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Home My WebLink About207-114MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-13A PRUDHOE BAY UNIT NGI-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 NGI-13A 50-029-20347-01-00 207-114-0 G SPT 7794 2071140 1948 3223 3224 3223 3228 66 94 94 92 4YRTST P Josh Hunt 9/9/2023 4 year MIT -IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-13A Inspection Date: Tubing OA Packer Depth 119 2485 2452 2438IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH230909121800 BBL Pumped:5 BBL Returned:3.1 Tuesday, October 17, 2023 Page 1 of 1          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 NGI-13A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-114 50-029-20347-01-00 9006 Conductor Surface Intermediate Production Liner 8515 80 2351 8464 682 9006 20" 13-3/8" 9-5/8" 7" 8515 34 - 114 34 - 2385 32 - 8496 8324 - 9006 34 - 114 34 - 2385 32 - 8005 7833 - 8515 none 520 2670 4760 5410 none 1530 4930 6870 7240 8598 - 9004 7" 26# x 7-5/8" 29# L-80 30 - 8331 8107 - 8513 Structural 7" Baker S-3 2090 / 2090 8286 7794 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 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 0028302 30 - 7840 323-049 13b. Pools active after work:PRUDHOE BAY 7" Camco A-1 8286 / 7794 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 Samantha Carlisle at 8:30 am, Feb 28, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.28 07:28:44 -09'00' DSR-2/28/23 RBDMS JSB 030223 PBU NGI-13A Sundry Number 323-049 207-114 PRUDHOE BAY Water Wash WCB 11-24-2023 ACTIVITYDATE SUMMARY 2/20/2023 T/I/O= 2600/68/42. LRS 72 Water Wash (TUBING WASH/PICKLE). Pumped 10 bbls of 60/40 MeOH, 50 bbls of 120*F diesel and 367 bbls of 120*F fresh water with 0.02% F-103 surfactant into the TBG. FP surface equipment with 2 bbls of 6/40 MeOH andlLet the treatment soak for 2 hours. Pumped 252 bbls of 120*F FW with surfactant and 15 bbls of 60/40 MeOH into the TBG. Final T/I/O= 40/80/100. Turn the well back to operations. Daily Report of Well Operations PBU NGI-13A 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 thes pool? Will planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NGI-13A Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-114 50-029-20347-01-00 ADL 0028302 9006 Conductor Surface Intermediate Production Liner 8515 80 2351 8464 682 9006 20" 13-3/8" 9-5/8" 7" 8515 34 - 114 34 - 2385 32 - 8496 8324 - 9006 34 - 114 34 - 2385 32 - 8005 7833 - 8515 none 520 2670 4760 5410 none 1530 4930 6870 7240 8598 - 9004 L-80 30 - 83318107 - 8513 Structural 7" Baker S-3 7" Camco A-1 8286 / 7794 2090 / 2090 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 2/16/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL 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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 7" 26# x 7-5/8" 29# By Meredith Guhl at 8:30 am, Jan 27, 2023 323-049 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.26 15:32:27 -09'00' DSR-1/30/23 X MGR02FEB22 10-404 DLB 02/02/2023GCW 02/03/23 JLC 2/3/2023 02/03/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.02.03 10:37:02 -09'00' RBDMS JSB 020323 Well Work Prognosis Well Name:NGI-13A API Number:50-029-20347-01 Current Status:Gas Injector Leg: Estimated Start Date:Feb 16, 2023 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:207-114 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~190,000 Mscf/Day Injection Pressure: 3,475 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): NGI-13A is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2019. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. -00 DLB Well Work Prognosis Well Work Prognosis STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS A It n g ^^q. 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operation�hdCdp�ylT /'�❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change 9 P 9r Co Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Water Wash 21 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 207-114 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 21 6. API Number: 50-029-20347-01-00 7 Property Designation (Lease Number): ADL 028302 8. Well Name and Number: PBU NGI-13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9006 feet Plugs measured None feet true vertical 8515 feet Junk measured None feet Effective Depth: measured 9006 feet Packer measured 8286 feet true vertical 8515 feet Packer true vertical 7794 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34 - 114 34-114 1530 520 Surface 2351 13-3/8" 34-2385 34-2385 4930 2670 Intermediate 8464 9-5/8" 32-8496 32-8005 6870 4760 Production Liner 682 7' 8324-9006 7833-8515 7240 5410 Perforation Depth: Measured depth: 8598-9004 feet True vertical depth: 8107-8513 feet Tubing (size, grade, measured and true vertical depth) 7" 26# x 7-5/8" 29.7#, L-80 30-8331 30-7840 Packers and SSSV (type, measured and 7' Baker S-3 Packer 8286 7794 true vertical depth) 7" Camco A-1 SSSV 2090 2090 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: 261000 50 3574 Subsequent to operation: 306085 50 3630 14. Attachments (required per 20MC 25.070.25.071,&25.283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Rl SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-535 Authorized. Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: bmwd2@BP.com Authorized Signature: Date: / eC� O Contact Phone: +1 9075644675 Farm 10-404 Revised 04/2917 1;10 ,0 "rZ (r{,."fjr JAN 0 2020 Submit Original Only Dai PBU NGI-13A ivU=coawovizo i emp=N t i tSU wAbH/rlcKLt) rump down Ibg. w/ 10 bbl 60/40 spear, 204 bbls 80* DSL/Xylene, Displace w/290 bbls Freshwater w/ F103 surfactant. Freeze protected surface lines with 3 bbls 60/40 meth. Let soak 3 hrs. Flushed TBG with 290 bbls Freshwater w/ F103. Freeze protected TBG with 10 bbls 60/40 meth. RDMO. Notified DSO to POI upon LRS departure. 12/13/2019 MV. IA. OA=Oben. SV_ SSV. W\/=Shut FWHP=Rnn/srmx; TAFF - �vn• rxu WELLHEAD= MCEVOY ACTUATOR= BAKER CKB. ELEV = 48' REF ELEV = 51.32' BF. ELEV = 19.54' KOP = 2408' Max AVIe = 33" CM 4453' Dahxn MD = 8967' Dahxn TVD = 8424' S5 w, L-ao Tel, 33 - ID = 6276' !0" CONDUCTOR, 94#, HdO, D = 19.124' I—t 80' Y Minimum ID = 5.77" @ 8310' 7" HES RN NIPPLE 7-5/8" TBG, 29.7#, L-80 VAM TOP HC, 2079' .0459 bpf, D = 6.875" BG, 26#, L-80 TGI, .0383 bpf, D = 6.276' 2102' j l3-3/8" V+F'STOCK (10/15/07) 13-3/8" EZSV (10/13/07) -4 13-3/8" CSC, 72#, W80 BUTT, ID= 12.347" 7-5/8" TBG, 29.7#, L-80 VAM TDP HC, .0459 bpf, ID= 6.675" 8324 9-5/8"X7" BKR G2 ZXP LTP J = 6276' TO eTC M 1 PIN, 9-5/8" CSG, 47#, L-80 8496° HY DRIL 563, D - 8.681" \ SOLD LNR, 26#, L-80 BTC -M, .0383 bpf, D = 6276" 8598' \ \J\ 7" SLTD LNR, 26#, L-80 BTC -M. .0383 bpf, D = 6276' 9006' NGI-13A 1 8253' 1 7" X 7-5/8" XO, D = B-2 7" CAMCO DB -6 NP, D = 600- 7"X 00"7"X 7-5/8' XO, D = 6276" 13-3/8" MILLOUT WINDOW (NGI-13A) 2385'-2408- 13-3/8" 385-2408' X 7" XO, D = 6.276" HES R MP, D = 5963- 9-5/8- X 7" BKR S-3 PKR, ID = 6.00- _H7- HES RN NIP. D = 5.77" 9-518- CSG, 47#, L-80 HYDRL 563 XO PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 0° @ 8598' 7" 1 SLTD 1 8598-9004 w! FN1C LNR HGR, D = 6.350' 8331' 7' MULESHOE, 8331' D - fi.276' 8372' 8350' 7' XO D = 6.276" MENTS DATE REV BYWCKB, DATE REV BY COMMENTS 07108179 PKR 141PLETION 10131107 D14 G143A) 08D4108 KWPJCORRECTDNS 02/11/11 MB/JMDAFETY NOTE 11/19/19 DD/JMDEF 8 BF ELEV PRUDHOE BAY UNR WELL: NGI-13A PERMIT No: 1071140 API No: 50-029-20347-01 BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Don Brown Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU NGI-13A Permit to Drill Number: 207-114 Sundry Number: 319-535 Dear Mr. Brown: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.clogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such 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, J . Price Chair DATED thisD� day of November, 2019. 3BDMSE�✓NOV 2 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 HLCOVED NOV 21 2019 1. Type of Request: ,Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair -Well ❑ j� ❑ ?:/sliujdgwn Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change pp ro m ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Water Wash 0 ` 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ Permit to Drill Number: 207-114 ' 9. Address: P.O. Box 196612 Anchorage, AK r6AP1 99519-6612 Stre[igraphic ❑ Service ® Number: 50-029-20347-01-00 ' 7. If perforating: What Regulation or Conservation Ober governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU NGI-13A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028302 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 1 1 9006 8515 9006 851 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 2351 13-3/8" 34-2385 34-2385 4930 2670 Intermediate 8442 9-5/8" 32-8496 32-8005 6870 4760 Production Liner 682 7" 26# L-80 8324-9006 7833-8515 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8598 - 9004 8107 - 8513 7" 26# x 7-5/8" 29.74 L-80 30-8331 Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8286 / 7794 7" Cam. A-1 SSSV 2090/2090 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 - 14. Estimated Date for Commencing Operations: 12/6/2019 . 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 • Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Brown, Don L. be deviated from without prior written approval. Contact Email: browd2@BP.Com Au[horizetl Name: Brown, Don L. Contact Phone: +1 9075644675 Authorized Title: Petroleum Engineer Authorized Signature: Qono VY ��J.w-{,,.tJy� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BDMS-L�N0V 2 71019 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 —t{ 6'Y APPROVED BYTHE Approved by: a COMMISSIONER COMMISSION Date: I 1 Ji OFIGINAL i�tj�z;z,9 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 10-403 Sundry Application for Well PBU NGI-13A PTD #207-114 Expected Start Date: December 6, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 290900 Mscf/Da Injection Pressure: 3995 psi Reservoir Pressure (Estimate): 3380 psi Program Objective(s): NGI-13A has had several successful water washes historically, the most recent being on 8/15/17. These water washes have been successful, and this water wash is being completed to ensure injectivity remains intact. If this water wash goes to plan, injectivity should improve as the process is designed to dissolve salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. Proposed Program: 1. Pump diesel/xylene water wash as per attached pumping template. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU NGI-13A PTD #207-114 Pump Schedule: 'Nei NGI-13A Work Dead Gas injector §eater ;wash AFE 0 Date 1tt2plt^� Engineer Don Brown Phone i907,-%-4-4:.75 H2S value r wA H25 Date tl;A Gear Increase well injecvvity by performing a water wash. Use 2 full uprights of fresh coater mixed wth 0.02% F-103 surfactant. Use 200 bbls of diesel/xylene. Pump Schedule Staize FluidType, Purm Into vol bbis Rate ) Max Pres' i 1 Spear klethancit'ftiater TBG 10 1-2 3000 2 Sotrent CieseVX,alene TBG 200 Max 3000 3 0-oer-Flush Fresh 'Nater TBG 600 See Below 3000 4 Freeze Protect ktetnarol±':Nater 'BG 1c t ' 3COC 5 6 7 1.) 10 bbl 60(40 McOH/water spear 2.) 200 bbls 50/50 diesel/xylene heated to 80 deerees F or as hat as LRS can heat it. 3.) pump 600 bbis of fresh water with 0.02°s F-103 surfactant per following: a.) Pump 292 bbis or fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut -down pumps and let diesel/xylene soak across perfs for 4 hours - this should allow •- 100 bbis of DIX to be pumped into perfs and a remaining 100 bbis to soak. b.) Resume pumping at 0.5 bpm for next 200 bbls of fresh water with 0.02% F-103 surfactant. c.r Once 492 bbis of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 trpm for remainder of overflush (-108 bbis}. 4.110 bbis of 60(40 McOH/water freeze protect 5.) RDMO. Return well to gas injection. Directions When fining out the pumping template, please note the following: htR g1 TestType Target Pressure Max Pressure Test Fluid Integrity Limits Conferred ❑ M(f #2 Test Type Target Pressure ktax Applied Pressure Test Fluid hie Lents confrmed ❑ hHT *3 Test Type Target Pressure kiax Appliedl Pressure Test Fluid Integrity Limits Confirmed ❑ If "MIT' is selected as a stage, the corresponding MIT section must be filled out. The boxes are defined as follows Test Type: Type of test to be performed (MIT -T, MIT -IA, MIT -OA, etc) Target Pressure: This is the requested Mtt test pressure (ie MIT -T to 2500 psi) Max Applied Pressure: This is the max pressure that can be applied in order to achieve a passing MIT of the target test pressure, typically 10% greater than target pressure. BP practice 100218 (10-45) requires that the test pressure must remain above or equal to the target pressure during the entire test evaluation period. This pressure must not exceed the lowest rated working pressure (taking into account corrosion, erosion, etc) of any well barrier element in the well barrier envelope Test Fluid: The fluid to be used for the test. Integrity Limits Confirmed: By checking this box you have confirmed that the "Max Applied Pressure" requested is within the limits of the yells 'Nell Barrier Envelope BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU NGI-13A PTD #207-114 Wellbore Schematic: TREE= 6-318'CMO 'E FAD- MCFVOY: ACTUATOR BAKER OKB. F.LEV 48' REF etV- 6137. BF. ELEY= 1954,.. IKOP= 2408' iT•TBG264, L-0OTCL -4-33' °MAx Angle-' 33'Q4453' {.0947 bpLD=6276' rDaO MD -. 8967'.. ,__.._ DaE TVD= 8424'55 / L0•CCNDUCTCR9M. HIO, D.19.124• Mlinimum ID 7" HES RN NIPPLE 'r 5r8 -TBG, 29 16,L BC VAM IOPHC. '- 2079' - 0459 bpf, Q 6 875- i ISG, %#. L-80 ICS, 0383 bpf, D 6 276' 2102' f &576• CSG STUB 2454' , 17W CSG, 73F 2708...._ KM BUTT. D .12 _i�.�. ... - 267M, SAFETY NOTES; RM MRESA SSS•` NGI-13A `2079'-{7-5/8'XrXo-D=82'2w f 2080' - -17' CAMCO UB B NP, Q 6 zlor rx7=s�e�za:o-6sis-' --1 13.378'MLL0UTNRAOW (NOI-17A) 2365'-2408' ..._1-,-..._.__,,.. ._. .....,. - .8253' k 7-518'X2%O, D•6278' 8284' !7-hFS RNF', Q5963• 6288' r �S-S!e' % T' 0KR S-3 PKR D' 6 C0' RNWQ $.77' 1.0459 bpf, D=6.875) 8324' 9.5/8'Xf-MRC 21XPLTP w / RMC (W HGR, D 6350- 7' L 6331 r276"10[ TBG, 26M, L-80 TCL, .0383 bpf, D = 6,278' I I 8331' 10-6276" -6 6 976' 95A'GBG, 47M,L-00 T0'O1ti. 569 XO TO BTGM ^- 8;272' '--'..'— '�_ .... .. _. ,— 6350 TXO PN. Q-6276• PERFORATQN SL#AMARY REF LOG ANGLE AT TOP PERF: O.0 8598' I Note Rek bPTdwWnDBbr HaMlta rldaL, I9-578'GSG, 47M, L-80 -6498.:•,. \ SRE 1 SEE NIERYA4_z ' DATE -j fN 563, D=8681• \ \ / 7• SLID 8698 9004 SLOT i 102607 \ r SOLD LNR, 2BM, 1-80 eTGM, .0383 LDf• D a 6.278•--�8(�• � \ \ \ ` 7- SLID LW 260, L-80 STC -M, 0383 bpf, D =8276' BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 PRUDHOE SAYUNR V EL4 WA13A PERMR tW:'101140 API W: 50029-26347-01 BP EXPb" bn Mwka} BY ._...._- COM,INTB....—�, 07)0"FtEVB i(10311p7 680408 02111n1 PKR 014 _ IGIPJC MBUMD OItNS1ALCOMPIETKW..—__-UATB-'RlV .w ._ _ SDETRACK_ I�Ifi417A _ DRLG DRAFT g0Fg CTDN6_. ADDEDSSSVSAFETYNOTE - --"'-1 1Vi&19 _ _ DWJMD ADDED OKS REF SBF ELEV I _ BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 PRUDHOE SAYUNR V EL4 WA13A PERMR tW:'101140 API W: 50029-26347-01 BP EXPb" bn Mwka} MEMORANDUM TO: Jim Regg / P.I. Supervisor,1� ic14��9 FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 3, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. NGI-13A PRUDHOE BAY UNIT NGI-13A Ste: Inspector Reviewed By: P.I. Supry`T� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-13A API Well Number 50-029-20347-01-00 Inspector Name: Brian Bixby Permit Number: 207-114-0 Inspection Date: 9/30/2019 — Insp Num: mitBDB190930144826 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3A 'Type Inj G, TVD 7794 Tubing 3374 - 3366 ' 3362 - 33542071140 F Type Test SPT Test psi 1948 IA 13 2499. 2488 - 2478ped: 3.1 BBL Returned: 2.9 OA 44 53 55 - 55 4YRTST P/ P Notes: Thursday, October 3, 2019 Page I of I • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Water Wash 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-114 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-20347-01-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU NGI-13A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL �rC 11.Present Well Condition Summary: El EE I V E D Total Depth: measured 9006 feet Plugs measured feet 9� true vertical 8515 feet Junk measured feet SEP 1 3 2017 Effective Depth: measured 9006 feet Packer measured 8285 feet true vertical 8515 feet Packer true vertical 7794.55 feet AOGCC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"94#H-40 36-116 36-116 1530 520 Surface 2351 13-3/8"72#N-80 34-2385 34-2385 4930 2670 Intermediate 8442 9-5/8"47#L-80 32-8474 32-7983 6870 4760 Production Liner 682 7"26#L-80 8324-9006 7833-8515 7240 5410 Perforation Depth: Measured depth: 8598-9004 feet feet y r � q True vertical depth: 8107-8513 feet feet SCANNED DEC 1 4 2O i 77 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 7"Camco A-1 SSSV 2090 2090 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8598'-9004'. Treatment descriptions including volumes used and final pressure: 20 Bbls 50/50 Methanol/VVater,200 Bbls 75`60/40 Diesel/Xylene,580 Bbls 120*Fresh Water w/0.02%F-103 Surfactant,550 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -195441 200 3237 Subsequent to operation: -154406 450 3044 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-317 Authorized Name: Oestgaard,Finn Contact Name: Stone,Christopher Authorized Title: Productio Engineer Challenger Contact Email: Christopher.Stone©bp.com Authorized Signature: — Date: 61•"IS-17 Contact Phone: +1 907 564 5518 / i Form 10-404 Revised 04/2017A/4(i 1171 .1171 . JO f 1 7/ 1 o� RBDM S ) C�i7"1 2 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission RECEIVED 333 West Seventh Avenue G Anchorage, AK 99501-3572 SEP 1 3 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 11, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Water Wash Stimulation covered by Sundry Approval # 317-317 for Well NGI-13A, PTD # 207-114. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 s • Q o O O o o O o O o rn � p N d V, 1 d L d' CC) U N o O O O O O O O O M M N- d• C)) d C) dt CC) d) CO N N CX) N o0 N m d O N- CO f— CO I"- 0 LU CO CC) CA r N O 00 M N- O CO d' CO C) 0 CO O I-- CO N CO N N N- N- O I 1 1 1 1 1 1 1 I H N O d N CO CA CO N- O CO CO CO CO CO N CO O (fl LC) d- CO O N M CO N- O M N- O to co co d' O CO O N M L N CO a) N N a) O C) p QC .r M C < ‘— CO d N N O CO N- O C0 M M M M N M O r- N = 00 N N CO • Z ~• CO cp O O O O z 00 CD O O O i co Z J CO CO CO CO • CO CO- eNN (D N C(O CA o0 N N _ N _ N M CA eN CO N 03 O CC) d' N d' co CNC) N = OO M d O M O N ti J (N co O N CO W co O — • W ° .NUUW O O t1 ZZZZZ Z Q W W m 00 CO CO CO O ~ Z » » 0 U) Z =, H H !— I— H . . . Packers and SSV's Attachment PBU NGI-13A SW Name Type MD TVD Depscription NGI-13A SSSV 2090 2089.91 7" Camco A-1 SSSV NGI-13A TBG PACKER 8285.4 7794.55 7" Baker S-3 Packer NGI-13A PACKER 8323.8 7832.95 7" Baker ZXP Top Packer • • A I eL a 0 2 R oo / I— o 0 \ 0 > o q t < 2% / 0 o/ $ 2 2 CU 0 / 0 2 ; •E a) & - . 0 e .473 o Q _7m 2 U E As <L. 0 k / 2 / \ \ 2 0 m a 2E ƒ _ 't 2 ® � Q R ƒ § / / 5 W � / \ E o Et> \ O 0 - ¢ J 2 p 20 « / 7 > 5 A13 2 L. ljj D G \ \ a 9 § m co o ƒ © m / / \ > % 0. G = » » a. m Ce / / \ c G o 6 : o co o w $ y > II 0 0 ° 03 ° % 03 /� / 0® - / � R bj / a ® 7 = •k / \ 2 t f \ / { ƒ© m ± 2 o ± p 7 _ - 2 .g / o / g o = 5 n e ® - r m A m Q = o ag0 _c0D. ._ \ f5 = LC) C 0 ® � ® © •F \ $ o = _ ® 5 5 7 0 �, # e / \,, a__c, c) 0 f a ± 0 .55 E o o / 0 2 C / \ / / A /§ O. ^ r / 2 ± r w ± / ¥ » >- / / Waco / a co_ $ EN \ / 0 \ / < TREE= 6-318"CMJ • WELLHEAD= MCEVOY, SAFETY NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKERR KB.ELEV= 48' BF. ELEV = KOP= 2408' J 33' —Jr"X 7-518"XO, ID=6.276" Max Angle=33°@ 4453' 7"TBG,26#, L-80 TCII, — 33' Datum MD= 8967 .0383 bpf, ID=6.276" Datum TVD= 8424'SS 20"CONDUCTOR,94#, H-40. ID=19.124" 80' Minimum ID = 5.77" @ 8310' 2079° 17-518"X 7"X0, ID=6.276" 7" HES RN NIPPLE 2090' —7"CA MCO DB-6 NIP, ID=6.00" 7-5/8"TBG,29.74,L-80 VAM TOP HC, - 2079' 2102' 7"X 7-5(8"XO, ID=6.276" .0459 bpf, ID=6.875" 7"TBG,26#, L-80 TCII, .0383 bpf, ID=6.276" - 2102' 13-3/8"WHIPSTOCK(10/15/07) —1 2385' 13-3/8"EZSV(10/13/07) H 2415' 13-3/8"MILLOUT WINDOW(NGI-13A) 2385'-2408' 9-5/8"CSG STUB, 2434' A ear 13-3/8"CSG,72#, H 2709' N-80 BUTT, ID=12.347" Va \ 8253' —7-5/8"X 7"XO, ID=6.276" �s 8264' H 7"HES R NIP, ID=5.963" -iii/i 111111 iii iflgra iiiiiiiii�iiii'iN; 8286' """'.""mmi Ill' 9-5/8"X 7"BKR S-3 PKR,ID=6.00" i�.iii 11111 'F iiia,. �inv/iii V MVA i i�MAW �� 8310' —�7"HES RN NIP,ID=5.77" EVAN% 7-5/8"TBG,29.74: 8253' Vr L-80 VAM TOP HC, .0459 bpf, ID=6.875" 8324' 9-518"X7"BKR G2 ZXP LTP 1 tklit w/HMC LNR HGR,ID=6.350" 8331' 17"M6.276" E, 7"TBG,26#, L-80 TCII, .0383 bpf, ID=6.276" 8331' IPIID=6.276" 9-5/8"CSG.47#. L-80 HYDRIL 563 XO TO BTC-M H 8372' 1— 8350° —17"XO PIN, ID=6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF:0°@ 8598' 9-5/8"CSG,47#,L-80 8496' Note: Refer to Production DB for historical perf data HYDRIC 563, ID=8.681" SIZE SPF INTERVAL Opn/Sqz DATE \ 7" SLTD 8598-9004 SLOT 10/28/07 \ \ 7"SOLID LNR,26#, L-80 BTC-M,.0383 bpf, ID=6.276" H 8598' \ \ 7"SLTD LNR, 26#,L-80 BTC-M,.0383 bpf, ID=6.276" H 9006' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/08/79 PKR 141 ORIGINAL COMPLETION WELL: NGI-13A 10/31107 D14 SIDETRACK(NGI-13A) PERMIT No:'2071140 08/04/08 KH/PJC DRLG DRAFT CORRECTIONS API No: 50-029-20347-01 02/11/11 MB/JMD. ADDED SSSV SAFETY NOTE SEC 1, T11 N, R14E,489'FSL&841'FVVL BP Exploration (Alaska) • OFTy • • /,�� THE STATE Alaska Oil and Gas 1, ,;-s � 14 of \ T ccKA Conservation Commission � f£2 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O,°' Y*¢` ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Christopher Stone DS2and18PE BP Exploration(Alaska), Inc. SUMS JUL L 2 0 2017, P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU NGI-13A Permit to Drill Number: 207-114 Sundry Number: 317-317 Dear Mr. Stone: 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, Hollis S. French .�� Chair DATED this day of July, 2017. RBDMS (-LAIL 1 3 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS ' 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 11 ' Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Water Wash 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-114 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0• 6. API Number: 50-029-20347-01-00 • 7. If perforating: 8. Well Name and Num r: What Regulation or Conservation Order governs well spacing in this pool? �� Will planned perforations require a spacing exception? Yes 0 No I3 PBU NGI-13A D 9. Property Designation(Lease Number): 10. Field/Pools: JUL 1 0 2017 ADL 0028302 • PRUDHOE BAY,PRUDHOE OIL • 01. 7��/? 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk 9006 . 8515 . 9006 • 8515 ' Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 36-116 35-115 1530 520 Surface 2351 13-3/8"72#N-80 34-2385 34-2385 4930 2670 Intermediate 8442 9-5/8"47#L-80 32-8474 32-7983 6870 4760 Production Liner 682 7"26#L-80 8324-9006 7833-8515 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8598-9004 8107-8513 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 7"Camco A-1 SSSV 2090, 2090.32 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 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: Stone,Christopher be deviated from without prior written approval. Contact Email: Christopher.Stone@bp.com Authorized Name: Stone,Christopher Contact Phone: +1 907 564 5518 Authorized Title: DS 21./ ji ..._ Authorized Signature: Date: . ../14-7,.. t^.... COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3r7-3 « Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 027 Spacing Exception Required? Yes 0 No Subsequent Form Required: `D -404, APPROVED BYTHE '•� Approved by: COMMISSIONER41PCOMMISSION Date: l'' I' - "t �\l RBDMS I,u JUL 1 3 2017 /\'ORIGINAL 1h17/ a l I-i Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED CEIVED JUL 10 2017 RE: BP Exploration (Alaska), Inc. �� Report of Sundry Approvals (10-403) C July 7, 2017 To Whom it May Concern: Attached please find the Sundry Application for a Water Wash on Well NGI-13A, PTD # 207-114. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: NGI-13A Well Type: Gas Injection Well API Number: 50-029-20347-01 Well Activity Conventional 4 Classification: Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: TREAMENTS Estimated Cost, $K: AWGRS Job Scope: TUBING WASH/PICKLE Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Well Intervention Engineer: Jamin Laplante Contact numbers: 907-365-9140 907-564-4137 Lead Engineer: Chris Stone Contact numbers: (907)564-5518 (907)440-4011 Date Created: June 28, 2017 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 6/26/2017 209,460 3,273 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date, ppm) NA 0 ppm Maximum Deviation(Angle and 33° 4,453' MD Depth) Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 9° 2,420'MD Reservoir pressure(date, 9/6/2015 3,436 psi Minimum ID and Depth 5.770" 8,310' MD psig) Reservoir Temp, F 138°F Shut-in Wellhead Pressure Est.2550 psi Known mech.integrity None problems(specifics) Last downhole operation(date, operation) 9/7/2015 Set 6"Al SSSV at 2090.' Most recent TD tag(date,depth, 9/6/2015 8955'SLM 3.50"Cent, 2.0"SB toolstring OD) . Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, NGI-13A is a gas injector that was sidetracked in October 2007 and completed with a slotted liner across background information, the reservoir. The last water wash was pumped 8/24/14 and saw an--25 mmscfpd increase in injection etc: rates. The job pumped 82 bbls 50 F diesel/xylene, 595 bbls 100 F fresh water w/0.02%F-103 surfactant. Recently, the performance of this injector has started to degrade, prompting the need to perform a water wash. This wash will use D/X at a reduced concentration of 60/40 in an attempt to see if positive results can be achieved in line with the successful water wash that was pumped in 2014. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work v$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Reduced injectivity due to depositions. Specific Intervention or Well Objectives: 1 Pump diesel/xylene water wash to restore injectivity by cleaning perfs and tubing. 2 3 Key risks,critical issues: Mitigation plan: 1 High pressure pumping Use pressure cross check checklist Use extreme caution and ensure all personal on 2 Gas Injection Well location are aware of pressure sources and well barriers. Follow well entry gas pad wellwork section 3.8 Reducing the ratio from 50/50 pumped on previous water wash jobs to 60/40 D/X for 2017 water wash 3 Increased diesel/xylene ratio optimization and economic study.Results will be evaluated and water wash strategy updated.Accept risk of potentially less effective water wash Review MSDS pre-job,discuss safety precautions/gear, 4 Working with Xylene how to handle spills,how to handle contact to personal to ensure personal know how to respond Summary Service Line Activity Step# 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 FB Pump diesel/xylene water wash as per attached pumping template. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Post water wash return well to gas injection service. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • • Q 0 0 0 0 0 0 0 0 0 co N (` CO r r O r O r N L V CC) U y 0 0 0 0 0 0 0 0 0 L. M M Nt6) V' CA 11- 1.0 • IC) 0) 00 N N CO N CO N m V CO I- N- CO N- CO 1"-- 01 M 1C) O r N O CO 00 M I"- O CO V M 0) CC) M O N- 00 `- N N. CO N N N- I"- • i I— M O N CO Nr N CO O CO I- O CO M M M CO N M O I� N- N N f- w Nt CO O N (fl CO O M I- O LO M O M O N CO • N CO O N N 00 CO V M 2 I 1 I 1 QV O N co CO '.;:t N N O) CO I- O I-0 CO0MMMMNC') Q N • Z CO N NCO -0 0 • co O O CO Q 0 °000 _j0 _j0 • Z 00 00 00 (0 C -T- N *k J J J J (I) _ CO CO N CO N CO O L4-+p N N _ N _ N Mrn LC) LO N- ti N N M N Lo r- C co0co V 0 M O N - I� G) N co M N co W O • W W cu• p < 2 00000 OOWEtOZZZZZ Z CCW W m m m m m O DZ > > > D D U) Z- H I- I- I- i 0 Packers and SSV's Attachment PBU NGI-13 SW Name Type MD TVD Depscription NGI-13A SSSV 2090 2089.91 7" Camco A-1 SSSV NGI-13A TBG PACKER 8285.4 7794.55 7" Baker S-3 Packer NGI-13A PACKER 8323.8 7832.95 7" Baker ZXP Top Packer TREE= 6-3/8"UN WELLHEAD= MCEVOY 0s JOY NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKER N 01-1 3A KB.ELEV = 48 BE ELEV= KOP= 2408': 33' " . " 7"TBG, 26#, L-80 TCII, — 33' I —7"X 7-5/8XO, ID=6276 ) Max Angle=33'@ 4453' Datum MD= 8967 .0383 bpf, ID=6.276" Datum TVD= 8424SS 20"CONDUCTOR,944, H-40, ID=19.124" 80' 2079' —7-5/8"X 7"XO, ID=6.276" 7" HES RN NIPPLE Minimum ID = 5.77" @ 8310' 22019002 �7°77.:XCA7M-5C/80,,DBO-.6IDNI=P61.0=2766;00" 7-5/8"TBG,29.74, L-80 VAM TOP HC, —1 2079' .0459 bpf, ID=6.875" 7"TBG.26#, L-80 TCII, .0383 bpf, ID=6.276" — 2102' 13-3/8"WHIPSTOCK(10/15/07) —I 2385' 13-3/8"EZSV (10/13/07) — 2415' 13-3/8"MILLOUT WINDOW(NGI-13A) 2385'-2408' 9-5/8"CSG STUB 2434' 13-3/8"CSG,72#, H 2709' 1A\ 8253' —7-5/8"X 7"XO, ID=6.276" N-80 BUTT, ID=12.347" , AA\ ,irmab• 8264' —17"HES R NIP, ID=5.963" t7mNrop .000m" ,ArArmAroaffs ,oitawiriPmgmff ,000000ArimArgr.A ,offragamiffarmommiA. 1, 8286' H9-5/8"X 7"BKR S-3 PKR,ID=6.00" ."if Si;SSA I rifirifiliff;_gqi vffra" AfA 1 8310' —17"HES RN NIP, ID=5.77" IA ifil I:FA:lit)la Ai!ra r- 7-5/8"TBG, 29.74. 8253' tiP 'raw yr' L-80 VAM TOP HC, .0459 bpf, ID=6.875' 8324 9-5/8"X7"BKR C-2 ZXP LTP WI HMC LNR HGR, ID=6.350" 8331' —7"MULESHOE, 7"TBG,26#, L-80 TCII, .0383 bpf, ID=6.276" — 8331' 1ID=6.276" 9-5/8"CSG,47#,L-80 HYDRIL 563 XO TO BTC-M H 8372' I— 8350' H 7' XO PIN, ID=6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERE:0'@ 8598' 9-5/8"CSG,474,L-80 8496' \ Note: Refer to Production DB for historical pert data HYDRIL 563, ID=8.681" 1 SIZE SPF INTERVAL Opn/Sqz DATE \ 7" SLTD 8598-9004 SLOT 10/28/07 \ , \ . \ \ \ 7"SOLID LNR,26#, L-80 BTC-M, .0383 bpf, ID=6.276" H 8598' \ 7"SLTD LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276" H 9006' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/08/79 PKR 141 ORIGINAL COMPLETION WELL: NG-13A 10/31/07 014 SIDETRACK(NGI-13A) PERMIT No:'2071140 08/04/08 KH/PJC DRLG DRAFT CORRECTIONS API No: 50-029-20347-01 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 1,T11N,R14E,489'FSL&841'FWL BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,September 14,2015 P.I.Supervisor ' ,Pfei Ulq(E. SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NGI-13A FROM: Lou Grimaldi PRUDHOE BAY UNIT NGI-13A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry dr — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-13A API Well Number 50-029-20347-01-00 Inspector Name: Lou Grimaldi Permit Number: 207-114-0 Inspection Date: 9/12/2015 Insp Num: mitLG150912182735 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-13A -Type Inj G'TVD 7794 Tubing 1 3375 ' 3374• 3372 - 3372 - 3372 _ 3369 - t f - IA 6 2568 2571 2555 2538 2533 PTD I 2071140 Type Test SPT Test psi 1948 { Interval 4YRTST P/F P ' 1 OA 46 62 63 63 62 62 Notes: Problems with Thermal expansion in IA caused this test to be held for 2 hours thirty minutes for stabilization.Pretest pressures are as found and Initial through 60Min represent final 60 minutes of test.3.76 bbl'd iesel pumped form 6 psi up and 3.1 bbl's bled back to 200 psi. ,, Confidence in results is adequate. ✓ Monday,September 14,2015 Page 1 of 1 • . Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, September 12, 2015 9:26 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Sayers, Jessica; Pettus, Whitney Subject: OPERABLE:Injector NGI-13A (PTD #2071140) AOGCC MIT-IA Passed All, Injector NGI-13A(PTD#2071140) passed an AOGCC witnessed MIT-IA to 2500 psi on September 12, 2015 confirming two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED MAY0 ,2r �Q16 BP BP Alaskas -Well Integrity Coordinator SCAN WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, September 09, 2015 5:27 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace©alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Sayers, Jessica; Pettus, Whitney Subject: UNDER EVALUATION: Injector NGI-13A (PTD #2071140) Place on Injection for Compliance Testing All, Injector NGI-13A (PTD#2071140) was due for its AOGCC MIT-IA in July of 2015 and is now ready o be placed on injection. At this time,the well has been reclassified as Under Evaluation to facilitate with compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, September 09, 2015 5:27 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Sayers, Jessica; Pettus, Whitney Subject: UNDER EVALUATION: Injector NGI-13A (PTD #2071140) Place on Injection for Compliance Testing All, Injector NGI-13A(PTD#2071140) was due for its AOGCC MIT-IA in July of 2015 and is now ready to be placed on injection. At this time,the well has been reclassified as Under Evaluation to facilitate with compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus (.Alternate: Kevin Parks) BP Alaska -Well Integrity Coordinator G SCANNED SEP 0 9 2015 WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator(n)BP.com From: AK, C Well Integrity Coordinator Sent: Thursday, 36, 2015 9:31 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Supern�tendent; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integri oordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Injector NGI-13A (PTD #2071140) Due for AOGCC MIT-IA All, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, July 30, 2015 9:31 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE:Injector NGI-13A (PTD #2071140) Due for AOGCC MIT-IA Attachments: Injector NGI-13A (PTD #2071140) TIO PIotl.docx All, Injector NGI-13A(PTD#2071140) is due for an AOGCC MIT-IA on 07/31/2015. We will not be able to perform the MIT-IA due to SIMOPS on the pad. The well is reclassified as Not Operable and will be added to the quarterly Not Operable Injector Report until the SIMOPS issues are resolved. A copy of the TIO plot is included for reference. Thank you Kevin Parks BP Alaska Well Integrity Coordinator sCANNED JUL 3 .0 2015 G1/�/ Global Wells V�/ Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com 1 • • In~~~~ ~'rQ~~~# U1(~II ~~~i~t+~ry File ~ca~r~r Pace XHVZE This page identifies those iterns that were not scanned drtring thy: initial production scanning phase. They are available in the original fife, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ 1 ~- Well History File Identifier Organizing (cone) RES AN C for Items: Greyscale Items: ^ Poor Quality Originals: ^ Other: ~,wo,aee uiuimuiuuiu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: o Re.v~~e~~ iuumi~uium OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: / ~ D /s/ Project Proofing III II ~I II I I III II III BY: Maria Date: /~ /s/ Scanning Preparation _~ x 30 = ~~ + f S =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~~~ / 5~t~ ~ /s/ Production Scanning III II'lll VIII II III Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scannin Pre aration: ___4,~ TES NO BY: Maria Date: ! ~ ~ ~ ~ /s/ ~~/~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO Y BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II I I III Rescanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III IIII II ~_ P P 10/6/2005 Well History File Cover Page.doc • voF77 ��\1'/%i s THE STATE '� e��a I 2 -r. ,rd 2 7 ' / ` 17--- ''''2.,_ !` r� 4. / is ut ,_ __ 333 West Seventh Avenue F GovEItv'QR SEAN PARNLI.I. Anchorage Alaska 99501-3572 ," •,' ( it 907 779 1/33 Al Ae'- SC *5) Javier Farinez / j GPB GDE Lead PE a 6) ,--7F "] BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-13A Sundry Number: 314-212 Dear Mr. Farinez: 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, / 19a,,,_js__ Cathy P Foerster -- /' Chair DATED this tG day of April, 2014. Encl. RE D STATE OF ALASKA SPR 2 x • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS GC ' 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Water Wash 0, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill umber. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 207-114-0 3.Address: 6.API Number. Stratigraphic ❑ Service 0 , P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20347-01-00 . 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU NG-13A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 ' PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9006 . 8515 ' 9006 8515 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 29-109 29-109 Surface 2357 13-3/8"72#N-80 28-2385 28-2384.89 4930 2670 Intermediate 8474 9-5/8"47#L-80 29-8503 29-8012.15 6870 4760 Production None None None None None None Liner 680 7"26#L-80 8324-9004 7833.15-8513.12 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8598-9004 8107.15-8513.12 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(1t): See Attachment for Packer Depths 7"Camco A-1 SSSV 2090'.2089.91' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and- rrect to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name avier arinez Title GPB GDE Lead PE Signature Phone 564-5043 Date y j vi f GI Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3`LL.— 2`2„. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 6, Other: RBDMS____ MAY 1 0 2014 Spacing Exception Required? Yes ❑ No u Subsequent Form Required: u / APPROVED BY Approved by: A COMMISSIONER THE COMMISSION Date: 4__../ ./ Form 10-403l7evised 10/2012 6RoleGriNA, lid for 12 months from the date of approval. Submit Form and Attachments in Duplicate KL- , 4! 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J () I— HHRH Packers and SSV's Attachment ADL0028302 Well Facility Type MD Top Description ND Top NGI-13A SSSV 2090 7"Camco A-1 SSSV - 2090 NGI-13A PACKER 8286 :7" Baker S-3 Packer 7795 NGI-13A PACKER 8324 7" Baker ZXP Top Packer 7833 TREE 5,• 6-3/8"CM/ WELLHEAD= MCEVOY NGI 13 A SAFc1 Y NOTES: WELL REQUIRES A SSSV. ACTUATOR= BAKER KB.ELEV= 48 BF.ELEV= KOP= 2408' FP---") l I 33' 7"X 7-5/8"XO,ID=6.276" I 7 TBG,26#,L-80 TCII, — 33' Max Angle=33°@ 4453' Datum MD= 8967 0383 bpf,ID=6.276" Datum TVD= 8424'SS 20"CONDUCTOR,94#,H-40,ID=19.124" — 80' Minimum ID = 5.77" @ 8310' /\ 2079' —7-5/8"X 7"XO,ID=6.276° 7" HES RN NIPPLE11( —I2090' 7"CAMCO DB-6 NIP, ID=6.00" 7-5/8"TBG,29.7#,L-80 VAM TOP HC, — 2079' 2102' —17"X 7-5/8"XO,ID=6.276" .0459 bpf, ID=6.875" 7"TBG,26#,L-80 TCU, .0383 bpf, ID=6.276" —I 2102' 13-3/8"WHIPSTOCK(10/15/07) —I 2385' 13-3/8"EZSV(10/13/07) —I 2415' 13-3/8"MILLOUT WINDOW(NGI-13A) 2385-2408' 9-5/8"CSG STUB — 2434' 13-3/8"CSG,72#, H 2709' N-80 BUTT, ID=12.347" \\ 8253' 7-5/8"X 7"XO,ID=6.276" iiia ;110,4, 8264' —i 7"HES R NIP, ID=5.963" i 100100iiii o* 8286' H 9-5/8"X 7"BKR S-3 PKR,ID=6.00" �;!iiiiimmfino i l!r r 1;i ilii to- 8310' —17"HES RN NIP, ID=5.77" IF wir ilii I $ v r i�ii 7-5/8"TBG,29.7#, 8253' L-80 VAM TOP HC, 0459 bpf,ID=6.875" 8324' —9-5/8"X7"BKR C-2 ZXP LTP w/HMC LNR HGR, ID=6.350" 8331' 11 7"MULESHOE, 7"TBG,26#, L-80 TCII,.0383 bpf,ID=6.276" 8331' ID=6.276" 9-5/8"CSG,47#,L-80 HY DRIL 563 XO TO BTC-M H 8372' 8350' —17"XO PIN, ID=6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF:0°@ 8598' 9-5/8"CSG,47#,L-80 8496' \ Note: Refer to Production DB for historical perf data I IYDRIL 563, ID=8.681" SIZE SPF INTERVAL Opn/Sqz DATE \ \ 7" SLTD 8598-9004 SLOT 10/28/07 \ \ \ 7"SOLID LNR,26#,L-80 BTC-M,.0383 bpf, ID=6.276" H 8598' \ \ 7"SLTD LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276" H 9006' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/08/79 PKR 141 ORIGINAL COMPLETION WELL: NGI-13A 10/31/07 014 SIDETRACK(NGI-13A) PERMIT No:'2071140 08/04/08 KH/PJC DRLG DRAFT CORRECTIONS AR No: 50-029-20347-01 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 1,T11 N,R14E,489'FSL&841'FWL BP Exploration (Alaska) ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3,DBR,LHD,cAZ 01/15/14) General Information Well Name: NGI-13 Well Type: Injector API Number: 500292034701 Well Activity Classification: Conventional 4 Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, SM: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 N/A N/A 240.MMscfpd N/A N/A N/A 3,270 PSI Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 ppm Maximum Deviation(angle and depth) 33° 4,453'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 5.77"It 8,310' Reservoir pressure(date,psig) N/A 17,47C-7;7 Reservoir temperature,F 194°F Shut in wellhead pressure 2,520 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 12/5/2007.SSSV Maintenance Most recent TD tag,(date,depth,toolstring OD) 12/5/2007.8,981'SLM 9004'w/3.50"Cent&S.Bailer Comments,well history, Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used r/ background information,etc: successfully in the past on the NGINVGI/AGI gas injectors to improve injectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectevity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 • 2 3 Summary Step Service Line Activity 1 F Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Peri form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 05, 2011 TO: Jim Regg t I/ P.I. Supervisor �� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -13A FROM: Bob Noble PRUDHOE BAY UNIT NGI -13A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .1 NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -13A API Well Number: 50- 029 - 20347 -01 -00 Inspector Name: Bob Noble Insp Num: mitRCN110802163021 Permit Number: 207 -114 -0 Inspection Date: 7/31/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -13 (Type Inj. G ' TVD 7794 - 1 IA 1 230 2500 - 2490 i 2520 1 P.T.D 207114o TypeTest SPT Test psi 1948 • OA 80 335 330 370 Interval 4YRTST - Phi P , Tubing 3155 j 3175 3135 3135 Notes: Injection gas was very hot. The pressure increase could be because of thermal. U' r k't Friday, August 05, 2011 Page 1 of 1 ~~, _ ~, ~~ .~~ ~:,~,~ ~~ ~. . », MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microftlm Marker.doc Gas Injector Volume Calculations~Flow meters replaced Page 1 of 1 ~ Regg, James B (DOA) From: NSU, ADW Well Integriry Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~ ~ Sent: Wednesday, May 27, 2009 9:46 AM ~~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Engel, Harry R; Rossberg, R Steven; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; NSU, ADW Well Integrity Engineer; GPB, FS1 Fac Engr Subject: Gas Injector Volume Calculations -- Flow meters replaced Attachments: Gas Injector volume calculations.xls Jim, ~ / The flow meter on NGI-13 was blocked in on 03/29/09 returned to surface on 05/11/09; as this transmitter developed a small gas leak and was removed from service at that time. It wasn't until later that the lower design pressure was noticed on this and other transmitters, at which time the remainders were blocked in. The flow meters on NGI-01. 03 04. 05. 08. 12 were blocked in on 04/23/09.~nc~.nla~ed back in service on 05/12/09. The pressure-rate data for operation before and after this time was extrapolated graphicall to determine the rates for the time the transmitters were blocked in. Allowing them to operate or a short time after they were put back in service has been helpful in assuring the most accurate representation of the time they were out of service. I have attached a spreadsheet containing daily rates and pressures, as well as the graphical analysis completed to obtain the data for the time the transmitters were out of service. «Gas Injector volume calculations.xls» ~ Please call with any questions or concerns. c~;~.~ ~ Thank you, ~°'°- ,~~~ ,~G~._ o I 175-6~ Andrea Hughes Well Integrity Coordinator ~~~,,~ ~(j'- D 3 175-bLl Office: (907) 659-5102 A:`~,~~~~ ~Q~~ ~~- ~ ~~~~ Pager: (907) 659-5100 x1154 p~~ ~;~T ~~{ I"7S-D(~~ P ~'~u- NG~- 05 r~~-~c~c~ ~'g~ ~s . ~s~ ~~~-~~s-~ ~~u ~~~ - ~ z_ r7~-~~,~ f'~Lt Nc~-- i 3~ Z.~ ~- r~~ 8/6/2009 • • SUMMARY OF INJECTED VOLUMES DURING FLOW TRANSMITTER OUTAGE Volume Tubing Injected Pressure Date (MCFPD) (psi) NGI-01 05/12/09 119,210 3,165 05/11/09 117,670 3,148 05/10/09 136,884 3,360 05/09/09 144,134 3,440 05/08/09 143,228 3,430 05/07/09 145,131 3,451 05/06/09 143,681 3,435 05/05/09 140,146 3,396 05/04/09 140,509 3,400 05/03/09 142,865 3,426 05/02/09 141,868 3,415 05/01 /09 140, 871 3,404 04/30/09 135,796 3,348 04/29/09 135,977 3,350 04/28/09 134,708 3,336 04/27/09 133, 530 3, 323 04/26/09 140,056 3,395 04/25/09 142,503 3,422 04/24/09 140,328 3,398 04/23/09 138,515 3,378 NGI-03 05/12/09 110,330 3,450 05/11/09 110,692 3,455 05/10/09 110,836 3,457 05/09/09 111, 053 3,460 05/08/09 113,151 3,489 05/07/09 113,657 3,496 05/06/09 113,006 3,487 05/05/09 112 , 211 3, 476 05/04/09 113,947 3,500 05/03/09 113,368 3,492 05/02/09 114,814 3,512 05/01 /09 114, 091 3, 502 04/30/09 113,874 3,499 04/29/09 112,934 3,486 04/28/09 112,138 3,475 04/27/09 111,487 3,466 04/26/09 113,802 3,498 04/25/09 113,947 3,500 04/24/09 114, 091 3, 502 04/23/09 114,742 3,511 NGI Volume Calculations ~ ~ . NGI-04 05/12/09 112,110 3,070 05/11 /09 112,143 3,050 05/10/09 111,633 3,356 05/09/09 111,437 3,474 05/08/09 114, 568 1, 595 05/07/09 113,765 2,077 05/06/09 111,428 3,479 05/05/09 111,498 3,437 05/04/09 111,488 3,443 05/03/09 111,445 3,469 05/02/09 111,460 3,460 05/01/09 111,488 3,443 04/30/09 111,587 3,384 04/29/09 111,575 3,391 04/28/09 111,603 3,374 04/27/09 111,630 3,358 04/26/09 111,493 3,440 04/25/09 111,450 3,466 04/24/09 111,490 3,442 04/23/09 111,410 3,490 NGI-05 05/12/09 179,667 3,375 05/11/09 179,789 3,380 05/10/09 179,910 3,385 05/09/09 180,007 3,389 05/08/09 179,813 3,381 05/07/09 180,299 3,401 05/06/09 179,935 3,386 05/05/09 179,010 3,348 05/04/09 179,108 3, 352 05/03/09 179,667 3,375 05/02/09 179,472 3,367 05/01 /09 179,156 3, 354 04/30/09 177,892 3,302 04/29/09 178,062 3,309 04/28/09 177, 721 3, 295 04/27/09 977,405 3,282 04/26/09 179,108 3,352 04/25/09 179,667 3,375 04/24/09 179,156 3,354 04/23/09 180,178 3,396 NGI-08 05/12/09 150,117 3,470 05/11/09 150,117 3,470 05/10/09 150,117 3,470 05/09/09 149,821 3,467 05/08/09 148,833 3,457 05/07/09 151,599 3,485 05/06/09 150,117 3,470 ' 05/05/09 145,869 3,427 05/04/09 146,067 3,429 05/03/09 148,438 3,453 NGI Volume Calculations 2 ~ ! 05/02/09 147, 351 3,442 05/01 /09 145, 573 3,424 04/30/09 139,744 3,365 04/29/09 140,535 3,373 04/28/09 138,954 3,357 04/27/09 137,275 3,340 04/26/09 145,672 3,425 04/25/09 148,142 3,450 04/24/09 145,968 3,428 04/23/09 151, 006 3,479 NGI-12 05/12/09 179,508 3,400 05/11/09 179,508 3,400 05/10/09 179,508 3,400 05/09/09 181,429 3,419 05/08/09 180,216 3,407 05/07/09 179,508 3,400 05/06/09 179,508 3,400 05/05/09 177,485 3,380 05/04/09 177,587 3,381 05/03/09 180,014 3,405 05/02/09 179,002 3,395 05/01/09 177,283 3,378 04/30/09 171,721 3,323 04/29/09 172,429 3,330 04/28/09 170,912 3,315 04/27/09 169,294 3,299 04/26/09 177,485 3,380 04/25/09 180,014 3,405 04/24/09 178,193 3, 387 04/23/09 182,946 3,434 NGI-13 05/10/09 246,658 3,350 05/09/09 246,368 3,341 05/08/09 246,078 3,332 05/07/09 246,754 3,353 05/06/09 246,497 3,345 05/05/09 243,279 3,245 05/04/09 245,306 3,308 05/03/09 245,692 3,320 05/02/09 245,660 3,319 05/01/09 243,247 3,244 04/30/09 240,80'! 3,168 04/29/09 243,955 3,266 04/28/09 243,375 3,248 04/27/09 243,086 3,239 04/26/09 245,370 3,310 04/25/09 246,078 3,332 04/24/09 245,564 3,316 04/23/09 246,979 3,360 NGI Volume Calculations 3 ~ 04/22/09 247,494 3,376 04/21 /09 246, 979 3, 360 04/20/09 247,366 3,372 04/19/09 247,333 3,371 04/18/09 247,301 3,37p 04/17/09 247,301 3,370 04/16/09 246,658 3,350 04/15/09 246,722 3,352 04/14/09 245,821 3,324 04/13/09 244,244 3,275 04/12/09 243,536 3,253 04/11 /09 239,160 3,117 04/10/09 243,729 3,259 04/09/09 244,051 3,269 04/08/09 244,823 3,293 04/07/09 246,304 3,339 04/06/09 247,816 3,386 04/05/09 247,591 3,379 04/04/09 247,816 3,386 04/03/09 248,234 3,399 04/02/09 248,363 3,403 04/01/09 245,692 3,320 03/31/09 243,987 3,267 03/30/09 246,175 3, 335 03/29/09 247,237 3,368 03/28/09 249,103 3,426 03/27/09 248,588 3,410 03/26/09 245,757 3,322 03/25/09 245,049 3,300 03/24/09 245,049 3,300 NGI Volume Calculations ~ 4 155, 000 150,000 145,000 0 140,000 ~ NGI-01 y = 90.632x - 167640 135,000 130, 000 ~ ` ~, . , : . ~ ~ ,. , ~ ~ , , _. _ .. w. 125, 000 3,300 3,350 3,400 3,450 3,500 3,550 pressure ~ ~ NGI-03 140,000 120, 000 i 100,000 80,000 w ~ ~ 60,000 40,000 20, 000 0 3,350 3,400 3,450 3,500 3, 550 3,600 ~ PRESSURE y = -1.6665x + 117226 160, 000 140, 000 120, 000 100,000 w ~ 80,000 ~ 60,000 40,000 NGI-04 • r~ LJ 20,000 0 3,300 3,350 3,400 3,450 3,500 PRESSURE 3, 550 3,600 ~ NGf-05 182, 000 181,500 181,000 180, 500 180, 000 m ~ ~ ~ 179, 500 179,000 178, 500 178,000 177,500 y = 24.302x + 97587 3,300 3,320 3,340 3,360 3,380 3,400 Pressure 3,420 3,440 3,460 3,480 ~ ~ ~ NGI-08 160,000 155,000 i 150,000 m ~ 145,000 140,000 135, 000 y = 98.79x - 192684 ~ 130,000 , . , , ;, . 3,300 3,350 3,400 3,450 3,500 3,550 3,600 Pressure • NGI-12 200,000 195,000 190, 000 185,000 d ~ 180,000 175,000 170,000 rate = 101.13(pressure) - 164334 • C~ 165,000 160,000 ~ 3,300 3,350 3,400 3,450 3, 500 3,550 Pressure NGI-13A 260,000 255,000 ~J 250,000 245,000 w ~ ~ 240,000 235,000 ~ 230,000 225,000 2,500 2,600 2,700 2,800 2,900 3,000 3,100 3,200 3,300 3,400 3,500 PRESSURE UPDATE: NGI Flow Transmitter~ • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) Sent: Monday, May 04, 2009 2:11 PM ~~~~~ ~'~ /~ To: Regg, James B (DOA) ~` ~ ~ ~ Cc: GPB, FS1 OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FS1 Fac Engr; Rossberg, R Steven; NSU, ADW Well Integriry Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len i; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: UPDATE: NGI Flow Transmitters Jim, After further evaluation, it has been decided to leave the underrated flow transmitters on the seven NGI wells isolated until the fullv rated transmitters are available for replacement. The fully rated transmitters are expected to arrive on the slope on May 13th and work to install them is planned to begin on May 15th. After the transmitters are replaced, calculations wiil be made to determine injection volumes and rates for the time the meters were out of service. We will also provide our calculation and the exact number of days the fiow meters ~ were out of service. We will continue to update you on the status of the replacements. If you have any questions in the interim, please don't hesitate to contact me or Anna Dube. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Engel, Harry R Sent: Thursday, April 23, 2009 4:57 PM To: James Regg Cc: GPB, FSS OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FSi Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: NGI Flow Transmitters Jim- This is a follow up to our telephone conversation this afternoon regarding flow transmitters at ~ NGI pad. The NGI 13 flow transmitter failed on March 29th. There was a minor gas release associated with the failure, far below 1 MMSCF. The flow transmitter was found to be underrated, yet the 8/6/2009 UPDATE: NGI Flow Transmitter~ Page 2 of 2 ~ body is fully rated. We discovered six additional underrated flow transmitters at NGI 1, 3. 4. 5, 8, 12. All seven flow transmitters have been temporarily taken out of service. The wells remain on injection. No other gas injection well flow meters are affected. We have taken the following actions; a. Contacted the manufacturer and ordered metal backed Viton O rings which will increase transmitter operating pressure rating. These O rings will be installed in all seven wells within 1'~ week. This is a temporary modification until new transmitters are installed. b. New fully rated transmitters have been identified and will be installed in all wells in ~ approximately 2-6 weeks. Flow rates will be calculated during the periods when the transmitters are out of service. / As you requested, we will send you the flow rate calculation method and the total number of ~ days the transmitters were out of service. I will be out of the office for a few days next week. If you have any questions, please contact Andrea Hughes at 659-5102. Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 8/6/2009 DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071140 Well Name/No. PRUDHOE BAY UNIT NGI-13A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20347-01-00 MD 9006 TVD 8515 Completion Date 10/31/2007 Completion Status 1GINJ Current Status 1GINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / • Scale Media No Start Stop CH Received Comments Cement Evaluation "I "Log Cement Evaluation D C Las 15913/Gamma Ray pt LIS Verification rtD C Lis 16477~Gamma Ray I ~ Gamma Ray o G amma Ray D C // 17128 S N I v ee otes Well Cores/Samp les Information; Name ADDITIONAL INFOR Well Cored? / Chips Received? ~'YTI~ Analysis 1`tIV~ Received? 5 Col 1 90 8480 Case 11/19/2007 Cement Bond, and Image Lig w/PDC, USIT-D, CBL, GPIT, GR 28-Oct-2007 5 Col 1 90 8480 Case 11/19/2007 Cement Bond, and Image Lig w/PDC, USIT-D, CBL, GPIT, GR 28-Oct-2007 2100 9006 Open 1/24/2008 LAS GR and ROP in PDF and EMF graphics 8965 9006 Open 6/19/2008 LIS Veri, GR, ROP 8965 9006 Open 6/19/2008 LIS Veri, GR, ROP 25 Col 2440 9006 Open 11/3/2008 MD GR, ROP 28-Oct-2007 25 Col 2440 9006 Open 11/3/2008 TVD GR, ROP 28-Oct-2007 0 0 Open 11/3/2008 PDS, EMF and CGM of GR logs Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ,~N DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071140 Well Name/No. PRUDHOE BAY UNIT NGI-13A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20347-01-00 MD 9006 TVD 8515 Completion Date 10/31/2007 Completion Status 1GINJ Current Status 1GINJ UIC Y Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: NGI-13A October 29, 2008 AK-MW-5193767 NGI-13A: 2" x 5" & GAMMA RAY Logs: 1 Color Log 50-029-20347-01 2" x 5" T . TY & GAMMA RAY Logs: 1 Color Log 50-029-20347-01 l.-q, vnwt ~t ~ ~ (~ Digital Log Images: ~ 1 CD Rom 50-029-20347-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska} Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907-273-3536 Date: - Signed:( i~ ~/ U7C ao"~--cr~~~t~-rah NGI-13A (PTD #2071140) - I~ressure Trend is Due to Thermal Effe~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ Sent: Friday, July 18, 2008 9:42 AM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Winslow, Jack L.; Senden, Leslie B; NSU, ADW Well Integrity Engineer Subject: NGI-13A (PTD #2071140) - IA Pressure Trend is Due to Thermal Effects / Attachments: NGI-13 TIO, Injection and Temperature Plots.doc All, The IA pressure trend observed on NGI-13A (PTD #2071140) after the last bleed on 719/08 closely follows ambient temperature trends. I have attached a document containing a 10 plot, injection plot and an ambient temperature plot. There is no automated data to obtain the gas injection temperature for NGI-13A, so I obtained ambient temperatures from www.Weather.com for reference. It is evident that the bleeds were needed when the ambient temperatures were higher than current temperatures, likely due to the fully liquid packed annulus. A bleed has not been needed since 719/08 and the TIOs from yesterday were recorde a 0/0/170; when the ambient temperature reached a high of 47 degrees Fahrenheit. The well has been added to the Monthly Injection Report for further TIO monitoring. «NGI-13 TIO, Injection and Temperature Plots.doc» Please call with any questions or concerns. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 10, 2008 4:22 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FSi DS Ops Lead; GPB, FSl OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Senden, Leslie B; Hughes, Andrea Subject: NOTIFICATION OF BLEEDS: NGI-13A (PTD #2071140) IA pressure bleeds Hi all, Well NGI-13A (PTD #2071140) has had two recent bleed events. The IA pressure was bled down 2050 psi to 700 psi on 7/1/08 returning all fluid. The IA pressure was again bled down from 2000 psi to 1000 psi on 7/9/08. It is suspected that the increase in IA pressure is due to ambient effects and changes in injection rates. To be sure, the wellhead pressures will be closely monitored for the next week. An update with another TIO plot will be sent at that time. The plan forward includes: 1. Well Integrity Coordinator: Notify the AOGCC of bleeds -DONE 9/5/2008 NGI-13A (PTD #2071140) - I~ressure Trend is Due to Thermal Effe Page 2 of 2 2. Well Integrity Coordinator: Monitor wellhead pressures 3. Well Integrity Coordinator: Send an update to the AOGCC by 7/17 including a TIO plot A TIO plot, injection plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, Anna ~Du6e, ~1'.~ Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 9/5/2008 Pa~c ~~s -~ ~.~ , ~ z~~- ~, 4 .,.~+ '~ ~ ~~ ~.~~ i~ (~ ~/ OA 1S ~ 1~ ~~ r l l L • L • L • L ~~~~ ~~ • l ~ • 'l!' 1 yl 1• L • L L l~f r .L. 1 tl r ~ ~ t r i OEd?a'~i3 l:.,'s'^~~8 06A]bY~ C~14,"~'~_ Cfi;'~?r03 ~f~'~8;'f~8 O'i~108 ~',1GC Ambient Temperature 70 65 .. .m ~ 60 m r ~i 55 `o~ 50 m D 45 40 O ~ N W A Of ~I ~- i ~-oY~ a Q 0 a 0 ~n 0 a r r~ w ~ o o ' T { T V A) w~ 1 M a 2 Arrg WHIP, psig oaa'tr ooo'~ oao'Z oaa' 4 f ~ T T r 1'~ a 0 _~ ti 0 0 aaa' aoo aoa' a~z ooa' o$ ~ oao' oz ~ aao' os o OdIM~kBla~~W `U~kSfU~10+U~kd~I~W{~~ `t ~~ I N ~` I ,\ ~' :~ ~.I s' Q O O ~ `~ Oyy O Oii T T _ _ --; ~._. o a a a o a v- ri TREE = 6-3/8" CNU WELLHEAD MCEVOY ACTUATOR BAKER KB. ELEV = 48' BF. ELEV = KOP = 2408' Max Angle = 33` @ 4453' Datum MD = 9057' Datum TVD = 8s>15' SS 7" TBG, 26#; L-80 TCII, ~-~ 33' .0383 bpf, ID = 6.276" 20" CONDUCTOR; 94#, H-40, ID = 19.124" $d' Minimum ID = 5.77" @ 831 U' 7°' HES RN NIPPLE 7-518" TBG, 29.7#, L-80 VAM TOP HC, - 2079' ,0459 bpf, ID = 6.875" 7" TBG, 26#, L-80 TCIl, .0383 bpf, ID = 6.276" 23{j2' 13-318" WHIPSTOCK {10/15107} 2385' 13-318" EZSV {10/13/07) ~ 2435' ~. 9-5/8" CSG STUB I~ 2434' 13-318" CSG, 72#, N-80 BUTT, ID = 12.347" 9-518" CSG, 47#; L-80 HYDRIL 563, ID = 8.681" 7-5f8" X 7" XQ ID = 6.276" 7" HES R NIP, ID = 5.963" 9-5/8" X 7" BKR S-3 PKR, ID = 6.00" 7" HES RN NIP, ID = 5.77" 7-518" TBG, 29.7#, L-80 VAM TOP HC, .0459 bpf, ID = 6.875" N ® a S NOTES: I 8253° I E 7" TBG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" ~ 8333' 9-518" CSG, 47#, L-80 HYDRIL 563 XO TO BTGM $372' PERFORATION SUMMARY REF LOG: ???? ANGLE AT TOP PERF: 0° @ 8598' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 7" SLID 8598 - 9004 St_OT 10128107 7" X 7-518" XO, ID = 6.276" 7-518" X 7" XO, ID = 6.276" 7" CAMCO DB-6 NIP, ID = 6.00" 7" X 7-518" XO, ID = 6.276" 13-3(8" MILLOUT WINDOW (NGI-13A} 2385' - 2408' 7" SOLID LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" 8598' 7" SLTD LNR, 26#, L-80 BTGM; .0383 bpf, ED = 6.276" 9006' 9-518" X7" BKR G2 ZXP LTP w / HMC LNR HGR, ID = 6.350" 7" MULESHOE, ID = 6.276" i~- 7" XO PIN; (D = 6.276" DATE REV BY COMMENTS DATE REV BY ', Q71Q8179 PKR 141 ORIGINAL GOM PLETION 101311Q7 D14 SIDETRAGK(NGI-13A} 06!06108 ?/ PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: NGI<13A PERMIT No: 2071140 API No: 50-029-20347-01 SEC 1, T11N, R14E, 489' FSL & 841' FWL BP Exploration {Alaska) WELL L®G TRANSMITTAL To: State of Alaska June 10, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: NGI-13A AK-MW-5193767 1 LDWG formatted CD rom with verification listing. API#: 50-029-20347-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 _- ~' i ?~ Date: Signed: ~/(/~ by Date 01-24-2008 Transmittal Number:92926 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv Questions, please contact Douglas Dortch at the PDC at 564-4973 Contents B ~a~-lay ~~s°,i~ Jo'~ - (og ~ ~s9 rc~ 14Aa C~`~+ 102 # (5°i l a GI-13A J~C2D~-- (t~( ~ ! SS(3 V Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~~~~~t~ 41id Sas Cons. Cornonias;$~,~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 MEMORANDUM To: Jim Regg '7 P.I. Supervisor ~~CZ~ f Z ~~ ~~i/ FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 10, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-13A PRUDHOE BAY UNIT NGI-13A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv'~~~ Comm Well Name' PRUDHOE BAY UNIT NGI-13A Insp Num: mitLG0 7 1 209 1 4475 1 Rel Insp Num: API Well Number 50-029-20347-01-00 Permit Number 207-114-0 Inspector Name: Lou Grimaldi Inspection Date• 12/9/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ NGI-13A~Type Inj. ~ CT ~ TVD I 7794 I IA 650 j 4010 '~ ~ 3960 3950 ~ P T ~ zo7l Iao '~TypeTe 1st SPT ~~ Test psi ~ ~ I6o j z3o ~ aooo /1 OA zoo ~i 200 ~ Interval IMTAL P~)lj` P ~ Tnbmg ~ 3250 3250 ------ 3250 ~ 3250 i NOteS' 3.2 bbl's pumped. Pos[ rig workover initial MIT. Good test. ,/ Monday, December l0, 2007 Page 1 of I '• STATE OF ALASKA O-D~ ~~~~~'~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ 0 6 2087 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Dil & Gas Cons. Commission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ® GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well 4)f9j~@ ^ Development ^ Exploratory ®Service , ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/31!2007 12. Permit to Drill Number 207-114 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/17/2007 13. API Number . 50-029-20347-01-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/28/2007 14. Well Name and Number: PBU NGI-13A 489 FSL, 840 FWL, SEC. 01, T11N, R14E, UM Top of Productive Horizon: 5' FSL, 2929' FWL, SEC. 01, T11N, R14E, UM 8. KB (ft above MSL): 51.32' Ground (ft MSL): 15. Field /Pool(s): _ Prudhoe Bay Field / Prudhoe Bay Total Depth: 8' FSL, 2927' FWL, SEC. 01, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 9006 8515 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 687016 y- 5972801 Zone- ASP4 10. Total Depth (MD+TVD) 9006 8515 16. Property Designation: , ADL 028302 TPI: x- 689116 y- 5972370 Zone- ASP4 Total Depth: x- 689114 y- 5972373 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rimed information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed i rmation per 20 C 25.071): MWD, DIR, GR, PWD, USIT L//rYDos/ ~ ~,,~~,S-,r~o a3~~ 9;-~0 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH'TVD' HOLE AMOUNT WT. PER FT. GRADE > TOP BOTTOM ' TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 74' Surface 74' 20" 277 sx Arcticset Cement 13-3/8" 72# N-80 Surface 23 Surface 2385' 17-1/2" 4800 sx Arcticset II 9-5/8" 47# L-80 32' 8496' 32' 80 5' 1 -1 /4" 614 sx Lit Crete 379 x CI s 'G' 7" 26# L-80 8324' 9006' 7833' 8515' 8-1/2" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24: `, TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Slze and Number): SIZE DEPTH SET MD PACKER SET MD 7" Slotted Liner ~^ x ~-sis^, 2s# ~ zs.~#, L-80 / TCII 8331' 8286' MD TVD MD TVD 8597' - 9006' 8106' - 8515' 25. AGID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 100 Bbls Diesel 26. PRODUCTION TEST Date First Production: November 27, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Injection Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal t Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None f~:.~/~ r Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ B® ~.< UL~ ~ ~ ~QOy ~T* 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Sag River 8537' 8046' None TSHA 8585' 8094' TSHB 8600' 8109' TSHC 8621' 8130' Top of Sadlerochit 8628' 8137' 42SB 8663' 8172' 23SB 8824' 8333' 22TS 8883' 8392' 21 TS 8910' 8419' Top of Zone 1 B 8946' 8455' TDF /Zone 1A 8984' 8493' Formation at Total Depth (Name): TDF /Zone 1A 8984' 8493' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true nd correct to the best of my knowledge. ~ Signed Sondra tewman Title Drilling Technologist Date ' lJ~ - PBU NGI-13A 207-114 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Kris Honas, 564-4338 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Ire 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 .Revised 02/2007 Submit Original Only TRH = s-3/8" cNv WELLHEAD= GRAY ACTUATOR= BAKER KB. ELEV = 29.65 BF. ELEV = KOP = 2408' Max Angle = 33 Q 4453' ~~ Datum MD = 90ob Datum TVD= 8515' SS DRLG DRAFT N G I-13A 7-5/8' TBG, 29.7#, L-80, ~C VAM TOP, .0459 bpf, D = 6.875 TBG, 26#, L-80, TGB, .0383 bpf, D = 6.276 Minimum ID = 5.770" ~ 8309' 7" HES RN NIPPLE i13-318" WHPSTOCK 13-3/8" EZ5V6 (t0Y26106) 1-80, ID = 12.347" 2385 SAFETY NOTES: 2079• -17-5/a" x 7" xo, D = s.27s" i 2090• 7" CA MCO DB LANDING NP, D = 6.00" 2103' 7" x 7-s/s" xo, ID = 6.27x" 13-318" MILLOUT WMDOW 2385' - 2408' I /-SJtl- x i- xo, u = u-zici- 7" HES R NIP, ID = 5.963" ~~ 7-518" TBG, 29.7#, L-80, IPC VAM TOP, .0459 bpf, ID = 6.875 T' TBG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" 8331' 9-5/8" 47#, L-80, Hydrd 563 Casing -$496' PERFORATION SINNiMRY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sgz DATE SLOTTED 859TJ9006' I9-5/8" X 7" BKR S-3 PKR, D = 6.00" ~ 7" HES RN Nom, D = 5.770" j "-8324' 9-518" X 7" BKR ZXP PKR w / HMC HGR , D = 6.37" 8331' 7" MULE SHOE, ID = 6.276" 7" SOLD LNR, 26#, L-B0, L~~~~ BTGM, .0383 bpf, D = 6.276' ~ \ 7" PERFORATED LNR, 26#, L-80, BTGM, .0383 bpf, D = 6.276" 9006' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/08/79 OR1gNAL COMPLETION 11/15/06 RRDJTLH IBP PULLEDJWRP SET (1012006) 09/18/06 TEL/TLH IBP SET 10/29!07 D14 NGI-13A SIDETRACK 09/29/06 RRD/PJC PULL 8 RESET IBP 11/07/07 RDW/TL CORRECTIONS (7" TBG WFO) 09/30/06 JCMIPAG PULL IBP & ~P FISH t 1119/07 DSMIPJC TREE/ ACTUATOR CORRECTIONS 10/01JOfi RRDJPAG RESET BKR IBP 10/10/06 CJN/TLH IBP FISH PRUDHOE BAY UNfT WELL: NGF13A PERMfT No: # API No: 50-029-20347-01 Sec. 1, T11 N, R14E, 2531.95 FEL 4999-09 FNL BP Exploration (Alaska) ~ ~ BP EXPLORATION = Page 1 of 19' Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date I From - To I Nours I Task Code I NPT I Phase I Description of Operations 9/24/2007 00:00 - 00:30 0.50 MOB P PRE 00:30 - 16:00 15.50 MOB P PRE 16:00 - 18:00 2.00 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 00:00 5.00 RIGU P PRE 9/25/2007 00:00 - 12:00 12.00 RIGU N WAIT PRE 12:00 - 21:30 9.50 RIGU N WAIT PRE 21:30 - 00:00 2.50 RIGU N WAIT PRE 9/26/2007 00:00 - 12:00 12.00 RIGU N WAIT PRE 12:00 - 00:00 12.00 RIGU N WAIT PRE 9/27/2007 00:00 - 12:00 12.00 RIGU N WAIT PRE 12:00 - 00:00 12.00 RIGU N WAIT PRE R/D, prepare to move off location Move rig to NGI-13 Prepare to raise Derrick on the side of NGI Pad. -Remove front & rear booster tires. PJSM. Raise Derrick. PJSM. Rig up. -Clean and clear Rig floor -Hook up steam lines. -Prep all cables and hoses. Raise front wind wall and install braces -Skid rig floor into drilling position -Lower bridle lines, LD sheave and hang bridle lines in derrick -Lower C-section -Build BOP stack -Remove and break down block trolly -Install top drive goose neck and bale brace - PU top drive -Install upper top drive roller, remove bale brace and install lower top drive support brace Accept rig at 00:01 9-25-07 Cont. building BOP stack - RU top drive service loops - Mobilize rig tongs, IBOP and saver sub -Slide conveyor out into position -Move out block hanging roller assy. -Install auger into rock washer -Install upper and lower IBOPs and saver sub. Commission top drive -Prepare rig floor for painting -Install PASON weight indicator Waiting on wind speed to slow down to pull off well house and prepare well site to spot rig. Wind speed still too high to safely remove well house Cont. commissioning top drive -Change out grabber /bell guide to 5" (top drive) -Work on camera mount -Split BOP stack and reorient annular -Hook up koomey lines and kill line to stack -Torque IBOP and saver sub -Install 3 lock rings, torque and wire tie -Lower stand pipe and install valves -Clean and paint drawworks Wind speed still too high to safely remove well house Cont. working on stand pipe and mud manifold -Remove bale stabilizer -Remove hanging shackle from blocks -Install bales and 5" elevators -Cont. painting drawworks and tugger -Wiring driller console, PASON and camera system -Attach secondary fall arrester -Install heaters in cellar -Finish commissioning top drive -Attach kelly hose -Install cement stand pipe -Hang tongs -Attach hole fill line -Cleaning pipe shed -Painting rig floor Waiting on wind speed to slow down and remove well house Install derrick camera -Cont. preparing rig floor -Clean and paint rig floor and console guard - RU rig floor -Adjust kelly hose and stand pipe -Install glycol heaters in cellar Cont. adjusting kelly hose -Paint floor in pipe shed -Install camera mounts in pits and cellar -Cont. installing and calibrating PASON -Readjust elect. service loops (top drive) - Secure all guards for driller's console -Test run joystick for pipe skate -Clear rig floor of all unnecessary equipment - Secure all guards for hydraulic lines -Run camera line down derrick side -Service air slips and dress w/ 5" dies -Attach snub lines and EZTOROUE lines to tongs -Attach landings to Printed: 12/4/2007 8:41:30 AM • BP EXPLORATION Page 2 of 19 Operations Sumlmalry .Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date- From - To Hours Task Code NPT Phase Description of Operations 9/27/2007 12:00 - 00:00 12.00 RIGU N WAIT PRE BOP -Attach service loop rings -Set CROWN-O-MATIC Note: Removed well house and flow line -Install BPV- Prepare site 9/28/2007 00:00 - 03:00 3.00 RIGU N WAIT PRE Secure service loops -Finish painting in pipe shed Prepare well site -Lay down herculite and rig mats 03:00 - 03:30 0.50 MOB N WAIT PRE Skid rig floor to moving position 03:30 - 07:00 3.50 MOB P PRE Move rig down pad and spot on well -Spot and berm rock washer -Prepare rig pits -Hook up tiger tank -Skid rig floor to drilling position 07:00 - 09:00 2.00 RIGU P DECOMP RU line to OA - RU cellar dike -Fill pits w/ 9.8 ppg brine -Pull tree cap 09:00 - 10:00 1.00 WHSUR P DECOMP RU DSM lubricator -Pull BPV - RD DSM lubricator 10:00 - 11:00 1.00 WHSUR P DECOMP Pressure test OA to 2,000 psi x 30 min. Chart test 11:00 - 13:00 2.00 WHSUR P DECOMP RU line from tubing to hard line and tiger tank. Test w/ air and then test w/ brine to 1,000 psi. Blow down lines 13:00 - 14:00 1.00 WHSUR P DECOMP Pump down the annulus 9.8 ppg brine @ 3 bpm-190 psi without returns. At 31 bbls pressure began to increase to 860 psi. Shut down pumps and pressure held. No returns. Bleed off pressure 14:00 - 14:30 0.50 WHSUR P DECOMP Blow down lines - RU lines to pump down tubing and take returns to pits. 14:30 - 16:00 1.50 WHSUR P DECOMP Pump 9.8 ppg brine down tubing, taking returns to pits @ 6 bpm-1,100 psi -Dump diesel returns (dump 74 bbls) -Let diesel migrate x 30 min -Pump 10 bbls until clean -Blow down lines 16:00 - 17:00 1.00 WHSUR P DECOMP RU DSM lubricator -Install BPV - RD DSM lubricator -Install Cameron test dart 17:00 - 18:30 1.50 WHSUR P DECOMP RU line to IA -Test BPV to 1,000 psi f/ below x 30 min. Chart test 18:30 - 20:00 1.50 WHSUR P DECOMP RU on tree and test against test dart to 4,000 psi x 5 min. Chart test - RD test equipment and drain tree 20:00 - 20:30 0.50 WHSUR P DECOMP Terminate and blank off control lines on tree 20:30 - 22:00 1.50 WHSUR P DECOMP ND tree and adapter flange -Actuate LDS to check they are free -Confirm hanger thread with XO 22:00 - 00:00 2.00 BOPSU P DECOMP NU spacer spool and BOP 9/29/2007 00:00 - 02:30 2.50 BOPSU P DECOMP NU BOP - CO upper rams to 4 1/2" X 7" -Install secondary valve on IA -Confirm 3 1/2" x 6" variables in lower rams 02:30 - 04:00 1.50 BOPSU P DECOMP RU to test BOP w/ 5" test joint 04:00 - 11:30 7.50 BOPSU P DECOMP Test BOP and related equipment as per BP / AOGCC regulations. Test to 250 psi low - 4,000 psi high (annular preventer to 250 psi low - 3,500 psi high). RD 5" test joint. RU 7" test joint and test upper rams to 250 psi low - 4,000 psi high. Chart tests. Tests witnessed by WSL, Tourpusher and AOGCC Rep. (Chuck Scheve). 11:30 - 12:00 0.50 BOPSU P DECOMP RD testing equipment -Blow down lines -Vac out stack 12:00 - 13:00 1.00 FISH P DECOMP Dry rod out Cameron test dart - RU to pull back pressure valve w/ lubricator 13:00 - 14:00 1.00 FISH N WAIT DECOMP Wait on DSM 14:00 - 16:00 2.00 FISH P DECOMP RU DSM lubricator -Pull BPV - RD DSM lubricator 16:00 - 19:00 3.00 FISH P DECOMP MU spear assy. -Engage tubing hanger and pull /work tubing progressively to 350k until tubing came loose. Conduct derrick inspection after tubing came loose. Printed: 12/4/2007 8:41:30 AM BP EXPLORATION: Page 3 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/29/2007 19:00 - 20:30 1.50 PULL P DECOMP Pull tubing hanger to surface -Circulate soap sweep surface - surface @295 gpm - 320 psi 20:30 - 21:00 0.50 PULL P DECOMP RU to POH 7" tubing and control lines 21:00 - 00:00 3.00 PULL P DECOMP Break spear and LD tubing hanger - POH and LD 7" tubing (tight connections), recovering control lines. Both control lines broke off down hole @ +/- 950', and were recovered again @ +/- 1,200' 9/30/2007 00:00 - 02:30 2.50 PULL P DECOMP Cont. POH and LD 7" tubing (tight connections), recovering control lines to SSSV - LD SSSV Recovered 27 clamps Total jtts LD to this point: 53 jtts 7" tubing IJ4S 02:30 - 03:00 0.50 PULL P DECOMP RD control line spool and hydraulic hoses 03:00 - 05:30 2.50 PULL P DECOMP Cont. POH and LD 7" 8Rd tubing Total jtts LD overall: 99 jtts + 14.49' cut jt. 05:30 - 07:30 2.00 PULL P DECOMP Clean and RD casing tools - PU spear, make service breaks and LD -Clear rig floor -Install wear bushing ', 07:30 - 10:30 3.00 DHB P DECOMP RU E-line - MU tools -Run 8.3 gauge ring and junk basket to 3,518' (WLM) 10:30 - 12:30 2.00 DHB P DECOMP Make 2nd run w/ gauge ring and junk basket to 3,518' (WLM) 12:30 - 17:00 4.50 EVAL P DECOMP Run USIT/GR/CCL log -Log from 3,480' to 200' -Take repeated section from 2,450' to 2,200' 17:00 - 19:30 2.50 DHB P DECOMP MU 9-5/8" EZSV plug and run on E-line -Set ESZV plug @ 3,500' 19:30 - 20:00 0.50 DHB P DECOMP RD E-line 20:00 - 21:00 1.00 DHB P DECOMP RU testing equipment and chart recorder -Test EZSV plug to 2,000 psi x 10 min. Chart test - RD testing equipment 21:00 - 00:00 3.00 PULL N RREP DECOMP Rig service: clean wind walls -Paint dog house floor -Paint support brace for top drive rails Waiting for top drive PLC to replace damaged one 10/1/2007 00:00 - 12:00 12.00 PULL N RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: paint centrifuge room, paint motor room walls 12:00 - 00:00 12.00 PULL N RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: painting in mud pits, rock washer, mud pumps and motor room walls. Paint ears on top drive. Adjust bridle line in derrick. Put new cable on stabbing board countervveight. Start to install heat exchanger on CAT #1. Glue rubber into gaps on ceiling in motor room. Clean up around parts bin. 10/2/2007 00:00 - 12:00 12.00 PULL N RREP DECOMP Cont. servicing /painting on rig while waiting for top drive PLC to replace damaged one: stuff rubber into cracks in wind wall and screen room. Paint stand pipe, cement line, back stair landings, driller's console, pipe shed floor and CATS #1 & #2. Remove and clean under rotary table. Repair (weld) table lock. 12:00 - 16:00 4.00 PULL N RREP DECOMP Service /paint in rig while fixing top drive: clean wind walls. Paint lines in pump room and motor room. Fix glycol drip under drawworks. Glue rubber into cracks between walls in pit room -Finish repairing top drive 16:00 - 18:00 2.00 PULL P DECOMP MU BHA w/ 9-5/8" casing cutter -RIH on 5" DP singles to 840'. BHA hang @ 650' and 840'. Decide to POH to run 9-5/8" scraper 18:00 - 19:00 1.00 PULL P DECOMP POH and LD casing cutter 19:00 - 22:00 3.00 CLEAN P DECOMP MU 8-1/2" bit and 9-5/8" scraper and RIH w/ 5" DP by stands, Printed: 12!4/2007 8:41:30 AM t $P EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date I From ~ To I Hours I Task I Code I NPT Phase I Description of Operations 10/2/2007 19:00 - 22:00 3.00 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 PULL P 10/3/2007 00:00 - 00:30 0.50 PULL P 00:30 - 01:30 1.00 PULL P 01:30 - 04:00 2.50 PULL P 04:00 - 05:00 I 1.001 PULL I P 05:00 - 06:30 I 1.501 PULL I P 06:30 - 07:30 1.00 PULL I P 07:30 - 09:30 2.00 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 11:00 I 1.00 I PULL I P 11:00 - 13:00 I 2.001 PULL I P 13:00 - 15:00 2.00 PULL P 15:00 - 17:00 2.00 PULL P 17:00 - 18:30 1.50 PULL P 18:30 - 19:30 1.00 BOPSU P 19:30 - 20:30 1.00 BOPSU P 20:30 - 21:30 1.00 BOPSU P 21:30 - 22:30 I 1.001 PULL I P 22:30 - 23:30 1.00 PULL P 23:30 - 00:00 0.50 PULL P 10/4/2007 00:00 - 01:00 1.00 PULL P 01:00 - 02:00 1.00 PULL P 02:00 - 09:30 7.50 PULL P 09:30 - 11:00 I 1.501 PULL I P DECOMP and then in singles from pipe shed, to 2,645' DECOMP CBU @ 318 GPM - 240 psi DECOMP POOH f/ 2,645' to BHA DECOMP LD bit and scraper - MU BHA w/ 9-5/8" casing cutter DECOMP Finish MU BHA w/ 9-5/8" casing cutter DECOMP RIH w/ casing cutter to 2,446' DECOMP Locate collar @ 2,444'. PU and cut 9-5/8" casing @ 2,434'. POH and locate collar @ 2,326'. Run in and cut 9-5/8" casing @ 2,334' DECOMP Close annular preventer. Line up OA to tiger tank. Attempt to circulate out OA to tiger tank w/ none to very little returns. Pressure build up to 880 psi @ 3.5 bpm DECOMP POH to 2,200'. Attempt cut 9-5/8" casing @ 2,200' w/ 5.8 bpm, 800 psi - 75 rpm, 3.5k tq - No progress DECOMP Observe well - POH DECOMP Inspect and change knives on cutter -RIH to 2,195' DECOMP Pumping w/ 3.5 bpm 320 psi -Locate last cut attempt w/ knives at 2,200' -Begin rotating w/ 75 rpm, 3k tq -Begin pumping w/ 5.5 bpm 720 psi -Observe torque increase -Increase pump to 800 psi -Observe 500 psi pressure drop - "OA" pressure increase to 180 psi DECOMP Stop pumps - PU to tool joint -Close annular -Pressure to 1500 psi w/ no returns -Bleed pressure -Pressure up to 1500 psi -Returns observed at slop tank -Establish circulation w/ 3.5 bpm, 1340 psi -Shut down DECOMP PJSM - RU Hot Oil truck to pump down DP -Test lines to 2500 psi -Pump 125 bbls 100 deg diesel down DP w/ 2 bpm, 1250-450 psi taking returns out "OA" to slop tank -Displace diesel from DP w/ 40 bbls "Safe Surf O" and seawater pill at 140 deg. - 4 bpm, 720 psi DECOMP Allow diesel to soak in "OA" DECOMP Pump 40 bbls of soap pill @ 168 GPM - 690 psi, 61 bbls of diesel @ 84 GPM - 450 psi and 40 bbls high vis -Circulate w/ 9.8 ppg brine until clean @ 223 GPM -1850 psi DECOMP POH and LD casing cutter DECOMP Putl wear ring -Install test plug DECOMP C/O top rams to 9-5/8" DECOMP RU to test top rams w/ 9-5/8" test joint -Test top rams to 250 psi low - 4,000 psi high. Chart tests - RD 9-5/8" test joint and testing equipment -Pull test plug DECOMP MU 9-5/8" spear -Back out LDS -Engage mandrel hanger and pull casing to rotary table (250k to pull loose - 165k PUWT) DECOMP CBU staging pumps f/ 150 - 318 GPM @ 60-300 psi. DECOMP LD spear DECOMP Break out and LD mandrel hanger -Clear rig floor - RU elevators - MU head pin DECOMP Circulate to balance columns 200 GPM @ 200 psi DECOMP POH and LD 9-5/8" casing from cut @ 2,200'. Tight connections: breaking connections w/ rig tongs before applying casing tongs. Initial PUWT: 145k -Recovered 55 jts + cut joint (34.20') + 11 centralizers DECOMP Clean Arctic pack from casing tools and rig floor -Clean and unplug drip pan under rig floor - LD casing equipment - Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date I From - To I .Hours ( Task: I Code I NPT Phase I Description of Operations 10/4/2007 110:30 - 14•.00 1.50 BOPSU~P 14:00 - 15:30 ~ 1.50 PULL I P 15:30 - 16:30 1.00 PULL JI P 16:30 - 17:30 1.00 PULL P 17:30 - 18:30 ~ 1.00 ~ PULL I P 18:30 - 22:30 4.00 PULL P 22:30 - 00:00 1.50 PULL P 10/5/2007 00:00 - 00:30 0.50 PULL P 00:30 - 02:00 1.50 PULL P 02:00 - 03:00 1.001 FISH ( P 03:00 - 08:00 ~ 5.001 FISH I P 08:00 - 09:30 1.50 FISH P 09:30 - 11:00 1.50 FISH P 11:00 - 13:00 2.00 FISH P 13:00 - 14:30 I 1.501 FISH I P 14:30 - 22:00 ~ 7.501 FISH I P 10/6/2007 100:00 - 04.30 4.501 FISH P 04:30 - 08:00 I 3.501 FISH I P 08:00 - 10:00 I 2.001 FISH I P 10:.00 - 13:00 I 3.001 FISH I P 13:00 - 15:00 I 2.001 FISH I P 15:00 - 16:00 1.00 FISH P 16:00 - 17:00 I 1.00 i BOPSUFI P DECOMP Mobilize spear assembly to floor. DECOMP Install test plug -Change top rams to 4 1/2" X 7" variables DECOMP Test top rams w/ 5" test joint to 250 psi low - 4000 psi high. Chart test - RD test equipment -Pull test plug -Install wear ring DECOMP MU spear, BS, jars, 9- 6 1/4" DC's and accelerator jar DECOMP RIH to 2,135' DECOMP Screw in T.D. -Obtain parameters -PUW 107k -SOW 110k - Break circ. w/ 2 bpm 60 psi -tag fill /arctic pack at 2,170' (30' above fish) -Increase pump to 9 bpm 350 psi -Attempt to wash down w/ no success -Rotate w/ 25 rpm and wash down to engage fish at 2200' -Rotate 2 turns left to set grapple - Jarring on fish w/ 140k over -Fish free -Pull up to 2,135' dragging 90k to 190k over DECOMP Circulate out arctic pack -Clean same from shakers and troughs DECOMP Pump out of hole w/ fish due to swabbing DECOMP Stand back HWs and DCs - LD jars DECOMP LD spear DECOMP LD fish: 8.85' 9-5/8" casing stump + 3 jtts 9-5/8" casing + 8.45' casing cut jt. Recovered also 2 centralizers (1 broken) DECOMP Clear /clean rig floor - RD casing false table - C/O elevators - Mob. BHA to rig floor - RU wash pipe false table and tools DECOMP PJSM - MU 11-15/16" washover shoe + 4 jtts 11-3/4" wash pipe. Cont MU rest of BHA (drive sub, jars, DCs, HWDP) DECOMP Cut excess drilling line -Slip line DECOMP Service top drive -Adjust brakes on drawworks DECOMP RIH f/ 510' to 2,090', screwing into top drive on every stand. Started taking weight @ 2,090' DECOMP Wash and ream down to top of fish @ 2,336' - 50 RPM @ 2-5k torque, 295 GPM@ 240-360 psi. PUWT: 110k, SOWT: 105k, ROTWT: 105k DECOMP Washover 9-5/8" casing (fish) f/ 2,336' to 2,348'. 50-100 RPM @ 10-15k torque, 84-340 GPM. Tag hard on last 2' and mill without pumps for 3 hrs. DECOMP POH to change washover shoe DECOMP Stand back BHA DECOMP LD bumper sub and oil jars -Stand back one stand of wash pipe -Attempt to break out washover shoe w/ no success - LD bottom joint of wash pipe w/ washover shoe DECOMP PU new joint of wash pipe - MU shoe -RIH w/ wash pipe and Dc's DECOMP RIH w/ DP screwing in to every joint w/ T.D. (Running over) to 2,295' DECOMP Screw in T.D. -Obtain parameters -PUW 115k -SOW 115k - ROT 115 w/ 3-5k tq -Break circulation w/ 3 bpm 60 psi -wash over top of fish at 2,336 w/ no issues -Tag at 2,343' -Milling / washing over f/ 2,343' to 2,345' w/ 70-100 rpm 7-13k tq - 5-15k weight on shoe - 2,345' all torque dropped off - No progress DECOMP Observe well - POH DECOMP Stand back DC's - LD jars -Stand back 1 stand wash pipe - Bottom joint of wash pipe and shoe left in hole. DECOMP Clear /clean floor -Pull wear ring -Install test plug - RU to test BOP Printed: 12/4/2007 8:41:30 AM BP EXPLORATION- Page s of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/6/2007 17:00 - 21:30 4.50 BOPSU P DECOMP Test BOP and related equipment as per BP / AOGCC regulations. Test to 250 psi low - 4,000 psi high (annular preventer to 250 psi low - 3,500 psi high). Test w/ 5" test joint. Chart tests. Test witnessed by WSL and Tourpusher. Bob Noble, AOGCC Rep, waived witness of test 21:30 - 22:30 1.00 BOPSU P DECOMP RD testing equipment -Pull Test plug -Install wear bushing 22:30 - 00:00 1.50 FISH P DECOMP Mobilize tools to rig floor - MU spear assembly, bumber sub and jars 10/7/2007 00:00 - 01:00 1.00 FISH P DECOMP MU DCs and HWDP 01:00 - 02:00 1.00 FISH P DECOMP RIH on 5" DP to 2,288' -Screw in TD and check parameters - RIH and tag fish @ 2,318' -Engage fish 02:00 - 03:30 1.50 FISH P DECOMP POH w/ fish to HWDP 03:30 - 04:30 1.00 FISH P DECOMP Stand back HWDP and DCs -Pull spear assembly with fish - Disengage and LD spear assembly - LD jars assembly - C/O elevators -Break washover shoe f/ fish - LD joint of wash pipe 04:30 - 05:30 1.00 FISH P DECOMP C/O elevators - PU wash pipe stand f/ derrick and RIH -Break out 6-5/8 REG pin x 4-1/2 IF box XO f/ top of drive sub - MU 6-5/8 REG lifting sub and stand back wash pipe in derrick - Clear floor 05:30 - 08:00 2.50 FISH P DECOMP MU Multi string cutter -RIH to 2,269' 08:00 - 09:00 1.00 FISH P DECOMP Obtain parameters -PUW 107k -SOW 110k -Continue to RIH - Enter 9 5/8" stub at 2,336' w/ no issues -Continue RIH to 2,400' -Screw in TD -Pumping w/ 500 psi -Locate casing collar at 2,405' - PU to spot knives at 2,400' -Cut casing at 2,400' w/ 70 rpm, 900 psi -Observe total pressure loss of 650 psi -Set down on cut w/ no pump, no rotary -Pull up to 2,364' - Locate collar at 2,366' -Spot knives and cut casing at 2,361' as before. 09:00 - 10:00 1.00 FISH P DECOMP POH to BHA 10:00 - 11:00 1.00 FISH P DECOMP Stand back DC's -Service break cutter - LD cutter bullnose and stab. 11:00 - 11:30 0.50 FISH P DECOMP Clear /Clean floor -Mob spear assembly to rig floor 11:30 - 13:30 2.00 FISH P DECOMP PU spear BHA -RIH to 2,300' 13:30 - 14:00 0.50 FISH P DECOMP Obtain parameters -PUW 110k -SOW 115k -Break circulation w/ 3.5 bpm, 60 psi -Engage fish at 2,336' -Pull up and hit jars 1 time w/ 180k -Pulled free -Set back down, turn 2 LH turns to ensure grapple set. PU w/ no overpull. 14:00 - 16:00 2.00 FISH P DECOMP POH -Stand back 8HA 16:00 - 17:00 1.00 FISH P DECOMP LD fish (recovered 9.38' piece) -Pin pulled out of "FO" collar 17:00 - 19:30 2.50 FISH P DECOMP Inspect grapple (OK) - MU BHA -RIH to 2,300' 19:30 - 21:30 2.00 FISH P DECOMP Screw in TD and check parameters -RIH and tag fish @ 2,345' - Engage fish - Jar on fish pulling to 250k, let jar hit, pull to 350k and then slack off to set jars back and repeat jarring -Jar 153 times with no progress -Disengage spear 21:30 - 22:00 0.50 FISH P DECOMP Conduct derrick inspection after jarring 22:00 - 23:00 1.00 FISH P DECOMP POH to BHA 23:00 - 00:00 1.00 FISH P DECOMP Stand back HWDP and DCs - LD spear assembly 10/8/2007 00:00 - 01:00 1.00 FISH P DECOMP Clear /clean rig floor -Mob. washover tools to rig floor - RU false table and wash pipe handling tools 01:00 - 02:30 1.50 FISH P DECOMP MU washover shoe, 1 jt wash pipe, drive sub and jars - RIH w/ DCs and HWDP 02:30 - 04:00 1.50 FISH P DECOMP RIH on 5" DP to 2,300'. Screw in TD on every stand (running over) Prnted: 12/4/2007 8:41:30 AM BP EXPLORATION Page 7 of 19 Operations Sumlmary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 ',Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 ~~Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/8/2007 04:00 - 12:00 8.00 FISH P DECOMP Check parameters PUW 110k, SOW 115k, ROTW: 115k -Tag fish @ 2,344' - Washover /mill fish f/ 2,344' - 2,346'. 50-120 RPM @ 5-7k torque; 173 GPM @ 70 psi - "Dry Drill" f/ 30 min in attempt to make drill w/ no success 12:00 - 14:00 2.00 FISH P DECOMP POH -Stand back BHA -PJSM -Break shoe -Inspect same - Shoe shows very little wear - LD wash pipe and drive sub. 14:00 - 15:30 1.50 FISH P DECOMP MU 11-1 /4" Pilot mill w/ 8-9/16" pilot - MU jars -RIH w/ DCs and HWDP 15:30 - 16:30 1.00 FISH P DECOMP RIH on 5" DP (7 stands) to +/- 1,000'. Stab safety valve - Electric brake locked out 16:30 - 00:00 7.50 FISH N RREP DECOMP Rig repair: changing out electric brake on drawworks 10/9/2007 00:00 - 04:00 4.00 FISH N RREP DECOMP Continue Rig repair: -C/O "Dretech" electric brake on drawworks. 04:00 - 05:00 1.00 FISH P DECOMP Continue to RIH to 2,278' md. 05:00 - 07:30 2.50 FISH P DECOMP Screw in TD -Obtain parameters: -P/U= 110K, SOW= 114K, ROT= 114K. -Milling on "FO" collar/ casing f/ 2,345'-2351' md. -RPM= 110, Tq= 3-5K @ 770 psi w/ 700 gpm. -Pump H.V. /fiber sweeps while milling. -Last 1ft milled in 5 minutes, indicating milling on casing below collar. 07:30 - 08:30 1.00 FISH P DECOMP Pump HV /fiber sweep around w/ 700 gpm, 770 psi. -Rotate and reciprocate w/ 150 rpm. 08:30 - 10:00 1.50 FISH P DECOMP POH -Stand back DC's - LD pilot mill assembly. -Mill showed good wear pattern. 10:00 - 10:30 0.50 FISH P DECOMP Clean /Clear Rig floor. -P/U "Wash Over assembly" to rig floor. 10:30 - 11:30 1.00 FISH P DECOMP R/U and attempt to test casing w/ no success. -Seawater pumping away @ 1.5 bpm / 600 psi. 11:30 - 14:30 3.00 FISH P DECOMP PJSM. -R/U Wachs cutter on rig floor. -P/U 1 stand of Washpipe f/ derrick. -Cut Washpipe w/ Wachs cutter (3 cuts). -Washpipe jts had fused together. -L/D Wachs cutter. -Clean /Clear Rig floor. 14:30 - 16:30 2.00 FISH P DECOMP M/U BHA. 16:30 - 18:30 2.00 FISH P DECOMP RIH to 2,270' md. -Screw into each stand of DP to prevent overFlow f/ Washpipe. 18:30 - 00:00 5.50 FISH P DECOMP Wash over 9 5/8" casing f/ 2,351' and to 2,381' md. -GPM= 212 @ 90 psi. RPM= 80, Tq= 3K-5K, P/U= 115K. 10/10/2007 00:00 - 11:30 11.50 FISH P DECOMP Continue to Wash over 9 5/8" casing to 2,406' md. -No progress at casing collar. -WOB= 5-20K, RPM= 80, Tq= 18K. -P/U= 115K, SOW= 111 K, ROT wt= 114. -200 gpm @ 120 psi. 11:30 - 12:30 1.00 FISH P DECOMP POH to BHA. 12:30 - 15:30 3.00 FISH P DECOMP Stand back BHA. -L/D Wash pipe. -Noted trouble breaking Wash pipe connections. 15:30 - 17:00 1.50 FISH P DECOMP M/U 9 5/8" casing Spear assembly. 17:00 - 17:30 0.50 FISH P DECOMP RIH w/ Spear assembly to 2,300' md. 17:30 - 18:00 0.50 FISH P DECOMP Tag Fish @ 2,351' md. -Engage Fish. Printed: 12/4/2007 8:41:30 AM ~I BP EXPLORATION Page 8 of 1 s L Operations Sumlmary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 ''Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT I Phase Description of Operations 10/10/2007 17:30 - 18:00 0.50 FISH P 18:00 - 19:00 1.00 FISH I P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 21:00 0.50 FISH P 21:00 - 22:00 1.00 FISH I P 22:00 - 23:30 1.50 FISH P 23:30 - 00:00 0.50 FISH P 10/11/2007 00:00 - 00:30 0.50 FISH P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 FISH P 01:30 - 02:00 0.50 FISH P 02:00 - 04:00 I 2.001 FISH I P 04:00 - 12:00 I 8.001 FISH I P 12:00 - 19:00 I 7.001 FISH I P 19:00 - 20:30 1.50 FISH P 20:30 - 22:00 1.50 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 00:00 1.50 FISH P 110/12/2007 100:00 - 03:00 I 3.001 CLEAN I P 03:00 - 05:00 I 2.001 CLEAN I P 05:00 - 06:30 I .1.501 CLEAN I P DECOMP -P/U= 115K, SOW= 111K. -212 gpm @ 80 psi. DECOMP POH w/ Fish. DECOMP Stand back BHA. -- UD Fish (9.7 ft). -M/U BHA for 2nd Spear run. DECOMP RIH w/ Spear to 2,300' md. DECOMP Tag Fish @ 2,360' md. -Engage Fish. -P/U= 115K, SOW= 111K. -212 gpm @ 80 psi. DECOMP POH to BHA. DECOMP Stand back BHA. -UD Fish (37.27 ft). -UD BHA. DECOMP Clear Rig Floor. DECOMP Continue to clear Rig floor of Wash over tools. DECOMP Service Rig. DECOMP P/U & M/U Pilot Mill BHA. DECOMP RIH w/ 5" DP & Pilot Mill assembly. -Tag Fish @ 2,397' md. DECOMP Suck out Pits # 1 & 2. -Displace Seawater to 9.1 ppg LSND milling fluid. -Pumped 30 bbl High viscosity spacer. -Pumped 350 bbls of 9.1 ppg LSND milling fluid. -330 psi / 550 gpm. DECOMP Ease into 9 5/8" stump. -Attempt to mill, Mud running over shakers. -C/O shaker screens. -Mill f/ 2,404' to 2,416' md. -P/U= 111 K, S/0= 115K, ROT= 115K. -W06= 5-7K, Tq= 3k, RPM= 110. -450 psi / 650 gpm DECOMP Continue to mill 9 5/8" casing f/ 2,416' to 2,440' md. -Pump Hi vis sweeps every 6' milled. -420 psi / 650 gpm. -W06= 6-9K, Tq= 1-8K. DECOMP Pump 30 bbl Hi vis sweep. -Pump 20 bbls water. -Circulate, Reciprocate & Rotate until hole clean. -2K Tq @ 150 RPM. 420 psi @ 650 gpm. Total Mud contaminated metal recovered= 2,100 lbs. DECOMP POH DECOMP Stand back, UD BHA. DECOMP Pull Wear ring. Flush Stack and Flow line. -Install Test plug. DECOMP Open all Ram doors. - Clean metal shavings from cavity and rams. DECOMP R/U for BOP body test @ 250 psi low & 4000 psi high for 5 minutes. -Test 4 1/2" x 7" Variables -Pass. -3 1/2" x 6" Variables -Pass. -Blind rams. -Pass. DECOMP ~ M/U 12 1/4" bit, 13 3/8" scraper, 12 1/4" string mill and jars. Printed: 12/4/2007 8:41:30 AM ___ BP EXPLORATION Page 9 of 19' Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: .Date I From - To I Hours I Task I Code I NPT 10/12/2007 05:00 - 06:30 I 1.501 CLEAN P 06:30 - 07:30 1.00 CLEAN P 07:30 - 09:00 1.50 CLEAN P 09:00 - 11:00 I 2.001 CLEAN t P 11:00 - 12:00 I 1.00 CLEAN P 12:00 - 13:30 1.50 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 15:30 I 1.00 I CLEAN I P 15:30 - 17:30 I 2.00 CLEAN I P 17:30 - 18:30 I 1.001 CLEAN I P 18:30 - 19:00 I 0.501 CLEAN I P 19:00 - 19:30 0.50 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 22:00 I 1.501 CLEAN I P 22:00 - 22:30 I 0.501 CLEAN I P 22:30 - 00:00 1.50 CLEAN P 10/13/2007 00:00 - 01:30 1.50 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 04:30 I 2.00 I CLEAN I P 04:30 - 05:00 I 0.501 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 06:30 1.00 CLEAN P .Phase Description of Operations DECOMP -RIH w/ DC's. DECOMP RIH w/ DP to 2,300' md. DECOMP Screw in Top Drive. -Ream to bottom. -P/U= 111K, SOW= 115K, ROT wt= 115K. -GPM= 290 @ 1200 psi. -Taking weight at 2,302' md. -Clean out f/ 2,302' to 2,404' md, RPM= 100, WOB= 0. -Clean out f/ 2,404' to 2,436' md, RPM= 100, WOB= 2-4K. DECOMP Pump Hi Vis sweep: -Reciprocate & rotate @ 100 rpm. ` -GPM= 200 @ 1240 psi. DECOMP Observe well - POH to BHA. DECOMP Stand back DC's - LD BHA. DECOMP Clean & Clear Rig floor of tools. -P/U RTTS. DECOMP M/U 13 3/8" RTTS. -RIH w/ DC's. DECOMP RIH w/ DP t/ 2,430' md. -Drilling fluid running over tool joints. -Screw into each joint. DECOMP Set RTTS @ 2,430' md. -Test casing -Failed. -Injecting @ 600 psi / 1.5 bpm. DECOMP Set RTTS @ 2,360' md. -Test casing -Failed. -Injecting @ 730 psi / 1.9 bpm. -Perform FIT @ 2,360' and to 10.6 ppg EMW. -Applied 185 psi -Pass. DECOMP Set RTTS @ 2,330' md. -Test casing -Failed. DECOMP Set RTTS @ 2,200' md. -Test casing for 20 minutes @ 2000 psi -Pass. -R/D test equipment. DECOMP Observe well - no flow. -Pump dry job. -POH f/ 2,200' to 366' md. DECOMP Stand back HWDP and DCs. -L/D RTTS. DECOMP P/U casing cutter & DP to 930' md. DECOMP RIH w/ Casing cutter f/ 903' to 2,366' md. DECOMP Attempt to break circulation. -Casing cutter nozzle plugged. -Attempt to reverse circulate to clear nozzle. -Work drill string in an attempt to clear nozzle. -Pressure up drill string to engage knives. -Work drill string. -Locate 13 3/8" Casing collars @ 2,419' and & 2,378' md. DECOMP Observe well - No flow. -POH wet (plugged nozzle). DECOMP Stand back DC's -Service break and LD cutter. DECOMP Clean & Clear rig floor. DECOMP M/U 13 3/8" EZSV running tool on DC's. Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 10 of 19 Operatolns SuIInllnary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date )From - To_ I Hours I Task I Code) NPT Phase Description of Operations 10/13/2007 105:30 - 06:30 I 1.001 CLEAN J P 06:30 - 08:00 I 1.501 CLEAN P 08:00 - 08:30 0.50 CLEAN P 08:30 - 10:00 I 1.501 CLEAN I P 10:00 - 11:00 1.00 CLEAN P 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 13:00 0.50 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 17:30 3.50 CLEAN P 17:30 - 18:00 0.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 19:30 1.00 I CLEAN I P 19:30 - 21:30 2.00 CLEAN P 21:30 - 23:30 I 2.001 STWHIPI P 23:30 - 00:00 I 0.501 STWHIPI P DECOMP -Dummy run through wear ring. -M/U EZSV. -RIH w/ DC's. DECOMP RIH w/ DP at controlled rate to 2,400' md. DECOMP Screw in Top Drive -Obtain parameters: P/U= 105K, SOW= 105K. -Spot EZSV top at 2,415' md. -Set EZSV per HES rep directions. -Rotate 40 Right Hand turns. -P/U in 10K over pull increments to 40K over. -Pull to 65K over and shear off of EZSV. -P/U 3 ft, Rotate 25 Right Hand turns. -Set down w/ 45K weight on EZSV to ensure no movement. DECOMP R/U testing equipment. -Isolate all surface equipment. -Test EZSV to 2000 psi f/ 15 min. -Record on chart -Pass. -RD test equipment -Blow down lines and Top Drive. DECOMP Observe well -Static - POH to BHA. DECOMP Stand back DC's &HWDP - L/D EZSV running tool. DECOMP Clean & Clear Rig floor. DECOMP Pull wear ring, Drain stack. DECOMP Set test plug. R/U BOP test equipment. DECOMP PJSM -Test BOPS per BP / AOGCC regulations: -Test to 250 psi low - 4,000 psi high. -Annular preventer to 250 psi low - 3500 psi high. -Test w/ 5" test joint -Chart tests -Pass. -Test witnessed by WSL and Toolpusher. -Jeff Jones, AOGCC Rep, waived witness of test. DECOMP Pull test plug. Install Wear ring. DECOMP Blow down Kill & Choke lines. -Break down Floor valves. DECOMP P/U Mills, XO's, Flex jt, Float, UBHO & Bumper subs. DECOMP PJSM. M/U Window mill & lower mill. -M/U Flex jt, Upper mill, XO, Float sub & UBHO sub. WEXIT P/U Whipstock. Attach Mills. -Orient UBHO sub. -P/U XO, Flex collar, XO, Bumper sub & six 8" DCs. WEXIT P/U XO & DC. -At 309' md, stacked 30-35K while RIH. -Work pipe per Baker rep. -Decision to POH. Pulled 40K over to free. -POH. 110/14/2007 ~ 00:00 - 01:30 1.50 STWHIP N DFAL WEXIT Whipstock left set in hole. Anchor @ 309' md. -Top of slide @ 279' md, Retrievable slot @ 287' md. ~ -Continue to POH: Stand back DCs, Break off starter Mill. -L/D Bumper sub, Flex collar & Mills. 01:30 - 02:30 1.00 STWHIP N DFAL WEXIT R/D SLB tools & sheave. 02:30 - 03:30 1.00 STWHIP N DFAL WEXIT P/U & M/U Retrieval hook, Jars, Bumper sub. -M/U DCs &HWDP. 03:30 - 04:00 0.50 STWHIP N DFAL WEXIT Hook into Fish, open Jars w/ 25K over. -Pulled 62K over & sheared anchor. 04:00 - 05:00 1.00 STWHIP N DFAL WEXIT POH -UD Bumper sub, Jars and Retrieval hook. Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date ` From - To Hours .Task Code NPT Phase Description of Operations 10/14/2007 05:00 - 05:30 0.50 STWHIP N DFAL WEXIT PJSM. L/D Whipstock. 05:30 - 07:00 I 1.501 STWHIPI N I DFAL I WEXIT 07:00 - 08:00 1.00 STWHIP N DFAL WEXIT 08:00 - 09:30 1.50 STWHIP N DFAL WEXIT 109:00 - 13:00 ( 2.001 STWHIPI N DFAL I WEXIT 13:00 - 15:00 I 2.001 STWHIPI N I DFAL I WEXIT 15:00 - 16:30 1.50 STWHIP N DFAL WEXIT 16:30 - 18:00 1.50 STWHIP N DFAL WEXIT 18:00 - 20:00 2.00 STWHIP N DFAL WEXIT 20:30 - 210:30 I 10.001 STWHIPI P I DFAL I WEXIT 21:30 - 22:00 0.50 STWHIP P WEXIT 22:00 - 23:00 1.00 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT 10/15/2007 00:00 - 01:30 1.50 STWHIP N DFAL WEXIT 01:30 - 02:30 I 1.001 STWHIPI P I I WEXIT 02:30 - 03:00 I 0.501 STWHIPI P I I WEXIT 03:30 - 04:30 I 9.001 STWHIP P I WEXIT WEXIT 04:30 - 06:30 I 2.001 STWHIPI P I I WEXIT 06:30 - 07:00 0.50 STWHIP P WEXIT 07:00 - 09:00 2.00 STWHIP P WEXIT 09:00 - 10:00 1.00 STWHIP P WEXIT 10:00 - 12:00 2.00 STWHIP P WEXIT -Inspect anchor: No apparent damage. Clear & clean Rig floor. -Cut drilling line. -Service T.D. Adjust brakes. M/U 12 1/4" bit, string mills, Bumper Sub & Jars. -RIH w/ DC's. RIH w/ 5" DP -Tag EZSV at 2,415' md. Circulate @ 6 bpm / 470 psi. -Condition mud w/ 0.5% lubricant [Lo-Torq] -P/U= 132K -SOW= 135K -Rot wt= 135K -Rotate & Reciprocate DP @ 20 rpm. Flow Check well -Static. -POH f/ 2,400' to 600' md. -POH slowly due to high winds. -Service loop blowing outside wind walls. Rack back BHA, L/D string mills. P/U & M/U Flex DC and window mill. -L/D same in pipe shed. P/U Whipstock, Window mill, Flex collar. -P/U & Orient UBHO sub. -P/U DCs and HWDP. PJSM. Hang E-line sheave in derrick. RIH f/ 635' to 2,397' md. -Run speed 90-120 seconds per stand. Fill pipe, drill string pressured up to 1800 psi. -Bleed off. -Re-pressure up to 1700 psi. -No Returns, bleed off pressure. -Assembly plugged. RU Gyro tools and E-line bottom sheave. -RIH w/ Gyro to 2,397' md. -E-line failure. POH & troubleshoot E-line failure. C/O Gyro tool head. -Wireline cable short [midcable]. -Switch to large cable spool. RIH w/ Gyro tool. -Orient Whipstock per Gyro survey to azimuth 99. -POH w/ Gyro tool. Single into anchor setting depth at 2,415' md. -Set whipstock anchor w/ 25K down. -Confirm anchor set with 45K down. R/D & L/D Schlumberger E-line. Pump dry job. -POH t/ 6 1/4" DCs @ 635' md. Stand back DCs &HWDP. -L/D Mill, UBHO, Flex collar, XOs & Jars. Clear & clean rig floor. PJSM - M/U Milling BHA. RIH w/ DP. Tag Whipstock @ 2,385' md. Cut window f/ 2,385' - 2,387' md. ~ Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 12 of 19 Operations Summalry Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT .Phase Description of Operations 10/15/2007 10:00 - 12:00 2.00 STWHIP P WEXIT -P/U= 138K, SOW= 136K, ROT wt= 138K. -RPM= 80, W06= 5-15K,Tq= 8K. -294 gpm @ 150 psi. 12:00 - 15:30 3.50 STWHIP P WEXIT Continue to Mill window f/ 2,387' to 2,388' md. 15:30 - 16:30 1.00 STWHIP N RREP WEXIT Top Drive failure. Let cool down, reset Top drive. 16:30 - 00:00 7.50 STWHIP P WEXIT Mill window f/ 2,388' to 2,393' md. 10/16/2007 00:00 - 09:00 9.00 STWHIP P WEXIT Mill window & 20' new hole f/ 2,393' to 2,435' md. -P/U = 138K, SOW = 136K, Rot Wt = 138K. -RPM = 120, WOB = 30K, Tq = 4K -595 gpm @ 650 psi. 09:00 - 11:30 2.50 STWHIP P WEXIT Pump sweep, surface to surface. -Condition mud. -Reciprocate & Rotate w/ RPM = 120. -595 gpm @ 545 psi. 11:30 - 12:00 0.50 STWHIP P WEXIT Stand back 1 std DP. -R/U f/ LOT. 12:00 - 13:00 1.00 STWHIP P WEXIT Perform & chart LOT. -EMW = 13.9. -Flow check well -Static. -R/D all lines. -Blow down Kill line, Choke line, & Manual Kill line. 13:00 - 14:30 1.50 STWHIP P WEXIT L/D 1 jt DP. -POH f/ 2,331' to 629' md. 14:30 - 18:00 I 3.501 STWHIPI P 18:00 - 18:30 0.50 STWHIP P 18:30 - 19:00 0.50 STWHIP P 19:00 - 21:30 2.50 STWHIP P 21:30 - 22:30 1.001 STWHIP P 22:30 - 00:00 1.50 STWHIP P 110/17/2007 100:00 - 02:30 I 2.501 STWHIPI P 02:30 - 05:00 I 2.501 STWHIPI P 05:00 - 06:00 I 1.001 STWHIPI P 06:00 - 08:00 2.00 STWHIP P 08:00 - 09:00 1.00 STWHIP P WEXIT Rack back lstd HWDP. -Break down Mill assy. -Upper String Mill 1/8" out of gauge. WEXIT Clear Rig floor. WEXIT P/U Milling assembly to Rig floor. WEXIT M/U Milling assembly. -Work getting bit breaker to fit mill. WEXIT P/U 14 jts of HWDP f/ pipe shed. WEXIT P/U jts of 5" DP f/ pipe shed &RIH t/ 1,400' md. -Circulate drillstring volume every 10 jts. -380 gpm @140 psi. WEXIT P/U 60 jts of 5" DP f/ pipe shed. -RIH t/ 2,385' md. -Circulate every 10 jts. -380 gpm @ 140 psi WEXIT Dress window f/ 2,385' t/ 2,437' md. -P/U= 110K, SOW=115K, Rot wt= 115K. -RPM= 90, WOB= 2-20K, Tq= 2-18K. 378 gpm @ 240 psi. WEXIT Circulate hole clean. -Monitor well -Static. -Pump dry job. -POH. WEXIT Stand back HWDP. -P/U jars and stand back. -Inspect and L/D mills (Full gauge). WEXIT Clear &Clean floor. -P/U MWD and drilling BHA to Rig floor. Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 13_of 19 Operations Summary Report ,Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date I From - To I Hours I Task I Code I NPT I Phase I Description of Operations 10/17/2007 09:00 - 10:00 1.00 STWHIP P WEXIT Pull wear ring. -Flush stack & flowline. -Install wear ring. 10:00 - 15:00 5.00 STWHIP P WEXIT PJSM. -P/U & M/U Drilling BHA. -Orient UBHO sub. 15:00 - 16:00 1.00 STWHIP P WEXIT Surface test MWD. -RIH f/ 721' t/ 2,100' md. 16:00 - 17:00 1.00 STWHIP P WEXIT Correlate depth w/ MWD. -MAD Pass f/ 2,100 t/ 2,322' md. 17:00 - 18:00 1.00 STWHIP P WEXIT Run Gyrodata tool. -Orient Drill string t/ exit window. 18:00 - 00:00 6.00 DRILL P INT1 Obtain Slow Pump Rate. -Drill f/ 2,437' U 2,800' md. -Slide 60', rotate 30' per stand. -Pump sweeps as needed. -Run Gyrodata surveys at connections (3 surveys). 10/18/2007 00:00 - 12:00 12.00 DRILL P INT1 Directionally drill w/ sweeps f/ 2,800' to 4,127' md. -W06= 10-20K, RPM= 80, P/U= 153K, -SOW= 140K, ROT wt= 146K, -Tq On= 5K, Tq off= 3K, 1400 psi @ 550 gpm. -AST= 1.31, ART= 6.04, ADT= 7.35 hrs. 12:00 - 20:30 8.50 DRILL P INT1 Directionally drill w/ sweeps f/ 4,127' to 4,882' md. -WOB= 10-20K, RPM= 80, P/U= 170K, -SOW= 150K, ROT wt= 158K, -Tq on= 5-7K, Tq off= 4K, 1200 psi @ 550 gpm. -AST= 1.16, ART= 4.83, ADT= 5.99 hrs. 20:30 - 22:00 1.50 DRILL P INT1 Pump Hi Vis sweep, Circ hole clean (3X B/U). -1200 psi @ 550 gpm. 22:00 - 00:00 2.00 DRILL P INT1 Survey, Obtain SPR, Flow check well -static. -Begin pumping out of the hole @ drilling rate. -POH f/ 4,882' to 3,935' md. -1200 psi @ 550 gpm. -Mud wt in= 9.2 ppg, Mud wt out= 9.2+ ppg. -Shaker screens = 180s. 10/19/2007 00:00 - 01:30 1.50 DRILL P INT1 Short Trip f/ 3,935' to 3,450' md. -Pump out of hole @ Drilling rates. 01:30 - 02:00 0.50 DRILL P INT1 Pump Nut Plug/ SAPP sweep. 02:00 - 03:00 1.00 DRILL P INT1 Continue Short trip f/ 3,450' to 2,600' md. -Pump out of hole @ Drilling rates. 03:00 - 04:00 1.00 DRILL P INT1 CBU. Rotate & Reciprocate DP. -1320 psi @ 650 gpm. 04:00 - 05:00 1.00 DRILL P INT1 Monitor well -Static. -RIH f/ 2,600' to 4,882' md. -Wash last std to bottom. 05:00 - 12:00 7.00 DRILL P INT1 Drill w/ sweeps f/ 4,882' to 5,482' md. -W06= 15-25K, RPM= 80, P/U= 182K, -SOW= 155K, ROT wt= 170K, -Tq On= 6-8K, Tq off= 4K, 1720 psi @ 600 gpm. -AST= 0.34, ART= 4.20, ADT= 4.54 hrs. 12:00 - 00:00 12.00 DRILL P INT1 Continue to drill ahead f/ 5,482' to 6,112' md. -Continue to utilize Hi Vis sweeps. Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date from = To Hours. Task Code NPT Phase ~ 10/19/2007 12:00 - 00:00 12.00 DRILL P INT1 10/20/2007 100:00 - 07:30 I 7.501 DRILL I P I I INT1 07:30 - 07:31 0.021 DRILL ~ N I MISC INT1 07:30 - 10:30 3.00 DRILL P INT1 10:30 - 12:00 I 1.501 DRILL I P I I INT1 12:00 - 16:00 I 4.001 DRILL I P I I INT1 16:00 - 17:00 1.00 DRILL P INT1 17:00 - 18:00 1.00 DRILL P INT1 18:00 - 22:30 4.50 DRILL P INT1 22:30 - 00:00 I 1.501 DRILL I P I I INT1 110/21/2007 100:00 - 06:00 I 6.001 DRILL I P I I INT1 06:00 - 12:00 I 6.001 DRILL I P I I INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 10/22/2007 100:00 - 12:00 I 12.001 DRILL I P I I INT1 Spud Date: 6/9/1979 Start: 9/24/2007 End: 10/31 /2007 Rig Release: 10/31 /2007 Rig Number: Description of Operations -WOB= 15-25K, RPM= 80, P/U= 205K, -SOW= 164K, ROT wt= 182K, -Tq On= 9K, Tq off= 7K, 1830 psi @ 650 gpm. -AST= 0.34, ART= 4.20, ADT= 4.54 hrs. -Shaker screens 180s & 200s. Continue Drilling w/ Sweeps f/ 6,112' to 6,396 and / 5,950' tvd. -P/U wt= 212K, SOW= 165K, ROT wt= 188K, -GPM= 647, Psi on= 1760, Psi off= 1580, -RPM= 80, Tq On= 10K, Tq off= 9K. (NO NPT, Ignore) Circulate Hi Vis Sweep, -GBU X3 @ 634 gpm / 1580 psi, 80 rpm. -Obtain SPRs, Flow check well -static. -Mud wt in= 9.3 ppg, Mud wt out= 9.3 ppg. POH (pump out) f/ 6,396' to 5,355' md. -Pump 595 gpm @ 1430 psi. Continue to POH (pump out) f/ 5,355 to 2,328' md. -Attempt to pull into window. -Rotate 90 degrees & pull clean into window. Circulate Hi Vis Sweep inside casing. -575 gpm @ 1080 psi, RPM= 60. POH f/ 2,328' to 720' md. Rack back HWDP, Flex collar. -Pull Bit and break off, Down load MWD. -L/D TM HOC, UBHO, XO & Mud motor. P/U new Bit & Mud motor. -Shallow hole pulse test MWD. -560 gpm @ 1420 psi. -P/U 5" DP from pipe shed f/ 716' to 2,131' md. Continue to single in the hole w/ 5" DP to 2,385' md. -Work tight through window to 2,408' md. -RIH in open hole f/ 2,408' to 6,296' md. -Fill pipe @ 30 stds. Wash last std to bottom @ 6,396' md. -Obtain SPR. Pump Hi Vis Sweep. Directional Drill f/ 6,396' to 6,767' md. -GPM= 656, Psi on= 2270, Psi off= 1990. -WOB= 10-25K, RPM= 70, Tq on= 12K, Tq off= 10K. -P/U= 220K -SOW= 165K -ROT wt= 190K. -ADT= 4.06, AST= 1.01, ART= 3.05. -Mud wt= 9.5 ppg. Continue Directionally Drilling f/ 6,767' to 7,431' md. -Pump Hi Vis Sweeps as needed. -Add Spike fluid for Fluid properties needed. -GPM= 650, Psi on= 2320, Psi off= 1990. -WOB= 10-25K, RPM= 70, Tq on= 14K, Tq off= 12K. -P/U= 236K -SOW= 179K -ROT wt= 206K. -ADT= 4.06, AST= 1.01, ART= 3.05. -Mud wt= 9.6 ppg. Shaker screens= 180s & 200s. Continue to Directionally Drill ahead f/ 7,431' to 7,748' md. -Utilize Hi Vis Sweeps & Lubricants as needed. -Add Spike fluid for required Mud properties. -GPM= 656, Psi on= 2400, Psi off= 2080. -W06= 10-25K, RPM= 80, Tq on= 14K, Tq off= 13K. Printed: 12/4/2007 8:41:30 AM f ~ BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2007 00:00 - 12:00 12.00 DRILL P INT1 -P/U= 240K -SOW= 180K -ROT wt= 210K. 12:00 - 00:00 I 12.001 DRILL I P I I INT1 10/23/2007 100:00 - 08:00 I 8.001 DRILL I P I I INT1 08:00 - 09:00 I 1.001 DRILL I P I I INT1 09:00 - 09:30 0.50 DRILL P INT1 09:30 - 11:00 1.50 DRILL P INT1 11:00 - 11:30 0.50 DRILL I P INT1 11:30 - 13:00 1.50 DRILL P INT1 13:00 - 13:30 0.50 DRILL P INT1 13:30 - 14:30 1.00 DRILL P INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 16:30 I 0.50 DRILL P INT1 16:30 - 18:00 1.50 DRILL P INT1 18:00 - 18;30 0.50 DRILL P INT1 18:30 - 19:30 1.00 DRILL P INT1 19:30 - 21:00 1.50 DRILL P INT1 21:00 - 00:00 3.00 DRILL P INT1 10/24/2007 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 02:00 1.00 DRILL P INT1 02:00 - 06:00 4.00 DRILL P INT1 -ADT= 7.16, AST= 5.25, ART= 1.91. -Mud wt= 9.8 ppg. Continue Directionally Drilling f/ 7,748' to 8,116' and / 7,625' tvd. -Pump Hi Vis Sweeps as needed. -GPM= 650, Psi on= 2350, Psi off= 2050. -W06= 10K, RPM= 80, Tq on= 13-15K, Tq off= 12K. -P/U= 250K -SOW= 194K -ROT wt= 221 K. -ADT= 7.38, AST= 4.28, ART= 3.10. -Mud wt= 9.8 ppg. Shaker screens= 180s & 200s. -Maximum gas units 3000, calculated @ 8,042' - 8,048' md. Continue directionally drilling f/ 8,116' MD to 8,449' MD. -GPM= 650, Psi on= 2400, Psi off= 2110. -WOB= 10K, RPM= 80, Tq on= 13K, Tq off= 12K. -P/U= 252K -SOW= 195K -ROT wt= 220K. -Mud wt= 9.8 PPg• CBU per Geologist -643 gpm-2050 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8449'-8469' CBU per Geologist -643 gpm-2050 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8469'-8474' CBU per Geologist -643 gpm-2050 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8474'-8481' CBU per Geologist -643 gpm-2050 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8481'-8486' CBU per Geologist -643 gpm-2000 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8486'-8491' CBU per Geologist -643 gpm-2000 psi -Catch sample at bottoms up Control drilling per Geologist f/ 8491'-8496' CBU per Geologist -643 gpm-2000 psi -Catch sample at bottoms up. Confirm TD @ 8,496' MD (8,005' TVD) Pump Hi-vis sweep w/nut plug -Circulate surface to surface Check well for flow -Pump out of the hole to 6,295' @ 643 gpm/ 1950-2000 psi CBU @ 6,295' - 640 gpm / 1840 psi - 80 RPM / 6k TO PUW: 202k -SOW: 153k - ROTW: 180k RIH f/ 6,295' to 8,496' CBU 3x @ 8,496' - 640 gpm / 2000 psi - 80 RPM / 13k TO Printed: 12/4/2007 8:41:30 AM ~ ~ BP EXPLORATION Page 16 of 19 Operations Slummary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Mourn Task Code NPT Phase Description of Operations 10/24/2007 02:00 - 06:00 4.00 DRILL P INT1 PUW: 260k -SOW: 195k - ROTW: 225k 06:00 - 13:00 7.00 DRILL P INT1 Pump out of the hole f/ 8,496' to 2,340' -Check PUW: 120k / SOW: 115k 13:00 - 14:30 1.50 DRILL P INT1 Pump Hi-vis sweep and circulate hole clean -Run back through window. OK -Pump dry job 14:30 - 16:00 1.50 DRILL P INT1 Blow down top drive - POH f/ 2,340' to 716' ~~ 16:00 - 19:00 3.00 DRILL P INT1 Rack back HWDP - LD 8" DCs- Download MWD - LD MWD, motor and rest of BHA 19:00 - 19:30 0.50 DRILL P INT1 Clean /clear rig floor 19:30 - 22:00 2.50 BOPSU P INT1 PJSM -Pull wear ring and install test plug - C/O top rams to 9-5/8" - RU 9-5/8" test joint and testing equipment -Test top rams to 250 psi low - 4,000 psi high, 5 min. each. Chart test. Test witnessed by WSL and Tourpusher - RD test joint and testing equipment -Pull test plug 22:00 - 00:00 2.00 CASE P LNR1 PJSM - C/O bales -Install Frank's fill up tool - RU casing elevators, slips and tongs 10/25/2007 00:00 - 02:30 2.50 CASE P INT1 Cont. RU to run casing: RU stabbing board -Test turn torque equipment - MU safety valve 02:30 - 05:30 3.00 CASE P INT1 PJSM -Run 9-5/8 " 47# L-80 HYD 563 casing to 2,349' 05:30 - 06:30 1.00 CASE P INT1 Circulate casing volume @ window - 211 gpm / 270 psi PUW: 148k -SOW: 142k 06:30 - 12:00 5.50 CASE P INT1 Cont. running 9-5/8" 47# L-80 HYD 563 casing f/ 2,349' to 6,461' PUW: 350k -SOW: 227k 12:00 - 16:00 4.00 CASE P INT1 Finish running 9-5/8" 47# L-80 HYD 563 casing f/ 6,461' to 8,496'. Total jtts run: 210. Shoe @ 8,496' - FC @ 8,412'. Total centralizers used: 56 (1 ea on jtts 1, 2 & 3 - 1 every other joint from jt 6 to jt 110) 16:00 - 17:30 1.50 CASE P INT1 CBU @ 8,496'. 170 gpm / 380 psi Attemp to reciprocate casing. Pull to 490k. Casing does not reciprocate. SOW:285k 17:30 - 18:30 1.00 CEMT P INT1 LD Frank's fill up tool - MU XO HYD 563 pin x BTC box - RU cement head ,valves and cement line 18:30 - 21:00 2.50 CEMT P INT1 Break circulation @ 2 bpm / 120 psi -Stage pumps to 6.5 bpm / 550 psi -Circulate and condition mud for cement job -Hold PJSM for cement job while circulating 21:00 - 22:30 1.50 CEMT P INT1 Give to Schlumberger: - Pump 5 bbls of water and test lines to 4,000 psi - Pump 60 bbls 10.6 ppg Mud Push @ 5 bpm - Drop bottom plug. Pump 245 bbls 12.5 ppg Lite Crete cement @ 5-7 bpm - Pump 79 bbls 15.8 ppg tail cement @ 5-6 bpm - Drop top plug and pump 10 bbls of water. Switch to rig pumps 22:30 - 00:00 1.50 CEMT P INT1 Cont. displacing cement w/ 9.9 ppg mud on rig pumps @ 6.5-7 bpm. Slow pumps to 3 bpm before bumping plug. Bump plug at 1,250 psi final circulating pressure and pressure up to 2,300 psi. Hold pressure x 10 min. Bleed pressure and check floats - OK. Total displacement to bump plug: 615 bbls CIP @ 00:00 10/26/07 10/26/2007 00:00 - 06:00 6.00 CEMT P LNR1 .Wait until cement develops 50 psi compressive strength before splitting BOP stack. While WOC: clean up rig floor -clean up casing tongs and Printed: 12/4/2007 8:41:30 AM ~~ ! ~ BP EXPLORATION Page 17 of 19 Operations Summary Report Legal Well Name: NGI-13 .Common Well Name: NGI-13 Spud Date: 6/9/1979 'Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code I NPT I Phase Description of Operations 10/26/2007 00:00 - 06:00 6.00 CEMT P 06:00 - 11:00 I 5.001 CASE I P 11:00 - 13:00 2.00 BOPSU P 13:00 - 15:00 2.00 BOPSU P 15:00 - 18:30 3.50 BOPSU P 18:30 - 20:00 1.50 BOPSU P 20:00 - 22:30 2.50 DRILL P 22:30 - 00:00 1.50 DRILL P 10/27/2007 00:00 - 02:30 2.50 GRILL P 02:30 - 06:00 3.50 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:00 1.50 DRILL P 08:00 - 09:30 I 1.501 EVAL I P LNR1 remove f/ rig floor -remove thread protectors, XO and centralizers f/ rig floor - LD and break Frank's fill up tool apart - clean drip pan -evacuate mud from casing -rinse stack and blow down lines LNR1 PJSM -Pull casing to 275k (225k + blocks weight) - RD flow line -Split BOP stack and tubing spool -Set emergency slips - Cut casing and dress - LD 21' cut off joint + pup joint - ND old tubing spool - NU new tubing spool and install packoff. Test to 3,800 psi x 30 min. LNR1 NU BOP, flow line and choke hose -Install test plug LNR1 C/O top rams to 4-1/2" x 7" variable - RU to test BOP LNR1 Test BOP and related equipment as per BP / AOGCC regulations. Test w/ 5" test joint to 250 psi low - 4,000 psi high (annular preventer to 250 psi low - 3,500 psi high). Perform koomey test. Test witnessed by WSL and Toolpusher. Bob Noble, AOGCC rep, waived witness of test. LNR1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 09:30 - 11:00 1.50 DRILL P PROD1 11:00 - 13:00 2.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 16:00 1.50 DRILL P PROD1 16:00 - 00:00 I 8.001 DRILL I P I I PROD1 10/28/2007 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:30 1.00 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 06:30 2.00 DRILL P PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 SIMOPS: Little Red pump 132 bbls of dry crude down 13-3/8" x 9-5/8" annulus (freeze protect) - 2 BPM / 600-750 psi RD testing equipment -Pull test plug -Install wear ring -Blow down choke and kill lines MU 8-1/2" bit and BHA - RIH w/ HWDP -Shallow test MWD @+/- 700' RIH to 2,600' Cont. RIH f/ 2,600' to 8,360' PJSM -Hang blocks -Slip/cut drilling line from new spool onto drum. Lubricate rig RIH and tag FC @ 8,412' -Break circulation 393 gpm / 1600 psi RU to test casing -Test casing to 4,000 psi x 30 min. Chart test - RD testing equipment Drill out FC and shoe trac to 8,494'. Tag shoe Displace to 8.8 ppg FloPro mud as per Mud Engineer Drill out shoe and 20' of new hole to 8,516' CBU 400 gpm / 1200 psi. Pull back to shoe RU testing equipment -Perform FIT to 10.0 ppg EMW (MW 8.8 ppg - 8,005' TVD -Press. 500 psi) - RD testing equipment, blow down kill and choke lines Drill 8-1/2" hole f/ 8,516' to 8,990'. No gas spikes on connections. Background (formation gas): 1800-3200 units Drill f/ 8,990' to 9,006'. TD as per Geologist (circulate at 8,990' and 9,000' while Geologist checks for markers)28/ CBU 2x - 500 gpm / 1590 psi Flow check -Pump out of the hole to the shoe. 475 gpm / 1480 psi CBU at the shoe 430 gpm / 1240 psi Flow check -RIH to 9,006' (wash last stand as a precaution) CBU 3x 500 gpm / 1610 psi -Pump clean 8.8 ppg FloPro mud pill to the bit Pump out of the hole to the shoe. Spot clean mud pill in open hole while POH CBU at the shoe. 500 gpm / 1590 psi -Pump dry job Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 18 of 19 Operatiolns Summary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date 10/28/2007 From - To) Hours ~ Task ~ Code I NPT Phase Description of Operations 08:00 - 13:00 5.00 DRILL P 13:00 - 16:00 3.00 DRILL P 16:00 - 17:30 1.50 EVAL P 17:30 - 22:00 4.50 EVAL P PROD1 POH f/ 8,496' (shoe) to BHA PROD1 LD BHA -Clean /clear rig floor OTHCMP RU Schiumberger e-line OTHCMP Run USIT log in hole and log from 9-5/8" shoe to surface. TOC @ 3,150' OTHCMP RD Schlumberger a-line RUNPRD RU to run 7" liner RUNPRD PJSM - MU and RIH 7" 26# L-80 BTC-M liner (10 slotted joints and 6 solid joints) as per design - MU liner hanger/liner top packer assy. -RIH on 1 stand 5" DP. Break circulation 3 bpm / 210 psi -Blow down top drive - RD casing tongs PUW /SOW: 65k RUNPRD RIH w/ 7" liner on 5" DP to 9,006'. @ 9-5/8" shoe: PUW 225k / SOW 192k. On bottom (9,006'): PUW 235k /SOW: 200k RUNPRD Drop 0.905 ball and pump to seat -Pressure up to 3,000 psi and set HMC liner hanger and C-2 ZXP liner top packer -Shear ball out @ 4,300 psi Shoe @ 9,006' -Top of liner (liner top packer) @ 8,324' RUNPRD CBU 512 gpm / 740 psi -Check flow -Pump dry job -Blow down top drive RUNPRD POH and LD 5" DP - LD liner running tool -Clear rig floor RUNCMP Pull wear ring -Install 7-5/8" test joint and test plug RUNCMP C/O top rams to 7-5/8" -Test top rams to 250 psi low / 4,000 psi high. Chart test. Test witnessed by WSL and Tourpusher - RD testing equipment -Pull test joint and test plug RUNCMP RU to run 7-5/8" tubing and completion equipment RUNCMP MU 7" tail pipe assy. & XO to 7-5/8" tubing -RIH 7-5/8" 29.7# L-80 VAM TOP HC tubing w/ tail pipe assy. to 560' RUNCMP Cont. RIH 7-5/8" 29.7# L-80 VAM TOP HC tubing w/ 7" tail pipe assy. f/ 560' to 6,500'. Controlling running speed to prevent mud from overflowing through pipe MISC RUNCMP (NO NPT, ignore) RUNCMP Cont. RIH 7-5/8" 29.7# L-80 VAM TOP HC tubing w/ 7" tail pipe assy. until tagging top of 7" liner RUNCMP Space out tubing RUNCMP MU tubing hanger -Land tubing and RIULDS. PUW 275k / SOW: 220k (blocks wt. 50k) Mule shoe @ 8,330' / S-3 packer @ 8,285' / No-Go DB-6 nipple @ 2,090'. Total jts run: 201 RUNCMP RU to reverse circulate -Pump down IA 35 bbls Hi-vis spacer, followed by 760 bbls 8.8 ppg clean brine (corrosion inhibitor in last 90 bbls of brine). 4 bpm / 850-1000 psi - RU Little Red and pump down IA 40 bbls diesel for freeze protect. 2bpm / 750-800 psi RUNCMP Drop ball and rod and let fall x 15 min. Pressure up tubing to 4,000 psi and hold pressure x 30 min. Chart test. Pressure drop 75 psi in first 15 min, w/ total pressure drop of 100 psi and stabilizing in 30 min. MIT-T OK -Bleed tubing pressure to 2,000 psi and pressure up IA to 4,000 psi. Hold pressure x 30 min. Chart test. Pressure drop 50 psi in first 15 min and stabilized for rest of test. MIT-IA OK Tests witnessed by WSL, Tourpusher and AOGCC rep. (Bob 22:00 - 23:00 1.00 EVAL P 23:00 - 00:00 1.00 CASE P 10/29/2007 00:00 - 02:00 2.00 CASE P 02:00 - 07:00 5.00 CASE P 07:00 - 09:00 I 2.OOI CASE I P 09:00 - 10:00 I 1.00 I CASE I P 10:00 - 18:00 8.00 CASE P 18:00 - 18:30 0.50 BOPSU P 18:30 - 20:00 1.50 BOPSU P 20:00 - 21:00 1.00 RU 21:00 - 00:00 3.00 RU 110/30/2007 100:00 - 12:00 I 12.00 12:00 - 12:00 24.00 RU 12:00 - 15:00 3.00 RU 15:00 - 17:00 2.00 17:00 - 18:00 1.00 18:00 - 22:00 I 4.00 22:00 - 00:00 I 2.00 Printed: 12/4/2007 8:41:30 AM BP EXPLORATION' Page 19 of 19 Operatiolns Sulmmary Report Legal Well Name: NGI-13 Common Well Name: NGI-13 Spud Date: 6/9/1979 Event Name: REENTER+COMPLETE Start: 9/24/2007 End: 10/31/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 10/31/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/30/2007 22:00 - 00:00 2.00 RUNCO RUNCMP Noble) 10/31/2007 00:00 - 00:30 0.50 RUNCO RUNCMP RD lines and landing joint 00:30 - 01:30 1.00 BOPSU P RUNCMP Suck stack out -Install TWC and test to 1,000 psi f/ above. 01:30 - 02:30 I 1.001 BOPSUf~ P 02:30 - 04:30 I 2.001 BOPSUFdP 04:30 - 05:30 1.00 BOPSU P 05:30 - 10:00 4.50 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 14:30 3.50 WHSUR P 14:30 - 17:00 2.50 WHSUR P 17:00 - 19:00 I 2.001 WHSURI P 19:00 - 20:00 1.00 I WHSUR ( P 20:00 - 20:30 0.50 WHSUR P 111/1/2007 100:00 - I 0.001 WHSUR Chart test. RUNCMP Blow down all lines -Clean drip pan - RD flow line -Pull bell nipple RUNCMP C/O top rams to 3-1/2" x 6", and bottom rams to 2-7/8" x 5" - C/O saver sub, dies and bell guide to 4" on top drive (preparation for next well) RUNCMP ND BOP and choke line RUNCMP NU adapter flange and tree. Test tree to 5,000 psi w/ diesel. RUNCMP RU DSM lubricator -Test lubricator to 500 psi -Pull TWC - RD DSM lubricator RUNCMP RU slickline unit RUNCMP RIH w/ slickline to 8,309' to retrieve ball and rod from RHC plug. Pull to surface without the ball and rod. RIH w/ slickline and make second attempt. Retrieve ball and rod - LD slickline unit RUNCMP RU Little Red -Test lines -Bullhead 100 bbls of diesel down tubing @ 2 bpm / 1,800 psi - RD Little Red RUNCMP RU DSM lubricator -Install BPV - RD DSM lubricator RUNCMP Secure tree -Release rig at 20:30 10/31/07 OA= 120 psi - IA= 0 psi - TBG= 0 psi (after BPV installed) Note: before installing BPV recorded 145 psi in tubing RUNCMP Printed: 12/4/2007 8:41:30 AM BP EXPLORATION Page 1 of 1 .Leak-Off Test Summary. Legal Name: NGI-13 Common Name: NGI-13 .Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure {BHP) EMW 10/12/2007 FfT 2,360.0 (ft) 2,359.0 (ft) 9.10 (ppg) 185 (psi) 1,300 (psi) 10.61 (ppg) 10/16/2007 LOT 2,385.0 (ft) 2,383.0 (ft) 9.10 (ppg) 600 (psi) 1,727 (psi) 13.95 (ppg) 10/27/2007 FIT 8,516.0 (ft) 8,005.0 (ft) 8.80 (ppg) 500 (psi) 4,159 (psi) 10.00 (ppg) ~~ Printed: 12/4/2007 8:52:13 AM • Sperry Drilling Services Survey Report Company: BP Rmoco Date: 11)912007 Time: 15:19;45 Page: 1 Field: Prudhoe Bay (various} Co-ordinate(NE) Reference: Well: NGI-13, True North Site: NGt Vertical (TVD) Reference: 17.62 +.:33.7 51.3 Well: NGI-13 Section (VS) Reference: User (O.OON,O.OOE, 102.95Azi) Wellpath: NGI-13A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay (various) Map System:US State Pl ane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: NGI-13 Slot Name: 13 NGI-13 Well Position: +N/-S 2049.34 ft Northing: 5972800.71 ft Latitude: 70 19 49.983 N +E/-W 310.32 ft Easting : 687015.51 ft Longitude: 148 28 58.774 W Position Uncertainty: 0.00 ft Wellpath: NGI-13A Drilled From: NGI-13 500292034701 Tie-on Depth: 2383.70 ft Current Datum: 17.62 + 33.7 Height 51.32 ft Above System Datum: Mean Sea Level Magnetic Data: 10/1/2007 Declination: 23.69 deg Field Strength: 57669 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.70 0.00 0.00 102.95 Survey Program for Definitive Wellpath Date: 11/9/2007 Validated: No Version: 9 Actual From To Survey Toolcode Tool Name ft ft 83.70 2383.70 NGI-13 GYD CT MS (83.70-3033.7 GYD-CT-CMS Gyrodata cont.casing m/s 2385.00 2605.00 NGI-13A GYD-GC-SS (2385.00-260 GYD-GC-SS Gyrodata gyro single shots 2657.43 8966.59 NGI-13A IIFR+MS+Sag (2657.43-8 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg .deg ft ft ft ft ft ft 33.70 0.00 0.00 33.70 -17.62 0.00 0.00 5972800.71 687015.51 TIE LINE 83.70 0.11 27.20 83.70 32.38 0.04 0.02 5972800.76 687015.53 GYD-CT-CMS 133.70 0.04 311.92 133.70 82.38 0.10 0.03 5972800.81 687015.54 GYD-CT-CMS 183.70 0.17 266.30 183.70 132.38 0.11 -0.06 5972800.82 687015.45 GYD-CT-CMS 233.70 0.17 266.26 233.70 182.38 0.10 -0.21 5972800.80 687015.30 GYD-CT-CMS 283.70 0.14 242.73 283.70 232.38 0.07 -0.34 5972800.77 687015.17 GYD-CT-CMS 333.70 0.33 239.32 333.70 282.38 -0.04 -0.51 5972800.66 687015.00 GYD-CT-CMS 383.70 0.37 241.97 383.70 332.38 -0.18 -0.78 5972800.51 687014.73 GYD-CT-CMS 433.70 0.39 228.18 433.70 382.38 -0.37 -1.05 5972800.31 687014.47 GYD-CT-CMS 483.70 0.73 232.60 483.69 432.37 -0.68 -1.43 5972799.99 687014.10 GYD-CT-CMS 533.70 0.87 229.96 533.69 482.37 -1.12 -1.97 5972799.54 687013.56 GYD-CT-CMS 583.70 1.03 218.97 583.68 532.36 -1.71 -2.55 5972798.93 687013.00 GYD-CT-CMS 633.70 1.05 217.70 633.67 582.35 -2.43 -3.11 5972798.21 687012.46 GYD-CT-CMS 683.70 0.78 215.91 683.67 632.35 -3.06 -3.59 5972797.56 687012.00 GYD-CT-CMS 733.70 0.79 216.24 733.66 682.34 -3.62 -3.99 5972796.99 687011.61 GYD-CT-CMS 783.70 0.85 228.09 783.66 732.34 -4.15 -4.47 5972796.45 687011.14 GYD-CT-CMS 833.70 0.69 212.26 833.65 782.33 -4.64 -4.91 5972795.94 687010.72 GYD-CT-CMS 883.70 0.62 221.02 883.65 832.33 -5.10 -5.25 5972795.48 687010.39 GYD-CT-CMS 933.70 0.53 212.49 933.65 882.33 -5.50 -5.55 5972795.07 687010.10 GYD-CT-CMS 983.70 0.39 226.97 983.65 932.33 -5.81 -5.79 5972794.76 687009.86 GYD-CT-CMS 1033.70 0.23 194.88 1033.65 982.33 -6.02 -5.94 5972794.54 687009.72 GYD-CT-CMS 1083.70 0.16 201.14 1083.65 1032.33 -6.19 -6.00 5972794.38 687009.67 GYD-CT-CMS 1133.70 0.17 167.46 1133.65 1082.33 -6.33 -6.01 5972794.24 687009.66 GYD-CT-CMS 1183.70 0.27 159.19 1183.64 1132.32 -6.51 -5.95 5972794.05 687009.73 GYD-CT-CMS 1233.70 0.35 160.58 1233.64 1182.32 -6.76 -5.85 5972793.80 687009.83 GYD-CT-CMS 1283.70 0.17 146.11 1283.64 1232.32 -6.97 -5.76 5972793.60 687009.92 GYD-CT-CMS 1333.70 0.40 154.95 1333.64 1282.32 -7.19 -5.65 5972793.38 687010.04 GYD-CT-CMS 1383.70 0.40 153.80 1383.64 1332.32 -7.50 -5.50 5972793.07 687010.20 GYD-CT-CMS • Sperry Drilling Services Survey Report Company: BP Amoco Date: 11f9/2007 Time: 15:19:45: Page: 2 Field: Prutlhoe Bay (various) Go-ordinate(NE) Reference: Well: NGI.13, True North .Site: NGI vertical (TVD) Reference: 17 .62 +33.7 51.3 Well: NGI-13 Section (VS) Reference: User (O.OON,O.OOE,1 02.95Azi) Wetlpath: NGI-13A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN `MapE Tool ft deg deg ft ft ft ft ft ` ft 1433.70 0.46 162.10 1433.64 1382.32 -7.85 -5.36 5972792.73 687010.35 GYD-CT-CMS 1483.70 0.31 95.05 1483.64 1432.32 -8.05 -5.16 5972792.53 687010.55 GYD-CT-CMS 1533.70 0.34 98.75 1533.64 1482.32 -8.09 -4.88 5972792.50 687010.83 GYD-CT-CMS 1583.70 0.43 68.80 1583.64 1532.32 -8.04 -4.56 5972792.56 687011.15 GYD-CT-CMS 1633.70 0.47 91.57 1633.64 1582.32 -7.98 -4.18 5972792.63 687011.53 GYD-CT-CMS 1683.70 0.55 99.82 1683.63 1632.31 -8.03 -3.74 5972792.59 687011.97 GYD-CT-CMS 1733.70 0.68 111.42 1733.63 1682.31 -8.18 -3.23 5972792.46 687012.49 GYD-CT-CMS 1783.70 0.62 111.01 1783.63 1732.31 -8.38 -2.70 5972792.27 687013.02 GYD-CT-CMS 1833.70 0.62 106.34 1833.63 1782.31 -8.55 -2.19 5972792.11 687013.53 GYD-CT-CMS 1883.70 0.54 92.75 1883.62 1832.30 -8.64 -1.70 5972792.03 687014.03 GYD-CT-CMS 1933.70 0.59 98.79 1933.62 1882.30 -8.69 -1.21 5972791.99 687014.52 GYD-CT-CMS 1983.70 0.61 97.15 1983.62 1932.30 -8.76 -0.69 5972791.93 687015.04 GYD-CT-CMS 2033.70 0.64 95.76 2033.61 1982.29 -8.82 -0.15 5972791.89 687015.58 GYD-CT-CMS 2083.70 0.62 100.11 2083.61 2032.29 -8.90 0.40 5972791.83 687016.13 GYD-CT-CMS 2133.70 0.61 95.63 2133.61 2082.29 -8.97 0.93 5972791.77 687016.66 GYD-CT-CMS 2183.70 0.55 102.64 2183.61 2132.29 -9.05 1.43 5972791.70 687017.16 GYD-CT-CMS 2233.70 0.55 87.85 2233.60 2182.28 -9.09 1.90 5972791.67 687017.64 GYD-CT-CMS 2283.70 0.53 75.83 2283.60 2232.28 -9.03 2.37 5972791.74 687018.10 GYD-CT-CMS 2333.70 0.62 88.23 2333.60 2282.28 -8.96 2.87 5972791.82 687018.60 GYD-CT-CMS 2383.70 0.64 82.56 2383.60 2332.28 -8.92 3.42 5972791.88 687019.15 GYD-CT-CMS 2385.00 0.64 82.71 2384.90 2333.58 -8.92 3.43 5972791.88 687019.16 GYD-GC-SS 2420.00 3.79 102.00 2419.87 2368.55 -9.13 4.76 5972791.70 687020.49 GYD-GC-SS 2514.00 6.46 81.00 2513.49 2462.17 -8.95 13.02 5972792.09 687028.75 GYD-GC-SS 2605.00 10.61 82.00 2603.46 2552.14 -6.98 26.38 5972794.39 687042.05 GYD-GC-SS 2657.43 12.64 83.83 2654.81 2603.49 -5.69 36.86 5972795.94 687052.50 MWD+IFR+MS 2751.39 16.82 87.08 2745.67 2694.35 -3.90 60.67 5972798.33 687076.25 MWD+IFR+MS 2846.06 20.45 89.47 2835.36 2784.04 -3.05 90.90 5972799.93 687106.45 MWD+IFR+MS 2939.94 25.14 97.79 2921.91 2870.59 -5.60 127.09 5972798.28 687142.69 MWD+IFR+MS 3034.96 29.50 100.42 3006.31 2954.99 -12.57 170.11 5972792.39 687185.87 MWD+IFR+MS 3128.39 30.13 101.60 3087.37 3036.05 -21.44 215.71 5972784.65 687231.67 MWD+IFR+MS 3222.23 29.75 102.78 3168.69 3117.37 -31.33 261.49 5972775.91 687277.68 MWD+IFR+MS 3315.26 30.98 104.35 3248.96 3197.64 -42.37 307.20 5972766.01 687323.65 MWD+IFR+MS 3411.10 30.86 103.78 3331.18 3279.86 -54.34 354.97 5972755.24 687371.70 MWD+IFR+MS 3506.46 30.02 103.79 3413.39 3362.07 -65.85 401.89 5972744.90 687418.89 MWD+IFR+MS 3600.28 30.12 103.77 3494.59 3443.27 -77.05 447.54 5972734.85 687464.81 MWD+IFR+MS 3694.13 31.04 103.56 3575.38 3524.06 -88.33 493.94 5972724.73 687511.46 MWD+IFR+MS 3789.80 30.57 102.86 3657.56 3606.24 -99.53 541.63 5972714.72 687559.42 MWD+IFR+MS 3885.10 29.38 102.00 3740.11 3688.79 -109.78 588.13 5972705.63 687606.15 MWD+IFR+MS 3980.96 29.53 101.76 3823.58 3772.26 -119.48 634.26 5972697.08 687652.51 MWD+IFR+MS 4075.11 29.75 101.18 3905.41 3854.09 -128.74 679.89 5972688.96 687698.35 MWD+IFR+MS 4168.90 30.44 103.69 3986.56 3935.24 -138.88 725.80 5972679.98 687744.50 MWD+IFR+MS 4263.50 31.44 103.10 4067.70 4016.38 -150.14 773.12 5972669.90 687792.08 MWD+IFR+MS 4358.58 32.53 102.54 4148.34 4097.02 -161.31 822.22 5972659.95 687841.45 MWD+IFR+MS 4453.07 33.30 102.29 4227.66 4176.34 -172.35 872.37 5972650.17 687891.85 MWD+IFR+MS 4549.28 32.81 104.71 4308.30 4256.98 -184.59 923.39 5972639.21 687943.16 MWD+IFR+MS 4643.56 30.76 104.31 4388.44 4337.12 -197.04 971.46 5972627.96 687991.52 MWD+IFR+MS 4734.62 30.00 104.67 4467.00 4415.68 -208.56 1016.05 5972617.56 688036.38 MWD+IFR+MS 4831.88 29.57 104.45 4551.41 4500.09 -220.70 1062.81 5972606.58 688083.43 MWD+IFR+MS 4926.76 28.74 103.38 4634.27 4582.95 -231.83 1107.67 5972596.58 688128.55 MWD+IFR+MS 5020.92 28.79 103.34 4716.81 4665.49 -242.30 1151.76 5972587.22 688172.88 MWD+IFR+MS 5115.82 29.00 101.76 4799.89 4748.57 -252.26 1196.51 5972578.37 688217.87 MWD+IFR+MS 5210.77 28.55 105.51 4883.13 4831.81 -263.02 1240.91 5972568.73 688262.52 MWD+IFR+MS Sperry Drilling Services Survey Report Company: BP AmoCO Date: 11!9!2007 Time: 15:19:45 Pager 3 :Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: W eIL• NGI-13, Tcue North Site: NGI 'Vertical (TVD) Reference: 17.62:+ 33.7 51:3 WeIL• NGI-13 Section (VS) Reference: User (OOON,O.OOE,102.95Azi) Wellpatb: NGI -f3A SurveyCalcnlation'Method: Mi nimum Curvature 'Db: Oracle Survey MD Inc! Azim TVD ' Sys TVD N/S E/W MapN MapE Tonl ft deg deg ft ft ft ft ft ft 5305.40 28.56 105.65 4966.24 4914.92 -275.17 1284.49 5972557.67 688306.38 MWD+IFR+MS 5399.38 29.62 104.66 5048.37 4997.05 -287.10 1328.59 5972546.83 688350.76 MWD+IFR+MS 5495.81 30.53 103.98 5131.82 5080.50 -299.05 1375.41 5972536.06 688397.86 MWD+IFR+MS 5592.13 30.55 103.98 5214.77 5163.45 -310.88 1422.91 5972525.42 688445.64 MWD+IFR+MS 5685.36 28.65 104.71 5295.83 5244.51 -322.28 1467.52 5972515.14 688490.52 MWD+IFR+MS 5780.19 28.89 105.69 5378.96 5327.64 -334.24 1511.56 5972504.27 688534.84 MWD+IFR+MS 5874.80 27.91 101.91 5462.19 5410.87 -345.00 1555.24 5972494.61 688578.77 MWD+IFR+MS 5969.84 25.74 101.96 5547.00 5495.68 -353.86 1597.19 5972486.79 688620.93 MWD+IFR+MS 6063.97 22.49 102.12 5632.90 5581.58 -361.88 1634.80 5972479.72 688658.73 MWD+IFR+MS 6158.05 19.48 103.36 5720.73 5669.41 -369.29 1667.67 5972473.13 688691.76 MWD+IFR+MS 6253.08 15.72 104.18 5811.29 5759.97 -376.10 1695.57 5972467.02 688719.83 MWD+IFR+MS 6345.09 14.48 106.41 5900.13 5848.81 -382.41 1718.69 5972461.29 688743.10 MWD+IFR+MS 6434.06 15.86 106.35 5985.99 5934.67 -388.97 1741.03 5972455.28 688765.59 MWD+IFR+MS 6528.57 13.88 102.99 6077.34 6026.02 -395.16 1764.47 5972449.69 688789.18 MWD+IFR+MS 6621.96 14.59 102.06 6167.86 6116.54 -400.13 1786.89 5972445.27 688811.71 MWD+IFR+MS 6718.11 13.74 107.73 6261.09 6209.77 -406.14 1809.61 5972439.83 688834.57 MWD+IFR+MS 6807.99 14.42 108.12 6348.27 6296.95 -412.87 1830.41 5972433.62 688855.53 MWD+IFR+MS 6907.39 12.76 105.58 6444.88 6393.56 -419.67 1852.75 5972427.38 688878.03 MWD+IFR+MS 6999.02 13.56 105.78 6534.11 6482.79 -425.31 1872.84 5972422.25 688898.25 MWD+IFR+MS 7098.68 14.58 104.70 6630.77 6579.45 -431.67 1896.21 5972416.47 688921.78 MWD+IFR+MS 7192.30 15.50 105.29 6721.19 6669.87 -437.96 1919.68 5972410.77 688945.39 MWD+IFR+MS 7285.75 16.42 106.41 6811.03 6759.71 -444.98 1944.39 5972404.37 688970.27 MWD+IFR+MS 7380.93 16.94 105.82 6902.21 6850.89 -452.56 1970.64 5972397.44 688996.70 MWD+IFR+MS 7476.55 15.21 104.14 6994.09 6942.77 -459.42 1996.21 5972391.22 689022.43 MWD+IFR+MS 7569.58 12.74 104.94 7084.36 7033.04 -465.05 2017.96 5972386.14 689044.31 MWD+IFR+MS 7664.03 10.92 106.90 7176.80 7125.48 -470.34 2036.58 5972381.32 689063.06 MWD+IFR+MS 7759.67 9.57 103.36 7270.91 7219.59 -474.81 2052.98 5972377.26 689079.57 MWD+IFR+MS 7854.88 7.87 104.28 7365.02 7313.70 -478.25 2067.00 5972374.17 689093.67 MWD+IFR+MS 7949.01 5.25 107.32 7458.52 7407.20 -481.12 2077.36 5972371.56 689104.09 MWD+IFR+MS 8043.62 3.20 107.79 7552.87 7501.55 -483.21 2084.01 5972369.63 689110.79 MWD+IFR+MS 8137.19 1.60 108.48 7646.36 7595.04 -484.43 2087.73 5972368.51 689114.54 MWD+IFR+MS 8230.95 0.20 118.20 7740.10 7688.78 -484.92 2089.12 5972368.05 689115.94 MWD+IFR+MS 8324.73 0.17 354.60 7833.88 7782.56 -484.86 2089.25 5972368.12 689116.07 MWD+IFR+MS 8418.84 0.19 297.24 7927.99 7876.67 -484.65 2089.10 5972368.32 689115.91 MWD+IFR+MS 8443.48 0.20 316.30 7952.63 7901.31 -484.60 2089.03 5972368.37 689115.85 MWD+IFR+MS 8511.80 0.32 319.54 8020.95 7969.63 -484.36 2088.83 5972368.60 689115.63 MWD+IFR+MS 8603.12 0.31 346.19 8112.27 8060.95 -483.93 2088.60 5972369.03 689115.40 MWD+IFR+MS 8698.99 0.54 331.30 8208.14 8156.82 -483.28 2088.32 5972369.67 689115.10 MWD+IFR+MS 8793.58 0.61 333.23 8302.72 8251.40 -482.44 2087.88 5972370.50 689114.64 MWD+IFR+MS 8886.76 0.81 346.65 8395.89 8344.57 -481.36 2087.51 5972371.57 689114.24 MWD+IFR+MS 8966.59 0.70 348.44 8475.72 8424.40 -480.33 2087.28 5972372.59 689113.99 MWD+IFR+MS 9006.00 0.70 348.44 8515.12 8463.80 -479.86 2087.18 5972373.06 689113.88 PROJECTED to TD 11/12!07 NO. 4496 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne Wa_II .Inh $ 1 nn riser s:n.. n..a., o~ n_~__ L3-08 11637143 LDL - 10/27/07 1 L3-08 11637143 LDL _ C 3 10/28/07 1 N-12 11626132 LDL j ~ -~(G 11/03/07 1 14-18B 11637368 ISOLATION SCANNER '~-- 10126/07 1 NGI-13A 11637144 CEMENT BOND & IMAGE LOG 10/28/07 1 GNI-04 11676971 USIT ~j'~--- J'~- 11/05/07 1 ~~-~~~ ~+~•~•~~~~~~•+.~~- ~~~..~~~ ~ u ~ .aw~.n.v r.~.v RG I VRI.119V VIYG l+Vf T ~ra~.n Iv: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 '~ ~. ~ ~r ~ >t , 900 E. Benson Blvd. ~ ^'` ' ' t~ Anchorage, Alaska 99508 ~r Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ Received by: ,~_ 0 MEMORANDUM To: Jim Regg ~~j tt(Z ~ ~ ~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 31, 2007 SLI6JECT: Mechanical Integrity'Cests BP EXPLORA'f[ON (ALASKA) !NC NGI-13A PRIiD1iOF, BAY UNIT NGI-13A Sre: Inspector NON-CONFIDENTIAL Reviewed By• P.I. Soprv ~ 11 -Z-lD7 Comm Well Name' PRUDHOE BAY UNIT' NGI-13A API Well Number: so-o2~-zo347-o t -oo Inspector Name: Bob Noble Insp Num: mitRCN071031073757 Permit Number: 207-I I4-0 Inspection Date• 10l3U2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ___ Well j NGI-I3A ,Type Inj. ~ N ' TVD _...7838 IA 175 x000 •%' 3950 39s0 r 1_. P.T. o7t lao LTypeTest sPT ~-Test psi aooo OA o o _ o o _ ~ __ _._ Interval orxER p~ P / Tubing ?ooo z9oo zaso zsso ! '~ NOteS' Post compleation IA pressure test l • \~~~ ~ 1 ~~~~ Nay ~ ~ Zoo? Wednesday, October 3l, 2007 page I of I Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-13A BP Exploration Alaska, Inc. Permit No: 207-114 Surface Location: 489' FSL, 840' FWL, SEC. O1, Tl 1N, R14E, UM Bottomhole Location: 1' FSL, 2945' FWL, SEC. Ol, T11N, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness y equired test, contact the Commission's petroleum field inspector ~ (907 659 607 (pager). J ~:~ No Ch irm DATED this day st, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~J ~ ~ ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL ~~I3 20 AAC 25.005 ~~~~V~~ AUG 2 2 2007 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if ` r ~$ . ^ Coalbed Methane ^ ~~~gs ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU NGI-13A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9002 TVD 8512 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 840' FWL 489' FSL SEC 01 T11 N R14E UM 7. Property Designation: ADL 028302 Pool , , , , . , Top of Productive Horizon: 1' FSL, 2945' FWL, SEC. 01, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: ~ 0, 20 ~ ~ (~'~ Total Depth: 1' FSL, 2945' FWL, SEC. 01, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,100' 4b. Location of Well (State Base Plane Coordinates): Surface: x-687016 y-5972801 Zone-ASP4 10. KB Elevation Plan (Height above GL): 48.6 feet 15. Distance to Nearest Well Within Pool: 385' 16. Deviated Wells: Kickoff Depth: 2410 feet Maximum Hole An le: 30 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3390 Surface: 2590 18. Casin cPr `ram: S ificatio ns <To = Settin De th ->Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 12-1/4" 9-5/8" 47# L-80 TC-II 8467' Surface Surface 8467' 7977' 837 sx LiteCrete 404 sx Class'G' 8-1/2" 7" 26# L-80 BTC-M 735' 8267' 7777' 9002' 8512' Uncemented Slotted Liner 19. PRESE NT WELLCONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 8950 Total Depth TVD (ft): Plugs (measured): 8620 7595 Effective Depth MD (ft): 8907 Effective Depth TVD (ft): 8581 Junk (measured): 8830 Casing Length ize Cement Volume MD TVD Conductor /Structural 74' 20" 277 sx Arcticset 74' 74' Surface 2709' 13-3/8" 4800 sx Arcticset II 2709' 2709' Intermediate 8015' 9-5/8" 700 sx Class'G' 8015' 7741' Pr duction Liner 1224' 7" 325 sx Class 'G' 7725' - 8949' 7459' - 8619' Perforation Depth MD (ft): 8410' - 8862' Perforation Depth TVD (ft): 8123' - 8540' 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 f ~egoing is true and correct. Contact Kris Honas, 564-4338 Printed Name G rl s Title Senior Drilling Engineer Prepared By Name/Number: Si nature `~ " ~ Phone 564-4191 Date ~ f Terrie Hubble, 564-4628 .Commission Use Onl Permit To Drill Number: ~D,?/ ~ API Number: 50-029-20347-01-00 Permit Approva Date: See cover letter for ~ other re uirements Conditions of Approval: ~d~~(~ ` ~~ ~5 If box is checked, wel~may not be used to explore for, test, or produce coalbed me~t,,thane, gas hydrates, or gas contained shales: LU M L ~ ~ ~C(-MCCn~ ~~C7~~~~ `,~ Samples Req'd: ^ Yes u No ud Log Req'd: ^ Yes ~No _ ! /r~~~ ~ ~~ (H~S Measures: [Yes ctio a Survey Req'd: ®Yes ^ No Other: ` PROVED BY THE COMMISSION Date ~ ~ ~ ,COMMISSIONER iSIQIt Form 10-401 Revised 12/2005 (,/ ~ ~ Submi In Duplicate R1G1NA~ • To: Alaska Oil & Gas Conservation Commission From: Kristopher E. Honas, Drilling Engineer Date: August 20, 2007 Re: NGI-13A Sidetrack Permit to Drill by Approval is requested for the permit to drill NGI-13A. The NGI-13A sidetrack is currently scheduled for Doyon 14 beginning August, 2007. Well NGI-13 is an Ivishak gas cap injector currently shut-in due to a failed MIT-IA which lead to the discovery of a production casing leak at 5101' MD. The well also has a history of TxIA communication via the SSSV. The well has been shut in and secured with a wireline retrievable plug set at 7595' MD (3/22/06). NGI-13 was drilled and completed in July 1979. The well is completed with 7" tubing. The 7" liner has 400' of perforations. Well integrity issues began with T x IA communication. The source appeared to be the SSSV control line. In February 2002 the SSSV was changed and a mechanical integrity test on the inner annulus passed. By 2005 the IA pressure began to increase again and the SSSV was replaced with an injection valve. The well received an AA from the state in June 2006 to continue operations. When another MIT-IA failed in September a production casing leak was discovered at 5101' MD. The liquid leak rate was 1.2 gpm. The AA was canceled and a plug was set at 7595' MD. The plan to repair NGI-13 includes the following: The existing 7" tubing string will be cut and pulled below 3000' MD. The 9-5/8" casing will be pulled from 40' below the EOCU formation. tt is possible that some cement and 9-5/8" casing will need to be milled. A whipstock exit from the 13-3/8" casing below the EOCU formation is estimated at -2410' MD. A 12-1/4" bit will be used to drill from the window to -8473' MD (below the bottom of the HRZ formation). 9-5/8" production casing will be run with cement to 4100' MD. An 8-1/2" bit will be used to drill from the 9-5/8" shoe to TD at 9002' MD. The production hole will utilize 7" slotted liner. The well will be completed with 7-5/8" plastic coated tubing with premium threads from the 7" liner top to surface. Planned Well Summary Well NGI-13A Well Injector Target Ivishak T e Sidetrack Ob'ective Estimated Start Date: August 30, 2007 Time to Com lete: 26.7 Days Surface Northin Eastin Offsets TRS Location 5,972,800.71 687,014.51 4790.73' FNL / 840.08' FWL 11 N, 14E, 1 Target Northin Eastin TVDss Offsets TRS Location 5,972,365.5 689,132.5 -7738.5 5279.1' FNL / 2945.26' FWL 11 N, 14E, 1 Bottom Northin Eastin TVDss Offsets TRS Location 5,972365.5 689132.5 -8464.5 5279.1' FNL / 2945.26' FWL 11 N, 14E, 1 Planned KOP: 2410'MD / 2363'TVDss Planned TD: 9002' MD / 8465' TVDss Ri Doyon 14 API Number: 50-029-20347-01 RKB: 48.6' NGI-13A Permit to Drill Application Page 1 • • Surface and Anti-Collision Issues Close Approach/Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Well Interval: 12 1/4" intermediate interval into top of the Put River formation. Maximum antici ated BHP: 3,390 psi at 8,000' TVDss. Maximum surface ressure: 2,590 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: A worst case scenario of 9.6 ppg pore pressure, 10.6 ppg FIT and 10.1 mud, fives a 25 bbl kick tolerance. Planned BOPE test pressure: 250 psi low / 4,000 psi high - 7 da test c cle Workover o s / 14 da test c cle Drillin o s BOPE configuration for 9 s/8" int casin to to bottom . Annular preventer, 9 s/e"pipe rams, blind/shear rams, variable rams. Well Interval: 8'/z" in'ection interval in Ivishak Zones 1, 2, 3 and 4 sands Maximum antici ated BHP: 3,390 psi at 8,300' TVDss. Maximum surface pressure: 2,560 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.4 pp mud and 9.0 p EMW FIT. Planned BOPE test ressure: 250 si low / 4,000 si hi h -14 da test c cle Drillin o erations Planned com letion fluid: 8.4 pp seawater / 7.1 p Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. Area of Review Nearby Cement Integrity Annulus Integrity Well Name Dist, Ft. Comments Production/Intermediate Cement Barriers Will be P&A'd pre-rig. Original 9-5/8" casing cemented in three stages with no indication of losses. First stage (6/24/79): 700 sks of 15.8 . pp~class G, bumped the plug and held 2000. si. econd stage: pumped 300 sks of Arcticset I through the lower FO tool. Third NGI-13 385' PC Leak sta e: um ed 75 sks of Arcticset. The 7" liner was fully cemented on 3/23/76. 1490' The cement was tagged at 7940' MD 168' (outside'/ above the top of the liner. 9-5/8" casing was NGI-05 mile radius Normal cemented with some returns on 3/16/76. NGI-07 was P&A'd for the NGI-07A sidetrack, 1940' NGI-07A has a USIT log in the 9-5/8" (outside'/ intermediate interval proving zonal isolation. NGI-07 mile radius Normal Lo ed on 10/13/2006 7" liner was fully cemented on 11 /10/75. Approximately 572' of cement was 2020' washed/reamed from top of liner. 9-5/8" casing (outside'/ was cemented with 1000 sks. There is no NGI-02 mile radius Normal indication of losses durin the cement 'ob. NGI-13A Permit to Drill Application Page 2 • Hydrogen Sulfide NGI is not designated as an H2S site. #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) Well Name H2S i.evel Gas in'ector - no sam les Gas in'ector - no sam les Gas in'ector - no sam les Gas in'ector - no sam les Gas in'ector - no sam les N/A -Gas Injector Formation Markers NGI-13A (Based on SOR) Formation T Est. Formation NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks OTE: All formation tops are required from urface to TD for all new wells ~ °"' ° - ° ° ~ ° - ~ • ~ ~ ~ ~ ~ ....... ................................... G1 505 ......................:::::::::::::::::::~©.::::::::::::::::: SV6 ........ 20 ......_ .............1'600`_. .......................... BPRF 1830 20 EOCU 2315 ~•" ""' 2(3•••••• Planned K4P (~2A10'11rID) SVS 3085 20 SV4 3335 20 S V 3 3775 20 SV2 3937 20 SV 1 4325 20 UG4 4978 20 UG4A 4835 20 UG3 5040 20 UGl 5500 20 WS2 6120 20 WS1 6310 20 CM3 6560 20 CM2 7260 20 Commercial Projected Tops based on NGI-07 ****IMPORTANT**** Will be necessary to adjust KOP after acquiring new EOCU pick. (See Comments Section Below) Set 9 5/8' casing 5-10' below BHRZ ----------------------------------------- Expect -50' thick Put River sand (~100md) in pressure communication with underlying Ivishak Fm. CM 1 7405 ......... 20~ "" ' . THRZ ........_.. 7743 "° 20 BHRZ .._ ............... .. ... TPTR 7935 20 es BPTR 7990 20 ~ .................................................................................................... Kingak Fm. truncated by LCU ....................................... LCU ~" ~` 0-5' lower Kingak (TJA) possible NGI-13A Permit to Drill Application (minimal exposure thus <9.OIb mud should be sufficient) • .~ TKNG TSGR 7990 20 TSHA 8040 20 TSHB SO55 20 TSHC 8070 20 TSAD 8080 20 es 42SB 8120 20 es TCGL 8160 20 es BCGL 8225 20 ~,P~ I 23SB I I 8275 ! 20 I vPa 22TS 8330 20 yes 21TS 8360 20 ...........es....... TZ 1 B ..... ......................8..4.05...................... ...................20 .................. es TDF ~... I 8445 I 20 BSAD 8475 20 Final TD = 8465TVDSS (-5-10' above BSAD) Slotted Liner Completion TD Criteria: Intermediate Casing Point - TD 5-10' below BHRZ -verify Put River formation in sample. Production - TD well 60' tvd below Z1 B or 10' above BSAD. Adequate rathole to complete lowest Z1 B sand is required. Faults The proposed NGI-13A well is located in an upthrown fault block with structural dip expected to be to the south. One seismically mapped fault crossing is expected. This possible fault will be crossed in the CM2 formation. The risk of lost circulation for this fault crossing is low due to the presence of clay within the CM2, which likely produced clay-smearing along the fault plane and thus, lowers the risk of lost circulation. There are also a number of faults at the Sag River and Shublik level. These faults will be avoided by hitting the targets planned in the directional. It will be important to avoid these faults due to lost circulation potential. Fault Details Formation Where Encounter Fault MD Intersect Tvnss intersect Est. Throw Tnrow Direction Uncertain CM2 7900 ft. -7365 ft 10-20 ft. Down to SE +/- 200 ft. MD Directional -Sperry WP_05 KOP: 2410' MD Maximum Hole An le: ~30° in the 12'/" intermediate section Close Approach Wells: All wells pass major risk close approach criteria. The closest well is NGI-14 at 127' ctr-ctr 52' allowable deviation at 2445' tanned MD. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 20100' Nearest Well within Pool: NGI-13 parent wellbore is 385' away from planned well NGI-13A in the Ivishak NGI-13A Permit to Drill Application Page 4 • • Logging Program Hole Section Required Sensors /Service 12'/2" intermediate: Real time MWD Dir/GR/PWD 8 %" roduction: Real time MWD Dir/GR/PWD O en Hole: None Cased Hole: USIT/GR in Intermediate section to find TOC and base of EOCU formation Mud Program Hole Section / o eration: Drilling 12-'/4" interval, window - 8277' To HRZ T e Densit Viscosit PV YP Chlorides API FL H LSND 9.1 -9.3 45-60 15-22 25-30 <600 6.0-8.0 9.0-9.5 Hole Section / o eration: Drillin 12 '/o" interval, 8277' HRZ) - 8467' Int TD T e Densit Viscosit PV YP Chlorides API FL H LSND 9.8 45 - 60 18 - 25 25 - 35 <600 < 5.5 9.0 - 9.5 Hole Section /operation: Drillin 8''/2" production interval to 9002' TD) T pe Densit Viscosit PV YP LSRV API FL H Flo-Pro SF 8.8 45 - 55 8 -15 24 - 30 >20,000 7.0 - 9.0 9.0 - 9.5 Disposal Annular No annular injection in this well. In'ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at Handlin DS-04. Any metal cuttings should be sent to the North Slope Borough. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for disposal. Casing/Tubing Program Sizzle Tb O.D. Wt/Ft Grade Conn Burst Colplspse Length MD / TVDrkb MD / TVDrkb 12'/" 9 5/8" 47# L-80 TC-II 6,870 4,760 8467' Surface 8,467' / 7977' 8 %2" 7" 26# L-80 BTC-M Slotted Slotted 735' 8267' / 7777' 9002' / 8512' Tubing 7 5/8" 29.7# L-80 Vam Top HC 6,890 4,970 7,930' Surface 8267' / 7777' NGI-13A Permit to Drill Application Page 5 • • Cement Program Casin Strin 9 $/8", 47#, L-80, TC-II Intermediate casin Slurry Design Basis: 4367' of 9 s/e' x 12?/" annulus with 30% excess, plus ~90' of 9 $/8", 47#, shoe track. TOC at -4100 MD. Pre-Flush: 20 bbls CW100 S acer Fluid: 60 bbls MudPush II at 10.6 Slur T e 12.5 Litecrete Mix method Mix on the fl Lead Slurry: BHST /BHCT 101 ° F / 72° F confirm with SLB rior to cementin Slur Volume 190 bbl / 1373 cf / 837 sx Litecrete, 12.5 ; 1.64 cf/sk Slur T e 15.8 Class `G' slur with `GASBLOK' additive Mix method Mix on the fl Tail Slurry: BHST /BHCT 170° F / 130° F Slur Volume 84 bbls / 473 cf / 404 sx Class 'G', 15.8 ; 1.17 cf/sk. NGI-13A Drill and Complete Procedure Summary Pre-Riq Operations: 1. Pull the WRP set at 7595' MD. 2. Run a static bottom hole pressure survey to determine proper mud weights during drilling operations. 3. Plug and abandon the existing perforations with 53 bbls of 15.8 ppg class G cement. Lay cement in with coil from PBTD to the 9-5/8" x 7" tubing packer. Cement volume based on the following calculations: a. 1182' of 7", 29# liner: .037149 bbls/ft = 43.9 bbls b. 114' of 9-5/8", 47# casing: .073206 bbls/ft = 8.3 bbls c. 9' of 9-5/8", 47# x 7", 29#: .025606 bbls/ft = 0.23 bbls d. 9' of 7", 29" tubing: .037149 bbls/ft = 0.33 bbls e. TOTAL: 53 bbls 4. RU slick line and drift the tubing to TOC to verify depth. 5. Pressure test the cement plug to 2500 psi. 6. Perforate the tubing above the production packer for circulation holes. 7. Circulate the well to 9.8 ppg brine. 8. Jet cut the 7", 26# tubing in the middle of a full joint at -3000' MD. 9. Bleed all casing and tubing pressures to zero. Freeze protect the tubing and IA with diesel to 2200' MD. 10. Function all lock down screws and repair/replace as necessary. 11. PPPOT - T to 5000 psi, PPPOT - IC to 3500 psi. 12. Set a BPV. Remove the wellhouse and flow lines. Level the pad as necessary. Riq Operations: 1. MIRU Nabors rig 2ES. 2. MIT-OA to 2000 psi for 30 minutes. 3. Pull BPV. 4. Run and test a TWC from below to 1000 psi for 30 minutes. 5. Nipple down the tree. Nipple up and test the BOPE to 4,000 psi high, 250 psi low. Pull the TWC. NGI-13A Permit to Drill Application Page 6 • • a. Ensure one set of rams are equipped to close around 7" tubulars. 6. Circulate out freeze protect by circulating 9.8 ppg brine around tubing cut. 7. Unseat the hanger. Pull and lay down 7" tubing from the pre-rig casing cut at 3000' MD. 8. Rig up E-line. Make up a gauge ring /junk basket to drift 9-5/8" casing. RIH and tag tubing stump. POOH. 9. Make up USIT\GR\CCL. RIH, log from tubing stump to surface looking for TOC, EOCU formation and casing collars. Rig down E-line. 10. Change out one set of rams to 9-5/8". Test to 4000 psi high and 250 psi low. 11. Make up 9-5/8" casing cutter for 47# casing. RIH, picking up singles. Cut casing as deep as possible above the top of cement depending on USIT results, DO NOT cut a collar. NOTE: KOP must be at least 10' below EOCU formation. If cement is above the bottom of the EOCU, cut the casing deep enough to position the top of the window 10' below EOCU. Make additional cuts every 90' until the TOC is reached. Washover and pull the ~90' sections one at a time until the deepest cut is reached. 12. Establish circulation through 13-3/8" x 9-5/8" annulus to verify cut above TOC. POOH. 13. Spear 9-5/8" 47# casing from the mandrel hanger. Circulate as required to clear annulus. Pull and lay down. 14. Change rams back to variables. Test to 4000 psi high, 250 psi low. 15. PU 13-3/8" casing scraper and 12-1/4" mill assembly. Cleanout to the EZSV set depth. POOH. LD assembly. 16. Make up an EZSV for 13-3/8" 72# casing. RIH and set as deep as 9-5/8" casing cut allows. POOH. 17. Test the EZSV and 13 3/8" casing to 4000 psi for 30 minutes. Chart test. ~~c~ _~ 18. Pick up and RIH with 13-3/8" Baker bottom trip anchor whipstock assembly. a. Verify orientation with Gyro. 19. Shear off. Displace well to 9.1 ppg milling fluid. 20. Mill window, plus 20' beyond the window. Circulate well clean. 21. Conduct FIT. If FIT does not reach a minimum of 10.6 ppg, contact engineer immediately. 22. Drill the 12-1/4" intermediate hole increasing MW as necessary until 200 ft above the HRZ. At 200 ft above the HRZ, the MW must be adjusted to a minimum weight of 9.8 ppg. ~~ 23. Drill ahead to TD in the base HRZ /top Put River at -8467' MD with 9.8 ppg drilling fluid; monitor for losses. ~~ Circulate the wellbore clean. POOH and lay down 12-1 /4" drilling assembly. 24. Change out one set of rams to 9-5/8". Test to 4000 psi high, 250 psi low. 25. Run 9-5/8", 47#, TCII casing to TD. 26. Cement 9-5/8" production casing to 4100' MD. Pump freeze protection to ensure the annulus is protected below 2100' TVD. 27. Change rams back to variables. Test to 4000 psi high, 250 psi low. 28. Make up and RIH to the landing collar with the 8-1/2" drilling assembly. 29. Test the 9-5/8" casing to 4000 psi for 30 minutes and chart. 30. Drill out the 9-5/8" float equipment to the shoe. 31. Displace the well with 8.8 ppg FloPro SF drilling fluid. 32. Drill out the shoe, plus 20' of new formation. 33. Conduct an FIT to 10.0 ppg EMW. 34. Drill the 8-1/2" hole to TD at 9,002' MD. 35. Circulate the well bore clean, short tip to the shoe; circulate. POOH. 36. Run USIT/GR/CCL log on 9 5/8" casing to find TOC. 37. Pickup and RIH with 7" slotted production liner. 38. At TD, release from liner. Set liner top hanger/packer. POOH. 39. Change out rams to 7-5/8" for running tubulars. Test to 4000 psi high, 250 psi low. 40. Make up and run 7-5/8", 29.7#, L-80, VAM TOP internally plastic coated (IPC) completion string. Torque turn each connection. 41. Reverse circulate corrosion inhibitor and diesel freeze protection sufficient for annular freeze protection to 2200' MD. NGI-13A Permit to Drill Application Page 7 ~~ 42. Drop the ball and rod. Set the packer and immediately bring pressure up to tubing test pressure of 4000 psi. Chart this test for 30 minutes. Bleed the tubing pressure to 2000 psi. Increase the annular pressure to 4000 psi. Chart this test for 30 minutes. Notify the AOGCC to witness tubing and annular pressure test. 43. Bleed the annulus pressure to zero. Bleed the tubing pressure to zero. 44. Set and test a TWC to 1000 psi. 45. Change rams back to variables. Nipple down the BOPE. 46. Nipple up and test the tree to 5000 psi. Lubricate out the TWC. 47. Rig up slickline. Pull the ball and rod. Rig down slickline. 48. Bullhead diesel freeze protection fluid down the tubing, sufficient to freeze protect 2200' of 7-5/8" tubing. 49. Secure the well with a BPV. RDMO. Post-Rig Operations: 1. Set SSSV injection valve. 2. Install well house and instrumentation C -~ NGI-13A Permit to Drill Application Page 8 ~ • Drilling Hazards and Contingencies POST THIS NOTICE 1N THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.90 ppg EMW. This pressure is estimated based on offset well pressures and should be confirmed from the pre-rig bottom hole pressure survey. B. The Put River is in pressure communication with underlying Ivishak, monitor PWD for potential pressure increase. II. Lost Circulation/Faults A. One fault is expected to be crossed in the CM2 formation. Risk of lost circulation from this fault is anticipated to be low. There are also faults near the Shublik and Sag River formations. The directional plan attempts to avoid these faults due to a higher risk of lost circulation. No losses occurred in the parent NGI-13A wellbore and the potential for lost circulation for NGI-13A is considered low. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 45.5 bbls with 9.6 ppg mud, 10.6 ppg FIT, and an 9.0 ppg pore pressure at the Put River. This FIT should prove to be adequate formation strength for expected ECD's. B. Recent sidetrack AGI-07A experienced gas cut mud in the reservoir, although reservoir pressure was predicted at 7.7 ppg. After weighting up to 9.0+ ppg the gas ceased, but minor static losses ensued and did not cease throughout the remainder of the well and completion. Gas-detection/mud logging equipment will be available to aid the mud weight decision process if gas cut mud occurs in this well. C. The Kick Tolerance for the production hole section is infinite with 8.4 ppg mud, 10.0 ppg FIT, and an 8.3 ppg pore pressure. This FIT should prove adequate formation strength for expected ECD's. IV. Casing/ Formation Integrity Testing Test Point Test lle h Test t e TEST Pressure 12 '/" window 20-ft min from the 12 '/" window FIT 10.6 EMW 9-5/8" casing Landin collar to surface 30 minute recorded 4000 si 9-5/8" shoe 20-ft minimum from the 7" shoe FIT 10.0 EMW 7" casing Landing collar to surface 30 minute recorded 4000 psi V. Stuck Pipe A. Stuck pipe not anticipated. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal with the short, vertical, slotted liner completion. VI. Hydrogen Sulfide A. NGI is not designated as an H2S site since samples are not taken on the pad, however Standard Operating Procedures for H2S precautions should be followed at all times. VIII. Anti-Collision Issues A. All wells pass major risk close approach criteria. The closest well is NGI-14 at 127' ctr-ctr (52.25' allowable deviation) at 2445' planned MD. NGI-13A Permit to Drill Application Page 9 __ ..TREE _ '. '~ ~ WELLHEAD = GRAY ................................. .................. ~ I ACTUATOR = A}CELSON .................................................. .. . . SAFETY ROTES: .. .. . ........ KB. ELEV = 48' .................................................................... BF. ELEV = . ................... .......... . _ . . .......3 300' KOP , Max Angle = 27 ~ 41 DO' ' Datum.MD..= .........................9188'. ~ 2199' ?" OTIS RPB SSSV NIP, ID = 5.963" Datum T VD = 8800' SS ?" TBG-NPC, 26#, L-80, .0383 bpf, ID = 6.278" 2220' 13-318" CSG, 72#, N-80, ID = 1 L J4r'"' 2709' 7595' 4-1, ~" tiR~FD VVP.P (10M 2x106) Minimum ID = 4.843" ~76~0' '~ 7596' ?' SEAL BOftE EXT 7" BAKER SHEAROUT SUB ( °° ~ 7602' 9-575" 1{ T' BAKER SAB=2 PKR ?'TBG-hdPC, 29#, L-80, .03?1 bpf, ID = 8.184" ~~ 7611' ~ 7620' ?"BAKER SHEAP,OUT SUB 7611' ELhdD TT LOGGED 0512418? TAP ~F ," LNR 7725' ~- 9-51g° CSG, 4?#, rJ-80, ID = 8.s81" 8015' PERFORP.TIOr! SU~v1b1AR'`~' REF LOG: BRCS Ord OSr50P9 ANGLE AT TOP F'ERF: 18 L 8410' Note: Referto Production DB fnr historical perf data SIZE 5PF INTER~IAL OpnlSgz DATE 3-318" 4 841 D -5532 t1 19801`198? 3-31$" 4 8538 - 8863 'v 1980M 987 3-318" 4 8885 - $?50 t: 1980,x1987 3-318" 4 8?60 - 8?80 tm: 198011987 3-318" 4 8785 - 882'1 ~:_; 1980M 987 3-3A8" 4 8852 - 8882 C 1980119$? PBTD 8907' -' 7" LNR, 29#, N-80, .03?1 bpf, ID = 6.'184" 8949' .;~ „,. rD 8950' _ ~< °-°, DATE REV BY COMMENTS DATE REV BY COMMENTS OilUSll9 ORIGINAL COMPLETION 11~N5~06 RRDlTLH IBPPULLEDMIRPSET(1D12006) D9M 8106 TELITLH IBP SET 09129A08 RftDiPJC PULL 8 RESET IBP 091341D6 JCMiPAG PULL IBP ~ IBP FISH 10A01/06 RRDIPAG RESET BKR IBP 10M 0106 CJNITLH IBP FISH PRUDHOE BAY UNIT V'JELL NGI-13 PERMIT No: 178-0910 API No: 50-029-20347-00 SEC 1 , T11 N, R14E 2531.95 FEL 4999.09 FNL 8P 6~lorotion (141oako) II'~ = r V11911-E~tD= .....................:.............. GRAY ............................... ACTUATOR= .................. . A}{~SOIU . ... ... .... . ... .. .. ............. ...... KB:_E~ - . ..... . . . . . . d8~ .. ......... BF. EL2J = ....................................... ....................... . .............................. Kt~P = .................. .. . . ..................... Max.A,ngle..=....... ............ .. ............ . ~T...a~,7.-4100' Datum MD= 9188' DeturnND= 8800' SS ~ ~7" TBG-NPC, 26#, L-$0, .0383 bpf, ID = 6.276" ~--{ 2220' 13-318" CSG, 72#, N-80, ID =12.347" ~--~ 2709' Minimum ID = 4.843" X7620' 7" BAKER SHEAR©UT SUB 7" TBG-NPC. 29#. L-80..0371 bpf. ID = 6.1$4" ~~ 76 71' TOP OF 7" LNR ~-1 7725' 9-518" CSG, 47#, N-80, ID = 8.6$1" 80 75' PERFORATIdN SUMMARY REF LOG: BHCS ON 06/30179 ANGLE AT TOP PERF: 18 ~ 8410' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 4 8410 -8532 C 1980/1987 3-318" 4 8536 - 8663 C 198011987 3-318" 4 8665 - 8750 C 1980M 987 3-318" 4 8760 - 8780 C 1980M 987 3-3P8" 4 8785 - 8821 C 1980M 987 3-318" 4 6852 - 8862 C 1980M 987 '' PRE-RIC 2199' ~~7" OTIS RPB SSSV NIP, ID = 5.963" _3000' -i Jet Cuti•'~6#tuding -757d' Tul~inp Punthfor Gireul~tion 7596' 7" SEAL BORE E}(T 7602' 9-518" ~ 7" BAHER SAB-2 PFtR 7620' 7" BAt4ER SHEAROUT SUB 7611' ELMD TT LOGGED OSf24187 Plug and ~abandan original perForatons with 53 bbls et ~ 5.8 ppg cement firom PBTD t4 ~-rJ/$" X 7"° Bakef ~/~B-~ PKR 8830'S~M FISH: IBPBULLNOSE 8907' 2S' OF 4" PERF GUN PBTD 8907' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 8949' TD 8--~ DATE REV BY COMMENTS DATE REV BY COMMENTS oilUl~9 ORIGINAL CifMPLETION 11M 5106 RR~ITLH IBP PULLEDMIRP SET (1012006) 09M8N6 TELITLH IBP SET 09C19~6 RRDaPJC PULL & RESET IBP 09130106 JCMIPAG PULL IBP 8 IBP FISH 10101A76 RRDiPAG RESETBKRIBP 10M0106 CJN/TLH IBP FISH PRUDHOE BAY UNIT WELL: NGI-13 PERMIT No: 178-0910 API No: 50-029-20347-00 SEC 1, 711 N, R14E 2531.95 FEL 4999.D9 FNL BP E~gflorrlion ~Alrakr~ t~~~~ ~~ ___ . ._~ ~ .. ~,~ ~ 189' ~ , . ~ --~ } ---- ~~ ~ a. ;~ 2A'f0•~ t [ k 1~ ~ t ~ i, ~`~ ~. 8,i~ +~ . _ ~ r ~~ ~ I n r ~ ~ ..~ - _ ,_. t _ _.. .._,,,,_,. y..,.4 a~ °'~ ~ ~ .. '. _ _... p ~ - ~ .- i -- ~. ~3 QV• f ...W COMP ANY DEFAILS REFERENCE INFORMATI ON SURVEY PROGRAM B P Amoco Co-ordinate (N iE)Reference: Well Centre:N Gl-13, True North t h Fm Depth To Swvey/Plan Tool Plan:NGI-13A WPS(NGI-13/Plan NGI-13A) l'I ~ Vertical (T VD) Reference: 1%'GL+2%.SR KB 46.511 Iculation Meth od: Minimum Cunazure Section I VSI Rekrence: User Defined ( ' ILIXIN,U.IX1E) 4111 .(X1 91X11.65 Planned: NGI-UA WP S V34 MWD +IFR+MS Created By: Sperry Drilling Date: I~ IOi2007 Ertor Syste m: LSCWSA Measwed D epth Reference: 1% GL+2%.SR KB 46.50 Scan McOr Error Surfa od: Trav Cylinder North ce: Elliptical+Cazing Calc ulation Method: Minimwo Curv atwc WELL DEfAll.S tart rr 1 ~I MD, 4 . 6TVD Name +N/-S +F/-W Northiob Eaniug Latitude Longitude Slot Start Dir 4'r100':2430' MD 2429.95'TVD ----- , R° NGI-13 2049.34 310.32 5972%W.71 fi%7015.51 70"19'49.9%3N 14%"28'S8.774W 13 280 36° SECTION DETAILS __--;---L - \24° Sec MD Inc Azi TVD +Ni-S +E.-W DLeg TFace VSec Target 3000 -- End Dir :3119 62' 3085 TTVD --- ----- ( 2410.00 0.12 75.00 2409.96 2.36 5.57 0.00 0.00 4.89 -~ - ~ - . , . ~ ~ - - 2 2430.00 2.51 89.32 ~ X9.95 _4_ 2.37 6.03 12.00 15.00 5.33 . 3 3119.62 30.02 102.86 3085.70 -36.59 192.94 4.00 14.65 196.22 4 5896.00 30.02 102.86 5489.62 -345.72 1547.16 0.00 0.00 1585.27 ~ S 6259.35 15.50 104.55 5823.78 -378.32 1683.50 4.00 178.20 1725.45 - - ~ - -+- - -~- ~ 3500 6 7009.35 IS.SO 104.88 6546.50 -428.67 1877.50 0.00 0.00 1925.81 NGI-13A TO Rev 1 • ~ 7 7009.87 15.49 104.55 6547.00 -4'_8.71 1877.64 2.00 -180.00 1925.95 - ~ ~ ~ ~ ~ ~ ~ ~ - ~ ~ - - ---- • ~ - ~ 8 7502.17 15.49 104.55 7021.42 -461.74 2004.90 0.00 0.00 2057.38 '~ 9 8276.65 0.00 0.00 7786.50 -487.88 2105.61 2.00 180.00 2161.39 NGI-13ATIrev 1 10 SS 16.65 0.00 0.00 8026.50 -487.88 2105.61 0.00 0.00 2161.39 NGI-13AT2rev 1 11 9001 65 0 00 0 00 6511 50 88 -467 2105 61 0 00 0.00 2161.39 NGI-13AT3rcw 1 4000 . . . . . . . ' i _ -__- ___-__^ __ _-~ - ~` FORMATION TOP DETAILS --- ~ r _~ - _ . ~ ~ - I 4500 ~ - - _ - .-- - No. TVDPath MDPath Formation _ -- I - ?~ " 1 5546.50 5960.87 UGI '. - - - 2 6166.50 6615.01 WS2 00 ~ - ~ ~ 3 6356.50 6812.18 WSI _--_ - ~ L 4 0006.50 7071.61 CM3 5000 , S 7306.50 7794.37 CM2 g _._ i - _ ----- .--- -. :~ 6 745L50 7940.88 CMI '_ - -r--r- '--. __ _ ' ' -~ 7 7786.50 8276.65 THRZ -~T T_ __ _ 5500. , Start it 4"%1 00' :5896' MD S4 9.62' TVD 8 7976.50 8466.65 BHRZl1'PTR _ --~--~- - ~ , - " 9 8031.50 8521.65 LCU/TKNG ~ ~ - ~ ~ ~ 10 8026.50 8516.65 TSGR y - . .._T - . ~- '~ UGI ' ' I I 8076.50 8566.65 TSHA G -- - - - - ` 60 00\ d Dir 6259.35 M D, 582 78 TVD 12 8091.50 8581.65 TSHB - ---- z~ 13 8IOG.50 8596.65 TSHC - I4 8116.50 8606.65 TSAD > 6000 - --- ' ' ' IS 8156.50 8646.65 4258 a, ° Sta rt Dir 2";10 0 :700 35 MD, 6546.5 T VD Ib 8196.50 8686.65 TCGL 2 .. ... ~ _ - - ~ - - ---.- `t~. W S¢500°~ 35 - 17 8261.50 8751 65 BCGL ~ _T __ . _--__ En d Dir :700 9.87 , 65 47 TVD . 18 8311.50 8801.65 23SB ~ -~ ' WSI 19 8366.50 8856.65 22TS ~ ~ ' 20 8396.50 8886.65 21TS ~ ' NGI-13 ATORev I 21 844L50 8931.65 TZIB _- - ~ ` CMj000 22 8481.50 8971.65 TDF --- ', - N t-P3A T O 23 851 L50 9001.65 BSAD ~ ._ . __-_- _ S tan Dirt"! 100':7 02.1 TMD,7021A 2TVD 7000 +~ . ' -•-~~ - . ~_ . ~ __. 7s CMI o I - ,. , ~ ~. --- -~ - _ , ~ _. ~. - '~' --- _ "- ' ~ - __-_. ~ ~. ~ ~ -- -- ...-.-.--- ~ - - " _ - ~ _. BHRZTPTR TSGR - THR _. 000{ - ~--~~ End Dir : ~r1-13A T NGI-13A 8276. lrev~ 1 revl S' MD opol . 7786.5' TV y D .- - -- - -.__-. . -~-.:.. _ - _ 8000 _: -. _. CU~TKNG - - - - _ - . __ _. TSHC 425 TCGL B' TSH _ ..TSAD - - ' .. .. _..,.. - _ _ _ BCG>~ Total Dep p th : 90 1.65' MD, 851 1.5' TVD - ~- - TARGET DETAILS 2356 217 ~ Plan NGI- 3A _ ~ j ' ~_ . - +- -- - 22TS TL 4 NGI-13A T 3rev I ~ y . : Name TVD +NI-S +E;-W Northing Easting Shape - TDF BSA 00 NGI-13 A WP . .. . _.. _ - .~~_.. - -- --- NGI-13A TO RevI 6546.50 -428.67 1877.50 5972419.00 668903.00 Point ~ - - - ---'------- NGI-13A TO 6746.50 -398.7 1 1719.19 5972445.00 6%8744.00 Point NGi- 13 (NGI-13 ) - ~ ~ ~ - -`_-'-- `-'_-" -- - NGI-13A TIrev I 778650 -487.88 2105.61 5972365.50 689132.50 Point NGI-13ArevlGeopoly 7786.50 -487.88 2105.61 5972365.50 689132.50 Polygon NGI-13A T2rev I 8026.50 -487.88 2105.61 5972365.50 689132.50 Point 1000 2000 3000 4000 HALLIBURTON NGI-13A T3rev I 8511.50 -487.88 2105.61 5972365.50 689132.50 Point Vertical Section at 103.05° [IOOOk%in] Sperry Grilling Service • COMPANY DETAILS BP Amoco Calculation Method: Minvnum Curvanue Error System: ISCWSA Scan Method: Trav Cylinder North Ertor Surface: Elliptical + Cazing Warning Method: Rules Baud HALLIf~URTON Sperry Drilling Bervicee 259 REFERENCE INFORMATION SURVEY PROGRAM inate (Nr El Reference: Well Cenire:NGl-13. True North DepM Fm Depth To Survty/Plan Tool Plan:NGI-13A WPS( NGI-13lPlan NGl-13A) tical (TVD) Reference: 1%'GL+2N.5RKB 4650 ection IVSI Reference: User Defined (O.ININ,IfIN1E) 24111.1X1 91X11.65 Planned: NGI-13A WP S V34 MWD+IFR+MS Created By: Sperry Drilling Date: 1lIIU21NI7 aced Depth Reference: 1%'GL+2%.SRKB 46.5(1 Calculation Method: Minimum Curvature WELL DETAIL-S Name +W-S +E/-W Northing Fasting Latitude Longitude Slot NGI-l3 2(W9.34 31U.32 5972%W.71 6%7015.51 711"19'49.9%3N 14%"2%'S%.774W U - --~ _-- - '- - "-~ - j-y ~ TARGET DETAILS j 1 - - ~ .---. .. 1 ~~ - -- - Name TVD +Ni-S +Er-W Northing Fasting Shape - --~ - - ~ -- --- ~-- --- ~ - ~ ~ NGI-13A TO RevI 6546.50 -428.67 1877.50 5972419.00 688903.00 Cvcle (Radius: ISO) . NGl-13A TO 6746.50 -398.71 1719.19 5972445.00 688744.00 Cvcle(Radius:150) NGI-13A TIrev 1 7786.50 -487.88 2!05.61 5972365.50 689132.50 Point - _ _ _ _ NGI-13A rerl Geopoly 7786.50 -487.88 2105.61 5972365.50 689132.50 Polygon NGI-13A TIrev 1 8026.50 -487.88 2105.61 5972365.50 689132.50 Point --- - NGI-13A T3rev 1 8511.50 -487.88 2105.61 5972365.50 6 1 ...5 mm 1 ,C -- ri 0 r 0 0 rn -j FORMATION TOP DETAILS No. TVDPath MDPath Formation I 5546.SU 596Q87 UGI 2 6166.50 6615.01 WS2 3 6356.50 6812.18 WSI 4 6606.50 7071.61 CM3 S 7306.50 7794.37 CM2 6 7451.50 7940.88 CMI 7 778650 8276.65 THRZ 8 7976.50 8466.65 BHRZTPTR 9 8031.50 8521.65 LCU:TKNG 10 8026.50 8516.65 TSGR II 8076.50 8566.65 TSHA 12 8091.50 8581.65 TSHB 13 8106.50 8596.65 TSHC 14 8116.50 8606.65 TSAD 15 8156.50 8646.65 4256 16 8196.50 8686.65 TCGL 17 8261.50 8751.65 BCGL IS 8311.50 8801.65 2356 19 6366.50 8856.65 22TS 20 8396.50 8886.65 21TS 21 8441.50 8931.65 TZIB 22 8481.50 6971.65 TDF 23 8511.50 9001.65 BSAD ~ I .4000 SI8 .__._ SECTION DETAILS ,_ Sec MD Inc Azi TVD +N/-S +Ei-W DLeg TFace VSec Target _ 1 2410.00 0.12 75.00 2409.96 2.36 5.57 0.00 0.00 4.89 ' ~ ~ ~ ~ ~ - ~ -~ ~ - 2 2430.00 2.51 89.32 2429.95 2.37 6.03 12.00 15.00 5.33 -'--{"` 3 3119.62 30.02 102.86 3085.70 -36.59 192.94 4.00 14.65 196.22 ---- 4 5896.00 30.02 102.86 5489.62 -345.72 1547.16 0.00 0.00 1565.27 ~- - ~ S 6259.35 15.50 104.55 5823.78 -376.32 1683.50 4.00 17620 1725.45 - ., - -- 6 7009.35 15.50 104.55 6546.50 -428.67 1877.50 0.00 0.00 1925.81 NGI-13A TO Rev I 7 7009.87 IS 49 104.55 6547.00 -428.71 1877.64 2.00 -180.00 1925.95 8 7502.17 15.49 104.55 7021.42 -461.74 2004.90 0.00 0.00 2057.36 9 8276.65 0.00 0.00 7786.50 -487.88 2105.61 2.00 180.00 2161.39 NGI-13A TIrev! 10 8516.65 0.00 0.00 8026.50 -487.88 2105.61 0.00 0.00 2161.39 NGI-13A T2rn~ l 777 1036 I I 9001.65 0.00 0.00 851 1.50 -487.88 2105.61 0.00 0.00 2161.39 NGI-13A T3rev I West(-) East • Sperry-Sun BP Planning Report Company: BP Amoco Date: 2/6/2007 Time: 14:47;13 Page: l Field: Prudhoe Bay (various) Co-ordinate(NE) Reference: Wetl: NGI-13, True North Site: NGI` Vertical (TVD) Reference: 18'GL+2$.5RKB 46.5 `Well: NGI-13 Section (VS) Reference: User (O:OON,O:OOE,103.05Azi) Wellpath: Plan NGl-13A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: NGI-13A WP 5 Date Composed: 1/4/2007 Version: 35 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay (various) Map SysterrLiS State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumNAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea Level Geomagnetic Model: bggm2006 Site: NGI TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5970744.41 ft Latitude: 70 19 29.828 N From: Map Easting: 686756.30 ft Longitude: 148 29 7.834 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: NGI-13 Slot Name: 13 NGI-13 Well Position: +N/-S 2049.34 ft Northing: 5972800.71 ft Latitude: 70 19 49.983 N +E/-W 310.32 ft Easting : 687015.51 ft Longitude: 148 28 58.774 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 8516.65 8026.50 9.625 12.250 9 5/8" 9001.65 8511.50 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 5960.87 5546.50 UG1 0.00 0.00 6615.01 6166.50 WS2 0.00 0.00 6812.18 6356.50 WS1 0.00 0.00 7071.61 6606.50 CM3 0.00 0.00 7794.37 7306.50 CM2 0.00 0.00 7940.88 7451.50 CM1 0.00 0.00 8276.65 7786.50 THRZ 0.00 0.00 8466.65 7976.50 BHRZlTPTR 0.00 0.00 8521.65 8031.50 LCU/TKNG 0.00 0.00 8516.65 8026.50 TSGR 0.00 0.00 8566.65 8076.50 TSHA 0.00 0.00 8581.65 8091.50 TSHB 0.00 0.00 8596.65 8106.50 TSHC 0.00 0.00 8606.65 8116.50 TSAD 0.00 0.00 8646.65 8156.50 42S8 0.00 0.00 8686.65 8196.50 TCGL 0.00 0.00 8751.65 8261.50 BCGL 0.00 0.00 8801.65 8311.50 23SB 0.00 0.00 8856.65 8366.50 22TS 0.00 0.00 8886.65 8396.50 21 TS 0.00 0.00 8931.65 8441.50 TZ1B 0.00 0.00 8971.65 8481.50 TDF 0.00 0.00 9001.65 8511.50 BSAD 0.00 0.00 Targets Map Map <---- Latitude ----> <--- Longitude --- Name Description TVD +N/-$ +E/-W Northing Easting. .Deg 'Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft NGI-13A TO Rev 1 6546.50 -428.67 1877.50 5972419.00 688903.00 70 19 45.765 N 148 28 3.961 W -Plan hit target NGI-13A T1rev 1 7786.50 -487.88 2105.61 5972365.50 689132.50 70 19 45.182 N 148 27 57.302 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 2!6!2007 Time: 14:47:13 Yager 2 Field: Prudhoe Bay (various) - Co-ordinate(NE) Refereucec Well: NGI-13, True North Site: NGI Vertical (TVD) Reference: 18'GL+28.5RK6 46 .5 WeII: NGI-13 S ection (VS) Reference: User (O.OON,O.OOE, 103.05Azi) Wellpath: Plan NGI-13A S urvey Calculation Method: "Minimum Curvature Db: Oracle Targets Map MaP _---- Latitude ----~ ~--- Lo ngitude --- Name Description TV D +N/-S +E/-W Northi ng Easting`'` Deg. Min Sec Deg Min Sec Dip. Dia ft ft ft ft ft -Plan hit target NGI-13A rev! Geopoly 7786. 50 -487 .88 2 105. 61 5972365. 50 689 132.50 70 19 45.182 N 148 27 57.302 W -Polygon 1 7786. 50 -335 .49 1 911. 84 5972513. 00 688935.00 70 19 46.681 N 148 28 2.958 W -Polygon 2 7786. 50 -732 .99 2 005. 96 5972118. 00 689039.00 70 19 42.772 N 148 28 0.213 W -Polygon 3 7786. 50 -687 .47 2 427. 25 5972174. 00 689459.00 70 19 43.218 N 148 27 47.913 W -Polygon 4 7786. 50 -265 .34 2 307. 73 5972593. 00 689329.00 70 19 47.370 N 148 27 51.399 W -Plan hit target NGI-13A T2rev 1 8026. 50 -487 .88 2 105. 61 5972365. 50 689 132.50 70 19 45.182 N 148 27 57.302 W -Plan hit target NGI-13A T3rev 1 8511. 50 -487 .88 2 105. 61 5972365. 50 689 132.50 70 19 45.182 N 148 27 57.302 W -Plan hit target Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft ..deg deg ft ft ft deg/100ftdeg/100ftdegN00ft deg 2410.00 0.12 75.00 2409.96 2.36 5 .57 0.00 0.00 0.00 0.00 2430.00 2.51 89.32 2429.95 2.37 6 .03 12.00 11.98 71.61 15.00 3119.62 30.02 102.86 3085.70 -36.59 192 .94 4.00 3.99 1.96 14.65 5896.00 30.02 102.86 5489.62 -345.72 1547 .16 0.00 0.00 0.00 0.00 6259.35 15.50 104.55 5823.78 -378.32 1683 .50 4.00 -4.00 0.47 178.20 7009.35 15.50 104.55 6546.50 -428.67 1877 .50 0.00 0.00 0.00 0.00 NGI -13A TO Rev 1 7009.87 15.49 104.55 6547.00 -428.71 1877 .64 2.00 -1.99 0.00 -180.00 7502.17 15.49 104.55 7021.42 -461.74 2004 .90 0.00 0.00 0.00 0.00 8276.65 0.00 0.00 7786.50 -487.88 2105 .61 2.00 -2.00 0.00 180.00 NGI -13AT1rev1 8516.65 0.00 0.00 8026.50 -487.88 2105 .61 0.00 0.00 0.00 0.00 NGI -13A T2rev 1 9001.65 0.00 0.00 8511.50 -487.88 2105 .61 0.00 0.00 0.00 0.00 NGI -13A T3rev 1 Survey MD Inc! Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg ft ft ft ft fY deg/100ft ft ft' 2410.00 0.12 75.00 2409.96 2363.46 4. 89 2.36 5.57 0.00 5972803.21 687021 .02 Start Dir 1 2430.00 2.51 89.32 2429.95 2383.45 5. 33 2.37 6.03 12.00 5972803.23 687021 .47 Start Dir 4 /. 2500.00 5.27 97.05 2499.78 2453.28 10 .02 2.00 10.75 4.00 5972802.97 687026 .20 MWD+IFR 2600.00 9.25 100.06 2598.96 2552.46 22 .62 0.03 23.22 4.00 5972801.32 687038 .72 MWD+IFR 2700.00 13.24 101.26 2697.02 2650.52 42 .10 -3.61 42.38 4.00 5972798.16 687057 .97 MWD+IFR 2800.00 17.24 101.91 2793.48 2746.98 68. 38 -8.91 68.13 4.00 5972793.50 687083 .83 MWD+IFR 2900.00 21.24 102.32 2887.88 2841.38 101 .32 -15.84 100.34 4.00 5972787.38 687116 .20 MWD+IFR 3000.00 25.24 102.61 2979.75 2933.25 140 .77 -24.36 138.85 4.00 5972779.82 687154 .92 MWD+IFR 3100.00 29.24 102.82 3068.64 3022.14 186 .52 -34.44 183.49 4.00 5972770.86 687199 .79 MWD+IFR 3119.62 30.02 102.86 3085.70 3039.20 196 .22 -36.59 192.94 4.00 5972768.94 687209 .29 End Dir : 1 3200.00 30.02 102.86 3155.29 3108.79 236 .44 -45.54 232.15 0.00 5972760.97 687248 .71 MWD+IFR 3300.00 30.02 102.86 3241.88 3195.38 286 .47 -56.68 280.93 0.00 5972751.06 687297 .74 MWD+IFR 3400.00 30.02 102.86 3328.46 3281.96 336 .50 -67.81 329.70 0.00 5972741.14 687346 .78 MWl}+IFR 3500.00 30.02 102.86 3415.05 3368.55 386 .53 -78.95 378.48 0:00 5972731.23 687395 .82 MWD+IFR 3600.00 30.02 102.86 3501.63 3455.13 436 .56 -90.08 427.26 0.00 5972721.31 687444 .85 MWD+IFR 3700.00 30.02 102.86 3588.22 3541.72 486 .59 -101.21 476.03 0.00 5972711.40 687493 .89 MWD+IFR 3800.00 30.02 102.86 3674.80 3628.30 536 .62 -112.35 524.81 0.00 5972701.49 687542 .92 MWD+IFR 3900.00 30.02 102.86 3761.39 3714.89 586 .65 -123.48 573.58 0.00 5972691.57 687591 .96 MWD+IFR 4000.00 30.02 102.86 3847.97 3801.47 636 .68 -134.62 622.36 0.00 5972681.66 687640 .99 MWD+IFR 4100.00 30.02 102.86 3934.56 3888.06 686 .72 -145.75 671.14 0.00 5972671.75 687690 .03 MWD+IFR 4200.00 30.02 102.86 4021.14 3974.64 736 .75 -156.88 719.91 0.00 5972661.83 687739 .07 MWD+IFR 4300.00 30.02 102.86 4107.72 4061.22 786 .78 -168.02 768.69 0.00 5972651.92 687788 .10 MWD+IFR 4400.00 30.02 102.86 4194.31 4147.81 836 .81 -179.15 817.47 0.00 5972642.00 687837 .14 MWD+IFR 4500.00 30.02 102.86 4280.89 4234.39 886 .84 -190.29 866.24 0.00 5972632.09 687886 .17 MWD+IFR 4600.00 30.02 102.86 4367.48 4320.98 936 .87 -201.42 915.02 0.00 5972622.18 687935 .21 MWD+IFR 4700.00 30.02 102.86 4454.06 4407.56 986 .90 -212.55 963.80 0.00 5972612.26 687984.25 MWD+IFR Went Sperry-Sun BP Planning Report Company: BP Amoco Date: 2/6/2007 Time: 14:47:13 Page: 3 Field: Prudhoe Bay (various) C o-ordinate( NE) Reference: WeQ` NGI-13, True North Site: NGI V ertica l (TVD) Reference: ' 18'GL+28.5R K6 46 .5 We1L• NG I-13 Section (VS) Reference: User (O.OON,O:OOE, 103.05Az i) WellQath: PIanNGI-13A S urvey Calculation Me thod: Minimum Curvature Db: Oracle Survey MD Inci Azim TVD Sys TVD VS N/S E/W DLS MapN YIapE Tool/Co ft deg deg _ ft ft ft ft ft deg/100ft ft ft 4800. 00 30. 02 102. 86 4540. 65 4494. 15 1036. 93 -223. 69 1012. 57 0.00 5972602. 35 688033. 28 MWD+IFR 4900. 00 30. 02 102. 86 4627. 23 4580. 73 1086. 96 -234. 82 1061. 35 0.00 5972592. 43 688082. 32 MWD+IFR 5000. 00 30. 02 102. 86 4713. 82 4667. 32 1136. 99 -245. 96 1110. 13 0.00 5972582. 52 688131. 35 MWD+IFR 5100. 00 30. 02 102. 86 4800. 40 4753. 90 1187. 02 -257. 09 1158. 90 0.00 5972572. 61 688180. 39 MWD+IFR 5200. 00 30. 02 102. 86 4886. 99 4840. 49 1237. 05 -268. 22 1207. 68 0.00 5972562. 69 688229. 43 MWD+IFR 5300. 00 30 .02 102. 86 4973. 57 4927. 07 1287. 08 -279. 36 1256. 45 0.00 5972552. 78 688278. 46 MWD+IFR 5400. 00 30 .02 102. 86 5060. 15 5013. 65 1337 .12 -290. 49 1305. 23 0.00 5972542. 86 688327. 50 MVVI}~IFR 5500. 00 30 .02 102. 86 5146. 74 5100. 24 1387 .15 -301 .63 1354. 01 0.00 5972532. 95 688376. 53 MWD+IFR 5600. 00 30 .02 102. 86 5233. 32 5186. 82 1437 .18 -312 .76 1402. 78 0.00 5972523. 04 688425. 57 MWD+IFR 5700. 00 30 .02 102. 86 5319. 91 5273. 41 1487 .21 -323 .89 1451. 56 0.00 5972513. 12 688474. 60 MWD+IFR 5800. 00 30 .02 102. 86 5406. 49 5359. 99 1537 .24 -335 .03 1500. 34 0.00 5972503. 21 688523. 64 MWD+IFR 5896. 00 30 .02 102. 86 5489. 62 5443. 12 1585. 27 -345. 72 1547. 16 0.00 5972493. 69 688570. 72 Start Dir 4 / 5900. 00 29 .86 102. 87 5493. 08 5446. 58 1587. 26 -346. 16 1549. 11 4.00 5972493. 30 688572. 67 MWD+IFR 5960. 87 27 .43 103. 04 5546. 50 5500. 00 1616 .44 -352 .70 1577. 54 4.00 5972487. 47 688601. 26 UG1 6000. 00 25 .86 103. 16 5581. 47 5534. 97 1633 .99 -356 .67 1594. 63 4.00 5972483. 92 688618. 44 MWD+IFR 6100. 00 21 .87 103. 55 5672. 90 5626. 40 1674 .44 -366 .00 1633. 99 4.00 5972475. 57 688658. 02 MWD+IFR 6200. 00 17 .87 104. 10 5766. 93 5720. 43 1708 .41 -374 .11 1666. 99 4.00 5972468. 30 688691. 21 MWD+IFR 6259. 35 15 .50 104. 55 5823. 78 5777. 28 1725 .45 -378 .32 1683. 50 4.00 5972464. 50 688707. 82 End Dir 6300 .00 15 .50 104 .55 5862. 95 5816. 45 1736 .31 -381 .05 1694. 02 0.00 5972462. 04 688718. 40 MWD+IFR 6400 .00 15 .50 104 .55 5959. 31 5912. 81 1763 .02 -387 .76 1719. 88 0.00 5972455. 97 688744. 42 MWD+IFR 6500 .00 15 .50 104 .55 6055. 68 6009. 18 1789 .74 -394 .47 1745. 75 0.00 5972449. 90 688770. 45 MWD+IFR 6600 .00 15 .50 104 .55 6152. 04 6105. 54 1816 .45 -401 .19 1771. 62 0.00 5972443. 84 688796. 47 MWD+IFR 6615 .01 15 .50 104 .55 6166. 50 6120. 00 1820 .46 -402 .20 1775. 50 0.00 5972442. 92 688800. 38 WS2 6700 .00 15 .50 104 .55 6248. 40 6201. 90 1843 .17 -407 .90 1797. 48 0.00 5972437. 77 688822. 49 MWD+IFR 6800 .00 15 .50 104 .55 6344. 77 6298. 27 1869 .88 -414 .62 1823. 35 0.00 5972431. 70 688848. 52 MWD+IFR 6812 .18 15 .50 104 .55 6356. 50 6310. 00 1873 .13 -415 .43 1826. 50 0.00 5972430. 96 688851. 69 WS1 6900 .00 15 .50 104 .55 6441. 13 6394. 63 1896 .60 -421 .33 1849. 22 0.00 5972425. 64 688874. 54 MWD+IFR 7000 .00 15 .50 104 .55 6537. 49 6490. 99 1923 .31 -428 .04 1875. 08 0.00 5972419 .57 688900. 57 MWD+IFR 7009 .35 15 .50 104 .55 6546. 50 6500. 00 1925 .81 -428 .67 1877. 50 0.00 5972419 .00 688903. 00 NGI-13A T 7009 .87 15 .49 104 .55 6547. 00 6500. 50 1925 .95 -428 .71 1877. 64 1.98 5972418. 97 688903. 14 End Dir 7071 .61 15 .49 104 .55 6606. 50 6560. 00 1942 .43 -432 .85 1893. 60 0.00 5972415. 23 688919. 19 CPA3 7100 .00 15 .49 104 .55 6633. 86 6587. 36 1950 .01 -434 .75 1900. 94 0.00 5972413. 51 688926. 58 MWD+IFR 7200 .00 15 .49 104 .55 6730. 23 6683. 73 1976 .71 -441 .46 1926. 79 0.00 5972407. 44 688952. 58 MWD+IFR 7300 .00 15 .49 104 .55 6826. 59 6780. 09 2003 .40 -448 .17 1952. 64 0.00 5972401. 38 688978. 59 MWD+IFR 7400 .00 15 .49 104 .55 6922. 96 6876. 46 2030 .10 -454 .88 1978. 49 0.00 5972395. 32 689004. 60 MWD+IFR 7500 .00 15 .49 104 .55 7019. 33 6972. 83 2056 .80 -461 .59 2004. 33 0.00 5972389 .25 689030. 61 MWD+IFR 7502 .17 15 .49 104 .55 7021. 42 6974. 92 2057 .38 -461 .74 2004. 90 0.00 5972389 .12 689031. 17 Start Dir 2 / 7600 .00 13 .53 104 .55 7116. 13 7069. 63 2081 .88 -467 .90 2028. 62 2.00 5972383 .56 689055. 04 MWD+IFR 7700 .00 11 .53 104 .55 7213. 74 7167. 24 2103 .57 -473 .35 2049. 63 2.00 5972378 .63 689076. 17 MWD+IFR 7794 .37 9 .65 104 .55 7306. 50 7260. 00 2120 .91 -477 .71 2066. 41 2.00 5972374 .70 689093. 06 CM2 7800 .00 9 .53 104 .55 7312. 05 7265. 55 2121 .85 -477 .94 2067. 32 2.00 5972374 .48 689093. 97 MWD+IFR 7900 .00 7 .53 104 .55 7410. 94 7364. 44 2136 .68 -481 .67 2081. 68 2.00 5972371 .11 689108. 42 MWD+IFR 7940 .88 6 .72 104 .55 7451. 50 7405. 00 2141 .75 -482 .94 2086. 59 2.00 5972369 .96 689113. 36 CM1 8000 .00 5 .53 104 .55 7510. 28 7463. 78 2148 .05 -484 .53 2092. 69 2.00 5972368 .53 689119. 50 MWD+IFR 8100 .00 3 .53 104 .55 7609. 96 7563 .46 2155 .95 -486 .51 2100. 34 2.00 5972366 .74 689127. 20 MWD+IFR 8200 .00 1 .53 104 .55 7709. 86 7663 .36 2160 .37 -487 .62 2104. 62 2.00 5972365 .73 689131. 50 MWD+IFR 8276 .65 0 .00 0 .00 7786. 50 7740. 00 2161 .39 -487 .88 2105. 61 2.00 5972365 .50 689132. 50 NGI-13A 8300 .00 0 .00 0 .00 7809. 85 7763. 35 2161 .39 -487 .88 2105. 61 0.00 5972365 .50 689132. 50 MWD+IFR 8400 .00 0 .00 0 .00 7909. 85 7863. 35 2161 .39 -487 .88 2105. 61 0.00 5972365 .50 689132. 50 MWD+IFR 8466 .65 0 .00 0 .00 7976. 50 7930 .00 2161 .39 -487 .88 2105. 61 0.00 5972365 ,50 689132. 50 BHRZlfPT 8500 .00 0 .00 0 .00 8009. 85 7963 .35 2161 .39 -487 .88 2105. 61 0,00 5972365 .50 689132. 50 MWD+IFR 8516 .65 0 .00 0 .00 8026. 50 7980 .00 2161 .39 -487 .88 2105. 61 0,00 5972365 .50 689132. 50 NGI-13A 8521 .65 0 .00 0 .00 8031. 50 7985 .00 2161 .39 -487 .88 2105. 61 0.00 5972365 .50 689132. 50 LCU/TKNG nent S 5 Rev S S ev 1 S S S ev 1 • Sperry-Sun BP Planning Report Company: BP ArrtOCO Date: 2/6/2007 Time: .14:47:13 Page: 4 Field:.' Prudhoe Bay(various) Co-ordinate(NE) Reference: Well: NGt-13, True North Site: NGI Vertical (TyD) Reference: 18'GL+28.5RK6 46.5 Well: NGI-13 Section (VS) Reference: User (OAON,O.OOE,103.05Azi) Wellpeth: Plan NGI-13A Survey Calculation;Method: Minimum Curvature Db; OraGe Survey M1) Incl Azim TVD Sys TVD ft deg deg ft ft 8566. 65 0.00 0.00 8076. 50 8030. 00 8581. 65 0.00 0.00 8091. 50 8045. 00 8596. 65 0.00 0.00 8106. 50 8060. 00 8600. 00 0.00 0.00 8109. 85 8063. 35 8606. 65 0.00 0.00 8116. 50 8070. 00 8646. 65 0.00 0.00 8156. 50 8110. 00 8686. 65 0.00 0.00 8196. 50 8150. 00 8700. 00 0.00 0.00 8209. 85 8163. 35 8751. 65 0.00 0.00 8261. 50 8215. 00 8800. 00 0.00 0.00 8309. 85 8263. 35 8801. 65 0.00 0.00 8311. 50 8265. 00 8856. 65 0.00 0.00 8366. 50 8320. 00 8886. 65 0.00 0.00 8396. 50 8350. 00 8900. 00 0.00 0.00 8409. 85 8363. 35 8931. 65 0.00 0.00 8441. 50 8395. 00 8971. 65 0.00 0.00 8481. 50 8435. 00 9000. 00 0.00 0.00 8509. 85 8463. 35 9001. 65 0.00 0.00 8511. 50 8465. 00 VS N/S FJW DLS Mapiv ft ft ft deg/t00ft ft , 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 2161.39 -487.88 2105.61 0.00 5972365.50 MapE Tool/Ca ft 689132.50 TSHA 689132.50 TSHB 689132.50 TSHC 689132.50 MWD+IFR 689132.50 TSAD 689132.50 42S6 689132.50 TCGL 689132.50 MWD+IFR 689132.50 BCGL 689132.50 MWD+IFR 689132.50 23SB 689132.50 22TS 689132.50 21 TS 689132.50 MWD+IFR 689132.50 TZ1 B 689132.50 TDF 689132.50 MWD+IFR 689132.50 NGI-13A 1 Nam. N(:1-IS : wF.ll uL-1'nus -N'-ti ~t'-W N~IUhmg Fa+tioF LaWU1: INI°Xnuk %hn WYJS JIO i. SY7?%1X171 G']01351 ]U-1`/'dY `/%vN IiY?%'3%"IJ4W IY ANTI-COLLISION SEITWCS IntolPUlalion Medlod:MD Interval: 511.1111 Dejlt~Ran6e PtOU1: 24111.(X) To: yIXI I.GS Maximum Range: 1097.31 Reference: Plan: NGI-13A WP 5 l'()MI'ANY III:IN1ti tll'Amrwr~ ('akWutxl°M Wd'. Mmimmu ('unwun Inur sramm. uewsn tica°MdWxl. Imv ['YWNY. M14rM I~n~'r 9ml+u~. Ilhlntal' f'uu°X WammX McNuJ: kulX tlv+N ]I1kVrV YNIIIiRAxI Uaplh l~m Ihpth l~r Jmv ylPLw fool _JIU)XI `/1X11 l~3 1'Lmnd: N(il-ItA WP3 V?d MWU~IPk~M1Iti WI~1.YA111 ULIAIL% 160 Al ~ From Colour To MD YW Nlil-ISA 150 l~G~ >A 2410 3250 rmmwcl~alm Na-13 '°°°MU: Yalu«, ~G> 33 3250 3$00 0 3500 3750 w1. Lw m: 1%GL 2XSN1U1 wyw 37so 4000 - - aooo 4250 ~~,,,° (moo ~o %m~ naX~ N's la.w rNl'm IS'u 125 2 4250 4500 IIOn3 u,ln n,IXI a~sl 4500 4750 4750 5000 5000 5250 5250 5500 "~i~11° S SOO 5750 --- S7SO 6000 - LIJII ILI-UII. FW,~~N Nixk ~ LI-UI 11`Lmal1'I LIJIIAR AtiUr~r NuL - 1.1-U?o.l-.I?I nlan'r Nall - Nfi1JIJ INIiHIJI FId 114J / 6000 62SO N NfiH131Nti1Jl<I. xWM1ir Wak ,O 0 6250 6500 - r~xa{m i?~aii uii M wa NGI-11 IN(i1-111 Mayx kiNL 7S . N(il-1_ IN`lil-1?), FlaNir Nuk - N(il-II IN(il-1 ~l NIlIJ<Nllk\ - N(il-14ltJlil-IJI. 111aN~1 Nlil 1'W N(il-IrA ~ - Nxil-IAA W'Y3 0 ~ ~` ' 5 z ~ I 0 = _ _ ~ ~ ~ 0 \ 270 90 / i 25 0 i 75 240 120 100 Pre Plans Rem oved . See AC Scan for Plans Parents Profile @ No Errors 125 1Ll'1ll>N UtirA1L,4 2I tiix x1IX hr' ANN SO 1 ?d111 LY1 U.I. ]5.1X1 IVU ~N'-ti :JIY)`/( :~( ~E'-W Dlag fF,xc Vtix 'IeNY.I 5.37 U.W VW JAY ISO 24301X1 2.31 %`/l: l 31IY.fi2 3U.U'_ IU'_.N6 4 3XYfiW 300 ' IU' lifi ?dr/.Y3 X17 311%37U -i65'1 34%1 fi ^ 143]? (.UY 1?.W IS.W StY IY'_Y4 O.W 14.fi3 1`N~" ISd7 l4 U W O W IS%3' J _ _ 3 fi23Y.33 13.3U IW.53 _ - 3%21.7% -Y7%.3'_ . . . _ IG%350 4.W I7S,'.A I7?343 I6O fi 7W035 13511 IW.33 7 701F1%7 13.4Y IW53 fi54fi 511 >2%.fi7 fiiJ7lXl -0?%]I I%]7.311 O.W O.W IY'_S FI Ntil~l lA IU NXVI 1%77 to ?.W -I XUW IY23.Y3 Ig O % JSU_.IJ IS iY IIW.33 JU_I.d? -t(.1 ]J '_(NW!NI IIIXI O.W _'US7 iS ^ %~Jfi,n: IIIXI II INI 5 U IU 131! 1 fNI UNNI TIF(~311 -ITJ.Y.~ YU~I SU 1%]Sn _Illi RI ~ W I%11.1X1 ?I(1 lY NIiI-I lA iln~' 1 ' IU>fil U(xl U fNI .IGI JY Nlil ISA f' 1 Travelling Cylinder Azimuth (TFO+AZI) [d . ,, , , 11 'NNII,RS UNNI UIXI eg] vs Centre to Centre Separation [SOWin] - %<I1511 -ITJ,Y% _ , - _rv1 '_Ilu fit 111x1 U.W 'If I.IY Nfil-IiA'flrnl • • Sperry-Sun Anticollision Report Company: BP AmoCO Date: 2/6/2007 Time:. 14:51;48 Page: 1 Fielde Prudhoe Bay {various) Reference Site: NGI Co-ordinat e(NE) Re ference:` Well: NGI-13, True North ,Reference Well: 'NGI-13 Vertical (T VD) Refe rence: 18'GL+28 .5RK6 46:5 .Reference WellpatlPJarr NGl-13A Ub: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - TBefe~ecB[GHT sf§fihCipekRiarfifllHlANNED PROGRAM Interpolation Meth odMD Interval: 50.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 2 410.00 to 9001.65 ft Scan Method: Trav Cylinder North Maximum Radius:1 097.31 ft Error Surface : Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/27/2006 Validated: No Version: 3 Planned From To Survey Toolcode Tool N ame ft ft 98.50 2410.00 1 : Camera based gyro multisho (98.50-92461~`(BfJ-MS Camera based gyro multishot 2410.00 9001.65 Planned: NGI-13A WP 5 V36 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft ` in in 8516.65 8026.50 9.625 12.250 9 5/8" 9001.65 8511.50 7.000 8.500 7" Summary <--------- ----------- Offset Wellpath -----.-- -------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distanc e Area Deviation Warning ft ft ft _ ft ft Lis DS 01 L1-01 L1-01 V3 5840.73 6300.00 186.75 110.87 75.88 Pass: Major Risk Lis DS 01 L1-01 Plan#119 L1-01A VO Pla 5840.73 6300.00 186.75 110.87 75.88 Pass: Major Risk Lis DS 01 L1-02 L1-02 V1 6843.73 6750.00 884.96 115.27 769.69 Pass: Major Risk NGI NGI-04 NGI-04 V2 5410.93 5500.00 231.85 95.97 135.88 Pass: Major Risk NGI NGI-05 NGI-05 V1 5205.35 5300.00 406.73 135.16 271.56 Pass: Major Risk NGI NGI-09 NGI-09 V2 3161.21 3150.00 439.29 91.63 347.66 Pass: Major Risk NGI NGI-10 NGI-10 V1 3112.98 3100.00 319.91 75.30 244.60 Pass: Major Risk NGI NGI-11 NGI-11 V1 2996.68 3000.00 211.35 87.72 123.63 Pass: Major Risk NGI NGI-12 NGI-12 V1 2424.87 2450.00 317.41 67.97 249.44 Pass: Major Risk NGI NGI-13 NGI-13 V1 2448.46 2450.00 1.19 1.10 0.09 Pass: NOERRORS NGI NGI-14 NGI-14 V1 2446.99 2450.00 126.99 74.75 52.25 Pass: Major Risk Site: Lis DS 01 Well: L1-01 Rule Assigned: Major Risk Wellpath: L1-01 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TUD Ref. Offset TFO+AZI TFO-H S Casing/118istanc eArea Deviation :.Warning ft ff ft ft ft ft deg deg in ft ft ft 5122.92 4820.25 5050.00 4750.15 12.48 11.52 21.21 278.35 9.625 1067.80 100.63 967.17 Pass 5152.51 4845.86 5100.00 4781.17 12.56 11.59 20.93 278.07 9.625 1027.83 100.96 926.87 Pass 5182.09 4871.48 5150.00 4812.28 12.63 11.63 20.61 277.76 9.625 987.90 101.22 886.68 Pass 5211.84 4897.24 5200.00 4843.61 12.71 11.62 20.26 277.40 9.625 948.15 101.37 846.79 Pass 5241.75 4923.13 5250.00 4875.05 12.79 11.67 19.88 277.02 9.625 908.56 101.60 806.96 Pass 5271.60 4948.98 5300.00 4906.54 12.87 11.78 19.45 276.60 9.625 869.00 101.97 767.03 Pass 5301.32 4974.72 5350.00 4938.04 12.94 11.95 18.97 276.11 9.625 829.45 102.45 727.00 Pass 5330.96 5000.38 5400.00 4969.51 13.02 12.16 18.43 275.57 9.625 789.90 102.98 686.93 Pass 5360.54 5025.99 5450.00 5001.00 13.10 12.33 17.82 274.96 9.625 750.43 103.44 646.99 Pass 5389.99 5051.49 5500.00 5032.46 13.18 12.54 17.13 274.28 9.625 710.98 103.95 607.04 Pass 5419.22 5076.80 5550.00 5063.85 13.26 12.77 16.35 273.49 9.625 671.54 104.51 567.03 Pass 5448.31 5101.99 5600.00 5095.22 13.34 12.97 15.44 272.59 9.625 632.20 104.96 527.23 Pass 5477.40 5127.17 5650.00 5126.65 13.42 13.08 14.41 271.55 9.625 593.07 105.25 487.82 Pass 5506.44 5152.31 5700.00 5158.09 13.50 13.27 13.21 270.36 9.625 554.15 105.70 448.45 Pass 5535.29 5177.30 5750.00 5189.48 13.58 13.53 11.82 268.96 9.625 515.45 106.29 409.16 Pass 5564.00 5202.15 5800.00 5220.95 13.66 13.73 10.15 267.29 9.625 477.16 106.74 370.42 Pass 5592.55 5226.87 5850.00 5252.41 13.73 13.98 8.15 265.29 9.625 439.33 107.29 332.04 Pass 5620.82 5251.35 5900.00 5283.73 13.81 14.27 5.75 262.90 9.625 402.03 107.97 294.05 Pass 5648.62 5275.42 5950.00 5314.78 13.89 14.57 2.82 259.96 9.625 365.39 108.67 256.72 Pass 5676.11 5299.22 6000.00 5345.70 13.97 14.80 359.20 256.34 9.625 329.86 109.22 220.64 Pass Alaska Department of Natural Resources Land Administration System Page 1 of 2 • • ~ ~~Or. .,l _~ i'~i :!'-~a ?~iC`(:: ~ ~ _ i.3'i r'~t'"`. ~V1 .. ~.I~r~JcJ~a~C.h StC~tQ.. f.iaU~~~~7 ~~ii .TY~i9rID~ ..................... ..... Alaska DNR Caste summary File Type ADL File Number: ?8302 i~ prin. table .C..a..se Fife. Sum .m...ary See Township, Range, Section and Acreage? C Yes ~ No New Search LAS MenEa I Case Abstract ~ Case Detail ~ Lana Abstract 1~[lc: ADL 28302 '''= Search for Status Plat Updates AS Of U~i2 i'2CIO C~stofner: OOO107~77 BP E}~1'LOitATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LANDMANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~;~. OIL & GAS LLASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Stata,rs: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Once of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: C~~ NORTH SLOPE Last Transaction< AA-NRB ASSIGNMENT APPROVED 11~~ridian: U 7-mriz~htt~: OI1N Run~c~: 01=~E ,S'c~ctiurt: O1 .Sccti~»r;1c~r~es: 6=}0 Search Plats <llc~ri~liun: U 7~utirnt~hit~.~ 01 I N Ran,~Tc~: 0l 4L S'<°ctinir: 02 .~'~°ctrcm .=1c~re.c: 6=}0 alrruGun: U Tuticnshlt>: Ol 1N Run,~re: OI~E ,S~c'~11Un: 11 .~'rrtinrr ~lcf~c's: 6=10 Llc~ridiun: [, Tn~ti~ns{~iE!.~ 01 1 V' Runge: 01-1E .Sc c7ron: 1 ? ~Sec~cinrr ,lcres: 6=10 Leal Description OS-28-196 * * *SALE NOTICE LEGAL DESCRIPTION* * ~` C74-123 11N 1=~E UM1, 2, 11,12 2560.00 U- 3- 7 lend ~ Case Surt~rnar Last updated on 08/23/2007. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=283 02&... 8/23/2007 • • TRANSMITTAL LETTER CHECKLIST WELL NAME P~~ /yC>f' ~3~ PTD# O~~ ~I~~~ Development ~/ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -^) from records, data and logs acquired for well SPACING The permit is approved subject to full. compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception.. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (,name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev; 7/13/2007 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 _Well Name: PRUDHOE BAY UNIT NGI-13A Program SER Well bore seg ^ PTD#:2071140 Company BP EXPLORATION (ALAS INC Initial Class/Type SER / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permitfeeattached___________________________-.-____ _____. --- NA__ __________. 2 Lease number appropriate-_----_____ _- _--.-______ Yes_ __-_-_-__ ______ 3 Uniquew~ll-name and number___________________________ ___________ Yes_ _--____-. 4 Well locatedin_a_defined-pool__ ________.,_-.__ ________ __________ Yes- ---_-- ___ 5 Well located proper distance from drilling unit boundary_ - Yes - - ---- - - - - - - - -- 6 Well locatedproperdistancefromotherwells____________________ ___ ______Yes_ _______--_---_-___-__________. 7 Sufficient acreage_available in-drilling unit _ _ - - _ _ _ . - _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 If-deviated, )s wellbore plat_inc_luded - - Yes - - 9 Operator only affected party - _ - Yes - - - 10 Operator has_appropriatebondinforce.._______-___________ __________ Yes. ____-_¢IanketBond#6194193--._-_________,-___--____,______-__-___-_.-,__-.- 11 Permit can be issued without conservation order - Yes - - Appr Date 12 Pe[mitcanbeissuedwithoutadministrative_approval_______________ __________Yes_ --__--___________-_----__-__-______--- ACS 8123/2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authprized by Injection Order # (put 10# in_ comments)_ (Fpr- Yes _ . - _ _ _ _ AIO.3 - _ _ - . - _'- - . - _ _ _ _ _ .. - .. - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells-withintl4_mile area of review identified(Fo[servicewellonly)_____ __________Yes_ _,__--__-___-________--__--________-_-_--__--__,-_---. - - - - - -- 16 Pre-produced injector; duration_ofpn-production Less than 3 months (For service well only) - - NA_ - - 17 Nonconven, gas conforms to AS31,05,030Q.1_.A),Q.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - _ _ _ _ _ _ _ . - - . - - Engineering 18 Conductor string.provided_______________________________ ________ _ NA__ --- - _--_-Con_ductor_set_inNGl-13(178-091).__________---. 19 Surfacecasingprotectsall_knownUSDWs_____________________ _____ ____ NA__ _--_--No aquifers, A1O4B,_conclusion3,--_______.____..-._- ---___ -__----..--.-....-- 20 CMT-vol- adequate_to circulate-on conductor & surf_csg - - _ - - _ _ _ _ _ _ _ _ _ - - - - - _ _ _N_A_ _ _ _ _ _ _ - Surface casing set in NGI-1.3- - - - - - - - - - - - - - - - - - 21 CMT-v_ol_ adeguate_to tie-in long string to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ - - _ - - TOC intended_above-Cretaceous. _ - _ _ _ _ _ _ _ _ _ _ _ - - - - 22 C_MT_willcoyer_allknown_productivehorizons____________________ __________ No__ ______Slotted.linercompletionplanned,____----___________-__-.--_-_________-_--,-_--- 23 Casing des~ns adequate for C, T, B &. permafrost - Yes - - - 24 Adequate tan_kage_or reserve pit - _ _ - .. - - - _ - . Yes Rig is_equipped with steel-pits. - No resen!e_pitplanned. All waste to-approved disposal well(s).- _ _ - - - 25 If_a_re-drill,has-a-10-403foraband4nment been aP-proved______---._ -------_- Yes- __..-_307.2.68___-__..__--_-______._--_-______________________ ___ 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - -Yes _ _ _ _ .Proximity analysis performed: Traveling cylinder path calculated, Nearest segment is P&Aportign of NGI-13.. - - 27 Ifdiverterrequired,does)tmeetregulations____________________ __________ NA-_ ______BOPStackwillalready_be_inplace.__-__-.__-__- Appr Date 28 _D_rilling fluid_ program schematic & equip listadequate_ - - .. _ _ . - Yes - Maximum expected formation pressure 7.9_ BMW in zone.- Planned MW $.$ ppg and up to_9.8 ppg_in HRZ._ TEM 8!3112007 29 8OPEs,_dothe meetregulation_.- y Yes_ _____________________________________________--__---_---____,-_---_.-- ~ ~~n/1 ~~~ 30 BOPE-press rating appropriate; test to-(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ MASP calculated at 2590pSi, 4000_psi-BQP testplanned, _ _ _ _ _ - - - - . - - .. - _ . - _ _ - _ _ _ _ _ _ _ - _ _ ~ r~,~li. \ 31 Choke. manifoldcomp_Iiesw/APIRP-53GMay84)_____ ____________ ___ Yes- ---_________-_--_- 32 Work will occur without operation shutdown_____________________ ______ ___ Yes- ______________-----_- -__________--__.-_____ ______-__-._--_--_--__ --- 33 Is presence of H2S gas probable- .... - - No, . - _ H2S is not_reported ai NGI however is likely in_the gas. Rig_i& equ~ped w~h sensors.and alarms, 34 Mechanical_condition of wells within AOR verified (.For service wel_I onty) Yes - Only well. in AOR is PBAed portion of NGI.13. -All_other wells beyond 1!4 mile._ - - - - - .. . Geology 35 Pe[mitcanbeissuedw/ohydrogen_sulfidemeasures_____ _________ __---._-__N_o_ ____-.---.-___________-____-______- 36 Data_presentedonpotentialoverpressurezones__________________ __________ NA._ ____________-____-____ _______-__---_ Appr Date 37 Seism(c_analysisofshallowgas_zones_ - - _ - _ _ - NA - -- ACS 812312007 38 Seabed condition survey_(if Off-sho(e) - - - _ _ _ _ _ _ _ - _ _ - - - _ - - _ _ - NA - _ - _ _ _ _ _ _ _ , _ - - 39 Contact namelphone far weekly_progress reports [exploratory only] Yes - Kris-Honas 564-4338 _ - - _ _ Geologic Engineering Pu Commissioner: Date Com si Date: Commissioner Date pp D Jl ~, c~ / ~ Q~ r C Well History File APPENDIX Information of detailed nature that is not • pariiculariy germane to the Well Perrnilting .Process but is part of the history file. To improve the readability of the Well History file and. to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made to chronologically organize this category o1 information. s • ngi-13a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 06 15:09:50 2008 Reel Header Service name .............LISTPE Date . ...................08/06/06 Ori9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date . ...................08/06/06 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 • scientific Technical services scientific Technical services NGI-13A 500292034701 BP Exploraion Alaska Sperry Drilling Services 06-JUN-08 MWD RUN 1 MWD RUN 2 JOB NUMBER: w-0005193767 w-0005193767 LOGGING ENGINEER: C. CREGLOW A. MUNRO OPERATOR WITNESS: J. HABATHUR J. HABATHUR SURFACE LOCATION SECTION: 1 TOWNSHIP: 11N RANGE: 14E FNL: FSL: 489 FEL: FWL: 840 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 51.32 DERRICK FLOOR: GROUND LEVEL: 17.62 WELL CASING RECORD Page 1 MWD RUN 3 w-0005193767 0. OBI M. BURLEY 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: ngi-13a.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 2305.0 8.500 9.625 8496.0 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. THIS WELLBORE EXITS THE NGI-13 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 2305'MD/2305'TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED WITHOUT MWD TOOLS. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 5 JUNE 2008, QUOTING AUTHORIZATION FROM DOUG STONER (BP). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL NGI-13A WITH API# 50-029-20347-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9006'MD/8515'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 i ngi-13a.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2100.5 8957.5 ROP 2440.5 9006.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 1 2100.5 2 6397.0 3 8496.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6397.0 8496.0 9006.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ...., Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2100.5 9006 5553.25 13812 2100.5 9006 GR MWD API 13.69 401.07 81.9235 13715 2100.5 8957.5 ROP MWD FPH 0.03 926.26 140.378 13132 2440.5 9006 First Reading For Entire File..........2100.5 Last Reading For Entire File...........9006 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/06 Maximum Physical Record..65535 File Type . ..............LO Next File Name...........STSLIB.002 Page 3 ngi-13a.tapx Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... Version Number. ........1.0.0 Date of Generation....,..08/06/06 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 for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 2100.5 ROP 2440.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 6338.0 6397.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: Page 4 20-OCT-07 Insite 74.11 Memory 6397.0 2440.0 6397.0 12.6 33.3 TOOL NUMBER 103770 12.250 2305.0 Polymer 9.20 46.0 9.0 1500 .0 .000 .0 .000 99.0 .000 .0 .000 .0 ~ ~ ngi-13a.tapx 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 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2100.5 6397 4248.75 8594 2100.5 6397 GR MWDO10 API 13.69 126.49 69.4995 8476 2100.5 6338 ROP MWDO10 FPH 1.91 926.26 178.65 7914 2440.5 6397 First Reading For Entire File..........2100.5 Last Reading For Entire File...........6397 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSL26.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLIB.002 Comment Record FILE HEADER Page 5 ~ ~ ngi-13a.tapx FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6338.5 8437.0 ROP 6397.5 8496.0 LOG HEADER DATA DATE LOGGED: 24-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION; 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8496.0 TOP LOG INTERVAL (FT): 6397.0 BOTTOM LOG INTERVAL (FT): 8496.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ,2 MAXIMUM ANGLE: 33.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2305.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 50.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 124.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Di rection .................Down Page 6 a • ngi-13a.tapx 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 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FPH 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 6338.5 8496 7417.25 4316 6338.5 8496 GR MWD020 API 33.38 377,23 112.628 4198 6338.5 8437 ROP MWD020 FPH 0.03 151,47 78.6981 4198 6397.5 8496 First Reading For Entire File..........6338.5 Last Reading For Entire File.........,.8496 File Trailer Service name... .......STSLIB.003 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/06/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........5T5LIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/06/06 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8437.5 8957.5 ROP 8496.5 9006.0 LOG HEADER DATA Page 7 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ngi-13a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 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 (DEG F) 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 28-OCT-07 Insite 74.11 Memory 9006.0 8496.0 9006.0 .3 .8 TOOL NUMBER 242567 8.500 8496.0 Polymer 8.80 51.0 9.0 5200 6.0 .000 .0 .oo0 149.0 .000 .0 .000 .0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FPH 4 1 68 8 3 Page 8 ~ ~ ngi-13a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8437.5 9006 8721.75 1138 8437.5 9006 GR MwD030 API 16.28 401.07 59.2594 1041 8437.5 8957.5 ROP MWD030 FPH 1.29 381.1 97.2934 1020 8496.5 9006 First Reading For Entire File..........8437.5 Last Reading For Entire File...........9006 File Trailer Service name... .....,.STSL26.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.....,.08/06/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................08/06/06 Origin ...................sTs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/06/06 0ri9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 9