED PLUG OUT OF STA #2 AT 6710' SLM, DRIFT W/ 3-3l8" DUMMY GUN & SAMPLE BAILER TO 14160' SLM. NK-65A, Post Drill Work Page 2 07/05/05 LOGGED SCMT PASSES FROM 8100' - 14190' (TD). RAN REPEAT SECTIONS OVER CEMENT TOP AT 8506', CATCHING LINER TOP fN SAME PASS. ALSO LOGGED REPEAT SECTION OVER PERF INTERVAL FROM 13900' - 14190'. LOGGED GR/CCL FROM 3000 TO TD AS PER PROGRAM. DRILLING ENGINEER REQUESTED TIE-INTO SPERRY SUN MWD LOG DATED 13-MAY-05. USED RUN #4 TO CORRELATE NEAR 14100'. OLD WELL COMPLETION DEPTHS ARE OFF DEPTH WITH TIE-IN TO MWD LOG. 08/08/05 CORRELATED TO SPERRY MW D DGR DATED 12-MAY-2005. PERFORATED 14108' -14134' W ITH 26' OF 2- 7/8" 6 SPF HSD 2906 PJ HMX. 08/09/05 RUN STATIC W- 3.6 CENT. AND PETRADAT DUAL PETRADAT GAUGES, WITH KB. - BF: CORR. OF 28'. MADE STOPS AT 9850', 9750', 9650', 9850', TVDS (DATA FROM GAUGES INCONCLUSIVE). 08!09/05 RUN STATIC W- 3.6 CENT. AND PETRADAT DUAL PETRADAT GAUGES, WITH KB. - BF. CORR. OF 28'. MADE STOPS AT 9850', 9750', 9650', 9850', TVDS (DATA FROM GAUGES INCONCLUSIVE). 08/7 5/05 RAN DUEL PETREDAT GAUGE, MADE STOPS AT 14122' MD, 14019' MD, 13927' MD AND 14122'. (USED RKB CORRECTION). 0917 4105 DRIFT TUBING W/ 2 7/8" DG, S. BAILER. TAGGED TD AT 14136' SLM, STICKY ON BOTTOM. (RECOVERED SMALL AMOUNT OF FILL IN S. BAILER.) • Halliburton Global Company: BP Amoco Date: 6/22/2005 Time: 10:32:27 Page: I I Field: Niakuk ` Co-ordinate(NE) Reference: Well: NK-65, True North I Site: NK Main Pad Vertical ("tVD) Refer ence: NK-65A: 48.3 I ~~ Well: NK-65 Section (VS) Referen ce: Well (O.OON,O.OOE,1 9.38Azi) I Wellpath: NK-65A --------- -_____ --- ___-- Survey Calculation M _-_______- ethod: Minimum Curvature ___________--__- Db: Oracle -----. _ __-_J Field: Niakuk North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: NK-65 Stot Name: NK-65 Well Position: +N/-S -1493.36 ft Northing: 5979969.66 ft Latitude: 70 20 51.158 N +E/-W 7143.64 ft Easting : 721736.39 ft Longitude: 148 11 59.242 W Position Uncertainty: 0.00 ft Wellpath: NK-65A Drilled From: NK-65PB1 500292286901 Tie-on Depth: 8454.44 ft Current Datum: NK-65A: Height 48.30 ft Above System Datum: Mean Sea Level Magnetic Data: 5/2/2004 Declination: 25.57 deg Field Strength: 57611 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD} +N!-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 19.38 Survey Program for Definitive Wellpath Date: 6(22(2005 Validated: Yes Version: 8 Actual From To Survey Toolcode Tool Name ft ft 88.04 2768.04 1 : Gyrodata gyro single shots (88.04-2768.Q1YI~~C-SS Gyrodata gyro single shots .. 2809.14 8454.44 NK-65P61 MWD Finder (2809.14-12926.OA,~~ MWD -Standard 8513.00 14143.86 NK-65A IIFR+MS (8513.00-14143.86) MWD+IFR+MS MWD +IFR + Multi Station Survey ~4D Inc! Arim TVD Sys "CVll V'/S E/W ~~fapN ~~1apE "tool ft deg dey ft ft ft ft ft ft 28.50 OAO 0.00 28.50 -19.80 0.00 0.00 5979969.66 ' 721736.39 TIE LINE 88.04 0.40 131.00 88.04 39.74 -0.14 0.16 5979969.53 721736.55 GYD-GC-SS 188.04 1.30 93.90 188.03 139.73 -0.44 1.55 5979969.26 721737.96 GYD-GC-SS 288.04 1.70 89.10 287.99 239.69 -0.50 4.17 5979969.29 721740.57 GYD-GC-SS 347.04 1.30 62.60 346.97 298.67 -0.17 5.64 5979969.65 721742.03 GYD-GC-SS 438.04 1.20 18.80 437.95 389.65 1.20 6.86 5979971.06 721743.21 GYD-GC-SS 488.04 1.80 346.60 487.94 439.64 2.46 6.85 5979972.32 721743.16 GYD-GC-SS 588.04 3.90 322.20 587.81 539.51 6.68 4.40 5979976.46 721740.59 GYD-GC-SS 688.04 5.10 310.90 687.50 639,20 12.28 -1.05 5979981.90 721734.98 GYD-GC-SS 788.04 5.00 307.50 787.12 738.82 17.84 -7.86 5979987.26 721728.00 GYD-GC-SS 888.04 4.40 313.20 886.78 838.48 23.12 -14.12 5979992.35 721721.60 GYD-GC-SS 988.04 3.20 322.50 986.56 938.26 27.96 -18.61 5979997.05 721716.96 GYD-GC-SS 1088.04 2.70 329.20 1086.43 1038.13 32.19 -21.52 5980001.20 721713.93 GYD-GC-SS 1188.04 2.70 328.90 1186.32 1138.02 36.23 -23.94 5980005.17 721711.39 GYD-GC-SS 1288.04 3.00 329.10 1286.19 1237.89 40.50 -26.50 5980009.35 721708.70 GYD-GC-SS 1388.04 3.00 338.90 1386.05 1337.75 45.18 -28.79 5980013.97 721706.28 GYD-GC-SS 1488.04 2.90 355.80 1485.92 1437.62 50.15 -29.91 5980018.90 721705.01 GYD-GC-SS 158$.04 3.20 22.70 1585.79 1537.49 55.25 -29.02 5980024.02 721705.75 GYD-GC-SS 1688.04 3.50 26.80 1685.62 1637.32 60.55 -26.57 5980029.39 721708.04 GYD-GC-SS 1788.04 4.90 25.10 1785.35 1737.05 67.14 -23.38 5980036.07 721711.04 GYD-GC-SS 1888.04 7.10 23.20 1884.79 1836.49 76.69 -19.13 5980045.74 721715.00 GYD-GC-SS 1988.04 9.51 27.80 1983.74 1935.44 89.68 -12.85 5980058.91 721720.90 GYD-GC-SS 2088.04 11.02 35.80 2082.14 2033.84 104.74 -3.40 5980074.25 721729.89 GYD-GC-SS 2188.04 13.48 38.60 2179.86 2131.56 121.60 9.46 5980091.48 721742.25 GYD-GC-SS 2288.04 15.91 36.60 2276.58 2228.28 141.72 24.91 5980112.05 721757.10 GYD-GC-SS 2388.04 18.36 33.10 2372.13 2323.83 165.92 41.69 5980136.73 721773.15 GYD-GC-SS 2488.04 20.56 27.90 2466.42 2418.12 194.64 58.51 5980165.93 721789.11 GYD-GC-SS 2588.04 23.41 25.40 2559.14 2510.$4 228.11 75.25 5980199.88 721804.85 GYD-GC-SS Halliburton Global Company: BP Amoco Field: Niakuk Sate: NK Main Pad Well: NK -65 Wel-paNr NK -65A Surve~~ ~~ ~ ~NID ~~ ~lncl ~~ ~Azim TVD ~~ ft deg deg ft 2688. 04 26. 13 24. 30 2649 .94 2768. 04 27. 95 26. 10 2721 .19 2809. 14 28. 99 25. 70 2757 .32 2903. 14 31. 51 25. 20 2838 .51 2996. 54 33. 99 26. 90 2917 .06 3092. 34 37. 08 27. 90 2995 .01 3184. 34 39. 70 26. 70 3067 .11 3278. 64 41. 81 26. 80 3138 .54 3370. 94 44. 67 27. 70 3205 .78 3464. 74 47. 30 27. 50 3270 .95 3555. 64 47. 80 28. 40 3332 .30 3648. 14 48. 05 29. 30 3394 .29 3741. 74 48. 21 30. 60 3456 .76 3836 .34 48. 49 31. 30 3519 .63 3926 .34 48. 61 31. 60 3579 .21 4021 .84 47. 24 30. 70 3643 .20 4118 .54 46. 08 28. 40 3709 .57 4208. 64 45. 75 28. 30 3772 .26 4297 .44 45. 80 28. 60 3834 .19 4395 .74 45. 03 26. 80 3903 .20 4487 .94 44. 52 25. 90 3968 .65 4584. 34 46. 18 24. 70 4036 .40 4678. 44 47. 70 24. 40 4100 .64 4772. 34 47. 67 25. 10 4163 .86 4864. 84 47. 36 25. 40 4226 .33 4960. 54 47. 02 25. 30 4291 .37 5053. 94 47. 25 26. 40 4354 .90 5147. 24 47. 71 26. 60 4417 .96 5241. 44 47. 99 27. 30 4481 .18 5335 .84 47. 91 26. 70 4544 .40 5434 .14 47. 92 27. 40 4610 .29 5521 .44 47. 73 26. 60 4668 .90 5612 .64 48. 05 27. 40 4730 .06 5708 .44 48. 15 27. 20 4794 .04 5803 .34 47. 95 26. 40 4857 .47 5898 .64 48. 48 27. 40 4920 .98 5993 .04 48. 88 28. 90 4983 .31 6087 .34 48. 79 28. 60 5045 .38 6167 .04 48. 37 28. 50 5098 .11 6291 .34 47. 95 27. 20 5181 .02 6385 .64 47. 94 30. 00 5244 .20 6480 .14 47. 99 30. 00 5307 .47 6573 .84 47. 85 33. 10 5370 .27 6672 .24 48. 05 34. 40 5436 .18 6767 .64 48. 23 35. 10 5499 .84 6860 .34 48 .09 36. 20 5561 ,68 6954 .54 48 .21 35. 20 5624 ,53 7046 .14 47. 86 34. 20 5685 .78 7138 .24 48. 30 34. 50 5747 .31 7229 .64 48. 32 34. 80 5808 .10 7325 .74 47. 68 32. 90 5872 .41 7420 .34 46. 99 33. 70 5936 .52 Date: 6/22/2005 Time: 10:32:27 Page: 2 j Co-ordinate(NEj Reference: Well: NK-65, True North I Vertical (TVD) Reference: NK-65A: 48.3 j Section (VS) Reference: Well (O.OON,O.OOE,19.38Azi) ~ Survey Calculation Method: Minimum Curvature Ub: Oracle Sys TVD ti/S E/W MapN MapE: ft ft ft ft ft Tool 2601 .64 266 .13 92 .83 5980238. 41 721821. 31 GYD-GC-SS 2672 .89 299 .02 108 .33 5980271. 75 721835. 82 GYD-GC-SS 2709 .02 316 .65 116 .89 5980289. 61 721843. 86 MWD 2790 .21 359 .41 137 .23 5980332. 95 721862. 92 MWD 2868 .76 404 .78 159 .44 5980378 .97 721883. 78 MWD 2946 .71 454 .20 185 .07 5980429 .12 721907. 94 MWD 3018 ,81 504 .97 211 .26 5980480 .64 721932. 61 MWD 3090. 24 559 .94 238 .97 5980536 .40 721958. 68 MWD 3157 .48 616 .14 267 .93 5980593. 43 721985. 96 MWD 3222 .65 675 .92 299 .17 5980654. 10 722015. 42 MWD 3284 .00 735 .16 330 .61 5980714. 25 722045. 09 MWD 3345 .99 795 .30 363 .74 5980775. 34 722076. 43 MWD 3408 .46 855 .69 398 .54 5980836. 73 722109. 42 MWD 3471 .33 916 .31 434 .89 5980898. 40 722143. 97 MWD 3530 .91 973 .86 470 .09 5980956. 96 722177. 44 MWD 3594 .90 1034 .52 506 .76 5981018. 67 722212. 30 MWD 3661 .27 1095 .68 541 .45 5981080. 84 722245. 17 MWD 3723 .96 1152 .64 572 .19 5981138. 67 722274. 20 MWD 3785 .89 1208 .59 602 .50 5981195. 49 722302. 85 MWD 3854 .90 1270 .57 635 .05 5981258. 40 722333. 54 MWD 3920 .35 1328 .76 663 .87 5981317. 42 722360. 63 MWD 3988 .10 1390 .76 693 .17 5981380 .26 722388. 08 MWD 4052 .34 1453 .30 721 .73 5981443. 61 722414. 78 MWD 4115 .56 1516 .35 750 .80 5981507. 49 722441. 97 MWD 4178 .03 1578 .05 779 .90 5981570. 02 722469. 23 MWD 4243 .07 1641 .50 809 .96 5981634. 33 722497. 39 MWD 4306 .60 1703 .10 839 .81 5981696. 79 722525. 41 MWD 4369 .66 1764 .64 870 .49 5981759. 21 722554. 26 MWD 4432 .88 1826 .90 902 .14 5981822. 37 722584. 05 MWD 4496 .10 1889 .35 933 .97 5981885. 73 722614. 01 MWD 4561 .99 1954 .32 967 .14 5981951. 66 722645. 25 MWD 4620 .60 2011 .97 996 .52 5982010. 14 722672. 90 MWD 4681 .76 2072 .25 1027 .23 5982071. 30 722701. 82 MWD 4745 .74 2135 .61 1059 .94 5982135. 60 722732. 63 MWD 4809 .17 2198 .61 1091 .76 5982199. 51 722762. 58 MWD 4872 .68 2261 .98 1123 .91 5982263. 80 722792. 84 MWD 4935 .01 2324 .49 1157 .36 5982327. 27 722824. 42 MWD 4997 .08 2386 .73 1191 .51 5982390. 49 722856. 71 MWD 5049 .81 2439 .22 1220 .07 5982443. 80 722883. 71 MWD 5132 .72 2521 .10 1263 .33 5982526. 92 722924. 53 MWD 5195 .90 2582 .56 1296 .84 5982589. 34 722956. 20 MWD 5259 .17 2643 .35 1331 .94 5982651. 14 722989. 48 MWD 5321 .97 2702 .60 1368 .32 5982711. 44 723024. 09 MWD 5387 .88 2763 .35 1408 .91 5982773. 36 723062. 87 MWD 5451 .54 2821 .73 1449 .41 5982832. 91 723101. 62 MWD 5513 .38 2877 .85 1489 .66 5982890. 19 723140. 19 MWD 5576 .23 2934 .83 1530 .60 5982948. 36 723179. 43 MWD 5637 .48 2990 .82 1569 .38 5983005. 47 723216. 53 MWD 5699 .01 3047 .40 1608. 04 5983063. 16 723253. 50 MWD 5759 .80 3103 .55 1646. 85 5983120. 43 723290. 63 MWD 5824 .11 3162 .85 1686. 63 5983180. 88 723328. 64 MWD 5888 .22 3220 .99 1724. 82 5983240. 13 723365. 09 MWD Halliburton Global Company: BP Amoco Date: 6/22/2005 Time: 10:32:27 Page: 3 ~ Field: Niakuk Co-ordinate(~E) Refcrence: Well: NK-65, True North ~ Site: NK Main Pad Vertical (TVD) Reference: NK-65A: 48.3 Well: NK-65 Section (V5) Reference: Well (O.OON,O.OOE,19.38Azi) I Wellpath: NK-65A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD NlS E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7511.84 46.61 33.80 5999.16 5950.86 3276.45 1761.88 5983296.66 723400.48 MWD 7609.44 47.28 35.00 6065.79 6017.49 3335.29 1802.17 5983356.66 723439.02 MWD 7696.34 47.65 36.00 6124.54 6076.24 3387.42 1839.36 5983409.86 723474.64 MWD 7797.24 46.72 33.60 6193.12 6144.82 3448.18 1881.60 5983471.84 723515.07 MWD 7888.74 46.60 34.60 6255.92 6207.62 3503.28 1918.91 5983528.03 723550.73 MWD 7983.84 46.67 33.50 6321.22 6272.92 3560.56 1957.62 5983586.43 723587.72 MWD 8076.04 47.10 32.60 6384.24 6335.94 3616.98 1994.32 5983643.90 723622.74 MWD 8169.14 47.57 34.30 6447.33 6399.03 3674.09 2032.06 5983702.10 723658.77 MWD 8262.44 46.91 34.20 6510.68 6462.38 3730.71 2070.61 5983759.84 723695.63 MWD 8357.14 46.36 33.40 6575.70 6527.40 3787.92 2108.91 5983818.15 723732.22 MWD 8454.44 45.93 32.70 6643.11 6594.81 3846.73 2147.17 5983878.06 723768.72 MWD 8513.00 45.62 31.83 6683.96 ~ 6635.66 3882.21 2169.58 5983914.19 723790.07 MWD+IFR+MS 8558.11 47.81 29.60 6714.89 6666.59 3910.45 2186.34 5983942.91 723805.98 MWD+IFR+MS 8589.53 50.95 28.17 6735.34 6687.04 3931.33 2197.85 5983964.12 723816.87 MWD+IFR+MS 8617.66 53.26 26.65 6752.62 6704.32 3951.03 2208.06 5983984.12 723826.50 MWD+IFR+MS 8651.28 55.76 27.08 6772.14 6723.84 3975.45 2220.43 5984008.89 723838.14 MWD+IFR+MS 8681.79 57.35 25.60 6788.95 6740.65 3998.27 2231.73 5984032.03 723848.75 MWD+IFR+MS 8712.86 58.76 24.15 6805.39 6757.09 4022.18 2242.81 5984056.26 723859.12 MWD+IFR+MS 8741.70 60.22 25.32 6820.03 6771.73 4044.75 2253.21 5984079.12 723868.85 MWD+IFR+MS 8774.44 61.58 25.27 6835.96 6787.66 4070.61 2265.43 5984105.33 723880.30 MWD+IFR+MS 8805.56 62.14 27.05 6850.63 6802.33 4095.24 2277.53 5984130.31 723891.67 MWD+IFR+MS 8837.70 62.72 29.85 6865.51 6817.21 4120.29 2291.10 5984155.74 723904.49 MWD+IFR+MS 8899.21 62.76 28.35 6893.69 6845.39 4168.06 2317.69 5984204.28 723929.65 MWD+IFR+MS 8993.32 62.18 29.63 6937.19 6888.89 4241.06 2358.14 5984278.44 723967.92 MWD+IFR+MS 9086.49 63.08 28.91 6980.02 6931.72 4313.23 2398.59 5984351.78 724006.22 MWD+IFR+MS 9179.65 62.90 25.33 7022.34 6974.04 4387.09 2436.42 5984426.72 724041.84 MWD+IFR+MS 9273.02 63.24 21.28 7064.64 7016.34 4463.52 2469.34 5984504.09 724072.48 MWD+IFR+MS 9366,24 63.02 18.69 7106.78 7058.48 4541.66 2497.76 5984583.03 724098.58 MWD+IFR+MS 9460.26 63.25 14.48 7149.28 7100.98 4622.02 2521.69 5984664.06 724120.12 MWD+IFR+MS 9554.09 63.15 11.94 7191.59 7143.29 4703.54 2540.82 5984746.11 724136.83 MWD+IFR+MS 9648.19 62.27 6.87 7234.76 7186.46 4786.00 2554.50 5984828.93 724148.06 MWD+IFR+MS 9742.04 62.75 5.26 7278.08 7229.78 4868.79 2563.29 5984911.94 724154.40 MWD+IFR+MS 9834.72 61.98 3.30 7321.07 7272.77 4950.66 2569.42 5984993.95 724158.11 MWD+IFR+MS 9928.00 62.11 3.31 7364.80 7316.50 5032.92 2574,17 5985076.31 724160.42 MWD+IFR+MS 10021.52 64.06 2.35 7407.13 7358.83 5116.20 2578.28 5985159.68 724162.07 MWD+IFR+MS 10114.37 64.07 2.42 7447.74 7399.44 5199.63 2581.76 5985243.16 724163.07 MWD+IFR+MS 10208.30 63.78 1.54 7489.03 7440.73 5283.95 2584.67 5985327.53 724163.49 MWD+IFR+MS 10299.25 63.58 1.64 7529.35 7481.05 5365.44 2586.94 5985409.05 724163.34 MWD+IFR+MS 10393.98 64.41 1.17 7570.89 7522.59 5450.55 2589.02 5985494.18 724162.91 MWD+IFR+MS 10486.32 64.41 0.42 7610.77 7562.47 5533.82 2590.18 5985577.45 724161.60 MWD+IFR+MS 10579.76 63.73 0.39 7651.63 7603.33 5617.85 2590.77 5985661.45 724159.71 MWD+IFR+MS 10672.44 64.80 2.07 7691.87 7643.57 5701.32 2592.57 5985744.93 724159.04 MWD+IFR+MS 10766.47 65.44 2.86 7731.43 7683.13 5786.54 2596.24 5985830.22 724160.18 MWD+IFR+MS 10859.85 65.02 2.87 7770.56 7722.26 5871.22 2600.48 5985914.99 724161.91 MWD+IFR+MS 10953.71 65.04 4.83 7810.18 7761.88 5956.11 2606.19 5986000.00 724165.11 MWD+IFR+MS 11046.95 64.49 4.54 7849.93 7801.63 6040.17 2613.08 5986084.23 724169.51 MWD+IFR+MS 11139.37 64.07 4.22 7890.04 7841.74 6123.19 2619.44 5986167.40 724173.41 MWD+IFR+MS 11233.22 63.79 4.40 7931.29 7882.99 6207.25 2625.77 5986251.61 724177.26 MWD+IFR+MS 11326.55 63.23 4.39 7972.92 7924.62 6290.54 2632.18 5986335.04 724181.19 MWD+IFR+MS 11420.05 62.68 4.39 8015.43 7967.13 6373.57 2638.55 5986418.22 724185.10 MWD+IFR+MS 11514.10 62.62 4.11 8058.64 8010.34 6456.88 2644.74 5986501.67 724188.83 MWD+IFR+MS 11607.19 63.83 3.79 8100.57 8052.27 6539.79 2650.46 5986584.71 724192.10 MWD+IFR+MS 11700.08 64.47 4.05 8141.07 8092.77 6623.19 2656.18 5986668.24 724195.34 MWD+IFR+MS Halliburton Global Company: BP Amoco Date: 6/22!2005 Time: 10:32:27 Patic: 4 Field: Niakuk Co-ordinate(NE) Reference: Well: NK-65, True North ~ Site: NK Main Pad Vertical (TVD) Reference: NK-65A: 48.3 Well: NK-65 Section (VS) Reference: Well (O.OON,O.OOE,19.38Azi) WeJlpath: NK-65A Survey Calculation Method: Minimum Curvature Db: Oracle &irvc~ MD Inc! Azim TVD Sys TVD S/S E/W I ft deg deg ft ft ft ft 11792.95 63.98 4.01 8181.46 8133.16 6706.61 2662.06 11885.23 63.52 3.15 8222.27 8173.97 6789.21 2667.23 11978.25 64.48 3.11 8263.05 8214.75 6872.69 2671.79 12072.05 65.23 4.65 8302.91 8254.61 6957.40 2677.54 12165.18 65.15 4.92 8341.99 8293.69 7041.64 2684.59 12259.88 64.46 4.70 8382.30 8334.00 7127.03 2691.78 12353.47 63.91 4.50 8423.06 8374.76 7211.01 2698.53 12447.33 63.67 4.56 8464.51 8416.21 7294.95 2705.19 12541.79 63.08 4.21 8506.84 8458.54 7379.15 2711.64 12635.04 60.88 4.98 8550.65 8502.35 7461.20 2718.23 12668.53 57.66 6.06 8567.76 8519.46 7489.85 2721.00 12700.11 55.27 6.61 8585.20 8536.90 7516.01 2723.90 12728.92 52.67 7.53 8602.15 8553.85 7539.13 2726.76 12762.21 48.99 8.51 8623.17 8574.87 7564.68 2730.36 12791.01 46.27 8.44 8642.58 8594.28 7585.73 2733.49 12820.31 43.98 9.49 8663.25 8614.95 7606.23 2736.72 12854.43 40.76 10.04 8688.46 8640.16 7628.89 2740.62 12885.75 37.80 10.29 8712.70 8664.40 7648.41 2744.12 12914.03 35.07 9.48 8735.45 8687.15 7664.95 2747.00 12948.08 31.97 7.72 8763.83 8715.53 7683.54 2749.83 12979.60 29.38 5.85 8790.94 .8742.64 7699.50 2751.74 13007.02 27.03 5.08 8815.10 8766.80 7712.40 2752.97 13041.02 22.71 5.02 8845.94 8797.64 7726.64 2754.23 13072.98 19.29 4.38 8875.77 8827.47 7738.05 2755.18 13101.46 17.96 5.11 8902.76 8854.46 7747.12 2755.93 13194.74 13.64 12.02 8992.50 8944.20 7772.21 2759.50 13287.52 12.55 12.09 9082.87 9034.57 7792.77 2763.89 13380.61 11.19 11.34 9173.97 9125.67 7811.52 2767.78 13473.91 11.69 11.58 9265.41 9217.11 7829.65 2771.46 13567.05 12.15 13.59 9356.55 9308.25 7848.42 2775.66 13660.80 10.88 13.94 9448.41 9400.11 7866.60 2780.11 13725.76 9.95 14.52 9512.30 9464.00 7877.99 2782.99 13779.84 12.82 14.27 9565.31 9517.01 7888.33 2785.64 13873.88 13.52 15.44 9656.87 9608.57 7909.03 2791.14 13967.69 13.48 12.99 9748.09 9699.79 7930.26 2796.52 14059.83 12.95 11.38 9837.79 9789.49 7950.84 2800.97 14143.86 11.65 12.38 9919.89 9871.59 7968.36 2804.65 .~ 14208.00 11.65 12.38 9982.71 9934.41 7981.01 2807.42 MapN MapE Tool ft ft 5986751.79 724198.75 MWD+IFR+MS 5986834.51 724201.47 MWD+IFR+MS 5986918.08 724203.56 MWD+IFR+MS 5987002.92 724206.80 MWD+IFR+MS 5987087.33 724211.36 MWD+IFR+MS 5987172.89 724216.02 MWD+IFR+MS 5987257.03 724220.28 MWD+IFR+MS 5987341.13 724224.45 MWD+-FR+MS 5987425.48 724228.41 MWD+IFR+MS 5987507.68 724232.57 MWD+IFR+MS 5987536.40 724234.48 MWD+IFR+MS 5987562.64 724236.61 MWD+IFR+MS 5987585.83 724238.79 MWD+IFR+MS 5987611.47 724241.63 MWD+IFR+MS 5987632.60 724244.14 MWD+IFR+MS 5987653.19 724246.76 MWD+IFR+MS 5987675.96 724249.99 MWD+IFR+MS 5987695.57 724252.91 MWD+IFR+MS 5987712.19 724255.30 MWD+IFR+MS 5987730.85 724257.57 MWD+IFR+MS 5987746.86 724259.01 MWD+IFR+MS 5987759.79 724259.86 MWD+IFR+MS 5987774.06 724260.70 MWD+IFR+MS 5987785.50 724261.31 MWD+IFR+MS 5987794.58 724261.79 MWD+IFR+MS 5987819.77 724264.62 MWD+IFR+MS 5987840.45 724268.40 MWD+IFR+MS 5987859.30 724271.73 MWD+IFR+MS 5987877.53 724274.87 MWD+IFR+MS 5987896.42 724278.51 MWD+IFR+MS 5987914.72 724282.42 MWD+IFR+MS 5987926.18 724284.97 MWD+IFR+MS 5987936.60 724287.31 MWD+IFR+MS 5987957.46 724292.20 MWD+IFR+MS 5987978.83 724296.94 MWO+IFR+MS 5987999.54 724300.78 MWD+IFR+MS 5988017.16 724303.94 MWD+IFR+MS 5988029.88 ' 724306.34 -PROJECTED to TD 4" CMJ WCiLHEAD = 11" - 5M FMC GEN. 5 ACTUATOR = BAKER KB. ELEV = 48.4' BF. ELEV = 19.8' KOP = 2000' Max Angle = 65 Datum MD = 14122' Datum TV D = 9850' SS HIV K-65A F i na I SAI~NOTES: DRLG DRAFT 2105' I-i 4-1/2" HES HXO NIPPLE 9-5/8" CSG, 40#, L-80, ID = 8.835" 6244' Minimum ID = 3.725" @ 13710' 4-1 /2" XN NIPPLE 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 8357' PERFORATION SUMMARY REF LOG: SWS-ANADRILL MEASURED DEPTH ANGLE AT TOP PERF: 12@ 14108' Note: Refer to Production DB for historical pert data 8513' -~ 7" Window Tcp d GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4537 4003 45 KBG2-1R DMY BEK-2 0 5/25/2005 2 6763 5497 48 KBG2-1R DMY BK 0 5/25/2005 1 8211 6476 47 KBG2-1R DMY BK 0 5/25/2005 8279' 4-1/2" HES X NIP, ID = 3.813" 8300' 7" X 4-1/2" BAKER S-3 PKR ID = 3.875" 8323' 4-1/2" HES X NIP, ID = 3.813" 8344' 4-1/2" HES X NIP, ID = 3.813" 8355' 4-1/2" TUBING TAIL WLEG 8342' 4 1/2" Liner hanger /packer TOP OF 4-1/2" LNR 12630' ~ '~" .m 7" CSG, 26#, L-80, ID = 6.276" 12800' ,, " " ' 4 112 XN Nipple, ID = 3.725 13710 _ ~ PBTD 13752' SHOE JOINT MILLED OUT TO 3.625"; PBTD 14175' CTM 4 1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13840' ~ 4 1/2" LNR 12.6#, L-80, ID = 3.958" PBTD 14144' TOP OF LANDING COLLAR 14144' 4 111" FLOAT SHOE 14208' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/18/98 ORIGINAL COMPLETION 05!25/05 RWL/PJC GLV GO 01/22/01 SIS-Isl CONVERTEDTOCANVAS 06/07/05 JAFITLH MILL SHOE JOINT 03/08/01 SIS-LG FINAL 06/21/05 VFIPJC DATUM TVD/MDCORRECTION 03/23/03 JMP/KK WANER SAFETY NOTE REV. 08/08/05 NBF/PJC PERFORATION 04/19/05 PGS Proposed Sidetrack Completion 05/16!05 CRM Sidetrack Camp(etion NIAKUK UNIT WELL: NK-65A PERMff No: 205-063 API No: 50-029-22869-01 SEC 36, T12N, R15E, 1429' FSL & 823' FEL BP 6cploration (Alaska) • • 09-Jul-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well NK-65A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,454.44' MD Window /Kickoff Survey: 8,513.00' MD (if applicable) Projected Survey: 14,208.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 I Date ~~~~ ~d~,~` Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(sj ~1 -- i~V3 ~~ 9 g ALASSA OIL AHD GAS COI~TSERQA~'IOH CODil-II5SIOH Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay NK-65A BP Exploration (Alaska) Inc. Permit No: 205-063 FRANK H. MURKOWSKI, GOVERNOR Py 1 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ' PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 1429' FSL, 823' FEL, SEC. 36, T12N, R15E, UM Bottomhole Location: 4165' FSL, 1988' FWL, SEC. 30, T12N, R16E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above development well. Permission to begin injection operations in this well is contingent on adding the Niakuk Ivishak- Sag River reservoir to the strata authorized for injection by Area Injection Order No. 14A. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. P s provide at least twenty-four (24) hours notice for a representative of the Commission wi ess any required test. Contact the Commission's petroleum field inspector at (909- 607 ger). DATED this~ay of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~, ~.t~~- 4- l t5 1205 STATE OF ALASKA ~ ~ ~' ~~-' os ALASk OIL AND GAS CONSERVATION COMMISSION ~~ V E~ PERMIT TO DRILL APR ~ 2 205 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current W ell Class ^ Exploratory ^ Devejgp~~t~~ ~1~~ 0@11111 ^ Stratigraphic Test ®Service ~ ^ Dev t Ingle Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Singie Well Bond No. 2S100302630-277 11. WeN Name an NK-65A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14280 TVD 9991 12. Field /Pool(s): Prudhoe Bay Field / Niakuk Pool 4a. Location of Well (Governmental Section): Surface: 1429' NSL 823' WEL SEC 36 T12N R15E UM 7. Property Designation: ADL 034635 , , . , , , Top of Productive Horizon: 4051' NSL, 1926' EWL, SEC. 30, T12N, R16E, UM 8. Land Use Permit: 13. Approximate ~ptid Date: April 26;f2005 Total Depth: 4165' NSL, 1988' EWL, SEC. 30, T12N, R16E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1100' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 721736 y- 5979969 Zone- ASP4 10. KB Elevation (Height above GL): 48.3' feet 15. Distance to Nearest Well Within Pool NK-38A at 2600"~ 16. Deviated Wetls: Kickoff Depth: 8500 feet Maximum Hole Angle: 67 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4900 Surface: 4000 ~ 18. Casing rogram: Size. Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 6-1/8" 4-1/2" 12.6# L-80 H dril 521 5930' 8350' 6580' 14280' 9991' 39 sx LiteCrete, 152 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed forRedriU AND Re-entry Qperations) Total Depth MD (ft): 14520 Total Depth TVD (ft): 9396 Plugs (measured): None Effective Depth MD (ft): 13752 Effective Depth TVb (ft): 9296 .Junk (measured): None Casin Len th Size Cement Volume MD TVD r r nd r 75' 20" 60 sx Arcticset A rox. 1 f 5' 115' rf 6205' 9-5/8" 283 sx PF 'E', 350 sx Class 'G' 6244' 5160' In rm i 12764' 7" 00 sx Class 'G' 12800' 9280' Pr i L'n 1210' 4-1/2" 190 sx Class 'G' 12630' - 13840' 9215' - 9301' Perforation Depth MD (ft): 12780' - 13060' Perforation Depth TVD (ft): 9272' - 9293' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name ~o%tr~- ~~;~,~ Title ,~,-,~~;,a ,(~rz.lr'e„ . ~~.; ~ Prepared By Name/NUmber: Si nature / ~-~~~~~~-~~~~ Phone .~~~j ~%/ F,, Date Y' /a ~~- Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: API Number: 50- 029-22869-01-00 Permit Approval Date: ~ / -; l~ See cover letter for other requirements Conditions of Approval: Sample equired 'Yes '_~ No Mud Log Required ~' Yes ~'No Hydr a ulfide Measures Yes `,~ No Directional Survey Required les ~_ No Other: T-~P )~ 1~ S C~ D ~ ~ /~ r T C..t r+~ ~ ~ ~ u,.~,(,c ~,7 ~; h~ f ut ~ ~ , P-~~r L ~ Z S ~- (r~, ~ ~ ~ l I~I~~ ff ~ a.~ ~-rYt.~- ~ ~~~c.i[~r 5~~}~~rr~~ ~t-1,L iS ~7rY~Jf . APPROVED BY h THE COMMISSION ~ ~~ A roved B : Date on Form 10-401 lved~ed ~~ "°~°' '-~ ~ ~ Via' ~ ~~.,M e~~~~'1S~ bmit In l~iplicate • • Well Name: NK-65A Drill and Complete Plan Summary Due to the 7" casing currently in the well and limitations with rotary drilling tools only as small as 4 3/a" OD, only asingle-string sidetrack is feasible to achieve this targeted injection point. The '~ deepest possible kick-off depth (without unacceptable wellbore collision risk) has been chosen. Furthermore, no other wells in the area can reasonably be sidetracked to achieve the target. The resulting planned completion employs a 6000' long 4'/z" liner from the sidetrack depth in the Ugnu through the Ivishak target depth. The production packer then must be positioned .~. roughly vertical 3000' above the reservoir top..~~gSO' tina To ensure the wellbore integrity in the absence of an annulus extending to the top of the reservoir, special considerations for the liner will be employed: 1. A premium liner connection will ensure liner mechanical integrity against leaks. ~ ¢I ~ (~~~ 2. The liner annulus will be fully cemented with alight-weight, high compressive strength lead cement, followed by 1000 annular feet of 15.8 ppg class G slurry. ~~ 3. An XN-nipple profile will be positioned in the liner just above the perforations to allow for ,/~ future pressure-testing plugs. T e of Well service / roducer / in'ector : Conventional Sidetrack In'ector Surface Location: X = 721,736.3 Y = 5,979,969.7 r 1429' FSL 823' FEL Sec. 36, T12N, R15E Umiat Target Location: X = 724,250.0 Y = 5,987,950.0 TVDss 9,420' TSAG 1229' FNL 1926' FWL Sec. 30, T12N, R16E Umiat Bottom Hole Location: X = 724,308.0 Y = 5,988,066.0 TVDss 9,943' Kavik 1114' FNL 1988' FWL Sec. 30, T12N, R16E Umiat ~ AFE Number: NED5L0545 Ri Nabors 2ES Estimated Start Date: 4/26/05 O eratin da s to com lete: 21.3 MD: 14,280' TVD: 9,991' GL: 19.8' KB: 28.5' KBE: 48.3' Well Desi n conventional, slimhole, etc.: Sin le-Strin Conventional Sidetrack Ob'ective: Ivishak water in'ector to su ort NK-38A NK-65A Permit to Drill Page 1 Formation Markers Formation Tops wp09 MD TVD TVDss Comments SV1 5078 -5030 TW SK 8768 6838 -6790 CM3 10,122 7388 -7340 CM1 12,561 8448 -8400 K3 13,000 8778 -8730 HRZ 13,300 9038 -8990 TKUP 13,510 9243 -9195 Ku aruk ma be 0-20' thick, normal res. TKNG 13,516 9253 -9205 TSGR 13,742 9468 -9420 10.0 PPG EMW ~ TSHU 13,823 9547 -9499 TSAD 13,882 9604 -9556 TZ2A2 14,102 9818 -9770 TZ2A1 14,124 9839 -9791 9.7 PPG EMW TZ1B 14,175 9892 -9844 TKVK 9918 -9870 TD 9991 -9943 TLSB 10,036 -9988 Base Lisburne @ -10,081' TVDss TD Criteria: TD will be picked by the well hole is needed to erf well to base of Ivis site geologist in collaboration with the town Geologist. Sufficient rat- hak. ,Directional KOP: 8500' MD Maximum Hole Angle: --67° in the up-hole section --14° in the 6-1/8" reservoir section Close Approach Wells: All wells pass major risk criteria for the planned sidetrack and pilot hole. The closest well NK-38A at 254' ctr-ctr distance and 49' allowable deviation at 10,590' tanned MD. Surve Pro ram: MWD Standard + IIFR /Cassandra Nearest Pro ert Line: 1100' to then e t lease line (open lease) Nearest Well within Pool: NK-38A @ 0 (closest well in reservoir section, excluding P&A wells) Area of Review No wells lie ithin the 1/4 mile area of review for this injector. The closest well is the vertical, abandoned wellbore of NK-04 at 2175' from the planned NK-65A Ivishak tar et at -9900' TVD. Casing/Tubing Program Hole Size Csg/Tbg WUFt Grade Conn Length Top Btm O.D. / ~ MD/TVD MD/TVD 6-1/8" 4-1/2" 12.6# L-80 H dri1521 5,930' 8,350/6,580' 14,280'/9,991' Tubin 4-1/2" 12.6# L-80 IBT-M 13,565' GL 13,594'/9,325' Mud Program Section Milling Mud Properties: LSND Whip Stock Window 7", 26# Densit Viscosit PV YP TauO MBT PH 11.4 45-55 15-22 28-35 3-5 <20 9.0-9.5 Open Hole Mud Properties: LSND ~ 6 1/8" hole section Densi ~ Viscosit PV YP TauO MBT PH 1.4 38-45 15-22 22-30 2-4 <20 9.0-9.5 tt.4 ?',~w~, NK-65A Permit to Drill Page 2 • Logging Program • 6-1/8" U Hole: Drillin Dir/GR/Res/Neu Open Hole: None Cased Hole: None 6-1/8" Reservoir: Sample Catchers -over entire section at 20' intervals Drillin Dir/GR/Res/Neu O en Hole: None Cased Hole: Post Ri : USIT RST, Tem ,Static Cement Program Casin S ize 4.5" 12.6#, L-80 Production Liner Basis: Lead: None 4-1C, Tail: Based on 80' shoe track, 5780' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X T' Liner Lap, and 200' of T' X 4" DP excess. OC: 8,350' MD (Top of Liner) Total Cement Volume: Lead 120 bbls, 674 ft3, 3 cks LiteCrete ~ 13.0 3/sk Tail 32.5 bbls, 183ft3, acks Class G ~ 15.8 pp 3/sack Well Control z ~ Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. 4 Diverter, ROPE and drilling fluid system schematics on file with the AOGCC. Ivishak Interval Maximum antici ated BHP 4900 si ~ 9420' TVDss 10.0 EMW Maximum surface ressure 4000 si .10 si/ft as radient to surface Kick tolerance Infinite with a 13 FIT Planned BOP test pressure Rams test to ,50 psi/250 psi. Annular test ,500 si/250 si 7" Casin Test 4000 si surface ressure Inte rit Test - 6-1/8" hole 13.0 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Un erforated Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. NK-65A Permit to Drill Page 3 • • Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. RU Slickline and drift to PBTD at 13,752' 2. Run PDS caliper log from production packer depth of 12,473' MD to surface 3. Fluid pack as necessary for cement plug. 4. R/U and RIH with coil tubing and spot cement from PBTD to 100' above the uppermost pert (cement volume = 16 bbls). 5. R/U E-line. If the PDS caliper indicates good to fair tubing below 8700' MD, cut the tubing in the first full joint above the packer, else cut at 8700' MD. 6. Displace the well to clean seawater by circulating down the tubing through the cut tubing. 7. Perform CMIT TxIA to 4000 psi. Freeze protect to 2,100' MD with diesel. 8. Bleed casing and annulus pressures to zero. 9. Cycle the tubing hanger LDS. 10. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVlTWC. 3. Nipple down tree. Nipple up and test BOPE to 4,OOOpsi. Pull BPV/TWC. 4. R/U. Pull 4 ~/z" tubing from the pre-rig tubing cut. 5. RIH w/ GR/JB on a-line to 8600' MD. 6. RIH with 7" bridge plug and set at ±8520' to allow fora 8500' whipstock KOP. 7. Pressure-test the 9 5/8" casing to 4000psi for 30 minutes. Record test. 8. P/U and RIH with T' Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 11.4 ppg LSND milling /drilling fluid. Completely displace the well prior to beginning milling operations. -~,,,~~ to - 4oj 10. Mill window in 7" casing at ± 8,500' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. t~Pw ~`~~• 11. Pull up into 9 5/8" casing and conduct an FIT to 13.0 ppg EMW. POOH. ~ 12. M/U 6 1/8" Dir/GR/Res assembly. 13. RIH, drill build intermediate section and trip for new bit in or after drilling Tuffs. 14. POH, add Neu/Den to LW D. Continue 6 1/8" section to TD. 15. Circulate, short trip, spot liner running pill, POOH. 16. Run and cement a 4'/z", 12.6#, L-80 solid production liner. / 17. Set liner top packer, circulate the well to seawater, test to 4000 psi. POOH UD all drill pipe. ~' 18. R/U and run 4 1/2", 12.6#, L-80 completion tubing. Land the tubing RILDS. 19. Set a TWC and test to 1000 psi 20. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 21. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 4,OOOpsi 30 minutes. Record each test. ~" 22. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 23. Rig down and move off. Post-Ria Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. RU coiled tubing and~t'eanout the drilling mud from the liner and provide at least 50' rat hole. 4. RU a-line, run USIT, perforate, run static pressure survey and baseline temp, RST and jewelry log. 5. Perform two step rate tests. / 6. Place well on water injection. NK-65A Permit to Drill Page 4 • w NK-65A Drilling Program Job 1: MIRU Hazards and Contingencies - NK-65 is near the northeastern corner of the pad with NK-18 on 15' center on the pad entrance side and NK-19A on 10' center to ocean side. Both NK-18 and NK-19A will require shut-in and wellhouse removal. Remove the actuator valve from NK-19A. The wells should be shut-in at the surface and the SSSV, and all surface flowlines and gas lift lines depressurized to header pressure. Also remove wellhouses from NK-17, NK-38A, and NK-43. - Niakuk is signated as an HZ.S site. Recent H2S data from the pad is as follows: Well Name H2S Readin Date #1 Closest SHL NK-18 0 m 7/10/01 #2 Closest SHL NK-19A m 1/4!05 #1 Closest BHL NK-62 20 m 1/26/05 #2 Closest BHL NK-38A -- m 3/31/05 The maximum on the pad is NK-62 at 200 ppm on 1/26/05. - Post Permit to Drill in the dog house and camp prior to spud Reference RP • "Drilling/VNork-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-comalete Well Hazards and Contingencies - NORM test all retrieved well head and completion equipment. - Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP • "De-completions" RP Job 4: Window Mill Hazards and Contingencies - Once milling is complete, make sure all BOP equipment is operable.. Wash out BOP stack to remove any metal cuttings, which may have settled there. / - The 7" casing was cemented with 46 bbls of class G at 15.8 ppg. TOC with USIT was marked at 11,730' MD. Expect no cement at the window depth. Reference RP • "Whipstock Sidetracks" RP • "Leak Off and Formation Integrity Tests" SOP NK-65A Permit to Drill Page 5 • • Job 7: Drill 6-1/8" Intermediate and Reservoir Sections Hazards and Contingencies - The well trajectory passes just over the recently drilled NK-38A; watch for indications of close approach. Discontinue drilling immediately and contact the Drilling Manager if the wellbore placement trends toward outside of the established tolerance. - The well is planned to drill into the Kavik far enough to see TKVK on LW D. Avoid drilling into the Lisburne formation. - The wellplan crosses no faults. All faults die upward below the HRZ. After drilling through the HRZ, the wellbore is designed to stay -250 to 300' away from all faults. - TD will be picked by the wetlsite geologist in collaboration with the town Geologist. TD well sooner if northern fault is encountered early, as evident by Kingak, Sag or Shublik. TD may be called earlier if drilling conditions are poor and at least 500' of the north fault block is drilled. - KICK TOLERANCE: In the worst-case scenario of 10.0 ppg pore pressure in the Kuparuk, a fracture gradient of 12.5 ppg at the 7" casing shoe, and 11.4 ppg mud in the hole, the kick /~~ tolerance is 54 bbls. Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Shale Drilling, Kingak and HRT' RP • "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies - Shouldered connections and a rotatable liner assembly will be employed to help get liner to bottom. Rotate and circulate in the open hole only if necessary. - Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will need to be run to extend --150' back up into the 7" intermediate liner. - Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs • "Production Liner/Casing and Cementing Guidelines" • Sch/umberger Cement Program NK-65A Permit to Drill Page 6 • • Job 10: DPC Perforate Production Casina Hazards and Contingencies - Observe Schlumberger's safety procedures while running in and out of hole with pert guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs • Follow Schlumberger perforating practices and recommendations. • "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Job 13: ND/NU/Release Ria Hazards and Contingencies - See Job 1 for adjacent well spacing. These are close weii centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. Reference RP • "Freeze Protecting an Inner Annulus" RP NK-65A Permit to Drill Page 7 TREE- 4 CNV WELLHEAD= 11"- 5M FMC GEN. S ACTUATOR= BAKER K8. REV = 60.26' BF. REV = 26.46' KOP= 2000' Max Angle = 91 @ 13162' Datum MD = 11791' Datum N D = 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" 6244' Minimum ID = 3.725" @ 12558' 4-1 /2"HES XN NIPPLE I 7" X 4-1 /2" BAKER S-3 FKR, ID = 3.875" I 12538' I--I 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" H 12580' TOP OF 41/2" LNR 12630' 7" CSG, 26#, L-80, ID = 6.276" H 1 PB~FORATION SUMMARY REF LOG: SW SA NA DRILL MEA SURED DEPTH ON 05/01 /98 ANGLEATTOP FERF 91 @ 12950' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DOTE 2-7/8" 6 12950-13060 O 05J13hJ8 2-7/8" 6 12780-12950 O 03/23/01 N K-65 / SAFETY NOTES: LINB2 IS HORIZONTAL @ 12873'. *" RAPS TBGX IA COMM.OPB2ATING PRESSUREOF THE9-5/8" ANNULUS MUST NOT IXCB'D2500 PSI'** 445' TBG LEAK (05!02/02) 209T 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DA 12462' I-1 4-1/2" HES X NIP, ID = 3.813" ~ 12558' N 4-1/2" XN NIP HES, ID= 3.725" 12580' 4-1/2" TUBING TAIL WL~ 12601' ELMD TT LOG UNAVAILABLE 12644' 7" X 5" BAKER LNR HGR PBTD 13752' F-- 4 1/7' LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" 13840' DATE REV BY COMMBJTS DATE REV BY COMMENTS 05/18/98 ORIGINAL COMPLETION 03/23/03 JMPACK WANERSAFETY NOTE REV. 01/22/01 Sly-Isl CONVERT® TO CANVAS 03ro8/01 SIS-LG FINAL 10/04/01 RN/TP CORRECTIDNS 05/02/02 JDM/KK TBG LEAK 10/10/02 JALlKK WANfft SAFETY NOTE NIAKUK UNIT WELL NK-65 PfftMfT No: 1980480 API No: 50-029-22869-00 SEC 36, T12N, R15E, 1429' FSL & 823' FEL BP E~loration (Alaska) ' TREE _. 4" CM! NOTES: K-65A Proposed /y WELLHEAD = 11" - 5M FMC GEN. 5 ACTUATOR= BAKER _~. KB. ELEV = 60.26' BF. ELEV - 26.46' KOP = 2000' Max Angle = 65 Datum MD = Datum TV D = 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" 6244' 4-1/2" 7BG, 12.6#, L-80, 0.0152 bpf, ID= 3.958" 8354' PERFORATION SUMMARY REF LOG: SWS-ANA DRILL MEASURED DEPTH ANGLE AT TOP PERT: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 6 12780-13060 S Minimum ID = 3.725" 4-1/2" HES XN NIPPLE TOP OF4-1/2" LNR 12630' ' 7" CSG, 26#, L-80, ID = 6.276" ~ 12800' PBTD 13752' 4 1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 13840' 2100' 4-1/2" HES HXO NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 1" BL 4 1" 3 1" 2 1" 1 1" 8295' 4-1/2" HES X NIP, ID = 3.813" 8305' 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 8320' 4-1/2" HES X NIP, ID = 3.813" 8342' 4-1/2" HES X NIP, ID = 3.813" 8354' 4-1/2" TUBING TAIL WLEG 8350' 4 1/2" Liner hanger /packer 8500' 7" Window $S Za 4 1/2" XN Nipple ~-~ 13700' 4 112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 14,280' DATE REV BY COMMENTS DATE REV BY COMMENTS 05/18/98 ORIGINAL COMPLETION 03/23/03 JMP/KK WANER SAFETY NOTE REV. 01/22/01 SIS-Isl CONVERTED TO CANVAS 03/14/05 PGS Proposed Sidetrack Completion 03/08/01 SIS-LG FINAL 10/04/01 RN/TP CORRECTIONS 05/02/02 JDM/KK TBG LEAK 10!10/02 JAL/KK WANER SAFETY NOTE NIAKUK UNff WELL: NK-65A PERMff No: 1980480 API No: 50-029-22869-00 SEC 36, T12N, R15E, 1429' FSL & 823' FEL BP Exploration (Alaska) S err -Sun P Y BP Planning Report Company: BP Amoco Date:'.. 3/23/2005 Time: 10:26`.23 Page: 1 Field: Niakuk Co-ordinate(NE) licference: .Well: NK-65, True North Site: NK Main Pad Vertical (TVD) Refere~nee: 19.8 + 28.5 48.3 Well: NK-65 y'i'ellpath: Plan NK-65A Section ('1'S) Reference: Survey Cakulafion Method:.. Well (O.OON,O.OOE,19.32Azi) Minimum Curvature Db: Oracle Plan: NK-65A WP09 Date Composed: 6/30/2004 Version: 32 Principal: Yes Tied-to: From: Definitive Path Field: Niakuk North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre. Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: NK Main Pad TR-12-15 UNITED STATES :North Slope Site Position: Northing: 5981257.79 ft Latitude: 70 21 5.879 N From: Map Easting: 714553.26 ft Longitude: 148 15 27.984 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: .1.64 deg Well: NK-65 Slot Name: NK-65 Well Position: +N/-S -1493.36 ft Northing: 5979969.66 ft Latitude: 70 20 51.158 N +E/-W 7143.64 ft Easting : 721736.39 ft Longitude: 148 11 59.242 W Position Uncertainty: 0.00 ft Casing Points MD TVll Diameter Hole Size Name ft ft in in 13741.57 9468.30 5.500 6.125 51/2" 14280.00 9990.80 3.500 4.750 3.5 Formations NID TVU Formations Lithology Dip Angle llip Direction ft ft deg deg 0.00 SV1 0.00 0.00 8768.26 6838.30 TWSK 0.00 0.00 10122.27 7388.30 CM3 0.00 0.00 12561.38 8448.30 CM1 0.00 0.00 13028.54 8778.30 K3 0.00 0.00 13300.48 9038.30 THRZ 0.00 0.00 13510.77 9243.30 TKUP 0.00 0.00 13515.90 9248.30 TKNG 0.00 0.00 13741.57 9468.30 TSGR 0.00 0.00 13822.81 9547.30 TSHU 0.00 0.00 13881.57 9604.30 TSAD 0.00 0.00 14102.18 9818.30 TZ2A2 0.00 0.00 48.30 48.30 TZ2A1 0.00 0.00 48.30 48.30 TZ16 0.00 0.00 48.30 48.30 TKVK 0.00 0.00 48.30 48.30 Top Lisburne 0.00 0.00 Targets Map Map <--- Latitude ---> <--- Longitude ---> Name Description TVD +N/-S +E/-W" Northing Easting Dcg Min Sec Deg Min Sec llip. Dir. ft ft ft ft ft N K-65A W I T1 9468.30 7902.84 2748.79 5987950.01 724250.05 70 22 8.877 N 148 10 38.836 W -Plan hit target NK-65A WI T2 9918.30 8001.32 2801.73 5988050.01 724300.05 70 22 9.845 N 148 10 37.286 W -Plan hit target ,. Sperry-Sun BP Planning Report Company: BP Amoco Date: 3/23/2005 Time: 10:26:23 Page: 2 Field: Niakuk Co-ordinate(N~) Reference: Well: NK-65, True North Site: NK Main Pad Vertical (TVD) Reference: 19.8 + 28.5 48.3 N'e11: NK-65 Section (VS) Kcfcrence: WeI((O.OON,O.OOE,19.32Azi) Wellpath: Plan NK-65A Survey Calculation Method: Minimum Curvature Db: Oracle Ylan Section Information r- -~ Mll ]ncl Azim TVD +V/-S +E/-R' DLS Build Turn TFO 7-arhet ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8500.00 45.67 31.86 6679.96 3885.85 2132.11 0.00 0.00 0.00 0.00 8520.00 48.07 31.86 6693.64 3898.25 2139.81 12.00 12.00 0.00 0.00 8910.00 67.57 31.86 6900.33 4177.26 2313.21 5.00 5.00 0.00 0.00 9110.00 67.57 31.86 6976.64 4334.28 2410.79 0.00 0.00 0.00 0.00 9760.00 66.90 3.63 7232.55 4897.48 2591.39 4.00 -0.10 -4.34 -97.00 9838.60 64.25 1.78 7265.05 4968.95 2594.77 4.00 -3.38 -2.35 -147.98 12541.48 64.25 1.78 8439.41 7402.21 2670.32 0.00 0.00 0.00 0.00 13189.40 12.80 15.00 8930.00 7790.00 2700.00 8.00 -7.94 2.04 176.30 13238.09 12.87 23.77 8977.48 7800.18 2703.58 4.00 0.15 18.01 92.10 13741.57 12.87 23.77 9468.30 7902.84 2748.79 0.00 0.00 0.00 0.00 NK-65A Wl T1 13761.57 12.87 23.77 9487.80 7906.92 2750.59 0.00 0.00 0.00 0.00 13802.65 14.06 28.66 9527.75 7915.49 2754.83 4.00 2.89 11.90 46.20 14205.27 14.06 28.66 9918.30 8001.32 2801.73 0.00 0.00 0.00 0.00 NK-65A WI T2 14280.27 14.06 28.66 9991.05 8017.31 2810.47 0.00 0.00 0.00 0.00 Survey JID [ncl Azim TVD S~°sI~D V'/S ~~ E/~i~ llLS MapA ~1apE Tool/Comment ft deg deg ft ft ft ft deg/100ft ft ft 48.30 0.15 148.20 48.30 0.00 -0.02 0.01 0.00 5979969.64 721736.41 Top Lisburne 8500.00 45.67 31.86 6679.96 6631.66 3885.85 2132.11 0.54 5983916.72 723752.51 MWD+IFR+MS 8520.00 48.07 31.86 6693.64 6645.34 3898.25 2139.81 12.00 5983929.34 723759.84 MWD+IFR+MS 8548.30 49.49 31.86 6712.28 6663.98 3916.33 2151.05 5.00 5983947.74 723770.54 Start Dir 12?/1 8568.30 50.49 31.86 6725.14 6676.84 3929.34 2159.13 5.00 5983960.98 723778.23 Start Dir 5?/10 8600.00 52.07 31.86 6744.97 6696.67 3950.34 2172.19 5.00 5983982.36 723790.66 MWD+IFR+MS 8700.00 57.07 31.86 6802.92 6754.62 4019.53 2215.18 5.00 5984052.79 723831.59 MWD+IFR+MS 8768.26 60.48 31.86 6838.30 6790.00 4069.10 2245.99 5.00 5984103.25 723860.91 TWSK 8800.00 62.07 31.86 6853.55 6805.25 4092.74 2260.68 5.00 5984127.31 723874.90 MWD+IFR+MS 8848.30 64.49 31.86 6875.27 6826.97 4129.38 2283.45 5.00 5984164.61 723896.57 End Dir :8800 8900.00 67.07 31.86 6896.48 6848.18 4169.42 2308.34 5.00 5984205.37 723920.26 MWD+IFR+MS 8910.00 67.57 31.86 6900.33 6852.03 4177.26 2313.21 5.00 5984213.34 723924.90 MWD+IFR+MS 9000.00 67.57 31.86 6934.67 6886.37 4247.92 2357.12 0.00 5984285.27 723966.70 MWD+IFR+MS 9048.30 67.57 31.86 6953.10 6904.80 4285.84 2380.69 0.00 5984323.87 723989.13 Start Dir 4?/10 9100.00 67.57 31.86 6972.83 6924.53 4326.43 2405.91 0.00 5984365.18 724013.14 MWD+IFR+MS 9110.00 67.57 31.86 6976.64 6928.34 4334.28 2410.79 0.00 5984373.18 724017.79 MWD+IFR+MS 9200.00 67.18 27.98 7011.28 6962.98 4406.26 2452.22 4.00 5984446.35 724057.07 MWD+IFR+MS 9300.00 66.85 23.65 7050.34 7002.04 4489.11 2492.30 4.00 5984530.34 724094.68 MWD+IFR+MS 9400.00 66.65 19.30 7089.83 7041.53 4574.58 2525.94 4.00 5984616.76 724125.77 MWD+IFR+MS 9500.00 66.56 14.95 7129.55 7081.25 4662.26 2552.95 4.00 5984705.20 724150.18 MWD+IFR+MS 9600.00 66.60 10.59 7169.32 7121.02 4751.72 2573.22 4.00 5984795.22 724167.79 MWD+IFR+MS 9700.00 66.75 6.23 7208.93 7160.63 4842.53 2586.65 4.00 5984886.39 724178.52 MWD+IFR+MS 9760.00 66.90 3.63 7232.55 7184.25 4897.48 2591.39 4.00 5984941.45 724181.64 MWD+IFR+MS 9773.76 66.44 3.31 7238.00 7189.70 4910.09 2592.15 4.00 5984954.08 724182.03 End Dir :9725 9800.00 65.55 2.70 7248.67 7200.37 4934.03 2593.41 4.00 5984978.04 724182.57 MWD+IFR+MS 9838.60 64.25 1.75 7265.05 7216.75 4968.95 2594.77 4.00 5985012.99 724182.91 MWD+IFR+MS 9900.00 64.25 1.78 7291.73 7243.43 5024.23 2596.49 0.00 5985068.29 724182.99 MWD+IFR+MS 10000.00 64.25 1.78 7335.17 7286.87 5114.26 2599.29 0.00 5985158.35 724183.12 MWD+IFR+MS 10100.00 64.25 1.78 7378.62 7330.32 5204.28 2602.08 0.00 5985248.42 724183.25 MWD+IFR+MS 10122.27 64.25 1.78 7388.30 7340.00 5224.33 2602.70 0.00 5985268.48 724183.28 CM3 10200.00 64.25 1.78 7422.07 7373.77 5294.31 2604.87 0.00 5985338.48 724183.38 MWD+IFR+MS 10300.00 64.25 1.78 7465.52 7417.22 5384.33 2607.67 0.00 5985428.54 724183.51 MWD+IFR+MS 10400.00 64.25 1.78 7508.97 7460.67 5474.35 2610.46 0.00 5985518.61 724183.64 MWD+IFR+MS 10500.00 64.25 1.78 7552.42 7504.12 5564.38 2613.26 0.00 5985608.67 724183.77 MWD+IFR+MS 10600.00 64.25 1.78 7595.86 7547.56 5654.40 2616.05 0.00 5985698.74 724183.90 MWD+IFR+MS 10700.00 64.25 1.78 7639.31 7591.01 5744.43 2618.85 0.00 5985788.80 724184.03 MWD+IFR+MS 10800.00 64.25 1.78 7682.76 7634.46 5834.45 2621.64 0.00 5985878.86 724184.16 MWD+IFR+MS S err -Sun p Y BP Planning Report Company: BP Amoco Date: 3/2312005 Ti me: 10:26:23 Page: 3 Field: Nia kuk Co-ord inate(nE) Reference: Well: NK-65, T rue North Site: NK Main Pad Vertical (TVD) Reference: 19.8 + 2g.5 48 :3 ~'Vcll: NK -65 Section (VS) Reference: Well (O:OON,O.OOE,19.32Azi) Wellpath: Pla n NK-65A Survey Calculation Dlethod: Minimum Curvature Db: Oracle Survey b1D lncl Azim I'VD Sys TVD ~lS E/W DLS MapN MapE TooilComment ft deg deg ft ft ft ft deg/100ft ft ft 10900.00 64.25 1.78 7726.21 7677.91 5924.48 2624.44 0.00 5985968.93 724184.29 MWD+IFR+MS 11000.00 64.25 1.78 7769.66 7721.36 6014.50 2627.23 0.00 5986058.99 724184.42 MWD+IFR+MS 11100.00 64.25 1.78 7813.11 7764.81 6104.53 2630.03 0.00 5986149.06 724184.55 MWD+IFR+MS 11200.00 64.25 1.78 7856.55 7808.25 6194.55 2632.82 0.00 5986239.12 724184.68 MWD+IFR+MS 11300.00 64.25 1.78 7900.00 7851.70 6284.58 2635.62 0.00 5986329.18 724184.81 MWD+IFR+MS 11400.00 64.25 1.78 7943.45 7895.15 6374.60 2638.41 0.00 5986419.25 724184.94 MWD+IFR+MS 11500.00 64.25 1.78 7986.90 7938.60 6464.62 2641.21 0.00 5986509.31 724185.07 MWD+IFR+MS 11600.00 64.25 1.78 8030.35 7982.05 6554.65 2644.00 0.00 5986599.37 724185.20 MWD+IFR+MS 11700.00 64.25 1.78 8073.80 8025.50 6644.67 2646.80 0.00 5986689.44 724185.33 MWD+IFR+MS 11800.00 64.25 1.78 8117.25 8068.95 6734.70 2649.59 0.00 5986779.50 724185.46 MWD+IFR+MS 11900.00 64.25 1.78 $160.69 8112.39 6824.72 2652.39 0.00 5986869.57 724185.59 MWD+IFR+MS 12000.00 64.25 1.78 8204.14 8155.84 6914.75 2655.18 0.00 5986959.63 724185.72 MWD+IFR+MS 12100.00 64.25 1.78 8247.59 8199.29 7004.77 2657.98 0.00 5987049.69 724185.85 MWD+IFR+MS 12200.00 64.25 1.78 8291.04 8242.74 7094.80 2660.77 0.00 5987139.76 724185.98 MWD+IFR+MS 12300.00 64.25 1.78 8334.49 8286.19 7184.82 2663.57 0.00 5987229.82 724186.11 MWD+IFR+MS 12400.00 64.25 1.78 8377.94 8329.64 7274.85 2666.36 0.00 5987319.89 724186.24 MWD+IFR+MS 12411.27 64.25 1.78 8382.83 8334.53 7284.99 2666.68 0.00 5987330.04 724186.25 Start Dir 4?/10 12500.00 64.25 1.78 $421.38 8373.08 7364.87 2669.16 0.00 5987409.95 724186.37 MWD+IFR+MS 12541.48 64.25 1.78 $439.41 8391.11 7402.21 2670.32 0.00 5987447.31 724186.42 MWD+IFR+MS 12561.38 62.66 1.89 $448.30 8400.00 7420.00 2670.89 8.00 5987465.11 724186.47 CM1 12600.00 59.58 2.13 8466.95 8418.65 7453.80 2672.07 8.00 5987498.92 724186.65 MWD+IFR+MS 12700.00 51.60 2.81 8523.42 8475.12 7536.15 2675.60 8.00 5987581.34 724187.74 MWD+IFR+MS 12800.00 43.62 3.67 8590.79 8542.49 7609.83 2679.74 8.00 5987655.10 724189.70 MWD+IFR+MS 12900.00 35.65 4.82 8667.74 8619.44 7673.40 2684.40 8.00 5987718.78 724192.48 MWD+IFR+MS 13000.00 27.70 6.53 8752.77 8704.47 7725.62 2689.50 8.00 5987771.12 724196.03 MWD+IFR+MS 13028.54 25.44 7.19 8778.30 8730.00 7738.29 2691.02 8.00 5987783.84 724197.18 K3 13100.00 19.79 9.47 8844.24 8795.94 7765.47 2694.94 8.00 5987811.12 724200.29 MWD+IFR+MS 13189.40 12.80 15.00 8930.00 8881.70 7790.00 2700.00 8.00 5987835.79 724204.62 MWD+IFR+MS 13200.00 12.79 16.91 8940.33 8892.03 7792.26 2700.65 4.00 5987838.06 724205.20 MWD+IFR+MS 13238.09 12.87 23.77 8977.48 8929.18 7800.18 2703.58 4.00 5987846.06 724207.90 MWD+IFR+MS 13300.00 12.87 23.77 9037.83 8989.53 7812.80 2709.14 0.00 5987858.84 724213.08 MWD+IFR+MS 13300.48 12.87 23.77 9038.30 8990.00 7812.90 2709.19 0.00 5987858.94 724213.12 THRZ 13400.00 12.87 23.77 9135.32 9087.02 7833.19 2718.12 0.00 5987879.49 724221.45 MWD+IFR+MS 13449.40 12.87 23.77 9183.47 9135.17 7843.26 2722.56 0.00 5987889.69 724225.59 End Dir :1340 13500.00 12.87 23.77 9232.80 9184.50 7853.58 2727.10 0.00 5987900.14 724229.83 MWD+IFR+MS 13510.77 12.87 23.77 9243.30 9195.00 7855.78 2728.07 0.00 5987902.36 724230.73 TKUP 13515.90 12.87 23.77 9248.30 9200.00 7856.82 2728.53 0.00 5987903.42 724231.16 TKNG 13600.00 12.87 23.77 9330.29 9281.99 7873.97 2736.08 0.00 5987920.78 724238.20 MWD+IFR+MS 13700.00 12.87 23.77 9427.77 9379.47 7894.36 2745.06 0.00 5987941.43 724246.57 MWD+IFR+MS 13730.27 12.87 23.77 9457.28 9408.98 7900.53 2747.78 0.00 5987947.68 724249.11 Start Dir 4?/10 13741.57 12.87 23.77 9468.30 9420.00 7902.84 2748.79 0.00 5987950.01 724250.05 NK-65A WI T1 13748.22 12.87 23.77 9474.78 9426.48 7904.20 2749.39 0.00 5987951.39 724250.61 End Dir :1369 13761.57 12.87 23.77 9487.80 9439.50 7906.92 2750.59 0.00 5987954.14 724251.73 MWD+IFR+MS 13800.00 13.98 28.36 9525.18 9476.88 7914.92 2754.52 4.00 5987962.26 724255.42 MWD+IFR+MS 13802.65 14.06 28.66 9527.75 9479.45 7915.49 2754.83 4.00 5987962.83 724255.71 MWD+IFR+MS 13822.81 14.06 28.66 9547.30 9499.00 7919.78 2757.18 0.00 5987967.20 724257.93 TSHU 13881.57 14.06 28.66 9604.30 9556.00 7932.31 2764.02 0.00 5987979.92 724264.40 TSAD 13900.00 14.06 28.66 9622.18 9573.88 7936.24 2766.17 0.00 5987983.91 724266.43 MWD+IFR+MS 14000.00 14.06 28.66 9719.18 9670.88 7957.56 2777.82 0.00 5988005.57 724277.45 MWD+IFR+MS 14100.00 14.06 28.66 9816.19 9767.89 7978.88 2789.47 0.00 5988027.22 724288.46 MWD+IFR+MS 14102.18 14.06 28.66 9818.30 9770.00 7979.34 2789.72 0.00 5988027.69 724288.70 TZ2A2 14200.00 14.06 28.66 9913.19 9864.89 8000.20 2801.12 0.00 5988048.87 724299.47 MWD+IFR+MS 14280.00 14.06 28.66 9990.80 9942.50 8017.25 2810.44 0.00 5988066.20 724308.28 3.5 r~ S er -Sun P rY BP Planning Report Survev ~MD ~ ft 14280.27 lncl Azim CVD Sys TVD N!S E/~V deg deg ft ft ft ft 14.06 28.66 9991.05 9942.75 8017.31 2810.47 DLS MapN deg/100ft ft 0.00 5988066.26 NIapE Tool/Comment ft 724308.31 MWD+IFR+MS NK-3 8A • Subject: NK-38A From: Jane Williamson <Jane_williamson~admin.state.ak.us> Date: Mon, 11 Apr 205 14:59:42 -08UU To: Cathy P Foerst~~r ~=-cath~~ foerst~rr~i!admin.staie.al:.us~= CC: R~~h~t~t P Crandall =bob cra~idall~cr,admin.st~~te.ak.us=~ Cathy, Gary Gustafson and Bob Gerik called to inform me that NK-38A, completed in the Ivishak, will soon be producing (possibly in a matter of a couple of days) at GORs above the regulatory allowable- 2x original GOR. They wish to continue to test this well for around 3 months to complete their test objectives. They are preparing an AFE for a water injector to support the well. 20AAC25.240 allows the Commission to grant an administrative waiver of this requirement upon written application if acquisition of pool performance data is necessary to determine an optimum reservoir management program, which seems to apply to this situation. I told them they need to send in a letter for waiver of the GOR limit requirement, with justification for continuing production with GORs above the regulatory limit. Also, if they plan to start injection operations, they will require an injection order -which requires a 30 day notice. They intend to have the GOR waiver application in tomorrow and will be starting the AIO process soon. Jane __ Jane Williamson, PE <jane ~~villiamson cc;admin.state.ak.ns> Reservoir Engineer Alaska Oil and Gas Conservation Commission __. __ _ __ 1 of 1 4/14/2005 1:22 PM Area Injection Order No. 14A • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Area Injection Order BP ) No.14A EXPLORATION (ALASKA) ) INC. for an order allowing underground )Prudhoe Bay Field injection of fluids for enhanced oil )Niakuk Oil Pool recovery in the Niakuk Oil Pool, ) Prudhoe Bay Field ) )December 31, 2001 IT APPEARING THAT: 1. By letter dated March 26, 2001, and received by the Commission March 27, 2001, BP Exploration (Alaska) Inc. ("BP") requested that the Alaska Oil and Gas Conservation. Commission ("Commission") revise Area Injection Order No. 14 ("AIO 14") for expansion of injection operations in Niakuk Oil Pool ("NOP"). The expansion area requested included sections 15, 22 and 27 of T12N, R15E UM. 2. The Commission published the first notice of opportunity for public hearing (June 12, 2001 hearing date) on April 21, 2001. 3. The Commission published the second notice of opportunity for public hearing (July 24, 2001 hearing date) in the Anchorage Daily News on May 29, 2001. 4. The Commission did not receive a protest or written request for public hearing. 5. BP provided supplemental application materials in support of the amendment to AIO 14 on July 23, 2001. 6. On August 20, 2001, the Commission approved Administrative Order 14.001 allowing water injection into well NK-28 until November 1, 2001 to gather information to support expansion of AIO 14. 7. By letter dated October 19, 2001, and received by the Commission on October 26, 2001, BP submitted a revised application for the expanded Niakuk Area Injection Order. 8. On November 14, 2001, the Commission approved Administrative Order 14.002 allowing continued injection of water into well NK-28 until February 1, 2002. 9. Additional information pertaining to the application was received December 3, 2001. 1 of 9 4/14/2005 1:28 PM Area Injection Order No. 14A ~~ • FINDINGS: 1. Authority 20 AAC 25.460 Commission regulation 20 AAC 25.460 provides authority to issue an order governing underground injection of fluids on an area basis for all wells within the same field, facility site, reservoir, project, or similar area. 2. Summary of Injection Projects A10 14, originally issued March 22, 1995, authorized enhanced recovery injection operations within the NOP. Conservation Order 329A (June 3, 1996) and Administrative Order 329.005 (January 12, 1998) designate pool rules for the affected area. Conservation Order 329A approved expansion of the pool to include additional acreage in the western area of the field. The proposed revision to A10 14 is to expand water injection operations into the Western portion of the Niakuk Oil Pool. Specifically, expansion of the Area Injection Order was proposed for conversion of well NK-28 from production to water injection service to provide pressure support for well NK-08A. 3. Injection Area (20 AAC 25.402(c)(1)), Pool Description (Pool Information (20 AAC 25.402(c)(5)) a) Niakuk Injection Area ("NIA"): BP has requested the expansion of injection operations to include sections 15, 22 and 27 of T12N, R15E UM. With inclusion of the proposed expansion, following area is included in-the NIA: T12N, R15E UM, Sections 13-15 (all); 22-27 (all); and 36 (NE/4) T12N, R16E UM, Sections 28 (W/2, NE/4, W/2 of SE/4, SE/4 of SE/4); 29-30 (all); 31 (N/2); and 32 (N/2) b) Niakuk Oil Pool: The NIA includes the Niakuk Oil Pool ("NOP") in the Kuparuk River Formation ("Kuparuk"). The Kuparuk is defined in the pool rules as the stratum that is common to and correlates with the accumulation found in the Niakuk 6 well between the measured depths ("MD") of 12,318 and 12,942 feet. 4. Operators/Surface Owners (20 AAC 25.402(c)(2) and 20 AAC 25.403(c)(3)) BP has provided all designated operators and surface owners within one-quarter mile radius of the NIA with a copy of the application for amendment of AIO 14. Those surface owners and operators are: BP, Mr. Leroy Oenga, Ms. Georgene Shugluk, BIA /Heirs of Jenny Oenga, Mr. Michael M. Delia, Mr. Wallace Oenga and the State of Alaska, Department of Natural Resources. 5. Description of Operation (20 AAC 25.402(c)(4)). The NOP has been developed from two drill sites, Heald Point and Lisburne DS L-5. There are 13 producers and 7 water injectors currently active on Heald Point and one producer on DS L-5. Produced water for re-injection is transported from the Lisburne Production Center 2 of 9 4/14/2005 1:28 PM Area Injection Order No. 14A through an 8" pipeline. Prior to year 2000, seawater injection was used to provide pressure support within the NOP. Current injection capacity is approximately 60,000 BWPD. Future injection requirements may require the use of one or more booster pumps at the drill site in order to provide sufficient water for injection. BP indicates there is potential to return to seawater injection at a future date. 6. Geologic Information (20 AAC 25.402(c)(5) The following is a summary of the geologic information for the NOP. a) Introduction: Three structurally defined areas are present in the NIA. Two east-west oriented grabens separated by a paleohigh that lacks Kuparuk sediments are present in the southern portion of the area. In the Northwestern portion of the NIA is a platform with numerous, west-northwest trending normal faults. b) Reservoir Interval: The NIA includes the NOP in the Kuparuk. The Kuparuk is defined in the pool rules as strata that are common to and correlate with the accumulation found in the Niakuk 6 well between 12,318 and 12,942 feet MD. c) Stratigraphy: The NOP consists of the Kuparuk that was deposited in an Early Cretaceous age marine environment. Within the expanded NIA, the Kuparuk consists of a stratigraphically complex accumulation of shale, siltstone and sandstone. These sediments are characterized by rapid changes in thickness, sedimentary facies, and cementation. Within the NIA, predominately fine grained Kuparuk basin fill initially accumulated north of the Niakuk Field Fault in the West Niakuk Graben (designated by BP as "Segment 1 ") and East Niakuk Graben (designated by BP as "Segment 2"), to a gross thickness exceeding 500 feet. The basin fill sediments are generally below the oil water contact in both grabens. A period of non-deposition or erosion separates the basin fill'sequence from a thick (100's of feet) series of predominately fine grained, aggradational, shoreface sandstones with a high net to gross ratio. The shoreface sands are present throughout the NIA and contain the majority of the oil in place. d) Structure Overview: The West Niakuk and East Niakuk Grabens (Segments 1 and 2) are fault-bounded depocenters cut by faults that are en echelon to the Niakuk Field Fault. The West Niakuk Platform (designated by BP as "Segment 3/5") consists of a system of horsts, grabens and half-grabens created by a series of high angle, principally normal faults that lie parallel with, and en echelon to, the Niakuk Field Fault. The top of the Kuparuk ranges from a high of -8800 feet True Vertical Depth sub-sea ("TVDss") in West Niakuk and dips to a low of -9800 feet TVDss in the eastern portion of East Niakuk. Most of the accommodation related to faulting in the NIA occurred during Kuparuk deposition, with significant fault displacement at the base of the interval and much smaller fault offsets at the top. e) Confining Intervals: The Kuparuk is bounded below by the Jurassic age Kingak Formation over most of the NIA. The Kingak Formation is a highly impermeable, low resistivity (2 - 3 ohm-meters) shale with a thickness varying from 400 to 800 feet. In the extreme SE corner of the Injection Area, the Kingak Formation has been interpreted as absent on seismic. In this small area, confinement of injected fluids will be provided by Lower Kuparuk siltstones and shales. The Kuparuk is overlain by the Lower Cretaceous age Highly Radioactive Zone ("HRZ") interval over the entire Injection Area. It is comprised of a 200 foot thick, black, organic rich, impermeable shale. 3 of 9 4/14/2005 1:28 PM Area Injection Order No. 14A • • ' f) Oil and Rock Properties: Oil gravity averages about 25 degrees API, with observations between 20-30 degrees API. Initial reservoir pressure was approximately 4500 pounds per square inch ("psi") at a datum of 8900' TVDss and the initial temperature ranged from 171 to 182 degrees F. The bubble point pressure is approximately 4200 psi, with solution gas/oil ratios of 600-700 Standard Cubic Feet per Stock Tank Barrel ("SCF/STB"), and oil formation volume factor of approximately 1.3 Reservoir Barrel per Stock Tank Barrel ("RVB/STB"). Initial solution gas/oil ratios are approximately 300 SCF/BBL. Pay averages about 16-21% porosity and 100-300 millidarcies ("md") permeability. Net sand to gross sand. ratios vary from .20 to .9. g) Compartmentalization: Within the NIA, the Kuparuk reservoir is compartmentalized. Three separate oil-water contacts have been identified within the injection area: West Niakuk Graben (Segment 1) at 9240 feet TVDss, the West Niakuk Platform (Segment 3/5) at 9285 feet TVDss, and at 9535 feet TVDss in the East Niakuk Graben (Segment 2). h) Original Oil in Place: Estimated total original oil in place ("OOIP") in the NOP is approximately 310 MMSTB. Cumulative production to date is 59 MMSTB. East Niakuk Graben (Segment 2) OOIP is estimated at 120 MMBO. West Niakuk Graben (Segment 1) OOIP is estimated at about 85 MMBO. West Niakuk Platform (Segment 3/5) is estimated at about 105 MMBO. 7. Infection Fluids (20 AAC 25.402{c)(9)). Injection will utilize either produced or source water. The wells are currently configured to allow 60,000 Barrels of Water per Day ("BWPD") total, with a maximum injection of up to 70,000 BWPD. The produced water will be a mix of Pt. McIntyre, West Beach, North Prudhoe Bay, Lisburne and Niakuk produced water separated through the Lisburne Production Center ("LPC"), with the majority_coming< from Pt. 'McIntyre. Seawater has been injected as well. SEM, `XRD and ERD analyses conducted on Niakuk core indicate very low clay content in reservoir intervals. As a result no significant. problems with formation plugging or clay., swelling due to fluid incompatibilities is .expected. Produced water may contain trace amounts of scale inhibitor, corrosion inhibitor, emulsion breakers, and other products used in the production process. Well Logs (20 AAC 25.402(c)(7)): The logs of existing injection wells are on file with the Commission. Specific to this application, the bond logs of NK-28 have been reviewed, and sufficient cement exists above the Kuparuk interval. 9. Mechanical Integrity (20 AAC 25.402(c)(8)): NK-28 is the only well currently planned to be converted to an injector. A Segmented Bond Tool was run in the well in July 1995. The tool shows good bond above and below the perforations. A mechanical integrity test was performed on the well on 8/12/01, which showed good mechanical isolation. All wells used for injection will be cased and cemented in accordance with 20 AAC 25.412. In drilling all NOP injection wells, the casing is pressure tested in accordance with 20 AAC 25.030. The NOP injection wells are designed to comply with the requirements specified in 20 AAC 25.412. 10. Infection Pressures (20 AAC 25.402(c)(10)): The estimated average and maximum wellhead injection pressure for the NOP water injection project is as follows: Surface Operating Pressure, pounds per square inch, gauge ("psig") Service Maximum /Average Water Injection 285012450 4 of 9 4/14/2005 1:28 PM Area Injection Order No. I4A • ' 11. Fracture Information (20 AAC 25.402(c)(11)): Injection in the Kuparuk at pressures above fracture parting pressure may be necessary to allow for additional recovery of oil. Water injection at the pressures proposed by BP should not initiate or propagate fractures through the confining strata. There are no freshwater strata in the area of issue. No fracture gradient has been obtained in the Kuparuk interval at Niakuk; however it is expected that the fracture gradient will be similar to that of the Kuparuk interval of Pt. McIntyre and West Beach Pools, or .60-.63 psi/ft. The Kuparuk Formation is overlain by the HRZ shale. l_eakoff test data for NK-05 and NK-06 indicate a fracture gradient of over .82 psi/ft. Surface injection pressures in excess of 3200 psi would be required to initiate a fracture into the HRZ. 12. Water Analysis (20 AAC 25.402(c)(12)): Produced water analysis from the NOP indicates 25,000 parts per million ("ppm") total dissolved solids (TDS). Calculation of TDS from wireline logs indicates NaCI equivalents of greater than 10,000 ppm in the formations above the Kuparuk Formation. Therefore, aquifer exemption is not required. 13. Hydrocarbon Recovery (20 AAC 25.402(c)(14)): BP projects waterflood overall recoveries of approximately 35-38% in the Segments 1 and 3/5 of the western Niakuk, (67 to 72 MMSTBO), and 24-27% Segment 2 of the eastern Niakuk region (or 29-33 MMSTBO). Recovery by primary depletion alone is estimated at about 13%. Waterflood has been ongoing in Niakuk since 1994. These recovery figures include wells drilled and completed to date, including the NK-28 conversion, but not future development. Incremental recovery of 1.2 MMBO is .projected as a result of conversion of NK-28 to water injection. a) Water Management Areas: The Niakuk accumulation is managed as three main pools Segment 1, Segment 3/5, and Segment 2. b).Reservoir Surveillance Results: Initial reservoir pressure is estimated at 4500 psi. Production prior to 1996 dropped reservoir pressures in some areas. After injection started in 1995, pressures stabilized at approximately 4000 psi in the Segments 1 and 3/5 in the western Niakuk. Segment 2 in the eastern Niakuk has shown mixed results from water injection because there is structural and stratigraphic compartmentalization that is not as evident in the western Niakuk. Segment 1 (West Niakuk Graben): Production in the Segment 1 began in April 1994. Injection began approximately one year later with the conversion of NK-10. Production has been sustained via pressure maintenance from this single injector. Aquifer support to the west may also be present, but has not been verified. Recent increases in oil production are attributed to redrilled well NK-07A. Although injection is currently adequate in this area, future conversions may be considered. Segment 3/5 (West Niakuk Platform): Production in Segment 3/5 began in January 1995. Injection began approximately two years later at NK-15. Production has been sustained via pressure maintenance from this one injector, although injection has also been attempted at NK-17 with poor injectivity caused by poor rock quality. Injection in the Segment 3/5 is currently not balanced with voidage, in part due to production from recently redrilled well NK-08A. Another reason is the reduction in injectivity at NK-15 since its conversion from seawater to produced water injection roughly one year ago. BP anticipates conversion of NK-28 to injection service will alleviate this situation and optimize recovery from NK-08A. 5 of 9 4/14/2005 1:28 PM Area Injection Order No. I4A • • NK-28, which has produced over 2 MMBO, has watered out, and was recently converted to injection. While injection has not fully matched production, the segment has shown low decline relative to the to the other segments. BP indicates that additional aquifer support to the west may be present, but has not been verified. Segment 2 (East Niakuk Graben): Segment 2 is more complex relative to the West Niakuk Graben and West Niakuk Platform. Production in Segment 2 began in April 1994. Injection began approximately one year later when NK-16, NK-23, and NK-38 were put into injection service. NK-65 was later put on injection in mid-1998. Production has been maintained to varying degrees via pressure maintenance from these injectors. NK-19 is an exception to this because it is completed in a relatively small isolated block that receives no pressure support. This well produced less than half a million barrels of oil before gassing out and dying due to low reservoir pressure and lack of injection support. NK-18 has had similar performance, but is not located in a completely isolated fault block. NK-18 was recently converted to injection in anticipation of production from the redrill of NK-19A. Because of the greater complexity and reservoir compartmentalization, BP states that well configuration and recovery performance in East Niakuk may differ substantially from what is seen in the west. c. Reservoir Simulation: BP has developed two reservoir models in the evaluation of the waterflood, infill drilling, water conversion candidates and future development options. Both models were built using a deterministic methodology. Kuparuk tops and bottoms were defined by seismic data, along with internal stratification where it could be seen. Well control was honored in defining the structure. Geologic descriptions from core, coupled with log data, were used to interpret internal stcatigraphy, and formed the. basis for an internal zonation scheme and the final simulation grid. Porosity in both models was derived from core data where available and an interpreted log model elsewhere. Porosity/permeability crossplots were derived from the cored intervals. Thelog model incorporates density, sonic, and neutron measurements along with adjustments for shale volumes, heavy minerals, and cementation, which are zone-specific in some cases. Initial water saturations are assigned by functions developed from core that incorporate porosity, height above the water column, saturation exponents (Archie model), and Waxman-Smits parameters. Relative permeability experiments have not been conducted with Niakuk rock samples. Accordingly, scalable relative permeability curves developed from Prudhoe Bay samples have been employed and are assigned based on initial water saturation. The lithologic description used in the current reservoir simulation contains 32 layers for Segment 2 in eastern Niakuk and 13 layers for Segments 1 and 3/5 in the western Niakuk. Simulation grids that averaged less than 15% porosity or 10 and permeability were zeroed out. BP provided results of the history matches obtained in the West and East Niakuk models. BP indicated some adjustments to description were required to obtain the match, particularly with respect to fault locations. 14. Mechanical Condition of Adjacent Wells (20 AAC 25.402(c)(15)). BP is utilizing injection wells previously covered by AIO 14. To the best of BP's knowledge, the wells within the Niakuk and Western Niakuk Participating Areas were constructed, and where applicable, have been abandoned to prevent the movement of fluids into freshwater sources. Information regarding wells that penetrate the injection zone within 1/4 mile radius of injection wells has been filed with the Commission. 15. Incorporation of AIO 14 Findings: The findings of fact in AIO 14 and amendments 6 of 9 4/14/2005 1:28 PM Area Injection Order No. 14A • " thereto are incorporated herein to the extent not inconsistent with this order. CONCLUSIONS: 1. The application requirements of 20 AAC 25.402 have been met. 2. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 3. The waters are currently injected under prior Commission approval of A10 14. Core tests indicate minimal plugging problems with injected water. No problems with compatibility of the fluids have been observed. 4. Revision of AIO 14 to expand the effected area is appropriate in accordance with 20 AAC 25.450 and 20 AAC 25.460. 5. NK-28 is the only existing well planned for water injection conversion in the expansion area. 6. Injection of water in NK-28 is needed to maintain pressure and improve recovery in the Western region of the Niakuk. 7. All injection wells are designed to comply with the mechanical integrity requirements specified in 20 AAC 25.412. Mechanical integrity of NK-28 has been demonstrated by mechanical integrity test. 8. An order for temporary water injection into NK-28 was approved by the Commission on August 20, 2001, and extended by order dated November 14, .2001. 9. Fluids injected for enhanced recovery will consist of a mix of either produced waters processed in the Lisburne Production Facilities, or water from the Prudhoe Bay Unit Seawater Treatment Plant. Produced water may contain trace amounts of scale inhibitor, corrosion inhibitor, emulsion breakers, and other products used in the production process. 10. The proposed injection operations will be conducted in permeable strata that can reasonably be expected to accept injected fluids at pressures less than the fracture pressure of the confining strata. 11. There are no USDW's within the project area. 12. Injection of water will significantly increase hydrocarbon ultimate recovery above primary production. 13. Reservoir surveillance, operating parameter surveillance and mechanical integrity tests will demonstrate appropriate performance of the water injection project or disclose possible abnormalities. 14. The conclusions in A10 14 and the amendments thereto are incorporated herein to the extent not inconsistent with this order. NOW, THEREFORE, IT IS ORDERED; 7 of 9 4/14/2005 1:28 PM Area Injection Order No. I4A • • 1. Except as otherwise provided herein, this order supersedes Area Injection Order No. 14 and previous revisions. 2. The following rules, in addition to statewide requirements under 20 AAC 25 (to the extent not superseded by these rules), govern enhanced oil recovery injection operations in the NOP in the affected area defined below. Umiat Meridian 'Township Range Sections T12N R15E 13-15 (all); 22-27 (all); 36 (NE/4) __ 'T12N .816E 28 (W/2, NE/4, W/2 of SE/4, SE/4 of SE/4); 29-30 (all); 31 (N/2); 32 (N/2) Rule 1 Authorized Iniection Strata for Enhanced Recovery and Authorized Iniection Fluids Enhanced recovery operations as described in the operator's applications are approved for the NOP within the Prudhoe Bay Field subject to these rules. 1) Authorized Iniection Strata: Within the affected area, fluids may be injected for. purposes of .pressure maintenance and enhanced recovery into strata defined as those that correlate with and are common to the. formations found in BP Niakuk No. 6 between the measured depths of 12,318 - .12942 feet. 2) Authorized Iniection Fluids: Fluids authorized for injection for the NOP: a. Produced water from LPC operations; b. Beaufort seawater; c. Trace amounts of scale inhibitor, corrosion inhibitor, emulsion breakers, and other products used in the production process; and d. Fluids injected for the purposes of stimulation per 20AAC24.280(2). Rule 2 Fluid Iniection Wells The injection of fluids must be conducted 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; or 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280. Rule 3 Monitoring the Tubing-Casing Annulus Pressure Variations The tubing-casing annulus pressure and injection rate of each injection well must be checked at {east weekly to confirm continued mechanical integrity. Rule 4 Demonstration of Tubing-Casing Annulus Mechanical Integrity A schedule must 8 of 9 4/14/2005 1:28 PM Area Injection Order No. 14A be developed and coordinated with the Commission that ensures that the tubing-casing annulus for each injection well is pressure tested prior to initiating injection, following well workovers affecting mechanical integrity, and at least once every four years thereafter. Rule 5 Notification of Well Integrity Failure Whenever injection rates or operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission by the first working day following the observation, and submit a plan of corrective action on Form 10-403 for Commission approval. Additionally, notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 6 Notification of Improper Class II Iniection Injection of fluids other than those listed in Rule 1, above, without prior authorization is considered improper Class II injection. Upon discovery of such an event, the operator must immediately notify the Commission, provide details of the operation, and propose actions to prevent recurrence. Additionally, notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 7 Other Conditions a. It is a condition of this authorization that the operator complies with all applicable Commission regulations. b. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated injection strata. Rule 8 Administrative Action Unless notice and.. public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles and will not result in an increased risk of fluid movement into freshwater. DONE at Anchorage, Alaska and dated December 31, 2001. Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission Julie M. Heusser, Commissionner Alaska Oil and Gas Conservation Commission Area Iniection Order Index 9 of 9 4/14/2005 1:28 PM `TERRIE L RUBBLE BP EXPLORATION AK INC ss-si,z5z 193.: PO BOX 196612 MB 7-5 'Mastercard Check" ANCHORAGE, AK 99519-66.12 /'~ DATE -I2 ~Q RAY TO THE ORDER OF - /~~~~ $ ' ~QI O~ W First National Bank Alaska ,DOLLARS Anchorage, AK 9950, MEMO~V` ~' ~~ ' ~: L 2 5 2 0 0 0 6 0 ~: 9 9 i 4 ~~~ 6 2 2 7 ~~~ L 5 5 6 ~~• 0 19 3 • ~ ~ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~,~ '~~/~ PTD# Zo~S -~ 6~',r~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\trans m ittal_checklis ~~ ~ << ~~ t ~~~ ,l , ~~ ~~ ~~ ~~`~~~~ v ~~7~ " ~~ ~~ ~ ~ ~~ . • • Permission to begin injection operations in this well is contingent on adding the Niakuk Ivishak-Sag River reservoir to the strata authorized for injection by Area Injection Order No. 14A. WELL PERMlT CHECKLIST Field & Pool PRUDHOE BAY, NIAK IV-SR UN OIL- 640147 Well Name: PRUDHOE BAY UN tJIA NK-65A Program SER Well bore seg PTD#:2050630 Company BP EXPLORATION (ALASKA) INC Initial Classffype SERI 1WINJ GeoArea 890 Unit 11650 On/Off Shore Off Annular Disposal Administration 1 Permit fee attached________________________ Yes__--- _---_____-_--__. 2 Lease numberappropriate------------------ Yes______ -- - - 3 Unique well-name and number _ _ - - _ - - _ ------------------------ _ Yes _ - - - - . , ----- - _ ------------------------------------------------------------------ 4 Well located ina_defined_pool_________________________________ ______ No________ UNDEFINEDNIAKUKIVI$HAKPOOL__----_---_____-_-__--___ -------------------- 5 Well located pCOperdistance-fromdrillingunit_boundary_---.--_________ .__._Yes___-_- STATEWIDE SPACING__________________________________ ____________----_ 6 Well located properdistance_f[omotherwells-__-___________________ ______Yes_-__- - -- - - 7 Su_fficientacreageayailablein-drillinqunit-----------------------_- ..-_-_Yes__--__- -___-___--,_-__-_______--__-______-_--__-_______-----_-_ 8 If_deviated,is_wellboreplat_included-_-_______. Yes_______ - _______________________ -- - - 9 Operator only affected party-____---------------------- --- --Yes------- -------__---- ------------------------------------------------------- 10 Ope[atorhas.appropriate-bond in force- -------- ---- -------- - --- Yes ------ ---------------- --- --------- ----- -- ------- -... ------ -- -- 11 Permit can be issued without conservation order_ _ - - - - - No- - _ _ - - - AS JANE SAYS I_N_TH_E_ATTACHED E-MAIL PERMISSION TO INJECT IN THIS WELL MUST-WAIT UNTIL_A1O1 Appr Date 12 Pe[mh-can be issued withoutadminist[alive-appr_oyal___________________ ______Yes_______ IS.tv1ODIFl_ED,_____--_-_-- ____-_--_--____-___----_______--_--____--_.-_ RPC 4/14!2005 13 Can permit be approved before 15-day wait No 14 Well located within area and strata authorized by-Injection Order# (put1O# in-comments)-(For- No- --------------------------------------------------------- 15 All wells within114_mileareaofreyiewidentified(Forservicewellonly)_________ ______Yes--___-_ Nowells within 114 mileAOR_-__-____---_________-.-__________----_______-.---- 16 Pre-produced injector: dur_ation_of pre p[oduction Less than_ 3 months-(For service we ll only) - - No_ - -- -- - 17 ACMP_Finding of Consistency-has been issued-forthis project _ _ - _ _ - NA_ . _ _ - - - _ _ - _ - - - Engineering 18 Conductorstring,provided_________________--_-__--_______. ____.- NA_-__-___ _____-_-__-_,___-----__-_____-., ---------------------------------- 19 Surface-rasing-protectsall_knownUSDWS_________________________ ______NA_-_-____ ___---_ - - -- - - 20 CMT-vol adequate_to circulate-on conductor_& surf_csg - - - - - - - - - - - NA_ _ - '- - 21 CMT.vol_ adequate_to tie-in long string to surf csg_ ! - - - , - NA_ _ _ . 22 CMT_willcoverallknown-productivehorizon_s_________ _________--_, ______Yes_.__-.- ___ 23 Casing designsadeguateforC,T,B&_p~tmafroSt-_-___---_---------- ------Yes-______ PremiumJinecconnections.._..________:_-_--_____-__--_-- ___ --___:______-_-- 24 Adequatetan_kage-or[eservepit_______________-_______--____- ______Yes_--__-- Nabors_2ES,--___;____- _-_- __ --------------------------- 25 Ifa_re-dCill,has_a_1.0-403 for abandonment been approved--___--_____- -__-__Yes_-_-:-- "___________ ____ __________________________________________-__-__ 26 Adequatewellbo-re separatjonproposed___________________________ ______ Yes_-_____ ___-_,-._ 27 If divertertequired, does it meet regulations- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - _ _ Sidetrack. , - _ - - - -- -- - - Appr Date 28 Drillingfluid_programschematic&equiplistadequate_----------------- ------Yes_--_-.- Max MW 11,4_ppg:--_____------__-_.._--_--__--.:______--.-.-__ WGA 4!1512005 29 B_OPEs,dotheymeetregu_lation___--_--_ -- - _-Yes_____ _ ____________---__-_______--____--____-___--_-- _-_-----_-__-- ----- 30 BOPE_pressratingappropriate;testto_(putpsigincomments)_____________ ______Yes_-___-_ Testto 4500psi._fvISP4000psi.-__-_____---_----_______--__-______---____ 31 Choke_manifoldcompliesw/APIRP-53fMay84)-__--------------___ ___--_Yes_-____ _-_: - - - -- -- 32 Work will occur without operation shutdown__________ _____________ ____ Yes-_____ _ -_----___-_-_ - --- - - - 33 Is presence.of H2S gas_probable - - - - - - - -Yes 200.ppm, - - - - - - - - - - - - - - - 34 Mechanical condition of wells within AOR verified (Forservice well only) _ - - _ _ _ Yes - . - _ - - No wells within AOR-- - - - - - - - - - - - - - -- --- -- Geology 35 Permit_can be issued wlo hydrogen_sulfide measures - - - - - - - - - - - - - - - _ _ No_ - _ - - _ - -------------------------------------------------------------- 36 Data-presented on potential overpressure zones______________________ ______NA-_-_--- __-__-----_- Appr Date 37 Seismic analysis-of shallow gas-zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- -- - NA- - - -- -- -- -- - RPC 4/1412005 38 SeabedcQnditionsunrey-(ifoff-shore)_________________________-- -_____NA____ -- - - 39 _ Contact namelphone_for_weeklyprogress-reports [exploratory onlyJ_ _ - - _ - - NA_ _ - _ Geologic Engineering D t D t D t Commissioner: a a e: Commissioner: e mis • a e • • 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 infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 25 10:46:36 2006 Reel Header Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA ~ a~-o~ Scientific Technical Services Scientific Technical Services NK-65A 500292286901 BP Exploration Alaska Sperry Drilling Services 25-APR-06 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0003694493 MW0003694493 LOGGING ENGINEER: A. SHANAHAN A. SHANAHAN OPERATOR WITNESS: D. MASKELL D. MASKELL SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 15E FNL: FSL: 1429 FEL: 823 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 48.30 GROUND LEVEL: 19.80 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 4 MW0003694493 A. SHANAHAN D. MASKELL OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8513.0 REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY FOR ORIENTING THE WHIPSTOCK, MILLING THE WINDOW, AND DRILLING A BIT OF RAT HOLE. SROP DATA WERE MERGED WITH RUN 2 MWD DATA. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND AT-BIT INCLINATION {ABI) MWD RUNS 3 & 4 ALSO INCLUDED AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD SGRC DATA ACQUIRED OVER THE INTERVAL 802$'MD-8513'MD (BIT DEPTHS) WHILE POOH AFTER MWD RUNS 2 & 3, WERE MERGED WITH RUN 2 MWD DATA. THESE MAD DATA WERE ACQUIRED FOR TIE-IN PURPOSES. SRAT DATA FOR THESE MAD PASSES WERE MERGED WITH RUN 2 MWD SROP DATA. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN NK-65 ON 4 MAY 1998. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 14 APRIL 2006, AS AUTHORIZED BY DAVE BOYER (BP) . 6. MWD RUNS 1-4 REPRESENT WELL NK-65A WITH API# 50-029-22869-01. THIS WELL REACHED A TOTAL DEPTH {TD) OF 14208'MD/9986'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 10.5 PPG MUD SALINITY: 800 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8003.0 14179.5 ROP 8053.5 14228.5 RPM 8518.5 14186.5 RPD 8515.5 14186.5 RPS 8518.5 14186.5 RPX 8518.5 14186.5 FET 8518.5 14186.5 NCNT 13728.5 14144.5 FCNT 13729.0 14145.0 NPHI 13729.0 14144.5 DRHO 13741.5 14157.5 RHOB 13741.5 14157.5 PEF 13741.5 14157.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8003.0 7979.0 8003.5 7979.5 8007.5 7982.5 8021.5 7996.0 8024.0 7999.0 8027.0 8002.0 8031.0 8006.0 8100.5 8073.5 8109.0 8083.0 8112.0 8085.5 8141.5 8114.5 8158.0 8132.0 8179.0 8153.5 8184.0 8158.0 8194.0 8168.5 8197.5 8171.5 8200.0 8174.5 8212.0 8185.5 5 • 8218.5 8191. 8225.5 8197.5 8237.0 8208.0 8242.5 8216.0 8249.5 8223.5 8265.0 8238.5 8285.0 8257.0 8310.0 8284.5 8355.5 8334.0 8365.0 8345.5 8369.0 8348.0 8373.5 8353.0 8394.5 8373.5 8397.0 8376.0 8406.0 8385.5 8426.0 8404.5 8435.0 8412.0 8448.5 8425.0 8481.5 8458.5 8483.5 8461.0 8504.0 8482.0 8511.5 8490.0 8535.5 8515.0 14228.5 14208.0 MERGED DATA SOURCE PBU TOOL CODE . BIT RUN NO MERGE TOP MERGE BASE MWD 2 7979.0 13791.0 MWD 3 13708.0 14058.0 MWD 4 13974.5 14208.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading Last Reading • ~ DEPT FT 8003 14228.5 11115.8 12452 8003 14228.5 FCNT MWD CNTS 243.37 3925.72 1097.56 833 13729 14145 NCNT MWD CNTS 17892.7 55491.4 34273.7 833 13728.5 14144.5 RHOB MWD G/CM 2.149 2.967 2.4236 833 13741.5 14157.5 DRHO MWD G/CM -0.054 0.409 0.0633433 833 13741.5 14157.5 RPD MWD OHMM 0.36 2000 9.37793 11337 8518.5 14186.5 RPM MWD OHMM 0.55 2000 10.5978 11337 8518.5 14186.5 RPS MWD OHMM 0.39 971.17 6.26756 11337 8518.5 14186.5 RPX MWD OHMM 1.03 1242.29 6.07318 11337 8518.5 14186.5 FET MWD HOUR 0.23 28.16 1.49384 11337 8518.5 14186.5 GR MWD API 17.19 475.27 109.395 12354 8003 14179.5 PEF MWD BARN 2.48 8.61 3.8366 833 13741.5 14157.5 ROP MWD FT/H 0.04 903.46 113.256 12351 8053.5 14228.5 NPHI MWD PU-S 4.46 53.25 18.0618 832 13729 14144.5 First Reading For Entire File..........8003 Last Reading For Entire File...........14228.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 7979.0 ROP 8028.0 RPD 8497.5 RPS 8497.5 RPM 8497.5 FET 8497.5 RPX 8497.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): STOP DEPTH 13742.0 13791.0 13749.0 13749.0 13749.0 13749.0 13749.0 09-MAY-05 Insite 66.37 Memory 13791.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD020 RPM MWD020 RPS MWD020 RPX MWD020 FET MWD020 GR MWD020 ROP MWD020 Name Service Unit DEPT FT 8539.0 13791.0 10.0 65.0 TOOL NUMBER 151107 148579 6.125 8513.0 LSND 9.60 47.0 9.7 900 4.0 1.590 70.0 .810 143.6 1.680 70.0 .970 70.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 7979 13791 10885 11625 7979 13791 RPD MWD020 OHMM RPM MWD020 OHMM RPS MWD020 OHMM RPX MWD020 OHMM FET MWD020 HOUR GR MWD020 API ROP MWD020 FT/H ~ 0.3 2000 0.55 2000 0.39 971.17 1.03 1242.29 0.23 20.23 20.45 475.27 0.04 903.46 First Reading For Entire File..........7979 Last Reading For Entire File...........13791 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD 8.00523 10504 497.5 13749 9.53765 10504 8497.5 13749 4.58062 10504 8497.5 13749 4.62688 10504 8497.5 13749 0.989447 10504 8497.5 13749 112.605 11527 7979 13742 120.4 11527 8028 13791 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 13708.0 FCNT 13708.5 NPHI 13708.5 PEF 13721.0 RHOB 13721.0 DRHO 13721.0 GR 13742.5 FET 13749.5 RPX 13749.5 RPS 13749.5 RPM 13749.5 RPD 13749.5 ROP 13791.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 13974.0 13974.0 13974.0 13987.5 13987.5 13987.5 14009.5 14016.5 14016.5 14016.5 14016.5 14016.5 14058.0 11-MAY-05 Insite 66.37 Memory 14058.0 13791.0 BOTTOM LOG INTERVAL (FT)~ BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON ASLD Azim. Stab Litho-Den EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FCNT MWD030 NCNT MWD030 RHOB MWD030 DRHO MWD030 RPD MWD030 RPM MWD030 RPS MWD030 RPX MWD030 FET MWD030 GR MWD030 PEF MWD030 ROP MWD030 14058.0 12.8 13.5 TOOL NUMBER 151107 153020 10715410 148579 6.125 8513.0 LSND 10.50 49.0 9.8 900 3.6 1.560 75.0 .810 150.0 1.700 75.0 .970 75.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 CNTS 4 1 68 4 2 CNTS 4 1 68 8 3 G/CM 4 1 68 12 4 G/CM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 OHMM 4 1 68 28 8 OHMM 4 1 68 32 9 HOUR 4 1 68 36 10 API 4 1 68 40 11 BARN 4 1 68 44 12 FT/H 4 1 68 48 13 NPHI MWD030 PU-S ~ 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13708 14058 13883 701 13708 14058 FCNT MWD030 CNTS 412.3 3925.72 1185.8 532 13708.5 13974 NCNT MWD030 CNTS 24384.4 55491.4 34968.4 533 13708 13974 RHOB MWD030 G/CM 2.149 2.967 2.42287 534 13721 13987.5 DRHO MWD030 G/CM -0.054 0.169 0.0585805 534 13721 13987.5 RPD MWD030 OHMM 1.96 235.7 35.6137 535 13749.5 14016.5 RPM MWD030 OHMM 1.84 250.8 34.1732 535 13749.5 14016.5 RPS MWD030 OHMM 1.87 499.87 36.2795 535 13749.5 14016.5 RPX MWD030 OHMM 1.83 399.35 31.766 535 13749.5 14016.5 FET MWD030 HOUR 1.47 28.16 7.08097 535 13749.5 14016.5 GR MWD030 API 17.19 471.95 65.4007 535 13742.5 14009.5 PEF MWD030 BARN 2.54 7.85 3.86496 534 13721 13987.5 ROP MWD030 FT/H 0.87 57.14 16.9274 534 13791.5 14058 NPHI MWD030 PU-S 4.46 37.52 17.2821 532 13708.5 13974 First Reading For Entire File..........13708 Last Reading For Entire File...........14058 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 13974.5 14124.0 NPHI 13974.5 14124.0 FONT 13974.5 14124.5 DRHO 13988.0 14137.0 PEF 13988.0 14137.0 RHOB 13988.0 14137.0 GR 14010.0 14159.0 RPM 14017.0 14166.0 RPX 14017.0 14166.0 RPD 14017.0 14166.0 . • FET 14017 14166.0 RPS 14017.0 14166.0 ROP 14058.5 14208.0 LOG HEADER DATA DATE LOGGED: 12-MAY-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14208.0 TOP LOG INTERVAL (FT) 14058.0 BOTTOM LOG INTERVAL (FT) 14208.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 11.7 MAXIMUM ANGLE: 13.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 CTN COMP THERMAL NEUTRON 153020 ASLD Azim. Stab Litho-Den 10715410 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT) 8513.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 10.50 MUD VISCOSITY (S) 50.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.550 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .760 150.0 MUD FILTRATE AT MT: 1.650 70.0 MUD CAKE AT MT: .920 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code .Offset Channel ~ DEPT FT 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 RHOB MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13974.5 14208 14091.3 468 13974.5 14208 FCNT MWD040 CNTS 243.37 1811.65 941.589 301 13974.5 14124.5 NCNT MWD040 CNTS 17892.7 41286.8 33039.3 300 13974.5 14124 RHOB MWD040 G/CM 2.208 2.849 2.4249 299 13988 14137 DRHO MWD040 G/CM -0.01 0.409 0.0718495 299 13988 14137 RPD MWD040 OHMM 1.64 36.96 12.8136 299 14017 14166 RPM MWD040 OHMM 1.57 37.88 12.3119 299 14017 14166 RPS MWD040 OHMM 1.57 41.04 11.8262 299 14017 14166 RPX MWD040 OHMM 1.55 38.93 10.8995 299 14017 14166 FET MWD040 HOUR 1.88 25.23 9.27873 299 14017 14166 GR MWD040 API 19.07 203.88 64.0188 299 14010 14159 PEF MWD040 BARN 2.48 8.61 3.78595 299 13988 14137 ROP MWD040 FT/H 1.26 29.14 15.7824 300 14058.5 14208 NPHI MWD040 PU-S 9.13 53.25 19.4445 300 13974.5 14124 First Reading For Entire File..........13974.5 Last Reading For Entire File...........14208 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/04/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/04/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments ................~5 LIS Writing Library Physical EOF Physical EOF ScientiZ^lc Technical Services End Of LIS File