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179-050
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: Water Wash Conductor Surface Intermediate Production Liner 520 2670 4760 7020 Structural 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: 13b. Pools active after work: 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 DSR-3/14/23 RBDMS JSB 031423 Sundry Number Water Wash MGR17MAR2023 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 WGI-04 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 179-050 50-029-20386-00-00 ADL 0028302 9584 Conductor Surface Intermediate Production Liner 8596 78 2703 8614 1252 9550 20" 13-3/8" 9-5/8" 7" 8564 31 - 109 31 - 2733 29 - 8643 8332 - 9584 31 - 109 31 - 2733 29 - 7705 7417 - 8596 8060 520 2670 4760 7020 none 1530 4930 6870 8160 9034 - 9469 7" 26# x 7-5/8" 29.7# L-80 x NT-95 26 - 82468076 - 8487 Structural 7" Baker S-3 , 7" Baker SAB 7" CAMCO DB-6 8036 , 8115 / 7157, 7225 2181 / 2181 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 By Meredith Guhl at 8:32 am, Jan 27, 2023 323-050 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.26 15:38:36 -09'00' 1/30/23 X MGR02FEB23 10-404 DLB 02/02/2023GCW 02/03/23JLC 2/3/2023 02/03/2023Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.03 10:37:58 -09'00' RBDMS JSB 020323 Well Work Prognosis Well Name:WGI-04 API Number:50-029-20386-00 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:179-050 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: 3,640 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): WGI-04 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2014. 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 Well Work Prognosis MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC WGI-04 PRUDHOE BAY UNIT WGI-04 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 WGI-04 50-029-20386-00-00 179-050-0 G SPT 7331 1790500 1833 3584 3595 3606 3610 43 43 43 45 4YRTST P Brian Bixby 5/22/2022 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 WGI-04 Inspection Date: Tubing OA Packer Depth 175 2523 2458 2448IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220522154204 BBL Pumped:3.9 BBL Returned:3 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 11:26:56 -08'00' Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:179-050 6.API Number:50-029-20386-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028302 Property Designation (Lease Number):10. 8. PBU WGI-04 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Water Wash Op Shutdown GAS GSTOR WAG 5 SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9584 Effective Depth MD: L-80 / NT-95 / L- 80 11. 8/1/2021 Commission Representative: 15. Suspended Contact Name: Dave Bjork Contact Email: david.bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Sr. Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 7" MCX SSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8596 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8036, 8115, 8228, 2181 7157, 7225, 7325, 2181 Date: Liner 1252 7"8332 - 9584 7417 - 8596 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 31 - 2733 31 - 2733 14. Estimated Date for Commencing Operations: BOP Sketch 31 - 109 Structural 6870/8150 Proposal Summary 13. Well Class after proposed work: 7" Baker S3, 7" Baker SAB, 7" Baker SB-2 9034 - 9469 8076 - 8487 7- 5/8" 29.7# x 7" 26# x 7" 29 26 - 8083, 8085 - 8142, 8228 - Production 9550 8564 None 8060 31 - 109 520 13-3/8" 9-5/8" Contact Phone:564-4672 Date: 4760/5080 78 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2703 4930 Intermediate 8614 29 - 8643 29 - 7705 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 3550 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 9:25 am, Jul 22, 2021 321-365 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.22 09:05:54 -08'00' Bo York DLB07/22/2021 DSR-7/22/21 X 10-404 MGR23JUL21 dts 7/23/2021 JLC 7/23/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.26 12:57:06 -08'00' RBDMS HEW 7/26/2021 THE STATE OIALASKA 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 WGI-04 Permit to Drill Number: 179-050 Sundry Number: 319-541 Dear Mr. Brown: Alaska Oil and Gas Conservati®n Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.7433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such 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, VJerem rice Chair DATED thisday of December, 2019. 3BDMSJ-�DEC 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED Nov 2 9 2019 Z— i 'n 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑AOa' seputdo ❑ Suspend ❑ Perforate p Other Stimulate ❑ Pull Tubing ❑ ICQI (kjAq, d(}$o, gram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Water Wash 2, Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 179-050 3. Address: P.O. Box 196612 Anchorage, AK 9 951 9-6 612 Stratigraphic ❑ Service 21 6. API Number: 50-029-20386-00-00 - 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? e. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 21 PBU WGI-04 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): 9584 8596 9550 8564 None 8060 Casing Length Size MD ND Burst Collapse Structural Conductor 78 20" 31-109 31 -109 1530 520 Surface 2703 13-3/8" 31-2733 31-2733 4930 2670 Intermediate 8614 9-5/8" 29-8643 29-7705 6870/8150 4760/5080 Production Liner 1 1252 7" 8332-9584 7417 -8596 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 26-8083, 9034- 8076 - 8487 7-5/8" 29.7# x 7" 269 x 7" 29# L-80 / N . / L-80 8065 - 8142, 8228 - 8246 Packers and SSSV Type: 7" Baker S-3 Packer Packers and SSSV MD (ft) and ND (ft): 8036/7157 7" Baker SAB Packer 8115/7225 1 7" Baker SB -2 Packer 8228 / 7325 7" MCX SSSV 2181/2181 12. Attachments: Proposal Summary p Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: 12/16/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG p 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: browd20BP.com Authorized Name: Brown, Don L. Contact Phone: +1 9075644675 Authorized Title: Petroleum Engineer Authorized Signature: �% �o.y, Date:/ / - a% "7 4 n 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 ❑ 319 -,941 Other: / Post Initial Injection MIT Req'd? Yes 11 ) BDMSL"EC 0 6 2019 No ❑/ Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: fD —Loco AP//PROVED BYTHE ,Q Approved by: - � COMMISSIONER COMMISSION I al C Date: Form 10-403 Revised 04/2017 0 R!J" l M m4? 24N°�� Qj Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 10-403 Sundry Application for Well PBU WGI-04 PTD #179-050 Expected Start Date: December 16, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 199121 Mscf/Da Injection Pressure: 3761 psi Reservoir Pressure (Estimate): 3427 psi Program Objective(s): WGI-04 has had several successful water washes historically, the most recent being on 11/24/14. These water washes have been successful and injectivity in this well has decreased since the 2016. 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 NGINVGI/AGI gas injectors to improve injectivity. This well is also an emergency gas source well. 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 WGI-04 PTD #179-050 Pump Schedule: Well WGI-04 Work Desc Gas InBctor 6tiater Wash AFE Q Date 1126119 Engineer Don Brown Phone k907) 564-4675 H2S Value r wA H2S Date r NIA CledP increase well injectivity by performing a water wash. Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 200 bbis of diesei/xylene. Pump Schedule Sta a Fluid Type Pump Into Vol bbis) Rate (born Max Pres i I Spear 6lethanol, Water TBG 15 1-,', 3000 2 Solvent DieseV>(lene TBG 2C0 Me-< 3000 3 Over -Flush Fresh Water TBG 6CC See Below 9000 4 Freeze Protect Methanol/Water TBG 10 t= 9000 5 6 T 1.) 10 bbi 60/40 McOH/water spear 2.1200 boils 50/50 diesel/xylene heated to 80 degrees F or as hot as LRS can heat it. 3.) Pump 600 bills of fresh water with 0.02% F-103 surfactant per following: a.) Pump 313 bbls of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut -down pumps and let diene:/xylene soak across perfs for 4 hours - this should allow - 100 bbis of D/X to be pumped into perfs and a remaining 100 bbls to soak. b.) Resume pumping at 1.0 bpm for next 200 bbis of fresh water w h 0.02% F-103 surfactant. c) Once 513 bbis of fresh water with 0.02% F-103 surfactant bas been pumped resume pumping at 1-3 bpm for remainder of overflush (^87 bbis). 4.) 15 bbis of 60/40 McOH/vrater freeze protect 5.) ROMO. Return well to gas injection. Directions When filling out the pumping template, please note the following: MIT #1 TestType Target Pressure Max Apphed Pressure Test Fluid InteontyLimtsConfirmed ❑ MIT #3 Test Type Target Pressure Idax Applied Pressure Test Fluid inteordy Limns oof,— ❑ If "MIT' is selected as a stage. the corresponding PAT 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 Mit 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 Confimced: By checking this box, you have confirmed that the "Max Applied Pressure` requested is within the limits of the wells Well Barrier Envelope". BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU WGI-04 PTD #179-050 Wellbore Schematic: Tf$- 631V ,� FCAD ACTIATOR BA ,KB. REV - BF. EL = 'Max All* 49 E '00t M?= 11 ID-6,276' � OW bpf, Ob{d.0 i73/e'(:SG. l2I,NeP,O-t2.34T 2733 Tar TE4G, x185 xQ L8G VAMTOP, D -8.8]i 70i `7 `i8' TBG, 29.7Y.:-80, VAM TOP- 800 0459 buf 1)-6 B7S Minimum ID = 4.843" @ 8246' L7" BKR SHEAROUT SUB r TBG, 2W}, K89, .037i apt, O = 8.161' i—<�7 T00OF r I.W - C (9.52'CSG. a]p. N80fSOQ95.D=3.681• f-� FBY-ORATIONSLWMW RFF LOG. BHM ON 10M6T/9 AW,LEATTOPFERR tgQ9034- NNW: Rafe• W RW ,0N DB for tstoncai pert data SQE SFF� MSNAL 1.Op'1'^"y2 U4TF SEE MCI.2 FOR FUYORA MW t]ATA _ _— . w r• ENit. z¢a, i.AP, 0371 '. o--'s:ieo= '..:.-- WGI-04 SAFETY NOTES; WELL REQUA7ES A SSS_y. 26 �-ri7S8XO D'6tdi' __142. �Am g�i18 rsN FS efa�etart-N� 2166' - ]-ar -FT6r,, iiW 2197'-� Oar i£S EOBlEJia2 J 2197__,- r GAMW DQC t4P, o m ti_c00' %_Y209' rxasB'xa, D=6. teC• BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0-5 : SE X 1ES iN W. MUTIDE BAY UNT,___ WFL WG404 ARM 50.029.20386-00 SEC 11, TI IN R14E BP ExpWatlnn (Alaska) 10-403 Sundry Application for Well PBU WGI-04 PTD #179-050 PU4CMWNSt.M RY REF LOO: BNCS ON 10/16179 ANXFAT TOPR74. 19 @ 9W We: Rater to Rudmwn 03 far ta4tOrcal pert dew WE SFF INTERVAL OpNS, OkTE 138' 4 9034 9134 O 0425187 13!8' 0 9142- 9309 O 0525!87 330' 4 9320-9362 ( O 052587 130' 4 9366 - 9360 O 052&87 3-38' 4 9392-94M O 052587 138' 4 9416-9438 O 052587 i 338' I i 4 9449- 9469 O 052W WGI-04 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 R4.ONDEBAY LUT W31 WG404 FFJW No 1790500 ARM 50.029-2038600 BP Exploration fAlaskal • : MEMORANDA? State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday,May 25,2018 P.I.Supervisor ' €Ct S/ t g SUBJECT: Mechanical Integrity Tests c BP EXPLORATION(ALASKA)INC. WGI-04 FROM: Austin McLeod PRUDHOE BAY UNIT WGI-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprve— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-04 API Well Number 50-029-20386-00-00 Inspector Name: Austin McLeod Permit Number: 179-050-0 Inspection Date: 5/9/2018 - Insp Num: mitSAM180509150956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-04 : Type Inj 0'1TVD 7331 - Tubing 3506 3506 3491 3186 3318 3089 PTD 1790500 - Type Test SPT Test psi 1833 ' IA 388 2500 - 2445 ' 2416 - 2400 - 2401 - BBL Pumped: 2.4 - BBL Returned: 2.6 " OA 73 70 _ 70 ' 71 - 71 - 70- Interval 4YRTST P/F P = Notes: MIT-IA to 2500 psi as per operator request. 149 inj temp. - C- CLLc r 4- NNE) JUN 0 12018 Friday,May 25,2018 Page 1 of 1 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM[ IN REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon _] Repair Well Plug Perforations Ll Perforate[ Other _; Water Wash Performed: Alter Casing ] Pull Tubing� Stimulate - Frac ❑ Waivers_ Time Extension ❑ Change Approved Program ❑ Operat. Shutdovir�_] Stimulate - Other ❑ Re-enter Suspended WeIC 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory [' Stratigraphic ❑ Service [ 179-050-0 3 Address. P.O Box 196612 6. API Number Anchorage, AK 99519-6612 50-029-20386-00-00 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0028302 PBU WGI-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: E C E I V E Total Depth measured 9584 feet Plugs measured None feeR true vertical 8596.25 feet Junk measured None feet DEC 19 MA Effective Depth measured 8060 feet Packer measured See Attachment feet true vertical 7177.9 feet true vertical See .Attachment feet I' OGC;C; Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 7825 20" 94# H-40 28.5 - 106.75 28.5 - 106.75 1530 520 Surface 2705.3 13-3/8" 72# N-80 28-2733,3 28-2733.28 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1252.06 7" 29# L-80 8331.94 - 9584 7417.42 - 8596.25 8160 7020 Perforation depth Measured depth See Attachment feet SC.4NNED JAN 1 2 2015 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 7" MCX SSSV 2181 218098 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured)- 9034'- 9082', 9084" - 9132', 9142'- 9180', 9216', 9218'- 9266', 9268'- 9307', 9320'- 9360', 9366'- 9378', 9392'- 9402', 9416'- 9436', 9449'- 9469'. Treatment descriptions including volumes used and final pressure: 10 Bbls Methonal, 200 Bbls Diesel / Xylene, 570 Bbls 0.02% F-103 Surfactant, 1371 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 248893 0 0 3642 Subsequent to operation. 0 242943 0 0 3504 14. Attachments: 15. Well Class after work Copies of Logs and Surveys Run Exploratcr[] DevelopmenCl Service [ Stratigraphic Daily Report of Well Operations X 16. WeII Status after work: Oil J Gas ❑ W DSPE GSTOR C WINJ ] WAG ❑ GINJ I" SUSP IJ SPLUC 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: 314-214 Contact Garry Catron Email Garry. Catron C!-BP.Com Printed Name Garry Catron Title PDC PE Signature G V cy— ZZ:_+ Phone 564-4424 Date 12/19/2014 Vr` Form 10-404 Revised 10/2012 RBD ,k1 nal — 4 Luis M§ mi rigiOnly Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription WGI-04 SSSV 2181 2180.98 7" MCX SSSV WGI-04 PACKER 8038.36 7159.16 7" Baker S-3 Packer WGI-04 PACKER 8116.5 7227.06 7" Baker SAB Packer WGI-04 PACKER 8227.8 7324.82-----t7---Baker SB -2 Packer Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20" 94# H-40 29 - 107 28.5 - 106.75 1530 520 INTERMEDIATE 1410 9-5/8" 47# L-80 26 - 1436 25.7 - 1435.95 6870 4760 INTERMEDIATE 779 9-5/8" 47# L-80 1433 - 2212 1432.86 - 2211.98 6870 4760 INTERMEDIATE 135 9-5/8" 47# SOO-95 2200 - 2335 2199.83 - 2335.18 8150 5080 INTERMEDIATE 6307 9-5/8" 47# N-80 2335 - 8643 2335.18 - 7704.79 6870 4760 LINER 1252 7" 29# L-80 8332 - 9584 7417.42 - 8596.25 8160 7020 SURFACE 2705 13-3/8" 72# N-80 28 - 2733 28 - 2733.28 4930 2670 TUBING 4 7" 26# L-80 23 - 27 23.28 - 27.26 7240 5410 TUBING 2162 7-5/8" 29.7# NT -95 27 - 2189 27.26 - 2188.82 8180 5120 TUBING 23 7" 26# L-80 2189 - 2211 2188.82 - 2211.37 7240 5410 TUBING 5436 7-5/8" 29.7# NT -95 2211 - 7647 2211.37 - 6827.94 8180 5120 TUBING 359 7-5/8" 29.7# L-80 7647 - 8006 6827.94 - 7131.23 6890 4790 TUBING 79 7" 26# L-80 8006 - 8085 7131.23 - 7199.83 7240 5410 TUBING 26 7-5/8" 29.7# L-80 8088 - 8114 7202.12 - 7225.12 6890 4790 TUBING 29 7" 29# L-80 8114 - 8143 7225.12 - 7250.63 8160 7020 TUBING 19 729# L-80 8228 - 8246 7324.82 - 7341.32 8160 7020 AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028302 MLK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base WGI-04 5/25/1987 PER 9034 9062 8075.9 8102.31 WGI-04 5/25/1987 APF 9062 9064 8102.31 8104.2 WGI-04 5/25/1987 APF 9064 9082 8104.2 8121.17 WGI-04 5/25/1987 PER 9084 9112 8123.05 8149.44 WGI-04 5/25/1987 APF 9112 9114 8149.44 8151.33 WGI-04 5/25/1987 APF 9114 9132 8151.33 8168.3 WGI-04 5/25/1987 PER 9142 9160 8177.74 8194.73 WGI-04 5/25/1987 APF 9160 9162 8194.73 8196.62 WGI-04 5/25/1987 APF 9162 9180 8196.62 8213.63 WGI-04 5/25/1987 PER 9182 9200 8215.52 8232.54 WGI-04 5/25/1987 APF 9200 9202 8232.54 8234.43 WGI-04 5/25/1987 APF 9202 9216 8234.43 8247.67 WGI-04 5/25/1987 PER 9218 9236 8249.56 8266.59 WGI-04 5/25/1987 APF 9236 9238 8266.59 8268.48 WGI-04 5/25/1987 APF 9238 9266 8268.48 8294.96 WGI-04 5/25/1987 PER 9268 9296 8296.85 8323.32 WGI-04 5/25/1987 APF 9296 9298 8323.32 8325.22 WGI-04 5/25/1987 APF 9298 9307 8325.22 8333.73 WGI-04 5/25/1987 PER 9320 9348 8346.02 8372.5 WGI-04 5/25/1987 APF 9348 9350 8372.5 8374.4 WGI-04 5/25/1987 APF 9350 9360 8374.4 8383.85 WGI-04 5/25/1987 PER 9366 9374 8389.53 8397.1 WGI-04 5/25/1987 APF 9374 9376 8397.1 8398.99 WGI-04 5/25/1987 APF 9376 9378 8398.99 8400.88 WGI-04 8/20/1980 PER 9392 9402 8414.13 8423.59 WGI-04 8/20/1980 PER 9416 9436 8436.84 8455.79 WGI-04 8/20/1980 PER 9449 9469 8468.11 8487.07 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF TREE = 6-3/8" CNV WELLHEAD = GRAY A,CTUATOR = BAKER KB. ELEV = 49' BF. ELEV = 12/24/07 KOP = 3200' Max Angle = 44 @ 6800' Datum MD = N/A Datum TVD = 8800' SS 7" TBG, 26#, L-80, 25- TC- 11, 5'TC-11, .0383 bpf, ID = 6.276" 9-5/8" CSG, 47#, L-80, TC -II, ID = 8.681" 1433' 7-5/8" TBG, 29.7#, NT95, VAM TOP 2186' IPC,.0459 bpf, ID = 6.875" 7" TBG, 26#, L-80, TC -11, .0383 bpf, ID = 6.276" 2209' 9-5/8" CSG, 47#, L-80, TC -11, ID = 8.681" 2212' 13-3/8" CSG, 72#, N-80, ID = 12.347" —2733- 17-5/8" TBG, NT95 XO L-80 VAM TOP, ID = 6.875'7645 7-5/8" TBG, 29.7#, L-80, VAM TOP 8003 IPC, .0459 bpf, ID = 6.875" Minimum ID = 4.843" @ 8245' 7' BKR SHEAROUT SUB I7" TBG, 26#, L-80, TC -11, .0383 bpf, ID = 6.276" I 8083' 7-5/8" TBG STUB (01/25/06) 8085' 7" TBG, 29#, L-80,.0371 bpf, ID = 6.184" 1-1 8142' 17" TBG, 29#, N-80_0371 bpf, ID = 6.184" 8246' TOP OF 7" LNR 8332' 9-5/8" CSG, 47#, N-80/SOO-95, ID = 8.681" $643' PERFORATION SUMMARY REF LOG: BHCS ON 10/16/79 ANGLE AT TOP PERF: 19 @ 9034' Note: Refer to Production DB for historical perf data SIZE SPF I INTERVAL I Opn/Sqz I DATE SEE PAGE 2 FOR PERFORATION DATA PBTD 9550' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9584' -O � S Y NOTES: WELL REQUIRES A SSS V. W G I 2517" X 7-5/8" XO, ID = 6.184" 1420' 9-5/8" HES ES CEMENTER 2186' 7-5/8" X 7" XO, ID = 6.184" 2197' 9-5/8" HES ES CEMENTER 2197' 7" CA MCO DB -6 NIP, ID = 6.000" 2209' 7" X 7-5/8" XO, ID = 6.184" 8003' -17-5/8" X 7" XO, ID = 6.184" 8015' 7" HRP,D6 -5/8" X 7" BKR S-3 PKR, ID = 6.000" 8036' —r9— 7" HES RN NIP, ID = 5.770- 8083' 7" MULESHOE, ID = 6.200" 8115' 9-5/8" X-7- BKR SAB PKR 8133' 7" HES RN NIP, ID = 5.5" 8142' 7" TUBING TAIL WLEG 8228' 9-5/8" X 7" BKR SB -2 PKR 8245' 7" BKR SHEA ROUT SUB, ID = 4.843" 8246' 7" TUBING TAIL 8227' ELMD TT LOGGED 05/25/87 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/28/79 ORIGINAL COMPLETION 12/24/07 JM/TLH DRAWING (CSG) CORRECTIONS 08/16/97 LAST WORKOVER 09/30/09 JLJ/SV DB -6 NIP CORRECTION 04/02/06 N4ES RWO 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 05/23/06 TEL/PJC SET 7" PRN PLUG @ 8060' 03/13/07 DCR/ PJCI DRLG DRAFT CORRECTIONS 11/20/07 DSM/PJC I TREE CORRECTONS (10/30/07) PRUDHOE BAY UNIT WELL: WGI-04 PERMIT No: 1790500 API No: 50-029-20386-00 SEC 11, T11 N, R14E BP Exploration (Alaska) W G I-04 PERFORATION SUMMARY REF LOG: BHCS ON 10/16/79 ANGLE AT TOP PERF: 19 @ 9034' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9034-9134 O 05/25/87 3-3/8" 0 9142-9309 O 05/25/87 3-3/8" 4 9320-9362 O 05/25/87 3-3/8" 4 9366-9380 O 05/25/87 3-3/8" 4 9392-9402 O 05/25/87 3-3/8" 4 9416-9438 O 05/25/87 3-3/8" 4 9449-9469 O 05/25/87 DATE REV BY COMMENTS DATE I REV BY COMMENTS 10/28/79 ORIGINAL COMPLETION 12/24/07 JM/TLH DRAWING (CSG) CORRECTIONS 08/16/97 LAST WORKOVER 09/30/09 JLJ/SV DB -6 NIP CORRECTION 04/02/06 N4ES RWO 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 05/23/06 TEL/PJC SET 7" PRN PLUG @ 8060' 03/13/07 DCR/ PJCJ DRLG DRAFT CORRECTIONS 11/20/07 DSM/PJC TREECORRECTONS(10/30/07) PRUDHOE BAY UNIT WELL: WGI-04 PERMIT No: 1790500 API No: 50-029-20386-00 SEC 11, T11N, R14E BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg _ DATE: Wednesday, July 09, 2014 P.I. Supervisor ZSUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-04 FROM: John Crisp PRUDHOE BAY UNIT WGI-04 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprva�'- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-04 Insp Num: mitJCr140513140255 Rel Insp Num: API Well Number 50-029-20386-00-00 Permit Number: 179-050-0 Inspector Name: John Crisp Inspection Date: 5/11/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-04 Type Inj G ' TVD 7331 IA 378 2514 2484 2489 2480 TD 1790500 Type Test SPT Test psi 1833 OA 35 32 34• 35 35 Interval 4YRTST P/F P Tubing 3562 ' 3563 j 3555 ' 3563 3562 Notes: 2.38 bbls pumped for test. SHIAGW Wednesday, July 09, 2014 Page I of 1 >���177, �� r1 HE STATE L ' 1_' 7 '` A /\ I- dI\ r 333 West Seventh Avenue GOVERNOR SEAN 1'ARN1-:LI_ Anchorage, Alaska 99501-3572 *':'� Main. 907.279.1433 p 3Ul 2 2 2014 Javier Farinez SLa�'1NE GPB GDE Lead PE 7 ' ��� BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-04 Sundry Number: 314-214 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, G Cathy P. 'oerster ¢fes Chair DATED this fv day of April, 2014. Encl. .4 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 3 2014 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program E Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash ❑� • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 179-050-0 • 3.Address: Stratigraphic El Service 0 • 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20386-00-00 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-04 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): 9584 8596 • 9550 8564 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 73 20"94#H-40 25-98 25-98 Surface 2711 13-3/8"72#N-80 24-2735 24-2734.97 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1252 7"29#L-80 8332-9584 7417.47-8596.25 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 7"MCX SSV 2181',2180.98' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ Q . WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name .avier F=rinez Title GPB GDE Lead PE Signature ,// Phone 564-5043 Date t.(,( 1, /!h Prepared by Garry Cntron 564-4424 , ( COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \4.— 2-\4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ p Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: `G _ 4 G 2.1 APPROVED BY Approved by: Y COMMISSIONER THE COMMISSION Date:4--/0 -/ / Form 10-403 Revised 10/2012 li a I or 12 moot s f m the date of approval. Submit Form amrAttachments in Duplicate IrI-F -1-14t. 1/q 44.4- U) U) 73 CD o C D °) o °) o CD o 0 0 0 0 0 0 0 0 Or) 012 .1- C9 0 0 0 0 co D OD O0 00 00 00 03 0 D 0 = J Z O J O J Z J J J J J J J J J Z a) Co O O O O O O O O O O O O O O O o 0 0 0 Cp N Co Co Co tiO oO N O CA CA N O O N p Nr Cn CC) I- N CC) Cf) Cn I- vt r- N- ti U) CC) 0 C) ON- U)) NO CO Co CO3 Co0v v Coo ER ER COO CO CoO OV Co0 7 Cn CO Co - 00 - - CO - N N T- Co Co - '- N T- OO Co Co OO Co co OO Nr OD 0- 0- OD Co CO OD OD OO N- 00 a) CO OD 00 CO O coo T- a) CO M N CO O C[) CO co N ' s 00 O cr N- N N N OD N COO N- N W I- N- N- N- N- N CL Cn 0- CO I- T- ti CO O CC) CC) M CD U) CO 0) O) N Co 'Cr 00 07 N O N N N CO U) 0 N N 07 N NJ' N N N OD N M C7 N N N N N- N 0- 0- CO 0- 0- 0- N- N 03 c\I E p m M CO CO M U) N 0- Nt Cn 0- U Nr CO N CO CO N '- CD M m C M CD C7 I OO In 0 O vT NT CO N 0 O �- Co N N N a) N CNO Co0 N a) Co0 Co CoO Co Co N N (/) 0 2 CD J CL N 0 to IN- 00 (NI T- CO N- CC CO ) C10 Co N CA Q W F' Cn CO 01 CD N CO 01 (N (N O 00 C'�) . OO N N '— 00 Cn Na N N M (N i N C7 N N O N CO CO O N N CO ( a N N T- Co N Co Co Co OD OD 00 N Lo Ul O o O O O CD O CD o (O OO Cp CD CD CD CD I- T J Z 0 _J 0 CO Z Z a0 CO CSO J J OD Cao OO 00 Z *k m *k m J N 4k J J J g g J J J J 4* 4 4t C4O (� *k CA O) *k 4# *k *k CD 00 ap N a0 N N N N N Co N N N N CO N N C j -0O ;D f� M ;0 CD CA "? CD 111 CO u Ul O) O) N- I� I'i L OD T-th O O M N- U CO O) N CN el, N- CO CO O N CSO C J N N N-LO CV Ch •N c7 N N W W W W W cc F• F• F• F- <C Q Q Q Q c F- 0 0 0 0 0 0wwwww w (0 0 2 2 2 2 2 0 0 0 0 0 o o o 0 0 0 0 0 0 CC CC Q CC u Z Z Z Z Z Z Z Z Z Z Z Z w w w w w w OC m m m m m 03 m m m m m 0 F- F- - -Z 2D 2D 2D 23 23 23 2D 0 Z Z FZ FZ ZJ > > > > >(n F- F- F- F- F- F- H H H F- Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base WGI-04 5/25/87 PER 9034 9062 8076 8102 WGI-04 5/25/87 APF 9062 9064 8102 8104 WGI-04 5/25/87 APF 9064 9082 8104 8121 WGI-04 5/25/87 PER 9084 9112 8123 8149 WGI-04 5/25/87 APF 9112 9114 8149 8151 WGI-04 5/25/87 APF 9114 9132 8151 8168 WGI-04 5/25/87 PER 9142 9160 8178 8195 WGI-04 5/25/87 APF 9160 9162 8195 8197 WGI-04 5/25/87 APF 9162 9180 8197 8214 WGI-04 5/25/87 PER 9182 9200 8216 8233 WGI-04 5/25/87 APF 9200 9202 8233 8234 WGI-04 5/25/87 APF 9202 9216 8234 8248 WGI-04 5/25/87 PER 9218 9236 8250 8267 WGI-04 5/25/87 - APF 9236 9238 8267 8268 WGI-04 5/25/87 APF 9238 9266 8268 8295 WGI-04 5/25/87 PER 9268 9296 8297 8323 WGI-04 5/25/87 APF 9296 9298 8323 8325 WGI-04 5/25/87 APF 9298 9307 8325 8334 WGI-04 5/25/87 PER 9320 9348 8346 8373 WGI-04 5/25/87 APF 9348 9350 8373 8374 WGI-04 5/25/87 APF 9350 9360 8374 8384 WGI-04 5/25/87 PER 9366 9374 8390 8397 WGI-04 5/25/87 APF 9374 9376 8397 8399 WGI-04 5/25/87 APF 9376 9378 8399 8401 WGI-04 8/20/80 PER 9392 9402 8414 8424 WGI-04 8/20/80 PER 9416 9436 8437 8456 WGI-04 8/20/80 PER 9449 9469 8468 8487 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE 'I FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028302 Well Facility Type _ MD Top Description TVD Top WGI-04 SSSV 2181 7" MCX SSV 2181 WGI-04 PACKER 8039 7" Baker S-3 Packer 7160 WGI-04 PACKER 8115 7" Baker SAB Packer 7226 WGI-04 PACKER 8228 7" Baker SB-2 Packer 7325 TREE= • 6-3/8"CM/ WELLHEAD= GRAY VVG 104 SA (NOTES: WELL REQUIRES A SSSV. •ACTUATOR= BAKER KB.ELEV= 49' BF.ELEV= • l KOP= 3200' 7"TBG,26#,L-80, -I 25' • ` 25' -17"X 7-5/8"XO,ID=6.184" Max Angle= 44 @ 6800' TC-11, .0383 bpf, • Datum MD= N/A 1420' -9-5/8"HES ES CEMENTER Datum TVD= 8800'SS ID=6.276" • • 2186' -7-5/8"X 7"XO,ID=6.184" • 9-5/8"CSG,47#,L-80,TC-II,ID=8.681" -I 1433' • 2197' 1-19-5/8"HES ES CEMENTER 7-5/8"TBG,29.7#,NT95,VAM TOP 2186' 2197' -I 7"CAMCO DB-6 NIP,ID=6.000" IPC,.0459 bpf, ID=6.875" 7"TBG,26#,L-80,TC-11, .0383 bpf, ID=6.276" H 2209' I 2209' --I X 7-5/8"XO,ID=6.184" 9-5/8"CSG,47#,L-80,TC-II, ID=8.681" 1 2212' IL13-3/8"CSG,72#,N-80,ID=12.347' - 2733' 14 7-5/8"TBG,NT95 XO L-80 VAM TOP,ID=6.875 --I 7645' 8003' -7-5/8"X 7"XO,ID=6.184" 7-5/8"TBG,29.7#,L-80,VAM TOP -I 8003' 8015' H 7"HES R NIP,ID=5.963" IPC,.0459 bpf,ID=6.875" 8036' 1-19-5/8"X 7"BKR S-3 PKR,ID=6.000" Minimum ID =4.843" @ 8245' 7" BKR SHEAROUT SUB 8060' -7"HES RN NIP,ID=5.770" I 7"TBG,26#,L-80,TC-11, .0383 bpf, ID=6.276" - 8083' ---I 8083' -17"MULESHOE,ID=6.200" 7-5/8"TBG STUB(01/25/06) H 8085' Z X 8115' H9-5/8"X 7"BKR SAB PKR I I8133' -I 7"HES RN NIP,ID=5.5" 7"TBG,29#,_L-80, .0371 bpf,ID=6.184" -1 8142' / \ ---I 8142' -7"TUBING TAIL WLEG z 8228' H 9-5/8"X 7"BKR SB-2 PKR I 8245' -7"BKR SHEAROUT SUB,ID=4.843" I 7"TBG,29#,N-80,.0371 bpf,ID=6.184" - 8246' / \ 8246' HT TUBING TAIL TOP OF 7"LNR -I 8332' 8227' H ELMD TT LOGGED 05/25/87 9-5/8"CSG,47#, N-80/SOO-95, ID=8.681" H 8643' A 111, HERFORATION SUMMARY REF LOG:BHCS ON 10/16/79 I ANGLE AT TOP PERF: 19 @ 9034' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL Opn/Sqz I DATE- SEE ATE SEE PAGE 2 FOR PERFORATION DATA I I I I 1 I PBTD --I 9550' I ,.....4 7"LNR,29#,L-80,.0371 bpf,ID=6.184" H 9584' ������������ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/28/79 _ORIGINAL COMPLETION 12/24/07 JMITLH DRAWING(CSG)CORRECTIONS WELL: WGI-04 08/16/97 LAST WORKOVER 09/30/09 JLJ/SV DB-6 NIP CORRECTION PERMIT No: 1790500 04/02/06 N4ES RWO 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-20386-00 05/23/06 TEL/PJC SET 7"PRN PLUG 0 8060' SEC 11,T11 N,R14E 03/13/07 DCR/PJC DRLG DRAFT CORRECTIONS 11/20/07 DSM/PJC TREE CORRECTONS(10/30/07) BP Exploration (Alaska) WGI-04 I' N\I x PERFORATION SUMMARY REF LOG:BHCS ON 10/16/79 g g ANGLE AT TOP I'tttF: 19 @ 9034' Note:Refer to Production DB for historical pert data 7 \ SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9034-9134 0 05/25/87 3-3/8" 0 9142-9309 0 05/25/87 3-3/8" 4 9320-9362 0 05/25/87 3-3/8" 4 9366-9380 0 05/25/87 3-3/8" 4 9392-9402 0 05/25/87 3-3/8" 4 9416-9438 0 05/25/87 3-3/8" 4 9449-9469 0 05/25/87 ' 1 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/28/79 ORIGINAL COMPLETION 12/24/07 JM/TLH DRAWING(CSG)CORRECTIONS WELL: WGI-04 08/16/97 LAST WORKOVER 09/30/09 JLJ/SV DB-6 NIP CORRECTION PERMIT No:'1790500 04/02/06 N4ES RWO 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-20386-00 05/23/06 TEL/PJC SET 7"PRN PLUG @ 8060' SEC 11,T11 N,R14E 03/13/07 DCR/PJC DRLG DRAFT CORRECTIONS 11/20/07 DSM/PJC TREE CORRECTONS(10/30/07) BP Exploration (Alaska) ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3,DBR,LHD,EAZ 01/15/14) • General Information Well Name: WGI-04 Well Type: Injector API Number: 500292038600 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, $M: 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 lnj Rate&Pressure 3/24/2014 N/A N/A 250.MMscfpd N/A N/A N/A 3,650 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent I-12S (date,ppm) N/A 0 ppm Maximum Deviation(angle and depth) 44° 6,800'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 4.843"©8,245' Reservoir pressure(date,psig) N/A 3,700 psi Reservoir temperature,F 134°F Shut in wellhead pressure 2,820 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 12/7/210.SSSV Maintenance Most recent TD tag,(date,depth,toolstring OD) 5/15/2010.9425'w/4-1/2"Cent Comments,well history, Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used • background information,etc: successfully in the past on the NGIM/GI/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:Perf 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 TO: Jim Regg ~c~~Cf E' ~' ~ tU P.I. Supervisor ~ l FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-04 PRUDHOE BAY UNIT WGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~~ Comm Well Name: PRUDHOE BAY UNIT WGI-04 Insp Num: mitLG100516053802 Rel Insp Num: API Well Number: 50-029-20386-00-0o Inspector Name: Lou Grimaldi Permit Number: 179-050-0 Inspection Date: 5/15/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 WGI-04 Type Ind. P.T.D~ I79os~peTest -~---- ~-- N ~ TVD SP~T Test psi ~----L~-- 7157 ~ t7s9 - IA pA - 4300 o 1010 ~~ 1060 o I o 1080 ~' 0 - InterVal 4YRTST p~F, P Tubing) 2630 2160 2180 2180 Notes: 2nd part of MIT see mitLG 100516052241). Bled IA from 4300 psi to 1010 psi and observed for 30 minutes. Minor pressure movement. Monday, May 24, 2010 Page 1 of I MEMORANDUM TO: Jim Regg ~~~ ~ ~1 ~!o P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-04 PRUDHOE BAY UNIT WGI-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~tj'~'~'-- Comm Well Name: PRUDHOE BAY UNIT WGI-04 API Well Number: 50-029-20386-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG100516052241 Permit Number: 179-050-0 Inspection Date: 5/15/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well wGI-oa Type Inj. NIT ~ -j-- ----I-- --- - 9o oo SPT ~ 7~s7 ~ IA i 4160 4400 ~~ - -~-j--- 4340 4300 y -r---T- - s TypeTest P.T.D~7 Test psi InteCVa14YRTST _ per, vs9 r i OA , 0 0 P y Tubin~ 2s90 2630 0 -}- 0 2630 i 2630 Notes: Tubing plug set in TT @8071' (wlm). IA pressured up from pretest when I arrived. Raised IA pressure to 4400, minor loss observed. Bled IA to 1010 and observed for 30 minutes (see subsequent test). i - 1 ("~ O t t ~ ~i Monday, May 24, 2010 Page I of 1 e e Subject: RE: WGI-04 Stud Nuts From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Mon, 29 May 2006 20:37:38 -0800 .';/, . 5J3èJD~ To: James Regg <jim_regg@admin.state.ak.us>, Admin AOGCC Prudhoe Bay l\é11 <aogcc -prudhoe _ bay@admin.state.ak.us> CC: Winton GAubert <winton_aubert@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, SchmoyAL@BP.com, "Engel, Harry R" (1) <Hany.Engel@BP.com> \ '\ q_ 0 b Hi Jim. On 5/26/06, we removed the tree from WGI-04 and replaced the short studs with the proper length studs. All the nuts now have full thread engagement. Attached is a post-job picture showing the current nut-stud configuration. Thank you for bringing this to our attention. Joe Anders, P .E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com 'jC,;~N~~£D ..-;. i~:, ,,.;'.. ç;i -----Original Message----- From: James Regg (mailto:jimJegg@admin.state.ak.us] Sent: Friday, May 19,200610:50 AM To: NSU, ADW Well Integrity Engineer; Admin AOGCC Prudhoe ßay Cc: Winton GAubert Subject: PBU WGI-04 MIT Inspector witnessed an MIT at WGI-04; test passed but he noted a deficiency during the wellhead inspection. Inspection report is attached. Please advise what timeline you have established to resolve the noted deficiency (i.e., all nuts on the studded connection from tubing head adaptor to master valve were made up with less than full threads); also advise how this will be resolved. Jim Regg AOGCC RE: PBU WGI-04 MIT e e Hi Jim, We plan to secure the well within the next 2-3 days to change out the flange bolts and have complete make up of all of the nut threads. Please let me know if you have any other questions. Thanks, Anna -----Original Message----- From: James Regg [ma_:.i:~!~:j irr'--J:::~99~_?9.:!:0i.~_:_:::;_~~~~_:~.Js:.\l_§.] Sent: Friday, May 19, 2006 10:50 AM To: NSU, ADW Well Integrity Engineer; Admin AOGCC Prudhoe Bay Cc: winton GAubert Subject: PBU WGI-04 MIT Inspector witnessed an MIT at WGI-04; test passed but he noted a deficiency during the wellhead inspection. Inspection report is attached. Please advise what timeline you have established to resolve the noted deficiency (i.e., all nuts on the studded connection from tubing head adaptor to master valve were made up with less than full threads); also advise how this will be resolved. Jim Regg AOGCC ...\C: TUN 1. .~~ ~Cif~~\ ~.t..!J 1 of 1 5/23/2006 8:43 AM ... AJ''-'' .. ............. V' ............... e e Inspector witnessed an MIT at WGI-04; test passed but he noted a deficiency during the wellhead inspection. Inspection report is attached. Please advise what timeline you have established to resolve the noted deficiency (i.e., all nuts on the studded connection from tubing head adaptor to master valve were made up with less than full threads); also advise how this will be resolved. Jim Regg AOGCC Content-Type: application/pdf 2006-0516 MIT PBU WGI-09 cs.pdf - - Content-Encoding: base64 ;;';:,f'·.P.l.I\'N~~' HJ~\' 1 S; ?On5 ~"W:J~·t"..~_~ \__~ i\i.J.. tJ t..._..J 1 of 1 5/19/2006 10:49 AM MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .~ './1' '!~'i k //.1/7 " ,(\ UP 'V:-1-( / \. DATE: Wednesday, May 17,2006 FROM: Chuck Scheve Petroleum Inspector SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-04 PRUDHOE BA Y UNIT WGI-04 " .&.:. ,,,,, ", .A.£f;~> ~~~~ ~A Src: Inspector Reviewed By: /~) r). .12.- P.I. Suprv, b Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT WGI-04 API Well Number 50-029-20386-00-00 Inspector Name: Chuck Scheve Insp Num: mìtCS060517071710 Permit Number: 179-050-0 Inspection Date: 5/16/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I WGI-04 ¡Type Inj. ¡ ¡TVD I -" ~80 I Well , G 7157 i IA 500 3000 I 2980 , i I , P.T. I 1790500 ITypeTest I SPT i Test psi I 789.25 ! OA 0 0 ! 0 ; 0 I ! _. , , I i Tubing i 3600 , 3600 , 3600 I 3600 I Interval WRKOVR P/F P , I i i Notes Pretest pressures were observed and found stable. Well demonstated good mechanical ìntegriy. During an inspection of the wellhead it was , noted that the studded connection from the tubing head adaptor to the master valve all nuts were made up with less than full threads. Some with as many as 3 empty threads in the nut. eej, HV5kJ-h,\..€) I"'. ;; ~ prc, Ce,;.Cl v-e ~.- . ^' (j Q~ l . " ¡ . ~ k.r::;\c¡ <::'~" ' e4'~U~ ~ l ' X v'J v\Utc{; if LCi.. ~ k( ~jC; <' .J ' I£-:¿'" " Wednesday, May 17,2006 Page 1 of 1 STATE OF ALASKA ~¡J? :f/J.0? ALAS.IL AND GAS CONSERVATION .MISSldN1<: REPORT OF SUNDRY WELL OPERATIONSi,,,, 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 49.0 8. Property Designation: ADL 028302 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 9584 8596 9550 Casing Structural Conductor Surface Intermediate Production Liner Length 45' 2705' 8615' ~:~(~~_j'\~~1~; ~;;- Perforation Depth MD (ft): Perforation Depth TVD (ft): o Operation Shutdown o Plug Perforations o Perforate New Pool o Other o Re-Enter Suspended Well o Time Extension o Perforate o Stimulate o Waiver 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 5. 99519-6612 179-050 6. API Number: 50-029-20386-00-00 9. Well Name and Number: PBU WGI-04 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 73' 73' 1530 520 13-3/8" 2733' 2733' 4930 2270 ~~5~p\ 8643' 7705' 8150 5080 ¿t¡ ,,~- 8332' - 9584' 7417' - 8596' 8160 7020 9034' - 9469' 8076' - 8487' RBOMS 8Ft MAY () 3 2DD6 Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8",29.7# x 7",26# & L-80 & 7", 29# L-80 & N-80 9-5/8" x 7" Baker 'S-3' packer; 9-5/8" x 7" Baker 'SAB' pkr & 9-5/8" x 7" Baker 'SB-2' pkr 8083'& 8115' - 8142' & 8228' - 8246' 8036'; 8115' & 8228' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cut & Pull leaking 9-5/8" casing in two different operations from 2212 to surface. Run new 9-5/8" casing and place ES Cementer at 2197' & at 1420' Treatment description including volumes used and final pressure: Squeeze 35 Bbls Arcticset II cement out the lower ES Cementer. However, it would not pressure test. Shutdown operations. Moved back on well, cut pulled and re-ran 9-5/8" casing to 1433'. Cemented w/90.3 Bbls Gas-Check cement. Successful pressure tests. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG 181 GINJ 0 WINJ 0 WDSPL est 0 my know edge. Sundry Number or N/A if C.O. Exempt 305-392 o Copies of Logs and Surveys run 181 Daily Report of Well Operations o Well Schematic Diagram Printed Name Terrie Hubble Title Technical Assistant Phone Date D5Jo?-f (Xp Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 9-5/8" casing has :2 one at Well: Field: API: Permit: - e WGI-04 Prudhoe Bay Unit 50-029-20386-00-00 179-050 Accept: Spud: Release: Ri: 01/18/06 N/A 02/05/06 Nabors 4ES PRE-RIG WORK 12/16/05 SAND PLUG SET AT 9000' - 9469'. DUMPED 4 - 50 LB BAGS OF SLUGGITS ON TTP. INITIAL TAG 8118' SLM, FINAL TAG 8116' SLM. RDMO. WELL LEFT SI. 01/05/06 PUNCH TUBING 10' OF PUNCHERS 1ST JOINT OF 7-5/8 TUBING ABOVE SABL PACKER 8090'- 8100' 4 SPF 0 PHASE. 01/08/06 TUBING PUNCH. STARTED RUNNING IN HOLE AT MIDNIGHT. 01/09/06 TUBING PUNCH STARTED RUNNING IN HOLE. TUBING PUNCH 8064' - 8074'. · fa BP EXPLORATION Operations Summary Report Page 1 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-04 WGI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/18/2006 Rig Release: 4/2/2006 Rig Number: Spud Date: 9/29/1979 End: 4/2/2006 Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2006 06:00 - 09:00 3.00 RIGD P PRE Scope down and lower Derrick. 09:00 - 12:00 3.00 RIGU P PRE Lay Herculite and extra Rig Mats. Spot Sub Base over well. Spot Pits, Pipe Shed and Camp. Raise and scope Derrick. Run in scoping pins. Accept Rig at 12:00. 12:00 - 18:00 6.00 RIGU N WAIT PRE 6 hours downtime due to having to spot and jack-up Rig on extra mat boards and timbers. Extra Rig height needed because of Wellhead configuration. 18:00 - 23:00 5.00 RIGU P DECOMP PJSM. RU floor. RU lines to tree. RU hardline toTiger Tank. Take on 120 degree seawater. Pressure testing lines to 3500 psi - good test. AOGCC notified of upcoming BOPE test. 23:00 - 00:00 1.00 KILL P DECOMP Pick up Lubricator. Pull BPV. Laydown the same. 1/19/2006 00:00 - 04:30 4.50 KILL P DECOMP Begin circulating 120 degree seawater down the tubing. Pump @ 2 bpm / 3000 psi. Circulate until all diesel returns out of backside (37 bbls). Switch to pump down IA and get all the diesel flushed out of tubing. Continue full circulation of well to kill well with seawater. 04:30 - 05:00 0.50 KILL P DECOMP Monitor well dead and blow down lines. 05:00 - 07:30 2.50 WHSUR P DECOMP Set two-way check and test with Cameron on location. ND Tree and Adater Flange. Prep Tree and Adapter Flange to be sent in for inspection. 07:30 - 00:00 16.50 BOPSUF P DECOMP Nipple-up Test Spool. Nipple up BOP Stack. Change out 7 5/8" Pipe Rams. Install 3" x 6" Variable-bore Pipe Rams. Attempt to test BOP Stack. Blind Ram door seal leaking. Make repairs. Pressure test on BOPE to 4000 psi not holding. Begin diagnostics of all BOPE. Changed dart in two-way check and pressure still bled off. Pumped down IA and up tubing against (through Tubing Punch holes) two-way check to 2000 psi - tested good. Continue surface line and equipment diagnostic testing. 1/20/2006 00:00 - 05:00 5.00 BOPSUF N SFAL DECOMP Continue diagnostics of BOPE for test to 4000 psi. Surface lines and equipment being inspected and tested in smaller sections to isolate problem area. Worked problem all the way back to the test pump. Call Little Red Services to assist in pressure testing of BOPE. Continue to try and work on test equipment until Little Red Services arrives. 05:00 - 06:00 1.00 BOPSUF N SFAL DECOMP Liitle Red on location. Have them RU to pump seawater from the pits into our BOPE. 06:00 - 19:30 13.50 BOPSUF N SFAL DECOMP Keep performing test diagnostics on all surface equipment. Problem has been determined to be the Tubing Hanger. Decision made to use Slickline to set a blanketing plug in the SSSV nipple to test against. Keep Little Red Services on location to pump for our pressure tests. RU Slickline unit. Slickline made two runs to set the plug and then set the prong. RD Slickline while completing BOPE test. 19:30 - 00:00 4.50 BOPSUF P DECOMP Test BOPE per BP/AOGCC state requirements. Tested all equipment to 250-300 psi low and 4000 psi high for 5 mins each. Annular bag tested to 3500 psi high. The State's right to witness test was waived by John Spaulding. 1/21/2006 00:00 - 00:30 0.50 BOPSUF P DECOMP Finish testing BOPE. RD Little Red Services. RD test equipment. Clean Rig Floor. 00:30 - 01 :30 1.00 FISH N SFAL DECOMP PJSM. RU Schlumburger Slickline to fish plug out of SSSV nipple. RIH to plug @ 2181'. Latch Prong and POOH with Prong. Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 2 of19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/21/2006 01 :30 - 04:00 2.50 FISH N SFAL DECOMP RIH with JRS Pulling Tool to latch Plug Body. Having to jar multiple times to try and pull Plug out of nipple. Working wire back and forth. Latched Plug and pulled out of nipple @ 3:30. POOH with Plug Body and lay down. Monitor well and ensure dead. RD Schlumburger. 04:00 - 04:30 0.50 FISH P DECOMP Make-up BHA #1 as follows: Baker Multi-String Cutter wI 8" Knives, XO. 04:30 - 11 :30 7.00 FISH P DECOMP Single in with BHA #1 and 3 1/2" Drill Pipe from Pipe shed. Total Joints = 255. 11 :30 - 12:00 0.50 FISH P DECOMP Pick-up a 10-ft x 3 1/2" Drill Pipe Pup Joint. Pick-up Kelly. Parameters are: PUW = 117K, SOW = 105K, RPMs = 65, Rot wt = 109K, Amps = 125 (-3000 ftllbs torque). Pump rate = 3.0 bpm/500 psi. 12:00 - 13:00 1.00 FISH P DECOMP Space-out Cutter to cut at 8,085'. Start cut at 12:10 hrs. Increase pump rates and open Knives. No indication of a cut after 30 minutes. Stop operations. Close Annular. Circulate down the 7 5/8" Tubing and take returns up the 7 5/8" x 9 5/8" Annulas. Pump rate was 1 3/4 bpm/2,500 psi and climbing. Pump rate through Tubing Punch holes at 8,090' during the initial Wellbore circulation was 2.0 bpm/3000 psi. 13:00 - 13:30 0.50 FISH P DECOMP Continue with cutting operations. Amps rernain steady at 125. Stop operations (total cutting time 55 minutes). Pull-up hole. Bring pump back on at 1 1/4 bpm/300 psi. Ease back down to "cut". Now taking weight. Stack 10K. Good sign. 13:30 - 15:00 1.50 FISH P DECOMP Circulate Well bore bottoms up at 4.5 bpm 11300 psi. Back down and stand back Kelly. 15:00 - 19:00 4.00 FISH P DECOMP POOH with 255 joints of 3.5" DP. Stand back DP. 19:00 - 20:00 1.00 FISH P DECOMP BHA #1 on surface. Break out Cutter. Check Knives for evidence of wear. About 1/2" worn down from initial length. MU BHA #2 as follows: Mule Shoe, 5 3/4" Spear, Stop Sub wI 8 1/4" Stop Ring, and XO. Lay down the BHA. 20:00 - 21 :30 1.50 BOPSUF P DECOMP Veco on location and installed Two-Way Check Valve. Pressure test to 1000 psi. 21 :30 - 23:00 1.50 BOPSUF P DECOMP Change out Pipe Rams to 7-5/8" for tubing completion. Pressure tested seal doors to 1500 psi - good test. 23:00 - 00:00 1.00 BOPSUF P DECOMP RU to pull Two-Way Check. 1/22/2006 00:00 - 00:30 0.50 BOPSUF P DECOMP Pull Two-Way Check Valve out. Monitor well to ensure dead. 00:30 - 01 :00 0.50 CHEM P DECOMP Mix and pump EB Mud Lub Pill down the IA @ 2 bpm 12000 psi. Pill volume = 13 bbls chased with 25 bbls of seawater. 01 :00 - 02:30 1.50 PULL P DECOMP Pick up BHA #2 (spear) and sting into Tubing Hanger. Bring 7-5/8" Tongs and Elevators up to Rig Floor. Drain BOPs. 02:30 - 03:00 0.50 PULL P DECOMP BOLDS and removed Control Lines Manifolds. Pull on workstring with 240K and no lifting or stretching of pipe seen on surface. Hold 155K on it while heating Tubing Spool for 30 mins. 03:00 - 04:00 1.00 PULL P DECOMP Work Pipe up and down to try and get the Tubing Hanger to unseat. Pulled 250K and was able to work up about 5". 04:00 - 05:00 1.00 PULL P DECOMP Pump down Kill Line up the IA with the Annular closed. Pump rate is 2 bpm @ 1600 psi. Try working pipe again and still not free. Pulled 250K and got about 6". 05:00 - 06:00 1.00 PULL P DECOMP Work Tubing up to 275K. - 12" of stretch. Hanger is free from Tubing Spool. 06:00 - 07:00 1.00 PULL P DECOMP Continue working Tubing. Pulled 300K, twice. Now have -16" . e Printed: 4/14/2006 11:12:22 AM e e BP EXPLORATION Page 30f 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/22/2006 06:00 - 07:00 1.00 PULL P DECOMP Stretch. Tubing appears to be partically cut but is not free. Unable to further work Tubing due to limits on the Derrick. Decission made with Anchorage Engineering to make a second cut in the same place (8,085'). 07:00 - 09:30 2.50 PULL N DPRB DECOMP Release Spear and lay down. Rig down 75/8" handling equipment. Call-out Dril-site Maint to install BPV/Dart. Hold Weekly Sunday Safety Meeting with Crew while WODSM to arrive on Location. 09:30 - 10:00 0.50 WHSUR N DPRB DECOMP Install BPVand Dart. Test same. 10:00 -11:00 1.00 BOPSUF N DPRB DECOMP Remove 7 5/8" Pipe Rams. Install 3 1/2" x 6" VB Pipe Rams. Test same. 11:00 - 11:30 0.50 WHSUR N DPRB DECOMP Drain Stack. Pick-up Lubricator. Pull Dart and BPV. Lay down same. 11 :30 - 12:00 0.50 FISH N DPRB DECOMP Make-up BHA #3 as follows: Baker 5 1/2" Multi-String Cutter w/8.0" Knives. 12:00 - 13:00 1.00 FISH N DPRB DECOMP Start TIH with BHA #3 and 3 1/2" Drill Pipe from Derrick. Shut down operations due to increasing winds. GPB Area now in Phase 2. Winds on location have increased to 40+ mph. Direction of wind causing the Blocks to be blown into the Derrick. 13:00 - 18:30 5.50 FISH N WAIT DECOMP Park BHA #3 at 1,517' (16 stands). Secure Well. Circulate Well bore with Charge Pump at idle. Maintain Rig. Notify Well Ops Supervisor of our status. 18:30 - 21:00 2.50 FISH N DPRB DECOMP Start TIH again with BHA #3 and 3 1/2" Drill Pipe with improved weather conditions. Winds on location have dropped to about 20 mph. Take extra precaution and monitor Derrick conditions while TIH. 21:00-21:15 0.25 FISH N DPRB DECOMP PU Kelly. Up weight = 120K Down weight = 102K. Bring on pump to pressure open the Knives on the BHA. 50 SPM (3 bpm) 1550 psi. RIH with Kelly to cut depth of 8085'. Stacked 5K @ 27' of Kelly in the hole. Slack off to neutral weight. 21:15 - 21:45 0.50 FISH N DPRB DECOMP Bring on rotation to re-cut @ 8085'. Rotating at 60 RPM 1150 Amps (-2500 ft-Ib of torque). After 5 mins, increase pump rate to 80 SPM (4.5 bpm) 11000 psi. Saw increase in pressure and torque for a second and then dropped back down. Another 10 mins later, increase pump rate to 90 SPM (5.25 bpm) 11200 psi. 5 mins later increase pump rate to 113 SPM (6.5 bpm) I 1500 psi. Approximately 25 mins after beginning cut, drop pump rate to 50 SPM to check pressure drop. At 50 SPM the pressure is now 375 psi. At 80 SPM the pressure is now 800 psi. 21 :45 - 22:00 0.25 FISH N DPRB DECOMP Down on pump and rotation. Pick up 2.5' out of hole. Bring the pump on at 50 SPM (3 bpm) 1550 psi. RIH to cut depth of 8085' slowly to see if pressure drop seen when Knives fully extend into cut. Stacked 14K down on cut and see pump rate of 50 SPM (3 bpm) 1400 psi. A pressure drop of 150 psi seen at cut depth. 22:00 - 00:00 2.00 FISH N DPRB DECOMP POOH with BHA #3 and 3.5" DP. Stand back Kelly and lay down 9 single joints of DP. Stand back 82 stands of DP. 1/23/2006 00:00 - 02:30 2.50 FISH N DPRB DECOMP Continue POOH with 3.5" DP and BHA #3. Stand back 82 stands of DP. Cut and slip Drilling Line while POOH with some weight below. 02:30 - 03:00 0.50 FISH N DPRB DECOMP At surface with BHA #3. Lay down the Cutter and inspect the Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 4 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/23/2006 02:30 - 03:00 0.50 FISH N DPRB DECOMP Knives for wear - wear seen on all three Knives. RU BHA #4 (Spear) and prepare to stab into Tubing Hanger. 03:00 - 03:30 0.50 FISH N DPRB DECOMP Stab into Tubing Hanger with BHA #4. Pick up 250K, still will not come free. Put steam on the Wellhead. Work Pipe up and down again. Pick up 270K and saw it release for a second but caught weight again. Tubing Hanger starts moving at about 205K . Pick up to 275K and still not coming. Total travel distance about 14". Re-dress Cutter (BHA #5) for next cut. 03:30 - 04:15 0.75 FISH N DPRB DECOMP RU to circulate bottoms up down the tubing. Work Pipe and pick up 105K. Circulate at 100 SPM 11250 psi. 04:15 - 04:30 0.25 FISH N DPRB DECOMP 140 bbls pumped in total. Blow down Lines. Pull on Pipe again to see if circulation cleared anything up. Pick up 250K and still not free. Pick up 275K and total travel distance of pipe about 16". Pipe started moving at about 190K. Work pipe up and down some more times to 275K with no change. Release Spear and lay down. 04:30 - 06:00 1.50 FISH N DPRB DECOMP Start RIH with BHA #5 with new Knives and 3.5" DP. Decision made to cut at 3500'. Will consult with Anchorage Engineering prior to cutting and adjust cut depth as agreed. 06:00 - 07:00 1.00 FISH N DPRB DECOMP Finish TIH with BHA #5 and 42 Stands of 3 1/2" Drill Pipe. 07:00 - 07:30 0.50 FISH N DPRB DECOMP Pick-up Kelly. Space-out Cutter to cut 7 5/8" Tubing at -4,000'. Parameters are as follows: PUW = 65K, SOW = 65K, ROTW = 65K. RPMs = 60. Benchmark psi = 55 strokes x 500 psi. Made cut in 11 minutes. Signs that the Tubing was severed were good. Had a 200 psi pressure drop. Check cut and tagged 2-ft lower. Stacked 6K on cut Stump. 07:30 - 09:00 1.50 FISH N DPRB DECOMP Set back Kelly. POOH with 3 1/2" drill Pipe and BHA #5. Lay down Cutter. 09:00 - 09:30 0.50 FISH N DPRB DECOMP Pick-up BHA #6...Spear. Plant Spear and pull Tubing Hanger 4 ft with a string weight of 125K. Tubing free at 4,000'. Land Hanger. Release Spear. 09:30 - 00:00 14.50 FISH N WAIT DECOMP Weather conditions now Phase 3 for the entire North Slope. Secure Well. Maintain Rig. 1/24/2006 00:00 - 06:00 6.00 FISH N WAIT DECOMP Phase 3 conditions. Continue to WOW. Reverse circulate the 9 5/8" x 7 5/8" Annulus and return up the 7 5/8" Tubing twice during the night to keep wellhead from slushing up. Continue to maintain Rig. Weather conditions are improving. Expect the Slope will be going to Phase 2 soon. 06:00 - 09:00 3.00 FISH N WAIT DECOMP Phase 2. Call out Drill-Site Maint. DSM dig out equipment from snow drifts and travel to location. 09:00 - 09:30 0.50 BOPSUF P DECOMP Install BPVand Dart in Tubing Hanger. 09:30 - 10:30 1.00 BOPSUF P DECOMP Change out 3 1/2" x 6" VB Pipe Rams. Install 75/8" Pipe Rams. Test. 10:30 - 12:00 1.50 BOPSUF P DECOMP Pick-up Lubricator. Pull Dart and pull BPV. Lay down same. Rig up Cameo Spooling Unit. 12:00 - 13:00 1.00 PULL P DECOMP Pick-up Spear. Plant Spear in 7" Pup Joint. Pull Tubing Hanger to Floor with no problems at 125K. Lay down Tubing Hanger and Spear Assembly. 13:00 - 17:00 4.00 PULL P DECOMP POOH and single down 75/8" Tubing in Pipe Shed. Spool Control Line. Recovered 54 Joints, SSSV Assembly. Also recovered -99%+ Control Lines and 45 SS Bands (estimate -12 Bands lost. No Band count from orginal tally). Rig down Cameo Spooling Unit. e e Printed: 4/14/2006 11 :12:22 AM e e BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/24/2006 17:00 - 20:00 3.00 PULL P DECOMP Continue POOH and single down remaining 7 5/8" Tubing to cut. Recovered total of 99 jts + 15.45' cut-off jt. Cut was very uniform & clean. 20:00 - 20:30 0.50 PULL P DECOMP RID 7 5/8" tubing handling tools. Clear & clean rig floor. 20:30 - 21 :30 1.00 PULL P DECOMP M/U treble hook & fish 13 SS bands out of BOP. Set test plug in tubing spool. 21 :30 - 22:30 1.00 BOPSUF P DECOMP Change out rams to 3 1/2" x 6" VB Rams. Function test same. Recovered 3 addtional SS bands in ram housing. Total Band recovery = 61 . 22:30 - 23:30 1.00 BOPSUF P DECOMP Pressure test rams & BOP body. LP 250 psi, HP 4000 psi. Tested Good. Charted same. 23:30 - 00:00 0.50 BOPSUF P DECOMP Pull test plug & LID same. Prep to M/U BHA #7. 1/25/2006 00:00 - 02:00 2.00 FISH N STUC DECOMP P/U & M/U 6 1/4" Spear Assy as follows: Muleshoe/Pack-off, 6 1/4" spear, Stop Sub, XO, Bumper Sub, Jars, XO 9' 4 3/4" DCs, XO, Accelerator, XO. TL = 320.20'. 02:00 - 03:30 1.50 FISH N STUC DECOMP RIH wI BHA on 3 1/2" DP. Ran 38 stands. 03:30 - 04:00 0.50 FISH N STUC DECOMP P/U kelly, break circulation. 3 BPM @ 300 psi. P/U Wt = 84k, S/O Wt = 78K. Tagged up 20' high & rotated string. Gained weight. Con't in hole & tagged top of cut @ 4001'. Engage fish & swallow 71/2'.. P/U to 100k & bleed off jars. Con't to P/U to 220k. tubing came free. P/U wt 206K. 04:00 - 05:00 1.00 FISH N STUC DECOMP Circulate bottoms up, 6 BPM @ 850 psi. Set back kelly & blow down lines. 05:00 - 08:00 3.00 FISH N STUC DECOMP POOH with 3 1/2" Drill Pipe standing back in Derrick. 08:00 - 08:30 0.50 FISH N STUC DECOMP Lay down BHA #7. Release Spear. 08:30 - 09:00 0.50 PULL P DECOMP Rig down 3 1/2" equipment. Rig up to handle 7 5/8" Tubing. 09:00 - 13:30 4.50 PULL P DECOMP POOH and single down 7 5/8" Tubing in Pipe Shed. Recovered and additional 102 Jts plus a 13.92' Cut-off Stub. Cut looked good. However, it fell back on itself and sliced the ends. Most likely from being dropped when the cut was made at 4,000'. Total Joints recovered = 202 plus the 13.92' Stub. All Tubing looked good. However, IPC shows E-Line/S-Line" tracks" where tools were run in and out of the Well on the low side. 13:30 - 15:00 1.50 FISH P DECOMP Rig down 75/8" handling equipment. Rig-up 3 1/2" handling equipment. Clear and clean floor. 15:00 - 16:00 1.00 FISH P DECOMP Make-up BHA #8 as follows: Tri-State type "B" spear, Stop Sub, XO, Bumper sub, Oil Jar, XO, Drill Collars, XO, Accelerator JAr, XO. 16:00 - 19:00 3.00 FISH P DECOMP TIH with BHA #8 and 3 1/2" Drill Pipe. 19:00 - 19:30 0.50 FISH P DECOMP P/U kelly & break circulation. 3 1/2 BPM @ 400 psi. P/U Wt = 140K, S/O Wt = 112K, Rot Wt = 125K. Tag top of cut @ 8085'. Rotate thru top of cut & swallow 6 1/2'. P/U & trip jars. wI +30KI. S/O to 10K over & rotate 13 rounds.....no release. P/U & jar w/60K over. Made 5 licks wI jars. P/U 5K over & rotate 12+ rounds & torque dropped off. Con't to rotate additional 15 turns, P/U 5' K-anchor free. 19:30-21:00 1.50 FISH P DECOMP Circulate bottoms up. 6 BPM @ 1150 psi. No losses. Set Back kelly. Blow down lines. prep to POOH. 21 :00 - 00:00 3.00 FISH P DECOMP POOH wI BHA #8. Stand back 31/2" DP. 1/26/2006 00:00 - 01 :00 1.00 FISH P DECOMP Con't to POOH & stand back 31/2" DP. 01 :00 - 01 :30 0.50 FISH P DECOMP Break out fish & LID Spear Assy. Recovered remaining cut jt, 7 5/8" pup jt, 7 5/8 x 7" X-Over. & K-Anchor. Clean floor. Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/26/2006 01 :30 - 02:30 1.00 CLEAN P DECOMP M/U BHA #9 as follows to scrape casing. 81/2" Bit, 95/8" Casing Scraper, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9' 61/4" DCs, XO, XO. TL = 312.77'. 02:30 - 06:30 4.00 CLEAN P DECOMP RIH with BHA #9...Bit and Scraper. Tag Packer at 8,115'. 06:30 - 09:00 2.50 CLEAN P DECOMP Rig up to reverse circulate. Reverse in with a 20 bbl Hi-Vis Sweep. Continue to reverse Well clean at 4.1 bpm/775 psi. with Sea Water. Recovered some scale and grit. Blow down Lines. 09:00 - 12:30 3.50 CLEAN P DECOMP POOH with 3 1/2" drill Pipe standing back in Derrick and BHA #9. 12:30 - 13:30 1.00 CLEAN P DECOMP Lay-down BHA #9. Clear and clean Floor. 13:30 - 14:30 1.00 EVAL P DECOMP Nipple down flow Nipple. Rig-up Shooting Flange. 14:30 - 15:00 0.50 EVAL P DECOMP PJSM with all. 15:00 - 16:30 1.50 EVAL P DECOMP Bring US IT Tools to floor. Rig up SWS. 16:30 - 21 :30 5.00 EVAL P DECOMP RIH with USIT Logging tool. Log from 8100 to 1300'. Top of cement @ 2274'. POOH & LId USIT log. 21 :30 - 22:30 1.00 EVAL P DECOMP RID E-line equip. 22:30 - 23:30 1.00 EVAL P DECOMP N/U adapter flange, drip pan & flow nipple. 23:30 - 00:00 0.50 EVAL P DECOMP P/U RTTS & RIH on 3 1/2" DP. 1/27/2006 00:00 - 00:30 0.50 EVAL P DECOMP Con't to RIH wI RTTS on 3 1/2" DP. 00:30 - 01 :00 0.50 EVAL P DECOMP Set RTTS @ 2315'. 01 :00 - 02:00 1.00 EVAL P DECOMP RlU test equip. Pressure up & test 9 5/8" casing from 2315 to TTP @ 8133'. Tested to 4000 psi for 30 min.Tested good. Charted test. RID test equip. Blow down lines. 02:00 - 03:30 1.50 EVAL P DECOMP Unset RTTS & POOH. LID RTTS. 03:30 - 06:30 3.00 CASE P DECOMP P/U RBP & setting tool. RIH on 3 1/2" DP. 06:30 - 07:00 0.50 CASE P DECOMP Set Halco RBP with center element at 3,986'. Top of RBP at 3,981'. Pull 1 Stand of Drill Pipe. 07:00 - 08:30 1.50 CASE P DECOMP Dump 1,500 Ibs of 20/40 mesh Sack Sand. Flush Drill Pipe. WOS. 08:30 - 09:00 0.50 CASE P DECOMP Run 1 Stand of Drill Pipe back in and tag TOS at 3,951'. Pull 1 Stand of drill Pipe. 09:00 - 11 :00 2.00 CASE P DECOMP Start to displace Sea Water in 9 5/8" casing with 9.8 Iblgal Brine at 4.0 bpm/500 psi. 11 :00 - 14:00 3.00 CASE N WAIT DECOMP Wait on additional 9.8 Brine to complete the displacement. Vac trucks and MI Mud Plant delays. (load and tally 9 5/8" Casing in Pipe Shed) 14:00 - 16:00 2.00 CASE P DECOMP Finish displacing 9 5/8" Casing with 9.8 Ib Brine at 4.0 bpm/500 psi. 16:00 - 17:00 1.00 CASE P DECOMP POOH & stand back 31/2" DP. 17:00 - 17:30 0.50 CASE P DECOMP LID setting tool. Clear & clean rig floor. 17:30 - 19:00 1.50 CASE P DECOMP P/U BHA # 10 to cut casing as follows: 81/4" Multi-String cutter, X-over, Stabilizer, X-over. TL = 12.55'. 19:00 - 21 :00 2.00 CASE P DECOMP RIH wI BHA #10 on 3 1/2" DP. P/U kelly & locate collar @ 2173'. 21 :00 - 22:00 1.00 CASE P DECOMP Space out & cut 95/8" casing @ 2195'. P/U Wt = 41K, S/O Wt = 40K, Rot Wt =141K. Pump 3.5 BPM @ 500 psi. 60 RPMs, Torq = 60 Amps. Cut for 1/2 hr. P/U & set back down & verify cut. Good indication, took weight. Plu 5' & close in annular. Break circulation thru annulus. 22:00 - 00:00 2.00 CASE P DECOMP Circulate & displace Arctic Pack out annulus. Pump 1 BPM 500 psi. Pump displacement fluid as follows: 40 bbls of Safe Surf "0",65 Bbbls 9.8 Brine, 75 Bbbls of Diesel, 40 Bbls of Safe e e Printed: 4/14/2006 11 :12:22 AM e e BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/27/2006 22:00 - 00:00 2.00 CASE P DECOMP Surf "0", 75 Bbls of Diesel. All fluids were heated to + 120 Degrees. This was followed by 170 bbls of heated 9.8 ppg Brine. SID & monitor well. 1/28/2006 00:00 - 06:00 6.00 CASE P DECOMP Con't to to displace out Arctic Pack alternating wI hot diesel & Safe Surf "0". Shut down & allow to soak. Then Displace entire annular volume to 9.8 ppg Brine 5.5 BPM @ 1400 psi.. SID & monitor well. Well Static. 06:00 - 07:30 1.50 CASE P DECOMP Set back Kelly. POOH with 3 1/2" Drill Pipe and BHA #10. 07:30 - 08:00 0.50 CASE P DECOMP Lay down BHA #10. Clear Floor. 08:00 - 08:30 0.50 BOPSUF P DECOMP Set Test Plug 08:30 - 14:00 5.50 BOPSUF P DECOMP Rig-up Test Equipment. Test BOPE perf BP/AOGCC requirements at 250/4000 psi. Test Hydril at 250/3500 psi. The State's right to witness the Test was waived by C. Sheve. 14:00 - 15:00 1.00 BOPSUF P DECOMP Change 3 1/2" x 6" VB Pipe Rams. Install 95/8" Pipe Rams. Body Test. 15:00 - 15:30 0.50 BOPSUF P DECOMP Brain stack. Pull Test Plug. Blow down Lines. 15:30 - 16:30 1.00 CASE P DECOMP Rig up equipment to handle 9 5/8" Casing. BOLDS. 16:30 - 17:00 0.50 CASE P DECOMP Make-up BHA #11...Spear Assembly. 17:00 - 18:30 1.50 CASE P DECOMP PJSM. Plant Spear. Pulled Casing Hanger free at 180K. Pulled to floor at 11 OK with no problems. ( Recovered 1 Control Line Band). LID hanger. M/U head pin in 95/8" casing. 18:30 - 21 :30 3.00 CASE P DECOMP Circulate well. 6 BPM @ 250 psi. Well appeared to clean up & then more gassy Arctic Pack came to surface. Circulated until hole remained clean. RID circulating equip. 21 :30 - 00:00 2.50 CASE P DECOMP RlU, POOH & LID 9 5/8" casing. Casing has a minimum of 1/4" skin of Arctic Pack on casing surface. Centralizers coming out intact. 1/29/2006 00:00 - 04:00 4.00 CASE P DECOMP Con't to POOH & LID 9 5/8" casing. Centralizers coming out intact. Check break out torq on 10 jts of csg. Torq 6000- 11000 ft-Ibs. Average 9300 ft-Ibs. Recovered total of 54 jts + 25.35' cutoff. Cut looked good. Recovered 11 centralizers. 04:00 - 06:00 2.00 CASE P DECOMP Clear & clean rig floor. RID casing tools. 06:00 - 06:30 0.50 CASE P DECOMP Lub Rig. Inspect Derrick. 06:30 - 08:30 2.00 BOPSUF P DECOMP Set Test Plug. Change 9 5/8" Pipe Rams. Install 3 1/2" x 6" VB Pipe Rams. Test. Drain Stack. Pull Test Plug. 08:30 - 09:30 1.00 CASE P DECOMP Pick-up BHA #11 Spear Assembly and break-out from Casing Hanger. Lay down same. 09:30 - 11 :00 1.50 CASE P DECOMP Make-up BHA #12 as follows: 12 1/4" Shoe, 11 3/4" Wash Pipe, WP Boot Basket, P x P XO, 13 3/8" Casing Scraper, XO, 2 ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, XO, 9 ea Drill Collars, 2 ea XOs. 11 :00 - 13:00 2.00 CASE P DECOMP Start RIH with BHA #12 and 3 1/2" Drill Pipe. Stop to reverse circulat out more Arctic Pack. 13:00 - 16:00 3.00 CASE P DECOMP Continue RIH slowely to keep fluids from surging out Drill Pipe. 16:00 - 17:00 1.00 CASE P DECOMP P/U kelly. Break circulation, 5 BPM @ 620 psi. Slowly wash down & tag casing stub @ 2195'. 17:00 - 18:00 1.00 CASE P DECOMP Wash down over casing stub & collar + 9' to 2221'.5 BPM @ 620 psi. Collar @ 2212'. 18:00 - 20:30 2.50 CASE P DECOMP Close in bag & reverse circulate well clean. Pump 40 bbl Hi-Vis pill & sweep hole. 6 BPM @ 810 psi. 20:30 - 21 :30 1.00 CASE P DECOMP POOH wI BHA # 12 on 3 1/2" DP. 21 :30 - 00:00 2.50 CASE P DECOMP Break out & LID BHA #12. 1/30/2006 00:00 - 00:30 0.50 CASE P DECOMP Finish LID BHA #12. Printed: 4/14/2006 11 :12:22 AM - e BP EXPLORATION Operations Summary Report Page 8 of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-04 WGI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/18/2006 Rig Release: 4/2/2006 Rig Number: Spud Date: 9/29/1979 End: 4/2/2006 Date From - To Hours Task Code NPT Phase Description of Operations 1/30/2006 00:30 - 01 :30 1.00 CASE P DECOMP Clean out junk basket. Clear & clean rig floor. 01 :30 - 04:00 2.50 CASE P DECOMP M/U BHA #13 to back off casing as follows: Bull Nose, XO, 9 - Drill Collars, XO, Blank Sub, Lower Anchor, Power Section, Upper Anchor, XO, XO. TL = 317.75'. 04:00 - 06:00 2.00 CASE P DECOMP RIH wI BHA # 13. Filled 4 stands wI Diesel. 06:00 - 07:30 1.50 CASE P DECOMP Set Back-off Tool to straddle 9 5/8" connection at 2,212'. Attempted to break connection several times at the Tool's deliverable max torque of 50,000 ftllbs. No-joy. 07:30 - 09:30 2.00 CASE P DECOMP POOH with 3 1/2" Drill Pipe and BHA #13. 09:30 - 10:30 1.00 CASE P DECOMP Lay down BHA #13. Inspect Tool. Tool appeared to have worked properly (pins sheared). 10:30 - 11 :30 1.00 CASE P DECOMP Clear and clean Rig Floor while waiting for SWS e-line to arrive on Location. (Also had crew watch safety video on Fall Protection). SWS arrive on Location and spot Unit. 11 :30 - 12:00 0.50 CASE P DECOMP Nipple-down Flow Nipple. Nipple-up Shooting Flange. 12:00 - 14:30 2.50 CASE P DECOMP PJSM with All. Rig-up SWS E-line to run String-Shot. RIH, correlate & fire string shot @ 2217'. POOH. RId E-line equip. 14:30 - 15:00 0.50 CASE P DECOMP NID shooting nflange. N/U flow nipple. 15:00 - 16:00 1.00 CASE P DECOMP M/U BHA # 14 to back off casing as follows: Bull Nose, XO, 9- Drill Collars, XO, Blank Sub, Lower Anchor, Power Section, Upper Anchor, XO, XO, TL = 317.75 16:00 - 18:30 2.50 CASE P DECOMP RIH wI BHA # 14 on 3 1/2" DP. Fill 4 stands wI Diesel. Fill remainder wI 9.8 ppg. 18:30 - 20:00 1.50 CASE P DECOMP M/U head pin. Space out tool to straddle 2212'. Pressure up & set Lower Anchor wI 1200 psi. S/O 20K wt. P/U & set Upper Anchor wI 4500 psi. bleed off & cycle tool. pressure up to 1200 psi & connection turned. Cycle tool 9 times & got 6 full revolutions. P/U & pull free. 20:00 - 21 :30 1.50 CASE P DECOMP POOH wI BHA #14 & stand back 3 1/2" DP. 21 :30 - 23:00 1.50 CASE P DECOMP Break out & LID BHA # 14. 23:00 - 00:00 1.00 CASE P DECOMP Clear & clean rig floor. 1/31/2006 00:00 - 01 :00 1.00 CASE P DECOMP M/U BHA #15 to recover csg stub as follows: Bull Nose, Spear wI 8.681" grapple, Spear Extension, Stop Sub, Bumper Sub, XO. TL = 20.24'. 01 :00 - 02:00 1.00 CASE P DECOMP RIH wI BHA #15 on 3 1/2" DP. 02:00 - 02:30 0.50 CASE P DECOMP Engage spear into casing stug. Make 8 revolutions to the left. P/U & casing cutoff is free. P/U Wt - 40K, S/O Wt = 40K. 02:30 - 03:30 1.00 CASE P DECOMP POOH wI BHA #15 on 3 1/2" DP. 03:30 - 04:00 0.50 CASE P DECOMP Break out cutoff jt. Inspect threads threads look good. screwed on collar.. no problem. Recovered 16.22' cutoff wI pin end.. LID BHA #15. ( Note: Collar looking up down hole). 04:00 - 05:00 1.00 CASE P DECOMP Clear & clean rig floor. 05:00 - 07:30 2.50 BOPSUF P INTERV Set test plug. Pull 3 1/2" x 6" VB rams & install 9 5/8" Casing Rams. Body test. Drain Stack. Pull Test Plug. 07:30 - 08:30 1.00 CASE P INTERV PJSM with All. Rig up equipment to handle 9 5/8" Casing. 08:30 - 09:00 0.50 CASE P INTERV Make-up Shoe Track as follows: Triple Connect 9 5/8" Screw-in-Sub wlPin end, HES Baffle Collar wlPlug installed, 9 5/8" L-80 BTC Pup Joint, HES 9 5/8" ES Cementer pinned at 2,750 psi, 9 5/8" 47 Iblft L-80 BTC pin x TCII Box XO Joint wlFF Centralizer. All shoe Track connections Baker-Loc applied to threads. 09:00 - 15:00 6.00 CASE P INTERV Single in with 9 5/8" 47 Iblft L-80 TCII Casing from Pipe Shed. Threads doped with Jet Lube Sealguard and the make-up Printed: 4/14/2006 11 :12:22 AM e e BP EXPLORATION Operations Summary Report Page 9 of19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-04 WGI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/18/2006 Rig Release: 4/2/2006 Rig Number: Spud Date: 9/29/1979 End: 4/2/2006 Date From - To Hours Task Code NPT Phase Description of Operations . 1/31/2006 09:00 - 15:00 6.00 CASE P INTERV torque = 17,500 ftllbs. Installed one free-floating centralizer on each Joint. 52 jts total run. 15:00 - 16:30 1.50 CASE P INTERV PJSM. Make up TC II pin x Btc box crossover & 15' Btc pup. 97K up wt, 100 K down. Tag up 41/2' in, rotate wI tongs, popped over, run in another 4' & take wt. Screw into 9 5/8" casing wI 2-5K on collar. Make 13 turns, final torque 10,000 ftllbs. Work torque down. Pull test to 250K , OIK. 16:30 - 18:00 1.50 CEMT P INTERV PJSM. Rig up cementing head & cementers. 18:00 - 19:00 1.00 CEMT P INTERV Hold PJSM wI all hands & discuss cement job. 19:00 - 00:00 5.00 CEMT P INTERV Diesel temp is below freezing. Called Hot oilers to heat diesel to 60-70 degrees to avoid flash set & freezing. Started to heat diesel & Hot oil truck broke down. Called & waited for 2nd truck & heated fluid. 2/1/2006 00:00 - 00:30 0.50 CEMT P INTERV Finish heating Diesel to 60-70 degrees for Cementing. 00:30 - 02:30 2.00 CEMT P INTERV Cement 9 5/8" Tie-back string as follows: Pump 2 bbls & pressure test lines to 4000 psi, Ok. Pump 25 bbls of brine @ 6-10 BPM, 550 psi. Open ES cementer wI 1500 psi.. Pump 110 bbls of Diesel 4-7 BPM @ 575 psi. Mix & pump 35 bbls of Arctic Set II cement @ 5 BPM @ 800 psi. SID Clear lines & drop plug. Displace plug w/1 0 bbls of fresh water followed by 151 bbls of 9.8 ppg brine @ 4-6 BPM. Final pressure 200 psi. Bumped plug & shut ES cementer wI 1450 psi. Open well ES Cementer holding. CIP @ 0210 Hrs. Had diesel returns to surface. 02:30 - 03:30 1.00 CEMT P INTERV Blow down lines. RID cementing equip. 03:30 - 05:30 2.00 BOPSUF P INTERV Suck out 9 5/8" casing. Drain BOP stack. NID & P/U BOPE & 13 5/8" spool. 05:30 - 06:00 0.50 WHSUR P INTERV Set emergency slips wI 150 K. 06:00 - 07:30 1.50 WHSUR P INTERV PJSM. Rig up WACHS casing cutter & cut 9 5/8" casing. 07:30 - 08:30 1.00 WHSUR P INTERV LID cut off joint, break out crossover, clear I clean rig floor. 08:30 - 10:00 1.50 WHSUR P INTERV PJSM. NID casing spool from BOPE. Attempt to install secondary seal over 9 5/8" casing stub...., would not fit. 10:00 - 13:00 3.00 WHSUR N SFAL INTERV Cut off 2' section of the 9 5/8" casing that was laid down & sent wI pack off to maching shop. 9 5/8" casing was slightly egged & approximately .060" over on the OD. Baker Machine modified ID of pack off as nessacery. 13:00 - 16:00 3.00 WHSUR P INTERV PJSM. Install upper & lower packoff. N/U tubing spool. Pressure test pack off to 3800 psi I OK. 16:00 - 17:00 1.00 BOPSUF P INTERV N/U BOPE. Load pipe shed wl7 5/8" tubing. 17:00 - 17:30 0.50 BOPSUF P INTERV Install test plug. 17:30 - 18:00 0.50 BOPSUF P INTERV Change out rams to 3 1/2" x 6" VB rams. 18:00 - 19:00 1.00 BOPSUF P INTERV Pressure test VB rams & BOP body. Lp 250 psi, Hp 4000 psi. test good. Charted same. 19:00 - 19:30 0.50 BOPSUF P INTERV RID test equip. Pull test plug. Install Wear Bushing. 19:30 - 21:00 1.50 CLEAN P INTERV RlU 3 1/2" DP tools. P/U & M/U BHA #16 as follows:P 81/2" Bit, 2 Boot Baskets, Bit Sub, Jars, XO, 9 - Drilll Collars, XO, XO. TL= 300.26'. 21 :00 - 23:00 2.00 CLEAN P INTERV RIH wI BHA # 16 on 3 1/2" DP. Tag up @ 2178'. 23:00 - 00:00 1.00 CLEAN P INTERV Displace hole wI 50 degree seawater. 5 BPM @ 350 psi. 2/2/2006 00:00 - 02:00 2.00 CLEAN P INTERV Drill out cement track from 2178' to 2211'. Con't in wI remaining kelly to 2231'. P/U Wt = 57K, S/O Wt = 54K, Rot Wt = 57K. 5 1/2 BPM @ 400 psi. 90 RPMs, 4-6K WOB, 2-4K. 02:00 - 03:00 1.00 CLEAN P INTERV Circulate & pump 40 bbl Hi-Vis sweep & clean hole. 6 BPM @ Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2006 02:00 - 03:00 1.00 CLEAN P INTERV 380 psi. 03:00 - 05:00 2.00 CLEAN P INTERV RlU test equip. Close rams & pressure test casing to 4000 psi for 30 min. Pressure leaked off 300 psi in 30 min. Final attempt leaked off 100 psi in 15 min. No test. Will re-test when out of hole wI blind rams. 05:00 - 07:00 2.00 CLEAN P INTERV POOH & LID BHA # 16. 07:00 - 08:30 1.50 CLEAN N DPRB INTERV PJSM. Close blind rams & pressure up 9 5/8" casing from surface to top of sand @ 3951' @ 4000 psi. Not holding, slight trickle up 0/A. Bleed off all pressure. 08:30 - 10:00 1.50 CLEAN N DPRB INTERV PJSM. Test Grey 9 5/8" x 13 5/8" pack off, no test. Tighten gland nuts & retest @ 3800 psi. 15 minutes, OK. 10:00 - 11 :30 1.50 CLEAN N DPRB INTERV PJSM. Close blind rams, test 9 5/8" casing from surface to top of sand @ 3951' @ 4000 psi. Not holding. Slight trickle of diesel form O/A as before. Bled 150 psi in 15 minutes. 11 :30 - 14:00 2.50 CLEAN N DPRB INTERV PJSM. Rig up & test 9 5/8" x 13 5/8" Grey pack off void as before @ 3900 psi, 30 minutes. Pressure up on 95/8" casing @ 4000 psi. No indication of communication to pack off void. Still bleeding off slowlly & slight trickle of diesel out of O/A. Bled 150 psi 1st 15 minutes, & 100 psi 2nd 15 minutes. No Good. Bleed all pressure. Reposition chart recorder & restest wI same results. 14:00 - 16:30 2.50 CLEAN N DPRB INTERV PJSM. M/U (9) 6 1/4" DCs & Halliburton RTTS & set approximately 20' below wellhead. Attempt to test, no good, circulating valve not closed. Pull RTTS to surface & remove circulating valve. RBIH & set approximately 14' below wellhead. 16:30 - 18:30 2.00 CLEAN N DPRB INTERV PJSM. Close pipe rams & pressure up from surface to top of RTTS to 4000 psi. Slight leak in ram doors on BOPE. Bleed off pressure & tighten ram doors. 18:30 - 19:30 1.00 CLEAN N DPRB INTERV Presuure up on RTTS @ 14' below wellhead. Test for 30 min. Tested good charted same. 19:30 - 21 :30 2.00 CLEAN N DPRB INTERV Pressure up down drill pipe from 14' below wellhead to sand on top of RBP. Could not get test bled off from 4000 psi to 3700 psi in 30 min. Made several attempts. Check for leaks, none @ surface. Diesel flowing out 13 3/8 x 9 5/8" annulus. Stops when pressure is bled off. 21 :30 - 23:00 1.50 CLEAN N DPRB INTERV Unset RTTS. POOH & inspect RTTS, OK. RIH to 1708' wI RTTS. 23:00 - 00:00 1.00 CLEAN N DPRB INTERV Circulate well wI seawater. Had some ice in returns. 2 1/2 BPM @ 90 psi. 2/3/2006 00:00 - 02:00 2.00 CLEAN N DPRB INTERV Set RTTS @ 1708'. Pressure up on RTTS from surface to 1708', 95/8" annulus to 4000 psi. Pressure bled off 100 psi in 10 min. 133/8" x 9 5/8" annulus flowed when pressued up. No test. Pressure up down drill pipe, below RTTS from 1708' - RBP to 4000 psi. Pressure bled off 300 psi in 15 min. NO FLOW OUT ANNULUS. Could not find any leaks @ surface. Attemped several times. Test no good. 02:00 - 02:30 0.50 CLEAN N DPRB INTERV RIH w RTTS to 2281' 02:30 - 03:30 1.00 CLEAN N DPRB INTERV Set RTTS @ 2281'. Pressure up down DP , below RTTS to 4000 psi. for 30 min. Tested Good. 03:30 - 04:00 0.50 CLEAN N DPRB INTERV Unset RTTS. Circulate well & warm wellbore. 04:00 - 06:00 2.00 CLEAN N DPRB INTERV POOH wI RTTS on 3 1/2" DP. LID RTTS & stand back DCs. 06:00 - 08:30 2.50 EVAL N DPRB INTERV PJSM. Rig up Schlumberger Eline. e e Printed: 4/14/2006 11:12:22AM BP EXPLORATION Page 11 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2006 08:30 - 12:00 3.50 EVAL N DPRB INTERV Run USIT log. Log indicates top of cement @ 1550' (+ -). 12:00 - 15:00 3.00 EVAL N DPRB INTERV PJSM. Rig down Schlumberger E line. Rig up flow nipple. 15:00 - 16:00 1.00 EVAL N DPRB INTERV PJSM. Pick up (9) 6 1/4" DCs & Halliburton RTTS. 16:00 - 17:30 1.50 EVAL N DPRB INTERV PJSM. RIH wI Halliburton 95/8" RTTS on 3 1/2" DP to 2300', 17:30 - 18:30 1.00 EVAL N DPRB INTERV Displace well to 9.8 ppg brine. pumped 4 BPM @ 250 psi. 18:30 - 20:00 1.50 EVAL N DPRB INTERV Set RTTS @ 2310' w/58K down. Presuure up DP & test below RTTS @ 2310' to 4000 psi for 30 min. Test good. 133/8" x 9 5/8" Annulus = 0 psi. Charted test. 20:00 - 23:00 3.00 EVAL N DPRB INTERV POOH to 2085'.2 stands of DP + single. Set RTTS w/54K down Wt. Pressure up drill pipe & test below RTTS @ 2085'. Pressured up to 4000 psi, Bled off, Re-pressure 2 more times & ran test for 30 min. Pressure bled from 4100 psi to 3220 psi in 30 min. No Test!. 133/8" x 9 5/8" Annulus pressure increased from 0 psi to 350 psi.. Bled off all pressures & Re-tested. Pressured up down DP & tested below RTTS @ 2085'. Pressure bled off from 4100 psi to 3250 in 30 min. 13 3/8" x 9 5/8" Annulus pressure increased from 0 to 800 psi. No Test!. Called enginer ( Dave Reem) & received orders to abandon operations after confirmation test @ 2310'. 23:00 - 00:00 1.00 EVAL N DPRB INTERV RIH to 2310'. Re-set RTTS. Began pressure test. 2/4/2006 00:00 - 00:30 0.50 EVAL N DPRB INTERV Pressured up down DP & tested below RTTS @ 2310'. Pressure bled off 50 psi in 12 min then flat lined @ 4000 psi for the next 25 min. Test good. 133/8" x 9 5/8" annulus remained @Opsi. 00:30 - 02:00 1.50 EVAL N DPRB INTERV Unset & equalize RTTS. POOH wI RTTS & stand back DP. LID RTTS. 02:00 - 03:00 1.00 EVAL N DPRB INTERV RIH wI 35 stands of DP & 6 1/4" DCs. 03:00 - 06:00 3.00 EVAL N DPRB INTERV POOH & LDDP. 06:00 - 09:00 3.00 EVAL N DPRB INTERV PJSM. RIH wI remaining DP in derrick. 09:00 - 13:00 4.00 EVAL N DPRB INTERV PJSM. POOH & LID drill pipe. 13:00 - 15:30 2.50 TA N DPRB INTERV PJSM. Pull wear bushing. Strap $ 1/2" Btc kill string. Prepare floor to run kill string. 15:30 - 18:00 2.50 TA N DPRB INTERV PJSM. M/U WLEG, pup, "X" Nipple, pup & RIH on 4 1/2" 12.6# L-80 IBT tubing, torquing connections to 3000 (+ -) ftllbs...to middle of knurl. Ran total of 56 jts. 18:00 - 20:30 2.50 TA N DPRB INTERV Plu landing jt. Wait on hanger. 20:30 - 21 :30 1.00 TA N DPRB INTERV M/U hanger into landing jt. Land kill string. RILDS. 21 :30 - 22:30 1.00 TA N DPRB INTERV Set TWC. Test same to 1000 psi. 22:30 - 00:00 1.50 TA N DPRB INTERV NID BOPE. 2/5/2006 00:00 - 00:30 0.50 TA N DPRB INTERV Finish NID BOPE. 00:30 - 03:30 3.00 TA N DPRB INTERV Hold PJSM. N/U adapter flange & tree. Test hanger void to 5000 psi for 30 min. Tested Good. 03:30 - 04:00 0.50 TA N DPRB INTERV Fill tree wI diesel & tested tree to 5000 psi, Tested Good. 04:00 - 05:00 1.00 TA N DPRB INTERV Wait on DSM to pull TWC. P/U lubricator & pull TWC. LID same. 05:00 - 07:00 2.00 TA N DPRB INTERV RlU Hot oilers, test lines & pump Diesel Freeze protect, 175 bbls, circulate down 95/8" x 41/2", taking returns up 4 1/2" tbg, see diesel returns up tubing. 07:00 - 09:00 2.00 TA N DPRB INTERV PJSM. Pick up lubricator, set BPV, lay down lubricator. Secure well. Rig released @ 09:00 hrs, 02/05/2006. 312012006 03:00 - 06:00 3.00 MOB P PRE Move Rig and Equipment from WGI-03 to WGI-04. 06:00 - 08:00 2.00 RIGU P PRE Spot Sub Base. Needed to use D-9 Cat to help get e e Printed: 4/14/2006 11:12:22AM e e BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/20/2006 06:00 - 08:00 2.00 RIGU P PRE Substructure up on gravel/mat-board Pad., Spot Pits and Pipe Shed. 08:00 - 10:00 2.00 RIGU P PRE Raise and scope Derrick. Accept Rig at 10:00 hrs. 10:00 - 16:30 6.50 PULL N WAIT DECOMP Wait on Drill-Site Maint to pull BPV. The Crew is on stand-by at Endicott and they will not release them. 16:30 - 17:00 0.50 PULL P DECOMP DSM Night Crew on location. Rig-up Lubricator. Pull PBV. Lay down same. 17:00 - 18:00 1.00 PULL P DECOMP Circulate out diesel freeze protection with hot 9.8 ppg brine taking returns to Tiger Tank. Pumped brine at 5.4 bpm 1280 psi. Monitor well dead. 18:00 - 18:30 0.50 PULL P DECOMP RU Lubricator and set BPV with DSM. Pressure test to 1000 psi - good. 18:30 - 20:00 1.50 PULL P DECOMP Nipple Down Tree and Adapter Flange. Call out Cameron. Notified AOGCC of upcoming BOPE test. 20:00 - 23:00 3.00 PULL P DECOMP Cameron set Dart in BPV. Well is secure. Begin to Nipple Up BOP Stack. 23:00 - 00:00 1.00 BOPSUF P DECOMP Rig up Test Equipment. Begin BOPE test per BP I AOGCC Requirements. Test the BOPE to 250 psi low and 4000 psi high. Test the Annular to a high test of 3500 psi. State's right to witness the test was waived by Lou Grimaldi. 3/21/2006 00:00 - 06:00 6.00 BOPSUF P DECOMP Continue testing BOPE per BP I AOGCC requirements. Test BOPE to 250 psi low and 4000 psi high. Test Annular to a high test of 3500 psi. State's right to witness the test was waived by Lou Grimaldi. Having problems holding any pressure at all. Cannot even get a low pressure test to hold without leaking. Same issues with test as first time on the well. Called Slickline PE's at 02:30 hours to give heads up that we may need a Plug in the 4 1/2" Kill String (Tubing) to test BOPE. Continue to diagnose all test equipment for potential problems. 06:00 - 11 :00 5.00 BOPSUF P DECOMP Sort out problems. Perform BOPE Test per BP/AOGCC requirements at 250/4000 psi. Good test. State's right to witness test waived by L Grimaldi. Blow down Lines. Rig down test equipment. 11 :00 - 14:30 3.50 BOPSUF N WAIT DECOMP Wait on Drill Site Maint. Crew on other jobs. 14:30 - 15:30 1.00 BOPSUF P DECOMP Pick-up Lubricator. Pull BPVIDart assembly. Lay down same. 15:30 - 16:00 0.50 PULL P DECOMP Pick-up Landing Joint. Pull Hanger to floor with no problems. 16:00 - 19:00 3.00 PULL P DECOMP POOH & LID 4 1/2" kill string. 19:00 - 20:00 1.00 PULL P DECOMP RID 4 1/2" handling tools. R/U tools to P/U & run 3 1/2" DP. Clear & clean rig floor. 20:00 - 21 :00 1.00 PULL P DECOMP Hold PJSM. P/U & M/U cutting assy as follows: 8 1/4" cutter wI 11" knives, X-Over Sub, 8 7/16" stabilizer, X-Over Sub. TL = 10.22'. RIH wI same. 21 :00 - 22:00 1.00 PULL P DECOMP P/U 3 1/2" DP, 1x1 & RIH wI cutting assy to 1396'. 22:00 - 23:00 1.00 PULL P DECOMP P/U kelly & attempt to locate collars to cut @ 1425'. No luck in finding TCII connections. Attempted @ 2 BPM, 300 psi & 3 BPM, 450 psi. Now plan to locate collars @ 2200' & correlate back. 23:00 - 00:00 1.00 PULL P DECOMP P/U 3 1/2" DP 1x1 & RIH to 2190'. 3/22/2006 00:00 - 00:30 0.50 PULL P DECOMP P/U kelly Break circulation, 2 BPM @ 350 psi. Located collars @ 2196 ( ES Cementer), 2198 (Pup Jt) & 2209 ( Baffle Collar) DPM. Drill pipe measurement l' shallow to loggers depth. 00:30 - 01 :00 0.50 PULL P DECOMP POOH & stand back DP to 1396'. 8 stands + 1 single. Printed: 4/14/2006 11 :12:22 AM e e BP EXPLORATION Operations Summary Report Page 130f 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: WGI-04 WGI-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1/18/2006 Rig Release: 4/2/2006 Rig Number: Spud Date: 9/29/1979 End: 4/2/2006 Date From - To Hours Task Code NPT Phase Description of Operation$ 3/22/2006 01 :00 - 01 :30 0.50 PULL P DECOMP P/U kelly & space out DP to 1424' Break circulation & cut 9 5/8" casing @ 1424' DPM. 4 1/2 BPM @ 1300 psi. 60 RPMs, Torq 60-150 amps. cut tubing in 6 min. Con't to insure good clean cut for 15min.. S/O & took weight @ cut. P/U 6' Lower, re-tag & confirm cut. P/U Wt = 34K, S/O Wt = 34K, Rot Wt = 33K. 01 :30 - 02:30 1.00 PULL P DECOMP Set back kelly. Install TIW valve. Close annular & circulate well. Displace diesel out 9 5/8" x 13 3/8" annulus. Pumped total of 100 bbls of 9.8 ppg. 4.5 BPM @ 240 psi. Confirmed 9.8 Brine returns. SID & monitor well, Blow down lines. 02:30 - 03:30 1.00 PULL P DECOMP POOH & stand back 3 1/2" DP. 03:30 - 06:00 2.50 PULL P DECOMP Hold PJSM. Drain BOP stack. Break Tubing head from casing head. set back BOP. Remove pack off. 06:00 - 07:00 1.00 PULL P DECOMP Set BOP Stack back on Well head. Test to 2,000 psi. 07:00 - 08:30 1.50 BOPSUF P DECOMP Pull VBPRs and install 95/8" Pipe Rams. Test at 2,000 psi. 08:30 - 09:30 1.00 CASE P DECOMP Rig up 9 5/8" Casing handling equipment. 09:30 - 10:00 0.50 CASE P DECOMP Pick-up Spear assembly w/8.681" Grapple. 10:00 - 10:30 0.50 CASE P DECOMP Plant Spear and pull Casing free at 75K. Lay down 9 5/8 Slips and Spear. 10:30 - 13:00 2.50 CASE P DECOMP Single down 95/8" 47 Iblft L-80 TCII Casing as follows: Top cut-off = 24.95', 33 Joints, bottom cut-off stub = 27.83'. Top of 95/8" Stump now at 1,430'. 13:00 - 14:00 1.00 CASE P DECOMP Rig down 9 5/8" Casing handling equipment. 14:00 - 15:00 1.00 CASE P DECOMP Clear and clean Floor. Rig up to handle Drill Collars and 3 1/2" Drill Pipe. 15:00 - 16:00 1.00 BOPSUF P DECOMP Install Test Plug. Pull 9 5/8" Pipe Rams. Install 3 1/2" x 6" VBPRs. Test at 2,000 psi. 16:00 - 16:30 0.50 BOPSUF P DECOMP Drain BOP stack. Pull test plug. 16:30 - 18:00 1.50 BOPSUF P DECOMP Load, tally & P/U 9' 6 1/4" DCs. RIH wI same. 18:00 - 19:00 1.00 BOPSUF P DECOMP M/U Back off assy as follows: Bull Nose, XO, 9' 6 1/4" Des, XO, Blanking Sub, Power Unitwl T & B slip Sec., XO, XO. TL = 317.62'. RIH wI same & fill wI diesel. 19:00 - 20:30 1.50 BOPSUF P DECOMP RIH wI BHA to back off casing. Fill every 5 stands. 20:30 - 22:30 2.00 BOPSUF P DECOMP Space out, fill String & P/U kelly. Set upper blocks @ 1437' & lower blocks @ 1464'. Pressure up & break connectionw/21 K torq at 1,444'. Back off casing threads 6118 revolutions. Unset Tool. 22:30 - 23:30 1.00 BOPSUF P DECOMP Set back kelly. Blow down lines & POOH wI Back off Assy. Pulling wet. 23:30 - 00:00 0.50 BOPSUF P DECOMP Inspect, break out & LID Back off BHA 3/23/2006 00:00 - 01 :00 1.00 BOPSUF P DECOMP Finish Break out & LID Back off BHA. 01 :00 - 02:00 1.00 CASE P DECOMP Clear & clean rig floor. 02:00 - 02:30 0.50 CASE P DECOMP M/U Spear Assy & bumper sub. RIH. 02:30 - 03:00 0.50 CASE P DECOMP RIH wI Spear Assy on 3 1/2" DP. 03:00 - 03:30 0.50 CASE P DECOMP P/U Wt = 34K, S/O Wt = 34K. P/U kelly & engage spear into 9 5/8" casing stub @ 1424'. Back out 2 full turns. 03:30 - 04:30 1.00 CASE P DECOMP Lost power to drawworks. Work on rig electical system to assign drwworks power. 04:30 - 05:00 0.50 CASE P DECOMP P/U & verify fish is free. Set back kelly & blow down lines. 05:00 - 06:00 1.00 CASE P DECOMP POOH wI casing stub. 06:00 - 06:30 0.50 CASE P DECOMP Lub Rig. Inspect Derrick. 06:30 - 07:00 0.50 CASE P DECOMP Lay down Casing Stump = 14.28' ( recovered pin end) and Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 14 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/23/2006 06:30 - 07:00 0.50 CASE P DECOMP Spear. Now have a 9 5/8" Box looking up with a Centralizer setting on top of the box at 1,444'. 07:00 - 08:00 1.00 CASE P DECOMP Make-up short catch Spear to fish Centralizer as follows: 08:00 - 08:30 0.50 CASE P DECOMP TIH with BHA and 3 1/2" Drill Pipe and set down on Centralizer at 1,444'. 08:30 - 09:00 0.50 CASE P DECOMP POOH with Drill Pipe BHA and Centralizer. 09:00 - 09:30 0.50 BOPSUF P DECOMP Drain Stack and install Test Plug. 09:30 - 10:00 0.50 BOPSUF P DECOMP Swap 31/2" VBPRs and install 9 5/8" Pipe Rams 10:00 - 10:30 0.50 BOPSUF P DECOMP Test to 2,000 psi. Pull test plug. 10:30 - 12:30 2.00 CASE P DECOMP Clear and clean Floor. Rig-up 9 5/8" Casing handling equipment. Rig-up Torque Turn equipment. 12:30 - 18:00 5.50 CASE P DECOMP Run 9 5/8" Tie-back string as follows: Baker Screw-in Sub, HES Baffle Plate wlPlug on seat, 95/8" Pup with 2' of Cement in place, HES ES-Cementer, 9 5/8" XO Joint. Ran 35 jts. TL .=1451.19'. 18:00 - 21 :00 3.00 CASE P DECOMP Space out & Tag up on stub. Slowly screw into casing stub. Made 8+ turns. P/U to 250K & pull test connection. Slack off. Pressure test casing to 1600 psi. Good test. 21 :00 - 21 :30 0.50 CASE P DECOMP RID casing tools & torq turn equip. Clear & clean rig floor. 21 :30 - 00:00 2.50 BOPSUF P DECOMP Drain stack. NID BOPE. P/U stack. 3/24/2006 00:00 - 00:30 0.50 WHSUR P DECOMP Install slips & set wI 150K over string weight. 00:30 - 02:00 1.50 BOPSUF P DECOMP N/U BOPE. Test break wI 1000 psi, Ok. Blow down lines. 02:00 - 02:30 0.50 CEMT P TIEB1 RlU cementing lines. Install Plug in cementing head. 02:30 - 03:00 0.50 CEMT P TIEB1 Hold PJSM & review cementing plan & make personnel assignments. 03:00 - 05:30 2.50 CEMT P TIEB1 Fill lines. Pressure test lines to 4000 psi, OK. Batch mix cement. Pump 25 bbls of 9.8 brine spacer.Pump 90.3 bbls of Gas- Check cement. Weight 15.8 ppg. Pumped @ 6 BPM @ 600 psi. SID & drop plug. Displace well w/1 07.5 bbls of 9.8 ppg brine @ 6 BPM @ 600 psi, Slowed displacement to 2 BPM for last 15 bbls. Pressure up & bump plug wI 1900 psi. Close ES cementer. Hold for 2 min. Bleed off pressure Got 3/4 Bbl back, Cementer holding. PD @ 0503 hrs. Had 5.54 bbls of cement returns to surface. 05:30 - 06:00 0.50 CEMT P TIEB1 Blow down lines, Wash up equip. & RID cementing equip. 06:00 - 08:30 2.50 BOPSUF P DECOMP WOC. Rig down Cement Head. Lift Stack. 08:30 - 10:00 1.50 WHSUR P DECOMP Cut-off 9 5/8" Casing with the Wachs cutter per Cameron Serviceman. Lay down the Cut-off Jt = 11.75', 95/8" TCII Short Joing, 9 5/8" TCII pin x 9 5/8" BTC box, 9 5/8" BTC pin x Cement Head thread. 10:00 - 14:30 4.50 WHSUR P DECOMP Problems with the "fit" (not un-common with the Gray Gen 2 equipment) of the pack-off ring. WO machine shop work to machine the "fix". 14:30 - 16:00 1.50 BOPSUF P DECOMP N/U BOPE. 16:00 - 16:30 0.50 WHSUR P DECOMP Pressure test Pack off to 3800 psi for 30 min. Tested good. 16:30 - 17:30 1.00 BOPSUF P DECOMP Change ot 9 5/8" rams for 3 1/2" x 6" VBR. 17:30 - 18:00 0.50 BOPSUF P DECOMP RIU test equip. Set test plug. 18:00 - 19:00 1.00 BOPSUF P DECOMP Pressure test break & rams. LP 250 psi, HP 4000 psi. Charted same. RID test equip. Pull Test plug. Install Wear Bushing. 19:00-21:00 2.00 CLEAN P DECOMP P/U, tally & M/U BHA to Clean out shoe track as follows: 81/2" Bit, 2 Boot Baskets, XO, Bumper Sub, Jar, XO, 9' 6 1/4" DCs, XO. TL = 307.48'. RIH wI same. Tag @ 1414'. e e Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page. 15 of19 Operations Summary. Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/24/2006 21 :00 - 22:00 1.00 CLEAN P DECOMP Displace 9.8 ppg brine wI Clean seawater. 6 BPM @ 150 psi. 22:00 - 00:00 2.00 CLEAN P DECOMP P/U kelly & break circulation. Drill out cement shoe track. Had soft cement from 1414 to 1426' (ES- Cementer). Con't to drill & wash from 1426 to 1431". ( Baffle) P/U Wt = 48K, S/O Wt = 48K. Rot Wt = 48K. 6 BPM @ 210 psi, 60-85 RPMs, WOB = 5-10K, 2.5-3.5K Torq. 3/25/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Con't to drill thru Baffle from 1432 to 1433'. Kelly down to 1442'. P/U, S/O & Rot Wt = 48K. 60080 RPMs, WOB = 5-10K, 6 BPM @ 210 psi. torq = 2-3.5K. 01 :00 - 01 :30 0.50 CLEAN P DECOMP Circulate bottoms up. 6 BPM @ 170 psi. 01 :30 - 03:30 2.00 CLEAN P DECOMP P/U 31/2" DP 1x1 & RIH. Tag sandlfill @ 3947'. 115jts +10'. 03:30 - 06:00 2.50 CLEAN P DECOMP Reverse circulate, pump Hi-Vis sweep 6 BPM @ 675 psi. & displace brine to seawater. 06:00 - 06:30 0.50 CLEAN P DECOMP Lub Rig and inspect Derrick. 06:30 - 08:00 1.50 EVAL P DECOMP Rig up test equipement and recording chart. Test 9 5/8" 47 Iblft L-80 at 2,500 psi for 5 minutes. Good. Bring pressure up for the final test at 4,000 psi/30 minutes. Good test. 08:00 - 09:00 1.00 CLEAN P DECOMP POOH with Drill Pipe and 8 1/2" Bit assembly. 09:00 - 10:00 1.00 CLEAN P DECOMP Lay down 61/4" Drill Collars. 10:00 - 10:30 0.50 CLEAN P DECOMP Clear and clean Rig floor. 10:30 - 11 :00 0.50 CLEAN P DECOMP Make-up BHA #20 as follows: 7 7/8" RCJB, w/8.50" Shoe, Boot Basket, Boot Basket, XO, Bumper Sub, Oil Jar, XO, 3 ea 6 1/4" Drill Collars, XO. 11 :00 - 12:00 1.00 CLEAN P DECOMP TIH with BHA and 3 1/2" Drill Pipe (124 Jts). Pick-up Kelly break circulations. Drop ball for RCJB. Ball on seat. PUW = 63K. SOW = 63K. Pump rate = 4.5 bpm/1350 psi. 12:00 - 12:30 0.50 CLEAN P DECOMP Tag junk at 3,953'. Wash and work down to 3,960'. No further progress. 12:30 - 13:00 0.50 CLEAN P DECOMP Set back Kelly. Drain and blow-down Lines. 13:00 - 14:00 1.00 CLEAN P DECOMP POOH with Drill Pipe and BHA. 14:00 - 14:30 0.50 CLEAN P DECOMP Lay down BHA. Clean and clean RCJB and Boot Baskets. RCJB had a large piece of rubber and several smaller pieces from the Wiper Plug. Also recovered large and small pieces of aluminum. Empty Boot Baskets and recovered 3 gals of aluminum chips and scale. Very little sand. 14:30 - 15:00 0.50 CLEAN P DECOMP Re-Ioad same BHA for run #2. 15:00 - 16:30 1.50 CLEAN P DECOMP TIH with BHA: Re-run #2. Pick-up Kelly. 16:30 - 17:00 0.50 CLEAN P DECOMP Pump Rate = 5.0 bpml1700 psi. PUW and SOW = 75K. Rotate at 20 rpms. Wash and work through junk from 3,960' - 3,964'. Then easy washing down to RBP at 3,985'. 17:00 - 18:30 1.50 CLEAN P DECOMP Circulate well. 6 BPM @ 2000 psi. Set back Kelly. 18:30 - 20:00 1.50 CLEAN P DECOMP POOH & stand back 31/2" DP. 20:00 - 21 :00 1.00 CLEAN P DECOMP LID 6 1/4" DCs. Break out junk basket. Recovered Aluminum Ring from wiper plug. Cone from baffle collar & pieces of rubber & cement. Empty boot baskets. Recovered 2 .5 gals. rubber & pes of cement + sand. 21 :00 - 22:00 1.00 CLEAN P DECOMP Clear & clean rig floor. M/U BHA as follows: RCJB, 2 Boot Baskets, BS, Bumper Sub, Jars, XO, 3 Des, XO TL = 133.88'. 22:00 - 23:30 1.50 CLEAN P DECOMP RIH wI RCJB BHA on 31/2" DP. Tagged @ 3953'. 23:30 - 00:00 0.50 CLEAN P DECOMP Break circulation 6 BPM @ 1900 psi. Wash down from 3953 to 3985'. P/U Wt = 75K, S/O Wt = 72K. Work pipe up & down over plug. 3/26/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Reverse circulate & work RCJB up & down over plug. Pump e e Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From ~ To Hours Task Code NPT Phase Description of Operations 3/26/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP 20 bbls Hi-Vis sweep. 6 BPM @ 1900 psi. 01 :00 - 02:30 1.50 CLEAN P DECOMP POOH & stand back 31/2" DP. 02:30 - 03:30 1.00 CLEAN P DECOMP Break out & LID LID RCJB Assy. Recovered 6 pes of rubber, 2 pes of cement & 2 pes of aluminum. boot Baskets contained 2 gals of sand & some cement. Clear rig floor. M/U RBP overshot tool to retreive plug. 03:30 - 05:30 2.00 CLEAN P DECOMP RIH wI Retreiving tool on 3 1/2" DP. 05:30 - 06:00 0.50 CLEAN P DECOMP Pick-up Kelly. Circulate Well. 06:00 - 08:30 2.50 CLEAN P DECOMP Set back Kelly. Pick-up singles and reverse down to TOS. Tag TOS at -3,960'. Continue to reverse out 20/40 mesh sand down to Halco 9 5/8" RBP at 3,985'. Reverse Well clean at 5.0 bpm/760 psi. 08:30 - 09:30 1.00 DHB P DECOMP Release Halco RBP. (Had to work to get released). 09:30 - 10:00 0.50 DHB P DECOMP Reverse circulate bottoms-up x 2. Monitor Well. Well dead. Fluid level static at top of Stack. 10:00 - 11 :30 1.50 DHB P DECOMP POOH with 3 1/2" Drill Pipe and Halco RBP. Lay down same. 11 :30 - 12:00 0.50 FISH P DECOMP Clean and clean floor. Prep for next BHA. 12:00 - 12:30 0.50 FISH P DECOMP Pick-up Next BHA as follows: 5.750" (w/5.875" Shoe) Reverse Circulating Jet Basket, Bumper Sub, Oil JAr, XO, Boot Basket, Boot Basket, XO, XO, XO, 4 3/4" Drill Collars, Circulate Sub. 12:30 - 14:00 1.50 FISH P DECOMP RIH wI BHA. Ran 42 stands of 31/2" DP. 14:00 - 16:30 2.50 FISH P DECOMP P/U 120 singles, 1x1 & con't to RIH to 8076'. 16:30 - 00:00 7.50 FISH N WAIT DECOMP Wait on trucks for cleaning pits & 10.4 ppg brine. Clean, service & work on rig. Circulate well 2 BPM @ 400 psi.. 3/27/2006 00:00 - 01 :00 1.00 FISH N WAIT DECOMP Con't to wait on trucks. Clean work on & service rig. 01 :00 - 04:00 3.00 FISH P DECOMP Clean pits. Take on 10.4 ppg Brine. 04:00 - 06:00 2.00 FISH P DECOMP Displace well bore to 10.4 ppg brine. Pump 5 BPM @ 950 psi. 06:00 - 07:00 1.00 FISH P DECOMP Returns weigh 10.4 Iblgal. Wellbore has been swapped over to 10.4 Iblgal Brine. 07:00 - 07:30 0.50 FISH P DECOMP Drop Ball for RCJB. Pick-up Joint 246. RIH to 8,108'. 07:30 - 08:30 1.00 FISH P DECOMP Pick-up Kelly. PUW = 129K. SOW = 105K. Bring pump on line at 5.0 bpm/1700 psi. Enter the top of the Packer at 8,119' (have to rotate slightly to drop in). Continue to wash, work, and slowely rotate down to 8,138'. Work from Packer to 8,138' several times. Unable to make any further progress. No fluid losses. 08:30 - 09:30 1.00 FISH P DECOMP Set back Kelly. Monitor Well. Fluid level remains static in the Flow Nipple. 09:30 - 12:00 2.50 FISH P DECOMP Trip out with 3 1/2" Drill Pipe (246 Jts) and BHA. 12:30 - 13:00 0.50 FISH P DECOMP Lay down BHA. Clean Jet Basket and recovered a hand full of SS Band pieces, Two chunks of hard rubber, and a small seal spring (spacer seal ring from the RBP). Boot Baskets were clean. 13:00 - 13:30 0.50 FISH P DECOMP Make-up next BHA as follows: 3 5/8" RCJB w/4 5/8" Shoe, XO, XO, Bumper Sub, Oil Jar, XO, Boot Basket, Boot Basket, XO, XO, XO, Drill Collars, Circulating Sub. 13:30 - 15:30 2.00 FISH P DECOMP Trip in with BHA and 31/2" Drill Pipe (246 Jts). 15:30 - 16:00 0.50 FISH P DECOMP Pick-up Kelly. POW = 132K. SOW = 102. Bring Pump on line at 5.0 bpm/1425 psi. Had to slightly rotate through Packer again. Continue to wash and slowely rotate down to PronglPlug at 8,138'. Got hung up. Worked free. 16:00 - 18:00 2.00 FISH P DECOMP Pump down for washed out swap and liner. Pull up above Packer. Monitor Well and observe bubbles breaking out at e e Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 17 of.19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2006 16:00 - 18:00 2.00 FISH P DECOMP surface. Continue to closely monitor Well while repairs are made. 18:00 - 20:30 2.50 FISH P DECOMP Circulate well. Had a small amount of gas to surface. 5 BPM @ 1450 psi. 20:30 - 23:00 2.50 FISH P DECOMP POOH w/3 1/2" DP & BHA. 23:00 - 00:00 1.00 FISH P DECOMP Break out BHA. recovered prong from plug. Junk basket also contained sand, 4 pes of SS bands & 1 pc of threaded brass shear pin. Redress RCJB. Boot baskets were empty. 3/28/2006 00:00 - 03:00 3.00 FISH P DECOMP RIH wI RCJB on 3 1/2" DP. 03:00 - 03:30 0.50 FISH P DECOMP P/U kelly & break circulation. 5 BPM @ 1450 psi. Wash down thru packer @ 8119' & con't down to 8137'. Work pipe up & down. P/U Wt = 138K, S/O Wt = 102K. 03:30 - 05:30 2.00 FISH P DECOMP Circulate bottoms up. 5 1/2 BPM @ 1630 psi. No losses, no gains. Very small amount of gas to surface when circulating bottoms up. Monitor well. Fluid level static. 05:30 - 08:30 3.00 FISH P DECOMP Set back kelly, Blow down lines. POOH wI RCJB assy & stand back 3 1/2" DP. 08:30 - 09:00 0.50 FISH P DECOMP Lay down BHA. Clean Jet Basket and recovered a few small pieces of SS Band, one small piece of control line, and one piece of hard rubber. Boot Baskets were both empty. 09:00 - 09:30 0.50 BOPSUF P DECOMP Pull Wear Bushing and set test Plug. 09:30 - 15:00 5.50 BOPSUF P DECOMP Test BOPE per BP/AOGCC requirements at 250/4000 psi. State's right to witness test was waived by J. Jones. Pull test plug, set wear bushing. 15:00 - 16:00 1.00 CLEAN P DECOMP PJSM. P/U BHA to cleanout profile in plug in RN nipple. 16:00 - 18:00 2.00 CLEAN P DECOMP RIH wI BHA on 3 1/2" DP. 18:00 - 18:30 0.50 CLEAN P DECOMP P/U kelly break circulation & wash down from Top of packer @ 8119 to 8140' This is 2.5' deeper than previuos runs. Pumped 5 BPM @ 1600 psi. 18:30-21:00 2.50 CLEAN P DECOMP Circulate well. Pumped 5 BPM A 1600 psi. Pumped 560 bbls. No gas to surface. Lost 2 bbls of brine while circulating. Set back kelly & blow down lines. 21 :00 - 00:00 3.00 CLEAN P DECOMP POOH wI BHA & stand back 31/2" DP. 3/29/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Break out RCJB & empty same. Recovered 2 pes of control line ea approx 4". a 2nd 1" brass shear pin & 8 pes of SS banding. . Boot baskets containe 1 pc of rubber. 00:30 - 01 :00 0.50 CLEAN P DECOMP Clean floor. Redress & M/U BHA. 01 :00 - 03:00 2.00 CLEAN P DECOMP RIH wI RCJB Assy on 3 1/2" DP. 03:00 - 03:30 0.50 CLEAN P DECOMP P/U kelly break circulation & work RCJB down thru packer @ 8119 to 8140'. Work string up & down several times to load tool. P/U Wt = 131K, S/O Wt = 102K. Pumped 5 BPM @ 1600 psi. tools going thru packer & tailpipe wI no problems. 03:30 - 05:30 2.00 CLEAN P DECOMP Circulate bottoms up. 5 BPM @ 1600 psi. No gas to surface. Pumped total of 550 bbls. No losses. 05:30 - 09:00 3.50 CLEAN P DECOMP POOH wI RCJB & stand back 31/2" DP. 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. Stand back collars, LID RCIJB BHA. Empty reverse circulating basket. Recovered (3) small pieces of stainless steel control line band. 10:00 - 11 :30 1.50 BOPSUF P RUNCMP PJSM. Pull wear bushing & set test plug. C/O pipe rams to 7 5/8". 11 :30 - 13:00 1.50 BOPSUF P RUNCMP PJSM. Conduct body test wI 7 5/8" rams installed @ 250 I 4000 psi, OK. Pull test plug. 13:00 - 17:00 4.00 RUNCm fp RUNCMP PJSM. Rig up to run 75/8" completion string. Pick up & rig up e e Printed: 4/14/2006 11:12:22 AM BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of OperationS 3/29/2006 13:00 - 17:00 4.00 RUNcor fp RUNCMP Gator Hawk equipment. Rig up torque turn equipment. 17:00 - 18:00 1.00 RUNCOr ~ RUNCMP P/U, M/U & Baker lock tail pipe & packer Assy. RIH wI same. 18:00 - 00:00 6.00 RUNCor RUNCMP P/U 75/8" 29.7#, L-80, IPC (TK-7), Vam Top, HC tubing & RIH wI same. Torq turn connections to 14450 Ft-Ibs & Gator Hawk each connection to 3800 psi with N2. Ran 60 jts. 3/30/2006 00:00 - 06:00 6.00 RUNCor fp RUNCMP Con't to RIH wl7 5/8" 29.7#, L-80, IPC, (TK-07), Vam Top, HC tubing. Torq turn all connections to 14450 ft-Ibs. Gator Hawk all connections to 3800 psi. Replace Jt # 88 had bad box. 95 jts in hole. 06:00 - 18:30 12.50 RUNCOI fP RUNCMP PJSM. Continue to RIH wl7 5/8",29.7#, L-80, IPC, Vam Top HC tubing, torque turning all connections to 14,450 ftllbs & Gator Hawking all connections wI nitrogen to 3800 psi. 18:30 - 20:00 1.50 RUNCOI fp RUNCMP Con't to RIH. P/U Wt = 235K, S/O Wt = 180K. Jt # 204 started to chatter & drag a bit. Stop, P/U & slowly went down wI normal down weight. Made connection, Jt # 205. P/U & jt would not go. Set 10K down wI no movement. String stuck. P/U 10K over to 245K. No movement. LID jt # 205. Consult wI Baker on allowable P/U & S/O parameters. RlU & break circulation, 3 BPM 275 psi. P/U to string wt & came free. Pull & LID jt # 204. 20:00 - 21 :30 1.50 RUNCOI fP RUNCMP M/U landing jt & hanger. Test hanger connection wI Gator Hawk tools. Land hanger. RILDS. 21 :30 - 23:00 1.50 RUNCO! fp RUNCMP RID Gator Hawk & Torq Turn equip. Clear & Clean rig floor. 23:00 - 00:00 1.00 RUNCOr fP RUNCMP RlU circulating equip. Close in well & pump 115 Bbls of inhibited seawater down annulus. 3 BPM @ 520 psi. 3/31/2006 00:00 - 01 :00 1.00 RUNCOr 1p RUNCMP RlU Hot Oilers & pump 42 bbls of diesel freeze protect down annulus. Pumped 2 BPM @ 850 psi. 01 :00 - 03:30 2.50 RUNCOr ,p RUNCMP Drop balllrod. Wait 15 min. Pressure up on tubing & set packer. Pressure up to 4000 psi & test tubing for 30 min. Bled off tubing to 1500 psi. Pressure up on annuluus ( Hot Oilers) to 4000 psi & tested for 30 min. Bled pressure off annulus to 0 psi & then tubing to 0 psi. Charted entire test. RID test equip & lines. . 03:30 - 04:30 1.00 WHSUR P RUNCMP P/U lubricator. Set BPV & blanking plug. Test same to 4000 psi. 04:30 - 06:30 2.00 BOPSUF P RUNCMP Change out 9 5/8" rams to 3 1/2" x 6" VBR. Test body, 250 I 4000 psi. 06:30 - 09:00 2.50 CLEAN P INTERV PJSM. NID flow riser, N/U shooting flange. Rig up Schlumberger slickline unit wI 1.25" OD wire. Pressure test slickline pack off to 500 psi, OK. 09:00 - 14:00 5.00 CLEAN P INTERV RIH wI slickline & 2" JUC to retrieve balll rod assembly from RN nipple @ 8060', latch on to & retrieve same. RIH wI 5.625" GS to retrieve RHC-M plug body from RN nipple @ 8060', latch on to & retrieve same, OK. 14:00 - 16:30 2.50 CLEAN P INTERV PJSM. RID Schlumberger slickline & NID shooting flange, N/U flow nipple. 16:30 - 18:00 1.50 CLEAN P INTERV PJSM. Pick up BHA to retrieve Plug in RN nipple @ 8140'. 18:00-21:00 3.00 CLEAN P INTERV RIH wI Short Catch spear to recover plug. RIH to 8111' Top of packer. 21 :00 - 22:00 1.00 CLEAN P INTERV P/U kelly break circulation. 1 1/2 BPM @ 90 psi. Take on seawater. 22:00 - 22:30 0.50 CLEAN P INTERV Establish fishing parameters. P/U Wt = 125K, S/O Wt = 108K. 1.5 BPM @ 90 psi. Con't in hole & latch up on plug in "RN" e e Printed: 4/14/2006 11 :12:22 AM BP EXPLORATION Page 19 of 19 Operations Summary Report Legal Well Name: WGI-04 Common Well Name: WGI-04 Spud Date: 9/29/1979 Event Name: WORKOVER Start: 1/18/2006 End: 4/2/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/2/2006 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/31/2006 22:00 - 22:30 0.50 CLEAN P INTERV nipple. Had 60# pressure increase. S/O 10k, then P/U 25K over & release plug. P/U out of Tailpipe. & check fluid level. Fluid level dropped out of sight. 22:30 - 23:30 1.00 CLEAN P INTERV Pumped 60 bbls seawater down annulus @ 5 BPM & brought fluid to surface. SID & monitor well. Weill dead. Fluid level dropped out of sight. Set back kelly & blow down lines. 23:30 - 00:00 0.50 CLEAN P INTERV POOH & LDDP. 4/1/2006 00:00 - 04:30 4.50 CLEAN P INTERV POOH & LID 31/2" DP. 04:30 - 05:00 0.50 CLEAN P INTERV Break out & LID BHA. 05:00 - 07:00 2.00 CLEAN P INTERV Clear & clean rig floor. 07:00 - 11 :30 4.50 CHEM P INTERV PJSM. N/U shooting flange. Rig up Schlumberger slickline wI slickline BOPE & pack off. Rig up Little Red Hot Oil Services to test spool below blind rams. PT slickline lubricator & BOPE to 1000 psi, OK. M/U DB plug & hang off above blind rams. Blind Rams closed. 11 :30 - 12:30 1.00 CHEM P INTERV PJSM. PT Little Red lines to 4000 psi, OK. Line up & pump (95) bbls diesel down 7 5/8" tbg @ 4.8 bpm 1475 psi initial circulating pressure, 4.8 bpm 11200 psi final circulating pressure, bullheading into formation. Monitor pressure after shutting down pump, bleeding off, well still taking fluid. 12:30 - 17:00 4.50 DHB P INTERV PJSM. Equalize pressure above & bleow blind rams, open blind rams & RIH wI plug on slickline. Saw a bobble @ 2198' but failed to set down. Ran down another 500' without seeing anything. POOH. Wrong tool. 5.98" OD. M/U 6.05" tool & RIH & set in DB-6 nipple @ 2198'. POOH, M/U Equalizing prong & RIH on slickline & set @ 2197'. 17:00 - 17:30 0.50 DHB P INTERV PJSM. Line up wI Little Red & diesel & pump 17 bbls to fill hole & PT 7 5/8" tbg against plug in DB-6 nipple @ 2198' to 3500 psi, 10 minutes, good test. Bleed off all pressure. 17:30 - 19:30 2.00 DHB P INTERV RID Slickline equip. Nld shooting flange. Clear Floor. 19:30 - 21:00 1.50 WHSUR P INTERV P/U lubricator & set BPV & blanking plug. test to 1000 psi, Ok. 21 :00 - 22:30 1.50 BOPSUF P INTERV NID BOPE. 22:30 - 00:00 1.50 WHSUR P INTERV N/U adapter fange. Test tubing hanger. 5000 psi, OK. 4/2/2006 00:00 - 02:00 2.00 WHSUR P INTERV N/U tree. Fill wI water & test tree to 5000 psi, Ok. Drain tree. 02:00 - 03:00 1.00 WHSUR P INTERV Secure tree & cellar. Release rig @ 0300 hrs. e e Printed: 4/14/2006 11 :12:22 AM Maunder, Thomas E (DOA) From: Jeff Jones Ueff_jones @admin.state.ak.us) Sent: Thursday, March 30, 2006 12:08 PM To: 'Winton Aubert' Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: Re: Doyon 14 W/O on DS -16 & relaxed AOGCC WO documentation requirements Winton Aubert wrote: > Jeff, v • The maximum anticipated WGI -04 surface pressure is 2800 psi - 2900 • psi. According to our regs, this surface pressure requires a • three - element stack (annular, pipe ram, blind ram). A surface • pressure of 3000 psi or more requires a four - element stack (annular, 2 • x pipe ram, blind ram). The sundry notice for the current WGI -04 • operation specifies a BOPE test pressure of 4000 psi, since BP MITs • injectors to 4000 psi. > I believe the above is in compliance with our regulations. > Please call me if I am incorrect, or if you want to discuss this. > Thanks, 11'l i n > Winton 93 -1231 >> Gentlemen, >> Please know that I have great respect for your many years of combined >> education and working experience and so I would like to ask your help with this question. What is your assessment of the compliance to >> AOGCC regulations for W/O operations pertaining to Nabors rig 4ES, >> currently performing a W/O on WGI -04 with an API 5K rated stack >> containing 1 annular, 1 pipe ram, 1 blind ram? Are they in compliance >> as far as the number of pipe rams? I spoke with Lee Hinckle (4ES BPXA >> Rep.) this morning and he said there was no mention of anticipated >> surface pressure in his well plan and he was unable to calculate it >> on the spot. He said the well plan mentioned 3800 PSI bottom hole >> pressure. I am just trying to get the criteria for 1 pipe ram versus >> 2 pipe rams straight in my mind so that when I am witnessing a BOPE >> test or speaking to the operators I am following the regulations or >> helping the operator with a variance issue. >> Thanks for your help in this matter, >> Jeff Thanks Winton, can you explain to me how you do that calculation? When I go to the rig for a BOPS test and there is no sundry and the well plan is sub -par or non - existent I guess I will have to do the calculation to determine ram coverage compliance. I want to make sure I am doing the calculation in the field like you are in the Anchorage office. Thanks, Jeff I 1 .~~=.{~;~ ~---=- :. -:.. ., - . .-....~~-.;. ~ t---I, j .~-- .-" ~ ~¡1r=U Schlumberger t: i*"ß 1') ,,",, .t! r, t' ./" ä t· !,,!... l ~J:F:j Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ._'. __Vf h.... .__.¿.)~ ~ HrH~j..S!aJ i Ancooragc ~C;ANNED FEB 2 8 2005 Well Job# Log Description Date BL 13-31A .)05- iliJO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B .QoS --Of"-.(¡, 11057071 SBHP SURVEY 12/02/05 1 NK-43 ,.Q~/-CO I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /ct9 - CoB7 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A /Qj'JC57 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 I ß (¡;.~ /34- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 /9tt ·,¡51- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 Jr.7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 ie:q-c(~~ 11051081 RST 08/10/05 1 L5-09 /C¡C - /~ 11090725 RST 11/11/05 1 15-44 ,qú - I f D 11194155 RST 01115/06 1 C-20B -;¿O{-f [4- 11075913 MCNL 08/29/05 1 02-14A QO~ J 1~5 11075901 MCNL 07/29/05 1 Z-21A -9ð 1- iO t 11076449 RST 06/30/05 1 F -27 A ¿Jo5-la4- 10928641 MCNL 09/01/05 1 MPH-15 -?C~-/5'1 11076486 USIT 12/15/05 13-31A -::::)05-1100 11133211 SCMT 12/23/05 WGI-04 ) ttt - o5L; 11183461 USIT 01/26/06 WGI-04 "Jet-C'S'C· 11211566 USIT 02/03/06 WGI-08 I c.¡c - 00/1 10987559 USIT 01/02/06 WGI-08 ¡ctð - c4Q 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: _?/{ ,:)? ( 00 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD -' 1 1 1 1 1 1 1 1 ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: t~èJ ) FW: WGI-04 Plan Forward e C7Y-Ð50 e Subject: FW: WGI-04 Plan Forward From: "Reem, David C" <~eemDC@BP.com>, Date: Thu, 16 Feb 200616:09:01 -0900 To: Winton Aubert <winton_aubert@admin.st Winton, as we discussed over the phone, attached is oµr plan forward to progress the RWO on WGI-04 (Sundry 305-392). As you know, we shut-down operations on this well on 2/05/2006 due to leaks in our new 9-5/8" tie-back casing. The proposed plan forward will be performed by the same rig (Nabors 4ES). Please call with any questions on our plans to proceed with this workover. Thanks. From: West, Howard J Sent: Thursday, February 16, 2006 4:03 PM To: Reem, David C Subject: WGI-04 Re-RWO AOGCC scope -- . .;,..,--* Mr. Reem, Please see attached. . '~~'. r ~. ¡:¡.N~~·~ / ' S~¡rt·,··c ,- Howard «WGI-04 RE-RWO AOGCCscope.doc» ~ l Content-Descrlpüon: WGI-04 RE-RWO AOGCCSCO;dO~~1 IIWGI-04 RE-RWO AOGCCscope.do Content-Type: applicationlmsword "II l . Content-Encoding: _~~~~ __~.___~J 1 of! 2/16/20064:11 PM e e Well status: Shut-in gas injectör,suspended from earlier workover attempt. Well has inner annulus x outer annulus communication. The well is secured with a 4 %" kill string to 2312' and an RBP at 3986'. Scope: Retrieve existing 4 %", 12.6 # kill string. Cut and pull -1600' of 9-5/8". Run back in with 1600' of new 9-5/8", 47#/ft, L-80 TC-II casing and cement surface. Re-complete with 7.625", 29.7#/ft, L-80 IPC Vam Top HC tubing, permanent packer with tail-pipe -2' above existing packer. Provide AOGCC field inspectörs 24-hr notices as reQuired to witness BOP tests and MITIA post packer settinQ. 1.MIRU· Nabors 4ES. Circ out diesel freeze-protect and verify well is dead. Pull BPV,set and test TWC in tubing hanger. NO tree and adapter flange. NU BOPE. Test BOPE to 250 psi (low)/3500 psi (high). 2. NO tree and adapter flange. NU BOPE. Test BOPE per BP and AOGCC regulations, 250 psi (low)/4000 psi (high). 3. Pull 4.5" kill string. 4. Mechanically cut the 9 5/8" casing in the 1st full joint above TOC. Circulate well with 9.8 brine through the cut. 5. NO BOP and tubing spool. NU BOP and test same per step #2. 6. Pull 9 5/8" casing down to the cut 7. Back off 9 5/8" casing stub. 8. RIH with new 95/8",47#, L-80 TC-II casing, shoe-track and over-shotguide- .§!J~!f{ Screw into existing 9-5/8" casing. PT casing to -2800 psi. . Pressure up to.øpen ES-cementer. Verify communication up 9 5/8" by 13 3/8" annulus. 9. CeiTient 9 5/8" to surface. 10. Lift BOP's, install slipslpack off, slack off on casing to fully engage slips. Test pack-off. Rough cut 9 5/8". Set back BOP's. Make final dressing cut on 9 5/8". NU tubing spool. NU BOP's. Test spool I BOP's to 4000 psi. 11. Drill out shoe track down to sand top on RBP. PT casing to 4000 psi. 12. Retrieve upper RBP and continue on with program outlined in Sundry # 305- 392. WGI-04 and WGI-03 workovers ') ) L1q-oso Subject: WGI-04 andWGI-03 workovers From: "Reem, David C" <ReemDC@BP.com> Date: Mon, 30Jan 2006 13:51:53-0900 To:···Wloton··Aubert·.<WÎ.ntÒn_aUbert@àdrnin..state.àk.us> Winton, referencing Sundry number 305-392 (WGI-04) and 306-008 (WGI-03), our original intent was to cement in our new 9-5/8" casing tie-back to surface. However, in an effort to allow some flexibility for a future rig sidetrack where the 9-5/8" would be cut and pulled to allow a 12-1/4" BHA to cut the sidetrack window in the 13-3/8" casing, we are now planning on only cementing in the bottom -500' of new 9-5/8" casing. Test pressures, etc remain the same as in the Sundry application. Should you have any questions regarding this slight change in scope, please call. Thanks. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) SCJ\NNEtx ~JAN 3 1 ,20nß 1 of 1 1/30/2006 3: 12 PM {(;;",' rr~ ~br[p" \ ~, r ;~' '\\ \\,~u: I " \ r I \<',\ I, ¡Jil, \ r ¡ ! " ' QJJ U il,) U t~ ) (]ìr : \ lí¡' ,iï:fjil' I,n: ;/',-//\ \, <:!"""f\) í¡',n,l/7/,1. /,~¡ 1, \ I, I L i ! \!" \, , i ~ \\ '>.', U'7, I /11 \ ! ': I, r~ !!r~! Ii OJ.J\ ",\" ¡ :~\ /!Ul\ \\1}) U / 1, \ l!b1J1j cQ) I ¡\~:' / 1 \~ ) ALASIiA. OIL AlWD GAS CONSERVATION COMMISSION / l I / FRANK H. MURKOWSKI, GOVERNOR David Reem Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 17q- ð5D Re: PBU WGI-04 Sundry Number: 305-392 $CANNED DEC ~~ B 2005 Dear Mr. Reem: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unless rehearing has been requested. Sincerely, '----- DATED thisL~y of December, 2005 Enc!. ~~ë~l.IWDS ) STATE OF ALASKA) ''£IV'£D ALASKA OIL AND GAS CONSERVATION COMMISSION Nil DEe 2] 2005 APPLICATION FOR SUNDRY APPROVA(.'kaOi'&Gasc A ons. Co . 20 AAC 25.280 nChorage l11f17/S8íon 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing /' 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: o Development 0 Exploratory o Stratigraphic IBI Service / 5. Permit To Drill Number 179-050 /' 6. API Number: /" 50- 029-20386-00-00 49.0 9. Well Name and Number: PBU WGI-04 ,./ 8. Property Designation: 11. Total Depth MD (ft): 9584 Casing Structural Conductor Surface Intermediate Production Liner 10. Field / Pool{s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8596 9550 8564 8133 Length Size MD,' TVD Burst ADL 028302 Junk (measured): None Collapse 45' 201' 73' 73' 1530 520 2705' 13-3/8" 2733' 27331 4930 2270 8615' 9-5/8" 8643' 7705' 8150 5080 1252' 7" 8332' - 9584' 7417' - 8596' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9034' - 9469' 8076' - 8487' Packers and SSSV Type: 9-5/8" x 7" BKR SAB 9-5/8" x 7" BKR SB-2 T~,bing Size: 1. r'~29# / W6~ Tubing Grade: Tubing MD (ft): L-80 8246' Packers and SSSV MD (ft): 8115' / 8228' ",,' 12. Attachments: IBI Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 30, 20~ / 0 Oil 0 Gas 16. Verbal Approval: Date: -ß11\ÎAG æ(GINJ Commission Representative: w,6r 17. I hereby certi that the foregoing is true and correct to the best of my knowledge. Printed Nam 3 Davi~ Reem ¡¿ Title Senior Drilling Engineer /' Prepared By Name/Number: Signature I V flf/ ~t... Phone 5''/-- ~74 3 Date 1%'/2D/05 Sondra Stewman, 564-4750 Commission Use Only 13. Well Class after proposed work: o Exploratory 0 Development IBI Service o Plugged DWINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance I Sundry Numbe~"T) - l"Çf9.-- . T ~S t- BoP E !-o 4-000 I~'. RBDMS BFL DEC 2 3 2005 COMMISSIONER APPROVED BY THE COMMISSION Date /1- - ],.7--£ Submit In Duplicate ORIGINAl ) ) Well Status: Shut-in gas injector. Well has confirmed tubing x inner annulus and inner annulus x outer annulus communication. The well is secured with a tubing tail plug. /"... Project: Retrieve existing 7.625", 29.7#, L-80 IPC STL completion leaving the packer and tail-pipe. Cut and pull -2700' of 9-5/8". Tie-back in with 2700' of new 9-5/8", ~. 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7.625", 29.7#/ft, L-80 IPC Yam Top HC tubing, permanent packer with tail-pipe -2' above existing packer. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. PRE-RWO · Set TTP in "RN" nipple to secure well (DONE). · Punch circ holes in 7-5/8" tubing 1 full joint above the packer. · Circulate the well over to seawater with diesel freeze protect. CMIT to 2000 psi to verify tubing tail plug integrity. MITOA to 2000 psi to verify 13-3/8" shoe / integrity. Set and test BPV in tubing hanger. RWO 1. MIRU workover rig. Circ out diesel freeze-protect and verify well is dead. Set /' TWC in tubing hanger and test. 2. ND tree, NU a~f~lly test BOPE per BP and AOGCC regulations (250 psi low pressure test/~O~~si high pressure test (test the annular to 3500 psi). 3. RIH w/multi~ng cutter (dressed w/8.5" knives) and cut the 1 st full joint of 7- 5/8" tubing above the packer. 4. Pull 7-5/8" tubing down to the cut. 5. Run 9-5/8" scraper to the 7-5/8" stub. 6. Set 9-5/8" Model 3L RBP just above tubing stub. Spot -20' of river sand on RBP. 7. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. / 8. Set 2nd RBP -600' below the TOC indicated on the USIT log. Spot 20' of sand on RBP. 9. Mechanically cut the 9-5/8" casing in the 1 st full joint above the T0C. 10. Mobilize and circulate out all Arctic Pack from the 9-5/8" x 13-3/8" annulus. 11. Pull 9-5/8" down to the cut. 12. Run wash shoe and 13-3/8" scraper down to the 9-5/8" stub. Ensure wash shoe is / able to get beyond the next 9-5/8" collar by -6'. Reverse circulate the wellbore clean. 13. Back-off 9-5/8" casing stub. 14. ND BOP and tubing spool. NU spacer spool and BOP. Test same per step #2. 15. RIH with new 9-5/8", 47#/ft, L-80 TC-II casing, shoe-track and over-shot guide- sub. Screw into existing 9-5/8" casing. PT casing to -2000 psi. Pressure up to open ES-cementer. Verify communication up 9-5/8" x 13-3/8" annulus. 16. Cement 9-5/8" in place with target top of cement = 500'md. Diesel ahead of cement to ensure freeze protection. Close ES-cementer. Pull -150K tension on 9-5/8" . ) ) 17. Split stack, install slips/pack-off, slack-off on casing to fully engage slips. Test pack-off. Rough cut 9-5/8". Set back BOPs. ND spacer spool. Make final dressing cut on 9-5/8" NU tubing spool. NU BOPs. Test spoollBOPs to 4000 pSI. 18. Drill out shoe-track down to sand top on upper RBP. PT casing to 4000 psi. 19. Retrieve upper 9-5/8" RBP. 20. Retrieve lower 9-5/8" RBP. 21. Spear 7" stub and rotate k-anchor free from SABL-3 packer. 22. RIH with reverse circulating junk basket(s) and clean off any debris on top of TTP set in original tail-pipe. POH and LDDP. 23. RIH with 7" WLEG, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" crossed over to 7-5/8", 29.7#/ft, L-80, IPC VamTop HC completion. Will have a 7" DB-6landing nipple at -2100' for flapper-type safety valve installation after the rig moves off. 24. Tag top of existing SABL-3, P/U 2-3', reverse in packer fluid and freeze protection. Allow freeze-protect fluid to U-tube between tubing and inner annulus. 25. Set S-3 packer. MIT - T to 4000 psi, MIT -IA to 4000 psi/, 26. Set BPV. ND BOP, NU and PT tree to 5000 psi. 27. RDMO. POST-RWO ". · Pull ball&rod from RHC sleeve. Pull RHC sleeve. . Pull TTP from the RN nipple. · Set A-I injection valve in DB-6 landing nipple. · Tie-in injection lines, fe-set wellhouse and instrumentation. · POI. MIT-IA w/AOGCC witness. TREE = GRA Y WELLHEAD = GRA Y "~',,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,J,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, ACTUA TOR = AXELSON KB.ELEv = ~~'-~,' BF.äBi;"" . KOP= '~~~~~~ì~;" '. Datum MD = 5ãtumTVb ; ) WGI-04 /1 \ 1 2180' 1 \ I :~::: ~ . \ 2733' ~ S,....kNOTES: 3200' ~4~~~~?" N/A "88ÖO,"5S 2' 1-17" X 7-5/8" XO 1 IT'TBG, 29#, L-80, .0371 bpf, 10=6,184" 1-1 17-5/8" TBG, 29.7#, L-80, .0459 bpf, 10 = 6.875" 1-1 17"TBG, 29#, L-80, .0371 bpf, 10=6.184" 1-1 I TOP OF 7-5/8" TBG 1-1 2' 2180' 1-17-5/8" X 7" XO, 10 = 7.625" I 2181' 1-17" CAM BAL-O SSSV NIP, 10 = 5.937" I 2186' 1-17" X 7-5/8" XO, 10 = 7.625" I 113-3/8" CSG, 72#, N~80, 10 = 12.347" 1-1 ~ Minimum ID = 4.843" @ 8245' BAKER SHEAROUT SUB I TOP OF 7" LNR 1-1 8332' ~'-_.~-'-"" ~ 8112' 1-17-5/8" X 7" XO, 10 = 7,0" 1 I l 1-19-5/8" X 7" BKR SAB PKR I Z :8:' 8115' jB~ 8133' 1- 7" HES RN NIP, 10 = 5,5" w /7" RPN PLUG (11/20/05) 8142' 1-17" TUBING TAIL WLEG 1 .:>< :8: 8228' 1-19-5/8" X 7" BKR SB-2 PKR. 1 8245' 1-17" BKR SHEA ROUT SUB, 10 = 4.843'l 8246' 1-17" TUBING TAIL 1 8227' 1-1 ELMO TT LOGGED OS/25/87 17-5/8" TBG, 29.7#, L-80, .0459 bpf, ID = 6.875" 1-1 8112' I TOP OF 7" TBG 1-1 8112' 17" TBG, 29#, L-80, ,0371 bpf, 10 = 6.184" 1-1 8142' I TOP OF 7" TBG 1-1 8228' 17" TBG, 29#, N-80, .0371 bpf, 10 = 6,184" 1-1 8246' I 9-5/8" CSG, 47#, N-80/S00-95, 10 = 8,681" 1-1 8643' ... it.. PERFORA TION SUMMA RY REF LOG: BHCS ON 10/16/79 ANGLE AT TOP PERF: 19 @ 9034' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 9034 - 9134 C OS/25/87 3-3/8" 0 9142 - 9309 C OS/25/87 3-3/8" 4 9320 - 9362 C OS/25/87 3-3/8" 4 9366 - 9380 C OS/25/87 3-3/8" 4 9392 - 9402 C OS/25/87 3-3/8" 4 9416 - 9438 C OS/25/87 3-3/8" 4 9449 - 9469 C OS/25/87 I I I I I PBTO 1-1 9550' A I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 9584' OATE 1 0/28/79 08/16/97 11/03/01 06/22/04 11/22/05 11/27/05 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV ER RN/TP CORRECTIONS A TO/TLP WAIVER SAFETY NOTE MORlPJC RPN PLUG @ 8133 EZL/PAG WAIVER SFTY NOTE DELETED OATE REV BY COMMENTS PRUOHOE BA Y UNrT WELL: WGI-04 PERMrT No: '1790500 API No: 50-029-20386-00 SEC 11, T11N, R14E BP Exploration (Alas ka) TREE = ¥y~~~~~p~ A CTUA TOR = KB. ELEV = BF.ËCèJ';'; KOP= Max Angle = Datum MD = ·bãiû'mTVÖ;" ... GRAY GRAY AXELSON 49' ') WGI-04 Propose,-) 3200' ... ...."....".".._,.".,...,-,.....,...,.. 44 @ 6800' N/A ààöÖ'ss 9-5/8" casing has 2 FOCs, top one at 2356'. 113-3/8" CSG, 72#, N-80, ID = 12.347" l-i 2733' I-~ 17-5/8" IPC TBG, 29.7#, L-80, ID = 6.875" l-i ....8055' 1- 17" TBG, 29#, L-80, .0371 bpf, ID = 6,184" l-i 8142' 17" TBG, 29#, N-80, .0371 bpf, ID = 6.184" l-i 8246' I TOP OF 7" LNR l-i 8332' I 9-5/8" CSG, 47#, N-80/S00-95, ID = 8.681" l-i 8643' DATE 10/28/79 08/16/97 11/03/01 06/22/04 11/22/05 11/27/05 ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/16/79 ANGLEATTOPÆRF: 19 @ 9034' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9034 - 9134 C OS/25/87 3-3/8" 0 9142 - 9309 C OS/25/87 3- 3/8" 4 9320 - 9362 C OS/25/87 3- 3/8" 4 9366 - 9380 C OS/25/87 3-3/8" 4 9392 - 9402 C OS/25/87 3-3/8" 4 9416 - 9438 C OS/25/87 3-3/8" 4 9449 - 9469 C OS/25/87 I PBTD 1--1 9550' 17" LNR, 29#, L-80, ,0371 bpf, ID = 6.184" l-i 9584' REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV ER RNITP CORRECTIONS A TDITLP wArvrn SAFETY NOTE MORlPJC RPN PLUG @ 8133 EZLlPAG WArvER sm NOTE DELETED DATE REV BY '"; I z ~ a I Top ....2300' of 9-5/8" Casing is 47#/ft, L-80, Gas-Tight premium thread connection FULLY cemented to surface. I -2100 1-i7" DB-6 Nip, ID=6.00" ~ ~ ~ -8065 l-i 7" HES R NIP, ID = 5.963" I ....8085 l-i 9-5/8" X 7" BKR S-3 PKR 1 -4t1ffi -7'1-ES~~0=5T1O' I 811:;)' - ~-b/ö'" ^ I'" tsl\K ~Ats t-'l\K 1 8133' - 7' I-ES~~ 0=55' I 8142' 8228' 8245' 8246' 1-i7" TUBING TAIL WLEG 1 l-i 9-5/8" X 7" BKR SB-2 PKR 1 l-i 7" BKR SHEA ROUT SUB, ID = 4.843" l-i 7" TUBING TAIL 1 Minimum ID = 4.843" @ 8245' BAKER SHEAROUT SUB I I I I COMMENTS PRUDHOE BA Y UNrr WELL: WGI-04 ÆRMrr No: ."1790500 API No: 50-029-20386-00 SEC11, T11N, R14E BP Exploration (Alaska) WGI-04 MITOA data ) ') Subject: WGI-04 MITOA data From: "Reem, David C"<ReemDC@BP.com> Date: Thu, 22 Dee 200508:34:30 -0900 To:WintonAubert<winton=aubert@admin.state..ak.us> ~ 01\J (\C\ Winton, on June 20,2004 there was an MITIA and an MITOA performed on the subject well, both witnessed by field inspector Jeff Jones. Both MITs were to 4500 psi and both passed. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) ijÇANNE[) DEe 2 s 2DD5 1 of 1 12/22/2005 8:41 AM _ STATE OF ALASKA . ALA" OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED DEC 1 6 2005 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations [2] Perforate New Pool D Perforate D 4. Current Well Class: Development Stratigraphic [J Stimulate D as GonJ: 1:9 '. Waiver D Time Extension D Anchora" Rim/S!' n Re-enter Suspended Well D g~ 5. Permit to Drill Number: 179-0500 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Pi 6. API Number: 50-029-20386-00-00 9. Well Name and Number: Exploratory Service 49 KB WGI-04 8. Property Designation: ADL-028302 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Total Depth measured 9584 true vertical 8596.25 feet feet Plugs (measured) Junk (measured) 8133 RPN None Effective Depth measured 9550 true vertical 8563.97 feet feet Casing Conductor Surface Production Liner Liner Length Size MD TVD Burst Collapse 73 20" 94# H-40 28 - 101 28 - 101 1530 520 2706 13-3/8" 72# N-80 27 - 2733 27 - 2732.98 5380 2670 8617 9-5/8" 47# N-80/S00-ge 26 - 8643 26 - 7705.15 6870 4760 18 7" 29# N-80 8228 - 8246 7324.99 - 7340.91 6890 4790 1252 7" 29# L-80 8332 - 9584 7417.47 - 8596.25 6890 4790 Perforation depth: Measured depth: 9034 - 9469 True Vertical depth: 8075.9 - 8487.07 Closed Closed Tubing: (size, grade, and measured depth) 7-5/8" 29.7# & 7" 29# L-80 23 - 8142 Packers and SSSV (type and measured depth) 7" Baker SAB Packer 7" Baker SB-2 Packer 8:11.Q.. 8228 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8(;A\N,N~J) (;it¡ ""'" t ." Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o ~~ 1~ o 0 1~0 15. Well Class after proposed work: Exploratory [J Development 16. Well Status after proposed work: Oil [J Gas WAG 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: RBDMS 8Ft DEC 1 /2005 Oil-Bbl o o Tubing pressure 3782 404 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service Pi x Contact Sharmaine Vestal WINJ WDSPL Signat Title Data Mgmt Engr Printed Name Sharmaine Vestal Phone 564-4424 Date 12/15/2005 Form 10-404 Revised 04/2004 Submit Original Only e e ... WGI-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 11/21/2005 ***WELL INJECTING ON ARRIVAL *** (secure well) DRIFTED W/ 6.03 G-RING TO TOP OF ISSSV @ 2164' SLM. PULLED 7" MCX ISSSV ON CAMCO CARRIER (SER# BP-705) BRUSHED RN NIP W/ 7" BLB & 4.65 G-RING. SET 7" RNP PLUG BODY (51/2" GS TO PULL) IN RN NIP @ 8122' SLM. *** JOB IN PROGRESS/ CONT ON 11-22-05 WSR*** 11/21/2005 T/I/O=2550/2230/1030 Well Kill (Secure Well) Pumped 9 bbls neat meth, 527 bbls Inhibited Sea Water, and freeze protected TBG w. 115 bbls Inhibited 60/40 methanol., SLB RIH w/ TTP ***Continued on 11-22-05 WSR*** 11/22/2005 ***CONT FROM 11-21-05 WSR*** (secure well ) SET PRONG (2.313 F.N, 4.40 CENT 39" BELOW F.N, 71"OAL), TOP OF PRONG @ 8118' SLM LRS PRESSURED UP ON PLUG TO 2000#, PLUG HOLDING. ATTEMPTED MIT -T, BUT WOULD NOT PASS DUE TO TXIA COMMUNICATION, CONTROL LINE PROBLEM. RDMO ***DSO NOTIFIED, WELL SECURE W/ TTP*** 11/23/2005 T/I/O=700/1160/1 050 Temp=SI Bleed WHP's < 300 psi (For Secure). IA FL @ 1638', OA FL near surface. (Balance and Control lines @ 850 psi & terminated @ wellhead). Bled lAP from 1160 psi to 250 psi in 35 minutes. Control line pressure dropped from 850 psi to 200 psi while bleeding the lA, and the balance line remained unchanged. Bled OAP from 1050 psi to 280 psi in 20 minutes. TBG FL @ 410'. While bleeding the IA the TBG pressure dropped 100 psi to 600 psi. Bled TBGP from 600 psi to 220 psi in 15 minutes. While bleeding the TBG pressure the lAP increased 90 psi to 340 psi, the OAP increased 120 psi to 400 psi. Bled lAP from 340 psi to 180 psi in 10 minutes. Bled OAP from 400 psi to 200 psi in 10 minutes. Monitor BUR for 15 minutes. Final WHP's=260/180/340. 11/24/2005 T/I/O=260/350/290. Temp=SI. Monitor post bleed (for secure). No change in TBGP, lAP increased 70 psi, OAP decreased 50psi o",e,r,l1ight. 11/25/2005 T/I/O=280/290/350. Temp=SI WHP's post-bleed (eval secure). Tubing increased 20 psi. lAP decreased 60 psi. OAP increased 60 psi. 11/25/2005 T/I/O=280/290/350. Temp= SI. OA fluid campaigÐ~. OA FL@ near surface:,J FLUIDS PUMPED BBLS 1 Diesel 115 MeOH 9 Neat Meth 527 SW 652 TOTAL STATUS: WGI-04 e -Æ ~ 17CJ-05° Subject: STATUS: WGI-04 From: "Anders, Joe L" <anders22@BP.com> Date: Mon, 21 Nov 2005 II :58:36 -0900 'it Z- ù< To: winton _é:luhert@admin.state.ak.us, jim_regg@admin.state.ak.us ~121q, 1; cc: "Rossberg, R Steven" <RossbcRS@BP.com>, "Engel, Harry R" <EngclHR@BP.com>, "NSlJ, ADW Well Operations Supervisor" <NSUADWWe\IOperationsSupervisor@BP.com>, "Schmoyer, AI" <SchrnoyAL@}BP.com>, "Mielke, Robert L," <robert.miclke(liJBP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSlJ, ADW WL & Completion Supervisor" <NSLJADWWL&CompletionSupcrvisor@BP.com>, "Luckett, Ely Z. (VECO)" <luckcz@BP.com>, "GPB, FSI/SIP/STP Area Mgr" <GPBFSITL@BP.com>, "OPS, FSl DS Ops Lead" <GPBFS I DSOpsLead@BP.com>, "OPB, Wells Opt Eng" <GPBWcllsOptEng@BP.com>, "GPB, Prod Opt 1'L" <GPBProdOptTL@BP.com>, "UPB, Optimization 'Engr" <GPBOptimizationEngr@BP.com>, "NSU, ADW Well Integrity Engineer" <NSU ADWW elllntcgrityEngineer@BP.com> Hi Jim & Winton. Well WGI-04 (PTD 1790590) is scheduled to be shut-in and a tubing tail plug set. The SSSV control line does not have integrity. This provides a flow path for tubing pressure to enter the IA past the SSSV seals if they loose integrity. Also, the well exhibits slow IAxOA communication, though both the MITIA and MITOA pass. Current plans are to leave the well shut-in and evaluate for a workover. Attached is a wellbore schematic. Please call if you have any questions. «WGI-04.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.eom ~NEC;! DEC 1 ~ ZüU5 Content-Description: WGI-04.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 11/22/20058:41 AM TREE = GRAY W8..LHEAD - GRAY WGI-04 SAFETY NOTES: ***SLOW fA X OA COMM. A CTIJII. TOR - AXELSON OPERAllNGLlMITS: MAX lAP = 2000 PSf;MAX KB. ELEV = 49' OAP = 2000 PSI (06/22/04 WAlVER)*** BF. ELEV- I \ KOP= 3200' 2' 1-j7" X 7-5/8" XO I ,/" I Max Angle = 44 @ 6800' '" DatumMD= N/A / DatumTVD - 8800' SS 17" TBG, 29#, L-80, .0371 bpf, D = 6.184" 2' I 7-518" TBG, 29.7#, L-80, .0459 bpf, ID - 6,875" 2180' 2180' 7 -518" X 7" XO, ID = 7.625" I 17" TOO, 29#, L-80, ,0371 bpf, ID = 6.184" 2186' l 1-j7" C'AM BAL-O SSSV NIP, ID = 5.937" I ~ ~ 2181' TOPOF 7-5/8" TBG 2186' " ::::- " 2186' J-l7" X 7 -5/8" XO, ID = 7,625'" 113-318" COO, 72#, N-80, ID = 12.347" 2733' µ ~ Minimum ID = 4.843" @ 8245' I BAKER SHEAROUT SUB 7-518" TBG, 29.7#, L-80, .0459 bpf, ID = 6.875" 8112' 8112' H7-518" X 7" XO, ID - 7,O"¡ ITOPOF7"TBG 8112' C8: 0::::--::>' 0::::.....::.. I 8115' 9-518" X 7" BKR SAB PKR I I . I 8133' H7" I-ES RN NIP, ID= 5.5" I 17" TBG, 29#, L-80, ,0371 bpf, ID- 6.184" 8142' I 8142' 7" lUBING TAIL WLffi C8: ..,......".. 8228' H9-518" X 7" BKR SB-2 PKR I TOP OF 7" TBG 8228' 0::::.....::.. I 8245' H7" BKRSt-EAROUT SUB, ID= 4.843" 17" TBG, 29#, N-80, .0371 bpf, ID= 6,184" 8246' I I 8246' H7" lUBING TAIL' I 822T H EL~ IT LOGGED OS/25187 I TOPOF 7" LNR 8332' ~ r-t 19-518" CSG, 47#, N-80/S00-95, ID= 8.681" 8643' PERFORATION SUMIt1ARY REF LOG: BHCS ON 10/16/79 ANGLE AT TOP PERF: 19 @9034' tobte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz 1:\ð.1E 3-3/8" 4 9034 - 9134 0 05125/87 ¡ 3-3/8" 0 9142 - 9309 0 05125/87 3-3/8" 4 9320 - 9362 0 05125/87 3-3/8" 4 9366 - 9380 0 05125/87 3-3/8" 4 9392 - 9402 0 05125/87 3-3/8" 4 9416 - 9438 0 05125/87 3-3/8" 4 9449 - 9469 0 05125/87 / I AnD 9550' ~ 17" LNR, 29#, L-80, .0371 bpf, ID - 6.184" I 9584' I DATE REV BY COMIllENTS I:\ð.TE RBI BY COMVIENTS FRUŒlOE BAY UNIT 10/28/79 ORIGINAL COMPLETION W8..L: VVGI-04 08/16/97 LAST WORKOVER ÆRMrr No: 1790500 11/03/01 Rf\VTP CORRECTIONS A PI No: 50-029-20386-00 06/22/04 ATD'TLP WA IVER SAFETY N01E SEC 11, T11N, R14E BP Exploration (Alaska) e WGI-04 (PTD# 1790500) High IA Pressure ) ) \ \ti S~þj~:'\W~.~(P~,~~~Ø~~,~~;~j~~~~%',ì' ,........,.'....... ..(~qtt\\1... '... ,.......' IfrOID.: tI~81.J,...A.I)'N·Wel1.· rntygrit". Eþgìh~er"··<NSlJAD·\YWe~llrjte~ity]jl1gil1eer@BP.cQm.>···· l)aìe:.·Th.\1,~7Qqt 2005··16:18:1470809 œ ~¡. Jim & Winton, GI well WGI-04 (PTD# 1790500) was shut-in on 10/27/05 due to high lAP. The well is currently waivered for IAxOA communication and is now experiencing IA pressurization from the tubing thru the SSSV profile. Drill-site operators were unable to maintain the MAASP of 2000 psi on the IA with bleeds and SI the well. The plan forward for the well is to pull & rerun the SSSV. A wellbore schematic has been included for reference. Please call if you have any questions. «WGI-04.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-51 02 907-659-5100 #1154 pgr \~ltð~I.N1EC¡ NOV 1 12.005, Content-Description: WGI-04.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 11/7/2005 11 :04 AM TREE = W8.LHEAD ::: 'A CTUA. TOR ::: KB. ELEV = BF. ELEV = KOP= Max Ange = ·DatÙmMÖ; DähÚnTVD ::: GRAY GRAY ÄX·ELSON 49' 3200' 44 @ 6800' N/Á 8800' SS IT'TBG, 29#, L-80, .0371 bpf, D =6.184" H 17-5/8" TBG, 29.7#, L-80, .0459 bpf, 10 = 6.875" H I7"TBG,29#, L-80,.0371 bpf,ID=6.184" H TOPOF 7-5/8" TBG H I 13-3/8"CSG, 72#,N-80,ID=12.347" H Minimum ID = 4.843" @ 8245' BAKERSHEAROUTSUB ) WGI-04 /1 \ 2' I 2180' 1 \ I ~:::: ~ . \ 2733' ~ ~ l7-5/8"TBG, 29.7#, L-80, .0459 bpf,lD =6.875" H 8112' I TOP OF 7"TBG H 8112' ! SAFETY NOTES: ***SLOW IA X OA COMM. OPERAllNGLlMITS: MAX lAP = 2000 PSI;MAX OAP = 2000 PSI (06/22/04 WAlVER)*** 2' 1-17" X 7-5/8" XO 1 2180' 1-17-5/8" X 7" XO, 10::: 7.625" 1 2181' I-IT' CAM BAL-O SSSV NIP, 10 = 5.937" 1 2186' 1-l7" x 7-5/8" XO, 10 = 7.625" I \ I 8112' l-j 7 -5/8" X 7" XO, 10 = 7.0" I z Z 8115' 1-i9-5/8" x 7" BKR SAB PKR 1 ! l 8133' I-jT' HES RN NIP, 10::: 5.5" I 8142' 1-i7" lUBING TAIL WLEG Z Z 8228' 1-i9-5/8" x 7" BKR SB-2 PKR 8245' I--1T' BKR SHEAROUf SUB, 10::: 4.843" 8246' I-IT' lUBING TAIL 1 8227' l-i ELMO TT LOGGED OS/25/87 1 . . ~ ~ 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184" H 8142' 1 TOP OF 7" TBG H 8228' IT' TBG, 29#, N-80, .0371 bpf,ID= 6.184" H 8246' I TOP OF 7" LNR H 8332' 19-5/8" CSG, 47#, N-80/S00-95, 10 = 8.681" H 8643' PffiFORA TION SUIVIVIARY REF LOG: BHCS ON 10/16/79 ANGLEAT TOP PERF: 19 @ 9034' f\bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz [)/\ TE 3-3/8" 4 9034 - 9134 0 OS/25/87 3-3/8" 0 9142 - 9309 0 OS/25/87 3-3/8" 4 9320 - 9362 0 OS/25/87 3-3/8" 4 9366 - 9380 0 OS/25/87 3-3/8" 4 9392 - 9402 0 OS/25/87 3-3/8" 4 9416 - 9438 0 OS/25/87 3-3/8" 4 9449 - 9469 0 OS/25/87 I I I I 1 FBTD 1-1 9550' a 1 T' LNR, 29#, L-80,.0371 bpf,ID=6.184" 1-1 9584' DA TE REV BY COMIVENTS 10/28/79 ORIGINAL COMPLETION 08/16/97 LAST WORKOV ER 11/03/01 Rt-.VTP CORRECTIONS 06/22/04 ATCVTLP WAIVER SAFETY t\DTE COIVIVIENTS [)/\ TE REV BY ffiUDHOE SA Y UNIT W8.L: VVGI-04 ÆR!VIrT No: 1790500 A PI No: 50-029-20386-00 SEC 11, T11N, R14E BP Exploration (Alaska) RE: WGI-04 Shut-In (PTD 1790500) ) ) ~~~jeFti~:}\y;Gt'?4ßlIut-~ (p~1)10gg5~qt ... rf~,:"~n~ers;J()~~"~an~efs1f~~r·9~}TI>· . . I;J:~te;M~xµ,l··~··..~l?r~ ..9$ ·.·lq:P3:q8j9~9q·.··...·· Hi Jim. Attached is a TIO plot for WGI-04. Please call if you have any questions Joe 659-5102 From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, April 11, 2005 9:57 AM To: Anders, Joe L Cc: Winton GAubert Subject: Re: WGI-04 Shut-In (PTD 1790500) Joe - SCl-\NNED ~\PR 2 5 2.005 Please send a TIO plot for WGI-04 (since March 1). Thanks. Jim Anders, Joe L wrote: Hello All. Well WGI-04 (PTD #1790500) has been SI due to high IA pressure. On 4/8/05, the Operator bled the IA pressure to 1100 psi. On 4/9/05, the IA pressure had increased to 2420 and the well was SI. Current plans are as follows: Obj: Locate tubing leak point 1. SL: Set TTP 2. EL: Video log Attached is a wellbore schematic. Please call if you have any questions. «WGI-04.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWelllnteç¡rítyEnç¡ineer@bp.com 10f2 4/11/200511:15AM RE: WGI-04 Shut-In (PTD 1790500) 20f2 ) Content-Description: WGI-04 TIO Plot 04-11-05.ZIP TIO Plot 04-11-05.ZIP Content-Type: application/x-zip-compressed Content-Encoding: base64 4/11/2005 11: 15 AM TREE = W8..LHEAD = AëtiJA. tÖFf;· KB. ELEV = BF. ELEV = KOP = 3200' Max Angle = 44 @ 6800' ï5ätu rÏÙvlD ;........ ....... ····..··NïA ·ÖiitLiïïï fVÖ; .... . ..... ääÖÓiss GRAY GRAY .. AXËlSON 49' IT' TBG, 29#, L-80, .0371 bpf, D = 6.184" H 17-5/8" TBG, 29.7#, L-80, .0459 bpf, 10 = 6.875" H 17"TBG,29#, L-80,.0371 bpf,ID=6.184" H TOPOF 7-5/8" TBG H 113-3/8" CSG, 72#, N-80, 10 = 12.347" H Minimum ID = 4.843" @ 8245' BAKERSHEAROUTSUB ') WGI-04 /1 \ 2' I 2180' 1 \ / 2186' ~~..!l 2186' ~ ~ I \ 2733' ~ ~ 17-5/8"TBG, 29.7#, L-80, .0459 bpf,lD =6.875" H 8112' ITOP OF 7" TBG H 8112' ) SAFEfYNOTES: ***SLOW IA X OA CO MM. OPERAT1NG LIMITS: MAX lAP = 2000 PSI; MAX OAP = 2000 PSI (06/22/04 WAlVER)*** 2' I~T' X 7-5/8" XO 1 2180' 1-17-5/8" X 7" XO, 10 = 7.625" I 2181' I-IT' CL\M BAL-O SSSV NIP, 10 = 5.937" I 2186' 1--17" x 7 -5/8" XO, 10 = 7.625" I \ I 8112' 1-l7-5/8" x 7" XO, 10= 7.0" I z ~ 8115' 1-19-5/8" x 7" BKR SA B PKR 1 ! , 8133' I--1T' HES RN NIP, 10 = 5.5" I 8142' I-iT' TUBING TAIL WLEG Z ~ 8228' 1-19-5/8" x 7" BKR SB-2 PKR 8245' 1-i7" BKRSHEAROUf SUB, 10= 4.843" 8246' 1-i7" TUBING TAIL I 8227' I-iELMD TT LOGGED OS/25/87 I . . ..a1 ~ IT'TBG,29#, L-80,.0371 bpf,ID=6.184" H 8142' I TOP OF 7" TBG H 8228' 17" TBG, 29#, N-80, .0371 bpf, 10= 6.184" H 8246' I TOP OF 7" LNR H 8332' 19-5/8" CSG, 47#, N-80/S00-95, 10 = 8.681" H 8643' PERFORATION SUMVlARY REF LOG: BHCS ON 10/16/79 ANGLE AT TOP PERF: 19 @9034' Note: Refer to Production DB for historical perf data SIZ E SPF INfER\! AL Opn/Sqz ()ð. TE 3-3/8" 4 9034 - 9134 0 OS/25/87 3-3/8" 0 9142 - 9309 0 OS/25/87 3-3/8" 4 9320 - 9362 0 OS/25/87 3-3/8" 4 9366 - 9380 0 OS/25/87 3-3/8" 4 9392 - 9402 0 OS/25/87 3-3/8" 4 9416 - 9438 0 OS/25/87 3-3/8" 4 9449 - 9469 0 OS/25/87 I I I I I AHD I~ 9550' & 17" lNR, 29#, L-80, .0371 bpf, 10 =6.184" 1-1 9584' DATE 10/28/79 08/16/97 11/03/01 06/22/04 REV BY CO MrÆNfS ORIGINAL COMPLETION LAST WORKOVER RN'TP CORRECTIONS ATD'TLP WAIVER SAFElY NOTE ()ð. TE RBI BY COM\ll8\lTS ffiUŒfOE BAY UNIT W8.L: VVGI-04 Æ~rr No: 1790500 A PI No: 50-029-20386-00 SEC 11, T11N, R14E BP Exploration (Alaska) ~~----~~-~----------~-_._----~----,,-------- . ~----=---- "'~·_--~~-~-~~~""""""~__~___>-<~Or~ WGI..o4 TIO Plot 4.000 ,-- - .- -, - -- __n______ - "----. .- -- - ----~--"-~-------------~~--------~------___________~___________._~_..~~~~_____~__-_~_____.___________.______,.._~__ __.~___.__.____.._ __ ~.... J.. At ~~"'-~JLI"~~~~JJ Il~r.. ~ 3.000 - 7" .... ¡ G) ... = fA I ... Q. o 411112004 ... I 611112004 j 811112004 ! 1 0f1112004 j 1211112004 211112005 411112005 ~- - - -- --- .---~~~~~,-- --e----~___ --~---<--~~~~~>_._-.~-_ --.--~___~_~_,,_..~_------+~_~,~~~~~~~-_~_~__~~_~~.____-.----,_~__~__"_-~__~ _ -~-'_r-.-__________~____" ._..___ ._~______ ____.~ ____ . ...... T. , -- .IA ..... OA OOA __ O("lf1A ~ Re: WGI 90-day retest ) Subject: Re: WGI 90-day retest From: James Regg <jim_regg@admin.state.ak.us> ~e¿a \ ~I Z:;(OIt Date: Fri, 15 Oct 2004 08:53:50 -0800 . r l To: "GPB, Ops Supt" <GPBOpsSupt@bp.com>, AdmiriAOGCC Prudhoe Bay: <a9gcc-prudhoe_bay@admin.state.ak.us> .. . .. .. . ) {;(l - i1Q-Oçv ~Ú&l -tJ.. Gilbert - When the Commission places a pad on 90 day test cycle, the intent of our letter is that ALL wells on the pad are tested at a 90 day cycle until you have demonstrated a failure rate that is acceptable «10%). If you have tested only those that failed, you have not satisfied our intent. What BP has done for WGI (as described) would be appropriate if we were looking at individual well failures, which is not the approach that was adopted for determining an acceptable failure rate for SVS. You should schedule a retest of WGI pad wells to be in compliance with our August 25 letter. Note that this has been copied to our inspectors to clarify any misunderstanding on their part. Jim Regg Inspection Supervisor AOGCC GPB, Ops Supt wrote: Jim Last week, one of our step -up DS Leads contacted John Crisp and arranged for the 90 day retest of WGI per your letter dated August 25, 2004 to Bruce Williams. John's understanding was that only the devices that failed (i.e., the SSSV on WGI-01 and WGI-04) needed a retest, and not the entire pad. Our DS Lead complied with this. Please confirm that we have met the requirements per your August 25th letter. Thanks, Gilbert Wong SCANNE[) NO\J 1. 6 2004 1 of 1 10/15/2004 8:54 AM /71-050 ~1f~1fŒ (ill~ !Æ~~~~~ / AI.ASIiA OIL AND GAS / CONSERVATION COMMISSION / I FRANK H. MURKOWSKI. GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 25, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from BP Exploration (Alaska) Inc. ("BPXA") documenting July 18, 2004, tests at Prudhoe Bay WGI-pad. Attached is a copy of the SVS Test Report. A subsequent Commission- witnessed test of Wells WGI-Ol and WGI-04 on August 7, 2004, revealed a repeat failure of the subsurface safety valve in Well WGI-04. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. Conservation Order 363 further clarifies that if installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the July 18,2004 test. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective July 18, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU WGI-pad must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, g~~ í? fI Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: PBU_WGI Insp Dt 07118/200 Inspected by Interval "Field Name PRUDHOE BAY Operator BP EXPLORA nON (ALASKA) INC InspNo SVSOPOOOOO0754 Related Insp: Operator Rep Bill Palmer Reason ISO-Day Src: Operator Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil, WAG, GIN], GAS, CYCLE, SI Inner PSI Outer PSI Tubing PSI YeslNo YeslNo WGI-OI 1790310 3725 2900 2600 P P 8 GIN] WGI-02 1790430 3725 2900 2650 P P P GIN] WGl-03 1790490 3725 2900 2620 P P P GINJ WGl-04 1790500 3725 2900 2680 P P 8 GIN] WGI-05 1900250 3725 2900 2460 P P P GINJ WGI-06 1900300 3725 2900 2360 P 4 P GIN] Retest Date: 7/20/2004 WGI-07 1900400 3725 2900 2360 P P P GIN] WGI-08 1900490 3725 2900 2400 P P P GINJ Comments Performance WGl-OI 7/18/2004: No press bleed down observed during SSSV test. WGI-06 7/20/2004: SSV serviced and passed retest. WGI-06 7/18/2004: SSV slow leak thru observed. WGI-02, 03 and 04 tested 7/17/2004 Wells 8 Components 24 Failures 3 Failure Rate 12.5% Thursday, August 12, 2004 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supen'isor í<~7 (~(Z(dcYt DA TE: Monday. June 21. 2004 SliB.JECT: t\1echanl~allnLegrlt) Tests BP EXPLORA nON I ALASK.A I rNC FROM: Jeff Jones Petroleum Inspector WGI-Ü4 PR UDHOE 8A Y UNIT \\'GI-04 I'-&~OSV Src: Inspector Re\'iewed By: P.I. Supn' 5f)/2- Comm NON-CONFIDENTIAL Permit Number: 179-050-0 Inspector Name: Jeff Jones Inspection Date: 6/20/2004 Well Name: PRUDHOE BA Y UNIT WGI-04 Insp Num: mitJJO~0621062350 Rellnsp Num: API Well Number: 50-029-20386-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WG 1-0-1 T)'pe Inj. N TVD 8596 IA Jûo -1500 -1500 -1-190 P.T. 1790500 TypeTest SPT Test psi 1806 ~5 OA -10 360 370 390 I nter\'a I REQVAR P/F P Tubing 1850 :!15ü 21-10 2130 Notes: BPX.A wai\'ered \\'ell: known 9 5/8 :,. 13 3/8 commUnlcallon. TTP set ,g' 8116' t\1D. The well was not on injection and was nOt at operating temperature 4.1 BBLS diesel pumped. ~~l( JërÌ ,Ù) A.oE-Cc. C\/fI1.'\h' £.( SLt. ~ì~,/\ I' ~( a...~C tl (?-l-l t\10nday. June 21. 2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~¿ti'1 b!ZC¡/('4. P.J. Supervisor l DATE: t\tonday, June 21. 2(10-1 SlIBJECT: t\techanicallmegrlt) TölS BP EXl'LOR..o\ nON IAl..o\SK.A'J rNC FROM: Jeff Jones Petroleum Inspector \\'GI.Ù4 PRUDHOE BAY UNIT WGI-ù4 Src: Inspector Re\'iewed By: NON-CONFIDENTIAL P.I. Supn' Comm ~'r~ \Vell Name: PRUDHOE BAY UNIT WGI-04 Insp Num: miLIJ04062 1 064 148 Rei Insp Num: API Well Number: 50-0:!9-20386-00-00 Permit Number: 179-050-0 Inspector Name: Jeff Jones Inspection Date: 6/20/2004 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well WGI-04 Type Inj. N TVD 8596 IA 1980 2420 :!-I20 2400 P.T. 1790500 TypeTest SPT Test psi I 8ù6 25 OA 180 -1500 -1360 43~0 Inten'al REQV AR P/F P Tubing I 1700 1765 1770 1770 Notes: I'vllT-OA BPXA waivered well: known 95/8 x 13 3/8 communication. TTP set @ 8116' 1\10. The \\ell \\'as not on injection and was nO! at operating temperature. 3 BBLS diesel pumped. ,AJc' A(~('c. c:<rffÛ"E'C./ SLLv'\C\rð : ..see CL+ktc (...~-tf:. Monday. June 21, 2004 Page I of I \v'GI-O-t (PTO 179-050) Subject: WGI-04 (PTD 179-050) I ~ From: James Regg <jim_regg@admin.state.ak.us> ~q b/1..1 CI . Date: Tue, 29 Jun 2004 14:09:37 -0800 .. . - . .. . ..0 To: '~SU, AÐW Wellfutegrity Engineer" <NSUADWWellIntegrityEn~eer@B;P.cp~>:~\~:"::i.' CC: W~ton GA~~e:rt .<winto~_aUbert@~uhnirLstate.ak.us> .. . :' ':'..~, -','- ¡: ',,- \~'.-, : -' "-,'. #. - I.' ...:.. AOGCC inspector witnessed two MITs atWGI-04 (6/20/04); noted in his report was the fact that WGI-04 has a BP internal waiver for known IAxOA communication. Continued operation of WGI-04 requires an AOGCC approved sundry application. Please also note that the well should be placed on our monthly injector waiver list. Jim Regg I of I 6/29/2004 2:09 Pl'v Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Sunday, January 12, 2003 7:54 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); 'NSU, ADW Well Integrity Engineer' Subject: Information concerning BP Internal waivers at NGI and WGI Tom and Jim, ©'" Please see the information that you requested concerning the as in :.ells with BP I g g J Y q internal waivers below. NGI -07: Waivered for production casing leak on 10/23/90. Records indicate on 8/20/90, the IAP was pressured to 2200 psi when it suddenly dropped to 2100 and started falling. A CMIT TxIA conducted 10/08/90 failed to hold 2500 psi. MITIA's routinely pass to 2000 psi, the most recent was on 06/02. WGI -04: W aivered for slow IAxOA comm on 4/28/00. MITIA passed 10/02 to 2650 psi. OA re- pressure review conducted 12/02 indicates the IAxOA communication is no longer present. WGI -05: Waivered for slow IAxOA comm on 5/12/00. MITIA passed 06/02 to 2060 psi. OA re- pressure rate not recently quantified. TIO trends indicate IAxOA comm is still present. If you have any questions, or would like to discuss in greater detail, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1- 907 - 659 -5102 pgr. 659 -5102, x. 1154 ,� - - - -- Original Message---- - From: Tom Maunder [mailto:tom maunder @admin.state.ak.us] Sent: Tuesday, December 24, 2002 9:41 AM To: Cubbon, John R Cc: Jim Regg (E- mail); NSU, ADW Well Integrity Engineer Subject: Re: NGI -11 (PTD #1770800) OA pressurization John, We have received you message with regard to NGI -11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. I seem to remember some discussions with regard to a couple of WGI wells that may have BP's internal waivers. Would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver. We suggest that you also look into repairing the well. Tom Maunder, PE AOGCC " Cubbon, John R" wrote: > Hi Tom and Jim, • The NGI pad operator has notified us that the bleed frequency for the • OA 1 at 0 > NGI -11 has increased recently. A brief history of events is as follows: > > 05/02/00: MITIA Passed to 3000 psi. > > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > > 10/19/02: DSO reported OA had jumped from 1600 to 2100 psi > > overnight. IA > gauge on wellhead shows 200 psi higher than test gauge. > > 10/20/02: PPPOT -T PASSED > > 12/22/02: PPPOT -IC PASSED > > 12/23/02: OAP increased 750 psi in 2 days. > • n see from the attached TIO lot since October 2002 the OA As you can p • repressurization rate for this well has increased. The source of the • pressure in the OA does not appear to be communication through the wellhead > (passing PPPOT -IC). > Our plan of action is as follows: > 1. MITIA to 3000 psi with the OA bled down to < 500 psi. > 2. MITOA to 3000 psi. > 3. Evaluate for an internal waiver to allow OAP to go to a maximum of > 2000 psi. • Please let me know if you would like us to procede in a different • manner or > if more information is required. > Thanks, • John Cubbon • GPB Well Integrity Coordinator • 1- 907 - 659 -5102 • pgr. 659 -5102, x. 1154 > «NGI -11 TIO.jpg>> «NGI- ll.pdf>> «NGI -II Inj. plot.jpg>> > ------------------------------------------------------------------------ > Name: NGI -11 TIO.jpg > NGI -11 TIO.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 > Name: NGI- ll.pdf > NGI- ll.pdf Type: Acrobat (application /pdf) > Encoding: base64 > Name: NGI -II Inj. plot.jpg > NGI -II Inj. plot.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 2 • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellintegrityEngineer @BP.com] Sent: Sunday, October 20, 2002 3:54 PM To: Maunder, Thomas E (DOA) Cc: 'jlanders @alaska.net' Subject: Information concerning internal waivers on injectors, and information about WGI -04 and WGI - 05 Attachments: WGI- 04,05.ZIP; Waiver'd injectors.xls CX :0 Hi Tom, Please see the attached spreadsheet and Word document for the information that you requested concerning BP's internally waivered wells and th WGI -04 and WGI -05 wells. Joe Anders has gathered some additional information to present to you and he will likely be contacting you on Monday, October 21, 2002 in order to set up an appointment. Please let me know if you have additional questions or need additional information. Best Regards, John Cubbon Well Integrity Engineer 659 -5102 � � �� � `� Zola V� Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Monday, October 21, 2002 5:40 PM To: 'Cammy Oechsli; 'Mike Bill'; Regg, James B (DOA) Subject: [Fwd: Information concerning internal waivers on injectors, and information about WGI -04 and WGI -05] Attachments: Information concerning internal waivers on injectors, and information about WGI -04 and WGI -05; tom_maunder.vcf EJ Id Information tom_maunder.vcf - oncerning interna... Here is the info I received in answer to my email. Tom • i Review of Ann -Comm Activities at WGI -04 and WGI -05 WGI -04: OA wavier for 2000 psi service, dated 4/28/00 > 04/07/99: Checked IAxOA packoff - bled off & did not build up. > 08/01/99: MITIA / MITOA Passed. > 03/17/00: DSO bled OA 1000 /550, monitored buildup rate > 05/05/00: DSO bled OA 2200/800 psi > 05/06/00: Distributed OA waiver > 08/09/00: MITIA, MITOA passed WC > 11/14/00: Bled IA 2000/1500, OA 1800/1000 > 02/11/01: DSO bled IA 2200/1600 > 06/14/01; DSO bled IA 2100/1580, bled OA 2100/1500 > 07/17/01: DSO bled IA > 09/26/01: MIT IA & MIT OA Passed (WC) > 12/27/01: DSO bled IA 2150/1500, bled OA 2150/1350 > 01/26/02: Valve Shop pumped 5 gallons GX down control line, did not see a pressure increase. > 02/03/02: DSO bled IA 2200 to 1500 psi, gas > 02/07/02: SL R &R SSSV - Control line would hold pressure > 02/08/02: DSO bled IA 2200 > 1700 > 02/10/02: DSO bled IA 1900/1400, Bled OA 1400/800 > 02/14/02: Monitor IAP > 02/15/02: PPPOT -T & PPPOT-IC Passed > 06/02/02: DSO bled gas from IA 2150 > 1150, Bled OA 1900 > 1200 > DSO ble IA 2 2_00 >1 4 0 0 -- - -- WGI-04 Annulus Pressures — so" TN OA n i 4 � 1 0A 812001 1 A 0I 002 411 er"2 7/18/2002 1011 WW2 WGI -05: OA wavier for 2000 psi service, dated 5/12/00 > 02/07/99: Valve shop pumped 4 gal of GX Sealant down Balance line. Did not pressure up. > 02/14/99: Ran re- packed SSSV; tested OK 2600/2200/2200 psi. > 07/29/99: DSM added GX Seal, cntl line held 4950 psi for 15 min. Per DSO notes, GX no help, WL time. > 07/31/99: Called DSM to re -apply GX. Cntl line tracks tbg, Bal line tracks IA, indicates upper set (of 3) packing is leaking. Pull and redress SSSV if GX fails. MITIA & MITOA Passed. > 8/13/99: DSM removed GX Sealant set -up. Seems to be holding good. > 08/23/99: SSSV pulled, ran WRDP with 3 sets packing. Bal would not hold. > 02/04/00: IA /OA 1680/1600 > 02/08/00: Loaded well with water wash, PPPOT -IC PASSED > 03/17/00: DSO bled OA 1100 /500 > 04/06/00: DSO bled OA 1100/700 psi > 04/13/00: DSO bled IA 1400/650, OA 1000/400 > 04/26/00: DSO bled OA 1300/500 > 04/30/00: DSO bled IA 1500/750, OA 1100/750 > 05105100: DSO bled IA & OA 1200/600 psi > 06/05/00: DSO bed IA 2075/1200, OA came down 1725/1600 > 09/01/00: DSO bled IA 2100/1500, OA 2000/1500 (MIT's (P) 08/08/00) > 11/18/00: Valve shop pumped GX into balance line > 08/15/01: MIT OA Passed > 08/25/01: AOGCC MIT IA Passed > 11/14/01: DSO bled IA 2200/1700 - OA 2200/2000 > 11/15/01: PPPOT -T Failed > 11/22/01: Bled down high OAP 2000 > 350 > 12/07/01: DSO bled IA > 01/21/02: CO ISSSV > 06/01/02: MITIA PASSED to 2060 psi ( AOGCC -J. Crisp) > 06/09/02: MITOA PASSED to 2000 psi (WC) > 08/09/02: Valve shop pumped GX sealant down the control line. > 08/17/02: Bled IA from 2230 psi to 400 psi and OA from 2070 to 350 psi. Valve crew called out to pump GX sealant into balance line. > 08/18/02: IAP gained 1200 psi and OAP gained 230 psi since yesterday. > 08/20/02: SL changed out SSSV in an effort to stop leakage past packing and into the IA. > 08/21/02: Bled OAP > 10/16/02: T /UO = 3650/260/230 psi. 0 WGI -05 Annulus Pressures Tbg 0 i o • y ° o IA � CV a. j i i I -a- OA, r 10t18t2001 1 A 88002 4118!1002 7/18rAM 10A 812002 1/3 GPB AOGCC Sundry & Waivered Injectors Revised: 10/20/02 AO" T $66d'taf9lsrr� " Cf1A1T #]{. r_Ni�tT IA Fi.I �" LTSi 1tIEPEi f I#ttTiL1NA C�fNrN1EFiTS AOGCC Sundry 300 -198, Slow TxIA comm 01 -08 IN YES TxIA Slow 1 121 48 12 Y YES 8/15/00 01 -09A In' IYES - PC leak IAxOA 481 1 12 12 YES AOGCC Sundry 300 -107, PC Leak 5/9/00 AOGCC Sundry #300 -106, IAxOA comm, 03 -10 IN YES IAxOA 24 YES 5/9/00 AOGCC Variance #399 -084, Rapid TAA comm 03 -11 In' YES TAA rapid 24 YES 5/21/99 • 03 -33 In' NO TAA 12 12 l Waivered, Slow TAA comm to MI 9112/96 04 -11A In' In Progress TAA Slow I I YES AOGCC Sundry in progress, Slow TAA comm AOGCC Sundry 301 -162, Rapid TAA comm 04 -17 In' YES TxIA 24 YES 10/11/02 04 -28 In' NO TxIA 12 Waiver, TAA comm 11/6/90 04 -42 In' YES TxIA 24 YES AOGCC 302 -059, TxIA comm 2/19/02 04 -45 In' YES TAA 24 YES AOGCC 300 -173, TAA comm 7/5/00 09/12 In' NO TAA - MI 24 24 Waiver, TxIA comm when on MI 3/15/99 Waivered, TAA comm [9/23/91] Possible IAxOA 09 -15 IN NO possible TxIAxOA 12 12 12 comm as well AOGCC Sundry 301 -351, Slow TAA comm 09 -37 In' YES TAA Slow 48 12 YES 12/21/01 AOGCC Sundry 301 -350, Slow TxIA comm 09 -40 In' YES TAA Slow 12 48 12 YES 12/21/01 AOGCC Sundry 9 -490, Slow TxIA comm 11 -10 In' YES -Slow TAA IAxOA 12 11/30/90 Possible IAxOA comm not TAA comm AOGCC Variance #398 -035, Slow TxIA comm 11 -29 In' YES TxIA Slow 48 12 YES 2/22/98 Waivered, Slow TxIA comm to MI [5/17/00] Possible slow IAxOA comm, Need to remove • 12 -02 IN NO IAxOA Slow 12 12 IAaiver on TxIA comm AOGCC Sundry # 301 -244, TAA comm 12 -21 In' YES TxIA 1 1 241 12 YES 10/16/01 12 -23 In' IYES IAxOA Rapid 24 YES AOGCC 300 -174, Rapid IAxOA comm 7/5/00 13 -09 In' YES TxIA Rapid 24 IYES AOGCC 301 -159, Rapid TAA comm 10/11/011 13 -15 In' IYES TAA 24 IYES IAOGCC 399 -091, TxIA comm 6/16/99 13 -31 In' YES TxIA Rapid 24 1 YES AOGCC 300 -188, Rapid TxIA comm 8/1/00 14 -14 In' YES TAA Slow 48 48 121 1 1 YES AOGCC 300 -199, Slow TxIA comm 5/9/00 14 -21 In' YES TAA Rapid 24 I I I I YES AOGCC 399 -248, Rapid TAA comm 12/17/99 AOGCC Sundry-Waivered Injectors rY 1 2/3 Y1lE�.0 �i�hil��.L � ._ ��, � .. IM�i��f1"f#LY � � Mt1 : f 11 #- 3A Chill 1 1 ,t 1VFT �+�"+F�t�'' , 1� C1a�i �, W14PS ILTS''� I�ITI�?�il�E. �C311Mt�1� Waiver, AOGCC verbal approval, TxIA comm when on MI [3/2/93] Possible IAxOA comm 16 -02 I Ini NO Possible TxIAxOA 12 12 12 and /or PC Leak Waiver, AOGCC verbal approval, TAA comm 16 -03 IN NO Possible TxIAxOA 12 12 12 12 when on MI [8/9/931 Possible IAxOA comm AOGCC verbal approval; TAA comm when on MI [2/22/94] Evidence of comm non - existent, 16 -05 In' NO TxIA - MI 12 12 12 need to cancel verbal sund Waiver, wtr &MI injection, Slow IAxOA comm 17 -06 IN NO IAxOA Slow 121 1 1 12 2/26/99 AOGCC Sundry in progress, TxIA comm, A -05 In' In Progress TAA YES LLR =.83b m @ 2750 psi AOGCC Sundry #301 -245, Rapid TxIA comm A -17 In' YES ITxIA Rapid 24 YES 10/16/01 A -31 In' YES PC Leak 24 12 12 YES AOGCC 300 -008, PC Leak 1110/00 AOGCC verbal approval, TxIA comm (possible leak @ bottom connection of upper packer) L -108 IN NO TxIA 6 10/02/02 LPC -01 In' NO PC Leak 12 Waiver, Small Packer Leak 7/12/93 AOGCC Sundry #302 -169, Rapid TxIA Comm M -30 In' YES TxIA Rapid 24 YES 6/6/02 NGI -07 In' INO PC Leak 12 1 Waiver, PC Leak NK -65 In' IYES TxIA Rapid 24 YES AOGCC 302 -168, Rapid TxIA comm 6/6/02 AOGCC Sundry #302 -016 expires 10/31/02, NS -29 IN YES TxIA Slow 1 241 121 3 iSlow TxIA comm 2/19/02 AOGCC Sundry #302 -017 expires 10/31/02, NS -31 In' YES TxIA Slow 24 12 3 Slow TxIA comm 2/19/02 P1 -01 In' IYES TxIA Rapid 12 YES AOGCC 398 -188, Rapid TxIA comm 7/22/98 AOGCC Sundry 300 -038, Rapid TxIA comm P -14 IN YES TxIA Rapid 24 YES 2/10/00 Waiver, TxIA comm on MI, Waiver needs • updating /canceling for WAG injection, No P2 -29 IN NO ?? 12 evidence of TxIA comm AOGCC Sundry # 301 -246, Rapid TxIA comm P -23 In' YES TxIA Rapid 24 YES 10/16/01 AOGCC Sundry #398 -243, Slow TxIA comm P2 -34 In' IYES TxIA Slow 24 12 12 IYES [9/23/981 Possible IAxOA comm Not a waiver; TxIA and Low OA FL, MONITOR S -25 In' NO TxIA, Low OA FL 1 6 6 Y LTSI TROUBLE WELL Waiver, Slow TxIA comm [5/13/01] Currently SI, S -31 IN NO I High IAP 12 Possible high IAP AOGCC Sundry # 301 -160, Slow TxIA comm U -05 In' YES TxIA Slow 48 12 Y YES [10/16/011 Current) SI AOGCC Sundry # 302 -170, Slow TAA comm W -42 IN YES TxIA Slow 48 12 YES 6/6/02 Possible IAxOA comm WB-06 In' I In Progress TxIA Slow AOGCC Sundry in progress, Slow TxIA comm AOGCC Sundry- Waivered Injectors 3/3 A I,E rY� u i ena' �A�t t 1 7- 14mll "AIM ::,PPP 0' tl� L A"1F W1 �'' Sf*?,` �i i1�171�3 �Gt3l�M� WGI -04 IN NO IAxOA 12 12 Waiver, IAxOA comm 4/28/00 WGI -05 In' NO IAxOA 12 12 X X Waiver, IAxOA comm 5/12/00 AOGCC Sundry # 301 -068, Slow TAA comm Y -03 In' YES TAA Slow 48 12 YES 4/27/01 AOGCC Sundry #300 -103, Rapid TAA comm Y -10 In' YES TxIA Rapid 24 YES [4/20/00] r I AOGCC Sundry- Waivered Injectors • • Maunder, Thomas E (DOA) From: Tom Maunder [tom_m au nder@ad min. state. ak.us] Sent: Wednesday, October 16, 2002 5:06 PM To: 'Joe Anders /Kevin Yeager'; 'Kira Barton' Cc: Regg, James B (DOA) Subject: WGI -04 a nd WGI -05 Attachments: tom_maunder.vcf r A CI ` C S-0 tom_maunder.vcf John, I was just looking at Jeff Jones reports of safety valve testing at WGI. He notes that the subject wells are on BP's internal waiver list for 9 -5/8" x 13 -3/8" communication. Please provide additional information with regard to the problems on these wells. This should include when the problem was noted, the diagnostics performed to determine the problem, what the IA and OA pressure history are, how often these annuli may require bleeding down. By copy of this email, you are also requested to provide a listing of ALL service wells that are presently waivered under BP's internal system. I will be out of town tomorrow and Friday. I would appreciate finding this information in my email box on Monday morning. Please call with any questions. Tom Maunder, PE AOGCC Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, October 16, 2002 5:07 PM To: 'Cammy Oechsli'; Seamount, Dan T (DOA); 'Mike Bill'; DOA AOGCC Prudhoe Bay Subject: [Fwd: WGI -04 and WGI -051 Attachments: WGI -04 and WGI -05; tom maunder.vcf U WGI -04 and tom_maunder.vcf WGI -05 All, Enclosed is a note I sent to Joe /Kevin, et al. When Jeff went out for some safety valve tests at WGI he noted that these 2 wells were tagged indicating they are on BP's internal waiver system. This was news to me. Tom I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor Chairman THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector DATE: October 20, 2002 SUBJECT: Mechanical Integrity Tests BPX WG'I WG 1-04 PBU Prudho® Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ,' WellI WGI-04 I Typelnj. i' ~' '1 T'V:D' J 7226 I Tubingl 3600 I 3600 I 3600 J 3600 I lntervall O P.T.D.I 179-050 ITypetestl P ITestpsil 1807 ICasingI' 150 I 2650l 2650} 2650I P/F I 13 Notes: Waiver compliance ,' 'p.T.D.i Notes: P.T.D. Notes: P.T.D. Notes: We, il p.T.D. Notes: Type testI ITM psi l I Casing I I I "' I I P/F I / / I Type Inj' I .....IT'V'D' I I Tubing I I I I I Intervall I TypetestI ' IT's{ psiI I Casing I I I I I P/F I I I I Type InJ. I I I I Tubing I I I I IIntervallI I Type testI ITest psi l I Casing I I I I I P/F I I I IType Inj. Type test Type INJ. Fluid Codes F -- FRESH WATER IN J. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O-- Other (describe in notes) I traveled to BPXs WGI pad and witnessed the annual MIT on well WGI-04. This well. has a waiver due to IA X OA communication, records indicate 150 psi per day leak rate. The pretest tubing and casing pressures were observed for 30 minutes and found to be stable. The casing was then pressured tested with no indication of communication during this 30 minute test. M.I.T.'s performed: l_ Attachments: Number of FailureS: 0 Total Time during tests: 1 hour CC: MIT report form 5/12/00 L.G. MIT PBU WGI-04 10-20-02 CS.xls 10/25/2002 MEMORANDUM TO: Julie Heusser, COmmissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 15, 2000 THRU: Tom Maunder, P. I. SuPerviso~o FROM: John Crisp~ SUBJECT: Petroleum InsPector Safety Valve Tests Prudhoe Bay Field VVGI Pad January 15, 2001. I traVeled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad. Bp representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a Safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valVes failed to h°ld DP. This well was shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected Wellhouses On WGI Pad during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 Wells, 24components tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspeCted, Attachments: SVS PBU WGI Pad 1-15,01jc cC; NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-Oljc.doc · ! Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field WGI Pad Separator psi: LPS HPS 1/15/01 3400 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE WGI-01 17903101 3400 2900 2440 P P P GINJ WGI-02 1790430! 3400 2900 ~650 P P P GINJ WGI-03 1790490! 3400 2900 2350 P P P GINJ WGI-04 1790500!~ 3400 2900 2350 P P P GINJ WGI-05 1900250! 3400 2900 2500 P P P GINJ WGI-06 1900300! 3400 2900 2460 P 4 9 GINJ WGI-07 19004~0~ 3400 2900 2480 P P P GINJ WGI-08 1900490' 3400 2900 2620 P P P GINJ Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% [] 90 Day Remarks: WGI-07 shut in untill repaired & re-tested. ' ,, o,,,, D.-,,),= ~ ,,el .qVR Pl~II WGI Pad 1-15-01ic.xls STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION COIVIMISSION 1. Operations performed: REPORT OF SUNDRY WELL OPERATIONS ~o,~?¢~fc& f6,4u~ ¢,7 []Operation Shutdown E~Stimulate []Plugging I-]Perforate [--I Pull Tubing []Alter Casing [~ Repair Well [--IOther r 2. Name of Operator 15. Type of well: 6. ARCO Alaska Inc. ! [] Development [] Exploratory 7. 3. Address [] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [~Service 4. Location of well at surface 8. 611' SNL, 1134' WEL, SEC. 11, T11N, R14E, UM 9. At top of productive interval 1535' NSL, 1116' EWL, SEC. 01, T11N, R14E, UM At effective depth 1618' NSL, 1227' EWL, SEC. 01, T11N, R14E, UM At total depth 1642' NSL, 1259' EVVL, SEC. 01, T11N, R14E, UM Datum Elevation (DF or KB) RKB = 49' Unit or Property Name Prudhoe Bay Unit Well Number WGI-4 Permit Number / Approval No. 79-50 397-127 10. APl Number 50-029-20386 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well Condition summary Total depth: measured 9584 feet Plugs (measured) true vertical 8596 feet Effective depth: measured 9459 feet Junk (measured) true vertical 8477 feet Casing Fill at 9459' ORIGINAL Length Size Cemented MD TVD Structural Conductor 45' 20" 338 sx Arctic Set 73' 73' Surface 2705' 13-3/8" 4000 sx Arctic Set II 2733' 2733' Intermediate Production 8615' 9-5/8" 500 sx Class 'G' 8643' 7705' Liner 1252' 7" 350 sx 8332' - 9584' 7417' - 8596' Perforation depth: measured 9034' - 9134', 9142' - 9309', 9320' - 9362', 9366' - 9380', 9392' - 9402', 9416' - 9438', 9449' - 9469' true vertical 8075' - 8168', 8177' - 8333', 8345' - 8383', 8389' - 8400', 8414' - 8423', 8436' - 8455', 8468' - 8486' Tubing (size, grade, and measured depth) 7-5/8", 29.7#, L-80, ST-L Mod to 2180'; 7", 29#, 2181' - 2186'; 7-5/8", 29.7#, L-80, ST-L Mod 2187' - 8112'; 7", 29#, 8113' - 8142'; 7", 29#, L-80 8228' - 8246' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SAD Packer at 8115'; 7" Camco Bal-O SSSV at 2181' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl ~l~.s_ka Oil & A~bor~9~ Casing Pressure Tubing Pressure 15. Attachments 116. Status of well classifications as: [-] Copies of Logs and Surveys run I I~ nil l~ G~-~ I~ Susnended ~ Daily Report of Well.~ations /q [ ~7~ ..... "' 17.1 hereby certify that tl~e forgoing is ~'/e~n~c/orrect to the best of my knowledge Signed ~---'~?-/'-~ ~ DanStoltz ~k"/~i~ ~ Title Senior Drillin~l Engineer I/'-~ Prepared By Name/Number: Service Water & Gas Injector Torrio HubblO's;6~i~8Duplicat Form 10-404 Rev. 06/15/88 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Barker, Elizabeth R (SAIC) [Elizabeth.Barker @bp.com] Sent: Monday, December 27, 2010 11:28 AM To: Maunder, Thomas E (DOA) Cc: Stewman, Sondra D; Barker, Elizabeth R (SAIC) Subject: RE: WGI -04 (179 -050) WO 8/11/97 - 8/t6/07 Attachments: WGI -04 RWO 1997.ZI P Hi Tom, I believe this is what you are looking for - RWO Operations Summary Report from 8/11 - 8/17/97. I have included Sondra as she is my mentor. Thank you, Liz Barker SAIC Projects Analyst D , 6 L U11 564 -5674 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, December 22, 2010 1:25 PM To: Barker, Elizabeth R (SAIC) Subject: WGI -04 (179 -050) WO 8/11/97 - 8/16/07 Hi Liz, This is not an urgent item. A workover was conducted on this well in August 1997. The operations report is in that same "short" format as I sent you on an earlier well. Could you please print off an operations report with greater detail? Returning via email as before will be fine. Thanks in advance for your assistance. Tom Maunder, PE AOGCC T oAow, o t0. �otiS c s QrovZcJ S v-r■■.9c_ \c��c,� O‘k\ VC= SG.��ti A ANCc" \t-- QC) 4CDC..Act- C‘ ik C5- (Y A-1 a f, - \. 12/27/2010 • • North America ALASKA BP Page 1 of 6'; Operation Summary:Report: Common Well Name: WGI- 04 _ DiMS i AFE No Event Type: COM- ONSHORE (CON) I Start Date: 8/11/1997 `End Date: 8/17/1997 4J9075 (0.00 ) Project: Prudhoe Bay (various) 1 Site: WGI Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1979 12:00:OOAM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °19'39.170 "0 Long: 0148 °29'56.399 "W Active Datum: ORIG KELLY BUSHING 44.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 8/11/1997 18:00 - 18:30 0.50 MOB P PREP Move rig *NO ACCIDENTS* NO SPILLS* ! I *895 DAYS SINCE LTA* *419 DAYS SINCE SPILL* *2 PJSM* Held safety meeting PJSM - TOPIC =N /D -N /U — 18:30 Completed operations 18:30 - 20:00 1.50 MOB P PREP Rig moved 100 % LAY HERCULITE & MATTING BOARDS -MOVE RIG OVER WELL -SPOT & SHIM SAME -PREP MUD TANKS TO TAKE ON FLUID- (ACCEPT RIG @ 2000 HRS. 8- 11 -97) 20:00 At well location - Celiar 120:00 22:00 2.00 FILTR P DE -COM Completion type Single Completion size 7 in Fluid system Fill pits with Brine FILL MUD TANKS W/ 9,6# BRINE -SPOT TIGER TANKS -BJ UNITS & STANBY MUD PUMP -FILL TIGER TANKS W/ 9.6# BRINE. __ ---- -.__ -- 22:00 Completed operations _._..___......_...__....-- 22:00 - 23:00 1.00 WCTRL P DE -COM Nipple up Lubricator Rigged up Lubricator RIG UP LUBRICATOR -PULL BPV -RIG DOWN LUBRICATOR. -RIG UP C ti__.__..__.___ -_ -. ________ . �_._.___ _ ._ _ 23:0 Equ p work completed _ __ 23:00 - 23:59 ' 1.00 FILTR P 1 ( DE -COM Fluid system Circulated at 8158 ft CIRC. TOTAL VOLUME OF WELL -FLOW _ – CHECK -WELL STATIC. --------------- - - -- 8/12/1997 00:00 - 01:00 1.00 FILTR P DE -COM Circulated at 8158 ft CIRC. TOTAL VOLUME OF WELL -FLOW CHECK -WELL STATIC. 01:00 Obtained bottoms up (100% annulus volume) __..._....__.__ 01:00 - 03:00 2.00 WCTRL P DE -COM Nipple down Surface tree Removed Surface tree RIG UP LUBRICATOR -SET BPV RIG DOWN LUBRICATOR = NIPPLE DOWN TREE & i I i ADAPTER FLANGE. I I 03:00 Equipment work completed_ 03:00 - 03:15 0.25 WCTRL P DE -COM Nipple up BOP stack *NO ACCIDENTS* NO SPILLS* *896 DAYS SINCE LTA" *420 DAYS SINCE SPILL* *2 PJSM* Held drill (Fire) AMAS -1 MIN. 30 SECS. 03.15 Completed operations _ - - -._ 03:15 - 06:00 2.75 WCTRL P DE -COM Rigged up BOP stack CHECK LDS,S - REMOVE CONTROL LINE ADAPTERS -N /U BOPE. 106:00 Stopped To hold safety meeting _ Printed 12/27/2010 11:18:47AM orth Ainerlca ALASKA - BP Page 2 of 6> Operation' Summary Report' Common Well Name: WGI- 04_DIMS AFE No Event Type: COM- ONSHORE (CON) Start Date: 8/11/1997 End Date: 8/17/1997 419075 (0.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 16 Spud DatefTime: 9/29/1979 12 ;00:00AM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °19'39.170 "0 Long: 0148 °29'56.399 "W Active Datum: ORIG KELLY BUSHING @44 5oft (above Mean Sea Level) Date From - To Hrs 1 Task Code J NPT NPT Depth Phase Description of Operations (hr) (ft)_...__._ -- _ __ - 06:30 0.50 WCTRL P - - -- DE -COM Heil safety meeting -- - -- PJSM= TOPIC =N/ BOPE - CELLAR SAFETY. 06:30 Completed operations } 06:30 - 08:30 2.00 WCTRL P DE -COM Rigged up BOP stack N/ U BOPE. 08:30 Equipment work completed__ 08:30 - 12:30 4.00 FTEST P DE -COM Test well control equipment Tested BOP stack RIU & TEST BOPE TO 250 - 5000#- (WITNESS TEST WAIVED BY CHUCK CHEVEY - AOGCC) 12:30 Function test completed satisfactorily ___ 12:30 - 15:30 3.00 PULL P DE -COM Pull Tubing, 7 in O.D. Laid down 21 ft of Tubing PULL TEST DART -R/U LUB. -PULL BPV -R /D LUB. =MAKE UP DUAL SPEAR W/ 6.220 GRAPPLES - PACKOFF & BUMPER SUB- BOLDS,S -PULL HANGER TO RIG FLOOR W/ 275K= STRING WT. 230K. =RIG DOWN SPEAR ASSEMBLY & HANGER. - 15:e at 81d0 0 Completed Aerations 15.30 - 16 :30 1.00 PULL P DE-COM Circulated ft 16:30 Obtained bottoms up (100% annulus volume 16:30 - 17:00 0.50 PULL j P DE -COM Laid down 160 ft of Tubing LAY DOWN 4 JTS. 7" TBG. 17:00 Completed operations _ _______.-_ 17:00 - 18:00 1.00 PULL P DE -COM Serviced Retrievable packer PICK UP & MAKE UP STORM PACKER. 18:00 Stopped: To hold safety_meetin 18:00 - 18:30 0.50 PULL P DE -COM Held safety meeting PJSM= TOPIC =N /D N/U 18:30 Completed operations 18:30 - 19:00 0.50 i PULL P DE -COM Serviced Retrievable packer SET STORM PACKER & TESTED TO 1000#. 19 :00 Equipment work completed _ 19:00 - 20:00 1.00 PULL P DE -COM Retrieved Seal assembly running tool MAKE UP PACKOFF RETRIEVING TOOL - ATTEMPT TO PULL PACKOFF -SHEAR OUT -LAY DOWN RETRIEVING TOOL. 20 :00 Equipment work completed 120:00 - 23:59 4.00 WCTRL P DE -COM Nipple down BOP stack Installed Seal assembly N/D BOPE- REMOVE TBG. SPOOL & 9 5/8" I i PACKOFF - INSTALL LOWER & UPPER SECTIONS OF PACKOFF & NEW TBG. SPOOL. TEST TO 5000# OK, 8/13/1997 00:00 - 03:00 3.00 WCTRL P DE -COM Installed Seal assembly N/D BOPE- REMOVE TBG. SPOOL & 9 5/8" PACKOFF - INSTALL LOWER & UPPER SECTIONS OF PACKOFF & NEW TBG. SPOOL. TEST TO 5000# OK. 03:00 Equipment work completed Printed 12/27/2010 11:18:47AM It orth.America - ALASKA BP P of 6 `Oper.tion Report Common Well Name: WGI- 04_DIMS AFE No Event Type: COM- ONSHORE (CON) Start Date: 8/11/1997 I End Date: 8/17/1997 4J9075 (0.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No,: DOYON 16 Spud Date/Time: 9/29/1979 12:00:00AM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 *19'39,170"0 Long: 0148 *29'56.399"W Active Datum: ORIG KELLY BUSHING @44.50ft (above Mean Sea Level) Date 1 From - To I Hrs Task Code l NPT I NPT Depth Phase Description of Operations — - 03 :00 - 03:15 0.25 WCTRL P DE -COM Nipple up BOP stack *NO ACCIDENTS* NO SPILLS* *897 DAYS SINCE LTA* *421 DAYS SINCE SPILL* *2 PJSM* Held drill (Spill) AMAS -2 MINS. 03:15 Completed operations 03:15 06:00 2.75 WCTRL P DE -COM Rigged up E. BOP stack N!U BOP 06:00 Stopped : To hold safety meeting 06:00 - 06:30 0.50 WCTRL P DE -COM Held safety meeting PJSM= TOPIC = LAYING DOWN TBG. 06:30 Completed operations_ 06:30 - 07:30 1.00 FTEST P DE -COM Test well control equipment Tested Choke line TEST BOTTOM FLANGE & CHOKE LINE TO 250- 5000# OK.= INSTALL WEAR RING 07:30 Function test completed satisfactorily -- 07:30 - 09 1.50 l PULL P — ^ DE -COM Pull Tubing, 7 in O.D. Circulated at 7980 ft RETRIEVE STORM PACKER =FLOW CHECK =LAY DOWN PACKER -RIU CIRC. HEAD= CBU =R /U CONTROL LINE SPOOL WHILE CIRC. . i 1.___ 1 09:00 Obtained bottoms up (100% annulus volume) 09:00 - 09:15 0.25 PULL P DE -COM Held drill (Fire) AMAS =2 MINS. 09:15 Completed operations _...._.-------- 09:15 - 18:00 8.75 PULL P DE -COM Laid down 7740 ft of Tubing LAYING DOWN 7" 26 & 29# L -80 IJ4S & AB MOD LTC TBG. 18:00 Stopped: To hold safety -meeting.- __- .._..,....... 18:00 - 18:30 0.50 PULL P € DE -COM Held safety meeting I PJSM = TOPIC LAY DOWN TBG, 18:30 Completed operations 18:30 - 20:30 2.00 PULL P DE -COM Laid down 240 ft of Tubing COMPLETE LAYING DOWN 258 JTS. & CUT OFF PIECE OF 7 " TBG.-CHEMICAL CUT LOOKS CLEAN. (OLD TBG. TALLY SHOWS 33 CL CLAMPS RUN IN HOLE= RECOVERED 30 CL CLAMPS =3 LEFT IN HOLE.) ESTIMATE TOP OF FISH @ 8174. 20:30 Completed operations _ —__ _ _ _ -_ 120:30 - 23:59 3.50 RUN P DE -COM Drillpipe. 5 in workstring run * NO ACCIDENTS* NO SPILLS* *898 DAYS SINCE LTA* *422 DAYS SINCE SPILL* *2 PJSM* Ran Drillpipe to 4050 ft (5 in OD) MAKE UP 6.025 SPEAR - BUMPER SUB - JARS - PICKUP 9 6 3/4" DC,S- ACCELERATOR JARS & RIH W/ 5" DP. Printed 12/27/2010 11:18:47AM I orth ArneriCa. :ALASKA` = BP Page 4 of 6 Operation :Summary: R Common Well Name: WGI- 04_DIMS AFE No Event Type: COM- ONSHORE (CON) Start Date: 8/11/1997 1 End Date: 8/17/1997 419075 (0.00 ) Project: Prudhoe Bay (various) , Site: WGI Rig Name /No.: DOYON 16 ' Spud Date/Time: 9/29/1979 12:00:OOAM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWt / Lat: 070 °19'39.170 "O Long: 0148 °29'56.399 "W Active Datum: ORIG KELLY BUSHING Q44.50ft (above Mean Sea Level) Date From - To Hrs Task ` Code NPT NPT Depth Phase Description of Operations . ..- _– ...- ___ - -- ...__..:__...__.. E ..__(hr)._....._.._.__,._..__._ th) M Ran D UP 6.025 to SPEAR-BUMPER f t (5 in $114/1997 00:00 01:00 1.00 RUN P DE-COM Ran Drillpipe e fo 4050 ft 5 in OD SUB -JARS- PICKUP 9 6 3/4" DC,S- ACCELERATOR JARS & RIH W/ 5" DP. 01:00 Stopped : To hold drill 01:00 01:15 0.25 ( RUN P DE -COM Held drill (Kick while tripping) I E AMAS -1 MIN. 30 SECS. 01:15 Completed operations 01:15 - 06:00 4.75 RUN P DE -COM Ran Drillpipe to 8000 ft (5 in OD) FINISH PICKING UP 5" DP & RIH W/ PIPE IN DERRICK. 06:00 Stopped _ To hold safety meeting 06:00 06:i0 6 30 0.50 RUN P DE -COM Held safety meeting PJSM = TOPIC =P /U 5" DP. 06:30 Completed aerations — _ - - ___ - 06:30 - 07:00 0.50 RUN P 1 DE -COM Ran Drillpipe to 8164 ft (5 in OD) FINISH P/U 5" DP. 07:00 On bottom 07:00 - 07:30 0.50 RUN P DE -COM Washed to 8164 ft PICK UP KELLY =TAG & SPEAR FISH @ 8164-PULL 115K OVER STRING WT. -JAR FISH LOOSE. 07:30 On bottom 07:30 - 08:30 1,00 RUN P DE -COM Circulated at 8203 ft CBU. 08:30 Obtained bottoms up (100% annulus volume) 08:30 - 08:45 0.25 ; RUN P DE -COM Flow check t 08:45 Observed well static 08:45 - 11:00 2.25 RUN P DE -COM Pulled Drillpipe in stands to 0 ft --- -- J...___._.__..,.._._...... 11:00 Completed operations --- _._. -- 11:00 - 13:30 2,50 RUN P DE -COM Removed Tubing handling equipment LAY DOWN FISHING TOOLS -RIG UP HANDLING EQUIPMENT -LAY DOWN FISH - RECOVERED 1 JT. 7" TBG. -1 CUT OFF PIECE & SEAL ASSEMBLY. -CLEAR FLOOR. — 13:30 Eq_upment work completed 13:30 - 16:30 3.00 RUN I P DE -COM Ran Drillpipe in stands to 8203 ft M/U 8 112" REVERSE JUNK BASKET -9 518" CSG. SCRAPER & RIH. 16:30 At Top of liner : 8203 ft — -- _ 16:30 - 16:45 0.25 RUN P DE -COM Held drill (Spill) AMAS =3 MINS. 16:45 Completed operations 16:45 18:00 1.25 RUN P 1 DE -COM Circulated at 8203 ft DROP BALL & CIRC. @ 8203. — S t o p p e d s a f e t y - 18:30 0.50 RUN P DE -COM Held safety meeting PJSM = TOPIC =LD DP. 18:30 Completed operations —_ 18:30 - 20:00 1.50 RUN P DE -COM Circulated at 8203 ft CBU WHILE LOADING- STRAPPING & CLEANING 7 5/8" TBG. 20:00 Obtained bottoms up ( annulus volume) 20:00 - 20:15 1 0.25 RUN P DE -COM Flow check 1 L _____.__.___.._.._____ ._ 20:15 Observed well static Printed 12/27/2010 11:18:47AM orth America `ALASKA `- $P Page 5 of 6 • Operatioln :Summary Report Common Well Name: WGI -04 DIMS AFE No Event Type: COM- ONSHORE (CON) I Start Date: 8/11/1997 End Date: 8/17/1997 4J9075 (0.00 ) Project: Prudhoe Bay (various) Site: WGI Rig Name /No.: DOYON 16 Spud Date/Time: 9/29/1979 12:00:00AM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °19'39.170 "0 Long: 0148 "29'56.399"W Active Datum: ORIG KELLY BUSHING ©44.50ft (above Mean Sea Level) Date From - To Firs Task Code NPT I NPT Depth ` Phase Description of Operations 20:15 - 23:59 3.75 RUN P DE -COM Laid down 8203 ft of Drillpipe POH- LAYING DOWN 5" DP & DC,S.�LEAN REVERSE JUNK BASKET - RECOVERED APPROX. 2 CL BANDS -CLEAR FLOOR. 8/15/1997 00:00 - 05:30 5.50 RUN P DE -COM Laid down 8203 ft of Drillpipe POH- LAYING DOWN 5" DP & DC,S. =CLEAN { REVERSE JUNK BASKET - RECOVERED APPROX. 2 CL BANDS -CLEAR FLOOR. 05:30 Completed operations 05:30 - 06:00 0.50 WCTRL P DE -COM Completion type Single Completion size 7.625 in Nipple up Top ram *NO ACCIDENTS* NO SPILLS* *899 DAYS SINCE LTA* *423 DAYS SINCE SPILL* ( *2 PJSM* Removed Bore p rotector PULL WEAR RING. 06:00 Stopped: To hold safety meeting 06:00 - 06:30 0.50 WCTRL P DE -COM Held safety meeting PJSM= TOPIC= RUNNING 7 5/8" TBG- - 06 :30 Completed operations 06:30 - 09:00 2.50 WCTRL P DE -COM Rigged up Top ram CHANGE TOP RAM F/ 7" TO 7 5/8" & TEST SAME TO 2500# OK. -RIG DOWN TEST TOOLS. 09:00 Equipment work completed 09:00 - 14:30 5.50 RUN P DE -COM Run Tubing, 7.625 in 0.D. *NO ACCIDENTS* NO SPILLS* *900 DAYS SINCE LTA* *424 DAYS SINCE SPILL* *2 PJSM* Ran Tubing to 2400 ft (7.625 in OD) RIG UP HANDLING TOOLS & RUN 75/8" TBG. 14:30 Handling equipment failed- Change o • eration 14:30 - 15:30 1.00 RUN N FAIL DE -COM Serviced Tubing handling equipment TONGS BROKE DOWN= CHANGE OUT SAME. 15 :30E t_uipment w ork completed _....._..__ 15:30 - 18:00 2.50 RUN P DE -COM Ran Tubing to 4250 ft (7.625 in OD) RUNNING 7 5/80" TBG. 18 :00 Stopped : To hold safety meeting 18:00 - 18:30 0.50 RUN P 1 DE -COM Held safety meeting PJSM = TOPIC = WORKING W/ 7 5/8" TBG. 18:30 Completed operations - - 18:30 - 23:59 5.50 RUN P DE -COM Ran Tubing to 8141 ft (7.625 in OD) FINISH RUNNING 203 JTS. 7 5/8" 29.7# L -80 STL -MOD TBG. -W1 CONTROL LINE TO SSSV -MAKE UP LANDING JT. - HANGER -LAND TBG. & RILDS. 8/16/1997 00:00 - 06:00 6.00 RUN P DE -COM Ran Tubing to 8141 ft (7.625 in OD) FINISH RUNNING 203 JTS. 7 5/8" 29.7# L -80 STL -MOD TBG. -W/ CONTROL LINE TO SSSV -MAKE UP LANDING JT. 1- HANGER -LAND TBG. & RILDS. 106:00 Hanger landed _........___ ,_..._. ___...__._..._.. __.. Printed 12/27/2010 11:18:47AM 4 orth America • ALASKA BP Page 6 of 6 Operation Summary Report` Common Well Name: WGI- 04_DIMS AFE No Event Type: COM- ONSHORE (CON) j Start Date: 8/11/1997 End Date: 8/17/1997 4J9075 (0.00 ) Project: Prudhoe Bay (various) I Site: WGI Rig Name /No.: DOYON 16 I Spud Date/Time: 9/29/1979 12:00:OOAM Rig Release: 8/17/1997 Rig Contractor: DOYON DRILLING INC. UWI: / Lat: 070 °19'39.170 "0 Long: °29'56.399 "W 0148 Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations @ Active Datum: ORIG KELLY BUSHING (ft) 44 50ft (above Mean Sea Level) p 06:00 - 06:30 0.50 RUN 1 P DE -COM Held safety meeting PJSM= TOPIGN /D BOPE -------------.. _.._.____._._.._.1------- -. —_ -- 06:30 Completed operations 06:30 - 07:00 0.50 RUN P DE -COM Installed Accessories FINISH RILDS= TIGHTEN GLAND PACKING NUTS. I 07:00 Equipment work completed 07:00 - 08:30 1.50 RUN P DE -COM Circulated at 8141 ft PUMP CORROSION INHIBITOR & 40 BBL. DIESEL DOWN ANNULUS. 08:30 Stopped : To pressure test 08 :30 - 11:30 3.00 RUN P DE -COM Set Permanent packer at 8114 ft with 4000 psi DROP BALL -RIG DOWN LANDING JT. -SET PACKER -TEST TBG. TO 4000# -BLEED PRESSURE TO 1500 # -TEST BACKSIDE TO 4000# -30 MINS. OK. 11:30 Packer set at 8114 ft 11:30 - 14:00 1 2.50 WCTRL P DE -COM Nipple down BOP stack Installed Accessories SET BPV -TEST DART & TEST TO 1000#. 14:00 Equipment work completed .____.__.._..._.._...._..._.. 14:00 - 17:00 3.00 WCTRL P DE -COM Removed BOP stack CHANGE TOP RAMS TO 3 1/2 X 6 VARIABLES & N/D ROPE. 17:00 EguipInent work completed — —,— 17:00 - 18:00 1.00 WCTRL P DE -COM Nipple up BOP stack Rigged up Surface tree NIPPLE UP ADAPTER FLANGE & TREE, 18:00 Stopped : To hold safes meeting 18:00 - 18:30 0.50 WCTRL P DE -COM Held safety meeting PJSM - TOPIC= CELLAR WORK. 18:30 Completed operations 18:30 - 20:30 2.00 WCTRL P DE -COM installed Surface tree FINISH NU TREE & TEST TO 5000# OK. _. __.—..._...__ ___.._--- --- ------- ___._.._._'. _,.._._..... ....- •-------- ......----- - - -.__ -- -. __......._..__._ _ 20 °upmentwork_ completed-- _._._._..___...._.. 20:30 - 22:00 1.50 WCTRL P DE -COM Tested Additional services TEST ANNULUS TO 2000# (STATE REQUIREMENT) 30 MINS. WITNESSED BY JOHN SPALDING AOGCC. OK. 22:00 Function test completed satisfactorilX__ -__.__ 22:00 - 23:59 2.00 MOB P DE -COM Move rig Rig moved 0 % P L C CLEAN LEAN& SECURE TREE.=VIOVE OFF LOCATION. (RIG REL.EASE__©_0100 -8 -17- — 8/17/1997 00:00 - 01:00 1.00 MOB P DE -COM 1Rig moved 0 % PREP CELLAR & SECURE TREE. =MOVE OFF WELL & CLEAN LOCATION. (RIG RELEASE @ 0100- 8- 17 -97) 01:00 Rig off station__ _ — Printed 12/27/2010 11:18:47AM Facility Date/Time 11 Aug 97 12 Aug 97 13 Aug 97 14 Aug 97 15 Aug 97 16 Aug 97 WGI Progress Report Well WGI-04 Rig Doyon 16 Page Date 18:00-18:30 18:30-20:00 20:00-22:00 22:00-23:00 23:00-01:00 01:00-03:00 03:00-03:15 03:15-06:00 06:00-06:30 06:30-08:30 08:30-12:30 12:30-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-03:00 03:00-03:15 03:15-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-09:15 09:15-18:00 18:00-18:30 18:30-20:30 20:30-01:00 01:00-01:15 01:15-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:30 08:30-08:45 08:45-11:00 11:00-13:30 13:30-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-20:00 20:00-20:15 20:15-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 Duration 1/2 hr 1-1/2 hr 2hr lhr 2hr 2hr 1/4 hr 2-3/4 hr 1/2 hr 2hr 4hr 3hr lhr 1/2 hr lhr 1/2 hr 1/2 hr lhr 7hr 1/4 hr 2-3/4 hr 1/2 hr lhr 1-1/2 hr 1/4 hr 8-3/4 hr 1/2 hr 2hr 4-1/2 hr 1/4 hr 4-3/4 hr 1/2 hr 1/2 hr 1/2 hr lhr 1/4 hr 2-1/4 hr 2-1/2 hr 3hr 1/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 1/4 hr 9-1/4 hr 1/2 hr 1/2 hr 2-1/2 hr 5-1/2 hr lhr 2-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr Activity Held safety meeting Rig moved 100.00 % Fill pits with Brine Rigged up Lubricator Circulated at 8158.00 ft Removed Surface tree Held drill (Fire) Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Laid down 21.00 ft of Tubing Circulated at 8140.00 ft Laid down 160.00 ft of Tubing Serviced Retrievable packer Held safety meeting Serviced Retrievable packer Retrieved Seal assembly running tool Installed Seal assembly Held drill (Spill) Rigged up BOP stack Held safety meeting Tested Choke line Circulated at 7980.00 ft Held drill (Fire) Laid down 7740.00 ft of Tubing Held safety meeting Laid down 240.00 ft of Tubing Ran Drillpipe to 4050.00 ft (5in OD) Held drill (Kick while tripping) Ran Drillpipe to 8000.00 ft (5in OD) Held safety meeting Ran Drillpipe to 8164.00 ft (5in OD) Washed to 8164.00 ft Circulated at 8203.00 ft Flow check Pulled Drillpipe in stands to 0.00 ft Removed Tubing handling equipment Ran Drillpipe in stands to 8203.00 ft Held drill (Spill) Circulated at 8203.00 ft Held safety meeting Circulated at 8203.00 ft Flow check Laid down 8203.00 ft of Drillpipe Removed Bore protector Held safety meeting Rigged up Top ram Ran Tubing to 2400.00 ft (7-5/8in OD) Serviced Tubing handling equipment Ran Tubing to 4250.00 ft (7-5/8in OD) Held safety meeting Ran Tubing to 8141.00 ft (7-5/8in OD) Held safety meeting 1 16 October 97 Facility Date/Time WGI Progress Report Well WGI-04 Page 2 Rig Doyon 16 Date 16 October 97 06:30-07:00 07:00-08:30 08:30-11:30 11:30-14:00 14:00-17:00 17:00-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-01:00 Duration 1/2 hr 1-1/2 hr 3hr 2-1/2 hr 3hr lhr 1/2 hr 2hr 1-1/2 hr 3hr Activity Installed Accessories Circulated at 8141.00 ft Set Permanent packer at 8114.00 ft with 4000.0 psi Installed Accessories Removed BOP stack Rigged up Surface tree Held safety meeting Installed Surface tree Tested Additional services Rig moved 0.00 % · :-"- STATE OF ALASKA ALASKA .~L AND GAS CONSERVATION CO,.,,vllSSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: []Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well []Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 611' SNL, 1134' WEL, SEC. 11, T11N, R14E, UM At top of productive interval 1535' NSL, 1116' EWL, SEC. 01, T11N, R14E, UM At effective depth 1618' NSL, 1227' EWL, SEC. 01, T11N, R14E, UM At total depth 1642' NSL, 1259' EVVL, SEC. 01, T11N, R14E, UM 5. Type of well: [] Development [] Exploratory [--I Stratigraphic [~ Service 6. Datum Elevation (DF or KB) RKB: 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-4 9. Permit Number 79 -50 10. APl Number 50-029-20386 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9584 feet true vertical 8596 feet Effective depth: measured 9459 feet true vertical 8477 feet Casing Length Size Structural Conductor 45' 20" Surface 2705' 13-3/8" Intermediate Production 8615' 9-5/8" Liner 1252' 7" Plugs (measured) Junk (measured) Fill at 9459' Cemented 338 sx Arctic Set 4000 sx Arctic Set II 500 sx Class 'G' 350 sx 73' 2733' 8643' 8332'-9584' TVD 73' 2733' 7705' 7417' - 8596' Perforation depth: measured true vertical 9034'-9082', 9084'-9132', 9142'-9180', 9182'-9216', 9218'-9266', 9268'-9307', 9320'-9360', 9366'-9378', 9392'-9402', 9416'-9436', 9449'-9469' 8075'-8121', 8122'-8168', 8177'-8213', 8215'-8247', 8249'-8294', 8296'-8333', 8345'-8383', 8389'-8400', 8414'-8423', 8436'-8455', 8468'-8486' Tubing (size, grade, and measured depth) 7", 29#, L-80 AB-Mod 8rd to 8220' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SB-2 Packer at 8231'; Otis SSSV at 2295' 13. Attachments [] Description summary of proposal [] Detailed operations program [--} BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: August 5, 1997 16. If proposal was verbally approved [] Oil [] Gas [] Suspended Service ~ Gas Injector Name of approver Date approved Contact Engineer Name/Number: /~lrown, 564-5582 Prepared By Name/Number: 17. I hereby certify that t~. e for/e'going i,j~ue and correct to the best of my knowledge Signed Oan Stoltz ,~~, ~ Title Senior Drilling Engineer OR!P INIAI · ,,.~ i i ¥1%li~ Terrie Hubble, 564-4628 Commission Use Only Conditions of Approval: Notify Commission so representative may witness ] Approval No.~.~ Plug integrity __ BOP Test / Location clearance __ Mechanical Integrity Test /,// Subsequent form required .10~_"~'q Approved by order of the Commission original Signeo By ,, ,..t~~ssioner Form 10-403 Rev. 06/15/88 David W, Jotmston Submit In Triplicate WGI-04 WORKOVER SUMMARY Obiective The objective of this rig workover is to increase the well's lagging injectivity by replacing the existing 7" tubing with 7-5/8" internally plastic coated tubing. The seals will be pulled from the existing packer and a new completion run to _+60' above the existing packer. Jewelry will remain 7" in size. Critical Well Information Existing 7", 29#, N80 Tubing I.D. = 6.184" 7" SSSV Landing Nipple: 2,292' MD Minimum ID (4.845" ID): 8,245' MD (Baker shear out sub) New 7-5/8" 29.04#, NT95HS ST-L Tubing I.D. = 6.875" 7" SSSV Landing nipple: 2,292' MD 7" Packer, XN nipple, 5.75" No-go Pre-Riq Procedure 1. Test annulus to 3,500psi if not recently tested. . I.D. = 6.184" PBTD (7"): Perforations: . 7", 29#, N80, Liner 9,550' MD ~-~ ~ 9,034'-9,469' MD R/U slickline and drift tubing down to 8,900'. ~53~'-'~ R/U coiled tubing and bullhead a 100bbl sizes salt pill to the perforations (preceded by 50bbls hi-vis NaCI brine spacer) followed by 50bbls 10ppg hi-vis brine spacer and 9.6ppg kill weight brine. 4. RIH with chemical cutter on wire-line and cut tubing at first full joint above the packer seals at _+8,199' MD. . Circulate well to 9.6ppg NaCI brine (zero pressure on tubing and IA). Freeze protect to _2,200' MD (if necessary). Estimated BHP at 8,076TVD is 3,550psi (8.4ppg EMW). Note that at this point, the well will be theoretically overbalanced by 162psi provided the seawater column is not reduced by fluid moving into the formation after the well has been killed. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Summary Ri.q Procedure 1. Test 9-5/8" packoff to 5000psi, and function lock down screws. 2. MIRU. Circulate well with 9.6 ppg NaCI brine. Set and test BPV. ND tree. NU BOP's. Set test dart (TWCV). Test BOP's. Pull test dart and BPV. 3. Pull 7" tubing from chemical cut made in pre-rig. Replace 9-5/8" packoff if necessary while pulling tubing. 4. M/U fishing assembly. RIH, retrieve seals, and POOH. If seals cannot be pulled, an overshot guide will be run as a contingency. WGI-04 Sundry Workover Procedure Page 2/2 . M/U and run new 7-5/8" NT-95HS ST-L completion with 7" SSSV, 9-5/8"x7" packer, 7" tailpipe with XN nipple configuration and a 7" WLEG. This will be set _+60' above the existing packer. No GLM's are required for this completion. NOTE: If the seals cannot be pulled, the completion will include an overshot guide instead of the WLEG. Drift tubing to maximum OD required post-rig. 6. Circulate well to NaCl brine/freeze protect tubing/annulus to _+2,200' MD. Land completion and test tubing to 4,200psi. 7. Set BPV/test dart and test from above. N/D BOP's. N/U and test tree. Pull test dart and BPV. Check well for flow. 8. Set BPV and RDMO. Prepared by: D~~s~s Drlg Engr Chris Brown Doyon 16 Operations Drilling Engineer (Office) 564-5582 (Home) 346-3773 (Pager) 275-1835 D~TF' RFFF..R'E'.KIC. E. AR~O f't. ASED IqRI F F]'NAI. COl F:nl COI_ i'iFll ROI .. CFi[ Rrll.. I A R' / P' F-- I:;' F f"l F,' A '/T t~ Nt [ Ar-;, ( F'AFi. K FK' ) IAI:;' I AR'/F'FRFF1RT T F1N I.. AR'/F'FRFOR'AT I ON I. AR'/F'FRFFIRAT T ON I AIr,.' / F'F R' F' Fl R' A T T fl N C rll_..I AR'/F'FK'F'RR'AT T F1N CF)I ._1._ AR/F'ERFORAT T ON r. nJ. J AR'/F'F.R'FF1F,'ATTF)N Cfll .I_AR/F'ERFFtR'ATT CFII .I ~F,'/PFR'FFIRA T T Oi'J P.[.ll .IAR !FIFR'Ff]!-TAT T F1N RO/..I AR/F'FR'FRF~'AT T ON RFll..I. Al7 / F'ER' F FIR'A T T. rlN r;i"J AND R.F t.IF- ' ' RECEIVED BY ____ HAVE A FI E !-, F_? Y BENNETT ATO- t ~,~o TRANY ~8,q. ¢. 7S ~_ AF'F'R[)VEI) D]'.%TR'T R1 IT T ON D I--.. r'. [--. ;r FiT RF R'lJlg i , rs' RI IN i , % ' R'I IN t . %" I;,'IIN t . % · R'IIN t . E'IIN i, ~' I:;'IIN t , % · R'I IN t . % · R'I IN t '=,; ' F~.'IIN I. %' ~]'l.li'Jt , q · R'l llg t r4 · · ./ IRIIhJ I . ';i" 1-7lIN i . %' F;'I!N i . %" R'llhJ ~ . '~;' DATA. l) R' F ?7 R' I-- F;.' DRF~F'R 'D K'FX'.?F P l) F," F.~.~ F F,' DRF?,.~FR r) R I-- :,: ,? I--, F,' I~R'F SXFI.~' flR'F.., ....., r) R F.% S,' F r;.' CENTRAl_ F!'!.ES CNFVRnN .. ~ EVTEN~TRN FYF'!..RRATTRN ~ARATHON Mr]RI[_ F' H T. I... I... ;r F' .:"7 F'R WFI..I .%TATF F1F · r F'x' a r-':. n F T I. F,':-," Al. A.?KA ARCO Alaska, In' Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 24, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: WGI-4 (33-1-11-14) Permit No. 7-230 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/MRO/jp Attachment cc: Standard Alaska Production Company P! (WGI-4)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AR3B--6132-C STATE OF ALASKA AL/-,v.(A OIL AND GAS CONSERVATION COiv~MISSION REPORT-OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Alter Casing [] Other [] 2. Name of Operator ARCO A1 asEa, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 611' FNL & 1134'FEL, Sec. 11, T11N, R14E, UN At top of productive interval 1535'FSL & 1116' FWL, Sec. 1, T11N, R14E, UN At effective depth 1618'FSL & 1227' FWL, Sec. 1, T11N, R14E, UN At total depth 1642'FSL & 1259' FWL, Sec. 1, T11N, R14E, UM 11. Present well condition summary Total depth' measured true vertical 9584 feet Plugs (measured) 8596 feet Perforate [~ Pull tubing 5. Datum elevation (DF or KB) 49' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-4 (33-1-11-14) 8. Approval number 7-230 9. APl number 50-- 029-20386 10. Pool Sadl erochi t None Effective depth: measured 9459 feet Junk (measured) true vertical 8477 feet 9459' - Fill Casing Length Size Cemented Measured depth ~ue Vertical depth Conductor 45' 20" 338 sx Arcticset 73' 73' Surface 2705' 13-3/8" 4000 sx Arcticset II 2733' 2733' Production 8615' 9-5/8" 500 sx Class G Cmt 8643' 7705' Liner 1252' 7" 350 sx 8332'-9584' 7417'-8596 Perforation depth: measured 9034-9082' 9084-9132' 9142-9180' 9182-9216' 9218-9266' 9268-9307', 9320-9360', 9366-9378' , 9392-9402' , 9416-9436' , 9449-9469' true vertical 8075-8121', 8122-8168', 8177-8213', 8215-8247', 8249-8294' 8296-8333', 8345-8383' ,- 8389-8400', 8414-8423', 8436-8455', 8468-8486' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd to 8220 'MD Packers and SSSV (type and measured depth) 9-5/8" X 7" Baker SB-2 Packer @ 8231'MD/0tis SSSV @ 2295'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure AUG. Nas~ 0i1 & Gas Cons. C0mmissiorl A~ch0rage 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 5/22/87 -- 210065 .... Subsequent to operation 5/28/87 -- 208059 .... Tubing Pressure 3875 3875 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~- Signed ~.~2,//~~~~ Title Operations Engineering Manager Date Form 10-404 Rev. 12-1-85 MRI3 (?F;E-F[Rll3~ Submit in Duplicate WGI-4 ADD PERFS Daily Report of Well Operations 5/24/87 PT rams/lub to 4000 PSI. OK. Pull SSSV. RIH w/bailer, TTL, and dummy gun. Tag bottom @ 9486'MD. POH. PT hardline to 4000 PSI.OK Pump in diesel/xylene wash - spot across perfs. 5/25/87 PT rams/lub to 4500 PSI. OK. RIH w/16' & 4' select fire gun #1, 3-3/8", 4 SPF @ 120° phasing. Shoot 9374-9378' (4'). Shoot 9200-9216' (16'). POH - all shots fired. PT rams/lub to 4000 PSI. OK. RIH w/11' & 12' select fire gun #2, 3-3/8", 4 SPF @ 120° phasing. Shoot 9348-9360' (12'). Shoot 9296-9307' (11'). Problems w/flow hose freezing up - hose changed out. OK. POH - all shots fired. PT rams/lub to 4000 PSI. OK. RIH w/26' gun, 3-3/8", 4 SPF @ 120° phasing Shoot 9240-9266' (26'). POH - all shots fired. PT rams/lub to 4000 PSI. OK. RIH w/4' & 20' select fire gun, 3-3/8", 4 SPF @ 120° phasing. Shoot 9236-9240' (4'). Shoot 9160-9180' (20'). POH - all shots fired. PT rams/lub. OK. RIH w/20' gun, 3-3/8", 4 SPF @ 120° phasing. Repaired union leak. Shoot 9112-9132' (20'). POH - all shots fi red. PT rams/lub. OK. RIH w/20' gun, 3-3/8", 4 SPF @ 120° phasing. Shoot 9062-9082' (20'). POH - all shots fired. PT rams/lub to 4000 PSI. OK. RIH w/SSSV and set @ 2267' SLM. Test to 4500 PSI. OK. POH. Flow test w/450 PSI differential, pressure. OK. STATE OF ALASKA '-". ALASK.. OIL AND GAS CONSERVATION COMN. .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Time extension ~ Change approved program ~ Plugging ,,~ Stimulate D Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska. Tnt. 3. Address Post 4. Location Office Box 100360, Anchoraqe, AK 99510 of well at surface 611' FNL & 1134'FEL, Sec. 11, T11N, R14E, UM At top of productive interval 1535'FSL & 11_16' FWL, Sec. 1, T11N, R14E, UM At effective depth 1635'FSL & 1250' FWL, Sec. 1, T11N, R14E, UM At total depth 1642'FSL & 1259' FWL~ Sec. 1~ T11N~ R14E~ UM 11. Present well condition summary Total depth: measured 9584 feet true vertical 8596 feet Effective depth: measured 9550 feet true vertical 8563 fe,-t Casing Length Conductor 45' Surface 2705' Production 8615' Plugs (measured) Junk (measured) 5. Datum elevation (DF or KB) 4~)' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-4 (33-1-11-14) 8. Permit number 79-50 9. APl number 50-- 029 -20386 10. Pool Sad] erochi t 9550' - Cement' None Size Cemented Measured depth Rue Vertical depth 20" 338 SX Arcticset 73' 73' 13-3/8'' 4000 sx Arcticset I! 2733' 2733' 9-5/8" 500 sx Class 6 Cmt 8643' 7705' Liner 1252' 7" 350 sx 8332'-9584' 7417'-859( Perforation depth: measured 9034-9064', 9084-9114', 9142-9162', 9182-9202', 9218-9238', 9268-9298', 9320-9350', 9366-9376', 9392-9402', 9416-9436', 9449-9469' true vertical 8075-8104', 8122-8151', 8177-8196', 8215-8234', 8249-8268' 8296-8325', 8345-8374', 8389-8398', 8414-8423', 8436-8455', 8468-8486' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd to 8220 'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SB-2 Packer @ 8231'MD/Otis SSSV @ 2295'MD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved Signed'~/~,¢'~, ~~~'?// //~'9/~-~-'~"~---'~// Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test [q Location clearanceI Approved by ~.~ Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date MR0 (265-6810) Submit in triplicate WGI-4 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well WGI-4. The proposed perforation intervals are as follows- Existing Perforations 9034-9064 (30') 9084-9114 (30') 9142-9162 (20') 9182-9202 (20') 9218-9238 (20') 9268-9298 (30') 9320-9350 (30') 9366-9376 (10') 9392-9402 (10') 9416-9436 (20') 9449-9469 (20') TOTAL = 240' Proposed Perforations 9064-9084 (20') 9114-9126 (12') 9162-9182 (20') 9238-9242 (4') 9260-9268 (8') 9298-9309 (11') 9350-9362 (12') 9376-9380 (4') TOTAL = 91' Reference BHCS of 10/16/79 A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOM HOLE LOCATION: ORIGINAL RKB: TOP OF SADLEROCHIT: ALL DEPTHS ARE RKB MD 9/27/79 WGI #4 ~'-~ SPUD DATE: 611'S & 1134'W of NE cr. Sec. 11, TllN, R14E, UM 1320'N & 1320'E of SW cr. Sec. 1, TllN, R14E, UM 28' 49' RKB TO Gray HANGER 9030'' MD AVERAGE HOLE ANGLE: 32.5o HAXIMUM ANGLE: 44.25o @'6800' ANGLE AT TD: 18.25o Depths are to TO~P of equipment ANNULUS FLUID: 10.8 ppg CaC12 w/ 15 bbl Diese L73' 20", 94#, Vetco (19.124" ID) H-40 2274' Bottom of 7", 26#, L-80 ABIJ4S (6.276" ID) 2295' Otis RPB SSSV Nipple (5.963" ID) 2335' Bottom of 9-5/8", 47#, S00-95 BTC (8.681" ID) _2356' Howco 9-5/8" FO 2486' Howco 9-5/8" FO 2733' 13-3/8", 72#, N-80 BTC (12.347" ID) w/ 4000 sx 8228' 8231' I 8245' 8246' 8332' Ib~. 8643' -) 9034' 7", 29#, L-80 ABMOD 8rd (6.184" ID) Baker Seal Bore Extension Assembly 9-5/8" x 7" Baker SB-2 Packer Baker Millout Extension Baker Shear Out Sub (4.843" ID) NO TAILPIPE Top of Liner, BOT MC Hanger 10/29/79 Liner lap squeeze 200 sx, required on original drilling due to liner cement failure. 9-5/8", 47#, N-80 BTC (8.681" ID) w/ 500 sx - 9064 ] 9084' - 9114 ] 9142' - 9162 _) 9182' - 9202 9218' - 9238 9268' - 9298 9320' - 9350 ] 9366' - 9376 _Fl 9392' - 9402 9416' - 9436 9449' - 9469 WORKOVER-STIMULATION 7/25/83 - Water washed w/ 500 bbls 9550' PBTD 9584' 7", 29#, L-80 BTC (6.184" ID) w/ 350 sx 9584' TD !I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4. 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF N I REL I NE BOP EQU I PHENT ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 7, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: WGI-4 Permit No. 79-50 Dear Mr. Chatterton: Attached is the "Subsequent" Sundry Notice detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFs/mre/jp Attachment cc: Standard Alaska Production Company P1 (WGI-4) W5-4 WELLS/34 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany "-'- STATE OF ALASKA ~"'". ALAS..., OIL AND GAS CONSERVATION COM, .$SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate j~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alasl~a, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 611' S & 1134' W of NE Cr. Sec. 11, TllN, R14E, UM At top of productive interval 1533' N & 1115' E of SW Cr. Sec. 1, TIN, R14E, UM At effective depth At total depth 1642' N & 1259' E of SW Cr. Sec. 1, TllN, R14E, UM 5. Datum elevation (DF or KB) 71' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-4 8. Approval number 79-50 9. APl number 50-- 029-20092 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 9584 feet Plugs (measured) 8596 feet Effective depth' measured true vertical Casing Length Structural Conductor 73 ' Surface 2508 ' Intermediate Production 8643 ' Liner 9550 feet Junk (measured) 8164 feet Size Cemented Measured depth True Vertical depth 20" 338 Sx Arcticset 73' 73' 13-3/8" 4000 Sx Arcticset II 2733' 2733' 9-5/8" 500 Sx C1 G 8643' 7709' Perforation depth: measured 9034-9064'; 9084-9114'; 9142-9162'; 9182-9202'; 9218-9238'; 9268-9298'; 9320-9350'; true vertical 9366-9376'; 9392-9402'; 9416-9436'; 9449-9469' 8079-8107'; 8126-8155'; 8181-8200'; 8219-8237'; 8253-8271'; 8300-8328'; 8349-8377'; Tubing (size, grade and measured depth) 8392-8401'; 8416-8426'; 8439-8458'; 8470-8489' 7", 26# & 29#, L-80, ABIJ4S & ABMOD 8 rd @ 8220 Packers and SSSV (type and measured depth) Baker SB-2 Packer @ 8231'; Otis RPB SSSV nipple ¢ 2295' 12. Stimulation or cement squeeze summary Intervals treated (measured) Ail Treatment description including volumes used and final pressure See attached 0il & Gas Cons. 13. Prior to well operation Representative Daily Average ~ or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 89,000 0 -- 3600 Subsequent to operation 0 185,000 0 -- 3600 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge'"' '~ //.._. ~ (:~-''~'.~," Signed T.T*D~T T C~ /0/. T.T T.'I'1'~.,.-.,- ..... ArP/h I I::i'~/hq(--."~ /,'}'70 Submit in Duplicate 180 WGI-4 Selective Stimulation Procedure AFE #699055 Property Code #2130629 1. MI & RU pump trucks and transports. 2. Stimulated well as follows: me Ce g. h. i. j · ne 20 bbl of methanol 1500 gal of 15% HC1 w/additives. 3000 gal of 12% HCl - 3% HF w/additives 1000 gal of 2% NH,C1 water. 1000 gal of 2% N~,C1 water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stzmulation grade benzoic acid flakes. 1500 gal of 15% HCl w/additives. 3000 gal of 12% HC1 - 3% HF w/additives. 1000 gal of 2% NHoC1 water. 1000 gal of 2% N~6C1 water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stzmulation grade benzoic acid flakes. 1500 gal of 15% HC1 w/additives. 3000 gal of 12% HC1 - 3% HF w/additives 1000 gal of 2%NH,C1 water. 1000 gal of 2%~ N~4Cl water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stzmulation grade benzoic acid flakes. 1500 gal of 15% HC1 w/additives. 3000 gal of 12% HC1 - 3% HF w/additives. 1000 gal of 2% NHAC1 water. 100 bbl of methandl. 250 bbls of 2% NH4C1 water. 10 bbl methanol 3. RD & released equipment and returned well to injection. WELLS/34 ARCO Alaska, Inc. Prudhoe Bay ,_ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 20, 1986 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS WGI-4 Permit No. 79-50 ~z~ Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice detailing work planned on the above-referenced well. Very truly yours, D. F. Scheve 7~ DFS/WWP/jp Attachment cc: Standard Alaska Production Company P1 (WGI-4)W5-4 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS,,.. OIL AND GAS CONSERVATION COMI, _,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension lq Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum eJevation(DF or KB) ARCO Alaska, Inc. 49' RKB feet 3. Address 6. UnitorProperty name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of wellatsurface 611' S & 1134' W of NE Cr., Sec. Attop ~ productiveinterval 1533' & 1115' E of SW Cr., Sec. At effective depth 11, TllN, R14E, UM 1, TllN, R14E, UM l~t4~a~de~t~259' E of SW Cr., Sec. 7. Well number WCI #4 8. Permit number 79-50 9. APl n~¢._e~O092 50-- 1, TllN, R14E, UM 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary 9584 Total depth: measured 8596 true vertical feet feet Plugs (measured) Effective depth: measured 9550 true vertical 8164 feet feet Junk (measured) Casing Length Size Structural Conductor 73' 20" Surface 2733' 13-3/8" Cemented Measured depth 338 Sx Arcticset 73' 4000 Sx Arcticset II 2733' ~ue Verticaldepth 73' 2733' Intermediate Production 8643' 9-5/8" 500 Sx C1 'G' 8643' 7709' Liner Perforation depth: measured 9034-9064'; 9084-9114'; 9142-9162'; 9182-9202' true vertical 9366-9376'; 9392-9402 ' 8079-8107'; 8126-8155'; 8181-8200'; 8219-8237' Tubing (size, grade and measured depth) 8392-8401' ; 9218-9238'; 9268-9298' ; 9416-9436'; 9449-9469' ; 8253-8271'; 8300-8328' ; 8416-8426'; 8439-8458' ; 9320-9350'; ; 8349-8377'; ; 8470-8489' 7"; 26# & 29#; L-80; ABIJ4S & ABMOD 8 rd @ 8220 Packers and SSSV (type and measured depth) Baker SB-2 Packer @ 8251'; O~i~ RPB S$SV ~ipple 0 2295' 12.Attachments Description summary of proposal ~ Detailed operations program [] ~, 7i,~i'; i'..~ :'~ BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver ~.*,,~-.-'~.~ 0!i ~.: :.i ::;: !:,.,:~.:,. b~;,;;'~-,JSCJ0~'~ .~,~ ~;;; ~;,;.~-~:~ Date app roved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~r .~ ~/*,¢¢.- Title Operations En~imeering Manager Commission Use Only Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 12-1-85 ! Approval No.,~'--'~ by order of Commissioner the commission Date Submit in triplicate .. WGI-4 Selective Stimulation Procedure 1. MI & RU pump trucks and transports. 2. Titrate acid and test iron content as follows: 0 i HC1 should be 13.5% to 17.5% with an Fe content of less than 300 ppm. HC1-HF should be 2.4% to 4.0% HF; 11.0% to 13.5% HC1 with an Fe content of less than 300 ppm. NOTE: Additives should not be added to acid system above 130°F to prevent precipitation of iron sequestering agents. Stimulate well as follows: a. 1500 gal of 15% HC1 w/additives. b. 3000 gal of 12% HCl - 3% HF w/additives c. 1000 gal of 2% NH,C1 water. d. 1000 gal of 2% N~,Cl water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stimulation grade benzoic acid flakes. e. 1500 gal of 15% HC1 w/additives. f. 3000 gal of 12% HC1 - 3% HF w/additives. g. 1000 gal of 2% NHoC1 water. h. 1000 gal of 2% N~,Cl water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stimulation grade benzoic acid flakes. i. 1500 gal of 15% HC1 w/additives. j. 3000 gal of 12% HC1 - 3% HF w/additives k. 1000 gal of 2% NH,C1 water. 1. 1000 gal of 2% N~,C1 water gelled to a viscosity of 100 cps w/CMHEC and 1000 lbs of stimulation grade benzoic acid flakes. m. 1500 gal of 15% HCl w/additives. n. 3000 gal of 12% HC1 - 3% HF w/additives. o. 1000 gal of 2% NH,C1 water. p. 100 bbl of methangl. q. 250 bbls of 2% NH4C1 water. Volume of hole to top of perforations: 341 bbls Volume of hole to bottom of perforations: 358 bbls All fluid should be filtered to 2 microns. RD & release equipment and return well to injection immediately. Test well for new injection capacity. ARCO Oil and Gas Company'-' NOrth Alas~ iistrict Post Oflice'-Dox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon ~Districl Operations Engineer July 23, 1981 Reference: ARCO Cased Hole Finals D.S.2-16 2/24/81 EPL Run 1 5" D.S.12-10 6/7/81 CNL Run 1 5" D.S.ii-10 6/7/81 CCL/W Gyro Run 1 2"/5" D.S.12-10 6/7/81 CNL Run 1 5" ,_.~WG, r~7~f~i-? 5/21/81 EPL Run 1 5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #454 DISIRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY MARATHON CHEVRON ARCO C,I and C, ds Con',party ,s a Oi',-'~s,on ol Allanl,cR,chl,eldCompany ARCO Oil and ~Company Alaska Di .... ,', Post Office B~;, :;~-!] ~-,qchora(j,.'.' .:': {;-.~h,-.'~ U~:. Telephone 'L,]7 277.~,~"; ".; ,,' September 9, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 I STAT TFC ;'FILF: Subject' WGI - 1 (Permit no. WGI - 2 (Permit no. ~I___- 3 (Permit no. ~:~~(Permi t no Dear Sir- 79-31) 79-43) 79-49) 79-50) Enclosed please find our Sundry Notices of Subsequent Report, for the subject wells, detailing the individual well perfor- ating procedures. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/sp Enclosures Fon-n 1'0-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL~__IOmL ~ WELLGAS D OTHER Gas Injection ~- NAME OF OPERATOR Atl antic Ri chfi el d Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 LOCATION OF WELL At surface 611' FNL, 1134' FEL, Sec 11, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc,) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-029-20386 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI-4 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field - Prudhoe 0il Pool 11. SEC., T,, R., M., (BOTTOM HOLE OBJECTIVE) Sec. 1, TllN, R14E, UM 12. PERMIT NO. 79-50 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTI PLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF.- WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (ot,.r) Perforate for injection (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent ~letalls, and give pertinent dates, Including estimated date of starting any proposed work. Began perf operations 8/20/80. Bled tbg and annulus pressure to O. Set tree and test equipment and pressure test to 5000 psi, ok. Install wireline BOP's and lubricator and test same Pull dummy valve. Perf'd following intervals per , GR/BHCS log ~f 10/16/79 ~/4 spf- 9451~ -~ 9471, 9418 - 9438, 9394 - 9404, 9368 9378, 9322 2 9352, 9270 ?9300, 9220 - 9240, .9184 2t9204, 9144 -~9164, 9086 Z~l16, 9036 '~ 9066. Makeup surface readout pressure recorder and run. Obtain readings and pull recorders..Ran and set ball valve. Test valve, flow well, SI well, and close safety ball valve. Installed and tested tree cap to 5000 psi, ok. Released well to Production 0600 hrs, 8/23/80. 16. I hereby certify that the foregoing is true and correct SIGNED~~~~~_ TITLE District Drilling Eng. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE., See Instructions On Reverse Side ARCO Oil and Gas Company Alaska Dist~'~; Post Office'-. .... X 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 1, 1980 Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commi ss i on 3001 Porcupine Drive Anchorage, Alaska 99501 Re- WGI i - Permit No. 79-31 WGI 2 -" " 79-43 WGI 3 -" " 79-49 Dear Sir' Enclosed please find Sundry Notices detailing work and start dates planned for the above mentioned wells. Very truly you~rs, P. A. VanDusen District Drilling Engineer PAV-ruo ARCO Oil and Gas Company is a Divisiol, r.l .~.tl..~Hi(-l{ich~:,q:!.-;,-,n~,._,.T 'Form 10~403 "-" r - ~. Submit "Intentions" in Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL GAS ['--'],OTHER GAS INJECTION 2. NAME OF OPERATOR Atl anti c Ri chfi el d ComP. any ;3. ADDRESS OF OPERATOR P. O. Box 360, Anchoraqe, 4. LOCATION OF WELL At surface 611'S & 1134'W of NE cr Sec. 5. APl NUMERICAL CODE 50-029-20386 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 14. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. Alaska 99510 WGI- 4 11, T11N, R14E, UM Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 1, T11N, R14E, UM 12. PERMIT NO. 79-50 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING L__J FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: FRACTURE TREATMENT' ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. ARCo Oil and Gas Company proposes to perforate selected intervals within the Sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report, A 5000 psi. WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety vlave will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/12/80 SuBsequent Work tleportert "' SIGNED ./'~, TITLE District Drill in9 Engineer, DATE 8/1/80 (This space for State office use) COMMISSIONER TITLE DATE BY ORDER OW THE COt,~,~IS$1ON See Instructions On Reverse Side Approv~! £etumed I~orm 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL' ',OTHER GAS INJECTION COM~ 5. APl NUMERICAL CODE 50-029-20386 - ?. iF ~NDIAN, ALLOTTEE OR TRI~ Prudhoe Bay Unit ~ __----~ g. WELL NO. Prudhoe Bay Field-Prudhoe 0il P0ol 2. NAME OF OPERATOR Atlantic Richfield Comp~any 3. ADDRESS OF OPERATOR P. O. Box 360~ Anchorage, 4. LOCATION OF WELL At su trace 611'S & 1134'~ of NE cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB Alaska 99510 14. 11, TllN, R14E, UM Check Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 1, T11N, R14E, UM 12. PERMIT NO. 79-50 3ort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE coMpLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL cHANGE PLANS (other) Perforate for Injection SUBSEQUENT REPORT OF.' WATER SHUT-OFF r'-"] REPAI RING WELL FRACTURE TREATMENT'H ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well COml~letlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnlnt details, and give pertinent dates, Including estimated date of starting any proposed work. ARCo 0il and Gas Company proposes to perforate selected intervals within the Sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report. A 5000 psi. WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety vlave will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/12/80 REr[ '!VFn AnOhul-age 16. I hereby certify that the for oing is t · and correct SIGNED ./'~' ~~--. TITLE District D rillin~ Engineer, DATE 8/1/80 (This space for State office use) CONDITIONS OF A NY;: /BY ORDER OF THE COld, MISSION ._ See Instructions On Reverse Side Returned May 29, 1980 Reference: ARCO Magnetic Tapes D.S. 3-7 10/7/76 Tape #60215 D.S. 6-11 5/15/80 Tape.#CN 9550-10810 ?~ 10/16/79 Tape #60027 ~/~lease sign and return' the attached copy as receipt of data. K. J. Sahlstrom 'North Engineering TRANSMITTAL #346 DISTRIBI North Geology R & D Drilling Eng. bimqager Geology State of Alaska TION -'F~xon Mobil Getty Phillips Sohio Marathon O~ev-ron A~CO C'd and Gas Company ~s '~ Divis;on ol Allanl,CglChlieldCon~pany ARCO Oil and Gas,~-qmpany ~-:-c;Tt C,';:'_:.:,? ~}.:-- . December 31~, 1979 . '. . · Reference -_ . . Enclosed is a Magnetic Tape for the following ARCO well, ' ' WGI- # 4 11/26/79 CNLOG 7550--.9550 Dresser Atlas ease sign and return the attached copy as receipt · of data, . iicom~ _ !gC)MM _ I P, ES ENG i I I ENG I ~ ~NG G~OL t J ST/',T TEC--- / 'cdNFi~ K. J. Sahlstrom North Engineering TEANS}4ITTAL # 542 DISTRIBLrFION North Geology R&D ~-illing Eng. Mm]ager D~ Geology State o~ Alaska F, xxon ~'bbil Getty Phillips Sohio }.larathon Chevron Anchor:-,.. 'Fe!,:.ph,:;.~e :.,'-0' 2T7:5'_;3/ November 30, 1979 Reference, F27closed are CaUsed Hole Logs for the following ARCO wells' D.S.. 3-4 D.S. 4-15 D.S, 7-Ii D.S, 7-14 D.S. 9-15 WGI ~ 4 11/2/79 TDT Run 2 11/5/79 CNL Run 3 10/24/-79 CN/GR/~,B Run 2 10/23/79 CN/GR/H$ Run 2 11/6/79 _ T-Er Run 2 9/27/79 EPL- Rrm 1 10/22/79 :acoustic CBL/\q31 10/27/79 CN/GR Run ]_ 2 & S" (stone log) S': 2 & 5" (same log) , 5II d)-/Please sign and retu]m the attached cop): as re.cjeipt of data. K, J. Sahlstrom North Engineering T , , 1~. TK%NS)IITT:\& = 503 Di STI(I B UT I OX North Ceo1 ogy Dri]_lJng Eng. t,!anager Geology State of A2aska f) & }Nxon ,X!obil Getty Sohio ?. !ara th on l']lillips Chevron November 13, 1979 Reference: ~nclosed isa Directional Survey for the following ARCO well: WGI #4 9/26/79 Magnetic Single Shot SDC ease sign mud return the attached copy as receipt of data.. K, J,. Sahlstrom North Engineering TRANSMITTAL # 474 DISTRIBD~ION North Geolo~, Drilling Eng. Manager R ~ D Geology State of Alaska }]XXO]I Mobil Getty Sohio Marathon Phillips Chevron ARCO Oil and Gas~.Company North Al~sk', --'".istrict Post Office x 360 Anchorage. Alaska 995'10 Telephone 907 2-77 5637 NOvember 8, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas' 3001 Porcupine Drive Anchorage, AK -99501 Subject' DS 3-1'l, Permit No. 79-47 Permit No. 79-48 ermit No. 79-50 Dear Si r' Enclosed please' find a Completion Report along with the Drilling History and GYroscopic Survey for each of the above-mentioned wells. Very truly yours, ~¢~J~. A. VanDusen District Drilling Engineer PAV'jh Enclosures .. ',-- n., · ARCO Oil and Gas Company is a Division of AtlanticR,chfieldC'ompaqy Form P-~7 SUBMIT INDUPL., ,TE* STATE OF ALASKA (see other In- stru(~tions on reverse side) Gl L AND GAS CONSERVATION COMMITTEE WELL:COIVlPLETION OR RECOMPLETION REPORT AND LOG* Gas ln.lectlon la. TYPE OF WELL: WELL[--']OIL GASwE LL L_J[--'I DRY r-'] Other b. TY~E OF COMPLETION: NEW WORK DEEP-r~I PLUG I--'-I DIFF. I---I WELLF~ OVER [~ EN I I BACK.I I RESER.I I Other 2. NAME OF OPERATOR ARCO 0il and Gas Company · 3, ADDRESS OF OPERATOR P, 0. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurf~l'S & 1134'W of NE cr Sec 11, TllN, R14E, UM At top prod. interval reported below 1533'N & lll5'E of SW cr Sec 1, TllN, R14E, UM At total depth 1642'N & 1259'E of SW cr Sec 1, TllN, R14E, UM 5. APl NUMERICAL CODE 50-029-20386 6. LEASE DESIGNATION AND SERIAL NO. APL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9, WELL NO. WGI #4 (33-1-11-14) IO..FIEL[~ AND P~)OL, vruanoe t~ay°~v~-~rudhoe Oil Pool 1 . SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 79-50 18. TOTAL DEPTH, MD&TVD 119. PLUG BACK MD&TVDI20. IF MULTIPLECOMPL., I CABLE TOOLS 9584' MD 8596' TVD 195~eI~T~lD 8164' TVD IHO~l MAN'~'mlng,e 1 21. ROTARY TOOLSA11 INTERVALS DRILLED BY 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* 23. WAS DIRECTIONAL Top Sadlerochit 9030'MD 8072'TVD SURVEYMADE Base Sadlerochit 9473'MD 8490'TVD Yes '24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/CAL/GR, FDC/CNL/CAL/CCL/GR, CBL, CNL/CCL/GR 25. CASING RECORD {Report all strings set in well) CASINGSIZE I WEIGHT, LB/FT. GRADE I DEPTH SET {MD) I HOLE SIZE CEMENTING RECORD 20" 194# Welded H-40I 73' I 30" 338 sx Arcticset cmt 13-3/8" 72# Butt N-80 I 2733' 17-1/2" 4000 sx Arcticset II cmt 9-5/8" 147# Butt S00-95I& N-8018643' 12-1/4" 500 sx Class G 26. LINERi RECORD 127~ I -TUBING RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE I DEPTH SET (MD) 7" 8332' 9584' 350 sx " 8246' 8231' 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. [ A b. . ; _ USeD N/A N/A ':"~ t - 30. PRODUCTION ~'~' : DATE FIRST PRODUCTIONN/A IPRODUCTION METHOD (Fl°wing' gas lift' pumping-size and type °f pump) ~'] ~..,,.Li. STATUS-(PrQd ucln~ or.l ;'- ,k,';r,~ L77~shut.ln) '~ ':-~i! 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ITEST WITNESSED BY I 32. LIST OF ATTACHMENTS Drilling History and Gyj'oscopic Survey 33. I hereby certify that the foregoing an~ atta~jled information is co~nplete and correct as determined from all available records. S,GNED~~J~~~., ~ T,TLE District Drilling Engineer DATE 11/5/79 *(See instructions and Spaces for Additional Data on Reverse Side) / ,--/// AMOUNT PULLED PACKER SET (MD) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH TRUE VERT. DEPTI None Top Sadlerochit 9030' 8072' Base Sadlerochit 9473' 8490' I · 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY,POROS TY FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Core data was sent by our Geology Department under a separate cover letter dated '10/24/79. DRILLING HISTORY WGI #4 (33-1-11-14) API 50-029-20386, ADL 28302, Permit No. 79-50 Spudded well @ 0700 hrs 9/29/79. Drld 17-1/2" hole to 2750'. Ran 13-3/8" 72# N-80 csg w/shoe @ 2733' Cmtd w/4000 sx Arcticset II cmt. Installed & tstd pkoff. Did top job w/2~O sx cmt. Installed & tstd BOP to 5000 psi w/DOG repre- sentative on site. Drld cmt & FS + 10' new hole. Tstd form to 12.5 ppg MW equiv. Drld 12-1/4" hole to 8670'. Circ hole for csg. PU shoe jt & FC jt. Air hose to elevators parted. Repaired air hose. Turned on air supply & air slips opened, dropping 2 jts into hole. Fished in hole for jts & rec. Circ & cond for csg. Ran 9-5/8" 47# S00-95 & N-80 csg, set @ 8643'. Cmtd w/500 sx Class G cmt. Installed & tstd pkoff to 5000 psi. Dwnsqzd 300 sx Arcticset cmt thru lower FO. Pumped 225 bbls Arcticpack thru upper FO followed by 75 sx cmt. Tstd csg to 3000 psi. Drld FS, cmt, + 10' new hole to 8682'. Tstd form to 12.5 ppg equiv MW. Drld 8-1/2" hole to 95~]t~'. Ran DIL/,SP, BHCS/CAL/GR, & FDC/CNL/ CAL/CCL/GR logs. Ran 7" 29# L-80 lnr w/top @ 8332 & shoe @ 9584'. Cmtd w/350 sx Class G cmt. Determined there was soft cmt above l nr lap. Found soft cmt during circ @ 9393'. Circ dwn to LC @ 9545', no cmt @ btms up. Press tst lnr lap & lnr to 3000 psi, leaked immed. Tstd again, held longer. Performed WSO tst. Had a light blow, then a strong blow indicating lnr lap or shoe cmt job failed. Rev out gas, wtr & gas cut mud. RIH w/bit & csg scraper to LC. RIH w/7" RTTS. Set pkr inside 7" @ 8474' Tst lap. Broke dwn @ 2500 psi. Tst lnr to 3000 psi, held ok. LD 7" RTTS pkrl RIH w/9-5/8" RTTS pkr. Set pkr @ 8015'. Sqzd lnr lap w/200 sx Class G cmt. Released pkr. RIH w/8-1/2" bit. Cleaned out cmt to top of lnr @ 8332'. RIH w/6" bit. Cleaned out cmt inside lnr top. Tst lnr lap to 3000 psi, ok. Drl out LC. Tst shoe to 3000 psi. Leaked off 650 psi in 30 min. Drld out shoe, ran CBL. RIH & set EZ drl cmt ret @ 9560'. Stab into ret. Sqzd s.hoe w/l~O0 sx Class G cmt. Tst 7" lnr to 3000 psi, ok. Conducted WSO tst, ok. Displ mud w/H20 & H20 w/CaC12. Tst csg to 3000 psi, ok. Ran 8- 1/2" gage ring & jnk bskt. Ran gyro. Ran 7" tbg'w/shear out sub @ 8246'. ND BOPE. NU X-mas tree & tstd to 5000 psi. Displ tbg w/diesel. Set pkr. Ran CNL/GR/CCL log from PBTD to 7550'. Started long term tbg tst. Released riq @ 0600 hrs 10/28/79. REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO OIL & GAS COMPANY WoS.~. #4 WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER A979 D0033 TYPE OF SURVEY MAGNETIC SINGLE SHOT DATE 9-26-79 SURVEY BY Steve Ratcli£f & John Bearden OFFICE ALAS~ F:'RI.J[~HO~' £~.~¥', ~,~ORTH SLOPE, AL. ASI~ [tS~'~, 27~.~0-.51':'24i1I), SURVEY'OR; DSS, SURVEYOR; STEVE RATCL. IFF'. 8274-E),502i"1I), i'4J"iS,. SURVEY BY SCIfi:NI'IFIC )'IRIL. L. ING, 08-0CT-79 E)83,'.~.;i.-.9072i'iI), [ISS, SURVEYOR; SI'EVE: RAI'CLIF!'F ' V I!: R 'l" I C A L. S E; C T i£ (3 N R E C Of~: 1) O F:: S LJI:~: V E Y R A l) I U S ' (3 F' C U R V Al' U R E' t~iEi: T H 0 l) · :CO OIL Ar,tO GAS 13', WE:t.I... NO: I : lj D H 0 E: I3' A T' ~, i',~ 0 R 'f' H S l.. 0 F:' E, AI..ASKA COHF'UTAT'I Oi',l TINE ' BAI'E 09: 17 ~ t 7 22-0C1'.-79 N 0 · :ASURE:I) DRIFI' DRIFI' IEF'TH ANGL. E DIRECI'ION FEEl' D M D TRUE COLIRSE VERTICAL VERTICAl_ LENGTH DEF:'TH SECI'ION FEET F'EET FEET R E C 1' A N C 0 0 R D I F'EET 13 U L A R NATES CLOSURE: I) I S T A N C E D I R E C '¥ F'E Iii; T Ii DOGL. SEVER riG/lO, .../,.~0. 1 0 S 38 E O. 2749.96 3.61 · . 0.84 S 5.32 .S 80 55 E 'E I N D A. T A F' R 0 tt till S "~ 8,54. 1 0 2890. '2 45 29'3'-2. 1 15 3(!' . 4 0 3O90° 5 45 315~. 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":' 4 4 0 N 40 N 41 N 41 N 4°:.. N 43 E: E E E 154. £;. 497. 457. ":' 2 ,.~ 0 · :209. 1.77. 93. ")'10. 34'2. 40:t4.63 356.53 "~ · ,..66.37 N 4145.0'7 32,7.15 4'::'":;"~ 0 t:3 536.89 N ,,,.I ~.. ! ,192.!9.12 '735.65 N 5339.51 9'70.98 N 5498,73 '5632.06 5702.65., 5886.:i. 6 6139.77 707.9:1. 9,'.;9. OS 1 ,'~c., ,~ 03 ,, 1 ,I :Il 7 + 83 1533.40 1593. q 1069o99 N 11':''~ ..9 N 1192.41N 1748.50 1'289. .. 52 N 244,0.4'E, 295.96 E 4'78.28 E 654,12 E 869.76 i.' 962.09' E'" 10 44. '39 Ii-'.' :L089.74 E 1209.93 E'. 1389.42 E 361.26 N 42 30 E 441.16 N 42 8 E 719.03 N 41 42 E 984.40 N 41 39 Ii!: '1303.56 N 41 51 E: 1438.93 N 41 58 E 1555.16 N 42 11E. 1615.35 N 42 25 E 1768.44 N 43 10 E 1995.65 N 44 8 E 1.1. 1.9' 0.4~ 0.2', 0.7; 1.4' 0.5', 1.1: "~% 4' 6 ..:~ ?,;'.~. ,I 3 0 '. o,::' ~. 'i 0 .'3 <) 70 :bO. 39 <) N 53. r,~ 5 :l N 50 1 "':' C) 61 . 54. 2060. 44 ' 14. ,..,o 4.2....,9 ' N · ~1(>1.06 1509.6-1 N 2:1. 35 ":' '~ . .,,ff. 1531.60 N ,' . , ....... OIL. ANDb ~. ^o° WELL. NO.* 4 IJI-'~HOE BAY, NORTH SL. OPE, ALAokA C 014 P U T A l'~[ T I M E D A l' E 09117: 17 22-0CT-79 PAGE NO:. A S U I;,' E [I [I R I f:' T E F' 1' H FEET DR I F'T Ar,loLE. DIRECTION LENGI'H · D ti D F E E l' 7207. 37 45 7394. 36 30 7743., 33 0 7889. .32 0 8219. 28 30 'rRLIE COURSE VERI'ICAL VERTICAL R E C 1' A N G U L. A R D E: F' T H S E C T I O'N FEEl' FEET FEET ' N 49 E 197. 6468.27 N 47 E ].87.. 6617.37 N 48 E 3.49. 6904.08 N 46 E ].46. 702'7.22 N 49 E 330. CLOSURE I)OGL~ C 0 0 R D I N A 1' E $ DISTANCE DIRECTION ~E. VER.'I 2'~57..,. .'77 1611.03 N 1605.15 E' 2370,39 1686,54 N 1689.02 E o~' 73 1820 92 N 1835 67 E ~.~68. .. · . 2646.90'" i874.41 N 1893.03 E 7312.2,1 '2812.63 1986,70 N 2015.57 E FEET D Fi 2274.19 N 44 5'1 E 2386.89 N 45 3 E ~585,62 N 45 14 E 2664,02 N 45 17 E 2830.10 N 45...~':~,~ E [u/lO( 0.7J 0.9~ 1.0~ 1.01 1.1.: I..I...OWING SURVEY SI'Al'IONS BY SC'IENTIFIC [IRII..LING / 8"'2t, .. ':.28 0 N 50 E 8306. 26 0 N 50 El 8369. 26 0 N 50 E 8464, 24 0 N 51 E 8560. 21 30 N 54 El , . 8'592. 21 0 N 53 E .. . ~.) ,-) 860... ~...1 0 N 55 E 8835. 18 30 N 53 E ' 90'72. 19 0 N 53 E ...... 55 ~'"'"'""' 744v.,8~. -,880.77 . .~030,69 N ..0o7,6,.~ [;. 2898 08 ~,,:,. =. . ~,~.. ~: ~?~.",,~.' .~ '.:.~; ,.?~;,:,,.~ .',.,,~: ,~ . ,, .~ . ,... , .'.,.~,,..~.,:.:;9~. ,~3t.9~.,,~ ,~0~90 ,,...~,.05.6.~3 N ,,.098.63 E. 2938 08 ,, ,,,, ,,? .;, . ',~,[., .? -, ) ~...,: ~, .~ ......... ,~ ~,,,? .; -., ,, .... , ,. ,,, . , . 76~0 ,.4~ ,:'~,;.~. ~~ Q~,~:~ ~0~8.8,,. N.:.~,.~ 1~8..08 :'E:.:', 2974 93 · , . · .~ : · ~ ... . ~:.:~ ~;~ ~,~..'.~.'~; . ~ ,., ,..~ ~ ,~,.., . " ~' o :,~ ;~?'~l~ ".''::'~ ":'.'?':~¢. c~' ~1;' ' ~. :'~'~,'~ ~ ~.':,' '''~ ,. "~ ") ,'. 76~0,,,.6. ~,~I.:,~.9'~: ~I"., , ;. ~08~ ,.7,, ,.. N "~137.40...~.'/.~ 986 4 233, 7878.88 3051,8~ ~;~:'¥~"1.,~.~.,~.0,. ,N? ,2203,99 E 3067 89 237. 8103.30 7360 69 2838,64 2003 60 N '~' · . ~.03.,,37 E 2856.07 N 45 27 E 7389 "~ 16 ' 2012 94 N' 2046,49 E' 2870 ='~:' .,.0 2~'53 ' .......... . .., ,,.~,.~ N 45 28 E N 45 31 E N 45 35 E N 45 40 E N 45 42 E N 45 43 E N 45 55 E 3128.02 2179.95 N 2264,83 E ' 3143,o50 i',l 46 6 E 6.5'" 0o0( 2.1~ 2,8'; 1.92 7.1; 1.1~1 0.2J F'INAL CI...OSURE - I) IRECI'ION I) I STANCE · .e ' S ....... e N ,46 .Dlii:G,.> 5 MIN 38 SE[,o E 3143050 FEET COMPLETION REPORT ~_ ~..." ... ~-"/..~.o OCTOBE 79 ARCO OIL AND GAS MAGNETIC HULTI-SHOT SURVEY -~-~ *~:: mB ~LEV 29 FT RADIUS OF CURVATURE M~THOD OF COMPUTAT~~ ~ DECLINATION 31 D~G EAST COMPUTED FOR SDC BY F RECORD OF .SURVEY ALL CALCULATIONS PERFORMED BY I B F4 ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D F1 SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES C L 0 $ U R E S DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT SECTION D[STANCE TIE IN WITH SPERRY-SUN MAGNETIC MULTI-SHOT SURVEY AT 27/+9 t'41,) DATED 10/3/79 2749 0 6 2749.00 2720,00 S38.00E 2779 1 15 2778,99 2749,99 S 5,00W 2872 0 0 2871.99 2842,99 $ 9.00W 2965 2 0 2964.97 2935,97 N63,00E 3059 4 45 3058.79 3029.79 N39.00E 3153 ~ 15 3152.18 3123,18 N39.00E 3245 11 30 3242.80 3213,80 N44.00E 3337 14 30 3332.43 ~303,4~ N49.00E 3429 17 45 3420.80 3391,80 3522 20 30 3508.66 3479.66 N42.00~ 3615 23 0 3595.03 3566,03 N3?,OOE 3707 24 0 3679.40 3650.40 N38.OOE 3799 26 15 3762,69 3733.69 NBT,OOE 3890 27 15 3~43.95 3814,95 N37.00E 3982 28 45 3925.18 3896,18 N~7.00E 4075 30 23 4006.06 3977,06 N37.0UE 4168 32 0 4085.61 4056.61 N~7.00E 4261 33 0 4164.05 4135.05 N39.00E 4353 34 0 4240.76 4211.76 N41.O0~ 5000 36 0 4770.73 4741.73 N4!.OOE 5092 35 0 4845.63 4816.63 N43.00E 5186 35 45 4922.27 4893,27 N41.OOE 0.8~ S 5.25 E 1,17 S 5,34 E 2,18 S' 5,22 E 2,95 S 6.28 E 0.50 N 10.55 E 8,77 N 1'7,25 E 20.58 N 27,70 E 34,b2 N 42,70 E 52,~7 N 60,75 E 75,b9 N 80.94 E 102.27 N 102,85 E 131,37 N 125.19 E 162.36 N 148.96 E 195.07 N 173,61 E 229,56 N 199.61E 266.22 N 227.22 E 304.68 N 256.21 E 344.06 N 286.97 E 382.95 N 319.61 E 663&01 N 563.07 E 702.71 N 598.81 E 743.15 i'1 635.22 E 5.31 $ 80 54 35 E 5.47 S 77 37 ~5 E 5,66 S 67 21 9 E 6.9~ S 64 50 50 E 10,56 N 87 16 6 E 19.35 N 63 3 0 E 34,51 N 53 2~ 15 E 55.10 N 50 48 26.E 80.54 N 48 58 11E 110.82 N 46 55 17 E 145.05 N 45 9 49 ~ 181.~7 N 43 37 8 E 220.34 N 42 32 10 E 261.14 N 41 40 9 k 304.21N 41 0 25 E 350.00 N 40 g8 5b E 398.09 N 40 3 39 E 448.03 N 39 49 5~ E 498.81 N 39 50 54 ~ 869.85 lq 40 20 22 E 923.25 N 40 26 ~ ~ 977.64 N 40 31 22 ~ 0,000 3,BO1 1,B44 2.157 2,931 3,723 3,539 3,279 3,~24 2.960 2,811 1.102 2.455 1,099 1,630 1.763 1.731 1.250 lek82 0.309 1.301 1.079 3.12 2,95 2.16 2,36 7.83 18,41 34,1; 80,36 1i0.76 145.0~ .~r 2g0.i3 303.44 348.~7 D96.56 4Qb.14 49°.7Z 866.~0 920.20 974.54 ARCO O/G WG MAGNETIC HULTI-$HOT SURVEY i8 ()CTCBEI-< 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I re M ELECTRONIC COi'qPUTEti TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SU ES DR I F T SEA D IREC DEG · TOTAL COORDINATES 5280 36 0 4998,44 4969,44 N42.00E 5374 37 0 5074.00 5045,00 N41.OOE 5466 37 15 5147.35 5118.35 N43,00E 555R ~8 0 5220,22 5191,22 N42,00E 5651 38 45 5293,13 5264,1~ N41,OOE 5744 39 1~ 5365,40 5336,40 N42,00E 78~,41N 826,28 N 867,55 N 908,96 N 952.20 N 996.03 N 5837 40 0 5437.03 5408.03 N42,005 1040,11 5928 40 0 5506,7~ 5477.74 N44,00E 1082.88 6021 40 30 5577.72 55~8.72 N41.OOE 1127,18 671,72 E 708,77 E 745,93 E 783,87 E 822,12 E 660,90 E 900.59 E 940,48 E 981,07 E 6113 41 0 5647,~2 5618,42 N45,00E 1171,09 N 1022.02 6207 38 30 5719.69 5690,69 N47,00E 1212,84 N 1065,25 6300 39 0 5792.21 576~.21 N49,00E 1251,79 N 1108,51 6392 40 0 5863.20 b834,20 N48.00E 1290,56 N 1152,34 6483 ~1 0 ~932.40 5903.40 N48,00E 1330,11N 1196,26 6576 41 30 6002,32 5973,32 NSi.OOE 1369,9~ N 1242.88 6669 ~3 0 6071,16 6042.16 N49,00E 1~10,12 N 1290,78 6761 44 0 6137,89 6108.89 N50.00E 1451,25 N 1358,9~ 6854 43 30 6205,07 ~176,07 N49.00E 1493.01N 1387,83 6948 40 30 6274,92 6245.92 NSI,OOE 1533.44 N 1436,01 7042 38 0 6347.71 6318.71 N49,00E 1571,6~ N 1481.56 ' 7137 37 15 6422.95 6393,95 N46,00E 1610.8~ FI 1524,~1 7232 37 0 6498.69 6469,69 N47.00E 1650,31 N 1565.91 7~27 37 0 6574.56 6545,56 N47,00E 1689,30 N 1607,72 7422 36 0 6650,93 6621.93 N46.00E 1728,19 N 1648,71 7517 35 0 6728,27 6699,27 N~6.0OE 1766,52 N 1688.39 7611 34 0 6805,74 6776.74 N45,0()E 1803,83 N 1726.36 7705 34 0 6883.67 6854.67 N47,00E 1840,34 N 1764.17 7800 33 0 6962,88 6933,88 N45,OOE 1876.77 h~ 1801.89 7895 32 0 7043,01 7014,01 N48,00E 1911,90 N 1838.91 CLOSURES STANCE AN$LE D M 1032,72 N 40 34 29 i 1088,63 N 40 37 20 E 114~,14 N 40 41 21 E 1200.27 N 40 46 26 E 1258.00 N 40 48 26 E 1316.52 N 40 50 17 E 1375,82 N 40 53 17 E i4~4,28 N 40 ~8 27 E 1494,34 N 41 2 8 E 1554,35 N 41 6 41 E 161~,24 N 41 17 ~5 ~ 1672,06 N 41 31 34 ~ 1730.16 N 41 45 41 E 1788.92 N 41 58 1 E 1849,72 N 42 12 ~8 E 1911.69 N 42 28 11 E 1974,55 N 42 41 41 E 2038,42 N 42 ~4 32 E 2100,84 N 43 7 14 E 2159,90 N 43 18 ~4 E 2217,73 N 43 25 9 E 2274.99 N 43 Z9 48 E 2332,06 N 43 34 ~7 E 2388,49 N 43 39 5 E 2443.61N 43 42 16 E 24~6,83 N 43 44 34 E 2549,35 N 43 47 21 E 2601,74 N 43 50 2 E 2652,73 N 43 53 6 E DOG LEG SEVERITY DEG/IOOFT 0,454 1,131 0,842 0,913 0,910 0,689 0,806 1,413 1,46~ 1,949 2.784' 1,007 1,176 1e099 1,515 1.898 1,207 0,741 3,315 2,779 1,401 O,4S~ 0,000 1,114 1,0~3 1,190 le~24 1,376 SEC T ! ON DISTANCE 1029.51 1085,31 1140.76 1196.86 1254,49 1312,90 1~72,12 1'90e5~ 1550,59 1610,69 1727.23 178~,2~ 1~47,3c 1~09,~ 1972,82 2036.94 2099.00 21b~,85 2216.79 2274,11 2~31,25 2587.74 2~42,90 2496.14 2948,69 2601.12 26~2.14 ARCO O/G WG[-4 MAGNETIC MULTI-,SHOT SURVEY '18 OCTOBER 79 RECORD OF SURVEY ALL CALCtJLAI'iONS PERFORHED BY I L~ ,",1 IELECTRONIC COMPUTEN TRUE HEA5, DRIFT VERTICAL DEPTH ANGLE DEPTH O M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 7990 31 0 7124.01 7095,01 N47.00E 1945,43 N 1875.51 E 8084 30 0 7205.00 7176.00 N46.00E 1978,27 N 1910.11 E 8211 28 0 7316,07 7287.07 NS0,OOE 2019,46 N 1955,86 E 8306 26 0 7400.71 7371.71 NSO.OOE 204.7,18 N 1988,89 E 8369 26 0 7457.33 7428.33 NSO.OOE 2064,93 N 2010.05 E 8464 24 O 7543.43 7514,43 NSi,OOE 2090,47 N 204,1,03 E 8560 21 30 7631,95 7602,95 N54,00E 2113.06 N 2070,47 E 8592 21 0 7661,78 7632.78 i'q53,0OE 2119,96 N 2079.80 E DATA FROH MAGNETIC MULTI-SHOT SURVEY bATED 10/16/79 8602 21 0 7671.11 7642,11 N55.0OE 2122,07 Fl 2082,70 E 8731 18 30 7792,51 7763.51 N52.00E 2147.99 N 2117.73 E 8826 1~ 45 7882,54 7853e54 N53,0OE 2166.46 N 2141,80 E 8921 18 45 7972,50 7943.50 N52.0OE 2185,O5 iq 2166,03 i 9015 19 30 8061.31 8032,31 NSI.OOE 2204,2Z N 219[).13 E 9110 19 45 8150.79 b121,79 NSi.OOE 2224.30 N 2214.,93 h 9204 19 30 8239.33 8210,33 NSO.OOE 2244.39 N 2239.29 E 9299 19 30 8328,88 b299.88 NSO.OOE 2264.77 Fi 2263.58 E 9393 19 0 8417oO3 8368,63 NSO,OOE 2284.69 N 2287,3~ E 9~+8~ lb 45 8507.52 8478,52 NSi.OOE 2304.24 N 23i1.03 E 9512 1~: 45 8530.24 6501,24 N51,OOC 2~09,09 i'~ 2317°03 g CLOSURES DI.STANCE ANGLE O .N S DOG LEG SEVERITY DEG/IOOFT 2702,27 N 43 57 5 E 2749,93 N 43 59 4.4 E 2811,33 N 44 5 0 E 2854.24 N 44 10 21E 28~1,71N 44 13 42 ~ 2958,56 N 44 25 0 E 2969.82 N 44 27 7 f 1,089 1,097 1,721 2,105 0,000 2,112 2,638 1,61~ 2973,35 N 44 27 48 E 3010,40 N 4.4 35 36 E 30~6.46 N 44 40 19 E 3076.71N 44 44 58 E 3107.29 N 44 48 58 E 31~9,02 N 44 52 44 E 3170.44 iq 44 5~ 5 E 3232,90 ~ 45 1 58 h ~2C3.49 N 45 5 3 E 327i.17 N 45 5 53 ~ 7'167 1,952 0,285 0.338 0,807 0.263 0.291 0,532 0,28~ 0.000 SECTION OISTANCE 27(.)1.73 2749,42 28i0,90 2853.87 2921,35 2958,16 2969,63 2973,17 3016,29 3046.37 3076.6~ 3159.00 3170,43 3202.02 3232,90 326~,49 3271.17 BOTTOM HOLE CLOSURE 3271.17 FEET AT N 45 5 53 E ARC(') O/G W~I-4 ?,'iAr3?~iETIC ;',~iULTI-SI'tOT SURVEY :INTERPOLATED TRUE VEiIqT[CAL DEPTHS~ COORDINATES AND CLOSUF~ES FOR GIVEN DFPTH,S TRUE CODE MEASURED VERTICAL TOTAL CL~Oi~,i)INATES C L O ~ U R E NAHFZ DEPTH DEPTH D ISTAF~C~ ANGL~ D M S OCTOBER ARCO O/G WGI-4 ?','~AGNETIC MULTI-SHOT SURVEY MEASUREO DEPTH AND OTHER DATA FOR EV~:RY EVEN 100 FEET OF' SUE~ SEA DEPTH, OCTOBER 79 TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD INAI'ES 2829 2829, 2800 0 0 2929 2929, 2900 0 0 3029 3029, 3000 0 0 313'3 3129, 3100 0 0 3231 3229, 3200 1 1 3333 3329. 3300 4 3 3~38 3429. 3400 8 4 3544 3529, 3500 14 6 3652 3629. 3600 22 8 3762 3729, 3700 32 10 3873 3829. 3800 44 12 3986 3929. 3900 57 13 4102 4029. 4000 72 15 4219 4129, 4100 90 18 4339 4229, 4200 109 19 4460 4329, 4300 130 21 4581 4429, 4400 152 22 4703. 4529, 4500 174 22 4826 4629, 4600 196 22 4949 4729. 4700 219 23 50?2 4829, 4800 243 24 51~4 4929. 4900 265 22 5318 5029. 5000 286 23 5443 5129, 5100 313 25 5569 5229. 5200 340 27 5697 5329. 5300 368 28 5626 5429. 5400 397 29 5957 5529. 5500 428 31 60H8 5629. 5600 459 31 6219 5.729. 5700 489 30 6347 5329. 5800 518 29 647b 5929. 5900 549 31 6612 6029. 6000 5d2 33 b748 6129. 6100 619 37 6987 6229, 6200 658 39 1.96 S 5,26 2,67 S 5,50 1,06 S 8,96 6,30 N 15,25 18.5~ N 25,82 34,16 N 41,97 54e86 N 62,49 81,48 N 86e05 113,88 N 111,$7 149,40 N 139,12 188,87 N 168,94 231,10 N 200,77 277,05 N 235.39 326.27 N 272.81 376,97 N 314.44 42~.~0 IN 359.04 480,06 N 404,02 532.70 N 449,79 586.33 N 496.41 640,43 N 543,44 694,13 N 590,8? 746.6~ N 638.29 857.31 i'~ ?36.46 914.00 N ?88.40 97~.90 iN $41.16 1034.86 N 695,8'1 1096.42 N 953.34 1159.39 i'.i 1010.56 1217.89 N 1070,69 1271.40 N 1130.87 1327.92 1'4 1193.82 1385.15 i, 1261.42 1445.44 N 1332.03 1507.54 N 1404.74 ARCO O/G WGI-4 MAGNETIC MULTI-SHOT SURVEY MEASUREED DEPTH AND OTHER DATA FOR LVLP, Y EVE~,I 10(; FELT OF .SUB ,SLA DEPTH, I6 OCTOGER 79 TRUE MEASURED VERTICAL SUB MD-TVD VkZkT I£AL DEPTH DEPTH SEA DIFFERENCE COI:~RECT I ON TOTAL COORDINATES 7018 6929. 6300 689 31 7144 6429. 6400 715 26 7270 6529, 6500 74i 26 7395 6629. 6600 766 25 7518 6729. 6700 789 23 7639 6829, 6800 810 21 7759 6929, 6900 830 20 7878 7029. 7000 849 19 7996 7129, 7100 867 18 6112 7229' 7200 883 16 8226 7329, 7300 897 14 8337 7429. 7400 908 11 8448 7529e 7500 919 11 8557 7629, 7600 928 9 8664 7729, 7700 935 7 8769 7829. 7800 940 5 8875 7929. 7900 946 6 8981 8029, 8000 951 5 9087 8129, 8100 957 6 9193 8229e 8200 964 7 9299 8329, 8300 970 6 9405 8429. 8400 976 6 9511 8529. 8500 982 6 1562,00 1613,78 1665.88 1717,09 1766,87 1861.00 1905,82 1947,47 1987.74 20~3,~5 ~055.9~ ~086,34 ~134,64 ~155,40 2197,11 ~219.39 ~264,77 2287,20 2308,83 1470,36 1582,61 1637,16 1688,76 1737.49 1785,89 1832.23 1677e70 1920.06 1999.30 20~5.9~ 2069.53 2100,18 2127,28 2154,34 2181,28 2208,85 2236.47 2263.58 2290.31 2~16e70 ARCO O/G WGI-4 MAGNETIC MULTI-SHOT SURVEY :1,8 OCTOBER 79 INTERPOLATED VALUES FOR EVEN 1000 FELT OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA 3000 2999. 2970, 4000 3940, 3911. 5000 4770. 4741, 6000 5561. 5532. 7000 6314. 6285, 8000 7132, 7103. 9000 8047, 8018, TOTAL COORDINATES 2.15 S 7.59 E 236.51 i~ 204,84 E 663,01 N ~63,07 E 1116.95 N 972.07 E 1554,64 N 1~61,67 E 1948e94 N 1879.26 E 2201.09 N 2186.24 E HORIZONTAL VIEW ARCO OIL & GAS W.G.I. No. 4 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT SCALE 1"=500' OCT. 18~ 1979 68OO 7200 6400 8000 7600 TVD: 85'50' TMD= 95 12~ 6400 6000, 48OO 52OO~ ALL DEPTHS SHOWN ARE TVD 44OO 4(XX3 3600 .vt 4OO 8OO 1200 1600 2OO0 240O 280O VERTICAL SECTION ARCO OIL 8~ GAS W.G.I. No. 4. RADIUS OF CURVATURE MAGNETIC MULTI-SHOT SCALE I"= I000' OCT. 18, I979 48oo~ ' 6~ ALL DEPTHS SHOWN ARE TVD TVD: 8530 ' TMD= 9512' : ' '-~:. .... ".:" ~"" ". '.' ' N HQ ? ~ ~ .., , , · ~TL~NTIC RICHFIELD ,COMPANY... ' ALASKA ME'A SURED DEPTH COMPUTAT IO:N OCTOBER 29,~ VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG MIN DIRECTION DEGREES DATE 1979 SEVERITY DEG/IO0 BOSS GYROSCOPIC SURV Y dOB NUMBER BOSS-16Q65 KELLY BUSHING ELEV. = Ag.D.O FT. RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION lO0 200 300 300.00 ~tO0 399.99 500 499.99 251,00 0 16 350,99 O 3q ~50.99 0 33 ............ ....... ___fl..:._o._O.,_,: _7_.9_9. 900 899.97 850.97 1000 999.97 950.,97 1100 1099.97 1050,97 1300 1299,96 '.: ' 1250.96 1400 1399,96 ! 350~ 96 .............. 15'~0 ...... I'~-9-n,-;-g6 ' i 4 5"D ,9 6 1.660 1599.96 i550.g6 1700 1699.96 1650.96 ................... i"~ 0'0 ............ i'79-9'-.-9 ~-'--'---'-'i--7-5-0-;'-9--~ -- 1900 189g.96 1850.96 1999.95 1950,95 S 15. 0 E S 1.10 W S 10.69 W ,10 2100 2099.95 2200 2199.95 2300 2299.95 ........ 2"~:'00 2500 2~99.95 2600 2599.95 .............. P.7o 0 ....... ~-6-g 9. q '~-- 2800 2799.90 2900 2899.85 ........... 3'O 0'6' ............ 2-9'-9 g';-'? A ........ '2.06 S .29 E -1.20 3.0~ S .19 E -1.95. 0 23 · 0 22 S 6.69 W .03 7,51 S .10 W -5.22 0 16 S 3,60 W .09 8.07 S .16 W -5.65 .- 37.30 E · 02 37.10 E .21 ~37~--0~" :""" ":" < ""TTO 1' 0.:~'~9';~ s ": ........... I;4.0 , . . . ,' .... . . 4~8.79 E '.:55. 1.0 ., 8 5. :.. S 1.68 0 22 N 88.80 £.," .SQ E -6.5 ' 10.51 S 1,11 E -6o, 10.7~ S 1.28 E -6.43 2.20 2 2.76 2.92 3,-O-~--E 5.16 E 3.53 E 5,88 E 3.36 E 3.3g E · . .. -~'. 68;" ':-- -6.7z~ -8.78 -~.02~- ..~ , .: . ' ,.,: : . .,: ,<:; :: :: .:.:,..(/:... 2q50.95 0 6 S 72-50 2550.95 0 21 S 61,89' '~CS-O-T 9 4 0 zi"3-----~---'~", i9 2750.90 2 12 S 17.50 2850.85 1 29 S 27.60 ~'~"5-0-;-'?~ .............. 3 ...... :~'~ ...... ]~-'~'e-;-~+-O' 028 .07 .10 ,25 .60 1.58 1.57 ~'1! "... :!5,6'~' 'S E -6,21 :' "~. E':~' .,,'..5;..70.:'"" "E -5.3~ E -5.08 E 2150.95 0 7 N 21.6,0 E 2250.95 0 12 N ~.0. 9 E 2350.95 O 1 S 2050.95 0 9 N 4'5. 9 E ATLA~TIC RICHFIELD COMPANY f."P UDHOE BAY ALAeKA ANCHORAGE,~ '<ALAS OCTOBER 29, 1'979 dOB NUMBER BOSS-1,6465 KELLY BUSHING ELEV. : 49.00 FT, TRUE FfE ASURED VERTICAL D E P T H DEP T H SUB-SEA v E DEPTH COURSE: DEG KIN DEGREES 3100 .-5200 31.98,22 3300 32';95,85 3500 3486.39 5600 3579.16 3760 3800 5760,82 5900 38~9.76 4OOO 3937.61 4100 402~.06 3437.39 3530.16 3711,82 3800"76 3888,61 3975.06 10 53 23 8 26 28 27. 54 29 9 N' "41. 44.29 E 38.40 E N 38',:90 E '.N...: 39,29 E'~ N ~9,79 E N 39,79 E 4200 41o8.9~ ,~o59.93 ~.qO0 4275,39 /+226,39 4500 /+357,86 /+308,86 ................. 4'~;'b'-~ ........ -4"~-:~ 9--;-~' 2 /+ 4700 4521,61 4472,61 4800 4603.09 455/+.09 4900 ~68Z~.61 /+635,61 32 40 33 5~ 3-~'---5'5 ......... 35 19 35 32 5000 4766.1/+ /+717.1~ 35 32 DEG/IO0 NORTH/SOUTH 3,06 60,1.3 N 3,26 88.20 N 5100 4847 5300 5009 5400 5089 5560 516g 5600 5247 5700 5800 5900 6000 6100 , ...8 4798,58 · 53 4879,53 ~5 46 3'5--~'.5 ........ 36 /+3 36 59 37' /+6 38 11 · 18 4960.18 · 2§ 5040.20 · 65 5119,65 ,47 5198,/+7 EAST/WEST SECTION 80.07 E 99,51 104.6q E 136.64 5325,32 5276.32 5402.08 5353,08 5~78.28 5429,28 555q.19 5505.]9 5629,97 5580,97 39 40 35 40 ,NO 36 36 N A0,59 E N' N 40;50' E' N 40,50 E N '41.29 E 2.00 263.71 N 1.58 30/.t,09 N · 39 518,67 N ,51 562,'~8 N 248.99 E 362.06 283,12 E 41/+.59 4 66.q/+ E 50/+.qO E 695,. .) 752,84 k ~'6,29 E · 2,98 959'51"".N.' · 865"39 .Ei..i' · 1.287,85 ":' '. :. '. ... . ',. .,:.<. · .. . .. '1 m ~~'0 ' E 1.63 N 43.50 E ,55 1051,56 N 955.51 E 1416,57 N qq,9O E .91 109'8,"22 N 1000,89 E 1481,59 · .. ,33 . .2~ 1.05 ,55 °55 692'92:::N. 619.7~ E . .' 926"..2~ 1~6'~:1'U N' 5~'¢.U~ t 9~'~.5i ..... "~ 780.01 N 698,70 E 1 824,qq N 738.99 E 1103,22 '869~10/N 780.1'2 E.:' ." "1'1'6J 914,5~ N 821,62 E 1225,16 N /+2. 0 E N--4-~;50 E 41 . 79 E N q2.59 E N ',2.70 E N q'2, 9 E ~TL .~, NT I C UG I-q PR UDFIOE ~LASKA n ! CHF .1: ELD I: GM__? A~Y.L'.:'/?.' :: '. B A Y SPERR ~NCHORAI COMPUTATI OIN DATE OCTOBER 29~, 1979 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16/+65 KELLY BUSliING ELE'V. = 49.00 FT. PEASURED VERTICAL VERTICAL REPTH DEP TH DEPTH INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 6200 57 ~+00 58 6500 59:36,57 6600 6011,03 6700 6084.04 6800 61,56 6'q00 6229,,50 7000 £306./+2 7100 6385.31 7200 646/+. 8/+ 7300 6544.64 7~00 6624 7500 6706.26 7600 6788,52 77130 7806 7~00 8000 6,100 P. 200 5887.57 5962.03 6035.0/+ 6336.31 6657.'.-26 6759"52. 6871,65 6822,65 6955.53 6406,53 41 11 IN 51.50 E 0 1 /+2 33 N 51,/+0 E 1.37 1345,8~ N 1300./+6 E' 1869.43 /+3 38 N 51.20 E 1,09 1388.56 N 1353,79 E 1937,5/4. 37 29 N /+9./+0 E .89 15! N ~7 9 N 48.90 E .45 1595.38 N 1602.09 E 2260.09 36 57 N 48,59 E ,28 1635,11 N 1647,40 E 232.0.31 ~ 22 N 47. 9 E .87 1 32 35 N /+7.59 E .83 1825,66 N 1858.86 E 31 53 N ~8,29 E .78 1861,39 N 1898,/+7 E 2658.23 · 70/+0.11 6991.11 7125,57 · 7076,57 7212.15 . 7163'15 7299.77 7250,77 8~00 8600 a70O ~800 8900 9000 ~100 o. 200 7388.33 7.'~39,33 7478,50 7~+29,50 7570.58 7521,58 27 24 21 4 N /+9,79 E 1,17 1991,/+1 N 20/+5,86 E 2851~,66 8 N 51./+0 E 3,02 2018,86 N 2079,23 E 2897,78 /+2 N 52,20 E 2,45 20~2,95 N 2109,83 E 2936,57 53 N: '51'90':?ETM 1'81"';'i':':/~i'"206~'79'N''::': : " 213-7 '; 8 ~ i": 'E 55 ' N 5~.50 E 2' 15'"' · ' ' . ' -..'.:':~ 2:138/+' 2 3' N .:' 2163 · 75 .E' 1/+ ' N .'55,;20-:E" :: .- ,39. 210~,,.o~.;:;:'u.: 2189,13. 31 N 5/+,90 E .30 2i'20'";'16 N 2'21/+.97"E ......... 15 N 53.79 E .81 2139.02 N 22~1.27 E 3098.12 33 N 54.20 E .34 2158.55 N 2268.15 E 3131.07 57 ' '" ' N · 5:3.59; :"E' ""G ~':"':':-"'.::'~:': 217.7,9'8::::.: N .'.. ': 22 9 ~ ,'80. E .':""!'" 766/+.05 761'5.05 7758.64 7709.64 7853.70 7804.70 19 17 18 7948.60 7899.60 8043.21 799/+.21 8137.53 8088.53 8231,93 8182.93 18 19 19 18 SFERRY-SUN:'UELL SUt~:V'EY: . 'JG I-q CONPUTATION DATE PPUDHOE E~AY OCTOBER 31,~ 1979 .T' ,.,:,':'~ " ~aE ASJ~RE.D VERTICAL VERTICAL INCLINATION EI'RECTION DFPTF$ DEPTH DEPTH DEG NIN DEGREES S El V E FL I '1' Y DEG/1 O0 ~300 '!:::5, 52. 0.00 8326.50 ~:,::': 82~ 5'g ': 19 . 18 ":: 1 7 8595,63 85~6,63 18 17 HOR]iZOI~}TAL DISPLACEMENT : 3286.36 FEE"[ AT NORTH,~ q6 DEG. ... ........ ? ......... ..................... ? ....... _,.._~.~?,._:..~..~_..~,,~ ..;,., . EOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16q65 KELLY BIJSHING ELEV, = 49.00 FT. RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 2252,9~ N 23~2,58 E ~3 MI.N, EAST AT MD : 3286.36 WG I-~- COI~PUT/~T lOIN /~L./~, S KA DATE 1979 dOB NUMBER BOSS-16465 KELLY BUSHING EILiE'V. = 49,.00 FT. TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES ND-TVD VERTICAL S ,10 W ,03 . S 2,20 E ,05. ,01 3000 2999.78 2950.78 15,64 S 6,~6 E ,22 ,18 O0 7080 ~:306,q2. 6257,q2 1515,94 N 1509, q0 E ~!O00 7125,57 7076.57 1~t96.93 N 1.937, 9000 ~04.~,21 799~,21 2139.02 N 22~ 1., 27 I THE CALCULATII(~IN P~OCEDURES ARE ~A~ED O [l~ ~HE USE OF:]l: 693,58 2q7,77 87z~,q'3 180,85 956,79 8.2,36 . :, J :::l ll:jj JJ ii: : ' : l 'J ' ' j : J:J:: j j j J : J JjjjJ PER WG I -4 PRU~HOE E~,AY AI../~ SIr ~ CONPUTATION DATE OCTOBER 31~ 1979 dOB NUMBER BOSS-16~65 KELLY BUSHING ELEVo : 49,. O0 Fl], TRUE SUB-SEA TOTAL . :~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~ 419 49'00 0,00 ,03 S ,00 E ,BO ,0~ 1q9 149.00 100'00 .59 S ,08 E ,BO .00 249 249.00 200.Og 1.10 S .1H E .00 .O0 ..... ::~,~ :~ ,,:, :., ,:l., .,,, ,::..,,.,,:, :,',',.:l:. ~' l:l'. ':, 5,, ':Z'i' :' ,' t'<.:,::"~ :.L),i.',:, :':,';'l':." ':~,'~" 7: :%~'('F 'I'':::~{'~U"~'~%'?'~ :"{': / "' IL'll'~''.:: ~C.~ 7:': .)li'l'l,''' :' :?':{S": ~"l,'}; ?l' ':~ :' ?:':/' .':' ?,' l}:{. { '~',:<ql{:13} '::. ,l l' I. :::":'l :Il'. :':' .{.l::'l]l':(',ll}I. .~ : ,~ ,:' o ' ~l:.: ~,oo..,I. I s.' ? :.::~l~ll,:: el:':':~::.:~l:~?.:~.: :~ ~:::~:~:~:~:;:~,:l:;:~:::~l:l~::::~ ~:~.~:~::~:::l :::':l:,::':~ ~:'l'l~:: :ll~.'.::::l.):~:: ?:::::ll.::::l:l:::{?.:'::~: Z49l 649 649,00 GOO,O0 q,76 S ,08 E ,02 .01 749 749,00 700.00 5,66 S ,0~ W ,0~ .OO 84~ 849.00 800.00 6.5D S ,05 E .O~ .OO 1249 l'"4g~_ · O0 1200. O0 1~,+~ ~4~.oo ~oo.oo 144v ~,,4,~. oo ~oo.oo 1549 154'0'. O0 1 500210'0'' 1649 1649.00 1600~00 1749 1 749. O0 1 700, O0 9.06 S . 16 E 9.61 ~.~2 s .71 E .04. .oo · . · . .: . . . · 'AlrL ~,r, iTI C RICHFIELD prUDHOE 6AY ALASKA CO~iPANY SPERRY-.qUN NEL'L' SURVEYING'' COMP ANCHORAGE, ALAS £OHPUTATION DATF OCTOBER 31~ 1979 dOB NUMBER BOSS-16q65 KELLY BUSHING ELEV. = 49.00 FT. TRUE SUB-SEA F~EASI~RED VERTICAL VERTICAL -6'~' 'iF':r i:i .................... D-'~"D-"f ~-,-i .... TOTAL RECTANGULAR COORDINATES MD-TVD NOR VERTICAL 10.&7 S 2049 21~9 2249 2349 2449 2o~.oo 2000.00 1o.6~ s 214,¢. oo 21oo.oo z o.,+5 s 2_ 2 ~+ ,~'7~'E-~,'--,' 2 2 0 0. o o = .... "" ?~i 2349.00 2380.00 5.97 S 2qqg. O'O 2~00,00 1.88 E 2.49 E. 2.71 E. 2549 2649 2749 294c, 3049 ~150 32<51 "355 5460 7,.967 'J676 25~9.00 26~9,00 2749.00 3'03 9 .g6 .' $..:' .'..:..:.:..:. .3'.,'.08. 28 29 30 49 49 49 .00 .00 ,00 31 52 49 49 .00 .00 2500.00 10.05 S 2600.00 18.35 S 2700.00 11..66 S 2800.01:? 1..'5 · 1 ~ S 2900.00 16,75 S 3000.00 13.08 S 3100.00 ~'~, 95 .5200,00 1.0,13 3300.00 27,40 .05 .05 .00 3.27 E .05 .00 3.78 E .05 .00 3.88 E · 06 .0 1 ~'449 O0 3400.00 50'32 3549.00 ::5500.00 78.4.5 . 1.05 .69 2.87 1.81 6.10 3,23 · . 1~.31 .' 7.13 . 12.3, 86 E "i:::..' 27, ~ '.'..,'....'..:'i:!;.:~..:,.: 8,9 3 · ...' ". .... .'... ,: S 16.2R ET ,~',' 29.05 E N 4 7.89 E N' ". .... 'i'77'6;.50 E N 96.6~ E 36 49. O0 3600,00 111.97 PP. UDHOE AL. AS~'A ., .ii~i'i!'i':: .~C,~OR.AG[. COrqPUTATION DATE O£T'OBER 31,~ 1~?~ dOB NUMBER BOSS-'16~t65 KELLY BUSHING ELEV, = FT. TRIIE SUB-SE A TOTAL 3P, 99 38z~9.00 3800.00 1.87.98 N 18&.16 E 50,I~ 12.35 ~913 39~9.00 3900.00 230.~0 N 220.90 E 6~,0~ 13.91 ,+~ ~9.oo ~oo.oo e75.~o ~ ~.~ E ~0.~5 ~.!0 q~ll q4~9.00 q400,O0 ~79,7~ h q33,2q E 1.62,26 22,01 q733 q, 549,00 fl500,00 533.q, 2 N 479.05 E 18q,57 22,37 z~56 ~6q9.00 ~600.00 587.09 N 526.00 E 207.~5 22.82 ~ s 7 ~ ~ 7 ~.:9"'o'o: :70 :~'; :" ~: ~:'o ;':~:;t ~ ~ ~ ~: ,~ ~'~ ~. ~ ~' ,.: ~ ~a::,~. ~'~ ... ,.: :. ~ ...~,, . . . · . . :..,, ,:...........::: ....' .. . ... . r,~st 5~.00 5~oo,oo ~0~.~5 N ~.12"~. ~ ..:. ~qgs 55q9,00 '5500.00' 1095 07 N . . .,, .- ~ ~ . .v',:..' ' ': ...... '~TL~r;TIC ~ICHF:IELD COMPAk¥ ; '. PR UD HO E ALASKA B A Y S'FERR.Y.,..U ~ k iELL.. SURVEY. tNG.'..'COMPANY ". ,~NC~,CRA~E,, AL,A~-! , ' ,' '.'... ::.., .,:SURV, CONPUTATZO~ DATE OCTOBER 31~ 1979 dOB NUMBER BOSS-16~65 KELLY BUSHING ELEV, = IRUE StJB-SE A I~E~SURED VERTICAL, VERTICAL RE CTANGLJL,~R ..... '6"[i'~;T'fi ........... : ...... :': ..... D E---'P-'~ .-: DEP :T H' ':' ~ . · . ," ..... : .................. 625q 57~9.00 5700.00 1205.01 N 638~ 58~9.00 5800.00 1257,20 N 6516 59q9. 6925 62~9' 705q 7180 6A4~. 7305 65~9. 75 76 77 79 2.9 66qq. 52 67~9, 72 6R49. 92 6949. 18 70q9. TOTAL : COORDINATES MD-TVD VERTICAL O0 6300.00 O0 6qO0oO0 O0 6500.00 O0 ~"~:i]'~ ..... 66~0'00' O0 6700'00' O0 '6800.00 1124,3R E 505.2.7 29.09 1189.12 E 535,,33 30.06 1256,78 E 567,52 32.19 1.537,57 N 1535.03 E 705,20 28,48 1587.49 N 1593, 05 E 731,1,3 25,93 1637.28 N 16e~9,86 E 756.~.5 25.32 O0 6900,00 O0 7000,00 O0 7100.00 1778 ,.,, ~2 N ....:,,.. .... . 1822o~4 N 1855.78 E 8z~ ,., 1865.fl8 N 1902.61 E ~t61,z~8 1905.32 N 19~7.~6 E 878.2,3 [~027 71~9. ~lq2 72~9. ~255 73~9. ~367 7~q9, ..................... O0 7200,00 O0 7300.00 O0 7~00.00 194.3, ¢+6 N 1978,39 N 2010,36 N 1989, 6.2"' E ."' 2036. q. 7 E, 2068.70 E ' :. ,. 18.23 16.76 8 93 · 27::':~'?' ;:':!~'~''~:: :'!"":' 7:':...-.:.:,., . 15',: 0 ' 966.80 "..i'..". "!. 13,53 918.5~+:. '.:.:i:.:.:/i.'.,,.'.~. '. 11.7 ~ ' PRU~HCE [JAY /~LArFA C Or", P AN ¥' COMPUTATION DATE OCTOBER 31~ 1979 dOB NUMBER. BOSS-1,6q65 KELLY BUSHING ELEV, = 49, O0 FT. f~F A SURE DEPTH l'kUE V£RT SUB-SEA VERT 8689 77q9,00 7700°00 8795 78~.9. O0 7800.00 RECT TOTAL R C{ S 2061,q3 .N 2133,55 E 9Z5,00 7,.22 2082,42 N 21.61,22 El 9q0,87 5,88 2101 o2 N 2 ~q6,05 5 12 9218 8249 c~'~ 2 3 8349 .. ~.~42 9 .q534 956 O ~57 2 Tt!F C/1L£ULATIO THE NEAREST · 00 8200,00 · 00 8300,00 .00 ~qO0.O0 :.. ; -. , . : ,~~~ ..~.:., :.. · O0 : 50.0 .'8,~ :,i' 8523~'8~ · N PRCCEDURES USE 20 FOOT MD (FROIv 2.160 2181.q6 N 2299.51 E 969.04 5.87 2202.2fl N 2326.93 E 974,80 5.75 2223 ~1 235q 1.5 E 98 · ~ · 0.50 5-70 · ~~r~: ~' ............ ..~,.. · 2.2 ~'8 ' 30 6:;".'6 ~':':: !E !":'!i:i: i":i'.9 'l;:,: .:~::':'.:~:~i :i i:::j':.::ii':'"::':"::.:;']:/;,:': :.':.!~ LINEAR INTERFOLATION BETWEEN i RADIUS OF CURVATURE) POINTS ," ! 'ATLANTIC RICHFIELD ANCHORAGE,' ALASK PP LIDHO E ALAS~'A t-.i A Y COf,IPUTAT I ON DATE OCTOBER 319 1979 P,,,F P T H ,,, 9584 T RUE VERTICAL SIJB -SE A VERTICAL R[CTAN6ULAR 849D.24 R~+1.2~ 2231 ~1515.H7 8AGG.87 223G.70 8595,63 85AG.G3 2252.94 TOTAL COORDINATES 2365.11 E 2,371.79 E 2392.58 E dOB NUMBER BOSS-16465 KELLY BUSHING ELEV- BASE SEDIMENT SURVEY DEPTH T.D. PLUG BACK = 49.00 FT. ~TL/~NTI C RICHF1EL:D___:CQNP_A_~K_Y.. ~... ~ .:! .~ PP UP, HC)E BAY ( ..... t * c~ ~ · , ~ ALASKA KL.j ~ ~ ~ $~ERRY-EUN TRUE SUB-SEA_ _~, COURSE NE'ASUkED VERTICAL VERTICAL I-~CL INATI ON DEPTH DEPTH DEPTH ~DEG MIN ~JELL ~-O'RVEYING, COMPANY PAGE 1 ANCHORAGE~ ALASKA [3ATE OF. sURVEy OCTOBER. 25, 1979 COMPUTATION DATE OCTOBER 29~ 1979 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-1GqG5 KELLY BUSHING ELEV. : COURSE DOG-LEG .... TOTAL DIRECTION SEVERITY RECTANGULAR COORDINATES DEGREES DEG/IO0 NO~THISOUTH EASTI~EST 49.60 FT. VERTICAL SECTION 0 0.00 '. -49,.00 0 0 100 100.00 51..00 0 21 200 200.00 15!,00. 0 17 .... 3'00 300.00 251,00 N O- 0 E . 0.00"' S 7- 69' E , ~5 $10,8.O E ' 0" OO ... ' ,30 .S ~ '. . ,85 :S . 0 16 S 15, 0 E .03 1.33 S · 04 E . · · 24 E qO0 399.99 350,99 500 499,99 q50.99 600 599,98 550'98 700 699'98 ' 650,98 900 899,97 850,97 1000 999,97 950,97 0 34 S 1,10 W 0 33 S 10.69 W .10 '0 ~ 3 0 30 o 29,' 0 23 0 22 1.100 1099.97 1050.97 ....................... ....... 1300 1,299.96 '1250,96', 14oo 1~99.96 ......................... 1' 5'"'6"0 .............. I'¥'9'~T~'g ...... 1600 1599.96 1550.96 1700 1699.96 1650.96 0 16 S 11., 0 W S 6.69 W .0,'5, S 3.60 W .09 2.06 S Z,O4 S O 16 S 37.30 E 0 3 S 37,10 E 7.51 8,07 S · 29 E -1.20 · 19 E -1,95. .~-~' ~~~~ S?:'. '~ :.: *021:'E.. ' ~3,57 '""' .ou' ..... '""'~'~u '~q"~O S ,10 ~ -5,22 · 16 W -5.65 · 02 10.51 S 1.i1 E -6.~0 · 21 10.74 S 1.28 E 2800 2799.90 2750.90 2 12 29130 2899.85 2850.85 1 29 30 O'd .................... 2'9"99'¥7'8--- ....... :-"29'5'0T'?'~'~' ........ 7'~=':--T'""~'''-: ......... 3~T;' ·. S 17.50 W S 27.60 E 1.58 13.40 S 3.,36 E -6.7q 1.57 16.39 S 3.39 E -8.78 ooo 220~ 2199.95 2150,95 0 7 N 21.60 E .07 1.0,3~ S 2.76 E -5.08 2300 2299.95 2250,95 0 12 N ilO. 9 E ,10 10,09 S 2.92 E -~.~O" '2-4"c' ................... 5 · ' . ,. 6 ~ 72,50 E.: 2 O0 2~99~95. 2450 95 O o ..: · '; '09.' :" .. '.'. 9'.~;9" S'::.. :'.. ::'3,~G: g.: ::.".'.:: 2600 ............................. 27'00 .................... ,ATL/~NTI C RICHFIELD PR UDHOE BAY ALASKA COMPANY ANCHORAGE~ ALASKA C-O-Mp-U i At I o k"' 1]A i[ OCTOBER 29, 1979 [3ATE OF SURVEY OCTOBER ~OSS GYROSCOPIC SUR'VE¥ dOB NUMBER BOSS-16465 KELLY BUSHING ELEV. = 49. OD FT. TRUE --~-~-E'~ ~u R ~ D VERTICAL PEPTH DEPTH SUB-SEA VERTICAL DEPTH DEG ?,IN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST' SECTION 3100 3200 ( :5300 ...... ' ~-'4'0 0 3500 3600 3700 ~00 ~900 3099.39 3050,39 · 3198.22 $1~9.22 3295.83 ,:3246,83 .. 3q86.39 ,5437.39 3579.16 3530..16 3670,6 3760,82 ,38q9.76 ':' ~8,00.'.76 qO00 3937.61 3888.61 4100 4024.06 3975,06 10 53 N ~1,20 E A.,51 2,~9 N ~' 21,7~'E.:: :' ' 17'53 . : . ! 4 13 N" 49 · 9 .E ':i:'..::./: .:..~.... 3,74 · ..::.:::'.::;:': ?'6.'~i:::i!/N'r::Li":.': 25:~.'.: : ::~:~..'39 20 ~3 N ~q.29 E 3.06 60.13 N 80.07 E 99.51 23 8 N 38,q0 E 3,26 88"20 N 104.6~ E 1~6.64 29 9 N :~9-'-79 E 9 N 39.79 E 2.00 4200 ,~ 08.'~ 4059.9~ 4~00 ~275,39 4500 4357,86 ~ 308,.86:::. . 4700 ~521,61 4472-61 flSO0 ~603.09 455~.09 32 40 N ~0,59 E 1.58 ]5 19 N 40.50 E .39 35 32 N 41,29 E .51 26:3.71 N 248.99 E :362,06 304.09 N 283.12 E ~14,59 518,67 N 466,44 E 695.17 562.48 N 504'.q0 E 752.84 5000 5100 520O 5300 5400 5500 56O0 5700 5&'O0 5900 6000 6100 4766.14 4847.Z8 4798,38:; : 4928.53 4879,53 5009.18 4960.18 5089..20 5040.20 5168.65. :':!'511 5247.47 5,.525,32 5276'32 5402.08 5478.28 5554,19 5629,97 , , 5353.08 5429.28 5505.19 36 43 36 59 40 36 N qf,) 36 N N 41.79 E N 42.59 E 45.50 E 44.90 E 1.05 .55 .55 780,01 N 698.70 E 104:3,43 82q.qq N 738.99 E 1 103,22 1051.56 N 955,51 E 14,16.57 109'8.22 N 1000,89 [ 1~81.59 ~.TL~NTI C ~ICHFIELD COMPANY SPERRY-SUN WELL SURVEYING COMPANY· .'~,." ' ,:/" ..... " · ............ P-A'~Ei" 3"i:" · · . /~NCHORAGE,m ALASKA ···'DATE 'O'F.$URVEY OCTOBER '25,~' 1979' UG PR UD HO E bAY TRUE SUB-SEA I,~FA SURE D DEPTH VERTICAL VERTICAL DEPTH DEPTH INC D 6200 6300 5706,75 5657:*:75 578A.31 57~5'~1 50 70 5936.57 5887.57 6011.03 5962.05 6084.04 6055.0A 6800 6400 7000 6156,'02 &22 ~ ' 50 100 2O0 500 7400' 7500 7600 7760 7806 6385.51 6336.31 6464.84 6~15.84 65~zt.64 6495.64 ,. 67 06,26 6871.65 6822.65 6955.5~ 6906,5~ 7900 7040.11 6991.11 ,, , ,, ~300 7388,33 7339,33 8~00 7~78,50 7~29.50 8500 7570.58 7521,58 COMPUTATION DATE BOSS GYROSCOPIC SURVEY OCTOBER 29~ 1.979 dOB NUMBER BOSS-1GAG5 KELLY BUSHING FLEV. : ~+9.00 FT. : ' ~' ' : "' ..... "'; ':".." :.'-. , .! ' .... ., i.- .. COURSE .' couRSE LINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL EG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 38 .~6 N:: 50;9'0 "£:::": '. i '.?' o · E:' .... 9 ~1 11 :'i~ 51;~0 'E ;'?0 i~O"A;~ .....N""' ...... ~248;~6 '~ ~:'i'~'~"~'~ i'11'1 42 33 ; N 51.40 E 1.37 1345,84 N 1300.46 E' 1869.43 43 38 N 51,20 E 1,09 1588,56 N 1353,79 E 1957.54 .'57 29 'N 49,40 E ,89 1555, N ~7 9 N 48,90 E ,45 1595,38 N 1602,09 E 2260..09 36 57 N 48,59 E ,22. 1635.11 N 1647.40 E 2320.31 ~ 4,.. ! 0 32 35 N 47,59 E ,83 1825,66 N 1858.86 E 2.604,89 31 53 + N ~8.29 E ,78 18.61.,39 N 1898.~7 E 2658,23 27 q N A9,79 E 1,17 1991,~.1 N '20q5,86 285~,6 2~ 8 N 51,~0 E ~,02 2018,86 N 2079.23 E 2897.78 21 42 N 52,20 E 2.A5 20A2,95 N 2109,83 E 2956,57 8900 7948.60 7899.60 9000 80~3.21 7994.21 9100 8137.53 8088.53 18 31 54.9 E N . 19 15 N 55.79 E ,81. 2159.02 N 22A1.27 E 19 33 N 54.20 E ,34 2.158.55 N 2268.15 E 3098.12 3131.07 '^TLAF.;TIC RICHFIELD CGF~PANY SPERRY-SUN ~,JELL SUPVEYING C'OMPA~Y ~N C.P:OF. A GE,~ ALASKA PAGE 4 DATE OF SURVEY OCTOBER 25~ pr UDI.-CE BAY AL. ASHA COPPUTATION DATE OCTOBER 31~ 1979 EOSS GYROSCOPIC SURVEY ,JOB NUMBER BOSS-16465 KELLY BUSHIHG ELEV. : 49.00 FT. TRUE SUB'SEA COURSE P E A % t'"FJ, E. D VERTICAL DFPT h DE P Tti VERTICAL INCLINATION', DEPTH DE6 FIN _ COURSE DOG-LEG £IRFCTION SE:VERITY DEGREES DEG/! O0 TOT_AL_ _: ... hE CTAkGULAR COOR DI K,'ATE S VERTICAL NGRTH/SOUTH EAST/~EST SECTION 8277.50 19 0 N 52.5~ E · 2..t97,,Se'N 2528.'78 E "3,196';]0 9460 6421.09 c'50O g515.87 8372.09 18 5'~ ,, ~ 8466,8,7 18 17 N 52.7'0 E .15 2217,23..iN 2346.56 E ~228.~.8: .N 52. 0 E .61 '2236,.701' N: 2~71.79. £ '.. 3260,89":"" 850 5.63 85A6.6 3 18 17 N 52. 6, E 0,00 2252.9fl N 2392.58 E ~2fl6.36 I-.~ORIZONTAL DISPLACEMENT = THf CALCULATION PROCEDURES . ARE 3286.36 FEET AT NORTH,~ 46 OEO. 43 MIN. EAST AT MD = 95P, zt .." ..:: · ':' ' . . ."":~=~ · :." .:.'.~':':'i:::.~.:'.:';:"':'<..i":'"::: :."~::' i :'::"'i! :.":'S"::.:';:'" .,":' :":"!:"'"!.'~'.' '="::::"~ .:':"~ 'i,S~.-.OF: TH. REar,., ~ ,.,. O ME. NS!ONAL BASED THE` ON :US OF' CURVATURE. ME:THOD R I CHF I ELD COMPANY SPERPY-SUN WELL SURVEYING COMPANY ANCHORAGE~ ALASKA gATE:OF SURVEY, OCTOBER PAGE'"'5"- 1979 WIS 1 PR LID~-;OE fiL.A. SKA [.",AY COMPUTAT IOl,. DATE OCTOBER 31~ 1979 dOB NUMBER 60SS-1~,465 KELLY BUSHING ELEV. = 49.00 FT. INTERPOLATED VALLES FOR E · . VEN~ 1 O'O0:. ::F E E'T:...'O.F..~'MEA SURED P, .F. ~ SI~RfD DEPTP- 3000 400D ,.,i 6000 ?OGO ~?000 900O TRUE VERTICAL DEPTH O.O0 .97 .95 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH N(DRTHISOUTH'. EA~'T/I'IEST' ".i:"'D.!FF ERE NC'E?':'i::~.i:'!".:::,:'i:i':::~OR RE:CT ION ::::' ": ':'.: ... ' .... 950.97 7-51 S -10 W .03 , -03 1950.95 10.65 S 2.20 E .05 .01 2950-78 15.6N S 6.'46 E 38'88,61 471'7.1 ~t '5! 6257.~2 7076.57 7994.21 .61' .19 999 1999 2999 3937 4766 5559 6306 7125 .42 1515.94 N 1509.40 E 693.58 247.77 .57 1896.03 N 1937.19 E 87/~.~3 180.85 · 21 2159.02 N 22A1.27 E 956.79 82.36 T H 0584 8595 E CALCULATIO A'~LSNII C WC, I -4 FRUDHCE A t../~ ~ !',' A H ~__~HF I .Ek C. COiF'ANY.; ,, E: A Y SPERRY -SUN NELL SURVEYING cOMPANY' ',' "".' "' PAGE . · : b.ATE.: .OF.: SU~..VE .Y.'. 0 CT Ob.':'~!~ .2 §.,':. 1979 .. ANC'HORAGE ~ ALACKA ~.,~. .. COK, PUTATION DATE OCTOBER 51, 1979 dOB NUMBER BOSS-16465 KELLY BUSHING ELEV, ,. INTERPOLATEQ....VAI U£S. FOR. EVEN 1 D'O.' F'Fr'T: OF :SUR*Si:i;~"'FiE'PTH::i.i:::::i;i.i:IL. >,i.'......'.:: = 49,00 FT. MF'ASt~RED DEPTH 49 149 249 TRIJE VE RT IC SUB-SEA TOTAL AL .VERTICAL _ RECTANGULA.R_ DEP'IH ' DEPTH'· :,:. ';: 49,00 0,00 149.00 lO0.O0 2q9,00 200,09 COORDI.N ATES MD-T~ NCRTH/SOUTH EAST/WE'sT ":.. DI FF£'REN -.:0,00, ' :'<:"::..::i'..:. O0 .03 S ,OD E ,[JO · 59 S · 08 E o00 1.10 S .1~ E ~49 549 649 749 s" s~: ".:. is o o'::~'o.i~ :.:.i..'.. :::'.:':i~.': :':::.::, :?'f: ~' ~'::::':~::i::.:i:i~!:~:':.i:i?: :::i:.:':i:i.:i:?~':O'.:i'.~i:i:!ii':??.!!i!!?iii~!ii:il!::i;i :::::::::::::::::::::::::::::::;.'i.::.:i:.i..'::~'~/: ~'!'~i!!:i L;<.! '!:<?ii:?ii :i ~.~.oo Goo.oo ~.~ $ .o~ F .O~ .0~ 74.9.00 700.00 5.66 S .0~ W .,03 .00 849 84.9,00 800,00 6.50 S ~ ,05 E ,05 ,00 :'!:,!~,': ~-::.,::.:,~:i:: -':'T6-" :== :::::::':~::~"' .... . , ........ ....: ....... ... 9.. · 00 ". :" 00 :,. ~ O'" .. :..:'. ? ,: 1, 8 ...G..6.L: ';;~.:.;.:.:.~:.?.~:.~,~?'.:.:,~:~:~.?.~:';':.:'.:...:c?'.?:.'::~'.:.'.. ~ 0 O..:.:~..:~:' ':.'?.:':' ~ 049 ' 1049 .. 0'0 : '1 O 00:,:'~ O S...:< ';: .<:'?: ~.::::..: ;~:::: '::": ~:";::: :O':.~.::.:::: L.~;:::;???~; ;.::~'. :. 'OD :~.:"..~.:~.: '. : :::.'~ ~:: ". · · ':9 ' "' ': ." ?;:::; : ": "'....:' ,': .',:,',~: 11 ~ ~ · 11 ~. ~ 00 100:..0 0..... 8 ~ 32.. 0.0.....::......:.~...:...::....:?..:,.... :..:..~..,.:...:.:..:.~:..~..::,:.~..::~.,..:..:...:....~ :.::::....:,...:...:.:..:.:::.....:....::........: 1249 1249.00 1200.00 1,~49 1'~ 49. 00,_, 1300.00 1449 1440..00 1400.00 ( 1509 1649 .... ,. ............ ~-..Z.,,~A-...1749'-" I 9.06 S .1~ E .04 .00 9.61 S .43 E .Oq .00 9.92 S .71 E .04 .00 'ATLA,~,iTIC ~ICHFIELD COMPANY WF-, I-~ NELL SURVEYING COMP ANY ANCHORAGE, ALASKA · £OMPUTATI'ON DATF DA TEi.,~OF SURVEY .. ·PAGE OCTOBER 25, 1979 pc, L!['., HC., E [) AY ALASK$ OCTOBER 31, 1979 dOB NUMBER BOSS-16465 KELLY BUSIIING ELEV. = 49.00 FT. II~JTERPO LATE D VALUES FOR .E VEN 1 OD FEET 'OF~,:SUB','rSEA DEP.TH~;'.'. ~?,. TRUE SU D'tEA SI~RE D VERTICAL VER DEPT 14 DEPTH D 1649 1849,00' 180 B-SE TICA 1949 1949.00 190 2049 2049,00 200 2149 2149.00 210 EPTH 2249 2249,00 220 2349 2349.00 238 2449 2449,00 2~0 0., O0 0.00 0.00 {3.00 0.00 0.00 0 · O0 A T L RECTANGULA - I",,t O R T H/S OU'T 10.67 10.63 lO.A5 -'io .~ 9.97 9'.96 OTAL COORDINATES MD-TVD VERTICAL .EAST/WEST DIFFERENCE . ':i..::ii.i ~i:':?C 'O Ri R E C TT I O'N " ..... , -:o q :.: o o.::i,.!.i:):::, :':.':,:,.~i?:" , os'"'":"' ...... '.".'.:".-'.' ..... ': '" ',"o':O' ..... ,05 ,00 · 05 ,OD 05 78.4.5 N 96 I11.97 N 3150 31 49.00 3100.00 25251 3249.00 3200. O0 3355 534 9.00 33 C) O.O 0 3567 3549,00 3500.00 3676 3649.0'0 3600. O0 2549 2549.00 2500.00 26:,49 2'649.00 2600.00 2749 27~9.00 2700.00 '~.i~-'~'~; .......... ~'~4T'~':"~"~-~': ...... ~'~,'o"o. 2949 2949,0'0 2900.00 3049 30~9.00 3000,00 16.75 'z r~5 10.13 27.40 10.03 1{3.35 11 16.2fl E 1.LIS 29.05 E 2.87 1,.81 47.89 E 6.10 3.23 S 3.27 E ,05 .00 S 3.78 E · 05 .00 S 3.88 E .06 .01 '~TLA r;TI C PP, UDHO E ALA~F',a RICHFIELD COI,IPANY SPERRy-SUN ~ELL SURVE'¥ING ANCHORAGE'! ALASKA CONPUTATION DATE OCTOBER 31, 1979 COMP ...... PAGE '8 . · ~.A. TE. OF i..'.'"$uRvEy .... 0 .CTO..B.E.R' 2 5~.'.19 dOB NUMBER BOSS-16465 KELLY BUSHING ELEV. = 49.00 FT. .. I NIERPOLA:'TFD V'A L IJE..'S F GR E V ENi:.I'01~ DEP .... '¥ ' TH :<'::'.' ~ :/':: .... "':. rqF/~ ?URED DEPTH 37~6 TRt]E SUB-SEA VERTICAL VERTICAL D E P T H D EP .T H . . 374.~.0D ;;'' STO0..~.O' 3P~99 3~49.00 /~913 5949.00 4129 4049.00 3800,00 3900,00 4000,00 TOTAL RECTANGULAR COORDI, NATES MD-TVp V~RTICAL N C R T H l S 0 O T H. :' .EAS T/W E'S'T':'i 'i D I F'FE REN ' :'iil;'i!i;;~:~ 1~ REC Tio . ~. :~.':ii: ':::': ::.:':::: ~,:'s':~:;.: ~::'::.:'~:::'.i.:..' ". ~,*:"; 187.98 ~J 186,16 E 51~.14 12,35 230.00 N 220.90 E 64,04 13.91 275.50 N 258,64 E ~0.15 16,10 ~ ~ ~ ~ :. ~ ~ g ,o ;:..':~ ~'~:..:'::~, :: ~:,':::::::::::::::::::::::::::::: ~S',":: :::::::::::::::::::::::::::: ~ ~ ~ ~ ': ~':;' o 0 ::, :::'::: ~ ':' :'--: ~ :7::.;::: ::::::::::::::::::::::::::: ,~ : ?.,::::: :::::::::::::: ::::::::::::..'.: :: ::::: :~::::::::::::: 4611 4449,00 4400,0D 479.79 h 433,24 E 162,20 22.01 4733 4549.00 4500.00 533.42 N 479, D5 E 184.57 22.37 4~56 A649.00 4600,00 587,09 N 526,00 E 207,35 22.82 , ~ 9 7 ~ 7 ~: o:, % o ','::, ~::9~::::">:'::,: ~'O':'::~:':S;~::~::::::::::::::::::::::::::::~:::::':,::::::? ::~: :::: :~:: : ~ ~ ,, 4 ~ 49, o ~:D::'D::::',: 6:::~" :", :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::: ::::::::::::::::::: :::::::::::::::::: :::::::::::::::::::::: ...................... ::.ii,.-2: ._ _ ..... . . ,.,.,..., ..,.,.,.. ....... ,.,........... .......... ...... ,,,,,.,. ,,..,, 5349 5049.00 5475 5149.60 5;601 5249.00 5730 5861 5000.00 802.14 N 718.54 E, 300.69 5100.00 857.90 N 769.79 E 326.13 5200,09 915.q~ N 822,~4 E 352,95 24.46 25,44 26.82 ~TL~LTIC !;I CHF IEL[; COMPANY SPERRY-SUN 'bELL SURVEY'ING "COMPANY ANCP, ORAGE, ALASKA.... DATE OF SURVEY OCTOBER 25, PAGE 19.79 .. WGI-A PR lJ,F', ~,(} E ALASKA kAY CONFUTATION DATE OCTOBER 31, 1979 dOB NUMBER BOSS-1GAG5 KELLY BUSHING ELEV. FT. INTERPOLATED VALtES FOR TRIJE SUB-SEA PF~gURED VERTICAL VERTICAL EVEN · 1. OD FEET-oF." StJB-SEA' D£PTH'..:i~.i~.· , TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEF'TM DEPTH DEPTH ......... ( 6i2b 5649.00 5~00.00 ~-254 5749.00 5700.00 ~,~H~ 58~9.00 5Hoo.oo ~.a,' i6 5,:~,,9. oo 59oo.oo 6651 6~A9,00 G'O00,0'0 ~,790 61.~9,00 GlOO,Og 6925 b249,00' 6200-'00 7054 6349.60 6300.00 7180 6449.00 6400.00 NCRTH/SOUTH 1205. O1 N 1257.20 N 1.511,01 N '" EAST/WEST DIFFERENCE " :":':.%:::CORRECT ION "' :" .:.:. ~::. ~. o ~ ~,~ o :::E.: ~ ~ ~ .'-~: ::ii: ~'~ .~ :..-.., .: 1124.38 E 505.27 29.09 1189, 12 E 535,33 30.06 1256.7R E 567.52 32.19 148 '.7.9: :.N .1 ~ 7 Z':: 676 o72. 1.537,57 N 1535,03 E 705,20 28,~8 1587.49 N 1593. 05 E. 731.13 25.93 7505 65A9.00 6500.00 ......................... ?'gD"§- ............. g~"4~-Tb-o~-: ~'" 6 G o o. o o 7552 67A9.00 6700.00 7672 6~49.00 6800,00 7792 694r~ · O0 6900.00 1637.28 N 1649.86 E 1686, 1733.06 N 1757,:99 E 1778.62 N 756,A'5 25.32 7"~10 7049.00 7000.00 ~027 7149.00 7100.00 / Hlq2 7249.00 7200.00 P, 255 7349,00 7300,0{3 F', 36 7 7449.00 74,00.00 1822. }~4 N 1 8 1P. 65.O8 N 1902.61 E P, 61.~H 18.23 1905.32 N 1947, q6 E 87~.23 16,76 1978.39 N 2030.~7 E 966.8 1 3 2010.36 N 206.8,70':'E:..~,,.:~.:., .' 91.8.5~ ..,' . . SPERRY-SUN 6iELL SURV£¥'ING COPPAK'.Y ANCHORAGE~ ALASKA · _'~.__I..L.f_._~_J.T~_!._C__._L~.I CHF IEL_D CO~'.'PANY DATE' OF SURVEY OCTOB, ER eS, PAGE' 10 1979 6!C-I-A CO'MPUTATION DATE PRUF'HCF [DAY OCTOBER 31~ 1979 ALAFKA dOB NUMBER BOSS-16465 KELLY BUSHING ELEV. : 4~.OO vat L'ES .F~R FVFN 1DB FE~T OF SUB-SF'A"'i_'~EPTH. ' "' TkUE SUB-SEA ...... ~_.,L[A.~URED VERTICAL..... VERTjCA~... R_E DEPTH DEPTH DEPTH NC · . ......... ( __~4 76 7549.00 ' 7.500"00 ~58 3 76 86,89 77 8795 78 P. 90O 79 9 O 06 P, '0 ~'~218 q'z23 49,00 7600,00 49.00 7700,00 49.00 7800,00 69.00 7900-00 49.00 '8000',00 &s.__~,Q '~100" 49.00 8200,00 H3qg.oo 8300,00 TOTAL ~I AN.G:I.JkA R COORDINATE~ MD-TVD :. ..... VERTICAL RTH/SOUTH :' EAST/WEST: DI'FFER£NcE :..:.:.coR:RECT"i'o"N ...... 2 o 37,6 9..:.N. 2 ! 0.3' 0 927.',:7.,'~: ': "~: ~)::m~:.'~ 2061,43 .9 2133,55 E 9~5,00 7,22 2082,~+2 N 21.61,22 E 940,87 5,88 2101,2 L' 2 86 E 9A6,D5 5 8 2120,,23 N 2140.22'N .' ".:. 22~2,:~ 21 2181.46 N 2299,51 E ~69,b~ 5,87 2202.24 ~J 2326.93 E 97q.80 5.75 9425 R449.DO RqO0,O.O... 2~23,01 N 2354,15 E ...................... ~.,~, ............. ~- '= ....... -'~',~~..,.. ~ . ,' '~..-.--.- .-:..,,- -,:.,. -,,.- , ...... ~ .. -......,.-~.-,'..-,',...,.-, ,:....~.'..-..:,.:.-,., TUF CALCULATION PRCCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT ND (FRO~~ RADIUS OF CURVATURE) POINTS 'ATLA ~,!T I C R I CHF IELD C 0 t~P A NY SPERRY-SUN WELL SURV EYING'COMPANY ANCHORAGE· ALASKA , . DATE.:OF SURVEY OCTOBER PAGET 25~ 1979 PP ALASKA hAY CO~PUTAT ION DATE OCTOBER 31· 197.9 ,JOB NUMBER BOSS-164&5 KELLY BUSHING E. LEV. : qgoO0 FT. INTERRO~LA TED VALLES .FOR SPECIAL .SURVEY:: TRUE VERTICAL SUB- VERTI DEP SEA CAL TH 8490,24 8~ql,2~ 2231,48 N 2.365,11 E BASE SEDIMENT BE15,H7 8466,87 2236,70 N 2.371,7~ E SURVEY DEPTH 8595,63 85A, G,G3 2252,9~ N 2392,58 E T,D, PLUG BACK x~ November 7, 1979 Reference' Fmciosed are Cased Ilole Logs for the following ARCO we'lls' ~S~-~_-_ 1 10/6/79 CNI, Rrm 1 5" -:~ ' "~' 10/16/79 CNL Run 1 5" ~5 9/16/79 CNL Run 1 S'" ~Please sign and return the attached copy as receipt of data, K. J. Sahlstrom North Engineering TP&NS).iITTAL # 459 I}'IS'I'I~,J Not' t i~ .Geology TL,-j I l.i~q~ blobJ 1 En~. ~!anager Gott)- Geolog>' State of Alaska ~p, chor~cj '!a~ka 99~'10 Te.l,:.phon~, ~07 277 563'7 November 6, 1979 Reference~ Enclosed are Directional Surveys for the following AP. OOwells: ~ 10/25/79 Gyroscopic Sperry-Sun . :D~~-4~_ 10/26/79_ Gyroscopic SperrY--Sum Please sign and return' the attached copy as receipt of data, K.. J~ Sahlstrom North Engineering TRANSMITTAL # 457 ])ISTRI~[fl'IOX North Geology Drilling Eng. ' ' ~mnager R&D geo]og)' Scare o.[ Alaska ~J(XOII Mobil Getty Sohio 5larathoa Pifillips Chevron Post O1:',"o ..~;¥ T~l~k. hon :. ~ .... November 6, 1979 Reference: Enclosed. are Open Hole Logs for the following ARCO wells: . :': 5/29/79 BHCS Run 1 2" & 5" ~ 10/16/79 CNL-.-FDC Run 1 5"' ~' FDC/GG Run 1 b" " " DIL Rrm 1 2" & 5" '"' " BHCS Run 1 2" & S" WG! # 4 10/16/79 CPL Run 1 5" E/~lease sign and return the attached copy as receipt of K, J, Sahlstrom North -Engineering TRA&~S}.!ITTAL # 455 DISTt{IB{[I'IOX Non cn (;eo]o~,x- ~- l~xxon DrJ. lling ~.Iobi1_ Eng. ~d~mage r Gott}: R & i~ Sohio Oeo!ogy alaratlmn State off Alaska Ph~ll~l~S D & bi Chevron T.'-:l-~.pho~;-? ?37 277 5:_-'.3F October 26, 1979 Reference' ~ncloSed are Cased tlole Logs for the following wells' D,S. 14~8 9/26/79 Differential Temperature. Run 1 5" '~. "' Fluid DenSity Run 1 5" " " Sonan Run 1 5" ~..a~--~ 9/24/79 Acoustic CBL-\~L Run 1 ~2~-~/~~-'~'! --~sign 10/13/79 Gamma Ray Collar Run 1 5" ,,~ Please and return the attached copy as receipt of data. K. J.. Sahlstrom North Engineering T~&,N~IITFAL ~ 437 post O~ica : 380 Anchorage, A!a:ka 9~510 October 30, 1979 Reference' Fmcl°sed is a Directional Survey for the following ARCO well' /~i # 4 10/18/79 Hagnetic ,~altishot SDC Please sign and return the attached copy as receipt of data. K. J.. Smh!strom N.r ch Fmgineering T_.K;~NSkrlITAL # 440 D)r_ S T i..'_-[ g~. ~i' ] ON N'Or th r.'~.o", ,-,, ~-,. Drill Geology State o:[ ] _'>'(. XO 7t '[Or) i..l. [;et ty ,_ 0~ 'LO :;".!a r a'tl ton Phillil)S Chevron ARCO Oil and Ga.~"-%mpany North Alask,_ Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 24, 1979 ; I 4'ENG I OEOt/ ~ I STAT TEC-- ~ CONFER: 'FI[F: Mr. Hoyle Hami 1 ton State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Core Summary, WGI #4 Dear Mr. Hamilton: Enclosed please find the Core Summary for WGI-4, submitted as Item No. 36 on Form P-7 for the above well. Very truly yours, Sr. Geological Associate RWC: GSL: kdm Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany CORE SUMMARY WGI #4 Sec. ll-TllN-R14E ARCo Oil & Gas Co. Core No. Drilled 8880'-8920' 8920'-8940' Recovery Ft/% 22.5'/56% 2'/10% Lithology Shale, conglomerate Shale, conglomerate Shows Trace Fluorescence, Possible Gas OCT 2 -~ I[~Zg Alaska Oii ,~ · Arlcti(,,~'agb '~ .... '~ ARCO Oil and Gasx,.~-ompany North Alas[ ';istrict Post Oflice L, OX 36,0 Anchorage, Alaska 99510 Telephone 907 277 5637 October 12, 1979- Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- DS 12-4, Permit No. Permit No. Permit No 79-48 79-47 79-50 DS 14-6, Permit No. 78-65 DS 14-8, Permit No. 78-67 Dear Si r' Enclosed please find'a Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, P.A. VanDusen District Drilling Engineer PAV:ms Enclosured ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ~6nn N61 10~04 REV. 3-1-70 SUBMIT 1N DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20386 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~] GAS[~ Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 WGI //4 (33-1-11-14) 4. LOCATION OF WELL 611'S & l134'W of NE cr Sec ll, TllN, R14E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi el d-Prudhoe Oil 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 1, TllN, R14E, UM 12. PERMIT NO. 79-50 Pool 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for September, 1979. Spudded well @ 0700 hrs 9/29/79. Drld 17-½" hole to 2750'. Ran 13-3/8" 72# N-80 csg. w/shoe @ 2733'. Cmtd w/4000 sx Arcticset II cmt. Installed and tstd pkoff. Did top job w/240 sx cmt. Installed and tstd BOP to 5000 psi w/DOG representative on site. Drld cmt and FS + 10' new hole. Tstd form to 12.5 ppg mud wt. equiv. As of 9/30/79, drllg 12-¼" hole @ 3730'. 14.SIGNEDI hereby ~certi~3 that ~~ect ,~'/~' TITLE District Drilling Engr. DATE 10/12/79 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil and Gas Conservation Ccmmission Hcyle H. Hamilton/~~Jf~" October 3, 1979 Chainman of the Ccmmiss~' Lonnie C. Smith .~~/ Cum~ssioner M Harold R. Hawkins.~_.~. To Witness BOP Test Petrole%~a Inspector~?}[~' ~ ARO0's W~I No. 4 Sec. 1, TI/N, R14#, UM Permit No. 79-50 September 29, 1979 - ~hile I was in Prudhoe Bay on another test, a BOP test came up on WGI #4 for A~3D. The supervisor for ARCO was Jerry Carpenter. The contract pusher for Panker Rig 141 was Tcm Black. BOP test started at 9:30 ~4 and was finished at 11:00 PM. I filled out an AO&GCC Field Inspection Report, to be attached. In summary: I witnessed the test on blowout equipment for ARO0 on ~I No. ~. The tests were satisfactory with one exception, the four backup bottles of nitrogen too low. September 30, 1979 - Jerry Cazpenter, AROD Supervisor contacted me that N2 backup was filled to 2200 psig each. Alaska Oil and Gas Conservation Commission Field Inspection of Blc~out Prevention Equipment Inspector Operator Well %~/ ~ L~ation: ~r~n~ Con~~or Location, General p/~_/) ZP~gf~z~ Well. Sign O~ General'Housekeeping ~ Res~e pit ~ Rig ~ ~ ~ BOPE Stack ~-~ /~,J./,~ Annular Preventer } db O ~ Pipe Rams . Blind Rams Choke Line Valves N.C.R. Valve Kill Line Valves Check Valve Test Pres sure ,~ O ./'~, Date Representat~ive Permit # _/b / --,~ ~ Casing Set ACCUPFJLATOR SYSTF~ _~. ~R~' Full Charge Pressure .~ ~'~9 psig Pressure After Closure /(5-'d~ 200 psig Above Pred%arge Attainted: / Full Charge Pressure Attained:_ .. min~_ sec, ' re, in d sec N2 / 7D ~.~ ~ 73"'6~ Controls: Master psig FAIlurE Remo.'ta ~.~, Blinds s~,~itch cover Kelly amd Fleer Safety Valves Upper Kelly L~+,~r. Kelly Ball Type Inside BOP 0 /~ Test Pressure o/~ Test Pressu.ce ._ ~/~ ~-0 oil Test Pressure Test Pressure ~/W Test Pressure Distribution orig. '- AO&GCC CC - Field Operator/SuPervisor cc - Drilling D~pt. Su~.r:~rintendent /7/~, _ Test Results: Failures / Test Tbre '/ Repair or Replacement of failed equipmen~ to be made within days and Inspector/Commission office notified. Remarks: H'?. ~ D~ , ra /]_E ~/z~,9 ~_z~_~z_z .Choke Manifold No. Valves No. flanges Adj rustable Chokes / Hy~a~cal ly operah~ choke / ARCO Oil and Ga;~'~mpany Alaska RegL_ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 21, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: WGI #4, Permit No. 79-50 Dear Mr. Hamilton' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 1~-3-403 REV. 1.~ 10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such 13roposals.) WELLI----I OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, AK 99510 4. LOCATION OF WELL At surface 611'S & 1134'W of NE cr Sec 11, TllN, R14E, Ug 13..ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20386 6. LE~SE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #4 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. PERMIT NO. 79-50 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L---- FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) ~.~ PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent ¢letells, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes a 60' core in the Put River Sandstone which should be encountered at 7909' subsea or approximately 8700'MD. 16. I hereby certify that the foj~going is true and correct (This sDace for Stat~e-o~ice use) / CONDITIONS O~ APPROVAL, IF ANY; TITLE District Drillina Enaineer DATE. 8/17/7g T IT LE DATE /¥prov,---.d .".%~'i · - See Instructions On Reverse Side August 1, 1979 Re· Prudhoe Bay Unit WGI $4 Atlantic Richfield Company Permit No. 79-50 Sur. Loc.: 611'S & 1134'W of NE cr Sec 11, TllN, R14E, UM. Bottomhole Loc.: 1320'N & !320'E of SW cr Sec 1, TllN, R14E, UM. Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 ~r. VanDusen: Dear ~' Enclosed is the approved application for permit to drill the aP~ve referenced well. Well samples, core chips and a mud .log are not required. A direc- tional survey is required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Man~ rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in-these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations You may be contacted by the Habitat Coordinator's office, Department of Fish and Came. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, 'Article 7 and the regulations promulgat~] thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations ~u may be. contacte~ by a representative of the Department of Environmental Conservation. Mr. P. A. VanDusen Prudhoe BaY Unit WGI %4 -2- August 1, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying t~is office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment~before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, ~oy~ H. ~itton Chairm~ of BY O~D~R O7 TH~ Alaska Oil & Gas COnservation Commission Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. ~Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. 'ARCO Oil and Ga,~"--'"'npany Alaska Regi,.,,, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 24, 1979 Mr. Hoyle Hamilton State of Alaska A1 aska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' WGI #3 WGI #4 Dear Mr. Hamilton' Enclosed is our Application for Permit to Drill, the $100 filing fee, and the required survey plat for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401 ~ SUBMIT IN TRII-_ :rE REV. 1-1-?1 (Other instructions o,: reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL [~] DEEPEN [~] b. TYPE OF WELL API #50-029-20386 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. I.F INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #4 OIL % WELL[] ~L~'] Or.mR Gas Injection SINGLE MULTIPLE 2. NAME OF OPERATOR Kt,,EIVED Atlantic Richfield Company 3. ADDRESS OF OPERATOR JUL ~-~ 7 ig?g P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 611'S & 1134'N of At propo~d prod. zone 1320'~ a 1320' 13. DIST~CE IN ~L~ ~ DI~ON FROM ~A~T TO~ 0R ~ST OFFICE* 9 m~les ~octh of DeadhoCse, Rlaska 14. BOND INFORMATION: TYPE Statewi desure~ and/OrNo. 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to neaxest drig, unit, if any) Federal Insurar 3960? '- 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. ce Co. -#8011-38-40 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTH .9515'MD, 8590'TVD 10, F..jELDAND POOl., OR WI,KD. CA'l; vruonoe Bay field PrlJdhno Oil Pool [Jl~. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, TllN, R14E, UM 12. Amount $100,000 17. NO,ACRES ASSIGNED TO THIS WELL 80 ' 20. ' ROTARY OR CABLE TOOLS Rotary 1800' 21. ELEVATIONS (Show whether DF, RT, CR, etc.) . 22. APPROX. DATE WORK WILL START 49' RKB October 1, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 H-40 80 250 sx PF II to surface 17-1/2" 13-3/8" 72 MN-80 2700 Circ to surface--approx 5500 sx 12-1/4" 9-5/8" 47 8.0&95 8550 +1000' cmt column on first stage Dlus 300 SX on second stage 8-1/2" 7" 29 N-80 951~_ Approx 35_Q Sx .......... :..- ..... - Atlantic Richfield Corn)any proposes todir, ectionally drillPt~ls well to +g51b'MD [_+UbWU' to produce the Sadlerochit zone. Logs will be run across selected "intervals. A diverter system will be used on the 17½" hole (sketch attached). A'13-5/8" 5000 psi RSRRA BOP stack will be used thereafter to TD. The BOP equipment will be pressure tested each week and operationally tested each trip. A string'of 7" 29# N-80 tubing, packer & necessary provi- sions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby~2 that %~e~in~ ;?~a~;otx SIGNED 7/18/79 TITLE District Drlg. En.qr. Crhis space for State office use) SAMPLES AND CORE CHIPS REQIJIRED []ws ~ [] No CONDITIONS OF APPROVAL, IF ANY: [] YEs j~NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO.. 7 ~ '- ~"O APPROVAL DATE APPOVED BY ~~ -~-~¢--~ .~~ TITLE ¢/ _~_ ___ Z ____f..., ...... *See Instruction OnReverse~Z'cu-u"C~'Side BY ORDER OF_ .THE DATE o/'~ /-tn O/ .J-I I ~' SURFACE DiVERTER SYSTEH 1 . 20" Bradenhead 20" 2000 psi drillin~j spool 20" 2000 psi annular preventer 6" butterfly valves Protracted Section Line ,~ .... 1184 LAT LONG. WELL 13026' LAT. LONG. WELL LAT. LONG. 2 I WELL I] 12 LAT. LONG. AS-BUILT No. I 70° 19'42.634" ' 148 029' 58.597" No. 2 70° 19'4 1.476" 148°29' 57.861" No. 3 70° 19'40.321" 148029' 57. 133" No. 4 70° 19'39. 170" 148o29'56.399'' Y 5 972 002.90 X' 684 985.72 Y' 5 971 885.82 X 685 013.80 Y 5 971 769.08 X 685 041.62 Y 5971 652.66 Y 685 069.67 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THIS PLAT REPRESENTS AN. AS-BUILT SURVEY MADE BY ME OR UNDER MY SUPER- VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORIRI~GT. DATE SU R VIEF-~OR ~ RECEIVED ? Ig7g ~aska Oil & O:.:s i ;,,i~., ~dh.mSSlOn I J Chanqed title No. J REVISION /.%¢. J7/79 IGD I DATE I BY ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS-BUILT WEST INJECTION SITE- WELLS 1,2,3 ~4 LOCATED IN PROTRACTED SECTION I I, TIIN, R 14 E, U.M., ALASKA PREPARED BY HEWlTT V. LOUNSBURYSASSOC. 725 W. 6TH. AVE., ANCHORAGE, ALASKA DATE JUNE 1979 SCALE I"= 300' CHKD. BY GDD FLD BOOK · · CHECK LIST FOR NEW WELL PERMITS the it fe hed 1. Is perm e attac ......................................... 2. Is w~ll to be located in a defined pool ............................. Oo~pany Yes No Remarks Lease & Well No. P~'/ Item Approve (1) Fee .~~ 3. Is a registered survey plat attached ................................ /~ 4. Is ~ell located proper distance frcm property line .................. 5. Is well lOCated proper distance frcm other wells .................... 6. Is sufficient unde~icated acreage available in this pool 7 Is well to'be deviated 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait ....................... Does operator have a bond in force ....... ........................... Is a conservation order needed ...................................... [2. Is administrative approval needed ................................... Is conductor string provided ........................................ (2) Loc. ~,~ .... (3) Admin. ,K,~d,~' L6. L4. Is enough cement used to circulate on conductor and surface ......... F~7) L5. Will cement tie in surface and intermediate or prcduction strings ... ~ Will c~ment cover all known productive horizons ..................... ~ (4) Casg. ~¢~ 17. Will surface casing protect fresh water zones ....................... L8. Will all cash~g give adequate safety in collapse, tension and kurst.. ~fi'O ~9. Does BOPE have sufficient pressure rating - Test to. ~o psig .. ~ Approval Reccmmended: (5) BOPE ~;~ ~dditional Requirements: Geology: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi ,. No Special'effort has been made to chronologically organize this category of information. PAGE ARCO OIL & W,G.I, ~10,4 DATA EVERY GR 7550,00 0.,00 7550,50 0,00 GAS H LAC~5_527' PRUDHO_E BAY . NORTH. SLoPE,ALASI~ 1 SAMPLES: NEU 7551.00 29,51 7551.50 28.29 0,00 7552.00 .28.78' 7552.50 29.39 41,36 41,18 7553.50 32.20 40,48 7554.oo 3o.24. 4o'8.1 .~;y "...:. : ;.-~'.. -.,~;;~' ~ 7554..50 29.88 41.84 7555. oo ~i~~ 28.9o ~ ;~ 42.8~.i-~ ~. -~.! 7555,50 27,80 7556.50 22.07 ~5.BG 7557.50 21.83 7558.00 ~:~18.5~ :~45;~15...':;~; 7558.50 21.3~ 7559.50 27,32 ~2.~9 '75~o.5o" 2~. 7565.50 31,59 39,46 7566.50 55.61 38,54, 7567.50 38.17 7568.00:::' :37.56 7568.50 35.98 ! ~7569.001: 34.,88 ! 38.68 38.3~ 3 8 · 4 6 38.83 7569.50 31.83 7570.0.0,. 29.15 7570.50 27.93 7571.00 30.85 7571.50 3~.39 7572.00 3~.76 37.62 7572.50 34.63 38,17 7573.00 34,88 38.17 7574'00 34.02 -..39,35 757~.50 32.32 4.0.37 7575.00 52.32 4.1.4~ PAGE 2 ARCO O_IL ~ GAS H W,G_,I. NO,~.. PR_UDH_~_O_E BAY NORT DATA~RY I SA~IPLES GR NEU 7575,50 7576°00 3[,22 q'2.03 7577,00 50,57 40.85 7577,50 7578-00 26.10 40,70 7578,50 7579.00 28,29 ~O,~B 7579 , 50 7580.00 29.~9 59,~9 758~,00 36.22 ~0.~8 7582.00 35.~9 39.09' 7582: 758~.00 30.37 -37,5B 758q.00 27,~ 37~0 7585,00 50~57 ~0.0~ 75 .oo' ' 7591.00 759;~. O0 35.12 3~.02 :.::.-::7592-50: "".' :: :::::;::: 759,5. O0 38.05 54. ~,8 759:~':50 : ::;: .' 38'90 ::::::3:~;90: :: '...:!' ::::::::::::::::::::: ::; 7594.00 :58.17 35.1~, :7594 ° 50: 6'95:::.: 35~ 67:: .. ..:- : .":.' ::';::.:.::'-:.'..: ': :..:'?.:.:.:. ...,".. ~:..: ::. :: 7595.00 ;57.80 7595.50 7596.00 40.85 7596-.5o 7597.00 7597 °50 7598.00 38.29 33.95 7598.50 37.68 7599,00 3~.83 3~.83 7500°00 35.75 3q.. 72 7600,50 37,56 35,23 PAGE ARCO OiL& GAS HL~]~]52.7 14 _;$_, !. N 0 · ff P ~LLD H N R T: ' _L~~.~S K A . DATA EVERY 1 GR NEU 7601,00 : 58;:05':. J?' ;:~ 5 ~71 ?J-:. :~'...::.':'~/~?'.':". '-'~.-: :.;'::'::.:~3':-~'~.:'.~.:.': '. :: - ~: - :. :..;" -; :::~: ...'..' ::]:': : ~' ' 760~ .50 35,73 36,15 7602. oo: 3~" ~ j.: ::~: ~35' 97:.::". :. :'.':":FL:.-.:: ?...?:.:::..:~ ? .:::: :':;..'.: :. :: :;: ~:: 7602.50 3~.~3 36.30 ..... 760).50 33.90 36.08 760~.50 35.00 36,0~ ~76o5. oo 7605.50 37.07 35,05 760~.50 38,78 3~.~9 ~7607.00~ ~~ 38~[7..~.~:.'~j36'3 7607.50 39.63 36.69 7608.50 3~.2~ 37.~0 7609.50 31.7[ 38,R~ 7610.50 29.76 35 93 7616,50 ~0.12 36,0~ 7617,,50 37.20 35,B6 76 ]. 8 · 00~ ;~' 38, '29 :: !':~ 56,7 [1.': .:~ 7618,50 37,56 37,77 :76].9. O0 :i 35 · 85 i:".:.:.'; 3B ' 83'. :'....-.'.:.j. 7619,50 35°85 38.9q 7620.:00:: 7620,50 :76~1,00 7621.50 7622°00 7622.50 ~3.78 32.66 7623.00 7625.50 ~0.85 51,78 762q.50 3q,88 32,66 7625,00 33'ql 32.85 7625.50 32.80 33,~7 7~26.00 32.07 33.95 .::: PAGE 4 ARCO OIL & W,G,I. NO,4 DATA E_V_ERY GAS HLAC 552~ PRUDHOE...BAY NORTH SLOPE_tALAS~A ! SAMPLES GR 7626.50- 37,20 7627,00 37,44 7627,50 ' 37,07 . 7628.00 38,17 7628,50 - 37,$2 NEU · _.. 3 3. G 9 '--~ '"' ~~'~/~.: '.-..'~ 33,3G 32.85 .---'. '.-.'/"~?.:::::?~'~'.' ":'~<'-.~::.%.-~'- - - 32,85 · ._ - .... · .......'..:.':.:. · . 33,'1~' : .~..~':' '~:.~::. ~- -.-... - 7629.00 37,44 33,40 7629,50 ' ' 38.78 ' 34,02 '-"-'--":.".:- !?:: ~;='.'"'~{::~'i.:-'-~-'"" 7630,00 38.54 35.12 7630.50 '- 36 · 46- 35.6.~.-.]:..'!':.'..-?~::i~i.-:.'- ':-:- '"'-.-'~ -: -' 7631.00 40,00 35,97 7631.50- 7632.00 ~,5[ - 35,89 7633,00 ~1,71 35,56 7633 · 50 "' ~ 2 · 80 :-':-/'35,4: ~.'.'.'.:'~.:..:~.'-:.'--:'-:--- :' . 7634.00 ~1.46 35,64 7635.00 41.59 35,89 76~5.50 gl,3~ ~5,86~'~ --'- ..--~ - .. ' - ' 7~f. oo ~7. / ~.~ 8 · 50 ~ 2 · ~ - ?3 ~:.,~:~_5 ~ ~..~ ~-~2~. ~ ~/;~ ¢~:~2~ ~ "~%~ ~.?~. ~:.%:::- ?;~F .L~'::~--~, ~.*~- ¢~ ' ' - ' 76~2,00 37,56 36,19 7oq-3. O0 76'45'50 7644.00 7644.50 36.22 35. 35,85 36, 39.27 : :36' 7645.00 41.34 35, 7645.50 ~3.29 71 52 7646.00 41,10 34.02 7647,00 38.17 34.02 7648.00 43.29 35,12 7648.50 .q, 4.02 '. 35.49 7649.00 45.2~ 35.89 7649,50 43.66 35.32 Basic Information Tape The Basic Infor-mation Tape (BIT) is a binary, partially multiplexed tape containing up to 20 data curves. The data samples are represented as IBM, 32-bit floating point numbers. The tape consists of a 276 byte heading record followed by a series of data records whose length is defined in the heading record. The last data record is followed by two end-of-files. The tapes are 9 track, 800 bits per inch. Heading Record The heading record contains the information necessary to recover the curve data from the data records and some identification information. 1. The Epilog Computation Center (gCC) number is a unique number assigned at one of the Dresser Computer Centers. Any questions regarding the data should, if possible, include this number. 2. Company name - Well name. These are free format fields used to identify the well. 3. The number of curves (N) is designated as a 16 bit binary integer number. This number must be less than or equal to 20. It gives the number of curves of data that will be in the data records. 4. Curve names. Each curve is designated by a 4 character name. A list of Dresser Atlas standard names is given in the appendix. These names appear in the order in which the data appears in the data record. 5. The starting and ending depth gives the first depth for which there is data on the tape and the last depth respect- ~vely. ¥~en the starting depth is smaller than the ending depth the data is recorded downward. With field data, the ending depth may be smaller since the data is recorded from the bottom of the well upward. The ending depth may be given as 0 or 99999 when it is not known during record- ing; this occurs on BlT tapes recorded in the field. 6. Level Spacing (L). This field designates the depth increment between the data samples. The data samples are taken at regularly spaced depth increments. 7. Number of samples (F). This field gives the number of samples of each.curve recorded in each data' record. This number will be less than or equal to 125. DATA R£CORDS The samples in the data records are recorded as floating point members (IBM standard). This consists of a sign bit, 7 bit exponent and a 24 bit mantissa normalized to the nearest 4 bits. sign bit. mantissa The exponent is biased by 40~6. Thus, 41100000~6 represents the number 1.0. The data record consists o'f N F . 4.bytes of data where N is the number of curves and F is the number of samples o£ each curve. The first F samples in the record will be of curve 1, the next F samples will be of curve 2, etc. Each record will contain data for F .L feet of data, wh~re L is the level spacing. The current standard usage at Dresser data center is Level spacing ~" L = .5 feet Samples per record. = F = 125 Thus each record represents 62.5 feet of data. These numbers are given as an example only, however, since L and F may vary from tape to tape, and will certainly be different for BIT tapes recorded in the field. DRESSER COMPUTER SERVICES DIVISION DATE 10 - 6 - 7 7 FI LE HAME I FILE NAME 2 I I DENTI FI CATION I I / FI ELD t SUB FI ELD FILE DATA SPEClFICAT'IONS (Continued) FI ELD DESCRIPTION Epilog Computation Number Company Name EXH BIT 1 Page I of APPLI CAT I ON FILE NUMBER Well Name N~mher of C~rve.~ on Tape Filler POS TION _.6 Curve Name s 7 Tape starting depth 8 Tape ending depth -9 i Data level spacing 10,.. Depth column (=0) 11 12 13 Filler Number of samples per record of each Filler curve 258 259I 260 261/ 262 263 / 266, 267 / 276 INT FP ' I NO. OF DECIMALS OF BYTES 8O 8__O___ l BASIC INFORMATION TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Co. Well W.G.I. No. 4 Prudhoe Bay Field County, State North Slope, Alaska Date 11 - 26- 79 Curve Name (Abbre,~iation) Standard Curve Name Log Used Scale and Units GE Gamma Ray CNLOG 0- 100 AP I NF.U Neutron CNLOG 60- 0 Porosity : , 11 000©00 7 '7 '777'7'7777:~' ' '000000 7777717777 .1 ] 0000 () 0 '77 'Y 7777 '7:77 000000 '17 '7777' 77 '77 1111 O0 O0 77 O0 O0 '77 '1. i. 1 i O0 O0 7~7 O0 OO 7'7 i 1 O0 0000 7'7 0() 0000 7'7 'l I 00 0000 77 00 0 () 00 '77 1,1. 00 00 0 il) 77 00 00 r) 0 77 11 00 0,000 '7 '7 00 00 00 7 '7 ] 1. 0000 O0 77 0000 O0 77 ]. 1 0000 00 7 't 00 (.) 0 00 77 1. 1. 00 00 77 00 00 77 11 O0 O0 77 O0 O0 77 11111 I 000000 77 000000 17 1 .'11,. 11. I 0 O 000 () 77 000000 77 660666 000000 000000 222222 777777'7'777 bb6666 000000 000000 222'2122 77777"77777 68 00 00 0 0 00 22 22 7 '7 6~ O0 O0 O0 O0 22 .22 '7'7 (;,, ~b O0 0000 O0 0000 22 77 66 00 0000 00 0000 22 'I 7 6666 b 666 00 00 00 00 00 O 0 22 7 '7 66~66666 O0 O0 O0 O0 O0 O0 22 77 6~ 66. 0000 00 0000 O0 22 77 e, 6 6~ 0000 O0 0000 O0 22 77 66 (5~ O0 O0 O0 O0 22 77 66 t~ 6 00 00 00 00 22 77 66066a 0000()0 000000 2222222222 '77 66~6~6 000000 000000 2222222222 77 *,.%Ig, Rr['* b&t~..R [:.'CA{ [.10'707,6',)027.1 ,~t)6 `5HIP bgO. :310 DATE 06-t~/4X-.80 08:02:25 H [j iN! I l" {"l P S v,, S Is L.. ! 0 ~, 3 ~ d I.! L - '19. * 5 'I' A t-~ "C * 1,~.'f.'AR£, L.ib~,,K PCAi_, 1.10701,60027J dU[~, ,SHiF St:,(-,). 3!0 DA'I'E. O6-:',~AX-80 O8;02:25 FI(JNI'!'{!R Sv,;,'.% ~'LI0~.34 ,J{.JiJ-79. *STAP, T* 111111 ilII!] Ii i,i 11 1I I1 I1 II I1 i11II1 YY 31.0 DA'I'E; 0a-MAY-80 ()6-MAY-80 (.)8:01:37 08:02:25 8 C H,B iJ lq B E f~, g E; P, C 0 M P U T I 0'707,6002 D/aTE: 80/ 5/ T,A P E ~,'i ~.; A D g R P,.: i'll F P'.[l..F. NA~E: F'R F: 'q 1 l.,~ U 6 k,U i 1" .001 PE~SICAL I~E,C ORD ~ ilJg Ngl,,'lg; 102~ BY'ILS 1, FiN G'.i'H: C' EIk!P g n'~': ? t l.,l.~{): k AI'~GE,: CUIiN'J' ¥; 1'79 Bi'TBS RECORD g'[L, AN"r I C P ICH[",I EbD wGJ ~4 I 4E 11 N. AbASK~ 0 tC ! ..") I t.,D D i L 4. J L .u [.'~ 1 J., C & [) ~ N [-' R~ NC l., ].C .il, h hl C.Nb AT CNL I',~LC r~ 1_, NL Ci,~L ~bC i:.~ h C APl AFI Afi APl 1 N G/C~ GIC '~ C/C CPS C_PS US/[- 42 42 q2 42 6O 60 0 1 12 12 4-1 69. .t5 42 34 52 0 0 0 0 6 0 4 1 0 0 .3 0 1 C' I 0 2 2 0 '2 0 SIZL EXP PROC SAM REP ogPI' 0 -q 0 0 I 68 0 4 0 0 1 68 0 ~ 0 0 1 68 0 4 0 0 1 08 0 0 0 42 q 0 0 I bU 0 '3 0 0 1 bO 0 q 0 0 I 68 0 4 0 0 1 68 0 ~ 0 0 1 68 0 4 0 0 1 b8 0 q 0 0 I bO 0 '~ 0 0 1 68 0 4 0 0 I 68 0 S Pi 1 .[, T 0 0 0 31 32 0 9500. (; 00 92 (.> C'o 000 9 !, 00.000 9090.000 !; 900.000 ~ luO.O0u F. e:,25. O00 S P G R $ P GE 5P (.; p, 5 P GP }-' rt i.j r5 G F SP Gl-:' G VA L, t,i F., -. ::33, O :120.9 2.1 10 0. '2 5 o 31. 7 ,.5 '14 75 ' 63 '~ ::3 2 39 3 6 2 2:2 2 25 -11,4 39 2 40 :i. 07 2 10 3 171 159 -53 179 2 171 -.50 147 2 152 --17 2 .500 . '119 .203 .8 '4..'4. 75[') 9,38 ,299 .68g 75(,) .656 . '15 ,g .93 a .938 .75 0 .438 .573 . 250 .750 .50O .e25 .06 3 · 500 .39~ .9 () 0 .875 .g75 .750 o188 .20 ~ .250 1, J:.~,D CAI~I. N P, A T DT 1, b CALI D T 1 L D CAL I, ,D T I Lb C A 1., J bIR.AT D T I L [) Cgl, I N P A D T I 1.., CAL, I i~F',A T DT I. 1.~ [> (]AL., I m ~ A T O'T 1 L D CAI,,i DT l hi') CALI F, E A 1' I lJ t) CA/,I aRA']' I..)'1" I. L,D CALl [.) !' VA L t,I L 8 3 500 2'79 563 328 ~:'727 '2.510 9.3 '75 t .59q 8.563 2.,1.15 9.188 9 b 3. :156 8. 352 2, :t, 54 9 '2.375 376,. 000 8.289 1 . 6.35 88.56,:3 52.531 8. :352 2.1,31 · 96.1,88 8.563 9.1.il 2.797 95.188 2.777 9. 109 3.439 103. 000 5.125 9.977 3.271 9'4.O00 2.~49 10.344 3.441. 114.1~8 4.988 ~.664 4. (')08 53.375 1') R ,H 0 i'~ C N L N C N L i b M D R H O N C N L i ,b, :~, D R H 0 N C N b 11., M i, L ~q NCNb 1. L H D P, H U .N C N L 1 DN DPHU t'q C N b 1 L M D R Ir, u t\.,C h L [',i C m L; N C 1',~ i., V/4 2. ,0 74 0.01,6 2338°000 2.807 0.088 225 4. 000 2'2. 906 -0. 002 50.000 4 3.219 0.025 3286.0O0 125.188 ,-'0.0O6 4340. 000 41.656 0.007 3480.000 '1.953 0.010 2045.000 2.5O2 0.010 2690.000 934 007 193a..ooo 2.406 .1661.000 20oo.000 -U.574 1249.000 t4t,~ g M ON I.C I'~ :p H I F C N,b bL, SU N P H I FC, IU b 8 l,J L L 8 U NPHi FCNb LDSU NPH 1 L~''C Iq I., b b 8 U N PHI FC N b bbSLI NPHi FCNb bbSU .N P H i 1' C N L, L L 8 U r~PHI, i~'C Nb bbSU NPHI 5CNL bbSU NPH/. FCNL V AL UE 3.3'98 25.78:1 941.500 3.594 31.592 853.000 56.68d 20.508 1.443.001) 80.813 2 '1.38 '1 142'1 . 0,00 407. '750 :l, ,3.6 12 2434. 000 lbO."'150 23.1.93 1497.000 14.109 33.057 6'18.500 3.508 43.848 b85.000 7.559 32.861 598.500 4.15o 39.746 424.250 i.304 52.4~1. 28'1.500 P 1I_,t:'_~ 'f'PAILER 1024 [-, i A P ,~; T i-< A .l I. E',, ~< Ar1l �? A A FRANK H. MURKOWSKI, GOVERNOR I AILASK OIL AND GAS � 333 W. 7' AVENUE, SUITE 100 CONSERVATION COMA'IISSION �� ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU WGI-04 Sundry Number: 305-392 Dear Mr. Reem: 7q- iso t U,2 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. !1]"- -- "'-I- - DATED this I- of December, 2005 Encl.
