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180-046
Imag~roject.Well History File Coverage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ,~ ~ (~- ~ _~//~ Well History File Identifier Organizing Ido,,~) ~d REsC~,N [] Grayscale items: Poor Quality Originals: DIGITAL DAT/~ [] Diskettes, No. [] Other. No/Type NOTES: BEVERLY ROBIN Project Proofing VINCENT~ARIA WINDY ~'/Other DATE: 9-o OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY: BEVER~r'~VINCENT SHERYL MARIA WINDY Scanning Preparation Z~7 x 30 = ~ + BY: BEVERL~VINCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES NO IF NO IN STAGE 1, PAGE(S) DISCREP~WERE FOUND: , YES , NO BEVERLY ROBIN VINCENT SHERYL MARI~WIND~ BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION iS REQUIRED OI DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd UNSCANNED, OVERSI7EU MATERIALS AVAILABLE: 1 ~y ~.6 I+,ILE # S~~ ~~_ To request any/all of the aUove information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 -Tax (907) 276-7542 OF sA THE STATE Alaska Oil and Gas _ ALAS netCommission Witt GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFA gP Anchorage, Alaska 99501-3572 Y 21�� A. Main: 907.279.1433 Sa�tiC� �+ Fax: 907.276.7542 Irene T. Garcia F SSHE Manager ExxonMobil Oil Corporation PO Box 196601 tla Anchorage, AK 99519 OL Re: Point Thomson Unit, Alaska State C No. 1 Sundry Number: 313-603 Dear Ms. Garcia: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080. within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this Z day of December, 2013. Encl. • QA/ RECEIVED STATE OF ALASKA \44 ' NOV 1 ALASKA OIL AND GAS CONSERVATION COMMISSION I2f 2.0/ 3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑., • Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ After Casing❑ Other F"" 5-€4,C.....- Pf4 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: it 4 .15 Exxon Mobil Corporation Exploratory Q • Development ❑ 180-046 ' 3.Address: Stratigraphic LI Service ❑ 6.API Number: PO Box 196601,Anchorage,AK 99519-6601 50-089-20011 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No 0Alaska State C No 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28382 • Point Thomson Unit • 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): 13,761 • 13,243 ' 0 0 Many plugs,see schematic None Casing Length Size MD ND Burst Collapse Structural Conductor 784' 20" 813' 813' 1,530 520 Surface 3,964' 13-3/8" 3,993' 3,993' 5,380 2,670 Intermediate 11,090 9-5/8" 11,119' 10,737' 7,720/8,150 7,100/7,100 Production 10,646' 7" 13,146' 12,639' 12,460/13,700 10,760/13,010 Liner 909' 4-1/2" 13757' 13,239' 14,420 14,320 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 • Stratigraphic❑ Development] Service ❑ 14.Estimated Date for 15.Well Status after proposed work: August 1,2014 CommencingOperations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 • Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tom Juranek 713-656-4225 Email tom.a.juranek@exxonmobil.com Printed Name Irene T.Garcia Title SSHE Manager Signature `�-_• _ q04 Phone 907-564-3773 Date l t it S//7 -- COMMISSION USE ONLY d- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 13 -- 4 03 Plug Integrity 5( BOP Test ❑ Mechanical Integrity Test ❑ Locationc/ Clearancele� ZO1 1 n - Other: *r f�/'i-O� J-0C4-4�+... -' C.45; Gac.�T-• Of 4.4� ,j Gt'as,0 i �" P 0- A/i r it _ 100j phe-e d- 4-pj i w ,C ,— 26A44 Zb.t e (e) Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: 6 0 ti07.- RBDMS k4A 1 9 2014 Y APPROVED BY /2 ,---- Approved b : COMMISSIONER THE COMMISSION Date: x•343 AO t4*U 1'iLAL Form andForm 10-403(Revised 10/2012) Apprd IiilIaa I alon hs from the date of approval. Attachments in Duplicate ,V RECEIVED ExxonMobil Production Company P.O.Box 196601 NOV 1 g 2013 Anchorage,Alaska 99519-6601 907 561 5331 Telephone "!,®GCC EkonMobil November 15, 2013 Production R-2013-OUT-019 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage,Alaska 99501-3572 Re: Application for Sundry Approval Well Abandonment: Alaska State C-1 (PTD No. 180-046) Dear Commissioner Foerster, ExxonMobil hereby applies for Sundry Approval to perform plugging and abandonment work on the subject well. The work is described in more detail on the attached Summary Procedure. The general procedure objectives will be: 1. Excavate the wellhead, check pressures in the well casing and uncemented annulus to verify that there is no internal pressure. 2. Verify the integrity of the surface cement plug in the 9-5/8"casing. 3. Cut off the wellhead and all casing strings to at least 3' below the natural tundra level. 4. Remove arctic pack from the inner annulus and cement the inner annulus with permafrost cement to surface. 5. Top off the 9-5/8"casing and all annuli with cement. 6. Install a well identification marker plate and backfill the excavation with gravel. Attached please find the following documents supporting this Application: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams If you have any questions or require additional information, please contact me at (907) 564-3773 or Tom Juranek at 713-656-4225. Sincerely, 141)) .i3 1 41/ki ,,�� QQ L 04 } Gt,o✓ t,v Irene T. Garcia SSHE Manager Attachments: • Sundry Application Form 10-403 • Proposed Work Procedure including before and after wellbore diagrams 41ei .,POINT THOMSON . PRODUCTION ALASKA STATE C-1 WELL HISTORY AND ABANDONMENT PROCEDURE Affected Wells and API/APTD Numbers: Alaska State C-1 API# 50-089-20011 APTD#: 180-046 Background: The Alaska State C-1 well was drilled in 1980-81. The well was suspended on July 14, 1981. It is now planned to plug and abandon the well, which requires removal of near surface arctic pack and cutting the wellhead and casing to at least three feet below ground level consistent with AOGCC guidance and regulations. The 9-5/8" casing contains 10.2 ppg calcium chloride brine below the surface cement plug set from 0'-60'. Arctic pack (gelled diesel) is present above TOC in the 9-5/8"x 13-3/8"annulus at-2,925'. The current well schematic is attached to this procedure. The reservoir section of the well is effectively isolated; therefore no pressure at the wellhead is anticipated during wellhead removal and . permanent plugging activities and no pressure was found during a wellhead inspection in 2009. OBJECTIVE: Permanently remove wellhead, remove up to 200' of Arctic Pack from the 9-5/8" x 13-3/8" annulus, fill all casing strings to surface with cement, and install marker plate. Note: An exception is requested for the existing 60' surface cement plug inside the 9- 5/8" casing. The downhole plugs in this well were pressure tested and/or tagged during the original suspension procedure and no other downhole work is required. Removing the 60' surface cement plug from this well would be problematic in that a Coiled Tubing Unit would be required, and there are safety concerns, and possibly regulatory requirements, with operating a CTU due to the close proximity to the Point Thomson airstrip. This procedure is consistent with previous guidance provided by the AOGCC. G!r- : �e,-< Zo Awe_ t-L) The following well abandonment program is planned:' 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days before operations begin. 2. MI and prepare location. Record pressures on the 9-5/8" casing and annuli. Bleed off any found pressure. 3. Notify AOGCC of planned operations and confirm steps to be witnessed throughout operation. 4. Remove glycol mixture refrigerant from both annuli of the refrigerated/insulated conductor via compressed air or by vacuum. Pump returns from catch pan to waste tank. 5. Cut-off the 28"x 32"x 36" casing with a torch to allow for the future use of Wachs saw. 6. Remove wellhead cap with 2" ball valve and verify(tag)9-5/8" cement plug. ALASKA STATE C-1 Abandonment Procedure 5 POINT THOMSON . 14 PRODUCTION 7. Remove two FMC 3-1/8", 5k gate valves. Send gate valves and 2" ball valve to warehouse stock in Anchorage. 8. RU Wachs saw and cut off wellhead and casing at a minimum of 3' below tundra level. 9. RU false rotary. 10. Run 1"jointed pipe inside the 9-5/8" x 13-3/8" annulus to about 200' and wash out Arctic Pack with warm diesel. Take Arctic Pack/diesel returns to dedicated waste tank. Leave jointed pipe in hole for cement job to follow. Notes: • If unable to run 1" pipe to 150' or deeper in 9-5/8" x 13-3/8" annulus (Step 10), run pipe as deep as possible and contact AOGCC to obtain approval for alternative depth. 11. Run 1"jointed pipe inside the 32" x 36" conductor casing as deep as possible. Leave jointed pipe in hole for cementing to follow 12. Run 1"jointed pipe into 28" x 32" conductor annulus as deep as possible. Leave pipe in annulus for cementing to follow. 13. Pump cement to surface in both conductor annuli. Top off 28" x 32"x 36" , " refrigerated/insulated conductor casing with cement as required. 14. Pump cement to surface in the 9-5/8" x 13-3/8" annulus. Ensure good cement returns. Cut-off jointed pipes and leave in hole. Diesel returns from cementing to be pumped from catch pan to appropriate waste tank. 15. Use torch to make second cut of casing strings flush with conductor. This cut must be a minimum of 3' below tundra level. 16. Top off 9-5/8" x 13-3/8" and 13-3/8" x 20"casings with cement as required. 17. Level casing stub using a grinder. Weld marker plate(circular plate w/36" OD)with well information across all casing strings. Marker plate to contain the following information bead welded onto it: Alaska State C No 1 Exxon Mobil Corporation PTD# 180-046 API#50-089-20011 18. Backfill cellar with gravel and compact to Point Thomson Project specifications. 19. Clean up location. Transport all wastes and site clean-up debris to Deadhorse for disposal at approved waste disposal sites in accordance with ExxonMobil Waste Management Plan. ALASKA STATE C-1 Abandonment Procedure a*o 2 • POINT THOMSON 1. PRODUCTION Exxon Mobil Corporation Alaska State C-1 API#50-089-20011 PTD#180-046 Current Well Schematic Wellhead A section in place with 13-5/8"flange, companion flange and marker post on top / '> d�`01ti7-=-/ Permafrost cement 0'-60'BGL in 9-5/8"casing 10.2 ppg CaCiz ,t TOC in 13-3/8"casing at 2,200' 20"94#H-40 STC Conductor at 813',cemented . ; with 3,500 sx BP at 2,405'with 100 sx permafrost on top ; . '6-.'1"'a' at 2,200'.Tested to 1500 psi. 7"casing cut and recovered from 2,500' 9-5/8"x 13-3/8"annulus cemented from 2,925'to 3,993'and filled with arctic pack 4;;1 TOC in 13-3/8"casing at 2,200' from 2,925"to surface 13-3/8"shoe squeezed twice with 300 Sx 13.3 13-3/8"72#N-80 BTC surface casing at 3,993',cemented class G each ppg with 4,850 sx permafrost and 500 sx class G cement 4 ® mud 0,'=' :I 7"32#P-110 LTC Tied-Back from 10,536'liner to surface and . fi cemented with 200 sx class G 9-5/8"shoe squeezed twice with 300 Sx class G4. S 9-5/8"47#RS 90&Soo95 Protective at 11,119', each and once with 400 Sx class G 2;4 cemented with 2,470 sx class G x, {- - TOC in 7'11,258'(Tagged and tested to 1,500 psi) • 4`, i" .s . - .s Retainer at 11,350' ►�� CX $ F-1 Packer at 11,425' Perforations: 11,476'-11,504' 13.4 ppg mud $a 11,512'-11,564' r squeezed with 300 sx class G Mud interface at 11,846' 24 1s 11,576'-11,600' 15.5 ppg mud 2 , ► s TOC,in 7"casing at 12,552'(Not tagged,tested to 7,000 psi) .S Retainer at 12,695' ►�. .1A '~ F-1 Packers at 12,775'&12,772' '►tet' 'S 7"liner lap squeezed twice ', X 4-1/2"Liner Hanger at 12,848' with 400 sx class G each 2•' - '110 7"35#P-110 LTC Production/Protective casing at 13,146' "` • a Perforations 13,426'-13,560', - .� squeezed with 350 sx class G g'- #k 15.5 ppg mud ::i gP?, } a _ Perforations 13,630'-13,654', A '.,� squeezed with 250 sx class G TOC in 4-1/2"liner at 13,660' i'.,...1,774. Perforations 13,666'-13,706', squeezed with 100 sx class G g* M - h,..____ 4-1/2"15.1 P-110 LTC Production Liner at 13,757', Total Depth 13,761' • cemented with 200 sx class G ALASKA STATE C-1 Current Sketch , ' `' '. :, 5 POINT THOMSON 1'6 PRODUCTION Exxon Mobil Corporation Alaska State C-1 API#50-089-20011 PTD#180-046 Proposed Post-P&A Well Schematic Wellhead cut off and marker plate installed at>_3' BGL 9-5/8"x 13-3/8"annulus cemented from±200'to surf 5 f7 ..- Permafrost cement 0'-60'BGL in 9-5/8"casing 4.' +" 4`�: 10.2 ppg CaC12 oz,' TOC in 13-3/8"casing at 2,200' `ire " 20"94#H-40 STC Conductor at 813',cemented k.` 05.0.., with 3,500 sx BP at 2,405'with 100 sx permafrost on top at 2 A41.: `' ` ; 2,200'.Tested to 1500 psi. k /A A 7"casing cut and recovered from 2,500' 9-5/8"x 13-3/8"annulus cemented from 2,925'to 3,993'and filled with arctic pack ,41 / ; TOC in 13-3/8"casing at 2,200' from 2,925"to±200' 1'' ' 13-3/8"shoe squeezed twice with 300 Sx 13.3 t' 13-3/8"72#N-80 BTC surface casing at 3,993',cemented class G each 4 ppg 0 with 4,850 sx permafrost and 500 sx class G cement �»�!3 mud El e,,0 '1.`.CI CI f 7"32#P-110 LTC Tied-Back from 10,536'liner to surface and g cemented with 200 sx class G 9-5/8"shoe squeezed twice with 300 Sx class 9-5/8"47#RS-90&Soo-95 Protective at 11,119', each and once with 400 Sx class G P" cemented with 2,470 sx class G �'° ; ...3'0/ ! TOC in 7"11,258'(Tagged and tested to 1,500 psi) ' . - 'P'.,\, Retainer at 11,350' 5' '► ►�1,i F-1 Packer at 11,425' -.I. `1, m T ".",).«.#7 .._.° Perforations: 11,476'-11,504' �'''• v, 11,512'-11,564' squeezed with 300 sx class G 13.4 ppg mud 5;" ;, Mud interface at 11,846' --"; 11,576'-11,600' 15.5 ppg mud t. -, TOC,in 7"casing at 12,552'(Not tagged,tested to 7,000 psi) 5, '' Retainer at 12,695' +`► ►�4: F-1 Packers at 12,775'&12,772' 50'► 4• ►.t "s 7"liner lap squeezed twice °, .. «�:" -' 'A : 4-1/2"Liner Hanger at 12,848' with 400 sx class G each r • ++a , s /R 7"35#P-110 LTC Production/Protective casing at 13,146' I Perforations 13,426'-13,560', - squeezed with 350 sx class G II .$ 15.5 ppg mud fi t, d'2,t Perforations 13,630'-13,654', ta .r squeezed with 250 sx class G TOC in 4-1/2"liner at 13,660' i '4 Perforations 13,666'-13,706', ` g:'''`. "�` squeezed with 100 sx class G fi 4-1/2"15.1 P-110 LTC Production Liner at 13,757', Total Depth 13,761' . cemented with 200 sx class G ALASKA STATE C-1 Proposed Sketch Schwartz, Guy L (DOA) From: Wong, Gilbert <gilbert.wong@exxonmobil.com> Sent: Wednesday, March 20, 2013 11:09 AM To: Schwartz, Guy L(DOA) Cc: Foerster, Catherine P(DOA); Hagedorn, Karen D Subject: RE:Vault installation on PTU#3 and Alaska State C-1 Guy, Thanks for the AOGCC's willingness to work with ExxonMobil. We will get back to you on your request. Regards, Gilbert Wong BTPO Operations Superintendent- Point Thomson Global Operations—ExxonMobil Production Office: 907-564-3607 Cell: 907-301-3318 Fax: 907-564-3705 e-mail: gilbert.wong@exxonmobil.com From: Schwartz, Guy L(DOA) [nlailto:quy.schwartzalaska.gov] Sent: Wednesday, March 20, 2013 10:44 AM To: Wong, Gilbert Cc: Foerster, Catherine P(DOA) Subject: Vault installation on PTU #3 and Alaska State C-1 Gilbert, Cathy and I had a meeting this morning with Karen Hagedorn (Exxon Prod mana:er) to discuss the proposed installation of"vaults"over the wellheads on PTU#3 and Ak State C-1 ( PTD 178-005 and 'ID 180-046). hese two wells are currently secured downhole properly and are awaiting final surface P&A. In order for the AOGCC to approve these enclosures we are requesting a written timeline for final P&A(cut off of surface wellhead and cement to surface) of the wells or operational justification to keep them as is. We understand the overriding driver is to proceed with the facility and production installation of the Point Thomson startup. The Commission is willing to work with Exxon to ensure the production facility construction timeline and Sim Ops concerns are addressed. It is our understanding that the vaults will still enable the required 5 year inspection cycle to continue but the Commission's position is that the wells must be properly abandoned at the soonest possible period. Additionally,the Commission will change the official well status from "P&A"to"Suspended" as requested back in 2009. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 1 907-793-1226 office 2 RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMAONE° REPORT OF SUNDRY WELL OPERATIONS A0000 1.Operations Abandon L Repair Well U Plug Perforations U Perforate U Other U Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Exxon Mobil Corporation Development ❑ Exploratory IO 180-046 • 3.Address: PO Box 196601 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6601 50-089-20011-0000• 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 28382 ' Alaska State C#1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Point Thomson • 11.Present Well Condition Summary: Total Depth measured 13,761 feet Plugs measured See Attached feet true vertical 13,243 feet Junk measured N/A feet Effective Depth measured surface feet Packer measured N/A feet true vertical surface feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 784' 20" 813' 813' 1,530 psi 520 psi Surface 3,964' 13-3/8" 3,993' 3,993' 5,380 psi 2,670 psi Intermediate 11,090' 9-5/8" 11,119' 10,737' 8,150/7,720 psi 7,100/7,100 psi Production 10,646' 7" 13,146' 12,639' 12,460/13,700 psi 10,760/13,010 psi Liner 909' 4-1/2" 13,757' 13,239' 14,420 psi 14,320 psi Perforation depth Measured depth N/A feet SCANNED IrJt a r"! True Vertical depth N/A feet Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: No Treatment 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A 0 psi N/A Subsequent to operation: N/A N/A N/A 0 psi N/A 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Well Photographs Exploratory 0 • Development❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations See Attachment 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 . SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Tom Juranek(713-656-4225) Email tom.a.iuranekAexxonmobil.com Printed Name Irene T.Garcia Title Alaska SSH&E Manager Signature 4014 t Phone 907-564-3773 Date 9/19/2013 RBDMS OCT 11 2� Form 10-404 Revised 10/2012 Ar l("-17 Submit Original Only 10//mod l ExxonMobil Production Come Ire arcia P.O.Box 196601 SSH&E�Glanager Anchorage,Alaska 99519-6601 ; 4 907 564 3773 Telephone 907 564 3719 Facsimile EkonMobil September 19, 2013 Production R-2013-OUT-010 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: 2013 Report of Sundry Well Operations Alaska State C#1 (PTD No. 180-046) Dear Mr. Schwartz: ExxonMobil hereby submits a Report of Sundry Well Operations for the wellhead inspection of the Alaska State C-1 well on the North Slope. The well is currently suspended, and the inspection was performed for purposes of planning the future abandonment of the well. Attached please find: • Form 10-404: Report of Sundry Well Operations • Well Schematic • Well Inspection Summary • Photographic documentation If you have any questions or require additional information, please contact Tom Juranek at (713)-656-4225. Sincerely, itg-a/tc-e.-4/ IG:ed:gg Attachment A Division of Exxon Mobil Corporation • • Exxon Mobil Corporation Alaska State C-1 Well Schematic API#: 50089200110000 APTD#: 180-046 Wellhead A section in place with 13-518" . 5K flange, companion flange and marker post on top fi TOC in 13-3/8"casing at 2,200' ,' '• 10.2 ppg CaCI, �< Permafrost cement 0' 60' BGL in 9 518"casing 20"94# H-40 STC Conductor at 813', BP at 2,405'. cemented with 3,500 sx r;/ `p 9-5/8" x 13-3/8"cemented from 7" casing cut and recovered from 2,500' • 2,925' to 3,993' and filled with arctic `' pack from 2.925" to surface 13-3/8". 72#N-80 BTC surface casing at 3,993'. 13.3 13-3/8"shoe squeezed twice with PP9 cemented with 4,850 sx permafrost and 500 sx G cmt 300 Sx class G each mud '= • 7" 32#P-110 LTC Tied-Back from 10,536' liner to surface and cemented with 200 sx class G 9-5/8" shoe squeezed twice with 300 ' 9-5/8"47#RS-90 & Soo-95 Protective at Sx class G each and once with 400 ' 11,119', cemented with 2.470 sx class G ••Sx class G , ' ? TOC in 7" 11,258' (Tagged and tested to 1.500 psi) Retainer at 11,350' Mud interface at 11,846' >Kr �g F-1 Packer at 11,425' Perforations: 11.476'- 11.504' 13.4 ppg mud 11.512'-11.564' squeezed with 300 sx class G 11,576' - 11.600' 15.5 ppg mud TOC, in 7" casing at 12,552' "'`7■.--+ Retainer at 12,695' ..r••17. F-1 Packers at 12,775'& 12,772' • 7" liner lap squeezed twice • $ 4-1/2" Liner Hanger at 12,848' with 400 sx class G each ! _ 7" 35#P-110 LTC Production/Protective casing at 13.146' • Perforations 13.426'— 13.560', squeezed with 350 sx p class G 15.5 ppg mud - Perforations 13,630'— • fi ; 13,654', squeezed with 250 sx TOC in 4-1/2" liner at .-� class G 13,660' •-- Perforations 13,666'— 13,706', squeezed with 100 sx ••, • -n class G Total Depth 13,761' 4-1/2" 15.1 P-110 LTC Production Liner at 13,757', cemented with 200 sx class G Well schematic is prepared by Fairweather ESP Inc.Last updated May-2009 • Alaska State C #1 Operations Summary A site and well head inspection was conducted in order to facilitate future P&A activity scheduled for summer of 2013. The wellhead inspection was warranted to ascertain well head part numbers and determine presence and height of 9 5/8" casing extending above A-section. Attached is summary of operation and photos. 08-13-13: Arrived on location @12:01. Excavated around wellhead, water invasion posed significant difficulty. Installed pressure gauges, verified 0 psi on 9 5/8" and annulus. Removed bleeder from blind to attempt camera run. Unable to access due to tar-like substance obstructing nipple. Attempted to break through with rod. Solid fill. Removed LDS from CH, verified stump presence with camera. Unable to verify height due to visibility. No bleeder screws or test ports to flush through. Replaced LDS. Secured well, found partial WH assbly #s, filled in excavation. Departed location 14:35. Adapter 13 5/8"-5k x 3 1/8"-5k 2013 Site Inspection Alaska State C#1 • S } M r M t. nz `\ . t / w '' VI! ' �t e-4 y k ''''7:.'":.• ' 7 �- `! �t �, s K� fSs =b _ y.,' N * {i-e rf.it_t d ro d �. '....:::::.'-.'"''' '''''''''''.1 .�S �' ,i44.-.,-0-tt. . - v ,'. 4. a '; 0, c ,.awY` w F ,L,111..1416, 4 o-.x Alaska State C #1 Excavation 2013 Site Inspection Alaska State C#1 • 0 - " • ; ' i . . O. - .., ■• . . , * ' ..4.,•.' . "..4 r...0 h, -', . , I. .0: t-' ... -, - • . * ,. - *4.- w•--: . - . - ' !, ,... ..1:*"2%,,f.t•..41P"rik ir'''-3 P' *),"-7 4 . , .. "-4111t• . r '''-rt r-" r 1 .-, 1-.40k id,* 0 110 - ,., . .1 . ,. * . i. •.- 40.e, -A, ,,-7.--.. .., •.:,'141.,:ilikr.A.-,--.s.,- ; ,:. - ,,,,rimiri Alaska State C #1 Pressure Test— 0 psi - ,;, -:71P-- , '1---• z'• . ' ' -,;„7.--- . 7 , _,„A :i•**4---1-Sit14‘.- ' N . : .t• , -. • ' °"!'"-'•-ff'- ----' -..-', -. ' ',7-'': ''' '2.7......"'''-i .., ''''. ''''.;'* . „,;..- 1:1`,-.----7.--- 1,',. ..'t.'1,:,.:', 1 .-.:.,, . • '`), '1"-* . ' '-'• • '' --:- ' *•-',/it'..-• •,..-- ;'.-2,,..,, t -, -.4 . „ , ,-, ,.,„ , .,.,,.. 1.4-- ' '' ''''-'-i;4-: - ;';'7';*,.- -1 e84,4: . - -'-',.,.- — ..?„.. . ,-,'. ., .•.%, 4x.:,,.;i,',!„:,, , .,„i, ,.,_,.....•: ,-..!..; . '.,1-7, ,."" , .-.,..*:.„,40k... c. . „.,,;„ 4.... . . ' . .. -,- „ .. r 1'■:41.0'' .;..:%:411111°°'A,'Y..:''' ''-' -'''''',. ''f l'''r''1.. qt.'*' ' , ' ' ■1i 444'4 ', p v.,..,...„.• :,-. , ,.) -,.,.:-,,4--, •.:,•••,, , i ---,--,...--!,-. , c_,-,... 1 , - •4'fr:;":,',2, ' -.l*Ity' 7;1 0 - -• , - - , Plugged Blind Nipple 2013 Site Inspection Alaska State C#1 • • From: Schwartz, Guy L (DOA) Sent: Wednesday, March 20, 2013 10:44 AM To: Gilbert Wong (gilbert.wong(aexxonmobil.com) Cc: Foerster, Catherine P (DOA) Subject: Vault installation on PTU #3 and Alaska State C -1 Gilbert, Cathy and I had a meeting this morning with Karen Hagedorn (Exxon Prod manager) to discuss the proposed installation of "vaults " over the wellheads on PTU #3 and Ak State C-1 ( PTD 178 -005 and PTD 180 -046). These two wells are currently secured downhole properly and are awaiting final surface P & A. In order for the AOGCC to approve these enclosures we are requesting a written timeline for final P & A (cut off of surface wellhead and cement to surface) of the wells or operational justification to keep them as is. We understand the overriding driver is to proceed with the facility and production installation of the Point Thomson startup. The Commission is willing to work with Exxon to ensure the production facility construction timeline and Sim Ops concerns are addressed. It is our understanding that the vaults will still enable the required 5 year inspection cycle to continue but the Commission's position is that the wells must be properly abandoned at the soonest possible period. Additionally, the Commission will change the official well status from "P &A" to "Suspended" as requested back in 2009. Regards, Guy Schwartz Senior Petroleum Engineer SCANNED MAR 2 0 2013 AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office • • Page 1 of 3 Schwartz, Guy L (DOA) From: Rob Dragnich [rob ©rgdragnichllc.com] Sent: Friday, January 04, 2013 12:00 PM To: Schwartz, Guy L (DOA) Cc: Fowler, Bill Permits /C; Gilbert Wong Subject: Re: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Hello Guy, r A- sf ' Thank you for your response and questions about the wellhead vaults. As a practical matter, there will not be any weight limitations. The vaults will be designed to support the largest Toads envisioned to travel across the pad including drilling rigs and 4000 ton modules on Singe Point Module Transporters (SPMTs). A surface marker will not be installed because it would create traffic obstructions . The location of the wellheads and vaults will be shown on as -built drawings to ensure no incompatible future activities occur in the area. The wells and vaults can easily be located in the future using measurements from the drawings. Other means could include GPS coordinates and metal detectors. Given the massive steel plates and relatively shallow gravel cover, metal detectors should provide simple and positive locations. With respect to future plans, although these wells are not planned to be used as part of the IPS, they are "capable of producing in paying quantities" and may have future utility for ExxonMobil and the other Working Interest Owners. Any determination regarding use (or P &A) of these wells likely would not be made until some time after startup of the Point Thomson Initial Production System (IPS), which is planned for the winter /spring of 2015 -16. There are additional considerations why we do not want to conduct any activities on these wells until after IPS startup. There will be a lot of construction, commissioning, and start-up activities on the Central Pad (PTU 3 pad) and C -1 Pad and avoiding any unnecessary simultaneous operations (SIMOPs) will help ensure a timely completion of construction and startup and reduced the potential for any incidents. Please advise if you have any further questions on these. Am I correct in interpreting your note below to say that a form 10 -403 approval will not be required but ExxonMobil should a form 10-404 after the work is completed? The form 10 -404 would include pictures to clearly illustrate the condition of the wellhead, the wellhead and vaults during construction, and a final picture showing the pad after installation of the vault and covers. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichllc.com 907 - 830 -4796 From: Guy Schwartz <guy.schwartz @alaska.gov> Date: Thu, 20 Dec 2012 20:25:37 +0000 To: Rob Dragnich <rob @rgdragnichllc.com> Cc: "Fowler, Bill Permits /C" <bill.permits.fowler @exxonmobil.com >, Gilbert Wong <gilbert.wong @exxonmobil.com> Subject: RE: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" 1/4/2013 • • Page 2 of 3 Rob, Thank you for the engineering drawings for the planned work. Some wellhead pictures will be required before and after the vault is installed. A 404 report of work can have some of the construction pictures included. Also, will there be any surface marker at all to identify the well? I assume there will be some weight limitations on what can be driven or these covers. Can you elaborate... . Can you restate your intended plans for the wells ( Alaska State C1 and PTU #3 ) in regards to future utility or a planned date for final P & A ? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From:Rob Dragnich [mailto:rob @rddragnichilc.com] Sent: Thursday, December 20, 2012 10:24 AM To: Schwartz, Guy L (DOA) Cc: Fowler, Bill Permits /C; Gilbert Wong Subject: FW: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Guy, Thanks again for your time to meet with our remediation well work supervisors last week. As discussed and as a follow -up to the attached note about the installation of wellhead "vaults" around the PTU #3 and Alaska State C -1 wells, attached are engineering drawings showing side and end sectional views of the vaults. My apologies for the detailed nature of the drawings. You can think of the vaults as large reinforced concrete boxes supported by piling. The boxes will have steel covers and a nominal 12 inches of gravel will be placed over the covers to allow for traffic. The covers can be removed when necessary to conduct the well inspections (every 5 years as required by AOGCC regulations for suspended wells). There is no physical work being done to the wells themselves. Rather the vaults are being installed to protect the wellheads from potential damage during construction and operations thereby maintaining the integrity and safety of the well and surrounding area. Also please note current timing for installation is now 2014 (vs. 2013 as shown below). Please advise if either a form 10 -403 (Application for Sundry Approval) or a form 10 -404 (Report of Sundry Well Operations) need to be submitted for these vaults. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichllc.com 907 - 830 -4796 From: Rob Dragnich <rob @rgdragnichlIc.com> Date: Wed, 14 Nov 2012 16:56:15 -0900 1/4/2013 Page 3 of 3 To: Guy Schwartz < .schwartz @aaska.gov> Cc: Gilbert Wong <gilbert.wong @exxonmobil.com >, Bill Fowler <fowler.bil @exxonmobil.com> Subject: PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) Wellhead "Vaults" Guy, thank you for your time to discuss ExxonMobil's plans for protecting the PTU 3 (PTD 178 -005) and Alaska State C -1 (PTD 180 -046) wells. The Point Thomson Project will use the gravel pads from which these wells were drilled for Initial Production System (IPS) facility purposes. As discussed, this note describes our plans for your consideration on whether an Application for Sundry Approval (Form 10- 403) or a Report of Sundry Operations (Form 10 -404) should be filed for the wellhead vaults we plan to install around these wells. The wellheads are lower than the planned finish grade of the pads and no work to them will be required. To ensure the wells will not be damaged during construction or operations, it is planned to install steel "vaults" that cover and protect the wellheads. These vaults will allow traffic over the wellheads while also allowing access to conduct future inspections pursuant to AOGCC regulations. The wellbore marker has been removed from the PTU 3 well and the C -1 wellbore marker will be removed before installing the vault. The locations of the wells will be carefully identified to ensure no construction work interferes with access and to aid in future inspections. Current plans call for installation of the vaults in March 2013. If you advise an application for a Sundry Approval should be filed, we will submit it at least 30 days prior to the time when installation of the vaults is scheduled to occur. Please feel free to contact me at 907 - 830 -4796 or email "rob @rgdragnichllc.com "if you would like further information or details on this. Thanks again for your time and help. Regards, Rob Dragnich R.G. Dragnich, LLC rob @rgdragnichllc.com 907 - 830 -4796 1/4/2013 WELLHEAD q. EXISTING GRAVEL LID TOP PLATE EXISTING INSULATION fv ••iii i i i � y i i fir ���� !�!i ;/ afkie • PILE SCHEDULE Li • •'• ' /n ••• I� • • 1 1 ��• •�/ �' � � ..� PILE LOCATION PLE SI7E QUANTITY SUPPLY LENGTH '�� ..E ... NII N// i ird �i7 E . _ 1.. _ _ & EMBEDMENT '' \ / / \ / \ / \ / \ " 1' '��� " � •• • N a 1 •j I / / ALASKA STATE 24 "t 4 45' I L • 0 • • -/ LAS VAULT / \ \ � \� \ TRUT. TYP L � �� :•� jA�' / \; NOTE' PROVIDE (1) 40' CONTINGENCY PIPE PER USE IN -----2 NATIVE SOIL \ \ \ / .'••.• • / \ / \ / / \/ EITHER VAULT. EXCAVATION SLOPE. TYR I I L .Li INSULATION, PCP • 1 NO GROUND THAWING SHALL BE PERFORMED DURING CONSTRUCTION. 2. ALL FILL SHALL BE UNFROZEN DURING PLACEMENT AND COMPACTION 3 INSTALLATION SHALL OCCUR DURING SUMMER. 4. FIELD VERIFY ALL EXISTING WELLHEAD DIMENSIONS AND ELEVATION PRIOR TO L FABRICATION. ALASKA STATE Cl VAULT END SECTION NOTE: VAULT HEIGHT MAY BE NTS ADJUSTED BY ENGINEER BASED UPON FIELD DATA. WELLHEAD & VAULT 9 -0" VERIFY WITH FINAL g VAULT DIMENSION SEE ALASKA STATE CI WELLHEAD, VERIFY USPT -WP- CDFND- 095003 -001 EXTENTS PRIOR TO FABRICATION 8" CLR, HIGHEST POINT OF TOP OF NEW PAD. REFER TO ALASKA AND NOTE 4 (SEE NOTE A) WELLHEAD TO BOTTOM OF STATE C -1 PAD PLAN DRAWINGS EXISTING GRAVEL I LID TOP PLATE USPT -WP- CORAL- 173043 -001 FOR IZ' FILL COVER LID TOP PLATE _ ELEVATION, PLACEMENT & COMPACTION EXISTING INSULATION •/ n ,// -/ . , ' • ‘11:94: 4:4217074.11414 :ii1 .W.V i ��!�it�'� —� • ��flail! �� TI r• i� / i i i Wir ttei 2411 1"" eat T 1.111111.11. J ml mall. —1 j! �iNS.0.1.iis J1 ui♦ /.� / • • .._ __ \ / \\ \ \ \ \ • ; ... r Y M OUNT TYP • � '• /\ / � / 7-7,..::::::,,,.,.....,. / \ K STRUT �! �j �% . ^ _ • BOTTOM OF .. nnn�rn>•∎• —�' L. `N_ EXCAVATION EXCAVATION i I INSULATION 4 "l. TYP `` \/'►� OF NATIVE SOIL 6' -0" MIN I S T THICK INSULATION LAYERS . e V �` SLOPE, TYP i t SEE DRAWING SHALL BE GRADED FLAT FOR INSULATION ` e �� � USPT -WP- CDFND- 095003 -002. fr PILE CONNECTION DETAIL, TYP C ) DRILL & SLURRY PILE, TYP GO k0 ALASKA STATE Cl VAULT SIDE SECTION _ NTS RERRENCE OWINGS DESCRIPTON 0 ..�� \N, REV 0EE °ESDRmDON BY CI« DADS PRa CML DRAWINGS — FOUNDATION USPT- OP-Cn0F 095000-001 CO/ROW O INDEX ' � ;..L.44,�1, 10 03/12 ISSUED FOR CONSTRUCTION FS SO S S E WELLHEAD VAULTS — PTU 13 & ALASKA STATE Cl USPT- 'NP- CAS1M- 095005 -001 WIER9L NOTES S* 49'M 1�Q �� Development t ALASKA S Cl �' L VAULT ELEVATIONS 3 "at -A --- L POINT THOMSON ALASKA _ .. _ _.. 1'AWLE D RAWN TO SR F:•. TZ??.. :'R.� ® ® m DRAWLED EU 18148-121... 'MELT �'o �.,oa os �z..• � � ® YrpNyP•rron• FLUOR. S M NIS ` "xosais hZy ■ USPT —WP— CDFND - 095002 -001 10121 1 V CL WELLHEAD LID TOP PLATE e:. • •.ito • • Ft .4. :-.4••• i mod. � ..�- . Wit. PILE SC EXISTING INSULATION i:RSA •�•.ii : p ilWgr.�:• r 1. o ., 'VMS. .:•': P I SCHEDULE ' -• I • ,�e1;•�•� �• , II -- ��1It • •- 4��•1.1 �• PILE LOCATION PILE SIZE QUANTITY SUPPLYLENGTN EXISTING GRAVEL 11 • 114 �, iI 1;1 • •� j \ .• 4;1s g% r �i• i• • •a1L .� PTU �3 24'440 751 S. EMBEDMENT 01M • �.I1�•4•�:1. •�• r 1 • :• - 4 45' i / _. ... _ /0000.,, . 404 V. T 42,4111 . 40 . 4 °. � ��� I I Vega , • • , // / \ \j \ \j \ \ \ STRUT. TYP •I• / ' NATIVE SOIL .. / / ,�'I'•: -4,- / \\ 1 II EXCAVATION SLOPE, TYP I I \ \ \� \ \� \ / \ /\ \' \ / INSULATION, TYP • _ NOTES 1. NO GROUND THAWING SHALL BE PERFORMED DURING CONSTRUCTION. ALL PTU #3 VAULT END SECTION 2 PLACE COMPAC ONN DURING ,, 3 3. INSTALLATION SHALL OCCUR DURING SUMMER. - 4 FIELD VERIFY ALL EXISTING WELLHEAD DIMENSIONS AND ELEVATION PRIOR TO - FABRICATION. NOTE: VAULT HEIGHT MAY BE ADJUSTED BY ENGINEER BASED - UPON FIELD DATA. WELLHEAD PTU#3 WELLHEAD. VERIFY & VAULT EXTENTS PRIOR TO FABRICATION fE 2' -8" CLR. HIGHEST POINT - 11' -O" VERIFY WITH FINAL (SEE NOTE 4) I OF WELLHEAD TO BOTTOM TOP OF NEW PAD, REFER TO CENTRAL VAULT DIMENSION SEE OF LID TOP PLATE PAD PLAN DRAWINGS USPT- WP- COFND- 095003 -001 12" FILL COVER LID TOP PLATE USPT -WP -CORAL - 773039 -001 FOR AND NOTE 4 ELEVATION, PLACEMENT & COMPACTION I EXISTING INSULATION • - ♦ �;,� �I ∎ ∎.R 1 0. Vi i ' ' MI , � 1=11 �i • I I� � 4 . 1 � �• •�; � � , 4I.�� E XISTING GRAVEL • 4 , "v..* 1� l 1.t ♦ • ia •:► • FILL S• •1• j. II • �. A A II.- •.� N 4I l 04I .. i •t II . �1 • •' r4 .N _ • a O� • • • yyy N .._ __00.. I�i iI.1 .i j I•i I I •�•.,.I� -. ...r_ *"". r � y MOUNT. TYP �� / \ / N ATIVE SOIL '•• •.� I I - _ - __ _ - L L- - \ \ \ \ \ � e _____... BOTTOM OF �'z.„ ,,, ,, ,_ - - ... -- �� ' '' - 47 / / / • EXCAVATION I \ \ \ \ \� \ \� \ \� \ \� \ \� \ - ` � Ld EXCAVATION 4' -0' MIN 1 _` SLOPE, TYP INSULATION 4 ° t. TYP \/ PROVIDE 2 LAYERS OF 2 - SEE DRAWING USPT- WP-CD THICK INSULATION BOARD ` � PILE CONNECTION tQ � CTION DETAIL, TYP 5003 -002 SHALL BE GRADED FLAT FOR INSULATION , � _`� �/ CTION ` N_ T L DRILL & SLURRY PILE, TY K50(611‘ PTU #3 VAULT SIDE SECTION DESCRimwN w.k e. DATE DE,p BY C.« APPD PRD CIVIL DRAWINGS FOUNDATION USPT- WP 095000 -001 MM111NG INCE< AR.RF.A .,4 ( 10 03/12 SSUED FOR CONCIRUCTk)N FK SB KW8 SP E *onMobil WELLHEAD VAULTS - PTU 13 & ALASKA STATE Cl user- wP- cosru- oawos -o01 GENERAL NOTES ' ae Tn Development PTU 113 VAULT ELEVATIONS 9'Gi"' — -- j POINT THOMSON ALASKA �« xR M . ∎ . III m a.,;. ww � ® YYUrMYMrwne F LU O R. kW. ID^^ x' SM 103-08-121 �Nf9 r "r0 h kh,\ :•∎...: c .... 0000 p wWNG ND KU t hn�� USPT- WP- CDFND- 095002 -002 2 w 2 r10 '��---------------- - - - - -- - --------- __------------------- - -- - -� * CENTRAL PAD i / 8 . -0 " FL WELLHEAD 3 VAULT (PERIMETER`\ 4 / I 8 -0" CL WELLHEAD 3 VAULT (PERIMETER`\ / / ryP / FOR \ / ryP /SHOWN FOR • �I ,'� / / © PILE • TYP /SHOWN l \ \\ / / r © PILE. ttv _ L REFERENCE) l \ \\ / o 9 \\� / A O \ \ WEST PAD \•', I W i I 1 j . I \ I I N ' d EXISTING I W I f o /"EXI STING 1 _ i H I H WELLHEAD 1 1 I I _ . J WE LLHEAD I I I 5 N EI BASIS OF BEARING E %ISTING •--10 - — I L i vSi EXISTING _ ( _ _ I I TELLHEAD ALIGNMENT IF % , I I TWELLHEAO ALIGNMENT \. - '�' 1 (FIELD VERIFY) / I (FIELD VERIFY) j GRAVEL MINE I _ \ © - ' / 1 \ \ O ' - y __— / I '� \\ % , \ \ i 1 11 li - ALASKA STATE VAULT LAYOUT PLAN I \\ VAULT LAYOUT PLAN / — Cl PAD \ NTS / I \ NTS ,,,// AIRSTRIP / ` . 1 I l� KEY PLAN ` ' 1, I NTS 1 t 4. 9k I / I t rO ```\ I j I EXISTING PRI #3 `` \\ r___. I �� ^ �O ♦ �` �� `, \\ ; '• • NE 5912413.63 \\, I v G ,` ; E 1608646 29 - - CDSIi - 000001 - OOI \\ I `�S S1 �v 1 •1 TO `` ._ . RREEE WP II ` VAULT i GpN 0$1 0a CONTROL `9999• CENTRAL PAD I VAULT EXISTING ALASKA STATE I ; J I N. 5 63 %��; ` i I E 1609987.83 I ti L —) I I 1 I •ropp� I ALASKA STATE CI PAD ,• ^1 I I • \ L _ I i „,---\..„,.0 - / - PTU #3 WELLHEAD VAULT SITE PLAN ALASKA STATE Cl WELLHEAD VAULT SITE PLAN NTS NTS REFERENCE ROWMX CESCNPROR \y REV DATE OISAUr . BY nW AMP PRa CML DRAWINGS FOUNDATION USPE -WV- COW "015000"001 UMW M U t (E� F A�9y -- 10 03/12 WNW FOR CgRIRUCTION 10 80 SP E*(onMobil WELLHEAD VAULTS - PTU /3 & ALASKA STATE Cl qP - U6Pi- NP- fDS11h0➢SWS -001 COOK NOTES ' M ..49 D evelopment SITE PLANS 3 POINT THOMSON ALASKA as i?..•.�;" m ® WMyP•nJOnt FLUOR. m I ®I m Eroouu I M 'Q7—OB -121 MS i nto an 1 fi,p �s. ... DRAWING PO bit El REV `�� � �e USPT— WP— CDFND- 095001 -001 1 1110 /- __________�///qq�� \�'_____�_ _ _______-- ////��jj_���1____ - - --` CENTRAL PAD - © T-P \ T / ```�\ ,r.'.'. ' 0 \ v / `` TE / EE-0 WELLHEAD 7 VAULT (PERIMETER` 8 -0 TL WELLHEAD 7 VAULT (PERIMETER`\ /VAULT FOR \ / / FOR \ g4T-j* , % ALE. TYP - - -- L REFERENC) \ \\ REFERENC) \ \\ / PILE, TTP L %O __ __ _ - j \ B OO i W \\ WEST PaD I \ 1 7 w 3 t i I 1 I 1 EXISTING I i 1 W I EXI I I I - - I 7 3 WELLHEAD I I I WELLHE AD 1 1 i N BASIS OF BEARING EXISTING _ l - ,( - _ I 1 G �, BASIS OF BEARING EXISTING N _ I I TWELLHEAD ALIGNMENT • - 41 T. / I 1 WELLHEAD ALIGNMENT l/ - I (FIELD VERIFY) ; (FIELD VERIFY) - -- I I GRAVEL MINE \ \ \\ VAULT LAYOUT PLAN / \ VAULT LAYOUT PLAN / � - C C T P�sTATE \ NTS \ NTS / AIRSTRIP ` , - j `` 1 I '� { KEY PLAN I V NTS ww 1 I �O Q� - • I . EXISTING PTU ,y3 \ • WELLHEAD ` \ \ \ I N: 5912413.63 \ \\\ ; E 1606646 29 \ \\ v \ \\'� ' VAULT 11 ! ' ROL ' CENTRAL PAD I VAULT EXISTING ALASKA STATE J Cl N 900530 63 �mm; ; r L E 1609967.63 • I ` , — e IL I �.• - I I ' I ALASKA STATE Cl PAD ,---- " \ ) PTU #3 WELLHEAD VAULT SITE PLAN ALASKA STATE Cl WELLHEAD VAULT SITE PLAN NTS NTS KM.. MAWS DESCRIPIIN REV ������� Pl_ OWE ssWP- mr1_oewm-0ol mow P OF , A,(•1 fo OS /1z WORD FOR wHSrRUCn Te s ox �� wIPS o !NM SP CML DRAWINGS — FOUNDATION IRPT •`- CDSYII- 005065 -001 AL NOTES Yy TV 3 9 .11 i onMobil W ELUiEAD VAULTS SITE PLANS ALASKA STATE Cl * . q Development 'r x R POINT THOMSON ALASKA . m ® m u "' E 1 •b1..o P ®WoEMF.z..W. FLUOR. ID""w SM I03- OB -12I Nf5 ' E1 \\i.� w " w � D USPT— WP— CDFND- 095001 -001 ^ 1 s 1 110 ~~s~~cs~a6~°s! ~p~cEea~ta~~ Com~sacsy Joint Interest U.S. - Alaska P.O. Box 195601 P,nchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile ~" V ~~• ~'~'4~~~~~ ~ ~ ~i1iV ~ ~ i~i(l.g ~laS~~ ~i~f ,~, ~;~ ~ `~~' ~~7t7ti~, Lpqti • ~ ~~4t11'8~~ RIISS1Qp°~ E~onMobi~ ~~o~~~~a~~ June 17, 2009 Mr. Johnny L. Aiken, Director North Slope Borough Planning and Community Services Department P.O. Box 69 Barrow, Alaska 99723 CJ ~C-~ ~°-~+~.~- ~ cr~ ~t ~~~.~~~~~ ~~~~ Re: Tundra Travel Completion Report Dear Mr. ' ~ $ ~ + ~ ~~ -Pi V ~ ` Aiken: AIQIs~~ stA~ ~~ Please find attached our 2009 Winter Tundra Travel Completion Report as required by North Slope Borough Conditional Use Permits. This Tundra Travel Completion Report pertains to the following activities authorized by the above permits: - Ice Road Construction from the Endicott causeway to the Point Thomson Unit Central Pad - Ice Road Construction to the Alaska State C-1 water source and other lakes from which water was withdrawn. - Tundra Travel /Ice Road Access - Point Thomson Unit Central Pad Mobilization & Construction - Well Inspections and Remediation The attached report reflects Tundra Travel activities through closure of the Alaska State C-1 ice road on May 19th, 2009, and includes the following elements: 1. Actual routes of travel and the location of all camps depicted on USGS topo maps 2. List of vehicles for off-road travel that has taken place 3. Statement of cleanup activities 4. Method of disposal of garbage and other camp debris 5. Report of known incidents of tundra damage and follow-up corrective actions A Division of ~xxon M~bi! ~~rp~~~tiar~ Mr. Johnny L. Aiken -2- June 17, 2009 If you have any questions, please contact me at 907-564-3617 or by email at mike.barker@exxonmobil.com. Thank you Sincerely, ~ ~~, .> ~ ~ '.~ ~ ~ ~ Mike Barker Environmental & Regulatory Manager KDC:eaa Attachments cc: Lori Aldrich, ADEC Gordon Brower, NSB Nina Brudie, DNR Larry Byrne, DNR DMLW Steve Davies, AOGCC Josephina Delgado-Plikat, DNR John Easton, DNR DOG Gary Evans, ADEC Susan Harvey, Harvey Consulting Lee Kayotuk, Kaktovik Tom Maunder, AOGCC William Morris, ADFG Craig Perham, USFWS Matt Rader, DNR DOG Barrett Ristroph, NSB Gary Schultz, DNR DMLW Roy Varner, NSB Waska Williams, NSB Ryan H. Winn, USACE Jack Winters, ADFG ExxonMobil Production Company Alaska Interest - Joint Interest U.S. P.O. Box 196601 Anchorage,Alaska 99519-6601 907 561 5331 Telephone June 1, 2009 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th.Ave., Suite 100 Anchorage, Alaska 99501 Re: Sundry Report of Sundry Well Operations Exxon Mobil Corporation Alaska State C-1 PTD No. 80-046 Sundry No. 309-078 Dear Commissioner Seamount: ,~~~~~~~~~ ,~'.a ~~! `s ~ ~~J9 ~~~Sa~~ ~~~ ,~~a' ~'~~ ~~~~V ` ~~~11TIlSStQ;~ .~~~~,"•~.'~~'~~~ E~onMobil Production Exxon Mobil Corporation hereby submits its Report of Sundry Well Operations for the wellhead inspection of the Alaska State C-1 well on the North Slope. The well is currently suspended, and the inspection was performed in accordance with AOGCC requirements for suspended wells. S ~t~ 3 j v1 ~ ~ ~t ~2 ~-~' ~~ During the operation, the wellhead was exposed by excavating the gravel cover. The wellhead was visually inspected, and the well integrity was verified by checking for and recording pressures in the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus; zero pressure was recorded in the casing and the annulus. One new gate valve and one new needle valve were installed on the wellhead. At the completion of the well inspection the wellhead was left covered with gravel. Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations Wellhead drawing Wellbore diagram Well plat Photographic documentation of the well before, during and after the work If you have any questions or require additional information, please contact me at 907-564-3617. Sincerely, ~ . V~- ~ D. Michael Barker Environmental and Regulatory Manager JAR:eaa Attachments A Division of Exxon Mobil Corporation STATE OF ALASKA ~~~~ ~ ~' :'~.~{~_`` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS #~~~'~~ ~'~ ~~~~ ~~~~~' ~'~`~'°~`'~~~~''~ Anchor~g~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Well Inspection ~ Performed: Alter Casing ~ Pull Tubing ^ Pertorate New Pool ~ Waiver^ Time Extension ~ Change Approved Program ~ Operat. Shutdown ^ PerForate ~ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Exuon Mobil Corporation Development ^ Exploratory^~ ~ ~ 80-46 3. Address: PO Box 196601 Stratigraphic^ Service^ 6. API Number: Mchorage,AK 99519-6601 50-089-20011 • 7. KB Elevation (ft): 9. Well Name and Number: 54 ~ Alaska State C No 1 8. Property Designation: 10. Field/Pool(s): ADL 28382 • Wildcat 11, Present Well Condition Summary: Total Depth measured 13,761 ' feet Plugs (measured) Plugged to Surface true vertical 13,243 • feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD ND Burst Collapse Structural Conductor 784' 20" 813' 813' 1530 520 Surface 3,964' 13 3/8" 3993' 3,993' 5380 2670 Intermediate 11,090' 9 518" 11,119' 10,737' 7720 / 7290 4990 / 7100 Production 10,646' 7" 13,146' 12,639' 12460 I 13700 10760 / 13010 Liner 909' 4 1/2" 13,757' = 13239' 14420 14320 Perforation depth: Measured depth: N/A True Vertical depth: N/A Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~ ~~' C f . . :,.~ ~ ~ 2D~~' Treatment descriptions including volumes used and final pressure: 13. Representative DailyAverage Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Well Photographs Exploratory~ Development ^ Service ^ Daily Report of Well Operations See Attachments 16. Well tatus~fter work: ~ us S~CCc. -"1-~11 SG C" Oil ~r~`Gas~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. G ~~ Sundry Number or N/A if C.O. Exempt: (~-~~ 309-078 " Contact Mike Barker Printed Name Mike Barker Title Environmental and Regulatory Manager < Signature ~ . ~~ Phone (907) 564-3617 Date ~ ~ Form 10-404 Revised 04/2006 "'- '` ' ~1~+~ Sy~mit Origi~al O ly ~ ~'~/~4y /s' ~ ~. ~G' ~ Daily Operations Log Alaska State C-1 Well Inspection Saturday, April 25, 2009 • Excavated cellar around wellhead. • Removed 4' of cellar box. • Jack hammered frozen gravel around wellhead. Removed marker post. • Applied heat to wellhead. Sunday, April 26, 2009 • Tested existing 3" 5K valve to 250/5000 psi for 5 min. Good test. • Installed new 3" 5K gate valve and tested to 250/5000 psi for 5 min. • Opened valves. Observed zero pressure. • Rigged up to hot tap top bull plug. Test to 1000 psi. Drilled bull plug. 0 psi noted. • Installed 2" 6K ball valve, tap bull plug, 1/2" needle valve and plug. • Wrapped new valves w/ visqueen and filled excavation. Day 3- Monday, April 27, 2009 • Demobilized the camp and wellwork equipment to Deadhorse. Alaska State C-1 McEvoy Split Speedhead System 5" LP 3-1/8" 5k. 13 5/8" 5k. --p 3-1/8 5K psi IA & OA valves are 3-1/8 5k MPN# P1000014761 Serial #08-11-2562 model 120+ L~Lotes Casing spool 24" tall ~ 2" ball valve and a needle valve ~ ~' ~ `~ `~ MPN# McEvoy Model "C" ~~~ 3-1/8 5K psi Exxon Mobil Corporation Alaska State C-1 Well Schematic API #: 50089200110000 APTD#: 180-046 Wellhead A section in place with 13-5/8" , 5K flange, companion flange and marker post on top TOC in 13-3/8" casing at 2,200' BP at 2,405'. 9-5/8" x 13-3/8" cemented from 2,925' to 3,993' and filled with arctic pack from 2,925" to surface 13-3/8" shoe squeezed twice with 300 Sx class G each 9-5/8" shoe squeezed twice with 300 Sx class G each and once with 400 Sx class G Mud interface at 11,846' 13.4 ppg mud 15.5 ppg mud 7" liner lap squeezed twice with 400 sx class G each 15.5 ppg mud TOC in 4-1/2" liner at 13,660' Total Depth 13,761' Permafrost cement 0'-60' BGL in 9-5/8" casing 20" 94# H-40 STC Conductor at 813', cemented with 3,500 sx 7" casing cut and recovered from 2,500' 13-3/8", 72# N-80 BTC surface casing at 3,993', cemented with 4,850 sx permafrost and 500 sx G cmt 7" 32# P-110 LTC Tied-Back from 10,536' liner to surface and cemented with 200 sx class G ' 9-5/8" 47# RS-90 & Soo-95 Protective at 11,119', cemented with 2,470 sx class G TOC in 7" 11,258' (Tagged and tested to 1,500 psi) Retainer at 11,350' F-1 Packer at 11,425' Perforations: 11,476' - 11,504' 11,512' - 11,564' 11,576' - 11,600' TOC, in 7" casing at 12,552' Retainer at 12,695' squeezed with 300 sx class G F-1 Packers at 12,775' & 12,772' 4-1/2" Liner Hanger at 12,848' 7" 35# P-110 LTC Production/Protective casing at 13,146' Perforations 13,426' - 13,560', squeezed with 350 sx class G Perforations 13,630' - 13,654', squeezed with 250 sx class G Perforations 13,666' - 13,706', squeezed with 100 sx class G 4-1/2" 15.1 P-110 LTC Production Liner at 13,757', cemented with 200 sx class G Well schematic is prepared by Fairweather E&P Inc. Last updated May-2009 • Bd~`` A~' oTAKED T ION forr ALASKA STATE C- I I T 9NI `reo Lat. 70°08~ 23.60° ~ -_ LonQ. l46° 14~ 29.89~~ 3 `- 2"- - - ~ -r` I ` X = 469932 ~ ~~,~,~` Y = 5900746 ~` ~ 6 rQund E isvation 25' = r -- - ~ - _ --~ - ~_a~ _ _ ~. 33 ~/2^ ~ ~o ~ ~~ ~ ,2 ~I ~~~~,. ~ a 8 I I. $ ~ ~ Propossd ' ~'~ ~ l} 'O otfom Hala `~'~~ g ~ ~ ~ Looation _ _ ~, _ ^ _ ~I 660' ......' -- ~~~9q~C.` ~ I 425Q~_- - ~----' ~ TRAIr - -- ( I I, 1~_.-'rrI-'14 I 13 , r 18 ~ IF \~~\I ` ~s I ~ "'tRP~R I I I 1` ,_-- ~ - -C----~--- ---i---~-- ~ ~ i i_ I 22 23 24 19 20 21 ; ~ ~ . ~ ~ `~ ..:~ ~ -- - „- -} - - - I : - - 1- - - ~ ~ ~ ~ ~ ` I ~ .:;:::r;,,_. '~ _ I 27 26 I 28 I 30 I ~ 29 I I I I ~ ,•"p' ~. _ ~_ _..~.. ~ I _ _ ~ - _ _ _e~ ~' ~# T~ - _ I ~ ~ ~ T ~~~c '' ~ I 34 ( 35 ( 36 ( 31 l 32y ~1 ! ~, 33 I W W I ~ : ~. <~ T9N I ~ ~I~ _. I ' ~ J ~ ~~~~ ~ ~ ~~~'~»'~S'~~~ 1~~= I Mile %y'~f'~' ~~';~,~'~ ~ *: 49T!+~ ~~:*~~ ,~~ :, ~ ... ......,. .~"~...o ••0 ~ ~' ~ ~ ~~;• •• •a• ~+•~•~ i~ Atld ~~ ttom Hole Locotibn _ 9-9-60 r -.:_, / ~ ~ Mdrew f. Potts • ~a ~ , ~ ~ f~'~',+~,.~: Hq. 3514•S .,:~~ ~ ~, ,~~ as- srnKEO we~~ ~ocarioN ; ,t~'~~''~.........::~;~s..° _ ALASKA STATE C- I ~~~fESS10~L~~~'~" ' ~--'r:. K_~ . ~~.~~ ` LOCATED.IN SECTION 14 T9 N. R 23 E. U.M. CERTIFICA7E OF SURVEYOR sustvEYED Fott I I hereby csrtity that I am propsrly ropiste~~d ond licansed ~ M proctic~ lond wrv~y~ny ~ths staf~. ot A~o~ko a~d t~wt th~~ EXXON COMPANY U. S. A. plot raprss~nt~ a bcoJion wrvey mads by me or under my direct aupavision and thai aN dstait~ an corroct. SURVEYEO BY Jew, 7~~lso ~,~,!(mw9:.~- BESSE, EPPS 8~ POTTS DQTE SURVEYOR ANCHORAG A 3-1 ' aa~E ~ i 7 ,~ ao ' _ ~ IA Alaska State C-1 well as left Y ~~ .~ `.~ ~- . ~. - N ' ~ ! I .~ ~ ~~ -. 1 ! i~, " q ' ~ ~ ' a {\ t I~ ~1~ . i, ~~ ~ ' ~,~.~ ~ . ~' , ~ . I ~ , . ~ , .' 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' .r e . :: iy K ~ , ' `•i"y.~ ~ ~ ' ' ,x- ~; ~~., - .v . , . . . . . - , . ~ ,•~r Y ~ M x ~~~,~~ ~~~~ y,M~~ ~ ~t,: .. a . . ~#~;,d ~ _. A'~. ~ ~ ~„~,: ~ - °.~• . ; ~'. _ , . , -, _ • , w . . ~ ~ ~ : ~ . : ~ ^ . , ,. _ : `.•,,~_ _ ~r ~, , . ,. . , ~ ,p .„ ~ „ , . . _ . .. ~ a~~, - • • - ~ ~ ~-~~ - ~ , r•- ~. ~ .~ .,; ~, - ,,, ..>~„ - •, .I s . - m , ~.: ,;.~~ ~ i, - _.~..: -- ,~~{ ~~,~ `•,a4,,,r'~' _ ~, .s r.wtn ~,., °'x`i • s ::~ i ~ , ~ ~ < <.~ _ 'X. ..r .~_. ~4_~.tn ... _.:.. ~ _ . ,..'. .. ~:r~ Alaska State C-1 wellhead as found ~~ < i .` >~-~~ 9!~ ~ ... °". 4 '~ . . .. ~: ~~.v _... (__._~ '-` ,~ S _ ~ ~ + ^ ~ ~t • ., - . /~~y ~ :~y : 4~ ~ . r. ''~}}~1g ~(^~'~ ~ ~~/ . .IV~C°id~l~J~'v~~J^~ ~ ~~~JJJUIG7 ~~ ~'~VJ~~ . ~'J 1H~Jua ~~~~l.W.l iLY\~~~.,~iE ~6s:~r\Y93:i ~'V0.11~.:J~i 3~.' ~~a~~~ i~~os?~a~, :i~s~~ ~~;, ?~fl9 ~J: ~? ;~;~,a ~°~o l;~a±~r,der, T~o~as ~ {~~~) ~~ab~~c~o ;~~: A~3~C~ ~a~r~dry ~3~~ic~ ~~~rr~s 3~~ ~~~y;^~~i~~i~~ ~=:c-~c; ,~:~.~a~rqc;~s Tom, the reports fo-r the 9 well inspection/remediation worl~ at Point T~omson left my office this afternoon. Thanks for your patience, I'm now 1oo:cinq ior contractors to ~id the work to for the next winter's work for the 3 we11 remediation efiort. Ii you have any questions regarding the recent work or next winter's anticipated s~ork, please call, Regards, Jack Maunder, Thomas E (DOA) Frorer Maunder, Thomas E (DOA) ~ent: Thursday, May 28, 2009 7:18 AM To: jack.a.rickner@exxonmobil.com Subject: RE: AOGCC Sundry No~ce Reports for Completed Field Acitivities Hi Jack, Thanks for the update. I will look forward to receiving the reports. I agree with your ~ntent to work to avoid the last min~~t.e crunch. ~ C;dll or message witn any details. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com Sent: Thursday, May 28, 2009 7:14 AM To: Maunder, Thomas E (DOA) Subject: AOGCC Sundry Notice Reports [mailto:jack.a.rickner@exxonmobil.com] for Completed Field Acitivities Tom, just a note to let you know I haven't been idle. Finally completed all the wellhead drawings, have all the attachments and photos together for all 9 wells. The package has been provided to our inhouse legal folks for there blessing. Hope to have their check off within a day or two. Will deliver to your office as soon as they catch my grammatical and spelling errors. Currently we are tentatively scheduling the summer stick picking work for July. Moving ahead on planning the winter remediation work for the PTU-4, West Staines #2, and the West Staines 18-9-23. Our current plans are to start the permitting, contracting, and procedure development (including which type of equipment to drill through the bridge plugs) this summer in hopes of avoiding a last minute crunch to obtain permits and equipment. That is our hope anyway. If you have any questions, please call. Regards, Jack Jack A. Rickner Pt. Thomson We11 Inspection & Remedia*ion Project 907-564-3783 281-217-4350 = ~~,~ _ ;;~, ~ i IVlaunder, 1'horr~as E ~DOA~ From: Maunder, Thomas E (DOA) Sent: Monday, May 11, 2009 8:18 AM To: Natasha Sachivichik Cc: jack.a.rickner@exxonmobil.com; Bili Penrose Subject: RE: PTU well inspection project AOGCC report status Thanks Natasha. That schedule should work. Tom fUlaunder, PE AOGCC From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] Sent: Monday, May 11, 2009 8:16 AM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e7oconmobil.com; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status To m, Sor~y for delayed reply. We should have the ~eports ready by the end of this we~k or beginning of the next week the latest. Thanks and regards, Natasha SacY~~vicln~le Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 07, 2009 12:29 PM To: Natasha Sachivichik Cc: jack.a.rickner@e~oconmobil.mm; Bill Penrose Subject: RE: PTU well inspection project AOGCC report status Natasha, et al, What sort of time frame are you looking at to submit all reports? I understand that submitting everything can help operational e~ciency. Tom From: Natasha Sachivichik [mailto:natasha.sachivichik@fairweather.com] Se~::: Th~~^5d8~, Mdy, n?~ 2n~9 11:14 aM To: Maunder, Thomas E (DOA) Cc: jack.a.rickner@e~oconmobil.com; Bill Penrose Subject: PTU well inspection project AOGCC report status 6/24/2009 /~~~ G, ,~n i i ~Pll~ I am w~riting in regards to the yesterday's phon~ conversation between you and Bill Penrose about the status of the Sundry repor~s for 9 wells inspection and rernediation project performed by ExxonlViobil. The field operations completed on April-29-2009. I would like to confirm that we are auvare of the 30 days requirement to submit the reports and are currently working on generating these reports. Could you please let me know if you would like a119 Sundry reports submitted at fihe same time. Thanks and regards, Natasl~a sach~v~c~~l2 Senior Drilling Engineer Fairweather E&P Services, Inc. 2000 East 88th Ave., Suite 200 Anchorage, Alaska 99507 Direct:907-343-0405 Cell: 907-575-7156 6/24/2009 Maunsler~ Th~mas E ~D~A) Fror~a: Maunder, Thomas E (DOA) Sent: Monday, March 23, 2009 10:14 AM To: jack.a.rickner@exxonmobil.com Cc: michael.d.murrey@exxonmobil.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Jack, et al, Following up on our conversation, it appears that options 1 and 2 should not present major issues. I concur that it is not desirable to have an open excavation. It is certainly possible that an excavation would collect melt water and what rain might fall. For this case, if you equip the well so that it can be monitored and then rebury some portion, this does not seem dissimilar to how the well structures have been for 20 - 30 years. I think that your finding the A section valve still functional after all these years should give some confidence that the damage risk from reburial is likely low. The final determination will be Exxon's based on the conditions determined for each well. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com] Sent: Sunday, March 22, 2009 4:33 PM To: Maunder, Thomas E (DOA) Cc: michael.d.murrey@exxonmobil.com; rob.g.dragnich@exxonmobil.com; mike.barker@exxonmobil.com Subject: RE: Wellhead Inspection Program Tom, we have a couple of concerns. From a safety standpoint, we would prefer not to leave an open excavation. And we are not sure if an open excavation would collect and retain water during the summer and then f~eeze as the temperatures cool. Not sure how this might ~mpact tubing and needle valves through time. At this point, we think that we have three scenarios. (1) The wellhead basically at or above ground/pad level. (2) the wellhead just at or slightly below pad level. (3) the wellhead below at perhaps 3-4 feet below pad/ground level. If the well head is above the normal grade of the well pad, we would install the new gate valve(s), flange with 1/2" NPT threads, needle valve(s}, and plug(s) in the end of the needle valve(s). That would allow us to read pressures in the summer time with relative ease. If the wellhead sections are just slightly below the pad level, we would like to leave the wellhead exposed and the valve(s) in place, flanged with needle valve(s) and plug(s) as above. There might be a slight dip in the surface of the pad but not significant. If the wellhead is some depth below grade (perhaps 3-4 feet), we have a number of options. It is this situation that I would like to discuss. We could: As proposed in our curren procesures, install new 3" gate valves (left in open positionj, tlange with lj2" needle valve (left in open position), install 3/8" stainless tubing to the surface and have a second needle valve present so that pressures could be read (needle valve left closed, gauge removed and plug inserted in needle valve opening). The tubing could be banded to the wellhead and to the above ground marker. we couid install che new ga~e valve (leit in closed position), flange; with 1/2" needle valve and a plug. After obLaining pressure reading, bury the gate valve(s) until the next time pressure readings are required. Again, an excavator would be required to gain access to the valves. Could leave the wellhead exposed with the walls of the excavated cellar sloped back at a shallow angle that would form more of a ramped walk way down to the wellhead. The valves could then be exposed for easy access. Valve handles could be chained or removed for security. The hole might resemble a depression that could be walked into and out of rather than a hole. The excavated area could be left open and return to at a later date to install a more conventional cellar if necessary. Valves installed and chained as above. If we found a well that did happen to have significant pressure that did not bleed off quickly, we would shut in well and contact our engineering group to decide on appropriate action including how to leave the well and confer with AOGCC. But on wellhead with no pressure or pressure that is quickly bled off, there are some concerns with leaving an open excavation as there are to leaving exposed wellhead sections, needle valves (with possible pressure that may build back with time), and marker posts. Would appreciate your views and input. Mike has discussed these options with our subject mater expert and with wellhead suppliers in Anchorage including Dave Craft with Cameron and Kevin Hite/Alan Mc Arthur with FMC. Mike, have I left out other options or would you like to add anything? Tom, as you know, we plan to remove the wellhead on the J-1 this winter and return to the area next winter to address the issues at PTU-4, west Staines #2, and the West Staines 18-9-23. The closure options for these three may not be as important as the others since we are scheduled to return and work on these. would appreciate any insight you may wish to share. Regards, Jack Jack A. Rickner Pt. Thomson Well Inspection & Remediation Project 907-564-3783 281-217-4350 Thomas E jack.a.rickner@exxonmobil.com Subject RE: Wellhead Inspection Program Hi Jack, I am in for a bit today. My preference would not to have valves buried nowever l do reaiize tnere is also a risk about surtace as well. What are your thoughts? Tom -----Original Message----- From: jack.a.rickner@exxonmobil.com [mailto:jack.a.rickner@exxonmobil.com~ "Maunder, 2 Sen~ a Sa_cur~ay; March 21, 2009 3:^ 1 Pi~I To: Maunder, Thomas E (DOA) Subj2ct: Wellhead Inspection Program Tom, would you be available Monday morning to discuss a question regarding ExxonMobil's Pt. Thomson nine well inspection and remediation program. If available, please phone me at either of the numbers below. I am only a few minutes from you office and would not take more than 30 minutes of your time. I would like to discuss the question of how to leave the wellheads, especially the question regarding valving arrangements (valves above grade to facilitate periodic checking of well pressures versus valves below grade and buried in gravel) If you are not available due to time constraints, please call and let me know. I'm scheduled to fly to Deadhorse Monday after lunch for Emergency Response Training and will not be available until Thursday. Your insight to this question would be appreciated. Regards, Jack Jack A. Rickner Pt. Thomson Well Inspection & Remediation Project 907-564-3783 281-217-4350 3 ~~ ~ ~~ ~ ~ ~ ~ ~ ~ ~~ ~~ ~ ; ~ ~~ ~ . ~ ~ ~ ~.~~ ~~ 4 7 ~ ~ ~ ~.~.. ~.~ ~-~~ _ l .~ l~ ~~ -~ AI.ASSA OIL A1~TD G~S CO1~T5ERQATIOrT COl-iI-IISSIOI~T Craig Haymes Alaska Production Manager E~onMobil Production Company PO Box 196601 Anchorage AK 99519-6601 Re: Exploration Well, Alaska State C-1 Sundry Number: 309-078 Dear Mr. Haymes: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval s~t out in the enclosed form. The Inspection Procedure document submitted with the well as "currently suspended." However, the status of tYus well accordin~ to the gfficial AOGCC records is still P&A, although as the Commission pointed out in previous correspondence this is one of several wells so classified that appear not to meet all of the applicable regulatory requu-ements for ~~lu~;ged and abandoned wells. We appreciate your inspection efforts as described in the application. ExxonMobil has submitted a request to chan~e the classification of this well to suspended ~tatus, but the Commission has not yet acted on thut request. Approval of this inspectian work proposal does not constitute or imply a decision an the request to change the well classification. When providing no~ice 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 deeision, or such further time as the Comnussion grants for good cause shown, a person af~'ected by it may file with the Commission an application for rehearing. A request for rehearin,g is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of March, 2009 Encl. ~ ~~f~~ ~ STATE OF ALASKA ~~ ~ ~~~ ~~~~ ~9 ' ,~ ~~D~ ALASKA OIL AND GAS CONSERVATION COM ~ , Od~ll ~ '~OOg ,5 ~ ` ~' APPUCATION FOR SUNDRY APPRMO~ALS ~ ~ 20 ,4aC 2szso p_~,~;~ ~~~~ ,~~ ~;~~ ~,~r~~. ~'~~rr--ss~a~ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ~ Perforatet'~~t0~c~~ Waiver^ ~ Other^~ Alter casing~ Repair well ^ Plug Perforations ^ Stimulate ^ Time E~ension ~ Site inspection Change approved program ^ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ / 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ExXOn Mobil Corporation Development ~ Exploratory ~ 7t'E0~4C-180O~~ 3. Address: Stratigraphic ~ Service ~ 6. API Number: PO Box 196601 Anchorage, AK 99519-6601 50-089-20011 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes ^ No ^ Alaska State C No 1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 28382 ~ 54 ' Wildcat 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,761 , 13,243 ~ Surface Surface See Attached None Casing Length Size MD ND Burst Collapse Structural Conductor 784' 20" 813' 813' 1530 520 SurFace 3964' 13 3/8" 3993' 3993' 5380 2670 Intermediate 11090' 9 5/8" 11119' 10737' 7720 I 7290 499017100 Production 10646' 7" 13146' 12639' 12460I13700 10760113010 Liner 909' 41/2" 13757' = 13239' 14420 14320 PerForation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A NIA N/A NIA NIA Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory Q~ Development ^ Service ~ 15. Estimated Date for 16. Well Status after proposed work: March 1, 2009 Commencing Operations: ~ Oil ^ Gas ~ Plugged ^ Abandoned Q 17.VerbalApproval: Date: WAG ^ GINJ ~ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker I Jack Rickner Printed Name Craig: Haymes Title Alaska Production Manager ' Phone (907) 564-3617/(907) 564-3783 Date Signature ~ ~ 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 ^ ~~ ~ ~~~ ~~~~ F~`~'~ ~ 'b Other: ~ ~iQ ~-,~ v.' C ~~~o~~cJc~c._.vi~f'c'h~\~~v.~~c~~.~~ccs~~ cA~~C` ~cc`~CG~~~r7~ p Subsequent Form Required: ~~~ ~~ ~~~~~~d ~ Q~ ~~°~S y~~y~~ APPROVED BY e < ~ ~ ~ : COMMISSIONER THE COMMISSION Date: roved b A pp y , Form 1~403 Revised 06/2006 ' ' '. ~ Submft fn Dupucate . . .. ~ .. ... r ` i ~~,.~. ExxonMobil Production Company P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile Craig A. Haymes ~ ~ ~ ~"~ ~ ~ k Alaska Production Man g ~`""""~ Jt. Interest U.S. ~EE~ `~ ~ i'_L'~'~ ~4i~5ka C~I ~ G~~ ~~r~~ . ~'~ ~' . _;... Arr~~h~r~~~ ~ebruary 25, 2009 Mr. Dan Seamount Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Ar~chorage, Alaska 99501 Re: Sundry Application to Inspect Exxon Mobil Corporation Alaska State C-1 PTD No. 180-046 Dear Commissioner Seamount: E~onMobil Production Exxon Mobil Corporation hereby submits an Application for Sundry Approval to perform a surFace inspection of the subject well. This inspection will assist in long=term well monitoring. No well work is anticip~ted at this time. Tfie top of the well will be exposed by excavating gravel covering it to allow verification of the well integrity by checking f~r and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus. The wellhead configuration may be modified to allow easier access for regular welfhead inspections in the future. Please find enclosed the following information: 1) Form 10-403 Application for Sundry Approval 2) Wellbore Schematic 3) Inspection Procedure 4) Photo of the Wellhead/Abandonment Marker at Present If you have any questions or require additional information, please contact Mike Barker at 564-3617 or Jack Rickner at 564-3783. Sincerely, ~ ~ ...~ ~ ~ CAH:eaa Attachments A Division of Exxon Mobil Corporation Exxan h4abil Garporatian Alaska 5ta~ C-1 VWe 1 I 5c he matic A~PI #: 50D8920011G000 APTQ#: 180-0.k~ ~lr_'itiesd A secta~n ~n asoe •a~th 13-5 S'f49,v~~ CO'?'109!10~1 f:9'Ma°_ 9't~ ^l8!PC?' U052 ~'1 20.? Pa~9f~o~2 ~e^-~~r[ a-~a7 o~i ~n 9-5 8' ~s~~r~ 'u: ~n 13~~8~° cs~;n•a gt2.2Ja" _ :~ c'~' ~4= ~ S3*: ~..a+i~~t~t~.•st ~18", BP st 2,4~5 ~,t~+tn t~0 5ac ~^~nsfr~sta~ v ; ~°"-~"~~`~ °•'~~^~r 3.5~ ~c n~ ~ ~ toP 9T2.~J~ . Tested b 15~ as;. ~ T' 9-5~$' x 13-3~~$' snnuius cer.~e~~~ f~m ~;: ~i :- cea~~~ Y.12 9"i~ •a.~Va.~+~ f•am 2.5~~ 2,925' b 3.993' s~~faiie~ •.ti~€t't s~tie ~ ~ ` psckfr~m~.925' b s~rfs^e 13-3,8. ~7~ squ~zed i,z~~^.,e ~.ys~ 3~~ t~ - 13-38' +2+~ t~YB~ 6T4 ~Jfis•~ ~s;na st 3.393 . Sx c6s~s G¢ec~ ;, `~ xy .~^rw_~s~~ •~r~R:~r +.85~7 ~x ~~~9f~~si 9~rJ 5~D sx v:;s~~ G l , ~~S ,.e ^-w_ ~t ~: " 32~ P-11 ~ L?C T~~-B9c+c fro^i 1~.536' 'si~er b sil~~e ; `~ 9'1 ~ •S_ ^"F?'St1°Cj '.ti'tC!'I ~ ~ 53C Gi955 ~ t ~ 9-5~$~ 5Ci~E rsail°_?~~ T,+~~~^..~ ,~~~7 3~; Sx `~-5 $' 4;?~ R5-9~ 3 5~~-95 P~~t?ct=,~ st 11,118'. ~less C; es~.n s~r~ ~nfle ~,+rAh 4~~ Sx c~sa= _ ;; 'w'~ se^^~~~~i •~s~~ 2,4;'~ sac c~ess G >' ; ~'. ,~,~ . ~.: .-~ -v ~ ~ a. 1 i.258 `~s~~e~ s~i t~~~ll to 1.5~ ~s~~,~ :;~t ?229'1B.' St 11.~~ ~ ~ '" a . >M 1• "; =-1 Pscke•et 11.425 > ~ ' ~5 ~~ "r ~, : ~ ~, " ~erfo~9Teans: 11.4,'5 - 1 1.~4 1~.4 aa nnud }~ '~~ Y ~ 11.512 - 11.564'~ ~yu~ez~eel >u~tti 3~ s~c cdesa G ~ ? i 11.5,'$ - 11.~~' htud ~!~~rfse~e ~st 1 1.$4~5~ ; ~ ,,,~,,,-,..-~ ~~;, 15.5 ~o~ ~u~l ," ' x - - >~ _ _ . m , ^~ =. ""~ +' ~s,~a et 12,552` ,;h~at ~~ed. 1~stacf 1a ~~.~~'J ps€,~ ~cets~~w_• st 12,~35 F-1 Pec~ce~ gt 12."5' 3 12'-~` ~" isn~r ~~p s~w_~~~ t~4~~ > ~~ °~ ; 4-1 ~Z" L~n~~ F~en~~ et 12.848 '~y'Rh 4~;.1 ~x v~9: s ~', ae.;h ~. ~",:i : _ ti ~. '~, ~` ~ ' '~5~ P-11~~ LT,^..~ Pradu~to~~?~~,t~~:ti~ae ~gan~ et 13,9 ~fi' r~ . ` ' ~e~fo•eto ~a t 3.~25' - 13.5aii . ~ : '~~, , ~ 5.~' __ sa~~zecl •,~°~th 35~7 sx c.ess G i 5.5 ~py~ r~-iud P+~rforeto~~ 13.a~~ - 13.~54 , ~a~mz~ -.ti~c~ 2~a ~ ~;9~~ ~ -^~ ~, ~-~ ~~ ~a~~~ ~c ya.~a Pe~f~•eto~s 13.65v - 13,-a5 . ~a.,~z~d ,s~~ ~ ~ a~ ~ ~,9» c ~~~* 4-t 2' 15.1 P-110 LT~ P^aiJ :? a~ ~~~~ 91 ?at8; C~epth 13.'S1 13.'5''. ~^~~t_ai °.t°th ~~~ ~x ~ s~s U Well schematic drawn June 29th, 2007 by Jesse Mohrbacher, Fairvveather E& P Services, Inc. E~ocon Mobil Corporation Alaska State C-1 API #: 50-089-20011 PTD #: 180-046 Inspection Procedure Backqround Well Information The Alaska State C-1 well was drilled in 1981. The well is currently suspended, but requires an inspection to verify its condition and continuing compliance with conditions of maintaining its suspended well status. Based on the well files, the 9-5/8" casing has a cement plug set at 0'-60', there is 10.2 ppg CaCl2 brine below it. A bridge plug is set at 2,405' with top of cement at 2,200'. The 9-5/8" x 13-3/8" annulus contains arctic pack from surFace to approximately 2,925' and cement plug from 2,925' to 3,993'. The well schematic is attached to this procedure. The reservoir section of the well is effectively isolated; therefore it is unlikely that high pressure will be encountered during the inspection. However, contingency plans and procedures will be included in the detailed inspection procedure to safely manage any well pressure encountered. The inspection will include the following steps: • General inspection of the well location to the extent possible (winter operations) • Excavation of gravel covering the wellhead and cellar • Visual inspection as to the condition of the wellhead • Verification of the well integrity by checking for and recording pressures in the 9-5/8" casing and the 9-5/8 x 13-3/8" annulus o Perform diagnostic test if pressure is found (i.e., trapped vs sustained pressure) o Identify contents of the casing and annulus by attempting to get a sample • Clean up of location and leave well in a safe and secure condition The proposed inspection will be supported by on-site equipment and materials such as excavator, camp, transportation, fuel and other essential elements of remote operations. The following well inspection program is planned: 1. Insure all necessary permits and applications are in place. Notify AOGCC at least 10 days hours before operations begin. 2. Mobilize all personnel and equipment to the Alaska State C-1 location. 3. Observe and record any signs of leaks in the area surrounding the well. Take photographs clearly showing the condition of the surrounding location. A detailed report documenting any found contamination will be prepared. 4. Heat the gravel around the wellhead. 5. Excavate gravel covering the well and cellar. Ensure access to all side outlets on wellhead sections. Monitor excavation with a four-gas monitor. 6. Install wellhead shelter, and rig up indirect fired hot air heater. Apply heat to wellhead shelter. Pump or vacuum the cellar dry when thawed. 7. Visually inspect the condition of wellhead side outlets valves, bull plugs, needle valves, test/grease ports, lock down screws, etc. Take photographs clearly showing the condition of the wellhead as found. Document any areas of concern. 8. Check pressures on the 9-5/8" casing and the 9-5/8" x 13-3/8" annulus. This may require the installation of needle valves and wellhead side out valves to facilitate recording and bleeding off pressures. In addition, operations such as removing VR plugs, hot tapping, and gate valve milling may be required to verify any well pressure. 9. If pressure is observed, then perForm diagnostic testing to determine if the pressure is sustained casing pressure or trapped pressure. Record pressure bleed down and build up. In addition, record the fluid type and volume. Take fluid samples for possible analysis. 10. Take photographs clearly showing the condition of the wellhead as left. Backfill the cellar with gravel with allowance for gravel settling with time. 11. Ensure well is safe and secure. Chain 8~ lock close any valves above ground level. 12. Clean up location. Remove any fluid from the well for proper disposal. Take photographs clearly showing the condition of the location as left. 13. Fill out inspection report and file a Report of Sundry Well Operations (Form 10-404). Exxon Mobil Corporation Alaska State C-1 API #: 50-089-20011 PTD #: 180-046 ~. a,.~ . - - < i~ ' .... , ~"_:..~~~,. ~,'~„'~'; ~.~. =~-~ " ~ ,~..~..,.~.~ ~.~ ~ :.:..,. ,~,~-v.-,.~ .~ ~:~..~ ~ _~ _ .~.y~ r . c „ . ~.~ ~ K.`..'~"' -,+-.- .. # .,.~ ~,,~ ,i1.T""Q~ + ..~ ~Y . '~.3~..ar, ._ . ._ _ . ' # . i.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEi~/E MAR 1 ~ 20~$ 1. Operations Abandon Repair Well Plug Perforations Stimulate r t c' PerFormed: Alter Casing ^ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension [~('~hOt~e Change Approved Program ^ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well [~ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ExxonMobil Production Company Development ^ Exploratory0 . ` ~ -o~~ 80-46 3. Address: PO Box 196601 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6601 50-089-20011 ' 7. KB Elevation (ft): 9. Well Name and Number: 54 ' Alaska State C No 1. 8. Property Designation: 10. Field/Pool(s): ADL 28382 ' Wildcat ' 11. Present Well Condition Summary: Total Depth measured 13761 ' feet Plugs (measured) See Attached true vertical 13243 , feet Junk (measured) None Effective Depth measured Surface feet true vertical Surface feet Casing Length Size MD TVD Burst Coliapse Structural Conductor 784' 20" 813' 813' 1530 520 Surface 3964' 13 3l8" 3993' 3993' S380 2670 Intermediate 11090' 9 5/8" 11119' 10737' 7720 / 7290 4990 / 7100 Production 10646' 7" 13146' 12639' 12460 / 13700 10760113010 Liner 909' 4 1/2" 13757' = 13239' 14420 14320 Perforation depth: Measured depth: 13666-13706, 13426-13560, 13630-13654, 11476-11504, 11512-11564, 11576-11600 True Vertical depth: 13152-13191, 12913-13045, 13114-13138, 11061-11086, 11093-11141, 11152-11174 Tubing: (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) Baker Model F1, 3 ea Baker F-1 @ 11425', 12772' 8~ 12775' Retainers @ 12695' 8~ 11350' CIBP @ 2405' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^~ • Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: Oil Q • Gas ^ WAG ^ GINJ ^ W~NJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt; Contact William C. Pecor Printed Name Willliam C. Pecor Title Point Thomson Coordinator Signature W~ ~_~ ~~tG~_ Phone (907) 564-3766 Date ~ ¢(jg ~ Form 10-404 Revised 04/2006 ~ ~j~~ S~t mit Original Only . ct=~~1/ ~ / ~,~ja~ ,t'~ ;~ ~L . i,.`~.-'. l~~t ` ~j Exxon Mobil Corporation Alaska State C-1 Well Schematic API #: 50089200110000 APTD#: 180-046 Wellhead A section in place with 13-5/8" flange, companion flange and marker post on top - ~.. ,:~ Permafrost cement 0'-60' BGL in 9-5/8" casing 10.2 ppg CaCiZ TOC in 13-3/8" casing at 2,200' ' s~ ~ 20" 94# H-40 STC Conductor at 813', e ,,,, ; cemented with 3,500 sx BP at 2,405' with 100 sx permafrost on s. h top at 2,200'. Tested to 1500 psi. ~, , 9-5/8" x 13-3/8" annulus cemented from + `~~ 7" casing cut and recovered from 2 500' 2,925' to 3,993' and filled with arctic , ~« pack from 2,925" to surface ; w'~ 13-3/8" shoe s ueezed twice with 300 9 13.3 ~ y 13-3/8" 72# N-80 BTC surface casing at 3,993', Sx class G each ~% mud ~ cemented with 4,850 sx permafrost and 500 sx class G ~ cement 's 7" 32# P-110 LTC Tied-Back from 10,536' liner to surtace ~ ~~ ~ and cemented with 200 sx class G 9-5/8" shoe squeezed twice with 300 Sx class G each and once with 400 Sx class G •t 9-5/8" 47# RS-90 8~ Soo-95 Protective at 11,119', 'a ~; .~ cemented with 2,470 sx class G i r; ;"; ~~, ~ TOC in 7" 11,258' (Tagged and tested to 1,500 psi) , * ~ r . ,~ Retainer at 11,350' , r' ~ , z ' z F-1 Packer at 11,425' a i; ~ '' r Pertorations: 11,476' - 11,504'1 ' ' 13.4 ppg mud z 11,512 - 11,564 rsqueezed with 300 sx class G Mud interface at 11,846' r~ ,~ 11,576' - 11,600' ~ 15.5 ppg mud ~. . z TOC in 7" casin at 12 552' N t t d t , g , ( o agge , ested to 7,000 psi) ? Q Retainer at 12,695' ~ z F-1 Packers at 12,775' 8~ 12,772' 7" liner lap squeezed twice ~ ;~ 4-1/2" liner Hanger at 12,848' with 400 sx class G each ~~ ~e ' t 7" 35# P-110 LTC Production/Protective casing at 13,146' ~ - ~s ~ t Pertorations 13,426' - 13,560', s,•~ , squeezed with 350 sx class G 15.5 ppg mud Perforations 13,630' - 13,654', squeezed with 250 sx class G TOC in 4-1/2" liner at 13,660' : Perforations 13,666' -13,706', '' squeezed with 100 sx class G 5~ 5 5 s 4-1/2" 15.1 P-110 LTC Production Liner at Total Depth 13,761' 13,757', cemented with 200 sx class G Well schematic drawn June 29'", 2007 by Jesse Mohrbacher, Fainveather E& P Services, Inc. Alaska State C-1 Drillsite Inspection August 22, 2007 This drillsite inspection occurred on August 22, 2007. As can be seen from the attached photographs, weather conditions were moderate (around 60 degrees F) and clear, allowing for good viewing conditions. There were no visible indications of well integrity problems nor were there indications of oil spills or stains on the pads and surrounding surface waters. The pad was level and did not exhibit signs of thermokarsting; foam insulation was used in its construction. The wellheads were below pad level and there was not an appreciable amount of gravel mounding over them. There was one small pipe pile in a stream adjacent to the pad that protruded about a foot above the water level. Some exposed foam insulation and liner material was observed around the edges and pieces of insulation were on the nearby tundra. There was a significant amount of vegetation growing on the pad. There was a significant amount of surface waters surrounding the pad and no hydrocarbon sheens were observed. . ~ ~, ~~ : _.. ~~ - ~ ,~K~ ~ : "` ~ S f ~ ' ,~ f' t : P 7 F jk ~ ~ "} i s ~'~t.~ .1.` . ~ 4 . #' '~ ~~ ~ F~~~ ... Alaska State C - 1 -1- ~'- ~,~ ' 4 . . . .•~ ~...~~~. ' .'~',d7/M ~ . . . ' • - . . .. . . ." . `~r . ~ ~ ..,+ ' ~ [ .' i ~ - ~ ~'F' .i: Y~L - • t , ~ ~ ~~ ~ ' ~. ~'~' .n ~ - ' ~ ~' ' ~ d d '~"~ ~4"'r k .i~~'7L Jj'~. ~.. Y,~' s. ' Y ._ ~r ~t .. 1 ' A `~°~ A! . ~. y' i .. ~~.~ 'w_• . , \.~ ~ ~S ~ ~'~~ ~ j . `~•'' ~.. ~ ~ .e .:i . .~ . . Y _ • ' • _ ~ " ~~ , ~. _ ~Nyf~~ .. ~ + ~ ~ M~ • . ~y"Y~1'j "r.. , fr s'~ ~ - ~ . ~_.~_ ` . ~ y .~ ~ s. ~4~. . .._ ' ~ .~t.. . . .~: 1 -~~. . .. ~ J~.~9'L .,V ...f ti ~~` ~~~ V ':~!~•'. ~ s l ~ ~'~ ,. ,r - - , . __~ _ - --~°~:~...- -_~::~ - , ~~ _ ''J,' w.e ' .- . 'z ~It ~ P..d.: ~ ~ ~ .. . . .. ... . . ~-~ . ~ - ~ t 's,~~ .. .,n °~ ~ ;S"F" r' c «_ . ~ ~ ~ ,3 '^r_.i • ~ 1'~9 ~ 4 . . . t~. ,'~A0. . ~ Mt*' ~.~.yfr.'~.,. `r+~r . ,..'i _> Ny ' ~ ~ t~~ ~ F5 ~ ~C " ^m y ~ 8 7 ^ ,~` ~G 3 "' k ~C ~+~ ^N §;. :.^. Y ` ~ Y_. , w . ~ u. ~ i . •~ .4T'~:+~ .J' 1 N .~ yf+ ~ ` ~~ ~~ ~ ~ . ~~ ~~ ' ~~ g}~ ~'r. , ~ .`<-~ ~~!=Htw +~r ~ = ~ ..,~~ R~ ~ `~' _ • ~ c..`. at ~ ~ ~ i .~ •~a ~ ~': ~ ....¢. e ~ ~ r.,~ -. .,y, A '. yy:' 4 ~..,~~ Y y_ ~ . ,K '+ ~.': . ,~L c:s- ~:- ` -c-,~_r ~ ~ ~.~i ~ 4!'~;4 ~ "~ .r , s~1 ~ ' q~; ~ . . ~ ~ ' x~Fr ~ . ~~ ,T ~,>r`' x ~ ~» ~ ^ +t ' Si ~~lq. .~~•~"~..y„y ,I~ ~~ ' ~~.'r~ '~`1'~~ ~ .. ._ 7 .~ ~ '~y~1~: t..~t Alaska State C -1 ~~ ,~r~~ ~ ' ~ ~ , ,. ,-~ ` ~ ~ - . . , t'.'r '" 1' y ~. , :.Y ~ . • : ~'• - ' (, ~ . - . . ~ . . . . '. . ; .: ~ + ~ . , Y r. .. . ..;~r: . .. - F, i ~ ~ ~ ' ~ .. , _ ~ ~. •, ' ~, i~ ~~~1 ~: y , ' ,, ~ '• ~._.if9-; `~ ~ ~ . . ~ .,s .. .. Alaska State C -1 -2- M -~! M~ - -~-~' :-"'~r~. ~~7i ~~,~~ .r- . -- . .'-. ~' = .-'{ ~' ..~ . ~ . - ' - _.. ~ ~..~. ...~er~ ...+ I, ,- . ~': ..~..... - " _;ab:.... ~ ' rs/r,~ ,s~ s~ ~r,?,~-~~ .Tr,Y~i .,' .. ~,`^ ~ t .. .. ' >af~ti~.~? Alaska State C - 1 -3- ~.~~ .-_ _ .----~_-. +~r`,~.... ~, ~ r , ..~ ~ . . ~ ... ~. ~p,~`~r~u':4~?~ ' " ~.. ` _ _. . ~.: y ~ -:=r~aGy55'~,;Z: s~+Mrr « . ,. ,.. . .~, . '~.~.. ,. ~~~.~,. ~„t . ~. ~ ~~M7.Y~`:' , . ~ .. .7, ., ' Z' "t ~ ~ 1'7„~ i-'c r~~., " _';'F .~ 6jrt ,.~ s~~ F j.,~ a~. i N ) ; ~J~ r ~R~` : -r:~ ~ ~ ~ ~ ~~ ~~t f . ~+~; ~1~-~~' i ~ ~ a~~ '~d , ~~~' ~ ~ ~~71 ~ :~ . . " i ` .. .~Lj ,~T "i r'y~4 f .-y, ~r, ~S( j'4~ ~,~+ ,F ~ . ~.,! ~ '•fL 'd~:.A~ l'.:n? $ ,. _, STATE OF ALASKA �fJ ' MAR 1 8 2008 ALASKA OIL AND GAS CONSERVATION COMMISSIO / APPLICATION FOR SUNDRY APPROVAL 0o&Gas Cons.Commission 20 AAC 25.280 1.Type of Request: Abandon❑ ❑Suspend J Operational shutdown p p ❑ Perforate ❑ Waiver[N n' raCY Other❑ Alter casing Repair well ❑ Plug Perforations❑ Stimulate ❑ Time Extension 0 Change approved prograrr❑ Pull Tubing❑ Perforate New Pool 0 Re-enter Suspended Well ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: IgID0q(00 ExxonMobil Production Company Development 0 Exploratory ,e - 8046 • J 3.Address: Stratigraphic ❑ Service ❑ 6„ I Number: PO Box 196601 Anchorage,AK 99519-6601 50-089-20011 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: N/A Spacing Exception Required? Yes 0 No ❑ �� ' Alaska State C No 1 9.Property Designation: 10.KB Elevation(ft): 11.F;-I:':'.ol(s): ADL 28382 54 Wildcat 12. PRESENT WELL CONDITIONS 1, ARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective le"• TVD(ft): Plugs(measured): Junk(measured): 13,761 13,243 Surface -urf a See Attached None Casing Length Size MD Y TVD Burst Collapse Structural Conductor 784' 20" ,,, 813' 1530 520 Surface 3964' 13 3/8” ••3' 3993' 5380 2670 Intermediate 11090' 9 5/8" '11(117' 10737' 7720/7290 4990/7100 Production 10646' 7" 131 /4G' 12639' 12460/13700 10760/13010 Liner 909' 4 1/2" 1377\` 13239' 14420 14320 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tu.i • i 7 Tubing Grade: Tubing MD(ft): 13666-13706,13426-13560, 13152-13191,12913-13045, 41 N/A N/A N/A 13630-13654,11476-11504, 13114-13138,11061-11086, 4 11512-11564,11576-11600 11093-11141,11152-11174 •E Packers and SSSV Type: Baker F-1 Pack•r- 4 ea Packers and SSSV MD(ft): Baker F-1 @ 11425',12772'&12775 Retainers @ 12695'&11350' CIBP @ 2405' 13.Attachments: Description Summary of Pro l ❑ 14.Well Class after proposed work: Detailed Operations Program 0 BOP Sket 0 Exploratory ❑J Development 0 Service 0 15.Estimated Date for 16.Well Status after proposed work: r Commencing Operations: Oil ❑J Gas ❑ Plugged ❑ Abandoned 0 17.Verbal Approval: Date• WAG ❑ GINJ 0 WINJ 0 WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true an correct to the best of my knowledge. Contact Rob Dragnich(907)564-3711 Printed Name William C.Pecor Title Point Thomson Coordinator Signature �� Phone (907)564-3766 Date COMMISSION USE ONLY Conditions of approval: Notify Corn ission so that a representative may witness Sundry Number: 0 y_ 1/9 Plug Integrity ❑ OP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ > Other: Subsequent Form Required: C.)--.„ �, -O('y� c�� \ Ar 2016.._ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ° RIG ! RBDMS Lk- FEB 1 1 2016 NA I Submit in Duplicate k,4a7'rA 17 2008 E—on a1-45 o :commissioner Dan Seamoun'. RECEIVED Alaska Cil and Gas Conservation Commssion 333 West 7th Avenue, Suite 100 MJ,; ?On Alaska 99501-3539 wiga Re: Pt. Thomson Wells — Plugging and Abandonment GaAlaska 041& on .Com mi Anchorage Dear Commissioner Seamount: In response to the Commission's December 7, 2007, letter to ExxonMobil, attached are sundry notices requesting the Staines River State No. 1, Alaska State C-1, and Point Thomson Unit No.'s 1, 2, and 3 wells be reclassified from abandoned to suspended status. Site inspection sundry notices, Form 10-404 reports and photos, are also attached for these five wells and the Point Thomson No 4, Alaska State J-1, West Staines No 18-9-23, and West Staines No. 2 wells. We are making plans to conduct the inspection and remediation work described in ExxonMobil's letter of November 14, 2007, and the Commission's December 7 letter during the winter of 2008-'09. As you know, we submitted a Plan of Development for PTU to the Department of Natural Resources that calls for drilling operations to be conducted during the winter of 2008-'09. Approval of this plan by DNR will afford the opportunity to conduct the well remediation work described in our November 14 letter in conjunction with that drilling plan. We share the Commission's desire to conduct the remediation work in a timely and date certain manner, but we would like the opportunity to revisit the timing of the remedial work if the drilling program does not proceed as currently planned. \Ne believe there are operational safety and efficiency factors that should be considered. Please note the Staines River State #1 well is under extended confidentiality as provided under AS 31.05.035(d) and 20 AAC 25.537(b). We have included its report as a separate, confidential attachment. We again thank the Commission for providing clarity around the issues and for providing adequate time for ExxonlVlobil to conduct a thorough and thoughtful review. Please feel free to contact me, Bill Pecor, or Rob Dragnich if you have any questions, Sincerer,:-. Ac<7 .AAtachrxents Mark :;eland; ConocoPhillips Vince LeMieL.x, Chevron Davies, Stephen F (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 15, 2008 8:10 AM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA); Norman, John K(DOA); 'Mintz, Robert E.' Cc: Davies, Stephen F (DOA); Roby, David S (DOA) Subject: FW: Permit to Drill and Sundry Applications All, Here is the reply to my message of last week to Rob Dragnich. Tom Original Message From: rob.g.dragnich@exxonmobil.com [mailto:rob.g.dragnich@exxonmobil.com] Sent: Friday, December 12, 2008 5 :23 PM To: Maunder, Thomas E (DOA) Subject: Re: Permit to Drill and Sundry Applications Tom, thank you for your note and for your time yesterday. In response to your questions: 1. We request the AOGCC initially process the APDs for the PTU 15 and PTU 16 wells. As you probably know, state and North Slope Borough seasonal drilling restrictions will only allow drilling deeper sections of the wells during the time period from November 1 to April 15 of each year. To maximize utilization of the drilling rig, an option we are evaluating is drilling the surface hole sections of both PTU 15 and PTU 16, before proceeding to the protective and production sections of the wells. Those portions of the 'wells could be drilled outside the seasonal window. We request the AOGCC keep the remaining permit applications in the active file, but not process them at this time considering the 24 month effective period from the date of approval for the permits. We will contact you in the future, when we need the additional permit applications processed, once we have further details on the order of the drilling program after the first two wells. We also would like to discuss with the AOGCC whether a spacing exception would be required for the PTU 15 well. PTU 15 is planned to be a gas injection well, but we might do some production testing as described in the drilling program for the well. The wellbore will be about 1150 feet from the lease line at the top of the Thomson Sand Formation, roughly 1000 feet at the bottomhole location. Would a spacing exception be necessary for this well? 2. Some of the March 2007 permit applications have the same bottomhole location as those filed in July 2008. While we would not drill two wells to the same bottomhole location, we request the AOGCC keep all applications in the active file until a determination is made as to which wells will be drilled from which surface locations. We would provide a reasonable amount of notice to the AOGCC before we needed approval of a particular permit application as noted above. 3 . We're working on the permit applications for the well inspection and remediation work. We expect to submit the North Slope Borough permit application this month (will send the AOGCC a copy of it) . The sundry notice applications should be submitted in January 2009. Thanks again. Please call if I can further clarify any of the above. And have a great Christmas & Happy New Year if I don't talk to you before the new year. Regards, Rob Dragnich 907-564-3711 (office) 907-564-3789 (fax) 907-830-4796 (cell) rob.g.dragnich@exxonmobil.com 1 1/27/2009 3:35 PM "Maunder, Thomas E (DOA) " To <tom.maunder@a rob.g.dragnich@exxonmobil.com laska.gov> cc Subject 12/11/2008 Permit to Drill and Sundry 03 :38 PM Applications Rob, ExxonMobil has on two occasions in the past year or so submitted a total of 16 Form 10-401 Permit to Drill (PTD) applications for new wells in the Pt. Thomson area. 7 permits (PTU #7 - PTU #13) were submitted March 30, 2007 and 9 additional permits (PTU #14 - PTU #22) were submitted July 10, 2008. We have the following questions: 1. If the Commission processes these applications, which permits need to be processed for the 2008 - 2009 drilling season? Which permits need to be processed for the 2009 - 2010 drilling season? 2 . Do any of the applications submitted July 10, 2008 replace any of the applications submitted March 30, 2007. 3 . When can we expect to receive the Form 10-403 Sundry Applications for the 4 legacy wells to be abandoned? Please respond to me with your reply. Tom Maunder, PE AOGCC 2 1/27/2009 3:35 PM ~, - J . , _. ..:..i 'F;-, -.. ~.:, ~~~. `~.v7 ~~ 'tv3% ~,. r ~ ~~~_2~~~ 3~ =r ~:,~ '~.u ~~~ ~ `~~~~~~T .{~ ~~ n?r~-- ~~i ~i'f.~~~~~ ~;,'-~ ~~ ~ ~F,~ , Z~ ~±`-~' ,-'t3' ~~3 z ~;.!wSi~3 €`~~" 1C_1i.[~'Ci ;k' 1~t~E,g~~i- ~..~:eon'i`.'~c~ui; ~~ro~~ir_~ion ~ ompan, :'v~ ~ox ~ y6~~' ~ ~;tchcrage; ~I~ 99~ i ~ R~ t t. ?~homson V~ielEs - Pl;agging and Abandonment I)ear i~/f,~. ~-iaymes.; 3~"s !, "r a~.r~i~Jc S~ „ ,,i~!~,i JR:'~,'~, .}~IC ,~ ~.., P`i^?!E .- ='9-` ^~_. ~=~)' :., _ ~, _-_ This is in ~espons~ to your letter of NUVember 14; 2007 responding to the A(aska Oil and Gas Conservatian Commission's ("Commission"} letter of iV1ay 18, 2007 regarding the condition of certain Pt. Thomson Unit wells. The schedule and plan for remedial work p~-ovided with your letter are acceptable subject to the follo~e~ing conditions: 1. ~~conl!/~obil will perform ~he proposed fie(d work for the 200~ - 2009 winter operating season regardless of whether there are any concurrent drilling operations in the Pt. Thomson ~.`nit. 2. All of the diesel will be removed from the VV. Staines State #18-9-23 (169-120) and W". Staines State #2 ( I 75-002) w~ells. [f any of the diesel cannot 6e removed, a Commission petroleum engineer or inspector shall determine whether the shallow wellbore p(ugs are competent, and ExxonMobi! must take any reasonable actions the Commission determines are necessary. 3. All current and future statutory and regulatory requirements and all applicable rules, orders, and permits of the Commission will be complied with unless a waiver to a specific requirement is timely and otherwise properly requested and granted by the Commission. To assist the Commission in ensuring that its ~ifes are complete and accurate, by March 31, 2008, please submit for each well a Form 10-404, a summary of the o6serva~ions from the work performed last summere ar~d location photos. F~nally, nothing above expressly or implicitly evidences the Commission's position with respect to the status of ~:xxonll~~obi) or an~ other person as a current Pt. Thomson Unit operator, working interest o~vner, or lessee. Ii you I?ave an~c qu~stions_ please ea(1 ;ne at 793~-!?2 f or Tom ~~aunder, PE at 793-12~Q. ~incereib, ~ ~~~ ~~~~ o ~~ ~~~ ~ f~~~~ ~ ~,athy t~. t=oerster ~~or~?mi~sion~~ ~xtt~nAAoba9 6~a~¢leac4aon ~~enp~ae~ P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile c~aaag Cae a~~~are~~ Alaska Production PVlanager Joint Interest U.S. ~~ ~~~~ ~~ ~~oda~cti~n November 14, 2007 Chairman John Norman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Pt. Thomson Wells - Plugging and Abandonment Dear Chairman Norman: We are providing this letter in response to the Commission's May 18, 2007, letter to ExxonMobil regarding Point Thomson area wells that are classified as plugged and abandoned. ExxonMobil, as Operator and on behalf of the working interest owners of nine of the listed Point Thomson area exploratory wells identified in the Commission's letter, has undertaken an extensive review of the current physical status of each of these wells. (As Operator of the remaining well, BP will respond directly to the Commission on it.) This work included reviewing ExxonMobil's and the Commission's well files, including confidential Commission files for one well, conducting on-site inspections to assess the physica! integrity of each well site, and conducting a joint owner review of each well by technical experts. We are pleased to report that none of these activities have identified any imminent safety or environmental threat conditions from the wells. Attached are photos taken during the on-site inspections. The extensive reviews provide the basis for this response to the Commission's letter. While we believe the wells met AOGCC requirements when the prior P&A actions were taken and are safe in their current condition, we recognize that performing certain remedial work can further reduce any risk of an incident that may occur in the future. With that in mind, we have developed the attached schedule and plan to conduct remedial work on the wells. If the Commission concurs with this work program, ExxonMobil will prepare the appropriate sundry notices and begin to carry out the actions. As described in this letter and accompanying attachment, the plan contemplates conducting remedial work on certain wells in the near future and reclassifying the remaining wells to a suspended status. The wells with planned near term remedial work do not appear to have future utility while the wells identified for reclassification are capable of producing in paying quantities. We believe it would be premature to conduct work on these latter wells that may make it more difficult to utilize them in future development operations. There are other existing suspended wells in the Point Thomson Unit, and we view this action as consistent with current circumstances. 'vve under~~a~~u ihat ~ e~~assif~~~#;or ~v:!! c~r.ry ?!? ~b!~9a~ion to abandon the wells in the future in compliance with regulatory requirements. ~~; ~~~~~~ ~~ A Division of ~xxon 11Aobil Corporateon ~ommissioner John Norman - 2- November 14, 2007 Piease note the plan caiis for conducting the most intensive phase of field work in conjunction with the first winter drilling season of currently-planned Point Thomson Operations drilling, which is proposed to occur during the winter of 2008-09. We believe conducting this work in conjunction with this drilling program will offer significant operational safety and efficiency benefits. In the event the drilling program does not progress as proposed, we will wrork with the Commission to determine appropriate timing for the remedial work. We believe this plan responds to the Commission's request that Exxon~/lobil provide information and documentation to demonstrate that the wells meet the requirements for plugging and abandonment or provide a schedule and plan for bringing these wells into comp(iance and should address any concerns that may exist regarding compliance with AOGCC requirements for plugging and abandonment. As the Commission is aware, a number of changes have occurred in the requirements for plugging and abandonment of wells over the past 40 or so years. We believe these changes were generally sound and resulted in safer operations. In some cases, however, the changes created specific conflicts for operators, e.g., the 1986 regulations required installing marker posts while the 1999 regulations prohibited such posts (unless the land owner requests them). The planned work program will address these matters on the weiis planned for near-term remedial work and through future actions on the remaining wells. Other regulatory changes involving placement of cement plugs and retainers, cementing of casing stubs, or requirements of fluids left in the well are more subtle. In general, it would be unnecessary and impractical to later attempt to modify many of these items, pa~ticularly those that exist at deeper depths in the wells. In the interest of transparency and clarity, we will address any variances or deviations from current regulations in our sundry notices filed with the Commission. We appreciate the Commission's help in providing clarity around the issues and allowing adequate time for ExxonMobil to conduct a through and thoughtful review. We look forward to your concurrence so we can proceed with the outlined work plans. Please feel free to contact me, Bill Pecor at 564-3766, or Rob Dragnich at 564-3711 if you have any questions. Sincerely, ;~ / ~/~ ,.,/' ~ ~'-~(~ ~~ % CA :rgd/jpc Attachments xc: Cmmissioner Cathy Foerster - AOGCC Commissioner Daniel T. Seamount - AOGCC Kevin Brown, BP Mark Ireland, ConocoPhillips Vince LeMieux, Chevron ~~ ~ ~ ~~ s ~~ d`~~•'r~ ~ Remedial Action Program Point Thomson Wells - Plugging and Abandonment Wells Affected Actions Timin PTU #1, PTU #2, PTU #3,_ - Conduct additional integrity investigations to include: - Conduct work during winter of 2008-09 PTU #4, Alaska State C-1, + Removal of gravel from around wellheads Staines River State #1, W. + Conduct visual inspection Staines State #18-9-23, W. + Install valves and pressure gauges Staines State #2, Alaska + Check for pressure in casing and all annuli State J-'1 + Conduct further diagnostics as appropriate PTU #4 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug + Repair or replace as necessary ~--~* - Remove near-surface arctic pack from 2 annuli and ho c9i~~` set cement plugs in annuli using top job techniques ~~~ (plugs to be at least 50' long) ~,/5~ - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance Staines State #18-9-23 W - Remove marker post - Conduct work in conjunction with first . ~ - Remove diesel above surface plug (1~ } year of Point Thomson delineation - Remove wellhead and casing to lower than 3' below drilling planned for winter of 2008-09 ground level - Verify integrity of surface plug + Repair or replace as necessary Q o ss~b~~ -5 C~~ c~\esE ~ - Remove near-surface diesel from annulus and set cement plug in annulus using top job techniques " (plug to be at least 50' long) - Install marker plate - Remove cellar - Conduct general location cleanup, and request final site clearance -1- W. Staines State #2 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ground ~evel drilling planned for winter of 2008-09 - Verify integrity of surFace plug ~-~r~~`~~ + Repair or replace as necessary - Remove near-surface arctic pack from annulus and C~S~~ ` set cement plug in annulus using top job techniques ' ~ ~ long) (plug to be at least 50 a~C' - Install marker plate ~ ~ - Remove cellar - Conduct general location cleanup, and request final site clearance Alaska State J-1 - Remove marker post - Conduct work in conjunction with first - Remove wellhead and casing to lower than 3' below year of Point Thomson delineation ho c~'le.S~\ ground level drilling planned for winter of 2008-09 - Verify integrity of surface plug ~p {4~ + Repair or replace as necessary ~~ - Install marker plate U ~ ~ - Remove cellar Conduct general location cleanup, and request final site clearance PTU #'1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #2 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections PTU #3 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGCC cancurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winter 2008-09 inspections -2- Staines River State #1 - File sundry notice to change well classification from - Submit sundry notice within 90 days of abandoned to suspended AOGC;C concurrence with action plan - Establish status reporting program in compliance with - Submit status report within 90 days of AOGCC regulations winte~ 2008-09 inspections Alaska State C-1 - File sundry notice to change we~l classification from - Submit sundry notice within 90 days of abandoned to suspended AOGC;C concurrence with action plan - Establish status reporting program in compliance with - Subm~t status report within 90 days of AOGCC regulations winter 2008-09 inspections -3- ~ ~~ .^ a.~ ~ .~ , 7. 1 ~ ! ~,~I r =~~: ~'~:~ -%'~, ~l~ay ~3, ~~07 ~ommissioner ~athy ~oerster Aiaska Oil and Gas Conservatior~ ~ommission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Point Thomson Wells - Plugging and Abandonment Dear Commissioner Foerster: _ .._~ ,, ~ ,~. ,_, ~., ~~ `~~~~~~ . ~ \ ~ ~° ~ i ~ ~il:~ ~,t~' '~ . '=-t, ~~. . ~ ~ n ~ ,~,-, ,,i~~.)~~~ ~ ~ _.:i1~~~~ 4 j-y3<:) 7yai,~i~.i3.9JJ"~l =~~ n~, ~:~> We have received the Commission's letter dated May 18, 2007 regarding potential issues related to certain Point Thomson wells that were drilled and subsequently plugged and abandoned. Regulatory compliance is a core value for ExxonMobil, and we take all matters seriously. Our prior track record of voluntarily re-abandoning some wells and undertaking other remediation work in the Point Thomson Unit should speak to this. The May 18 letter requests that ExxonMobil respond within 90 days and either provide sufficient information and documentation to demonstrate the wells meet all requirements for plugging and abandonment, or to provide a schedule and plan for bringing the wells into compliance. We have begun an immediate review of the wells in question and have two requests of the Commission to help expedite that review: 1. The well files for the Staines River St #1 well, which was drilled by Mobil in the 1979 timeframe and is under extended confidentiality, are not in our Anchorage office. It would facilitate our work to obtain a copy of the file from the Commission. 2. It would be helpful to obtain a copy of the concerns or issues identified in the Commiss+on's review. We intend to conduct a thorough review of all of the wells in question and having any initial assessment by the Commission to check against as our work progresses may facilitate an earlier completion. It appears the wells on the list were operated by Exxon, Mobil or BP (forrnerly Sohio). To the extent another operator may be responsible for any of the identified wells we will work vvith the other owners to determine appropriate handiing and response to the Commission. 9 will be out of town until May 31. Please contact Rob Dragnich at 907-574-3711 or Bill Pecor at 713-656-7064 to coordinate any information you are able to provide. Thank you for bringing these matters to our attention. ~incereiy yours, %~ .f'~--.:-~ --.__ ~ ~ ~ ~;je~c x~; ~r~g~;s ~il~'~Ik~r, ~~ ~:~~~~ ~~~ ~~, ~~~~~~~~!r~ ~~ ~~~~~ ~~ ~~ ~~ ~~~~~ ~/~~lS I ~. ~~~~~7 ~raig ~-Iaymes Alaska Production ~~Ianage~- ~xxon!Vlobil Pr~ducti~n Company I'O Box 196601 ~nchorage, AK 99~ 19 Re: Pt. Thomson Wells - Plugcing and Abandonment Dear I~1r. Haymes, 333 W. 7th AVEiUUE, SUITE 100 ANCHORAGE, ALRSKA 9950'!-3539 PF10RlE (907) 279-1433 FAX (907; 276-7542 During our review~ of the Pt. Thomson Fie(d in response to your recent apptications for permits to drill, the Alaska Oil and Gas Conservation Commission ("Coinmission"j identified the following wells that, according to our records, are c(assified as plugged and abandoned but do not meet the requirements for plugged and abandoned wells under 20 AAC 2~.10~ - 20 AAC 2~.172: W. Staines St. 18-9-23 W. Staines St #2 Pt. Thomson # 1 Pt. Thomson #2 Pt. Thomson #3 Pt. Thomson #4 Staines River St # 1 Alaska State C-1 Alaska State J-1 Challenge Island # 1 V/ithin 90 days of receipt of this letter, either provide sufficient information and documentation to demonstrate that these wells meet all the requirements for plugging and abandonment, or provide a schedule and plan for bringing these we(Is into compliance. Also, please note that, under AS 31.0~.090, the Commission cannot issue permits to drill to an operator that is in violation of a Commission regulation pertaining to drilling, plugging or abandonment of a wel(. The C~mm:ssion reserves the right to pursue an Entorcement ~ction according to 20 AAC 25- ~3~. ~ ;'~ !-i~3~,~i1~S :.:~ :: . ~~~ti°~ ~ i~. ~~i~' nd,~r~ ~ p ~ ~ ;=ina(f~~, IZOtnin~ ab~~~ shoti(d b~ ct~nstru~d tu ~~~id~nc:~~ ~~~~r~:ssl~~ or i~zzplic;it(~, tlze C~uminission's oo~iti~or~ vi~ir_~~ r~s~es;i ~~ ~h~ ~~.~rrP~t sta:us ~f E;cx~n.~tfl~ii ~r an~ flti~er person as a i~r. ~~h~mson u~~~t ~p~ratc~r or 1~ss~~. ~ ~' ~; o~ ha~~e any~ qu~:sti~ns, please ~;a11 ~ne at 793-1221. To: Cathy Foerster, Commissioner May 9, 2007 Fr: Tom Maunder, PE Re: Status of Pt. Thomson Area Wells Introduction: As instructed, an assessment of the wells in the P~ Thomson area was performed. The purposes of the assessment were to determine if the condition of the wells met the regulatory requirements in effect when operations were completed some years ago as well as if the wells would meet the now current regulatory requirements. There are a total of 21 wells in the general area (14 E~onMobil + 1 ConocoPhillips + 6 BP). This document will only address the E~onMobil wells. Recommendation: Based on examination of the well files, it is my assessment tha.t 5 of the 14 ExxonMobil wells are Plugged and Abandoned in accordance with the now current regulations. T'he remaining 9 wells should be considered Suspended and AOGCC's da.ta.bases should be changed to reflect this more accurate well status. E~onMobil shouid be required to perForm the work necessary to properly plug and abandon the wells. Discussion: There are 4 versions of the plugging requirements in effect depending on when the work was actually accomplished. A summary of the effective dates of the various regulations is listed below and copies of the regulations are attached. Requirements have become more proscriptive through time. There were major amendments to the AOGCC regulations effective 4/2/1986. These included significantly more proscriptive requirements for plug locations and lengths, a suspended well classification and included requirements for removal of the wellhead and casing "... at least 3' below rig grade." In the 11/7199 amendments, the cutoff requirement was changed to "... at least 3' belaw original grade." Prior to 1980, 50' cement plugs were required above hydrocarbon zones and at surface with heavy mud-laden fluid between plugs. After 1980 100' of cement was required above hydrocarbon zones and casing stubs were required to be covered. Neither regulation explicitly required cutting off the wellhead and casings, although removal of all "... structures and installations ..." was required as part of location cleanup in the 1980 regulations. Effective Date 9/30/1967 DNR, 11 AAC 22 4/13/1980 AOGCC, 20 AAC 25 4/2/1986 AOGCC, 20 AAC 25 11/711999 AOG~C, 20 AAC 25 The physical downhole work on 7 of the 14 E~onMobil operated wells was completed prior to April 13, 1980 and physical downhole work on 6 of the remaining wells was compieied prior io Aprii ~, i yaci. The iasi weii, ~lasica State ti 2, was piugged ana abandoned in 1Q 2002 according to the I 1/7/99 regulations. Regardless of when physical operations were completed in the legacy wells, letters were submitted (most in November 1986) requesting the status of the wells be ehanged from suspended to abandoned. These requests followed physical inspection of the locations for site clearance subsequent to removal of upper casing heads and installation of abandonment markers. No downhole work was performed subsequent to removal of the drilling rig. It is interesting that following the completion of downhole work that nearly every well was labeled suspended, and that term is not defined in AOGCC regulations until the 1986 amendments. Temporary abandonment is first addressed in the DNR regulations effective 9/30/67. Examination of the files for the ExxonMobil wells reveals that, so far as I can determine, the wells have been effectively abandoned downhole. All wells had cement placed over productive intervals and usually employed retainers or bridge plugs. One well, Alaska State J-1 does not ha.ve any open hole plugs, but the well appazently did not encounter hydrocarbons. The intermediate casing shoe was squeezed below a retainer. Moving up hole, most wells had a portion of the production casing (7") cut and pulled. In all cases except Pt. Thomson #1, a retainer and/ar a cement plug were placed on top of the stub. There was no specific requirement to cover the stub prior to April 13, 1980, although in 3 subsequent wells the cut top of the 7" was isolated. Wells generally had a retainer and/or cement placed at about 2500' with non-freezing fluids placed above it. Non-freezing fluids included CaCl2 brine and diesel. Where annuli were not cemented, non-freezing fluids such as arctic pack and diesel were placed. No well ha.d all casing head heads removed. It appears that the casing head.s from any casings smaller 13-3/8" were removed and the casings cut below the lowest flange depth. A blind flange with the abandonment post attached was then bolted to the flange. It is important to note that Exxon performed "re-abandonment" work on 4 of these wells that were located on the barrier islands offshore in 1998 - 1999. The offshore islands were being eroded, and it was likely that the well casings would be exposed possibly resulting in spills. E~cxon specifically sta.ted that the work would "... plug and abandon the wells according to current regulations." The 4 wells were re-entered, liquid hydrocarbons (diesel) removed, cement plugs placed and casings cut off well below sea level. These 4 wells and the Alaska State A-2 are the only wells that meet the plug and abandon requirements effective since April 2, 1986. Based on examination of the well files, it is my assessment that 5 of the 14 EacxonMobil wells are Plugged and Abandoned in accordance with current regulations. The remaining 9 wells should be considered Suspended and carried as such in the AOGCC database. E~onMobil shoutd be required to perform the work necessary to praperly plug and abandon the wells. Tom Maunder, PE Sr. Petroleum Engineer ExxonMobil Operated Wells Pt. Thomson Unit Area Well PTD Date Date Work to Effective Re ulation? Comment Assessed Actual Required Work Suspended P&A 9130/67 4/13/80 412/86 11/7/99 Status W. Staines St 169- 8/13/70 5/1/73 by YES YES NO NO Diesel in annulus and Suspended Remove fluids, place 18-9-23 120 sun casin . Not cutoff. lu s, cutoff wellhead Alaska State A-1 174- 9/6/75 ~ by letter YES YES NO YES Re-abandoned 1998 -1999. Plugged and None 0 ~ 4 11/86 Abandoned W. Staines St. #2 175- 5/26/75 ~ by letter YES YES NO NO Diesel in casing 150' - Suspended Remove fluids, place 002 9/86 2279'. AP in annulus. Not plugs, cutoff wellhead cutoff. Pt. Thomson #1 176- 12/8/77 ~ by letter YES NO NO NO No plug above cut 7" at Suspended Remove fluids, place 085 1~l86 4000'. Diesel in casing. plugs, cutoff wellhead AP in annulus. Not cutoff. Pt. Thomson #2 177- 8/12/78 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 064 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Pt. Thomson #3 178- 7/4/79 ~ by letter YES YES NO NO AP in annulus. Diesel in Suspended Remove diesel. Cutoff 005 11/86 casing at 40'. Not cutoff. wellhead. Remove some AP. Staines River St 179- 7/21/79 11/5/86 by letter YES YES NO NO Diesel in casing at 100'. Suspended Remove dieset, place #1(confidential) 001 11/86 Not cutoff. 1 s, cutoffwellhead Pt. Thomson #4 179• 12/20/80 ~ by letter NA YES N0~ NO* AP in 2 annuli. No diesel. Suspended Cutoff wellhead. O80 11/86 Not cutoff. Remove some AP. Alaska State C-1 180- 7114/81 ~ by letter NA YES NO* N0~ AP in 2 annuli. No diesel. Suspended Cutoffwellhead. 046 11/86 Not cutoff. Remove some AP. Alaska State D-1 180- 2I16/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 101 11/86 Abandoned Alaska State F-1 181- 5/30/82 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None 140 11186 Abandoned Alaska State G-2 182- 8/19/83 ~ by letter NA YES NO YES Re-abandoned 1998 -1999. Plugged and None confidential) 208 11/86 Abandoned Alaska State J-1 183- 6/14l84 ~ by letter NA YES N0~ N0~ No open hole plugs. No AP Suspended Cutoff wellhead. 045 11/86 or diesel. Not cutoff Remove some AP. Alaska State A-2 200- 3/8102 by NA NA NA YES Plugged and None l41 sundry Abandoned N0~-no liquids present. L, ExxonMobil Production Company P. O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3677 Facsimile December 19, 2008 Mr. Johnny Aiken North Slope Borough Planning Department P O Box 69 Craic~Haymes Alaska Production Manager Jointlnterest U.S. E~onMobil I'~oduction ~~~~ J~;I~ ~ ~ 20 Barrow, Alaska 99723 ~ ; ' ~ ~, (~ Re: Alaska State C-1 Condi tonal Development Permit Application Point Thomson Area Remediation Program North Slope, Alaska Dear Mr. Aiken: Exxon Mobil Corporation proposes to perform inspections and remedial work at nine former exploratory wells and drill sites in the Point Thomson area. The Conditional Development Permit application and following project documentation are attached for the Alaska State C-1 well: • Coastal Project Questionnaire including North Slope Borough Title 19 Analysis, • Project Description (including all maps), and • Application fee of $3,000. Additional permit applications or amendments to existing applications/permits will be submitted to the Alaska Department of Natural Resources, Alaska Department of Fish & Game, Alaska Department of Environmental Conservation, Alaska Oil and Gas Conservation Commission, and US Fish & Wildlife Service in January. Please call Rob Dragnich at 907-564-3711 or Mike Barker at 907-564-3716 if you have any questions. Sincerely, ~ ~- '~~~~ CAH/eaa Attachments cc: Shawn Stokes, ADEC Steve Schmitz, DNR DOG Gary Schultz, DNR DMLW Nina Brudie, DNR DCOM Patricia Bettis, DNR DMLW Jack Winters, ADFG Tom Maunder, AOGCC Cindy Godsey, EPA Craig Perham, USFW A Division of Exxon Mobil Corporation .; • ---- Land Management ~ Regulations Permit Application Permit Number Applicant Exxon Mobil Corporation Address P.O. Box 196601 Anchorage, AK 99519-6601 Contact Person Mike Barker Location (TRS) 660' EWL 660' SNL Sec. 14, T9N 823E UM Zoning District Proposed Start Date February 1, 2009 NORTH SLOPE BOROUGH DEPARTMENT OF PLANNING AN DCOMMUNITY SERVICES PERMITTING AND ZONING DIVISION Permit Type Conditional Development Date December 19, 2008 State ID Phone 907-564-3617 Project Name Alaska State C-1 Well Inspection Unitized Field Name and Pad Location Alaska State C-1 Completion Date: August 31, 2011 Proposed Development Inspect well, check casing pressures. Purpose of Development See attached Project Description. ^ Fill/Dredge Material Acres ® Oil and Gas Wells Number of New Surface Holes: 0 ® Temp. Water Use Source Alaska State C-1 Pit and Lake 17 Equipment All terrain vehicles, trucks. Purpose Water for camp, ice road construction Maximum Amount 1,000,000 gpd Feb 1 2009 - Au 31 2011 All terrain vehic es, rol igon, ® Off Road Travel: Period of Travel ~ g ~ Equipment steiger. aircraft Access to Site All terrain vehicles, aircraft ®Fuel Storage Type Diesel fuel stored in steel tanks Amount X10,000 gal on-mo I e to ave o secon ary containment capacity per Handling plan requirements for fuel transfers and handling. ^ Hazardous Type Amount Materials Storage Handling ® Solid Waste Treatment Backhaul to permitted facilities in Prudhoe Bay or incinerate on site. ^ Mining Mining Habitat ® Air Emissions Type Heavy equipment, trucks, heaters, generators Amount < 100 tons/yr All terrain vehicles, aircraft, trucks, heavy ® Noise/Vibrations Type equipment Amount <_ 110 dBA ^ Sensitive Habitat Floodplain Shoreline ® Transportation Type All terrain vehicles, aircraft, trucks ^ Marine Tanker Facility ^ Seismic Work ^ Utility Development ^ Recreational Development ^ Causeway Construction ^ Offshore Drilling ^ Residential Development ^ CD-ROM Included ^ Airport or Helicopter Pad ^ Oil Transport System ®Snow Removal • . ATTACH TO THIS APPLICATION THE FOLLOWING: -GENERAL VICINITY MAP -SPECIFIC LOCATION MAP, INCLUDING NEARBY EXISTrING DEVELOPMENT AND NATURAL FEATURES -SITE SPECIFIC FOOTPRINT (IN ESRI SHAPE FILE FORMAT) ON A CD-ROM -A DIGITAL GIS SHAPE FILE OR GEODATABASE OF THE PERMIT AREA WTI'H NO ATTRIBUTES. THE PROJECT SHOULD BE NAD 1927 ALASKA ALBERS OF GEOGRAPHIC -DESIGN PLANS (PLOT PLAN), ELEVATIONS, CROSS SECTIONS, PROFILES. AS APPROPRIATE -SUPPLEMENTAL INFORMATION, AERIAL PHOTOGRAPHS, STUDIES, ETC. (AS NEEDED) SEND TO:NORTH SLOPE BOORUGH, LAND MANAGEMENT ADMINISTRATOR PO BOX 69 BARROW, ALASKA 99723 PHONE: (907) 852-0320 ---------------------------------------------------- IHEREBY CERTIFY THAT THE FOREGOING IS TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE Authorized Signature ~`i..(~~tf +~~ Date Craig A. Haymes Name Alaska Production Manger Title FEE PAID ^ SPECIAL PLANNING COMMISSION MEETING ....$12,000.00 ^ DEVELOPMENT PERMIT...$2,000 + $500 PER WELL ^ ADMINISTRATIVE APPROVALS ...$1500.00 ® CONDITIONAL DEVELOPMENT PERMITS...$3,000.0 AMOUNT PAID $3,000 DECISION ^ ADMINISTRATIVELY APPROVED This is a minor amendment to a development pernut or is a use of land listed under administrative approvals for this zoning district. ^ REZONING APPROVED This proposed development substantially complies with the Master Plan, and a use permit is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations and provisions of state and federal law and pernuts served there under. ^ DEVELOPMENT PERMIT APPROVED The proposed development meets atl applicable mandatory Policies, represents the Developer's best efforts to implement all relevant best efforts and minimization policies, and as long as any conditions set forth in the accompanying letter are complied with, will represent a net public benefit. (See accompanying letter) ^ CONDITIONAL DEVELOPMENT PERMIT APPROVED This is a use of land that is listed as a conditional development for this zoning district or has been elevated by the Land Management Administrator to the Planning Commission. ^ PERMIT DENIED (See accompanying letter) Land Management Administrator Date If you wish to appeal this decision, use must submit written notice to the secretary of the Planning Commission prior to the next regularly scheduled meeting, stating the policy or policies in questions and the reason you believe the decision is incorrect. C~ • Project Description Point Thomson Area Remediation Program Exxon Mobil Corporation 1. Project Overview and Schedule Exxon Mobil Corporation (ExxonMobil), on behalf of itself and other Point Thomson area lease owners, intends to conduct various inspection and remedial actions at nine different former exploratory well sites in the Point Thomson area beginning during the winter of 2008-09. This project description covers the full range of remedial activities that are being planned although only a portion of the work may be conducted during the winter of 2008-09. The entire program is expected to be completed by August 31, 2011. The timing of specific components will depend upon the status and plans for other activities in the Point Thomson area. A key consideration is the extent to which the Point Thomson Drilling Program, which includes construction of a sea ice road from Prudhoe Bay to the Point Thomson area, proceeds during the winter of 2008-09. For instance, if the drilling program does not proceed as planned during the winter of 2008-09, certain remedial activities that can be conducted more efficiently and safely in conjunction with certain aspects of the drilling program may be deferred to when those activities are conducted. Any work that may be deferred is not time sensitive and deferral would not pose an environmental threat; the locations and wells are stable. A decision on remediation work to conduct this winter will be made following a determination of the drilling program activities that will proceed, development of detailed work plans, and receipt of the necessary permits. The work scope includes 1) conducting inspections of nine former exploration wells as required by Alaska Oil and Gas Conservation Commission regulations for suspended wells, 2} conducting further remedial work on plugged and abandoned wells, and 3) closure of the open reserve pit at the West Staines State #2 well location. Assuming receipt of all required permits and authorizations by January 30, 2009, the work will commence about February 1, 2009, and be completed by April 15, 2009. During the summer of 2009, the locations will be visited by helicopter to allow for further clean-up and inspections. If the sea ice road for the drilling program is not conducted during the 2008-09 winter season, the inspection and remediation work that is conducted during the 2008-09 winter season will be supported by agency-approved off-road vehicles such as steigers, cat trains or rolligons or a combination of all off-road vehicles and conventional vehicles on local ice roads. 2. Permit Requirements This project description provides information necessary to support the applications for permits, authorizations, and coverage under general permits summarized on Table 1 which are required to conduct the desired remediation work. Page 1 of 6 • . Table 1-Permit Re uirements A enc Re wired Authorizations State of Alaska Department of Natural Alaska Coastal Management Program Consistency Resources (DNR) Determination; expected to operate under following General Concurrence Determinations - GCD-5 Equipment Crossing of Streams - GCD-19 Cross Country Movement of Equipment Winter/Summer - GCD-34 Ice Road and Ice Pat Construction in the NSB - GCD-45 Storage of Materials at Existing Pads in the NSB - GCD-49 Removal of Uncontaminated Gravel Structures • Lease Plan of Operations Amendment* • Land Use Permit for Off Road Travel** • Land Use Permit for Ice Roads (onshore) • Temporary Water Use Permits** Department of Fish and Title 16/41 Fish Habitat Permit** Game Department of . Reserve Pit Closure Plan Environmental Conservation Sec. 401 NPDES Water Quality Certification** (ADEC) Alaska Oil and Gas Sundry Notice Approvals for well work Conservation Commission AOGCC Borou h/Local • North Slope Borough (NSB) Conditional Development Permits for activity in a Resource Development District without a Master Plan (within PTU) • Develo ment Permits for activities outside PTU United States of America • Environmental Protection Notice of Intent for coverage under NPDES General Permit AKG- Agency 33=0000 for Gravel Pit Dewatering** • Sill Prevention Control and Countermeasure SPCC Plan • US Fish 8~ Wildlife Service Letter of Authorization (LOA) for Incidental Taking of Polar Bears USFWS and Pacific Walrus** * Approval of the lease Plan of Operations is the primary authorization from DNR for conducting well and related operations on a lease. All of the former exploration well operations were conducted under an approved lease Plan of Operations. The status of these Plans of Operations is uncertain and ExxonMobil will work with the DNR/ DOG to determine appropriate authorizations for this work. ** Applications for similar activities were requested for the Point Thomson Drilling Program. Coverage under the existing requests to cover the remediation program will be requested rather than submittal of new applications. 3. Site Access Site access primarily will be accomplished through the ease of vehicles traveling on ice roads or off-road vehicles. Helicopter or fixed wing aircraft will also be used depending upon activity for the Point Thomson Drilling Program and the logistical capabilities that aze available. Figure 1 Page 2 of 6 ~ i shows the tundra and offshore ice road routes between the Prudhoe Bay area and the Point Thomson area. Figure 2 shows the specific drill site locations and tundra travel or ice road routes within the Point Thomson area. 4. Well Remediation Work There are nine former exploratory wells in the Point Thomson area at which ExxonMobil is planning to perform remedial work. The names of the wells and work being considered are shown on Table 2. Four of these wells have been plugged and abandoned (P&A'd) and five are suspended. All nine wells have wellheads that are partially or completely covered with gravel. ExxonMobil plans to excavate the gravel from around the wellheads, perform visual inspections of the wells, and install pressure gauges to verify there is no internal pressure. This work will be accomplished in the winter of 2008-09 and is not dependent upon the ice road or drilling program activities. Removal of debris and location clean-up will be performed at all sites as necessary. The excavated gravel will be retained on location. For the four P&A'd wells, ExxonMobil plans to remove marker posts, cut and remove casings to at least three feet below natural ground level, and weld marker plates upon the casing stubs to conform to current AOGCC regulations and practices. This will also include removal of some hydrocarbon based fluids from within the wellbores and verifying the integrity of existing cement plugs or placing of new cement plugs. The specific actions to be performed on these wells will be addressed in Sundry Notice requests submitted to the AOGCC. For some wells, it maybe necessary to mobilize a coiled tubing rig or other light duty drilling equipment to the area to conduct well remedial work. Table 2 -Point Thomson Area Wells Well Name Surface Location Well Status Planned Work PTU #1 1,320' NSL 660' WEL Suspended Inspection Sec. 32 T10N R23E UM PTU #2 2,615 NSL 1,801' WEL Suspended Inspection Sec. 3, T9N, R22E, UM PTU #3 660' NSL 711' WEL Suspended Inspection Sec. 34, T10N, R23E, UM Alaska State C-1 660' EWL 660' SNL Suspended Inspection Sec. 14, T9N R23E UM Staines River St. #1 321' NSL 1,658' EWL Suspended Inspection Sec. 17 T9N R24E UM PTU #4 2,700' NSL 2,900' WEL P8u4'd Inspection, well remedial work Sec. 32 T10N R22E UM Alaska State J-1 1,886' NSL 2,404' WEL P&A'd Inspection, well remedial work Sec. 23 T6N 822E UM West Staines St. #2 848' SNL 50' WEL P&A'd Inspection, well remedial work, Sec. 25 T9N R22 UM reserve it closure West Staines St. 1,514' SNL 1,730' WEL P&A'd Inspection, well remedial work 18-9-23 Sec. 18 T9N R23E UM Page 3 of b • • 5. West Staines State #2 Reserve Pit Closure The West Staines State #2 exploratory well site has an open but inactive reserve pit. The closure plan will include filling the pit and installing a gravel cap designed to eliminate ponding of surface water within the reserve pit footprint. An estimated 17,000 cy of fill material is required to fill the pit and construct the cap. It may be possible to obtain these amounts from existing gravel at the West Staines St. #2 pad and West Staines St. 18-9-23 pad approximately 2 miles to the north. Other sources of fill material are being evaluated and may be proposed to the ADEC as part of the closure process. Further details will be provided in the reserve pit closure plan that will be submitted to the ADEC for review and approval. 6. Water Requirements and Sources A temporary Water Use Permit (TWUP) was previously requested to obtain water from the Alaska State C-1 gravel pit. That permit application will be modified to also include additional shallow (non-fish bearing) lakes in the Point Thomson area and the scope will be broadened to address this remediation project. If ice roads are used, water will be hauled using water trucks or tanks on conventional trucks. If off-road vehicles are used, the water will be hauled in tanks placed on the off-road vehicles. 7. Logistical Support The remediation work will be supported by an existing camp at the PTU 3 pad, which was staged to support the Point Thomson Drilling Program and by one or more portable camps that may be transported to each location. These camps will be equipped with potable water storage tanks, gray water treatment plants, electrical generators, fuel storage tanks, and small. incinerators. All camps will operate under valid public drinking water supply and environmental health/food services permits issued by the ADEC to the camp operators. Up to 10,000 gallons of fuel will be stored on location and will be re-supplied as needed. Pump houses will be located on the water source lakes and be fitted with ADF&G approved water intake structures. 8. Waste Management Solid, non-burnable wastes will be deposited into containers on site for back-haul to the Prudhoe Bay area for disposal. Any food wastes that could attract wildlife will be incinerated onsite, stored in enclosed containers awaiting periodic hauling, or hauled each day to the PTU 3 staging area. Camp waste waters will be treated and discharged to the tundra by the camp operators in accordance with EPA's NPDES General Permit AKG-33-0000. Page 4 of 6 9. Wildlife Issues Wildlife that could be in the area during the winter includes owls, ravens, arctic foxes, polar bears and brown bears. Polar bears are expected to be present in the area and are known to den in the surrounding coastal environment. Brown bears inhabit the general area. It is unlikely they will still be active during the winter season but they may be present beginning in April when they emerge from their dens. LOAs from the USFWS for the incidental take of polar bears and Pacific walrus will be requested, and operations will be conducted in accordance with those authorizations. A Beaz- Personnel Encounter Plan which describes procedures to protect bears and personnel and avoid encounters has been prepared. The USFWS will be consulted as appropriate during planning and construction of ice roads and in conducting surveys to identify dens. If a polar bear den is identified, the USFWS will be notified and the transportation route will be altered to maintain at least one mile from bear dens unless otherwise approved by the USFWS. Approval for such changes will be addressed via the Land Use Permits. Project personnel will be instructed not to feed wildlife of any type or in any other way attempt to attract animals and birds either at the drill site or on ice roads. Food will be kept inside buildings or containers that minimize odors. Hazardous materials will be kept in drums or other secure containers. Any bear sightings will be immediately reported to the site superintendent and the personnel in the area warned of the location of the animal. Dedicated bear monitors will be maintained on location to look for and identify evidence of bear presence in the project vicinity. Upon identification of bear signs or a sighting, the bear monitor will notify the site superintendent of the presence of bears in the area. Bear monitors will also be assigned to continually watch bears when present in the project vicinity. Qualified bear monitors from the village of Kaktovik or Nuigsut will be employed, if available, particularly during periods of potential subsistence use of the Point Thomson area to monitor project activities and coordinate with onsite staff to ensure subsistence activities are not impeded. 10. Oil Spill Contingency Plans ADEC does not require oil discharge prevention and contingency plans be prepared or approved for remediation projects including well entries such as are being considered here. Spill Prevention Control and Countermeasure Plans (SPCC) as required by EPA regulations will be prepared and in effect. Page 5 of 6 • 11.0 Communications and Supervision An ExxonMobil designated representative will be on site at all times during operations. Twenty- four hour phone service will be available at the drilling or construction camp. The following persons or positions are designated contacts for the project. Name Title Phone/Email Mobile Phone TBD On-site TBD NA Su ervisors Mike Barker Regulatory 907-564-3617 907-223-9904 Mana er mike.barker exxonmobil.com Prior to the start of field operations this contact list will be updated and provided to the applicable agencies. 12.0 Environmental and Safety Training All North Slope based company and contractor personnel will complete an 8-hour unescorted training program provided by the North Slope Training Cooperative (NSTC), which will include receiving a Field Environmental Handbook, an Alaska Safety Handbook, and a North Slope Visitor's Guide. This training will provide the basis for compliance with lease terms and permit conditions/stipulations for most employees, including wildlife and environmental awareness training. Additional specialized training will be provided to employees as needed, including such topics as detailed waste analysis planning, manifesting, and permit compliance requirements. 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E'- F - ry~I _ ~ ~ ~''~ t E h ~--l---r IW 1a ~'}•.~,tvl',' R ~~+•h > 17r R ' ~ ~ "`' ..14 ~^'sFc~ ~f "'\{',: S ~ a --Ir~ ~-.' kr~' .,. aY~~} i ca~: j r ~` ~~, 1 ~t { ~~ f _~~ a~l"~~~'` a, Tr~~~=~i }_ ._ ~,. .r;; I j,~~ i,~ 1 _ ~ I ~~`/j^~ \ `fir ! .,~ 1 l' ,. ,t ~4A ~ - s -...-_~_;~.-„~.,,_- ,_._- r+~l~ t~+' ~t~.,';v1 ~,' ~\~.t,"~1(( d ~ I~ ~vcy dt ~~ ~~~`~ ~~`~'a.~t~` 1~`~'f `-r1. a r-[~.-c iy^'~ ,4,.< ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501 o3192 PHONE: (907) 279-1433 FAX: ¢907) 276-7542 December 2, 1999 R.C. Gardner Fairweather E & P Services, Inc. 715 L Street Anchorage, Alaska 99501 Re;¸ Location Clearance Work on Exxon's Alaska State Wells Dear Mr. Gardner: Reference your letter of November 17, 1999 on this subject. Our Petroleum Inspector Lou Grimaldi reported on the September 9, 1999 inspection trip to various Exxon State wells - copy attached. His report of the inspection trip states: "SUMMARY: C 1 and G2 locations still need some work. Based on my observations, I recommend the Al, D1, and F1 location clearances remain approved." Your assessment of the work that needs to be done on Exxon's Alaska State Wells C-1 and G-2 closely parallels what Mr. Grimaldi reported. As such. we anticipate that this additional work will be completed in the next few years. If you have comments, please contact me at (907) 793-1,_6 Sincerely, Blair E. Wondzell.'t~.E. Sr. Petroleum Engineer Enclosure CC: D. Michael Baker Exxon Company U.S.A. I-ak-st-wells.doc D:XPicgxFlaxman~xFLAXMAN G-2 CELLAR.jpg (local) - Microsoft Intemet Explorer Page I of 1 11/17/99 12:21:40 PM D:LPics'xl:laxmamNORTHSTAR F-1 PAD.jpg (local)- Microsoft Intemet Explorer Page 1 of 1 11/17/99 12:21:21 PM D:LPies'xFIaxman~FLAXMAN C-1 VSP.jpg (local) - Microsoft Intemet Explorer Page I of l ! 1/17/99 12:21:49 PM D:~PicSff:laxman'xFLAXMAN C-1 PIPES.jpg (local)- Microsoft Intemet Explorer Page I of 1 11/17/99 12:21:57 PM D:LPics~Flaxman'xFLAXMAN C-l PIastic.jpg (local) - Microsoft Internet Explorer Page 1 of 1 11/17/99 12:23:36 PM SENT BY: E & P $1::'RVtC£S, tN6; November 17, 1999 ll-18-BB ; 10:44; I}07 276 7§42;# 1/ 1 Alaska Oil and Cras Conservation Commission Robert H. Christenson, P.E., Chairman 3001 Porcupine .Drive Anchorage, Alaska 99501 Attention: Blair Wondzell, Senior Petroleum Engineer 'Re: Remaining Location ~learance Work Items: Exxon Alaska,State G-2 (PTD 82-208) and Alaska State C-1 (PTD 80-(.)46) Sites Dear Mr. Wondzell: Location clearance inspections at several Exxon Point Thomson IJnit locations were conducted by AOGCC inspector [.,GU Grimaldi on September 9, '1999. Mr. Grimaldi was accompanied on these inspections by D. Michael Barker of Exxon Company U.S.A., and K.C. Gardner representing Fairweather E & P Services Inc. These inspections revealed that specific additional site work is required at the above referenced locations, as described below. · Alaska State G:2....Locatig..nx Rapid wave ~rosion of the north side ot'Flaxman Island has occurred during the past three (3) open water seasons. This erosion has advanced into the G-2 pad area and exposed some small seawater pipelines w.hich were previously buried within the pad, At the ti~nc of the inspection these pipelines were protruding fi'om the eroded north face o1' the pad, and over the surf zone below. These pipelines appear to be empty, and while aesthetically objectionable, rose no enviromnental risk, Exxon is planning additional work on the 0-2 well site durhig tire next 'few years. This work will require the use of heavy equipment, The aforementioned pipelines will be removed when this equipment is on location and available to do the work. · Aba..kaState C.-...! Locatig~ Three (]3) steel deadman anchors (premmably tbr a communication tower) have reappeared on the southern edge of the pad due to frost jacking and thermokarsting These anchors were previously cut off below pad level during the 1998 - 1999 winter season, In addition, a VSP pipe has been exposed along the notlhem edge of the pad, also due to thermokarsting and subsidence, Exxon proposes to excavate and cut both the anchors and the VSP pipe below the active layer, This work would be done as soon as equipment is available in the area,, which most likely will be associated with arty work at, the 0-2 and A- l locations, Please contact the undersigned at 258-3446 or Mike Barker at Exxon (564-3691) if you have any questions concerning our approach to these remaining work items. RECEIVED 18 1999 ~daska .Off & Gas Cons. ~ommlsslon cc: D, Michael Barker gllCh0ral!e Exxon Company U,S.A, 715 L Street Anohomgo, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, Chairman DATE: September 10, 1999 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 74-0014 -- D 1 PTD# 80-0101 - G2 PTD# 82-0208 - F 1 PTD# 81-0140 - C1 PTD# 80-0046 - Thursday, September 9, 1999: ! traveled with Mike Barker (Exxon), Gar Caruthers (CH2M Hill), and Bob Gardner (Fairweather) to inspect Exxon's C1, G2, Al, D1, and F1 and locations in the Point Thompson Unit. I make reference throughout this report to Chuck Scheve's report dated August 3rd (see 199KHCFE.DOC) Alaska State C1: The C1 location still has at least 3 of the 6 pipes originally reported by Chuck, these are most probably deadmen used to stabilize the now removed communication tower. The rest of the location was clean and free of debris. Although there is still some remnants of the plastic underliner used during construction of the pad. This plastic is coming out in small pieces and should not pose a serious ecological problem. There is also a large casing stub at ground level that appears to be a Velocity Survey Pipe. I mentioned to Bob Gardener that this should also be removed. Alaska State G2: The G2 location on Flaxman Island was clean and free of debris. Exxon deepened the casing cut last winter and there was a slight depression where this was filled in. Due to the severe erosion on the North side of the island, there are three small diameter pipes and two heavy cables protruding from the eroded edge. These should be removed while being careful of possible contaminants held in the pipes. LOC CLEAR FLAXMAN ISLAND 9o9-99 LG.doc Page 1 of 2 Alaska State Al: The A1 Location was very clean and although somewhat irregular, smooth enough to pass inspection. Alaska State DI: The D1 location was completely underwater today. The V.S.P. mentioned in Chucks report was not visible even though we flew around the area for ten minutes. Alaska State Fl: The F1 location on North Star Island was clean and free of equipment and debris. The island is very smooth with evidence of sea ice scraping the top of the island. SUMMARY: C1 and G-2 locations still need some work. Based on my observations I recommend the D-l, G2 and F1 location clearances remain approved. Attachments: Photos; FLAXMAN G-2 PIPES.jpg FLAXMAN G-2 CELLAR.jpg NORTHSTAR F-1 PAD.jpg FLAXMAN C-1 VSP.jpg FLAXMAN C-1 PIPES.jpg FLAXMAN C-1 Plastic.jpg LOC CLEAR FLAXMAN ISLAND 9-9-99 LG.doc Page 2 of 2 D:~ics',Flaxman'xFLAXMAN C-1 VSP.jpg (local) - Microsoft Intemet Explorer Page I of 1 11/17/99 12:21:49 PM D:',PicsxFlaxmanxFLAXMAN C-1 PIPES.jpg (local) - Microsoft Intemet Explorer Page I of 1 11/17/99 12:21:57 PM A: \lg- flaxman\FLAXMAN C -I PIastic jpg (local) - Microsoft Internet Explorer Page 1 of 1 OAR 31 ck*_ial.' uu'y` s 'e w` �^AS garr4� ' s ` � � i <;. t- arcs v,+rt a � �°� °�- - "; .aw *�' •y,: avr � �A .. 1 � ; Ti .rte R. y+YR k � = •� $ � ��� � i �I I i i 11/17/99 12:10:00 PM Exxon Company, U.S.A. 1999 Remedial Work Completion Report Flaxman Island Area Well Re-Abandonment Project Beaufort Sea, Alaska E&,~r~ o,-, Summary of Work Completed /~,,.r,-z~c~ ~_~ The Exxon Flaxman Island Area Well Re-abandonment Project was conducted over two winter work seasons during 1998 and 1999. The project activities were extended into 1999 due to an unusually early winter breakup in 1998 and the addition of work tasks identified during the summer of 1998. Project operations were conducted at four locations (Alaska State A-l, C-1, D-l, F-1 ~ on Flaxman and North Star Islands and have been completed according to Exxon's work plans. Sundry well reports have been submitted for all well work on the Alaska State A-l, D-l, F-1 This report covers non-well operations conducted during the 1999 winter work season. Remedial work completed at the A-l, C-1, D-1 and F-1 well sites during the April and May 1999 work season included the following activities: , Removal of 994 cubic yards of diesel contaminated gravel from the Alaska State A-1 location on Flaxman Island. This contaminated material was discovered during a 1998 summer site visit to the A-1 location and scheduled for cleanup the following winter season. Additional details on this work are contained in the Exxon Company, U.S.A. Alaska State A-1 Former Fuel Storable Area Cleanup Report that has been provided to the AOGCC under a separate submittal. 2. Removal of three steel piling at the southeast edge of the drilling pad at the Alaska State C-1 location. . Removal of a 42 inch O.D. vertical seismic profile (VSP) casing to five (5) feet below the toe of the slope of Fiaxman Island at the Alaska State D-1 location. This casing was discovered during a 1998 summer site visit to the D-1 location. . Removal of a 30 inch O.D. structural casing at the Alaska State F-1 location to 18 feet below ground level and more than five (5) feet below the toe of the slope of North Star Island. Waste Management All waste materials generated during the project were handled in accordance with North Slope Borough, State of Alaska and Federal regulations. Project waste materials were disposed of as follows: AOGCC sup report 99 I Waste Material Quantity Handling and Disposal Recyclable steel 10,000 lb Transported to K&K Recycling, Fairbanks, AK. Wellheads, cemented 35,000 lb Transported to the NSB landfill. casings Transported daily to Deadhorse for final disposal at Camp trash 1,800 lb NSB solid waste treatment facility. Transported in secure tanks and injected at Pad 3 Wellbore fluids, Class II 5 bbl facility. Liquid Waste, Class I, 475 bbl Transported in secure tanks and injected at Pad 3 non-hazardous, facility Diesel contaminated 994 yd3 Transported in secure containers to Alaska Interstate gravel Construction in Deadhorse for thermal treatment. Transported to Deadhorse for disposal at NSB solid Miscellaneous debris 5,000 lb waste treatment facility. Note: Above quantities are for 1999 operations only. Cleanup activities consisted of grading of all excavations and a thorough stick picking effort during demobilization operations at the end of each winter work season. Summer debris pickup work was also conducted following each winter work season. AOGCC sup repon 99 2 COMPANY, U.S.A. POST OFFICE BOX 196601 · ANCHORAGE. ALASKA 99519-6601 · TELEPHONE (907~ 561-5331 PRODUCTION DEPARTMENT ALASKA INTEREST .JAMES F PRODIJC- C,N MANAGER - ALASKA April 13, 1999 S'T~.2( TECH _._ STAT TECH Flaxman Island Area Well Site Re-abandonments.__ Alaska State A-l, C-1, D-l, F-l, and G-2, Beauf~'t Sea, Alaska ~_ ~7~ ~ ,I L IFILE Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Consen.,ation Commissicn 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Christenson: This letter is intended to give you a status update of Exxon's work activities on Flaxman Island. No action on your part is required. During March and Apdl of 1998, Exxon Company, U. S. A. conducted well abandonment and casing removal operations in the vicinity of Flaxman Island in the Beaufort Sea. These activities were authorized by the AOGCC. Due to an unusually warm spring and early break-up, the work season for 1998 was cut short and not all of the work was completed. We inspected the work sites with the AOGCC in August 1998, and the remaining work was outlined in the AOGCC's letter to Exxon, dated September 4, 1998. In accordance with our letter responding to the AOGCC dated December 1, 1998, Exxon is now returning to the area to complete the work, including the abandonment of the Alaska State G-2 well. We are also removing large diameter casings that were exposed at the Alaska State D-1 and F-1 locations during 1998 and the smaller pipes noted at the Alaska State C-1 location. Lastly, we plan to remove the contaminated gravels from the Alaska State A-1 fuel storage area. If you have questions or require additional information, please contact Mike Barker at 907-564° 3691. Sincerer, /,,. DMB:ddm c:~lata\winword~mb\enviro~ot.tom~federal-state agencies~Robert Christenson 4-9-99.doc// / c: Mike Barker, Exxon /' Jim Haynes, DNR-DOG Jesse Mohrbacher, Fairweather / A DIVISION OF EXXON CORPORATION RECYCLE :--' _-..-~"~'4.ON COMPANY, U.S.A. ""'", ?RODUCTION DEPARTMENT ~,LASKA INTEREST · _~L!E$ F BRANCH December 1, 1998 Alaska State A-l, D-l, and C-1 Mr. David W. Johnston Chairman/Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Commissioner Johnston: This communication is in response to your letter dated September 4, 1998, which summarized the results of an August 1998 AOGCC inspection and requested Exxon to undertake some remedial work at the Alaska State A-l, D-l, and C-1 well sites. Following the AOGCC inspection of these well sites in August 1998, Exxon revisited them in late August, to conduct some of the site clean-up work, and to develop plans for the remainder. Below is a brief summary of the status and our current work plans for these well sites. Alaska State A-1 The referenced pallets have been removed from this site.. In addition, Exxon has been working with ADEC representatives to determine the cause of the sheen and evaluate the extent of hydrocarbon contaminated gravel. We have collected and analyzed gravel samples for hydrocarbons and are preparing a "Clean-up Plan" for ADEC review. Alaska State D-1 Exxon has notified the U. S. Coast Guard about the submerged large diameter pipe (a velocity survey pipe) and in turn, they have issued a "Notice to Mariners." Exxon plans to remove this pipe below the mud line during the upcoming 1998/1999 winter season. A DIVISION OF EXXON CORPORATION RECYCLEE Commissioner David W. Johnston 2 December 1, 1998 Alaska State C-1 Exxon has revisited this site and cleaned-up debris. However, we have not removed the six-inch pipes referenced in your letter. We will cut the pipes off this winter while we are working in the area. In addition to the work outlined in this letter, Exxon plans to conduct further clean-up activities at the Alaska State F-1 well site and to complete the abandonment work started last year on the Alaska State G-2 well site. We will contact you and your staff again as our plans and schedule become more finalized. In the interim, please contact Mike Barker at 564-3691 if you or any of your staff have any questions. DMB:ddm ¢:~dat~/inwora~lmb~ge~ciel~P.,ommll~ormr JOlll~or~ 1 .! Sincerely, / / TOIV~ KNOWLE$, GOYEi~NOI~ ALASKA OIL AND GAS CONSERVATION COMMISSION September 4. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James F. Branch Exxon Company'. U.S.A. P.O. Box 196601 Anchorage, Alaska 99519-6601 Re: Alaska State A 1. D 1 and C l Dear Mr. Branch: One of our inspectors visited scvcral Exxon cxplorator3' xx'cll sites in the Pt. Thompson Unit on the North Slope during August this year. Rob Dragnich accompanied him. Several of the sites require additional work as [bllows. Alaska State A1 (AOGCC Permit 74-014): The well is located on Flaxman Island. A portion of a plastic liner was visible on the north edge of the island, a small sheen was visible, and six wooden pallets remain at thc site. Alaska State D1 (AOGCC Permit 80-101): The well is located on Flaxman Island. A large diameter pipe was visible in the area of the drill site. which is now submerged, the pipe is obscured bx' waves and may only be visible from thc air. Alaska State C 1 (AOGCC Permit 80-046): The location appears to have a partially opened pit and scvcral six inch pipes standing in water on the southeast side of the location, thc casing max' need to be cut off dccper below ground lcvcl. These sites have previously bccn approved bx' thc state fbr abandonment. Howevcr. Exxon remains responsible for these sites and under 20 AAC 25.026 is not relieved of further claims bv the Commission a~cr abandonment. Accordingly', the Commission requests Exxon to undertake appropriate remedial work to correct thc above deficiencies. Please advise the Commission when Exxon will undertake rcmcdial work. Chairman~...~ PLUGGIN% & LOCATION CLE~/RA/qCE REPORT State of Alaska Review the well file, and-cc=sent on piuq~inq, well head s~atus, and location clearance - provide loc. clear, code. ~eil hea~ c~U o~f: ~ -- , ~arker post or plats: 7 / Conclusions: I Il I J ii Il I I I Code MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: Blair Wondzeil, ~ FILE NO: P. I. Supervisor FROM: Chuck Scheve,~ ~' SUBJECT: Petroleum Inspector August 3, 1998 i99khcfe. DOC Location Clearance Insp. Exxon Point Thompson Unit A1 PTD# 740014 D1 PTD~ 80-0101 G2 PTD# 82-0208 F 1 PTD# 81-0140 Cl PTD# 80-0046 Monday. AuQust 3~1998: I traveled with Rob Dragnich (Exxon), Gary Schultz (DNR) and Bob Gardner (Fairweather) to inspect Exxon's Al, D1, G2, F1 and C1 locations in the Point Thompson Unit. Alaska State Al: The A1 Location is on Flaxman Island and the well was P&A in 1975. The north edge of the island has eroded away revealing a layer of plastic (possibly a pit liner) approx. 3' below current pad level. Upon closer inspection a diesel odor was observed and a small sheen was visible on the bank in one spot. The affected area appeared to be 90' long on the north east corner of location. On the East edge of location there were 6 wooden pallets mostly covered with over burden and vegetation starting to grow on top of them. -~... Alaska State DI: The D1 location on Flaxman Island is mostly under water and the casing stub was cut off below the base of the island this past winter. The visible portion of the location was clean and free of debris. Off shore to the north east of remaining location there is what appears to be a large diameter pipe (possibly a velocity survey pipe or an unused conductor) that was only visible from the air and in the trough of the , ,waves. ~,'~:a,~ c..~.'l-.--~ lo~-~' '1.<)9 7.- ~ P'e~- i::~oL~ 1.7_~.~J~ E'~(v)~' Alaska State G2: The G2 location on Flaxman Island was clean and free of debris. Exxon plans to deepen the casing cut off this next winter due to the severe erosion of the island. Alaska State Fl: The F1 location on North Star Island was clean and free of equipment and debris, c~'-~t · c~-~' e~' loa,.~ ~r ! <~ 9 7- '-).9 Alaska State C1: The C1 location has what appears to be a partly open reserve nit and 6 each)6" pipes standing in a water covered area off the south east edge of location, it appears that the casing cut off is just below pad level, with the location mounded slightly to cover it. The marker post is weathering well and had the proper info welded to it. The rest of the location was clean and free of debris · SUMMARY: It is my understanding that the above mentioned locations all have approved location clearances, if this is the case I recommend that the commission reevaluate the Al, D1 and C1 locations. Based on my observations I recommend the G2 and F1 location clearances remain approved. Attachments: Photos Attachment to: Chuck Scheve's 8/3/98 Memo: "Location Clearance Inspections, Exxon" Location Clearance. Chuck conducted a location inspection on five Exxon wells, Alaska State A-l, C-l, D-l, and G-2. Wells A-l, D-l, and F-1 were re-abandonments. The Commission has previously acknowledged that all 5 wells were properly abandoned. * After a 9/5/84 inspection, on 9/20/84 LC Smith approved ~final abandonment" of Exxon's Alaska Sate well D-1 * After a 6/18/86 inspection, on 8/25/86 LC Smith approved "final location clearance" of Exxon's Alaska State wells F-1 & G-2 * After inspections on 8/27 and 9/12/86, on 11/21/98 LC Smith approved ~final location clearance" of Exxon's Alaska State wells A-1 & C-1. The diesel and pad liner at A-1 and the reserve pit at C-1 will be corrected under DEC's jurisdiction. The pipe offshore of D-1 will be removed this winter (98-99) per Exxon's Rob Dragnich. Well AbandOnments. I reviewed the 10-404 data on the three wells that were ~re-abandoned" A-l, D-l, and F-1 and can make the following comments: * Well A-I: diesel was displaced from the 9-5/8", the 9-5/8" x 13-3/8" annulus was circulated with cement at 205', and the casings were cut-off 40" below sea floor. Based on the 404 data, the re-abandonment is an improvement over the original and is acceptable: well A-1 is properly abandoned. * Well D-l: casings were cut-off 15'below MLLW, cemented 9-5/8" x 13-3/8" annulus, and re-cemented inside 9-5/8" from 47' to 16, MLLW. Based on the 404 data,, the re-abandonment is an improvement over the original and is acceptable: well D-1 is properly abandoned. · Well F-l: casings were cut-of 13' below MLLW, filled with cement the 7"x9-5/8" and 9-5/8" x 13-3/8" annuli, Blair E. Wondf~l,-Septe~%ber 11, 1998 . ~ , :, ~ ~~,~ ~ ~~ i ' y a .; F ~ ~, ?~ ''1~ ',~ , .~~ x ~ ~~ s - _~4 It 1 ~, R ~ .r.,' ~~ i ~,. r~ ~ ~~ j - ! C fir' lw. J x' 7 < 1Y" .~ I AS ~ ' l~.,. _ , S ~~ x~~~, r, ,~.r . 6 F. w: ~~ ~~~r ~~ ~; Nt ar[aer Pclst ~~ xd~ S~~.e. C- I (~~ ~ ~'o - O~t6 ` Re se~~2 ~..~ den Opt" ~ e. wa r November 21, 1986 Telecopy No. (907) 276-7542 Mr. John P. Clement, III Drilling Manager Exxon Corporation P. O. Box 60626 New Orleans, LA 70160-0626 Re: Final Location Clearance Pt. Thomson Unit Well No. 1 Pt. Thomson Unit Well No. 2 Pt. Thomson Unit Well No. 3 Alaska State A-1 Alaska state C-1 Dear Mr. Clement: Our representatives inspected the above referenced locations on August 27 and September 12, 1986, and found that cleanup was acceptable. Marker posts with the required information bead welded on them were in place, ~' Your letters dated November 10, 1986 requested that we change the status of each of these wells from suspended to abandoned. Since there were no changes made to the well bores of these wells, we did change the status to abandoned on the "Well Completion or Recompletion Report and Log" which had previously been submitted for each well. Based on the above, we hereby approve the final location clearance for the Pt. Thomson Unit wells Nos. 1, 2 and 3, Alaska State A-1 and C-1 wells. and the Sincerely, Lonnie C. Smith Commissioner j o/A.HJH. 47 E: (ON COMPANY, U.S.A. POST OFFICE BOX 60626- NEW ORLEANS, LOUISIANA 70160-0626 PRODUCTION DEPARTMENT OFFSHORE DIVISION JOHN P. CLEMENT, III DRILLING MANAGER November 10, 1986 Mr. Chad Chatterton Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: This letter is to request a change in status from suspended to abandoned for the following well: 80-46, Alaska State "C" No 1 Please refer to the attached form (10-407) for plug and suspension details dated 7/14/81. TVB: j cv Attachment Sincerely, Alaska Oil & O~s Cons A DIVISION OF EXXON CORPORATION , ' ' STATE OF ALASKA ' ' bUIlrlULl t. ,~'~" ALASKA~I ~ND GAS CONSERVATION C~'ISSION WELL COMPLETI ,' :OR RECOMPLETION- !PORT AND LOQ ' .Cleuifir.~{ion of Service Well ,. s,~,u, o, w,,, s,~: £,x.x ~'N ,z.7"/~ -/////~/~r/~ . -' ' ~. N~e of Operat~ 7. Pe~tt Num~ ;xxon ~t~tat~on 80-46 3. Addr.s 8. APl Numar ~ouch 660~, ~c~;age,.-~k. 99502 ........ ~8g-200~ ~ . g. Unit or 4. L~etion o~' well at surf~e LO~TIO~, 660' ~ & 660' SH~, Sec. ~4, 79~, R23~, U.H. VERIFI~ ~aska S~abe "C' At T~ Pr~ucing Intewal ' ~~ 10. Well N'um~ .... 3Z28' ~ & 707' SN~, Sec. Z4,. ~gH, ~3~. U.H. B.H.~ No. , At Total O~th ,,- 11. Field e~ P~I .. 3~68* ~ & 747' SN~ Sec. Z4~ ~9N;. E23~; U.H. S. ~le~tion in f~t (ind~ete KB, DF, etc.) " I 6. Lease O,ignation and Serial No. 54 KB I . ~ 26362 ~7 T~llD--th ;MD+TVD) 18. PiugB~k'D~t~~D) 19'Dlr~ti°nllSur~y" I 20'D~thwhlreSSSV~t I21'Thjcknm°fPlrmlfr01t . 22. Type El~tr~ or Other Logs Run DuaZ Zn~uc~on~ ~ous~L~ ~otma~on ~ns~z-~eu~ton, D~e~et,..VeZ~~ 23. CASING, LINER AND CEMENTING RECORD .... , ,, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" .... ~4 H'40 Sut~. 8~3~ 26" 350b sx Petma~¢°s~ 0, ........... Z3-3/8. 72 N-80 Su;~. 3,993~ ~77~/2" 4850 ex Pet;~500 cZ',~",'" O~ .... 9-5/8" 47 E;-90&S~-i5 $ut[, ZZ,ZZB' ~2-Z/4, 2470 sx =Z'G~ .. 0i ':'. ,,, ., 7" 32 & 35 P-Z~0 ......Sut[. Z3,~46' 8-~/2" 2400' sx ~ 'G' 2,500' 4-Z/2" ZS.Z P-ZZ0 Z2.848' Z3.757i 6" 200 sx c~ 'G' 0, - , .... ,. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SiZE ' DEPTH SET (MD) PACKER SET (MD) ~Z~ ~t[ota~ons squeezed w~h cemen~ ..... . ~3,666'-~3,706'~D (~3~52'-Z3~9~'~) 4 spE ........ ~3,426'-Z3,560'~ (Z29~3'-~3045'~D) 4 sp~ 26. ACID, FRACTURE, CEMENT SQUEEZE, E~C. - ........ Z3,630'-Z3,654'~D (Z3ZZ4'-Z3~38'~) 4 sp~ DEPTH iNTERVAL (MD) AMOUNT&KiN~OFMATERiALUS~D ' . ....... , ..... Z~,476'-ZZ,504'~D (ZZ06~'-ZZ086'~) 2 spE ...see A~ac~en~. ZZ,5Z2'-Z~,564'ND (~093'-Z~4~'~D) 2 sp~ ...... ~,576'-~,600'~ (~52'-Z~Z74'~VD) 4 sp~ ...... . ........ ............ 27. PRODUCTION TEST , ,, Date First Production I Meth"0d o~' Operation (Flowing, gas lift, etc.) FO~ATION TESTS ATTACHED Date 0' Test Hours Tested pRODucTION FoR ~IL-BBL GAS-McF wATE~-BBL CHOKE SIZE "l GAs-oIL RATIo TEST PERIOD ~ .... Flow Tu~ing Casing Pressure CALCULATED O~L-BBL GAS-McF WATER-BBL OIL GRAVITY-APl {corr} Pres~. 24-HOUR RATE ~ "28. CORE ~ATA ....... , , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. " RECEIVEO ~'~.~ ~:~ V ! 8 ~ ~ ~as~ 011 & 6as Cons. ~l~lon -. ,' . ~cho~ge ~ ~C ~ '.-'~. ~ ,, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit__ in duplica~' S~ STATE Of ALASKA ~ ALA '' OIL AND GAS CONSERVATION CO '.'SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ Exxon Co., U.S.A. 3. Address P.O. Box 60626 New Orleans, LA 4. Location of well at surface 660' E.W.L. & 660' Sec. 14, T9N-R23E UPM North Slope, At top of productive interval At effective depth At total depth 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Final Location Abandonment Packers and SSSV (type and measured depth) 70160-0626 S .N.L. Alaska 12. Stimulation or cement squeeze summary Intervals treated (measured) 13. 5. Datum elevation (DF or KB) 54' MSL Feet 6. Unit or Property name ADL 283. Alaska State "C" 7. Well number Exxon No. 1 8. Approval number 33O 9. APl number 50-- 089-20011 10. Pool Wildcat Permanently plugged to. surface feet Plugs (measured) feet feet Junk (measured) feet ECEIV D UL, I 0 ~' lnn~, - zoOO Measured depth Length Size Cemented Alaska Oil & Gas Cons, Anchorage Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation True Vertical depth Date 9/25/86 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I here~y certify that the foregoing is true and correct to the best of my knowledge Signed~° · ~. , TitleNew Orleans Drilling Mgr Tubing Pressure Form 10-404 Rev. 12-1-85 Submit in Duplicate MEMORA , " UM Sta - of Alaska ALASKA OI ~O GAS CONSERVATION COMMIS~ .... ON / TO: C.V. Ch DATE. September 5, 1986 Chairman ~f~ ~ F~LE NO.: D.JFB. 16 THRU: Lonnie C. Smith TELEPHONE NO.: Co~issioner FROM: John F. Boyle ~J~ ~ Petroleum Engineer Assr SUBJECT: Location Clearance Exxon Alaska State C-1 Permit No. 80-46 ednesday, August 27~ 1986: I traveled this date from Anchorage to ~dh~e ~ay and 'met..' ~i'th'" Tom Burford, Exxon representative. I visited the above listed location, and recommend it for final abandonment. _ ....... I filled out an AOGCC Surface Abandonment Report which is attached. Attachment Z-O01A(Rev 10-84) , 1 'ALASK L AND GAS CONSERVATION COMMISS N URFACE ABANDO'7MF,NT REPORT c 20 AAC 25, AWrICLE 2 FILE INFORMATION Operator C o P,R Date Downhole P & A Address N Q HoQA C (-\ V— Surface Location of Well Perniit No 0- 1 16 6� L _ Ft. F b 6 b Ft. F A) f L, API No. 50- op9 _ ;�d p Sec. TH: W. R23_ E ! ! M. Unit or Lease Name A/q s kA s 7 A7 Well No Field & Pool �Al'r - L 20 AAC 25.120 WELL ABANDONMENT MARKER Dia. Steel Post (4 "Min.) g '/ Length (10' Min.) / Height Above Final Grade Level (4' Min.) �5' Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds V' Set: On Well Head ✓ , On Cutoff Casing , In Concrete Plug Distance Below Final Grade Level Ft. in. A4 Sir �K!P Side Outlets: All Valves and Nipples Removed YQ..r All Openings Closed h'LJ With Blinds 6, Cement Other INFORMATION BEADWELDED DIRECTLY TO MARKER POST: (List Where_ Different from File Information) Operator Unit or Lease Name M41 y'y "tw, Well Number C.af Surface Location of Well: �_ Ft. F 6%w L, 0 Ft., F /1 L, Sec / �! T3 �[, R � V M 20 AAC 25.170 LOCATION CLEAN -UP PITS Filled In NQ , Liners Removed or Buried ri s , Debris Removed `="e. .r SURFACE OF PAD AND /OZ LOCATION Rough , Smooth Contoured Flat Compacted , Other CLEAN UP OF PAD AND /OR LOCATION: Clean , Pipe Scrap , Iron Scrap Wood Mud Cement , Paper , Other SURROUNDING AREA Wooded , Brush Tundra - N Grass Dirt Gravel , Sand Other CONDITION SURROUNDING AREA: Clean , Trash from Site Trees and /or Brush from Clearing Site , Other ACCESS ROAD Dirt Gravel Ice Other CONDITION ACCESS ROAD AND SURROUNDING Clean , Rough , Smooth , Trash from Operations , Trees and /or Brush from Clearing Road Spoil from Clearing Road , Other hJ REMAINING TO BE DONE RECOMMEND- APPROVAL OF ABANDONMENT: Ye No Final Inspection Yt.t 0 4 INSPECTED BY tY DATE 091'a-7 lei 05/26/81 C�Q- � � I _ �� _�/ +. I t 3'� � � n s _ �- -- - - -_ � -�- AL ,/-, OIL AND GAS CONSERVATION CO JlON 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 [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Exxon Company U.S.A. 54' M.S.L. 6. Unit or Property name,~L .-~.~ 3. Address P.O. Box 196601 Anchorage, Alaska 99519-6601 4. Location of well at surface660, ~ffN'~, 660' S~L, Sec. 14, r~JN, ~?3E LI~M, ~3rth Slope, Alaska At top of productive interval At effective depth At total depth 7. Well number 8. Permit number 80-46 9. APl number 50-- 089-20011 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Permanently abandoned to surface. feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth True Vertical depth RECEIVED AUG 1 5 1986 Alaska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August 15, 1986 14. If proposal was verbally approved Name of approver Mr. Ionnie Smith Date approved July 8, 1986 15' I here~~~)~ng Signed / , y. / is true and correct to th.% best of my knowledge Title ~/~/~'< Commission Use"~nl/ Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy ' ~mturned Date Y/tO'///,, Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Plan to ~onvert Alaska State "C" #1 from suspended to permanently abandoned status: 1. Cut off refrigeration pipes below grade. 2. Remove valve from well. 3. Reinstall well marker and back fill to grade. RECEIVED AUG 1 5 1986 Alaska Oil & Gas Cons. Commission Anchorage MEM.ORAF - UM Stat~ of Alaska ALASKA OIL AND GAS CONSERVATION COMM~ ~ION TO: C.V. ~~rton DATE: August 12, 1986 Chai~ FILE NO.: D.ADA. 44 THRU: Lonnie C. Smith TELEPHONE NO.: Commissioner FROM: Doug Amos Petroleum Inspector SUBJECT: Clean-up Inspection Exxon Alaska St. C-1 Permit No. 80-46 For Final Abandonment WedBe, sday~ June 18, 1986: I traveled this date from Kuparuk to Prudhoe BAY and ~&t With Tom Burfford, Exxon representative. The location listed above requires work as stated on the attached list and Shown in attached pictures. I filled out an AOGCC Surface Abandonment Report for this location. It is also attached. .001 A(Rev 10-84) ILE INFORMATION: Operator Address Surface Location of Well Ft. Sec. , Date Downhole P & A. 0 AAC 2~.120: WELL ABANDONblENT MARKER: Dia. Steel Post (4"Min.) ~', Len~t~h (10' Min.) Height Above Final Grade Level (4' Min.i Top of Marker PiPe Closed with: Cement Plug Screw Cap Pennit No. API No. Unit or Lease Name Wel 1 No. Field & Pool ~J', Welds Set: On Well Head ~ , On Cutoff Casing ~, In Concrete Plug Distance Below Final Grade Level Ft. in. ~ ~uw Side Outlets: All Valves and Nipples Removed ~O All Openings Closed ~, With Blinds ~ , With Cement ~, Other INFORMATION BEADWELDEI) DIRECT~LY TO MARKER POST: (List Where Different from File Information) Operator ~0~4 ~~ Unit or Lease Name Well .Number ~-} , Surface Location of Well: [p~O Ft. F~L, .[&~__Ft., F6~L, Sec. [~. , T ~ ~ , R_~...~, AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ~ Liners RemoVed or Buried /,~ Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough ,' Smooth , Contoured /,' Flat -- . Other ~[ ~ ~-~.1 ~ h ' , Compacted , CLEAN UP OF PAD AND/OR LOCATION: Clean. /,'Pipe Scrap__, Iron Scrap Paper , Other , Wood , Mud , Cement SURROUNDING AREA: Wooded , Brush , Tundra :~,~, Grass , Dirt , Gravel Sand , Other CONDITION SURROUNDING AR'EA: Clean o->', Trash from Site Other , Trees and/or Brush from Clearing Site ACCESS ROA'D: Dirt__, Gravel , Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean__, Rough , Smooth , Trash from Operations , Trees and/or Brush from Clearing Road __, Spoil from Clearing Road Other ~4 / A. REMAINING TO BE DONE': ~.l~ ~P~iO~t~ ~~ Z RECOMMEND-APPROEAL OF AB~NDON~IENT: Yes , No ~ PSnal InspectLon INSPECTED BY ~~ ~,O ~ DATE os/26/8 SUMMARY OF 1986 LOCATION CLEAN-UP WORK Location Pt. Thomson Required for Suspension Required for Abandonme~nt No work required -Remove valve & blind flange & needle valve -Level mound near well- head -Remove rat-hole below grade and cellar Pt. Thomson #2 No work required -Smooth down gravel mound near wellhead -Remove debris Pt. Thomson #3 No work required Alaska State A-1 No work required Alaska State C-1 No work required -No work required pro- vided wellhead is not too high after abandoning pit -Remove debris ,,'Lower wellhead -Cut off refrig pipes below grade -Remove valve & blind flange & needle valve Alaska State J-1 Remove trash -Remove sewage lift station -Remove debris-Regrade & smooth pad-Verify cellar filled with gravel - under water when inspected -Remove cellar boards 7/8/86 ~~-~ ~~ ~' j~,. ;~., ~,. ~ `. ~r- ~ ~~-_ -- ` _ -:. ~X'~~ n?'r ~~~~ o r o-~ A~~ roc 4 St. C-- 1 C \Q a r~ v P , __~ A FTC- ~- C c.EA ~ tee. ~ ` ~~ ...,; ~_ _° ,- ti~Y'~-°~ti °j 1 .~, ~ ~~ ~- --..~ E y .ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION D.H JONES EXPLORATION COORDINATOR -- ALASKA September 6, 1985 Exxon' s Drillsites Inspection and Status Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed for your review and approval are Sundry Notice forms 10-403 for ten Exxon drills±tes located on the North Slope. We request that the status of the Duck Island pad drillsites be approved as permanently abandoned, all the other drillsites to be maintained 'as suspended. Very truly yours NB3/13:ng Enclosures A DIVISION OF EXXON CORPORATION RECEIVED SEP1 1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA " ALASK .L AND GAS CONSERVATION .,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator n n .~ ~n~ n.~ .... ~ ~v 99502-060! , .~. ~ .... , ..........~, .... ; 4. Loca}~on of Surface' 660' E~L, 660' SNL, Sec. ~4, T9N, R23E, UPN Bottom' 3~68' E~L, 747' SNL, Sec. ~4, T9N, R23E, UPN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. RO-46 8. APl Number 50- 089=200!! 9. Unit or Lease Name Alaska State "C" 10. Well Number Exxon No. 1 11. Field and Pool Wildcat 54' MSI 12. ADL 28382 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment s~ee 20 AAC 25.105-170). We request a One year extension to August 1986 of the suspended status of this well. We will arrange to have the location inspected by your representative on a.yearly basis or until final abandonment. RECEIVE" SEPI 1 Alaska Oii & Gas Cons. Cot.,, Anchorage Signed' ,~_~~~///~//--U _~/~¢_- [ Title Exploration A]aska Coordinator- The space below for CommissiOn use Date 9/10/85 Conditions of Approval, if any: ~(~pproved Co~v Returned I~1~ LONHtE £. $M11:t E~¥ Order of Approved by COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MICROPALEO CONSULTANTS, INC. 4569-K MISSION GORGE PLACE SAN DIEGO, CA 92120-0890 TRANSMITTAL TO: Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Mike Minder ~-. llll I I , JOB NUMBER: 84-113 SHIPMENT ENCLOSURES: Exxon'AlaSka State C-1 Exxon Alaska State D-1 Paly Slides Box 1 % 1-60 Box 2 # 61-121 Box 3 # 122-170, Core #1-10 Paly Vials Box 1%1-104 Box 2 %105-150 %1-50 TAI vials Paly Slides Box 1 # 1-63 Box 2 % 64-125 Box 3 # 126-150 , , , ,, , ,, , ,, , ~,l' . ~,~ ~, ~~~%,,.~:~.~. ....~ .... ....... ........ ......... ....... ........... .. Please sign and return one copy. Thank you. MEMORN,,dUM Sta(,o of Alaska TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATION COMMISSION /(~~~..~O DATE: C.V. n Chair~l~ FILE NO: ,^/ Lonnie C. Smith 4~ TELEPHONE NO: c Bobby Fos terr6~q~; SUBJECT: Petroleum Inspector September 11, 1984. D.31.62 Inspect Suspended EXXON Locations Listed Below For Suspended Status. WednesdaT! September 5, 1984: I traveled this date to Prudhoe Bay and met with Junior Westbrook and Noreen Borys, Exxon representa- ' rives. As the attached pictures show the locations listed below are in compliance with AOGCC regulation 20 AAC 25.170. Therefore I recommend to the Commission that these wells be accepted as sus- pended from September 5, 1984 thru September 5, 1985. Duck Is land #2 Duck Is land #3 Alaska State A-1 Alaska State C-1 Alaska State F-i ' Point Thompson #1 Point Thompson #2 Point Thompson #3 Attachment/pictures in file 02-00IA(Rev. 10179) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 " Date Suspended _ ~~ /~"/ ~ Y~://~/~n~/~n~ _ /?~. Permit No. ~ Address Surface LocatiOH o~ ~.;eli' - ~ ' - . ...... LLo. ~t. ~~~, A~ Ft. F 5~ L A~I No. ~0~ ~-~ ~., Seo.~~ T~-~iR~~, .... '~.M' unit or Lease Name~:~5 ~ Well No~ ~ ~T ~. Field & Pool : - m,./.A._~ .~'_/ Condition' of Pits _ . _ __:_ ~'~ ~? ....... Well head - Ail outlets plugged Well sign - Attached to well head No Attached to well guard Attached to Information correct es No No No Cellar- Opened Yes No Rat Hole Fi 1 led ~ No Covered ~ No WaterWell - Plugged off Capped Open Explanation Fi 1 led Covered Ye s No No PhotograPhs taken to verify above condition~ Work to 1:~ done to be acceptable No Explanaton This well and location is (acc~eptable) (unacceptable) to suspended f.or the period of Inspected by be classified as Revised 8124/82 ! / / 1J + ~1~ ~e ;'j 1.y 3 ;~//~/a j'~ ..~ i~/L i' ~+ ''~'~'if ~(,fi~VGj ~~ _._ `{ ~~ ~/ ~~ 3 .~5 ~~ A ~ to "' +i:, a # .k_ ~ k ~. SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Exxon Corporation 80-46 3. Address P. O. Box 6601, Anchorage, AK 99502-0601 4. Location of Well Surface: Bottom' 660' EWL, 660' SNL, Sec. 14, T9N, R23E, UPM 3168' EWL, 747' SNL, Sec. 14, T9N, R23E, UPM. 5. Elevation in feet (indicate KB, DF, etc.) .54' MSI 12. 6. Lease Designation and Serial No. APL 28382 8. APl Number 5o-089-20011 9. Unit or Lease Name Alaska State "C" 10. Well Number Exxon No. 1 1 1. Field and Pool ,, Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing E] Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other E~[ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 1985 of the suspended status of this well We will arrange to have the location inspected by your representative on a yearly basis or until final abandonment. RECEIVED SEP 1 019'84 Alaska Oil & Gas Cons. Commission Anchorage ExploratiOn Coordinator- Signed v/~~~. ~~ Title Alaska The space below for Commission use Date 9/10/84 Conditions of Approval, if any: Approved Copy R,e.t, urne)d - -- BT LONNI[ C. SMITH By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in DuPlicate Se~tez~ber 29, 1983 ~xxon Co~pan~~, U.S.A. P. C. Box 6601 Anchorage, Alaska 99502 Cleanup Inspection for the ¥ollowing Wells: · . Tll~ ~.",17~ U Duck Island Unit ~o 2, Sec 8, , , . Duck Island Unit }~'o. 3, Sec. 10, TI~, RI7L, ~.~. Point '£'homson Dnit ~o. 1, Sec. 32, T10X-~, R23~, U.~.~. Point ~'homson Unit r;o. 2, Sec. 3, Tg1~, }12iE, U.}~. Point Thomson Unit ~:o. 3, Sec. 34, T10N, R23E, Alaska State A-l, Sec. 27, TiON, R24E, U.~. ~laska State C~li~ Sec. 14, T9b, R23~, U.~i. Alaska State D-l, Sec. 23, T10N, ~{23E, ~.h. Alaska State F-i, Sec. 17, T10~, R235, U.~]. Alaska State C-2, Sec. 35, T10N, R24E, Con t 1 e l:~..e n: Our re~..resentative inspected the ak~ve ten susie;ended and abandoned well sites for extension of cleanuI~ on August 31, 1983. With the exception of Alaska State C-2, the cleanup cf these ~'eil sites are satisfactory. Decause the drilling rig was still on location at Alaska State (~-2, a cleanup inspection could not be com~leted. Returned are eight approved 10-4~3's, Sundry ~.-~otices and }~epcrts on Wells, for all the listed wells em:copt for two which need no lurther approval. Alaska State G-2 has a year to go under 20 AAC 25.170(a) and Alaska Stat~ E-I wl:ich (classified as aban- d. ened) has previously been ~ranted an extension to August, i9S4 for removal of the sheet piling. The 10-403's which you subn]itted for Duck Island 5nit ~io. I an~ Alaska State D-1 are not necessar}: and are returned unsigned. Duck Island Unit ~o. I ~'as at~ndoned ~c~2~ole and Duck Island Unit ~:!o. 2 was sidetracked Iror.~ the ~ell kote cf ~o. 1. Conse- e~uentiy a 10-403 is not re.cuired for ~-~o. i. A subsequent insi~':ection of each well will be necessary by August, !9g4. Sincerely, Lonnie Cc.r';n~i s sioner LCS/J.~ :lc: !03: , MEMORALOUM Sta( of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C. V~~terton Chai~~ Thru: Lonnie C. Smith Commis s ioner FROM: Bobby Fos te~.~ Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: September 6, 1983 108B:Zl Inspect Suspended Exxon Location' s Listed Below. Wednesday, August 31, 1983: I met with Tom Bruford, Exxon repre- sentative, this date and inspected the following suspended loca- tion's. Pictures were taken and attached to each report. Duck Island #3 Duck Island #1 and #2 Point Thomson #1 Point Thomson #2 Point Thomson #3 Alaska State A-1 Alaska State C-1 Alaska State D-1 Alaska State F-1 Alaska State G-2 I recommend to the Commission that all these location's with the exception of Alaska State G-2 be accepted as suspended locations in regard to pads, pits, and well signs. Alaska State G-2 is not acceptable due to the rig still being on location. In summary, I inspected the above suspended lOcations. Attachments Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ~~ J/~J ~ ~/, i Date Suspended Address _~'.~~-~/z~D ~ ~~/ ~~~ S~rface L~ation of Well. Sec.~ , T_~ Wel 1 No., Field & Pool Condition of Pad ~o~ Condition of Pits Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard ~-Attached to ~ No Information correct No Cellar -- Opened Yes No Rat Hole Open~'~/~es No 'Fil led ~ No Fil led Yes No Covered · No Covered Ye s No WaterWell - Plugged off capped Open Explanation ~ .,~9,~J ~_~_ ~ ....... Photographs taken to verify above 'conditionsO No Exp la naton .;__ Work to be done to be acceptable _.~/~/~)/c7~_~ ............. This 'well and location is (acc~ptab~e) +a~n-=cceptab.~) tozbe suspended f.or tholed_ ' · Insisted by: ~~. classified as Revised 8~24/82 ~ x xo~ - ~/r~.s,~ s~A~ c - ~ SeC. ~y , ~ 9~, ~~~E, uyn - ~~.~,~~ ~, :~~ __._- ,.~_ F :r~~ ~~ ~` ~ . . ~ ~, ~ .~_ _ `M1 -,,~ . ,~ . NiADEINU.S.A. ~Q'. ~~~ ~~~ ~,~ ~~ tuc l~ /~~' l ~ ~' ~v iN~~ ~xxoti f11AS,~ .s~~~ ct~ ~ 1 r1l~~f'.~ c- ~ .Eq~1 Pisx•t1~- hcRe. ~~ Sp~~s: rlAl~t. ~~ e ~, 1 ~XYorJ CoL°~, Al~ss L~ S~.o~e G rn,~~,o,~,,~ ~•~ ~~~ vm ~~~~ ~~ ~~-- -~_ ~.~ _ ~ _ ~~ h."4L~4~t - ~Y M - r M. " L ~~, c,~ • 1~/aa%r ~ ~e C- l ,~ - ~--- ~' _a~ ,l:l~~ -~ d~ ~ ~vel ~ Yn,ge,[~,~ EXPLORATION DEPARTMENT ALASKA/PAC I F lC D IV ISlON EXXON COMPANY, U.S.A. POUCH 6601 Anchorage, Alaska 99502 TRANSMITTAL OF DATA FROM: Roy Lonqstreet TO: Alaska Oil & Gas Conservation commission Attn: Fran Jones 3001 Porcupine Drive Anchorage, Ak. 99501 Material transmitted Exxon Alaska State C-1 The materiallistedbelowisbeingtransmittedvia Hand delivered 1 BLP & 1 Sepia of the following: 5" HI/R Dipmeter Log, run 93 2"/5" Dip Arrow Plot, runs 1 & 2 Please acknowledge receipt of the above material by signing and returning the duplicate copy of this letter. Gas Cons. ~or'r,missl0n RECEIVED 2 Roy Longstreet August 26, 1983 Date E) ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION O H. JONES EXPLORATION COORDINATOR -- ALASKA July 26, 1983 Mr.. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval are Sundry Notices for one year extensions of the suspended status of the following Exxon wells. Point Thomson 1, 2, & 3 Duck Island 1, 2, & 3 ,:~,, D-l, F-I We would be pleased to arrange an inspection tour of each of these locations for your representative sometime in late August. Please contact Mr. R. L. Westbrook at (907) 263-3742 to arrange a convenient date. Very truly yours, NB: rms 40/42 A DIVISION OF EXXON CORPORATION STATE OF ALASKA (~i ALASK("' ~ll_ AND GAS CONSERVATION ivlMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Exxon Corporation 3. Address Pouch 6601 Anchorage, Alaska 99502 4. Location of Well Surface: Bottom: 660' EWL, 660' SNL, Sec. 14, T9N, R23E, UPM 3168' EWL, 747' SNL, Sec. 14, T9N, R23E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 54' MSL 12. I 6. Lease Designation and Serial No. ADL 28382 7. Permit No. 80-46 8. APl Number 50_089-20011 9. Unit or Lease Name Alaska State "C" 10. Well Number Exxon No. 1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We request a one year extension to August 1984 of the suspended status of this well. We will arrange to have the location inspeCted by your representative on a yearly basis or until final abandonment. Approved Copy Returned ,JUL 14. I hereby certify that the~foregoij~g is true and correct to the best of my knowledge. ~~ Exploration Coordinator - Signed Title Alaska Date 7/25/83 The space below for Commission use Conditions of Approval, if any: Our representative inspected this well site on August 31, 1983 and cleanup uas acceptable for a suspended location. A subsequent inspection will be - necessary by August, 1984. OltlGlflAt SIGX£9 Approved by ..n~f .,,-',r C. SMITH COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" ir~ Triplicate and "Subsequent Reports" in Duplicate September 15, !982 ~xxon Company U.S.A. P.O. Box 6601 Anchorage, Alaska 99502' Res Preolean-up Inspection of Alaska State C-1, Sec. 14, T9N, R2'3E, DM. C~ntlem~ns Our representative made a preclean-up inspection of tbs site and noted that the surface location information b~ad welded to the we1! marker was incorrect. It should read 660'EWL, 660'SNL ~Seco 14, TgN, R23Ew U~. i~tead of 660'NSL, 660'W~L. Also attention is directed to the mound around the marker post that should .be removed to final, ground level. It is pointed out that casing mst be cut off below final grade level and that casing heads, etc. are not to be concealed by mounding up around the marker post. Aerial photograph~ submitt~d in your letter of September I, 1982 to ~r, C. V. Chatterton ~ugge~t that clean-up £~ svbstantially correct, but we are unable to ~etermine the status of the w~ll marker or Sincerely, Lonnie C, Commissioner LCStJKTIg lh -MEMORANDUM S iate of Alaska FILE NO: Thru: Lonnie C. Smith ~~ 108/~ CcmmissionerM u TELEPHONE NO: 1982 'FROM' Harold R. Hawkins ,~../~.~;/~'~'~ ' '; SUBJECT: Petroleum. Inspector ~ '~ ~/t Inspection of Location Before Clean-up Started Exxon Company U.S.A. Sec. 14, T9N, R23E, UM 660' EWL and 660'SNL Alaska State C-1 Thursday, August .12, 1982 - I left Mobil's West Staines No. ~2, Sub~ect-of-another' repOrt, to Exxon"s Alaska State C-1 location. Exxon is waiting for several contractors to produce their bids to clean-up this location. There has been no clean-up of this location yet, suspended date was July 14, 1981. I checked the location data on the marker and took pictures that verify the information bead welded to marker post. The surface location data on the well markers is, wrong. The data on the marker .as sh~n in pictures 13, 14 and 15 are Exxon Alaska State C-l, Sec. 14, T9N, R23E, OM, and !~60'NSL and 660'WEL. Pictures #1 through 12 shows mound around marker post that should be removed to final ground level?, and debris of almost every description on and in the surrounding area off the pad. Pictures 13, 14, and 15 show marker post with wrong surface data. Pic~ares 16, 17, and 18 are random pictures of debris on and off the pad. Junior Westbrook, Exxon's suervisor, said when they get the bids back from the contractors the clean-up should start within a few days on this location. In summary, I inspected Alaska State C-1 before clean-up had started. Before C-1 is inspected for clean-up of location Exxon should be advised of the surface location data being wrong on the well marker post. 02-00lA(Rev.1D~/79) ~~ ~~ ,.5 ~~-~ ~~' .~ E ,, ~ s~,,.~ a~~~~ :. . - ---. --~-.- ,~~° •-~~ ~~. - ,~~ -, _~ ht _ti,~ b. ~ -. a tP~ tu'93.` '.c,. ~."~` .-_~,,,,,~~ ~~±~ ~~ S~ _ _ ~;,i ~ o~~"P~~ ;. _y _. w __ .~ ,~. ~: - ~ . .. _¢ P ~~"~ ~ H'~. ~ 9 r' t~~~1S ~~o.~ ~~~~~~~ ~ -~ ~s R "'.. ~ 6 ~G~ff f4 sT ~ '°~ scc ~~ T~~ ~ ~i L :~ ~qr /!~~ ~.. N ~ .. ~ s: A~r~ ~~' ~~~,r~ ~~~~I( °~~ ~A~GS ptih~~~ ~~~ Ar~p Y QFF THE ~'.~~ ~ /9~t~ l~ ~ /I ~~ ~~ ~ ~.~ f ,~ Avg; ! ~~ e~ ~~ r t ~~~" 1!gze '4'~at1. 'yit .. ~w, F Yi ~ ~ ~ R .~ ~: ~:, ,;~ yq' J •, { ~S';; v ?, ~ l ~ ~~,~ 1a-j~Q~"~ ~ ~~ ~% ~ ~ ~"~ ~~ ~~~s~~~ r+ i ' ~l ~ ~ 1~ Aa `7 q~~ I~9 ~ ~"[r `~ 'J v _r» Imo' G_R~N ~ ..,. ~;~~~ w ~~ ~- ~:_. -- Y '.P. /~ 6 i ~~ !- +!~ E ON COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 1, 1982 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: On August 12, 1982 a representative of the AOGCC (Harold Hawkins) along with R. L. Westbrook and R. G. Dragnich, conducted an inspection of several of our drilling locations in the Pt. Thomson and Duck Island areas. During these inspections, the representative indicated that one-year extensions on suspended wells would be approved after the cleanup work was completed at these locations. We therefore submit, the enclosed photographs of our Pt. Thomson #3 and:~iA!s~?~'Sta~t~e?'C'~:I~'~'drilling locations which indicate that the cleanup has been completed. We submitted Sundry Notices requesting extensions for these locations on August 10, 1982. Also attached are Sundry Notices requesting one-year extensions on our Pt. Thomson #1, Duck Island #2, Alaska State D-l, and Pt. Thomson #2 locations. These are wells which we wish to carry as suspended rather than abandonments. The Pt. Thomson #1 and Duck Island #2 locations were inspected by your representative who indicated that extensions would be approved. As you recall, Duck Island #1 .and 2 is a single wellhead and the AOGCC has previously approved the abandonment of Duck Island #1. The Alaska State D-1 location was previously submitted for abandonment approval on February 18, 1982 and was also inspected by your representative-. We understand that to obtain a final abandonment status for this location, the sheetpiling will have to be cut off below grade. The attached Sundry Notice requests a one-year extension to enable us to conduct this work at a future date. The Pt. Thomson #2 location has been suspended since September 1978 and was not included in the inspections. The attached Sundry Notice requests a one-year extension of this status. A E)~VISION OF EXXON CORPORA 'i'ION Mr. C. V. Chatterton September 1, 1982 Page Two We also request clarification of the status of Mobil's West Staines #2 location. This location was inspected by your repre- sentative and discussed at a meeting with Lonnie Smith and Jim Trimble of your office and Exxon representatives Dave Galloway and Rob Dragnich. Please advise Mobil as to the requirements for their obtaining a final abandonment for this location. Very truly yours, D. H.. Jones NPB..sjm 60~2 Attachment s E ( ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE. ALASKA 99502 EXPLORATION DEPARTMENT OFFSHORE ALASKA DIVISION August 10, 1982 Mr. C. V. Chatterton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950]. Dear Mr. Chatterton: Attached for your use are Forms 10-403 requesting one year extensions of the requirement to clean up and Point Thomson No. 3 drillsites. We plan to conduct general cleanup operations at both of these sites this summer, however we will be unable to fill in the pits at the Alaska State "C" loca- tion until the winter when we can haul gravel from the stockpile at the Point Thomson No. 3 location. We are currently utilizing the Point Thomson No. 3 pad as a storage area for tubulars and as a contingency gravel stockpile for future eXploratory drilling activities and plan to coninue doing so. We have also constructed a pit for mud and cuttings disposal adjacent to the pad. In addition, the following locations are ready for your inspection: Duck Island %1 and %2 (single wellhead) Point Thomson No. 1 Mobil's West Sta, ines ~2 A D!VISiON OF E~XOI~ CORPORATION Mr. C. V. Chatterton, Chairman August 10, 1982 Page Two We plan to conduct clean up operations this month at other drilling locations utilized during the winter of 1981-2 and we will submit appropriate sundry notices in the near future. R. L. Westbrook of this office will be contacting a member of your staff this week to coordinate inspection of Exxon's North Slope locations. Very truly yours, D. H. Jones NB: b sw 40/2 Attachments A(L STATE OF ALASKA (i, ALAsK ,L AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. Exxon Corporati on 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 5o_089-20011 4. Location of Well At Surface' 660' At Bottom Hole' EWL and 660' SNL, Sec 14, T9N, R23E, U.M. 3168' EWL, 747' SNL, Sec 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) KB + 54' MSL 6. Lease Designation and Serial No. ADL 28382 9. Unit or Lease Name Alaska State "C" 10. Well Number Exxon #1 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other DO [] Other ~ Pulling Tubing Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension of requirement to clean up location upon completion of the well. We plan to conduct a general clean up of the location this summer which will involve picking up trash, leveling and grading the site. However, we are not planning to fill in the pits this summer as there is not enough material on the location to accomplish this. We request the extension So that we can conduct this work during the winter using stockpiled gravel hauled from our Point Thomson No. 3 location. AUG 1 c, 1982 Alaska 0il & Gas C0ns~ C0mrnissi0n Anchorage Approved opY 14. I hereby certify tha/~ th~oreg~ing is true and correct to ~he best of ~y knowledge. Ret~ed Signed __~ ~ _ Title.. Drilling Manager ~'._ Q..,t, August 9, 1982 The space below~sion use Conditions of Approval, if any: O~ ~e~ese~tati~e i~spected thls suspended locatio~ o~ Au~st 12, 1982. ~is ~as be~O~e Clea~-u~ ~ad started' Ae~al p~ot. oB~a~s submitted o~ Se~tem~e~ Z b~ ~zzo~ sug6est clea:-u~ ~bsta~tia11~ co~ect. ~ell ma~ke~ ~o ~ou~d o~ August 12 i~s~ectio~' to be i~co~ect. A ~ei~spectlo~ ~ill be ~ecessa~ by Au~st 1983 By Order of ~,/~.~ Approved by ' aRIGtHAL ~l~[O COMMISSIONER the Commission Date .o~m ~0-403 BY LONNIE ~. SMIT~ Submit"Intentions"in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION May 17, 1982 Re: Exxon Alaska State ."C" No. 1 ADL 28382 North Slope, Alaska Ms. Elaine Johnson Alaska Oil & Gas ConservatiOn Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Johnson: In accordance with your letter of April 22, 1982, we enclose a copy of the Well History for the above captioned well. Thank you for bringing this matter to our attention. Very truly yours, L. Longstreet RLL: et enclosure A DIVISION OF EXXON CORPORATION EXXON ALASKA STATE "C" NO. 1 WELL HISTORY Spudded well on December 3, 1980. Drilled a 17-1/2" hole to 820' and ran open hole logs. Opened hole from 17-1/2" to 26" and cemented 20" casing at 813' with 3500 sacks of permafrost cement. Drilled a 17-1/2" hole to 4000' and ran open hole logs. Set 13-3/8" casing at 3993' and cemented with 4850 sacks permafrost plus 500 sacks class G cement. A pressure integrity test (PIT) below the 13-3/8" casing shoe leaked off at 11.7 ppg. Squeezed shoe with 300 sacks class G cement. A PIT leaked off at 12.3 ppg. Squeezed shoe with 300 sacks class G cement. A PIT leaked off at 12.2 ppg. Drilled a 12-1/4" hole to 6431' where the hole was kicked off to the east using a Dyna Drill. A 12-1/4" hole was directionally drilled to 11,131' where open hole logs were run. Set 9-5/8" casing at 11,119' and cemented with 2470 sacks class G cement. A PIT leaked off at 15.6 ppg. Squeezed shoe with 300 sacks class G cement. A PIT leaked off at 15.7 ppg. Squeezed shoe with 300 sacks class G cement. A PIT leaked off at 16.0 ppg. Directionally drilled an 8-1/2" hole 11,241' where the 9-5/8" shoe was squeezed with 400 sacks class G cement. A PIT leaked off at 16.7 ppg. At a drill depth of 11,623' a PIT leaked off at 15.1 ppg. While tripping in hole with a new bit at a drill depth of 1_~2~ an obstruction was hit at 11,237'. A sidetrack hole was kicked off at 11,256' and directionally drilled to 13,171' with an 8-1/2" ~'i~-~ ......... ~p~n hole logs were run and a 7" liner set from 10,536' to 13,146' and cemented with 1150 sacks class G cement. Two squeeze jobs were performed on the 7" liner lap, each consisting of 400 sacks class G cement. A PIT at the 7" shoe leaked off at 17.8 ppg. A 5-7/8" hole was directionally drilled and cored to 13,761'. Five cores were cut from 13,431' to 13,731'. The final total depth of 13,761' was reached on April 21, 1981. Open hole logs were run and a 4-1/2" liner was cemented from 12,848' to 13,757' with 200 sacks class G cement. The 7" casing was tied back from 10,536' to the surface and cemented with 250 sacks, class G cement. A DST through perforations 13,666'-13,706' flowed water at a rate of 803 barrels per day. Perforations were squeezed with 100 sacks class G cement. A DST through perforations 13,426'-13,560' flowed gas at a rate of 510 MCF per day and 37°API gravity condensate at a rate of 130 barrels per day. After.acid stimulation the interval flowed at a rate of 3,400 MCFG per day and 847 BC per day. Squeezed perforations with 350 sacks class G cement. A production test through perforations 13,630' to 13,654' flowed 558 BW per day, Squeezed perforations with 250 sacks class G cement. On a DST through perforations 11,476'-11,504', 11,512'-11,564' and 11,576'-11,600', fluid did not reach the surface. From a 36 hour test, 56 BO and GCM was reversed out. Squeezed perforations with 300 sacks class G cement. Tagged top of cement at 11,258'. Cut 7" casing at 2500' and recovered 60 joints. Placed a 100 sack perma~r~~9~9~nt plug on top of a ~Al~sk~ Oil & Gas Cons. Commission Anchorage ( C I TIAL bridge plug set at 2405' (TOC at 2200'). Displaced casing with 10.2 ppg CaC12 water from 60'-2200'. Placed a 26 sack permafrost cement plug from surface to 60'. Pumped 300 sacks class G cement followed by 170 barrels Arctic pack down 9-5/8" x 13-3/8" annulus. Installed a 13-5/8" x 5000# flange with a 3" x 5000# valve at surface. Well suspended at 1430 hours July 14, 1981. ECEIVEi) MAY ! ~,~ ~982 Oil & Gas Cons, Cu~nmission ~chora§e September 15, 1981 Mr. R. D. Ottman Exxon Company, U.S.A. P.O. Box 4279 Houston, Texas 77001 Re: Exxon State "C" No. Sec. 14, T9N, R23E North Slope, Alaska Dear Mr. Ottman: In reviewing the material received on the subject well accompanying your August 13, 1981 letter we note that the following items were not included: - Complete well history (20 AAC 25.070) - Dipmeter survey (20 AAC 25.536(b)(5)) - Digitized magnetic tape (20 AAC 25.536(b)(6)) Please send these missing items at your earliest convenience and eliminate your company's present non-compliance with AOAGCC regulations. Very truly yours, William Van Alen Petroleum Geologist COMPANY, U.S.A. POST OFFICE BOX 4279· HOUSTON, TEXAS 77001 EXPLORATION DEPARTMENT GULF/ATLANTIC DIVISION ALASKA/PACIFIC DIVISION R .D. OTTMANN OPERATIONS GEOLOGY JNFIDENTIAL August 13, 1981 Re: Exxon Alaska State "C" No. 1 ADL 28382 North Slope, Alaska Mr. Hoyle H. Hamilton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: We are attaching two copies of Form 10-407, Well Completion or Recompletion Report and Log, for the captioned well which was suspended on July 14, 1981. Also, we submit the following data: (1) (2) One set of washed and dried samples from 90' to 13,761'. One blueline and one sepia print of the complete mud log from 85' to 13,761'. (3) One composite sepia, one composite blueline print and a digital magnetic tape of the following open hole logs: Dual Induction BHC AcouStilog Compensated Neutron Densilog Compensated Densilog (4) Summary of formation test data. (5) Core chips taken at 1' intervals from the following cores: Core No. Interval 1 13,431'-13,490' 2 13,490'-13,550' 3 13,550'-13,610' 4 13,610'-13,700' 5 13,700'-13,731' (6) One copy of Sperry-Sun gyroscopic survey. Please note that the above material is marked confidential and should be kept confidential in accordance with the provisions of 20 AAC 25.537(d). RECEIVED Yours very truly, R. D. Ottmann RDO: RLL: e t attachments A DIVISION OF EXXON CORPORATION AUG 1 ) 1981 Nasl~ Oil & Gas Cons. Commission /~chorage · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. :Exxon Corporation 80-46 3. Address 8. APl Number :Pouch 6601, Anchorage, Alaska 99502 50-089-20011 4. Location of Well at surface 660' EWL & 660' SNL, Sec. 14, T9N, R23E, U.M. 9. Unit or Lease Name Alaska State "C" 10. Well No. NO. 1 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' KB ADL 28382 For the Month of. July ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Total Depth 13,761' (mo. footage 0'). Cut 7" csg at 2500' and recovered 60 joints. Placed a 100 sx permafrost cmt plug on top of bridge p~lug set at 2405' (TOC at 2200'). Displaced csg with 10.2 ppg CaC12 water from 60' to 2200'. Placed a 26 sx permafrost cmt plug from surface to 60'. Installed a 13-5/8" x 5000# flange with a 3" x 5000~ valve at surface. Well suspended at 1430 hours 7/14/81. 13. Casing or liner run and quantities of cement, results of pressur9 tests Pressure test TOC at 11,258' with 1500 psi for 15 min. - OK. Pumped 300 sx class 'G' cement (15.8 ppg) followed by 170 bbl Arctic pack down 9-5/8" x 13-3/8" annulus. ,14. Coring resume and brief description 15. Logs run and depth where run RECEIVEI) AUG 1 ) 1981 011 E Gms Cons. Commission /~chorage 1 6. DST data, perforating data, shows of H2S, miscellaneous data DST #4 from peris 11,476'-504' (2 spf); 11,512'-564' (2 spf); 11,576'-600' (4 spf). R~n nitrogen cushion to 4151 psi. IF 10 min, ISI 61 min, FF 36 hrs. 20 min., FSI 28 hrs. 37 min. Fluid did not reach surface. Reversed out 56 bbls 0 & GCM. IF 6004 psi, ISI 6566 psi, FF 3690 psi, FSI 6063 psi. Squeeze peris (DST #4) with 300 sx class 'G' cement. Tag TOC at 11,258'. ,, 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~~. ~ TITLE Supervisor - Operations Geoloqy DATE August 13: 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ' ~: STATE OF ALASKA ALASKA,~ .~NDGASCONSERVATIONC;.~/' 41SSION I~01tFIDENTIA!. :'WELL COMPLETIOi41OR RECOMPLETIOK. REPORT AND LOG 1. Status of Well Classifica{ion of Service Well OIL [] GAS [] SUSPENDED~} ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Exxon Corporation 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Ak. 99502 50-089-20011 -~o 0~L 4. Location of well at surface CAT'1 9. Unit or Lease Name 660' EWL & 660' SNL, Sec. 14, T9N, R23E, U.M. VERIFIED Alaska State "C" At Top Producing Interval Surf.~ 10. Well Number 3128' EWL & 707' SNL, Sec. 14,. T9N, R23E. U.M. B.H._~_~ No. 1 At Total Depth _ 11. Field and Pool 3168' EWL & 747' SNL, Sec. 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Wildcat 54 KB ADL 28382 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12-3-80 4-21-81 7-14-81I NA feet MSLI 1 ~'lTotal Dep'I;h--(MD+TVD) 18'Plug Back Depth(MD+TvD) 19' Directi°nal survey~...-.37¢j~ ~q)) . Surface YES [~ NO [] [20' Depth where SSSv set 21' Thickness °f Permafr°stNA feet MD 1950' 22. Type Electric or Other Logs Run : Dual Induction, Acoustilog, Formation Density-Neutron, Dipmeter, Velocity 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ~ CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94 H-40 Surf. 813 ' 26" 3500 sx Permafrost 0 ' 13-3/8" 72 N-80 Surf. 3,993' 17-1/2" 4850 sx Perm,500 c1"3' 0' 9-5/8" 47 R~-90&Soo-)5 Surf. 11,119' 12-1/4" 2470 sx cl'G' 0' .... 7" 32 & 35 P-110 Surf. 13,146' 8-1/2" 2400 sx cl 'G" 2,500' 4-1/2" 15.1 P-110 12,848' 13,757' 6" 200 sx cl 'G' 0' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) All perforations squeezed With cement NA 13,666'-13,706'MD (13152'-13191'TVD) 4 spf 13,426'-13,560'MD (12913 '-13045 'TVD) 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - 13,630'-13,654'MD (13114'-13138'TVD) 4 spf DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED 11~476'-11,504'MD (11061'-l1086'TVD) 2 sPf ''See AttaChment 11,512'-11,564'MD (l1093'-ll141'TVD) 2 spf 11,576'-11,600'MD (ll152'-ll174'TVD) 4 spf _ 27. PRODUCTION TEST Date~ Firs,t Production I Method of Operation (Flowing, gas lift, etc.) FORMATION TESTS ATTACHEDI , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing., Casing Pressure CALCULATED__ OI.L-BBE GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Pres~. RATE'~-- ' . 24-HOUR 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEE ATTACHMENT 'Alaska 0ii & Gas Cons. Commission ' -; ' , Anchoraoe . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,. Te r i tary Surf Surf SEE ATTACHMENT Paleocene 8200 8127 Thomson Sd 13,416 12,903 Pre-Miss 13,704 ~13,188 , 31, LIST OF ATTACHMENTS Acid & Squeeze Cement Jobs, Formation Tests, Core Data ........ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge e~~ ~ Operations Geology Sign ..... TitleSUpervisOr Date 8-13-81 , 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 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item. 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CORE DATA EXXON ALASKA STATE C-1 CONFIDENTIAL 28. Core #1 13,431'-13,490'. Rec 59' ss, dk gry, vfg, poor porosity with oil staining. Dip 0-5°. Core #2 13,490'-13,550'. Rec 60' ss, dk gry, vfg, fair porosity with oil staining. Dip 0-5°. Core #3 13,550'-13,610'. Rec 50' ss, dk gry, vf-fg, fair porosity with oil staining. Dip 0-5°. Core #4 13,610'-13,700'. Rec 15' ss, dk gry, vf-fg, fair porosity with oil staining. Dip 0-5°. Core #5 13,700'-13,731'. Rec 8' ss, dk gry, vfg, fair to good porosity with scattered oil staining. Dip 0-5°. 23' phyllite, med gry, waxy luster, no shows. Dip 10°. RECEIVED AUG 1 3 1981 Oil & Gas CODS. Commission A~chora~e ACID, FRACTURE, CEMENT SQUEEZE, ETC. EXXON ALASKA STATE C-1 CONFIDENTIAL 26. 13,666' - 13,706' 13,426' - 13,560' 13,426' - 13,560' 13,426'' - 13,560' 13,630' - 13,654' 11,476' - 11,504' 11,512' - 11,564' 11,576' - 11,600' Sqz w/100 sx class G cement. Acidize w/10,000 gal. 7-1/2% acid using 200 ball sealers. Sqz w/150 sx class G cement. Sqz w/200 sx class G cement. Sqz w/250 sx class G cement. Sqz w/300 sx class G cement RECEIYEI) AUG 1 ~ 1981 Oil & Gas Cons. Commission Anchorage FORMATION TESTS ExXoN A~SKA STATE "C,, NO. 1 TEST NUMBER DATE TYPE TEST INTERVAL 3 6/24/81 Prod 'n through Per fs 13,630'-13,654' (4 spf) Diesel CUSHION HOURS TESTED 47 hrs. 26 min. PROD ' N FOR TEST PERIOD 265 BW CHOKE SIZE 20/64" FLOW RATE (1) 558 BW/D FLOWING TBG PRESS 242 TBG SIZE 3-1/2" IFP ISIP FFP FSIP Based on 3 hour stabilized test 4 7/3/81 DST through Perfs 11,476'-11,504' (2 spf) 11,512'-11,564' (2 spf) 11,576'-11,600' (4 spf) Nitrogen 36 hrs. 20 min. 56 BO & GCM 20/64" (1) 58 psi 3-1/2" 6004 psi 6566 psi 3690 psi 6063 psi (1)Fluid did not reach surface CONFIDENTIAL FORMATION TESTS ~.X×ONA~SK~ sTAT~ "C" N0, i Page 1 TEST NUMBER DATE TYPE TEST iNTERVAL CUSHION HOURS TESTED 5/30/81 DST Through .Perfs 13,666'-13,706' (4 spf) Nitrogen 12 hr s PROD' N FOR TEST PERIOD CHOKE SIZE FLOW RATE 160 BW 32/64" (1) 803 BWPD FLOWING TBG pRESS TBG SIZE IFP" ISIP FFP FSIP 205 psi 3-1/2" 8256 psi 9498 psi 5887 psi 9757 psi (1)Based on 4 hour stabilized test 2 6/8/81 DST Through Perfs 13,426'-13,560' (4 spf) Nitrogen 32 hrs 576 MCFG + 147 BC 48/64" (1)510 MCFG/D & 130 BC/D (37° API Gty) 200 psi 3-1/2" 8098 psi 9575 psi 1022 psi 9973 psi (1)Based on 6 hour stabilized test 2A 6/13/81 Potential Test After Acid 13,426'-13,560' (4 spf) Diesel 24 hrs. 20 min. 1,766 MCFG + 420 BC 17/64" (1)3,400 ~.~C~ FG/D & 874 BC/D (37° API Gt¥) 2364 psi 3-1/2" (1)Based on last flow rate prior to water breakthrough CONFIDENTIAL TRUE NORTH CONFIEIENtI, L -. . . SURFACE LOCATION SEC14 T9N R23E - 660 FNL 660 FWL-- ~ 2495.54' S 88° 18' E Exxon Company, U.S.A. Our Boss Gyroscopic Survey Job No. Boss-16801 Alaska State C-1 Survey Date: May 23, 1981 Operator: Tom McGuire HORIZONTAL PROJECTION Scale: 1" = 500' EXXON ,COMPANY ALASKA STATE WELL NO. $_.,~- I l L)~...A.Ti.. F I E L ~. ............... NOR,TH SLOPE,~ ALASKA BOSS SURWEL TRUE L__'.PJEA. s_U...R.E._D. ...... V E...R..T_ I_C A L DEPTH DEPTH C-1 DATE OF SURVEY VERTICAL SECTION DIRECTION SUB SEA TVD COURSE ......... s.p..E_R_.R_Y=$.U_N.,__I_N C · RECORD OF SURVEY .?'--'.'.~ COURSE DOG'LEG PAGE I MAY 2;5, 1981 N-90-OO-OO-E BOSS-16801 INCLINATION 'DIRECTION.- SEV DEG MIN DEG MIN DEG/iO0 ...-.. R,~_C_!'_A_N_~_U__L_A_R.-i.':::'-i:?:-.'" C 00 RD IN ATE S NORTH/SOUTH .EAST/WEST VERTICAL SECTION 0,00 0.00 100.00 100.00 t ~200.00 200.00 !. 300.00__300.00____ 400.00 /+00.00 -54.00 46.00 '146.00 246.00 346°00 0 14 S 46 48 E- ' 0 11 N 40 42 E 0_3_7 .s_4.~_...,..~ ~_E '...' .. ,~ _ 0 8 N 59 54 E 0.00 N 0.00 E 0.00 .15 .41 .69 .96 ! -' · 500..00 ......... 5.0_0...0.0 ..... 600.00 600.00 700,00 699,99 .80.0..,.00 ...... 799,99 900.00 899.99 g.~.6~O0 546,00 645,99 745,99 8q5.99 .0__20 .......0 12 0 18 0._.3 2 0 26 .__10.0_0,.00 ........ 999.,~9 ........ 1100.00 1099.98 1200.00 1199.97 _.3,300_~_0_0 ........ 12g9.96 1400,00 1399,95 9.4.5:_99 1045,98 1~45.96" 1345.95 0_2.5. .~ 0 27 0--. 56 0 .'; 53 0 43 3_.30 ..... 4.21 4.9R 5.95 -- 6,8q ..500.00__1499.94 F ~VI600,O0 1599.95 | 1700.00 1699.9~ i 1800,00 1799,92 1900,00 1899,91 2C00,00 1999.90 I 'z'£O-o. o o t 1445,94 1545,93 1645-9;5 1745.92 1845.91 1945.90 2045,88 2145.87 2_2_~_5_,_8.6 2345,84 O' 39 :..'::::.:'..<·:i: :.'i'::': S:':.' 72 !iiii!:.:.'4'.Si:;!'E.:~!i<·!;::~ii!.!i.::.-. 25·<:i> !!! '-_i.,~,,. <.i~i:?9'3'2·i'i!'!S;i:!::]iiii!i?;;!:i?.?i!:!i.i!;~iii;:i' 0.39>: E:i:';:~?'i '::".' :' 10. 39 0 54 S 77 30 E .26 ~ 9.66 S 11.70 E 11.70 1 7 N 76 42 E .50 9,61 S 13.42 E 13,42 0 4. 7 '-. '" ":. '.': N': 53 -:: 12.~L E::..;: ..._.;: :.'.::'"'~:': · 51 .'..'-"::.'-~.'::~. ".:':':::: ~:{~:~:...~: -:'. 8. :98 .:.' S."..:~"',:;~":??';:-:>~;.:.:::~::?::~. 1'.~ · 9 1 ::.'. E .~':?:.;?..<...:..:' 1 q · 9 1 o .'.:; ': .' ;,. 15 8' E::??:?. /:.:> :' 2500,00 2499,82__ 26 27 ........ 28 29 00.00 2599,82 00,00 2699.81 00.00 2799,81 00.00 28~9.80 2445,82 2545,82 2645.81 2745.81 2845~80 0 50 S.__¢l 30 E .67 5.82 S 20.45 E 20.45 0 32 ..-.- N-'79:30/-E?..:.-.:.:::-:.<--..'..37 :i;;~.;~:'-;i:.:::i:~;:':;5.84 S ....::':>'.:<.....'.'....: 21.62 E 21.62 0 3 3 N'"' 7 2:~' 3.0. E' ~i!i¢?>'i;';:?.- · 07' .:'~-:-:?<"~:i:i!~?!? '5,61'-> S. ?:./.:?::..?~i!.;:.>: 22 · 53. E ' ' ' 22 · 53 0 39 N 69 6 E--- .11 · 5,27'S ..::.' ":'23,52 E 2~o._52 0 27 N 86 42 E .26 5.04 S 24.44 E 24.~4 · !'EXXON COhPANY i ALASKA'STATE WELL NO, L__WILDCAT FIELD C-1 -- . A~E 2' ...... · "- DATE OF' SURVEY MAY 23, 1981 "~ .--' .... - VERTICAL.SECTION DIRECTION N-90-OO-OO-E BOSS SURWEL TRUE SUB .... MEASURED VERTICAL SEA DEPTH DEPTH T-VD BOSS-16801 SPERRY-SUN~ INC. COURSE COURSE .-.'.i '.'.goG'J.r_u..<~I<'.' INCLINATION .. .... DIRECTION SEV >-.i":~.RECTANGULAR COORDINATES VERTICAL 3000.00 2999.80 2945.80 3100.00 3099.80 3045,80 , ~00.00 3199,79 3145,79 ~-J'300,O0 3299 79 " 3245,79 3400.00 3399.78 33~5o78 26 2'8 26 3l 0-'5'8 S 76 30 E .13 5.11 S 25.21 E 25.21 -~..,i* N:.:~.78:':~36 E .... ,20'::-:'.::<.:<i!?<7.:~.> 5,12 S ':?'~N:'."71.'18 E:: "": >.:". 06".-!:..:~ i:..--':'.:.. ."" 4.92 S ,;.~.";N~.::.,:,78':'".24::::E '"" "' /'- '09:~{/i<;~i~>!<'.;'-::;''' '. 4.70 S N 7.6 30 E ,45 q.42 S :<<';'.~.~....:i<;i<.?;i:~:27.53 E ........... 25.97 26.73 27.53 2-8 .-;~I8 ...... 3500.00 3499.77 3445.77 5600.00 5599.77 3545.77 3700.00 3699,76 . .3645.76 3800.00 3799.76 37~5,76 3900.00 3899.76 38~5.76 0 32 0 35 0 17 0 23 0 14 N 56 0 E .50 3.96 S 29.98 E 29.98 2.61 s-;-':?!i?~!i??:il;!i'~z'-'3o"E"'."..::'. 31.3o .... >< ::.::....-:':..:.'::; ,f , 2,18 S 30.98 E "'$-0-;-9'8 4000.00 3999.75 3945.75 4100,00 q200,O0 4300.00 4400.00 ,~099.73 40,,5.73 4199.72 4145.72 4299.70 42,45.70 ,+ 3'9 9"'6 8 ..... -4~ 4"5-,-6'8 '500.00 4~99.66 4445.66 j ~-,,"600.00 ~59'9.'64 ~545.64 4700,00 4699,62 4645,62 4800,00 4799,61 47z~5,61 4900.00 4899.59 ..... 4-~'~-5""59 5000.00 4999.57 4945.57 5100.00 5099.5~ 5045-.-5% 5200,00 5199,49 .51~5,49 1__5300,00 __5299,~Z~ 52~5,44 i 1 1 11 0 49 1 1 1 13 1 7 1--i" 9 0 56 0 52 1 5 1 10 i 55 1. 41 5400.00 5399.39 5345.59 2 4 S 59 18 W 1,05 2,45 S 30.10 E 30,10 .::' S. ~..-53 · 36- w .... :::..-.,..:...-:20. ' '. .... - 31~'2'~ ~!<?i.i.~.~<;.<'~'?..i:,.~?!{:~;<:~-8~.-~'O~E .!i~' ...... ~.:... 2-8-T5-'0' ';~!ili~ S:i>~'li;:''. 30"':'W<~: ':':?/~'~; < > . ~. 7 ~":; S' ?~:.~:~'..??~?~[{~27''''3 0:'~:; E:<?~?:??: 27.30 s 25 S 8 5~ S ll 5~ W .15~ 9.99 S 25.65 E 25,65 S :q:-' +>:l'2~E...¥<q:<~><:.-.. ~ 0 --S?l":O ':;.:.: 30 ].~'~:;E~:;~:~'~?:~:'~:;:~%:4 0 >':':<~ 14.0 ~ :~:; S' ;'~?~ '~;~:~;'~;:;~;:;~?:2 5.77 ~:~>'E'~"~: ~.;~:- :':... 25.77 S 3--i~--E .... ' .... '" ..... ; 32 ~ ][?'~'9--S .............. -'"'": ..... '2'5~6-9--E: "' .... 2576-9 S 9 36 E .15 I 19,25 S 25.92 E 25.92 S :,.;: 8:?48 -,..-E'~' 5500.00 5499.32 5445.32 j 5600,00 5599,26 55~+5,26 5700,00 5699,19 5645,19 L__,58.00.00 5799,09 5745.09 -- 59 o o .'o'o589'8';"~ 6 58 2 0 2 7 2 18 2 36 3 15 S 15 30 E ,12 34,56 S 29.07 E ' S ::: 15 i:~-..:.~ o'E:-/i:.:~::.:'~,:.-~.:~.i.~<.<~" 14'./:,/:';' '.<<;:!':~.'..:.'~-<?:, 5-8"7'0-4--S .... - . : 29 ,--~5~ E-- "~.~3~..::5~:~....~.E~.~.~{~.~:...~??~?.:~.67~.~.~.~?:......:~;.¥~?::~5~62 'S :/ :. '-32.69 E" '" 29~07 2-979-5 30,94 32.69 35'7.2'1 EX!XON COMPANY ALASKA STATE WELL NO, L_W ! L D C?~T_ F I E L D NORTH SLOPE, ALASKA BOSS SURWEL TRUE _~EASURED VER!I.,C.,A_L DEPTH DEPTH C-1 SUB SEA TVD .....~:~ ~-.: ::. _ -' . -:': --. PAGE :'.::' i.::!!.-:.i~':I:~-!'::'.'.::::~:: i>.:-<.. '--'.'"' 'D A l E 0 F S U R V E Y M A Y 23, 1 .................... 'i:. .... ..-i-....:.-.:'..........-.VERTICAL SECTION DIRECTION N-90-OO-OO-E BOSS-16801 SPERRY-SUN, INC. " ................... :' ::' '"" ¥ ' __I~..CLI~A TION D I R EC T I oN.?:i:'i.:~.::::::.-:~/~.~?~:.?:.~C.~T.A~..U.L~ R COORDI'NAT ES:?:!'::..~: VER TI CAL DEG MIN DEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 6000.00__5998.81__5944,81 '~'100. O0 6098.67 ',,~,,~200 · 00 . 6198.52 6300,00__6298,37 6044.67 '.'6144,52 6244,37 6~00.00 6398,22 63~4,22 3 7 S 34 42 E ,37 54,77 S 38,11 E 38,11 6.5.0_.~t00 649 6600,00 659 6700,00 669 6800.00 679 6900.00 689 8.. o 6 ...... 673~_ ..0.6__ 7.86 65q3.86 7.49 .6643.q9 6,86 6742,86 5.90 6841.90 3__24 S 51 12 E 1,77 7__'7.__-/+_9 S 52,65 E 52,65__ 3 q9 .... "S .... 88,-:..48;:'-E:i:::;~-i:?72,36 .-' . :'..' ".?:. ... 79,~2. S.~¥.!;::::;;<:.>:iii::~i:i;~::::>i:::i:i::;158o30 E .- .... 58.30 5 47 : ::":~!i:::;.N.'::i'i~7~:iii12.!~i;.E.!:ii 2" ":5 51:!:..-:":i:--:;i:!:::?..::i':!.-:~::i.:.:~ :'7 7' ' 87'-:':-S::}~i'~i!:i!ii~ii166.39 E.<?...i.:-:.. 66.39 8 q2 N 70 18 E 1,73 68,60 S 89,52 E 89,52 7000.00 6~94,5o I----7-100.00 .' 7092.71 7200,00 7190,67 75_OQ_..O.O ..... .7.288...~ 2__ 7400.00 7385.67 ..500.00 F-"f ~'o'o-;'o o 75 ? 7. 69q0.50 10 23 7038.71 11 21 7136.67 11 ~+8 72'34.42 12 33 7351.67 14 19 7428,08 16 26 18 57 7801.6i 23 57 N 72 0 E 1.09 -----I 2i.38 N 340.7i E __7892,67. 24 53 N 72 48 E ,99 ~ 3_5_.,_8_8 N 380,10 E · . 79'8-3-~-1'~ ..... 2'~'--2-6.. -:.ii'i!-'i.' N..74~ 2~::E~<"~:...¥?:~:~:>:..~,87.~.<:: '. .... '...! 45,87.::.N ~.:.<.~..<{~i..?;:~..'.420,88: E. '. 8073.26 26 2 -:;' ::'Ni;;:.::7 q.'":':36 :~i':;' E.:-:: !::':i:"_?:?:i:!i?':'' 61!:i:..:<.:.: ,':.::!'?i:!:{i.:!:,:57.47ii.:;"N-i~;iiii::i:i.'i':i?!'.:'i'-'?i!:::'.:462 - 7 i"::.::E"-i:.'i:< .~ ~ z ~ ~. 0 7 ~ ~ z 0 :'NZ7_.~LZ~..~L~ .~i:'i::'!':i:}i:.i:.:!:'_%0:'::'./::< <i:~' ::.: :ih ~_~.:-7.-.~U,': .:,,',',::. :::::::::::::::::::::::::::::::::::' ~5~_.7~ ~ ~ N 7~ 5~ E .5~ 7~.~_ N S~.~ E N 80 48 E 2.42 6~.60 S 105.54 E 105.54' N ' 85':?.18.? E~:.::::.:.:::~i~¥:%':..1 · 28 --' - .' '-:: :{'- 62,36":-.':"S ::~:.i~?::':.?~::: :::.'::.i"i'::l 24'. 25: :' E.":~:.i:::i:.:...:.. :; ." 124 · 25 '.:i' N.".7 6 i~ii: ;'? 0':;. ?i: E;~4:!:.:!i!i:i:.!iii~i:: :'::'92 ::.. :..:' i.!:'";::: :'?": 5 ~' 08:?!i:iS ::i:;ii?~i:il;~i~:;?ii:;i!i;!:i:.::143'. 9 8 :~:~. N 63 12 E 1.82 ~ 41.92 S 18~.66 E 184.66 N 64 18 E 2.15~ 30,21 S 208,44 236.02 J 7700,00 7671.24 7..8.0.0_..0 0 .......... 7.7 6 3 .. 8 9 7900.00 7855.61 8000~00 7946.67 ..... 8'foo.oo 8o~7.:8 8200,00 8127,26 .8300,00__8217,07 8400,00 8306,74 267.70 302,97 3~0e71 380.10 420,88 'q62,71 505,23 548.23 8500,00 1--8600.00-- L 8700,00 8900,00 8396.40 8342.40 8486,02 8432,02 8575,33 8521,35 8664.31 8610.31 8752-96 8698.96 26 11 N 78 30 E .7'4 88.66 N 591.50 E 591.50 26 29 : N 79..!ii421:~::iiE!:i.-i!!'::::;~?<:::i:?.:° ::::<:::::::::::::::::::?:::: .97.05::: N - :: :". :. 635.06. E: · 635.06 26 59 N :<81:-.::ii.30:i':i!:E:~?i!:i::~.-'i??:"i':':95:!!'~i?.:i.":?.':{lo ~. 39' N' ":'::. '.:: i:;'~::::":" 679.~3 'E · 679,43 27 19 N 82' ~8-E~'.<~:i:::."i'o68:' .'<. 110,62"N ' " 724,6~ E 72~,64 ~7 49 N 83 ~8 E .67 116.01 N 770,59 E 770.59 !'-"-EXXON CoMPA'NY i ALASKA STATE WELL L_W.I.LD ¢_A..T ..._F. ! E_L.D_ ......... NO. C-1 ..... ......... ' ·' '~; DATE~-iOF SUR'VEY. '""' MAY 2.9, 1981 ! '. .,~ · .:~ ...~.:,..~;: .'..:.:~":VERTICAL SECTION DIRECTION N-90-OO-OO-E NORTH SLOPE,, ALASKA BOSS SURWEL TRUE MEASURED VERTICAL ..... D E"P-fH .... D'E'P T'H SUB SEA TVD ......... BOSS-1680I SPERRY-SUN,~ INC. RECORD--~J'F--~-U"R'VEY . , ..-?.::':-.:-..:: .'",.. '...~;. . -'...': .' COURSE ' ' COURSE ..., D'o'G'LEGi.:.': :.i.'; AL ; .,.i:!;..?~:!;~L:~i.:i INCL.!._N.A...T.I.~_N .i:.~.~'.?.DIRECTION ;:~ SEV :RECTANGULAR...COORDINATES~.i~.:.' VERTICAL DEG MIN OY'~'--M I N iD'£"~ 7'i-0'0 N 0 R TgT'~-O-o'r H ~A-:~F'/'N E '.~"T ......... 'S~C-TI'O N ........ 9000.00 8841.27 9100.00 8929.00 200.00 9015.95 L? _ o.oo 9400.00 9189.55 8787.27 '8875.00 8961.95 90q8.55 9135.55 28 9 29 12 50 2 29 58 --2"9 q N 84 6 E .37 120.96 N 817.25 E 817.25 '. :..,; :.~;!.:~!:.. N:. 84.?" 18-~:i E' '~.!:~::.i.,..:"' 1 · 0-5', :i.'.',"~:7, '..?;~??' N ' ~:~ 8~'.~:~-'~ 2 ;':..C' E :?: ~?C'"~'· 86.'..".'~?.:~;?:-:.~'~/:{:1.S 0.54~:: 'N:'/.~:::~:C:~-- :~.?~':'.: 914:.,Li 8~? E:. :;.;":~.~ 914 · i 8 9500.00 9277.27 9600.00 9365,41 9700.00 9455.80 9800-00 9542,86 9900,00 9652,67 9223.27 9311.41 '9399.80 :.9488.86 . 28 20 N 86 24 E .74 141.40 N 1061,05 E 1061,05 28 2 '..~.:: N:i?.:86...',';:"18 .E.;:..." . .29 .-...:--;--¥?..L144,~l~;.:c:.N.,. '.;:..~,'-..'::.~.::-1.108.'.,:19.-~.E:.::-.... 1108.19 27 44 '".'/:"??N?iS:7' ii:!!i: ::i'O'..':i"E.?(-:!:? ?;;~:.''-: '. 45 ;-';::.;i:!;?i?~i:!i:':1':'.47'i~'!i?N~i'ii!!iiii:i?~i~!i::l'l:54:;":iS.7!:il;.E!i!??!i~,:'.; 1 i 54.87 26 21 ' ~':"':'~' _.:_.:.....~..:.,.:.,...N..:~;87 ?/i.2~..::. E/i: ...:,.:L,;:,.,:z . ~8.'./~"':L/.?:/:?I:'49."'-'"'"':'"'": A'4:?N'/~.;'?'/i":':'.'~;:?l 20":'"'"'-'"""":":" "'":"'"":':':':-0~'2 7:;::;;E'/~??: "'"' Z 200. 27 ~ ~ . __ ...... ........ _~~ . ..- ........ ... , ..... . . ..... ... :..., ..... ~_.~ ..: :.: 9578.67 25 50 N 87 18 E .52 151.55 N 1244.20 E i"~-4-A-.-P_-O' 10000.00 9723,00 I 10100.00 9813,87 } 10200,00 9904,77 Ll~0500.00__ 9995.52 10400.00 10086.44 500,00 10177,56 I ~600,00 10268,14 10700 O0 10558,82 ' i_108_ 0.o. .o o_ A 9.5 2__ 10900.00 lO54O.lO 11000,00 10650,45 11100,00 10720,52-- I 11200.00 i08i0. 8 14.%0_0.00 10900.7,+ 11400.00 10991,~8 9669,00 24 58 9759.87 . 24 23 9850.77: '- ' 24 5,3 99.41.52 .... 24 47 10032.44 24 26 10123,56 2~ 47 ~. . 1021~.14. 2~+ 50 10~04.82 25 2 10595,52 24 47 10486,10 25 22 10576,45 25 26 10666,52 26. 1 10756,48 25 47 10846.7 25 12 109~"-48 2'4 51 11500.00 11082.58 t ...... li'6"o'o-.-O'o----fl-l-fS'Jf7 ' 111700.00 11265.60. ~__1,!8,00 · 00 11;557.47 11900.00 11028.38 24 45 11119,77 25 7 11211.60 25 52 11505,~7 22 58 80 18 E ,95 130,45 N 1919.27 E 1919,27 79 30-'E.-' "":" .88 '/'::~:'":'~' 111.~5 N ~'~'?~'"¥"-'"~2037.39 E~'L.', 2057.39 77 36 E 1 · 0 '5 1-0~%-8'4--N ......... 2'O~-O-~'E ......... 2'075%-0'4 11449,79 11395,79 22 15 S EX'XON COMPANY ALASKA STATE wELL NO. L_W I L.D C A_T._F I ELD.. ............ NORTH SLOPE9 ALASKA BOSS SURWEL C-1 TRUE E A S U..R.E O ........ y E.R.T.,I.C A.L DEPTH DEPTH · "-L::.i!.-..L.~ .-<:.i"'C!i<~:' ~".~ <: ::"-'..'" :. 'V E R T I C A_ _L, S E C T I 0 N D I R E C T I. 0 N PAGE 5 MAY 23, 1981 N-90-OO-OO-E SPERRY-SU N.~. INC. . i '.. ". ' ~.i ."?:<< :~'.:..' ?i.'~'/.<i<.{'..-.,. '" RECORD OF:-' SURV'E.Y' SUB COURSE - .~.' C'OURS'E' :'-..i.." D"oG:"'LEGi:']';i!!':/""]:li;:/.:'ii>:i~ii..!i:;i!?';'i:i!/:i::'-!:' .':' I' '' TOT AL __SEA ......... I_N..C L I.N A.T..I 0 N -.DIRECTION .... L..,S.~_V~-!.'..:':'.':.:.:i-R..~.C.T_T..&~.G_U_LAR COORDINATES".': TVD DEG MIN BEG MIN DEG/iO0 NORTH/SOUTH EAST/UEST BOSS-16801 VERTICAL SECTION __120.00,00 115~2,53__1148.8,.53 i '~lO0,O0 11635,73 11581,73 ~,,~-200,00 11729,5~ 11675-5~ i__12300,00__1182~,12__11770,12__ 12~00.00 11919.29 11865.29 21 4. 3 S 75 30 E · 9.'5 95.1/4. N 2_.1._11 · ~2 E _2_!._.1_!_._¢.2 20 · 4- 7 '..'.~::..:..-:-.:':-. S--7-5--'~'&=T/E'.:' i.::..;"i:::! · 95;7.~.: :.:;<i!i:;ii~.i;i~{:;i~'i;i;.!;:; 85;'95 :.:i~: N ' .. ~.:: 21q 6 ·/+8 E '";.":- 21 ~ G . 4. 8 19 :. 4. 4 <.:" :" ::i!i...~; :::il;: ::i<:~i-li:'S':.]<7 4.; ..: 4:2'iE ::-:.i~;';:::~:::i>;:: 1 · 06':i:!;:;ili~i~!~i~ii!ii:iii~i~i.:;? 6::'9 3:~!iN':::~.?!~;i:':./i::::..i>;: 2179.90 E ~;:':~.!"::.: 2179.9 0 18 ;-~'_:~8 ::".:~i'<;->!.:_i:;i';;:i;;:::::S.":i'T__6.~ :i'.30 ;'.--E !'i;i:':?'.<':::: 2_.'_3.~,;':.:'i;i¢!~?ii!!'.~:'ii:!:::.ilii6 7'0 3':?:-N':% ":-i::::::i¢:?!<:!'.2. 210. 76 .E J"<::";' .',2_2_!_0_,..Z6_ ..... i7 37" s 68 0 E .69 55.9i N 2239.36 E 2259.36 ~__125 00.00. 12014.75 11960.75 17 1'2600".-0'0 .... 12'1'i'0'.-~''9 '1'2-0'56-.-~'9 ' ' 1'6~0..:~-:-.':':"... 'i.." SU69":4.2TE"-::"!.~::':i'.-<:::.56'>:i!i:-i~· 2294..14. 12700.00 12206.4.5 12152.4.5 25:'.0 1':i.: N i.: i::'iii.'i:;::i:i':~i;;;i>i'i: 1232 O' ;' 4. 7.:.::" E. ::i~i!.::i~i:/i:::/: 2.'.'520.4.7 L__i 2.800_,_00 ........ 1.2.3 02_,28 ...... '_ 1.22.~.8.,.78 1.4.'' "'__5]6 ~!i:! 5.~..ljO~_N '/i.; 'i'i:i!-_i<.;;~'-:. 234. 5'".:~+ .~E""::/i:.-.:!:..:. 2_~__~ 5 · 4. 0 12900.00 12399.50 1234.5.50 i4. 28 S 68 30 E .51 ~_. 5.6~ N 2368.95 E 2~68.95 13000.00 124.96.53 12~2.53 __13 32 __S 65 12 E__~.23 Z 3.86 S 2391.20 E 2391.20 13100.00 "12593.78 12539.78 13200.00 12691.07 12637.07 i__1.3300.00__12788.67 12734.67__ 134.00,00 12887,06 12833,06 8 58 S 4.8 6 E 3.37 4.5.19 S 2~66.34 E 24.66.34. _~3500.00 __12985.83 1 00,00 13084.,52 1 50.00 13133-80 1 ~/~' ** THE CA HORIZONTAL 29.'31.8~ 8 59 s 4.2 54 E .81 56.12 S 24.77.4.5 E 2/-+77.4.5 3030,-52 ." ' 9--3'8 ' ~<...:~.::~:.:..S?q. ZS:';.. 18<;':E '.:'....--.'. 65:!i::~:~?i~/~..:~i!~:;~!.~!!i::.~!.i;S;:.67~.~92~:~!.S.?iii;!:!~i~i~&.2488.5~!~.`E..~.:!:<;;>'~.~ 2q88.50 LCULATZONS ARE BASED ON THE ~N~U~ RADIUS OF CURVATURE ~ETHOB ** BZSPLACE~ENT = 2~95.5~ FEET AT SOUTH 88 DEC. 18 ~ZN. EAST (TRUE) T START O? SURVEY WAS [-:'-EXXON COhrANY ALASKA' STATE WELL NO'. NORTH'$~OPE~ ALASKA BOSS SURWEL C-1 ~'~'~' PA GE 6 MAY 23e 1981 r MEASURED DEPTH 154. 254. 354. TRUE V-ER T i'C-A'L DEPTH 154. 254. __ . . 354. 454. SPERR¥%'SUN, INC. ". .......... INTERPOLATED RECORD OF SURV'EY:.i..?ii!ii:!.;:::.i::i-"iii!ii.'-'.:'.~.i! ]' · ' - :':::i'!':'::?:~';i'';!:i:!''::,' T'O T A L , S U B 'g'CA ' "" .... '": ': ......... :-';-'-:':"::"~;;:fR'O'E~::::'i:'?¥:::r:-'¥':~"'i~::?:;::;>::;'"':~:" R'E'6'TA'N:~A-R----CO-OT(DTEA-T E S ..... TVD ELEVATION NORTH/SOUTH EAST/WEST 554. 654. 754. 854. 95~, 1054. 1154. 1254, ...... 1'3'5'4. 1454. 1654. ...... ~.75~' 1854'. 1954. ,.. 554 654 754 85'4 954 1-0'5'4-, 1154. 1354. 1'35'4'. 1454. 1554. 1654. 1754. 1'~ 5'4. 1954, "'. 500. ........ 800. -800. 1. s 900. -900. C~ 2. s 1 o o o. ..... .. .... -,. :yo-'~.-r ~:......i.::.?~'-:.:..:i:.:.:~..:...:.:::.i.::'~:i.:::.=:.:~?~s.:~..- . . . '4-;--E · ..~-' ....': ... :".'.;;::'.:. ?.: .:'?.:.:.~:'r:' 1..0 0 ., i l o o. :-: :::':.b.: ...... .::..:".;:'?,r:.;:.:.r'?~':;;;? l 0 0 · ':.'. '~Q~'.'.:.:'::;::'.:.:"?~:~;;?.:::~/:~ -':::'f:'s ':'; :' .:.::;. L'::'.'-'-~.~ 5 .... '"' 't200. - .~":.':':"'::~":-"::'"?.?.:::':?~'.:.~;?: 1200. :,.'~ ':: 6: E i"~o o", ......... ' .......... ...... ";i~o-o. .................. ~s .... ' .......~;--E .... m 1400. -1400. Z 7. S 7. E -: -. f~-O~.... .-. .... ......-.-..,:::::.::':,?.':::?~:~-:~'~f'S'O-O · -'.. 8-.-- ~- 160 0 ' :~ ': ~:: 600 .: -. "~.~;~?/~;???::;~?~',':~::~;.9" '~:/"S:?t:"/:;?:?~f"'::'?r 9 · E i 7 o o. :.,:::-.-;: :':':.":--.'.,..:': :'~:)::~:~;~?..~?;~;~:- ~ 7 o o · :':: '. ' ::r.':':-::/:::'"L?~;;:~'??~?:~:'~ ,T':s ;~;.":?"-'~:~"~'": 1 o. [. 1"8-0'0~ - rS-O"O'; ............ ":'"':'-' "":' ' '"'"'-"' '""-"::;: '::' :~-0'.=:' 'S' :';' "';; ~900. -~900. ~0. S 1~. E 2054, 2154, 2254. 235~o 2454. 205 215 225 2~5 245 255~. 2654, 2754. 2854. 2554. 2654. 2754. 2%'5'E · 22. E 23. E 2'4%--E----' O-T--E----' O. E 1. E 1. E '2. E 2. E E OF SURVEY . . . BOSS-16801 EXXON COMPANY ALASKA STATE WELL NO. _._W, IL.DC.~ _F.IELq .......... NORTH SLOPE, ALASKA BOSS SURWEL C-1 · BOSS-16801 · --'~4EAsURED DEPTH TRUE VERTIC DEPT AL H " ":.: .; :!ii i:? ;.. i.:.!.:,: ~!iii'!'!,ii::: :.;.'' :':. ':-'~: :,.:.:".-:.ili::i:?:'??."!'i!::i:?i..:?{'.~..:.::i..:::iil. i?:.:; .T:.::': !__.': c7.?.::.:.':?:: :'.??: i?:?.. T' O-y A'I '. ,SUB SEA TRUE RECTANGULAR CooRDINA TVD ELEVATION NORTH/SOUTH EAST/W TES EST 3054, 3254. 3354, 3454- 3054, 3154, 325~. 3354- 3454, · '. 330 O- -3300· 5, S · '3400. -3z~O0. 4. S · E , E · E 28, E 30, E 35f4. 3654. 3754, 3854, q054. 4154. 425~. 4354, 4554. 4654. 4754. 4854. 4954. 3554. 3654. 3754. 3854. 3954, 4154. 4~54. _ . - 4354. 4454· 4554. 4654. 4754. 4854, · E · E · E 3800. -3800. 2, S 31, E 3900, -3900, ~ 2, S 31, E 4 0 0 0 -. ¥:'..;.:~":?....~:.?-:'........'? ~: .: 4 0 0 0 '.'i?:ii~i!i~i~!::.~:.!?~.,. ./-.: /. :':~ :::~.?::.~ 3 :':ii~ S:~:::::!.i';!..:.c..~ ~-. 2 9 · E ~ ~ o o .:":i,~;:?.!i?~;:::.~'-i.?:.i::i.'Lii~;:' ..,:.:~ii:;i:~':':i.'~::..:/;:i: ~ 1 ~:?!::~?~?~i~.:~?:~::.~i:;?~.i!~i?ii~:;~:~i~;s:~i;i:~i~i;.i??.{??~:: 2~. E ~ 2 o o. -' ":~;.: )/.?'F;::.'.~: ::.;:?'.~.'., ;. '..-;' i- ~ 2 o o-":~.:~;:.????'~:~;;:~:.';.~''/. ':.~;~,~'~,~;~ 5..:.:~c;~Cs.;::~.:~:,c::~:.-.:...' - 2 7. ~ ~oo. -~ao. m 7, s 2~.E ~oo. -~oo. z g. s 2~.E ~800, -~800, ' ~6, S 26, E 5054. 5154. 5255· 5355, 5455. 5054 5154 5254 5354 5454 5300, -5300, 30, S 28, E 5400, -5400. 33° S 29, E 5555· 5655· 5755. 5855, 5554 5654 5754 - - . 5854 5 7 0 0. ........ - .. ,-. - 5 7 0 0. 5800. -5800, 44-'"'7s":":'/:' ""' 32. E 48. S 34, E EXXON COMPANY ALASKA STATE WELL NO. ~ILDCAT FIELD --NOR T M-- S"L-O'P E",- -A-L~-A'S K A BOSS SURWEL --M E-~'S'O R E D DEPTH C-1 TRUE V FR"F 'I C'A'LT. DEPTH '~'"~P-A"G'E' 8' "!::~:" '~<"'.:-"-:?:~":'""~""~' :':'"" "'DATE OF'-'SURVEY ...';:i'. ' MAY 2;5, 1981 BOSS-16801 .._ INTERPOLATED RECORDii~,.OF...'.suRV'Ey : . . . · .....;'... -:.;. . - ..... '.'-':' ': .TOTAL .......... S"O'B"$'E-A ........................ ' :"-:~"f'RTJ'E :' '"' ' ........... ~'E~CTA'~6-UL-A-R~C'O'O-I~TN-A-T E S TVD ELEVATI ON NOR TH/SOUT H EAST/WEST ----6055. 6256. 6556, 6456. 6054 6154 6254 6554 6454 4-O-.--E --' 4.5. E 46. E 4-9/-5 51. E 6556, 6656, 6757. ---68'58.I 6959. 7061. 7165. 7265- 75'6'7· 7471. ~~-5, 7682. 6554 665~ 675~ - 685~ 695~ · .... .. .... ...::., ,..,,... .: ~ ..,:., .... ...... · ~, _~:...:._ .:.,.~'. '..-.L~..'--...c. _' ..... 6'8'00· -6800. 71-. S ~-4"T'"-E' 6900. -6900, 66, S 99, E 7054. 7154. 7254. 7554. 7~54. 7554 76'54 7500. 7400. 7789. 8008. ,,; 8119, 8230. 8455. 8564. 775~. 785~. 8054. '8154, 8254. 8554. 845~· -7400. -E2127 5~. S 201. E 7 z o o.' ". 7 o o'. '.'~??:'t":;~?:~;:~';7':'''':~.::::. ~". :7. '::-N :?:~..;~:';;:::.~'... :::.":. :'"? 2 s ~. E ~7'8'o'o. '::"':" .......... :""":'::'::"?:-": .... '""-'TS-O"O', ~"':'""~';' '-:':""'""' '"" ........... Z~';~ ...... .... "'" ' ' 7900. -7900. 55, N ~8~. E 8500. ......... "' ............ ' ........ '-::':' ...... ' ....... ' ....... '"":'" ..... -85oo. '"' .... ' ........................ "':'"'" ¢;'~i~ ..... '"" ..... 5-"T1-;--E 8400. -8400. 9~. N 619. E 1--8676- 8788. 8901. 8 8 8 554 651~ 754 ~'5k &-6-9~E -- 719. E 771. E 8~'4%-'E EX,X ON COMb"ANY ALASKA 'STATE UELL NO. __W I L D C_A_T.. _F.I EL D NORTH SLOPE, ALASKA BOSS SURWEL C-1 ..............- ' , PAGE 9 ' L'.DATE OFi'suRvEY ;.;~ . MAY 23, 1981 BOSS-16801 MEASURED DEPTH TRUE VERTICA DERTH INTERPOLATED RECORD';.!OF". SUB SEA TRUE RECTANGULAR COORDINATES TVD ELEVATI ON NORTH/SO UTH EAST/WEST 9244. 9359. 9587. 9700. 905~ 9154 9254 9354 9200 ;.. i.:~ ?~-!~i?;,;?'?'.'i::.i~ii?{i!!~?~!!!i;~i;.~?i:.Zi',.,~20'0 ,:i'!i~iiiil. :' ~' :..i: ":~. ,'~i-{'. :i }/-?ii:',:}ii,..'~.'A~. ~"~!!;~ .N.'?:i':i! '~f!:!~-'ii';tfli.! :;~.:-.: _ ~A~ 8. 9300. -9300. 1~. N 1102. "9~00. -9~00. 1~7. N 1~55. E E E t t 9812. I9924. ....... ~. 10144. 10254. 9554. 9654, 9754, 9854. 9954. 9800. -9800. 155. N 1347, E 9900. -9900. 156. N 1393. E 10364, · 10054, 10474. 1 o_5_8.~_. 10695. 10805. ~~o9i5. 11026. 11157,__ 11248, 11359, j 1 10154. 102..54 · --f'o-3 5~. 10454. 1469, 11578, __1_1.68~ 11796, 11905, 0554 06.5~ 0754 10300. -10300. 159. N 1577. 10400. -10400. (222) 158. N 1624. · ..-:~: :< :.:.!-.. ..... :'~,::.':.:-:i:::?.i.'.::.:':!'?':!'.?',;.:;<:.%!'~'~:~:"~::~?..::...:~:._..~ ........... ?.. ......... ...... -- ~ ...... ,.:......, ......... . .... i o5o o . . 10800. -Z0800. Z ' 1~6. N 1815. zo~oo. -~o9oo. ~ ~. N 10854. 10954. 11054. E E E E 1861, E 11300. -11300. 112. N '2036. E 11400. -11400. 103. N 2077· E 1115~+. 1.1. 2.5.3_-__ 11354, 11454, I 1 2012. 2120. 2226. 2331. 11554, 11654. 11754. 11854. 11q~. EXXON COMPANY ALASKA-STATE WELL NO· L_~! LD~ A__.T___F. !E.L~._ ' NORTH"SLOP£, ALASKA BOSS SURWEL . . C-1 MAY 23~ 1981 BOSS-16801 MEASURED DEPTH TRUE VERTICAL DEPTH s'i5'~'1~]~-k-=$ UN, INTERPOLATED RECORD SUB SEA TVD INC ...... ' ........ ' ........ .. .:>-.:'.':..::'i..': '.:~Y.~::..':: :!':/:, ...'i{.'. ~: . '. : .' '..:' '..' :: T 0 T A L T R U E CO-O-R-OTN-A-I'-~ s ELEVATION NORTH/SOUTH EAST/WEST 12541· 2645, 12853, 12956, 13162 13265 13366 13468 12054, 12154, 12254, -- 12'3'5'4C 12454, 12554, . . . 12654,~. 12754,.:'i':'..' 12954, ·. ':i:;.:. 12200 °':' ::ii!ii:..:':'~i: '::. : :. ' ' 12200 2333 o .12"30'-0'~ ................ ='~2-3"0'0'~ '~'" ..... ""': ..... '12400· -Z2AO0·~ ~ O, N 2382, · : 12600, !i ;:.-: iii!ii~!):iii:!ii::!i~ii~}~!20 ~i!S!5{iiiii!:ii~i?ii'ii.:!i:i!:'i 2425. 12800, -12800, 12900° -12900· r'-' 52, s 2474° 13569 13650 :FROM 0,00 FEET TO 13079.80 FEET CURVE DATA LO..CATED IN THE APPEND.IX July 28, 1981 Mr. A. L. Hermann Dril ling Manager Exxon Company, U,S .A. Pouch 6601 Anchorage, Alaska 99502 Dear Mr. ~rmant We~~ SUNDRY NOTICES AND REPORTS ON WELLS form on~a=.e c~ Only one copy was submitted of the two necessa~, as stated on the form. We will make a xerc~ copy of the form this time but in the future we will not process any forms until the correct number are submitted. Yours truly, Chai.r~an HHH ~ be E~(0N COMPANY, U.S.A. POUCH 6601 · ANCHORAGE. ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS July 22, 1981 Mr. Hoyle H. Hamilton, Chairman State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Hamilton: Attached for your use is Form 10-403, which describes the suspension operations performed on Alaska State C-1. Also attached is an "as suspended" well sketch. Very truly yours, ~nn Drilling Manager JEO:sjm Attachments 295-662-100 RECEIVED JUL ~ ? 1981 A DIVISION OF EXXON CORPORATION STATE OF ALASKA ALASK ,L AND GAS CONSERVATION C .,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Exxon Corporation 3. Address P. O. :Box 2180, Houston, TX 77001 4. Location of Well COMPLETED WELL [] ~ ~ u ~ ~ ~.'P~l~it No. ~,,, ,'~ ,-- ~,.L.~ 80-46 ~U~ ~ APl Number s0- 089-20011 At Surface: 660' EWL and 660' SNL, Sec 14~1¢~,,,u~ T9N, R23E, U.M. At Bottom Hole: 3168' EWL, 747' SNL, Sec 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 28382 12. OTHER~[ 9. Unit or Lease Name · Alaska State "C" 10. Well Number Exxon #1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] XZ Suspend 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A. With retainer at i1,350', the last test interval was squeezed with 280 sacks of cement below the retainer. 20 sacks were left on top of the retainer. The cement was tagged at 11,258', and then pressure tested to 1500 psi. B. The 7" 32~ P-110 production casing was cut and recovered from 2500'. C. A bridge plug was set at 2405'. 100 sx of Permafrost cement were balanCed on top of the bridge plug (calculated TOC 2163'). The drill pipe was pulled to 2200' and reversed out, leaving the top of cement at 2200'. D. The plug was pressure tested to 1500 psi. E. A 10.2 ppg Calcium Chloride solution was circulated into the 9-5/8" casing at 2150'. F. A plug of Permafrost cement was placed from 60' to surface. G. Waste fluids on location were pumped down the 9-5/8" x 13-3/8" annulu H. 300 sacks of Class G cement followed by 170 Bbls Arctic Pack were pumped down the 9-5/8" x 13-3,/8" annulus. Estimated location of cement is 2900' to 3993'. I. The 9-5/8" x 13-3/8" annulus was pressure tested to 1000 psi. Note: The well site will be in condition for final inspection by July 1o 1982. 14.1 herebycertify~!· t~~~he Signed ~ The space below for C,~ s; - ' ' ~ best of my knowledge. Title Drilling Manager Date July 23, 198 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA STATE C-1 As Suspended EXXON USA PROPRIETARY 94# H-40 STC Conductor at 813' Top of permafrost cement at 2200' - Tested to 1500 psi Bridge Plug at 2405' 7" Stub at 2500' 9-5/8" x 13-3,/8'' annulus: Arctic Pack 0'-2900', Class G cmt 2900'-3993' 7" 32# P-110 LTC-Tied-Back from 10,536' to surface 9-5/8" 47# RS-90 & Soo-95 Protective at 11,119' TOC in 7" 11,258' ('Tagged and tested to Retainer at 11,350' CBL 1500 psi~ F-1 Packer at 11,425' DIL Perfs: 11,476' - 11,504' DIL 11,512' - 11,564' DIL 11,576' - 11,600' DIL --11,846' TOC at 12,552' - Tested to 7000 psi - Retainer at 12,695' not tagged F-1 Packers at 12,775' & 12,772' 4-1/2" Liner Hanger at 12,848' 7" .35# P-110 LTC' Production/Protective at 13,146' 15.5 pPg mud Perfs 13,426' - 13,560' DIL~)~ Perf.s 1~,/~ 13,654 TOC a~3, ~' Perfs~6' - 13,706' DI 4-1,/2" 15.19 P-110 LTC prOduction Liner at 13,757' Total Depth 13,761' ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto Chairman ~ ~ ~ THRU~ Lonnie Smith Commissioner Bobby Foster ',?? ~' Petroleum Inspector July 16, 1981 Witness Surface Cement Plug Setting on Exxon's Alaska State C-1 -- Well Suspension. Monday, July 1.3,...!9.8! After witnessing the BOPE test on SOHIO's A-14 I flew via ERA helicopter to Exxon's State C-1 and witnessed the setting of the 50 foot cement plug at the surface. The plug consisted of 26 skso of permafrost cement slurry and returns were received at surface. Attached to this report are pictures of the equipment to be installed on the well. The marker post will be bolted on top flange until the rig is moved off location and then it will be welded to the flange. In summary, I witnessed the surface cement plug setting on Exxon's Alaska State C-1 for well suspension. BF~be ' CONFIDENTIAL O /,-~ STATE OF ALASKA /. '~ ALASKA\~ . AND GAS CONSERVATION C{..~ .~IISSION NTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50_089-20011 4. Location of Well at surface 660' EWL & 660' SNL, Sec. 14, T9N, R23E, U.M. 9. Unit or Lease Name Alaska State "C" 10. Well No. 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54' KBI ADL 28382 For the Month of. June ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks · otal Depth 13,761' (mo. footage 0')o Plug Back Depth 12,700'. End of month operation is reducing NW from 15.6 to 13.3 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data Sm A~A~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~r~~ ~ Supervisor- SIGNED .,/~"/~ _~ /~~ TITLE Operations Geology REC[::IVED JUL 5 Il Gas Ceils, DATE July 15, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Submit in duplicate Rev. 7-1-80 · , ( I]ONFtDENIiAL 16. Squeeze perforations 13,666' - 13,706' with 100 sacks class 'G' cement. ~. ~'_.DST #2 13,426' - 13,560' (4 spf). Ran nitrogen cushion to ]~ 5638 psi. IF 11 min., ISI 85 min., FF 32 hrs. On a 6 hour %%\-} ~ stabilized flow test the w~e]_L__~.roduced gas at the rate of 510 ~CF/day and 130 bbls~~qns~day on a 3/4" ck with 200 psi wellhead pressure. IS~-~9575~psi, IF 8098 psi, FF 1022, FSI 9973 psi Acidize 13,426' - 13,560' with 10,000 gallons 7-1/2% acid and z~,~,~-~' 200 ball sealers displaced with 98 barrels of diesel. Flowed well for 24 hours 20 minutes. The diesel cushion was recovered in 51 minutes'. After a 3 hour clean up period the well was tested with the following results: Tbg Press ; ', Ac i d Minutes Ck Size (psi) Gas (K~/D) Cond (B/D) Water (BPD) 28 13/64" 3230 2800 394 394 24 15/64" 2776 3150 816 86 28 17/64" 2364 3400 ~74 79 When choke was opened to 19/64 r_brea occurred from a zone below the perforations~at%d_~~during the rest of the flow period ranged from 20 to 85%. On the final 6 hours the well flowed gas at a rate of 1600 ~ ~cf/d, condensate at 280 BPD and water at a rate of 813 BPD on a 19/64" ck with a flowing tubing pressure of 1550 psi. Squeeze perforations 13,426' - 13,560' with 150 sacks class 'G' cement. Squeeze perforations 13,426' - 13,560' with 200 sacks class 'G' cement. Conventional Production Test #3 13,630' - 13,654' (4 spf). Ran diesel cushion. Flow tested well for 47 hours 26 minutes. On a 3 hour stabilized test the well flowed w/242 psi tubing pressure on a 19/64" choke at a rate of 558 BW/day. Squeeze perforation. 13,630' - 13,654' with 250 sacks class 'G' cement. E: ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS July 13, 1981 Alaska Department. of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska 99701 Attention: Mr. Doug Lowery Gentlemen: COMM I 1 STAT TEC~ An oil spill' occurred o~.xon's Alaska State C-1 Well location at 0230 ADT on July 9, 19-~'"i] :~'~--'~ .......... Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Mr. R. L. Westbrook to Ms. Gloria Thomas of the Alaska Department of Environmental Conservation at 0955 ADT on July 9, 1981. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: July 9, 1981 at 0230 ADT. · Location of the discharge: Exxon's Alaska State C,.1 location in S14,T9N,R23E,UM. · Persons causing or responsible for discharge: None. Discharge was due to equipment failure. · · Type and amount of discharge: Waste diesel oil, 8-10 gallons. Cause of discharge: Check valve failed on injection pump suction and allowed oil and waste water to siphon from slop oil tank into sanitary waste pit through injection pump. 6. Environmental damage: None. Oil remained on location. · Cleanup actions undertaken: Oil was skimmed from sani- tary waste pit with skimmer and transferred to slop oil tank for injection into well annulus. Absorbent mater- ial was used for final cleanup of sheen on water surface. RECElYED A DIVISION OF EXXON CORPORATION JUL 1 4 1981 Alaska oil &'Gas Cons. C°mrniasior~ Anchorage Alaska Department of Environmental Conservation July 13, 1981 Page Two · Location, method and date of disposal of discharge and cleanup material: Oil skimmed off of waste pit was injected into well annulus. Contaminated absor- bent was incinerated in Camp incinerator on 7/9/81. 9. Action taken to prevent recurrence: Check valve was replaced. Please contact me at (907)276-4552 for any additional informatiOn you may require. A. L. Hermann JRH:jmw 240-910 cc: Mr. Hoyle Hamilton Alaska Oil and Gas Conversation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle 18ECEIVED 'JUL 1 4 1981 /llaska Oil & Gas Cons. Commission Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [~: COMPLETED WELL [] OTHER [] 2. Name of Operator 3. Address 4. Location of Well At Surface: Exxon Company, U. S. A. 660' EWL and 660' SNL, Sec 14, T9N, R23E, U.M. At Bottom Hole: 4250' EWL, 660' SNL, Sec 14 T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) +25 MSL I 6 . Lease Designation and Serial No. ADL 28382 12. 7. Permit No. 80-46 8. APl Number 50-089-20011 9. Unit or Lease Name Alaska State"C~ 10. Well Number Exxon # 1 11. Field and Pool Wildcat Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment I-~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~ Suspend Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The attached procedure is a detailed description of the suspension operations. Anticipated starting date is July 11, 1981. RECEIVED JUL 1 0 t~l Alaska Oil & Gas Cons. C0mmJssi0~ Anchorage Signed ~' ~. '/~/~~_~' Title The. spa;~below/or Comm'/sion use ..... for A.~. Hermann Conditions of Approval, if any: ~ Approv~ C~y Eetum~ By Order of Approvedby ~Y HOYLE H:~A~[T~ COMMISSIONER the Commission Date .. · uDm~/"lntel~ns' in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports"in Duplicate ~(~:'~ ~ Proposed ( Wellbore Schematic After Suspension AlaSka State~C-1 Surface plug O- 60' MD 20", 94 ppf, H-4~ STC Conductor Csg @ 813' MD TOC @ 2200 ' Bridge Plug @ 2400' MD 7" Csg stub @ 2500' MD 13 3/8", 72 ppf, N-80, BTC Surface Csg @ 3993' MD Arctic Pak to 3600' Class G Cement to 3993' (100 Sacks) .4ppg Mud JCC: dag 7/9/81 7", 32 ppf,. P-110, LTC Production Tie-Back to 10536' MD 9 5/8", 47 ppf, 47 ppf, RS-90, BTC Protective Csg to 11119' MD TOC in 7" @ 11235' MD EZSV @ 11350' MD Baker F-1 Packer @ 11425' CBL Perfs 11476 - 11564' CBL, 2 spf, 0° Phasing TOC @ 12550' MD EZSV @ 12695' MD Baker F-1 Packers at 12775 and 12772' MD 4~" Liner top @ 128~8' MD 7" 35 ppf, P-il0, LTC Production/Protective Liner to 13146' ' . - 0° Phasing Perfs 13426 13560' CBL, 4 spf,- Perfs 13633 - 13651' DIL, 4 spf, 0° Phasing TOC @ 13656' ~ Perfs 13666 - 13706' CBL, 4 spf, 0° Phasing 4½", 15.1 ppf, P-110 LTC Production Line'r No Scale ~' LBORE SCHEMATIC AFTER TESTING( Alaska State C-1 20", 94 ppf, H-40 STC Conductor @ 813' MD 9 5/8", 47 ppf, Soo-95, BTC Protective to 1300' MD 13 3/8", ~2 ppf, N-80, BTC Surface Casing @ 3993' MD 10.8 ppg Mud 13.4ppg Mud 7",. 32 ppf, P-110, LTC Production Tie-Back to 10536' MD 9 5/8", 47 ppf, RS-90, BTC Protective to 11119' MD 3½", 12.95 ppf, L-80, PH6~CB Test Tubing Baker Model F-1 Packer @ 11425' CBL Perfs 11476 - 11564' CBL: 2 spf, 0° Phasing o 13.4 ppg Mud TOC @ 12550' MD EZSV @ 12695' MD Baker F-1 Packers @ 12775 .and 12772' MD 4½", 15.1 ppf, P-110, LTC Liner top @ 12848' MD 7", 35 ppf, P-110, LTC Production/Protective Liner to 13146' MD .2ppg Mud JCC:dag 7/9/81 Perfs 13426 - 13560 CBL, 4 spf, 0° Phasing Perfs 13633 - 13651'DIL, 4 spf, 0° Phasing Perfs 13666 - 13706' CBL, 4 spf, 0° Phasing TOC @ 13656' MD 4~" 15.1 ppf, P-110 LTC Production Liner @ 13759' MD No Scale ALASKA STATE C-1 Surface Suspended Sketch 4" to 6" OD line pipe x 10' long Bead Weld Lettering As Follows: EXXON CO. U.S.A. EXXON Alaska State C-1 SEC. 14, T9N, R23E, UM 660' NSL,0660' WEL Lat. = 70' 08' 23.60" Long. = 146o 14' 29.89" ~....,,..,.---3" Companion Flange . /8" 13-5 5000 psi Ported Flange 13-5/8" 5000 psi Flange on Existing "A" Section 3", 5000 ps Gate Valve 9-5/8", .47 ppf csg. JCC: dag 7/9/81 ALASKA STATE C-1 Suspension Procedure This procedure begins following the plug back squeeze of production test interval 4. Note: Call Hoyle Hamilton, Commissioner of the Alaska Oil and Gas Conservation Commission, 24 hours prior to the final suspension procedures (279-1433). 1. Lay down test tubing. · Run in the hole with 3-1/2" drillpipe. Tag TOC and note depth. Close the upper pipe rams and test the plug to 1500 psi for 15 min. e POOH laying down drillpipe. Lay down all but 3000' of 3-1/2" drillpipe. e Nipple down the BOP stack and remove the "C" section. Install an 11" 10M# x 13-5/8" 10M# spacer spool and nipple up BOP stack. Test BOP stack to 200 psi and 7000 .psi with cup tester. Se Make ~up a Tri-State 5-3/16" OD Mechanical Cutter on 3-1/2" drillpipe with 1 joint 3-1/2" drillpipe below cutter and trip in hole. 6, Check for pressure in annulus before making casing cut. Cut 7", 32 ppf, Pll0 BTC casing at 2500 ft. MD. POOH. 7. . Install 7" casing rams in top preventer and test bonnet seals to 3500 psi. 8, Make up Tri-State or Bowen casing spear and latch into casing. Pick up casing and remove McEvoy casing hanger. Rig up casing crew and tongs. · Retrieve 2500' of 7", 32 ppf, Pll0, BTC casing. Limit tong speed breakout speed to 15 rpm initially and'increase speed to a maximum of 25 rpm if no galling is observed. Install thread protectors on casing joints before laying down casing. 10. Install 3-1/2" DP rams in top preventer. Test bonnets to 3500 psi. 11. Run wireline gauge ring and junk basket for 9-5/8" 47# to 2450'. Note: Begin injecting all waste fluids on location down 9-5/8" x 13-3/8" casing annulus beginning with remaining acid on location. Double check all mud tanks, pits, test tanks, waste oil tanks, effluent tanks, and miscell- aneous barrels to insure that no potential pollutants are left on location. Pump at least 500 bbls of fluids after acid. ,JUL Alaska 0;1 & (~as Cons. Anchorage Alaska State C-1 Suspension Procedure 12. Run in hole with 3-1/2" 13.30 ppf drillpipe and cast iron bridge plug for 47 ppf, 9-5/8" casing. Set CIBP at 2400 ft. 13. Set a 200 ft. balanced plug of permafrost cement On the bridge plug. Balance 100 sacks of permafrost on the plug and reverse out at 2200 ft. POOH. Clean out mud pits and inject fluids. 14. RIH with 3-1/2" DP and close 3-1/2" pipe rams. Pressure up to 1500 psi and~hold for 15 minutes to check bridge plug. Bleed pressure and open rams. 15. Rig up to pump 139 bbls. of 10.2 ppg CaC12 solution into 9-5/8" casing by adding 14900 lbs of High Test Flake Calcium Chloride (95% CaC12) .to 128 bbls. fresh water. Mix at approximately 60°F. The freezing point of '10.2 ppg CaC12 solution is -20°F. If excess CaC12 solution is required to maintain pump suction out of the rig suction pit, mix 116.3 lbs. CaC12 flake into 1 bbl. fresh water to make 1.09 bbl. of CaC12 solution. Note: Inhibit the CaCi? as follows: 25 gal/100 bbl C6rexit 7720 10 gal/100 bbl Corexit 7675 16. Rig up to displace the Calcium Chloride solution by reverse circulating. Pump a 5 bbl fresh water spacer and displace the 13.4 ppg mud into trip tank with 10.2 ppg CaC12 solution. Inject displaced mud down annulus. Pull out of hole with 3-1/2" drillpipe to 60 feet. Lay down drillpipe as it is pulled. Keep the hole full with Calcium Chloride solution. 17. With the open ended drillpipe at 60 ft., mix and pump the following cement slurry at 2 bpm. Cement 26 sks Permafrost Mix water 3.5 gals/sk (2.2 bbls total) Yield 0.95 cu ft/sk Slurry volume 4.4 bbls Slurry Weight 15.0 ppg 18. POOH with drillpipe. 19. Drain the BOP stack and 13-5/8" "B" section and nipple down the same. 20. Install a 13-5/8" flange with 3" valved companion flange assembly as shown in the attached sketch. Weld a piece of pipe to the top ~ of the flange and weld the following information to the pipe exte. nsion. Exxon Company, U.S.A. Exxon Alaska State C-1 Sec. 14, T9N, R23E, UM 660' NSL, 660' WEL Lat. = 70° 08' 23.60" Long. = 146° 14' 29.89" gE £1VE JUL 1 0 -- 2. -- ?... ~i~;~:.,,,d. : ~ /.':,.i,?.~..,~,~.,..'...b, :,.~.~~;?:!.:~'.,.. ? ',.~. .:..,- ,(./ ~ ~'~ I":.:-'~"-':;,,' ~" ,' ~'..:." ?. c~-' L j> c., ~/' ~> <~:i:~'~.',:' [' _ ~ >,.x t"/ /: ~L '2? ~..~ .~ ~ . -~ '~ ' ~1 / '~ .'~ ~ .. : ~ . , : '.' . .. .' - ~ . ~,.. .J..>'. >, ..... ,....~ .~ ;,.'. ,,-... '/..!'~...,, ~'~'.""'""-' t ' ~_. .... -_... (.:-._. DRILLING BULLETIN HO. 8~-REV]SION ]* November 10, .lg80 SAFE HANDLING OF COREX1T 7674 Corexit 7674 is a bactericide which will be'added to the packer fluids of all ,OCS wells completed after October 1, 1.979 (Corexit 7670 and. Corexit 7671 were 'used i'n wells preceding that date). Under normal use and following the precautions on the label, Corexit 7674 does not present a toxic hazard. However, like Corex-it 7670 and Corexit 7671, if used or handled improperly, Corexit 7674 can 'produce severe chemical burns to eyes and skin, and can even cause death if inhaled or swallowed. 'Fo avoid such accidents and to insure the safe use .and handling of this product, please comply with the following safety precautions: o Do not expose to high temperatures, sparks, and open flames. o Store drums (or bulk) in a segregated fireproof storage area wi'th proper fire fighting equipment available. o Do not ship or transport in trucks or any vehicle that is also transporting other flan~nable materials, including hydrocarbons or flam- mable solvents. o Mark the emp'Ly drums and return them to the supply base as soon as possible following the use of the chemical for proper disposal. o Use only in properly ventilated areas where plenty of fresl] air is available. o Keep container closed when not is use. o Wear protective clothing when handling (rubber gloves, goggles, protec- tive apron, and rubber boots). Should an accident occur involving CorexiL 1.574, Exxon Chem.ical Co. can be Consulted at' 715/656-3600, 24 hours a day, for the proper treatment. _ A copy o'f the.Material Safet~ Data Sheet f'q', Corexit 7~74 is attache,~~. *Supercedes original Drilling Bulletin bto."L% of December 15 1977 JUL .. Alaska State C-1 Suspends on Procedure 21. Rig up a suction line from the rig suction tank to the Halliburton annulus injection pump. Thoroughly clean out the rig suction tank and mix the following Arctic Pack solution'at 40° - 45°F. 175 bbls. diesel 5.7 bbls water 5.6 drums, SE-ii 100 sacks VG-69 342 lbs. salt Yields 200 bbls. 'Arctic Pack (Final volume) Test all lines to 5000.psi and pump 100 sacks of class G cement followed by a total of 200 bbls. Arctic Pack down annulus. Close in the 9-5/8" x 13-3,/8" casing annulus and carefully catch all remaining Arctic Pack from the Halliburton lines in 55 gallon drums. Maintain final pump pressure on annulus. Do not pump additional Arctic Pack. APPROVALS: Eng ine~i~g Supervisor l" S Ope~ti~ ~s CMR: dag' 7/10/81 Attachment s - 3 - R£££11f £D JUL 1 o 1 )8,1 Oil & Ga~ COns Anc~orag~ C°~i~io~ ALASKA OIL & GAS CONSERVATION COMMISSION Well File June 17, 1981 Hoyle H. ~amilton~ Chairman Exxon Alaska State C-1 Tom Berford with Exxon called at apprc~imately 9:50 AM this date and asked if they could again test the BOP stack to 7000 psi instead of 10, 000 psi and waive the blind ram test. Their wellhead setup is the same as described in memo to file dated June 10, 1981. They plan one more test between two in- tervals already tested. I approved his request and told him to have this entered on the tour sheet. · ,~ STATE OF'ALASKA ,, ' [:0NFIEIENTIA ALASKA[ - AND GAS CONSERVATION C(i[, ,vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, Drilling well [] Workover operation [] 2, Name of operator 7. Permit No. Exxon Corporation 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50-089-20011 4. Location of Well at surface 660' 5WL & 660' SNL, Sec. 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 54' KB 6. Lease Designation and Serial No. ADL 28382 9. Unit or Lease Name Alaska State "C" 10. Well No. 11. Field and Pool Wildcat For the Month of May ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Total Depth 13,761' (mo. footage 0'). Plug Back Depth 13,715'. Recove,r, ed stuck SWC gun by cutting and stripping over wireline. Milled cement inside 4-1/2 liner to 13,715' PBD. End of month operation is breaking down test assembly. 13. Casing or liner rUn and quantities of cement, results of pressur9 tests Set 4-1/2" liner from 12,848' to 13,757' and cemented with 200 sacks class G cement. ~. Pressure tested top of 4-1/2" liner to 7000 psi for 15 minutes. Held OK. Ban 7" caSing from top of tieback sleeve at 10,536' to surface and cemented with 250 sacks class G cement. Pressure tested 7" tieback to 7000 psi for 30 minutes. Held OK. Pressure tested 7" & 4-1/2" csg to 7000 psi, OK. 14. Coring resume and brief description 15. Logs run and depth where run Cement Bond Log 11,200' - 13,715' Gyro Survey 10,000' - 13,650' JUN 5 11i81 1 6. DST'data, perforating data, shows of H2S, miscellaneous data DST #1 from perfs 13,666' - 13,706' (4 spf). Ran nitrogen cushion to 5717 psi. IF 10 min., ISI 73 min. & FF 12 hrs. On a 4 hour stabilized flow test the well produced water at a rate of 803 bbs/day on a 1/2" ck with 205 psi wellhead pressure. ISIP 9498 psi, IF 8256 psi, FF 5887 psi, FSIP 9757 psi. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Supervisor - 'SIGNE~~.. ~ITLEOperatiOns GeOlOgy DATE June 15, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL FILE June 10, 1981 Hoyle H. Hamilton/~/~ Chairman Exxon Alaska State C-1 Junior Westbrook with Exxon called at approximately 11:00 AM this date and made the following requests regarding BOP testing. 2~ Delay the weekly BOP test, which is due today, until they complete the production test they are conducting now. They are on the final shut-in period of the test and should be through by 2:00 AM June 11, 1981. Test the stack to 7,000 psi instead of 10,000 psi. Waive the blind ram test. They have a 7-1/16" tubing head nippled up on top of BOP's and a test plug cannot be run through the tubing head to seat in the wellhead. They cannot test the blind rams with the setup they have. They have been tested numerous times at 10,000 psi. The maximum flowing pressure they have encountered on their tests so far, and this included the deepest test, was 200-300 psi wellhead. I discussed the above information with Bobby Foster and Russ Douglass and it was decided to grant the requests. I called Westbrook back and told him we were approving his re~ests and that this should be noted on the driller's log. Also he was to make sure that both pipe rams fit the tubing they were using. of ALASKA V \ NOTIFICATION 'fO O&GCC Date & Time of Notification: Person Notified: ?_?_$/- Inf~:rmati,.~n required by 18 AAC 75.110 e · , · · Date and time of discharge: Location of Discharge: Pers',~n or Persons causing or responsible for the di:.':harga: Type (s) and amount (s) of hazardous s.ubst~nce (s) discharged: Cause of Discharge: Environmental damage cause by the discharge t~ th~ extcent asceX: tainab la: ffo~ ,, , · Cleaning act ions undertaken: Location and method of ultimate disposal of t1{o l~azardot~s stol>st:artec and contaminated clean-up materials it~cludinlI data o[ disposal: June .5, 1981 Exxon Company U.S.A. P. O. Box 6601 Anchorage, Alaska 99.502 Re: Alaska Oil and Gas Conservation Commission Regulations Article 2, ABANDONMENT AND PLUGGING, 20 AAC 25.120 WELL ABANDONMENT MARKER and 20 AAC 25.170 LOCATION CLEAN UP. Gentlemen: This is in addition to our letter of June 4, 1981 regarding the above subject. This following well was omitted from the list of suspended wells: rs truly, Duck Is. Unit #3 ~ames K. Trimble Petroleum Engineer JKT~b~ COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS Alaska Department of Environmental Conservation P.O. Box 1601 Fairbanks, Alaska 99701 At%ention: Mr. Deug !owery May 14, 1981 COM.~,~ !-7-' cc:.: i Ii..-. Gentlemen: An oil spill occurred at EXxon's Alaska State C-1 drill site at 0500 ADT on May 9, 1981. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Ms. J. R. Hinn to Ms. Gloria Thomas of the Alaska Department of Environmental Conservation at 0820 ADT on May 11, 1981. The information required by 18 AAC 75.110 follows: 1. Date and time of diScharge: May 9, 1981 at 0500 ADT. ~ Location of the discharge: Exxon Alaska State C-1 drill pad. Sec. 14, T9N, R23E, UM. · Persons causing or responsible for discharge: Parker Drilling Company personnel. ~ of used motor oil. · Cause of discharge: Oil was discharged when a drum fell over due to the'supporting ice melting beneath it. The plug in the drum had not been properly replaced causing the oil to leak out upon the water. Oil on the water was contained within a gravel berm surrounding the rig genera- tor house. . Environmental damage: None. Ail discharged oil remained on the drill pad. · Cleanup actions undertaken: Oil was found floating on water contained within a gravel berm. The oil was skimmed from the water with absorbent and contaminated water was pumped into the waste oil tank. RECEIVED A DIVISION OF EXXON CORPORATION MAY .1 9 1981 Alaska Oil & Gas Cons. CommisSion Anchorage AlasKa Department of Environmental Conservation May 14, 1981 Page Two 1 Location, method and date of disposal of discharge and cleanup material: Contaminated absorbent was incinerated at Alaska State C-1 on May 9, 1981. Contaminated water will be injected into the well annulus. · Action taken to prevent recurrence: Discussed with person- nel the importance of proper handling of oil products. Please contact me at (907) 276-4552 for any additional information · ycu may require. '. Very truly yours, JRH: iww 290-910 cc: Mr, Hoyle Hamilton AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle RECEIVED 1 1A¥ 1 9 ] 81 Alaska Oil & ~as Cons. Cornrnissioj~ Anchorage '-~ STATE OF ALASKA , -\ ALASKA ,ZAND GAS CONSERVATION C( MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIo · Drilling well ::[[] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 so-089-20011 4. Location of Well at surface 660' ~4L & 660' SNL, Sec. 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54 ' KBI ADL 28382 9. Unit or Lease Name Alaska State "C" 10. Well No. No. 1 1 1. Field and Pool Wildcat For the Month of April ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth 13,761' (590' mo. footage). At months end we are preparing to fish for a stuck sidewall core gun, Top of fish is at 13,680'. 13. Casing or liner run and quantities of cement, results of pressure tests Set 7" liner from 10,536' to t3,146' and cemented with 1150 sx class G cement. Squeeze 7" liner lap below on RITS packer set at 10,125' w/400 sx class G cement. Resqueeze 7" liner lap below a retainer set at 10,325' w/400 sx class G cement. Drill out cement and pressure test top of 7" liner to 3000 psi for 30 minutes. Held OK. Performed PIT below 7" shoe at a drill depth of 13,171'. Leak off occurred at 17.8 ppg ~MW. 14. Coring resume and brief description Core #1 13,431'-13,490': Core #2 13,490'-13,550': Core #3 13,550'-13,610': Core #4 13,610'-13,700': Gore #5 13,700'-13,731': Rec. 59'. Rec. 60'. Rec. 59'. Rec. 15'. Rec. 8'. Ss, dk gry, vfg, poor P & P, spotty oil stain. Ss, dk gry, vfg, poor P & P, spotty oil stain. Ss, dk gry, vf-fg, poor P & P, pinpoint oil stain. Ss, dk gry, vf-fg, poor to fair P & P, patchy oil sta Ss, dk gry, vfg, poor to fair P & P, trace to patchy oil stain & 23' phyllitemed gry, no show. 15. Logs run and depth where run Ran the following open hole logs at 13,761': Dual Induction Compensated Neutron - Compensated Density Dipmeter BHC Acoustilog 1 6. DST data, perforating data, shows of H2S, miscellaneous data MAY ! § lOSIj Allsk~ OH & Gas Cons. Gornm~iofl AnOhorB~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Supervisor - .Operations Geology DATE May 13, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 10: STATE of ALASKA OIL & CAS CONSEILVATIOF.X :kI[SS[()N ,';t')T [ F [CATI OX TO ,. : : t' t , / 9_,.9_(_ i)ate ,r~ Time of .,ot/ficat[on _ . Person Notified: ~7~ ~°~e l( ~ ' -- /,' Inf()rmaticn requir,_'d bv !3 .,\.,'lC 75.11() . , . · , Da.re a~:d tine cf disch'.a, rge: LocatLon of D~schar~9: ~ Person or Persons causing or responsible for the dksci~ar3e: Type. (.~:~--..~amount (s) of hazardous substance (s)(',L:~char3c'd' ..i~c h arg e' Env[~onmenta~ d~mage cause by the d~scharge to the extent ;, Clea::Lng act/or:s undertaken:I Location and method of ultimate disposal of the hazardous and contaminated clean-up materials including data of disposal' , Actions taken to prevent recurrence of the discharge: COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 April 15, 1981 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowery Gentlemen: ,. An oil spill occurred at Exxon's ~aska State C-l~rill site at 0800 AST on April 11, 1981·~ ~ ? ~--.=~ ............." - '~ Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Ms. J. R. Hinn to Ms. Lorraine Rohloff of the Alaska Department of Environmental Conservation at 0900 AST on April 13, 1981. The information required by 18 AAC 75.110 follows: le Date and time of discharge: April 11, 1981 at 0800 AST. · Location of the discharge: Exxon Alaska State C-1 ~ pad Sec · Persons causing or responsible for discharge: None. Discharge was due to equipment failure. · · · A DIVISION OF EXXON CORPORATION Type and amount of discharge: Approximately__nine gallons of used gear lubricant· Cause of discharge: Leak in the rig compound· Environmental damage: None· Discharged fluid remained on the drill pad. A/asks Oil & 6as Coos Alaska Department of Environmental Conservation April 15, 1981 Page Two · Cleanup actions undertaken: Discharged lubricant was contained in a depressed area beneath the rig flOor. Contained fluid was pumped into the waste oil tank and remaining residue cleaned up with absorbent. ' · Location, method and date of disposal of discharge and clean up material: Contaminated absorbent was incinerated at Alaska State C-1 on April 11, 1981. · Action taken to prevent recurrence: Leak in rig compound was repaired. Rig personnel wers instructed to make periodic inspections of rig equipment to prevent future recurrence. Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, JRH:sjm 240-910 cc: Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive _.',' ,~'1~ .,-,~ ~ ~. T,Z' . . ~,,~age, ,.~.. 99504 R. K. Riddle RECEIVED, APR 1 8 1981 Alaska Oil & ?a~ Cons. Commission /-tnchorage ///' ALASKA[ ,. AND GAS CONSERVATION C(I, MISSION ~. ~ MONTHLY REPORT OF DRILLING AND wORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Exxon Corporation 80-46 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50_089-20011 4. Location of Well atsurface 660' ~ & 660' SNL, Sec. 14, T9N, R23E, U.M. 9. Unit or Lease Name Alaska State "C" 10. Well No. 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' KB ADL 28382 For the Month of. March ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth 13,171' (1037' mo. footage). Milled on junk to 11,256' where a sidetrack hole was kicked off with an 8-1/2" bit. During the month the mud weight was raised from 12.8 ppg to 13.5 ppg. 13. Casing or liner run and quantities of cement, results of Pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run Ran the following open hole logs at 13,171' MD: Dual Induction BHC Acoustilog Formation Density' Compensated Neutron Dipmeter 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SI _ TITLE Operations Geoloqy RECEIVED APR ! 4 1O81l 0il & Gas Cons. (,0remission DATE April 13, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 of ALASKA OIL & GAS CONSl,]kVk'rlOb~' 'to: [- NOTIFICATION TO O&GCC Date & Time of Notification: Person Notified: .)/~4 Info,,marion required by 18 AAC 75.110 · , · , , 6 . Date and time of disCharge: Location of Discharge: Per.~',)n or Persons causing or responsible for the di.~-charge: Typc' (s) and amount (s) of hazardous substance (s) discharged: Cause of D~scha~ge: Environmental damage cause by the discharge to the extent ascer- tainable: ,&/20,,~/~'?' , Cleaning actions undertaken: , Location and method of ultimate disposal of the hazardous subsI:ance and contaminated clean-up lnaterials including data ,,of disposal: · Actions takeu to prevent recurrence of the discharge' ,::" . .?, ~ ..: "I, COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502. E.~PLORATION DEPARTMENT ALASKA/PACIFIC DIVISION NPACO-RF-P Beaufort Sea 81 April 2, 1981 0 : 071-0YD-4-80 015 Fill for Exploratory Drill Pad Alaska State "C" 1 North Slope Borough, Ak. Colonel Lee R. Nunn District Engineer U. S. Army Corps of Engineers P. O. Box 7002 Anchorage, Alaska 99510 Dear colonel Nunn: The commencement of drilling operations at the subject well was delayed due to circumstances beyond our control, however, despite such delay we anticipate that actual drilling activity will have been concluded prior to May 15 and thus within the period provided for drilling to be conducted under the provision of Special Condition C. of the captioned permit. Although it is thus possible that literal compliance might be achieved without difficulty, we do not feel that we could in good conscience proceed without your complete concurrence with the logging, testing and completion procedures which almost certainly will require at least an additional thirty daYs beyond May 15 to complete. Accordingly we are by this letter requesting that the period for such activity be extended beyond the May 15 date of Special Condition C. for a sufficient period to permit the logging, testing and completion of the well in a safe and secure manner consistent with the directives and/or approvals of the Alaska Oil and Gas Conservation Commission. We regret that the request which we made to you by our letter of 17 March 1981 for an extension under special condition II(a) of permit 071-0YD-2-800193 was disruptive to the normal flow of the work of your staff. Every effort will be made. in the future to avoid a repetition of this incident.~C~~ Yours very truly, ~~ ~C°~~;~0 A DIVIs~R~:~ CORPORATION c: Shehla Anjum, NSB; Hoyle Hamilton, AOGCC; Glenn Harrison, DMEM; William Copeland, FLWM; Douglas Lowery, ADEC; J, Scott Grundy, ADFG; Ron Morris, NMFS; Jerry Stroebele, USFWS EICON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS Alaska Department of Environmental Conservation P.. O. Box 1601 Fairbanks, AK Attention: Mr. Doug Lowery April 1, 1981 CONFER: FILF: Gentlemen: An oil spill occurred at Exxon's Alaska State C-1 drill site at 0230 AST on March 30, 1981. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Ms. J. R. Hinn to an automatic telephone recorder at the Alaska Department of Envi- ronmental Conservation at 0830 AST on March 30, 1981. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: March 30, 1981 at 0230 AST. · Location of the discharge: Exxon Alaska State C-1 drill pad. Sec. 14, T9N, R23E, UM. · Persons causing or responsible for discharge: Water truck ~~ ~,~th Ke~iak O.~.].fie].~ Hau!ers~ · · · · Type and amount of discharge: Approximately five gallons of used engine oil. ~ . Cause of discharge: Oil drip pan which was spilled while being moved from beneath a water truck. The water truck was being repaired. Environmental damage: None. the drill pad. Spilled oil remained on Cleanup actions undertaken: Oil was cleaned up with absorbent. Contaminated snow and ice were chipped up and all contaminants placed in plastic-lined boxes. A DIVISION OF EXXON CORPORATION Alaska Department of Environmental Conservation April 1, 1981 Page Two · Location, method and date of disposal of discharge and clean up material: Contaminants were incinerated at Alaska State C-1 on March 30, 1981. · Action taken to prevent reburrence: Instructed driver to exercise caution to prevent further recurrence. Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, JRH:sjm 240-910 cc: Mr. Hoyle HamiltOn Hermann Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle STATE of ALASKA TO: F iRES l, 4,- I 1 GEOL,, 1 --F~cTE Of,?~/_j I,'.~i STAT TEC--~ CON_ FER: No'rz~ZCA'rTo~F~f'' O~¢CC OIL & GAS CONSERVATION ~MISSION DATE: .,7, -.3/-- SUBJECT: OIL SPILL REPORT at (location) Date& Time of Notification: Person Notified: Information required by 18 AAC 75.110 Date and time of discharge: 3-~ ~P- ~ / 2. Location of Discharge: ~~~ ,~~ ~ - / 3. Person or Persons causing or responsible for the discharge: 4. Type (s) and amount (s) of hazardous substance (s) discharged: 5. Cause of Discharge: 6. Environmental damage cause by the discharge to the extent ascer- tainable: ~ · Cleaning actions undertaken: · Location and method of ultimate dispOsal of the hazardous substance and contaminated clean-up materials including data of disposal: 9. Actions taken to prevent recurrence of the discharge: ALASKA~" L AND GAS CONSERVATION C~ 'MISSION //~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator Exxon Corporation 7. Permit No. 80-46 4. Location of Well atsurface 660' N~TL & 660' SNL, Sec. 14, T9N, R23E, U.M. 3. Address 8. APl Number Pouch 6601, Anchorage, Alaska 99502 50_089-20011 9. Unit or Lease Name Alaska State "C" 10. Well No. 11. Field and Pool Wildcat 5. Elevation in feet {indicate KB, DF, etc.) 6. Lease D_es_ig_~ti_on and Serial No. 54' KB ADL 2~3~2 For the Month of. February ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth 12,134' (1003' mo. footage). On 2/27/81, while tripping in the hole with a new bit, an obstruction was hit at 11,237'. A collar log indicated that the float shoe was missing. Current operation is reaming with a junk mill at 11,235'. Raised mud weight from 10.8 ppg to 12.8 ppg during the month. 13. Casing or liner run and quantities of cement, results of pressure tests Tested 9-5/8" casing to 6000 psi. At a drill depth of 11,131' a PIT was performed. Leak off occurred at 15.6 ppg [MW. Squeezed around 9-5/8" casing shoe with 300 sacks class G cement. PIT leaked off at 15.7 ppg [MW. Squeezed around 9-5/8" shoe with 300 sacks class G cement. .Leak off occurred at 16.0 ppg [MW. At a drill depth of 11,241' the shoe was squeezed with 400 sacks class G cement. A PIT was performed with leak off occurring at 16.7 ppg HMW. At a drill depth of 11,623' a PIT showed a 14. Coring resumeand brief description leak off of 15.1 ppg 15. Logs run and depth where run Ran a gyro survey from surface to 10,500' Casing Collar Log in 9-5/8" casing from 10,200' to 11,130' 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED MAR 1981 SuPervisor - Operations Geology DATE March 16, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 PRODUCTION DEPARTMENT ALASKA OPERATIONS Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowery March 4, 1981 Gentlemen: A hydraulic oil spill occurred on the ice road between Deadhorse and Exxon's Alaska State C-1 drill site location at 1635 AST on- February 23, 1981. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Ms. J· R. Hinn to Ms. Lorraine Rohloff of the Alaska Department of Environmental Conservation at 1350 AST on February 24, 1981. The information required by 18 AAC 75.110 follows: i · Date and time of discharge: February 23, 1981 at 1635 AST. · Location of the discharge: On the ice road ~between Deadhorse and Exxon's Alaska State C-1 drill site location in Sec. 24, T1ON, R17E, UM. Alaska State C-1 is located in Sec. 14, T9N, R23E, UM. , Persons causing or responsible for discharge: Discharge was due to equipment failure. None· , · Type and amount of discharge: Approximately five gallons of hydraulic oil. Cause of discharge: Broken hydraulic hose on a 16G Motor Grader. · EnVironmental damage: None· Discharged oil remained on the ice road· A DIVISION OF EXXON CORPORATION - 9 1§8! Alaska Oil & 6as Co.~s. ComrnJssior~ A~chorag9 .Alaska Department ~ .... Environmental Conservatic(~' Page Two ' , Cleanup actions undertaken: Hydraulic oil was cleaned up with absorbent and contaminated ice chipped up. All contaminants were placed in a barrel. · Location, method and date of disposal of discharge and clean up material: Contaminants were given to the North Slope Borough for incineration. , Action taken to prevent recurrence: hose has been repaired. Broken hydraulic Please contact me at (907) 276-4552 for any additional information you may require· , Very truly yours, ORH: sjm 240-910 218/G cc: Mr. Hoyle Hamilton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle Alaska Oil & G~.s Cons, Commission STATE of ALASKA OIL & GAS CONSERVATION COMMISSION DATE: SUBJECT: OIL SPILL at(location) NOTIFICATION TO O&GCC Date & Time of Notific~.tion: Person Notified:· Information reqa±red by 18 AAC 75.110 i. Date and time of discharge: ~ .... ~3--~ I ./ /-t/,',~ C- 2. Location of Discharge: ~~.... f ~..~-~ ~ /9 ,,~,oE'~ '~. '~ 3. Person or Persons causing or responsibls for the discharge: 4. Type (s) and amount (s) of hazardous suostance (s) discharged: 5. Cause o: :ischarge: ,. ~ . ~~. g'~ 6. Environmental damage cause by the discharge to the extent ascer- tainab le: · Cleaning actions undertaken: ........ ? : · Location and method of ultimate disposal of the hazardous substance and contaminated clean-up-materials including data of disposal: 9. Actions taken to prevent recurrence of the discharge: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/~t' Chairman .U- Thru: Lonnie C. Smith Commissioner Doug Amos ~ Petroleum Inspector February 17, 1981 Witness BOPE Test on EXXON'S AK. ST. C-1 Well Sec. 14, T9N, R23E, UM Permit No. 80-46 on Parker Rig No. 96. S~unday February_ !, 1981: I departed my residence at 3~30 pm for a 5:00 pm ideparture on Wien flight #75 arriving Prudhoe Bay at 8~ 00 pm. I arrived Parker Rig 96 at 9:00 pm. The BOPE test commenced at 10~ 00 pm. Monday F~r~a~ 2,_ 1981: The BOPE test was concluded at 8:00 am there were four failures all of which were corrected during this test. I filled out an A.O.G.C.C. BOPE test report which is attached. During the course of my site inspection I found the retaining area around the rig fuel tank to be filled with hard packed snow. This item was brought to the attention of Exxon representative Bill Llewell~. He assured me this problem would be corrected. In summary, I witnessed the BOPE test on EXXON'S ALASKA STATE C-1 well, there were four failures all of which were corrected during the course of this test. I filled out an A.O.G.C.C. BOPE test report which is attached. Attachme:nt:~ Bill Llewellyn Exxon representative called 02-10-81 and informed me that the retaining area around the fuel taD3~ had been cleared. ,DA :mm O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Ope rator ~;~ ~/,2 Location: Sec /~ T~A/ R~ M ~,A~0 Drilling Contractor ~:~/$~/(~/~ Representative ~/~.L / ~-~%4/~ ~ Permit # ~-~ ~/~'~asing Set @ //,?/2Z ft. Rig # ~ Representative Location, General Well Sign General Housekeeping Reserve pit Rig ROPE Stack Annular Preventer Pipe Rams ~ Blind Rams Choke Line Valves H.C.R. Valve.,~ Kill Line Valves Check Valve Test Pressure Il ACCUMULATOR SYSTEM Full Charge Pressure ~/~ psig Pressure After Closure /~7~ psig 200 psig Above Precharge Attained.-. Full Charge Pressure Attained: ~ N2 /~c:~f3;2Z~Z/~ ZZ~O psig Controls: Master ~/< Remote ~A~ Blinds switch cover min ~ sec rain ~ sec Kelly and Floor Safety Valves Upper Kelly_ / Test Pressure Lower Kelly~! Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold / No. Valves Test Pressure 2~ No. flanges Adjustable Chokes Hydrauically operated choke Test Results: Failures ~ Test Time /~ hrs. ~Q~ Repair or Replacement of failed equipment to be made within ~ days and Inspector/Commission office notified. Remarks: ~/~7'~ ,' ~~/~/~ ,~~ ~~ ~/~7 ~~ ~~ /.~ Dzstributfon orig. - AO&GCC cc - Operator cc - Supervisor Inspector STATE OF ALASKA O IDEHTIAL MONTHLY REPORT 'OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ .. Workover operation [] 2. Name of operator Exxon Corporation 3. Address Pouch 6601, Anchorage, Alaska 99502 4. Location of Well at surface 660' ~L & 660' SNL, Sec. 14, T9N, R23E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54 ' KB ADL 28382 7. Permit No. 80-46 8. APl Number 50- 089-20011 9. Unit or Lease Name Alaska State "C" 10. Well No. o 11. Field and Pool Wildcat For the Month of. January ,19 81 · 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth 11,131' (4319' mo. footage). Raised mud weight from 9.4 ppg to 10.8 ppg during the month. Establish injectivity down 9-5/8" x 13-3/8" annulus with 60 barrels 10.8 ppg mud. Average injection rate was 3 BPM at 460 psi. 13. Casing or liner run and quantities of cement, results of pressur9 tests Set 9-5/8" casing at 11,119' and cemented with 2470 sacks class G cement. 14. Coring resume and brief description 15. Logs run and depth where run Run following open hole logs at a measured depth of 11,131': Dual Induction BHC Acoustilog Formation Density - Compensated Neutron Dipmeter 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNE , TITLE Operations Geoloqy DATE February 15, 1981 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION February 11, 1981 Re: E___x×on AlaskA State "C" ...... ~__Well No. 1 p~-i--~h0mSOn-Area Sec. 14, T9N, R23E, U.M ADL 28382 Arctic Slope, Alaska LO/NS 80-42 - 80-85 C_4 ~N .G ] GEOL f .... IsTAT TEC !--'1 STA_T TEC-- Mr. Glenn Harrison, Director Division of Minerals & Energy Mgmt. 703 West Northern Lights Blvd. Anchorage, Alaska 99503 Dear Mr. Harrison: Each of the plans of operations filed subsequent to the subject Alaska State "C" Well No. 1 has, with the approval of your office, included as one of its essential components the procedure which is proposed for conducting a velocity survey of the well. With the subject well and with all prior operations we did not do so, but have covered this procedure with a Miscellaneous Land Use Permit. As it was mutually agreed in our discussions with John Miller prior to his departure that this procedure followed by Exxon was not only awkward but unique the change was made with all operations which follOwed the above. . Accordingly we would like to amend the subject plan of operations to provide for the inclusion of this omitted procedure. This will require a 40 inch diameter cased hole, 40 feet deep, located on the drill pad a short distance from the well bore which will be filled with water just prior to detonation. Experimentally one pound charges of Nitromon primer or an equivalent amount of Primacord will be used as well as an airgun as the energy source; the Nitromon serving the dual purpose of cavitating the hole and supplementing the energy source. A DIVISION OF EXXON CORPORATION As this well was drilled directionally a line of shot holes along the surface trace of the directional hole (approximately one such location for each 1000 feet of departure from the surface location of the borehole) as well as an airgun will be used as the energy source. This will provide for more direct velocity measurements and compensate for ray path distortion. I ECEIVED As a further alternative in the event neither of the above develop satisfactory data, we propose to use a steel tank 10 feet in diameter and 20 feet high filled with water with the airgun as the energy source. We earnestly request that we be allowed to amend the subject plan of operations to incorporate the above described velocity survey. Yours very truly, Robert K. Riddle RKR: et cc: Shehla Anjum, NSB Hoyle H. Hamilton, AOGCC Colonel Lee Nunn, USACOE William Copeland, FLWM Douglas Lowery, ADEC J. Scott Grundy, ADFG FEI3 1 1981 Alaska 0il & Gas Cons. Commission Anchorage COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 9071276-4552 February 6, 1981 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention' Mr. Doug Lowery Gentlemen: An oil spill occurred at Exxon's Alaska S~ate C-i drill site -- location at 1100 AST on February Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirma- tion of the telephone report made by Ms. J. R. Hinn to Ms. Lorraine Rohloff of the Alaska Department of Environmental Conservation at 1520 AST on February 3, 1981. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: February 3, 1981 at 1100 ACT. · Location of the discharge: Exxon Alaska Stare'C-1 drill pad. Sec. 14, T9N, R23E, UM. e Persons causing or responsible for discharge: Mechanic with Petroleum Services, Inc. · Type and amount of discharge: Ten to fifteen gallons of used engine oil. · Cause of discharge: Engine oil was spilled from a drain drum beneath a D-8 Cat when the mechanic . completed an oil change and failed to remove the drum before moving the equipment. · Environmental damage: None. Discharged oil remained on the drill pad and did not reach navigable waters. · Cleanup actions undertaken: Spilled oil was cleaned up with absorbent. Contaminated snow, ice and gravel were shoveled up and all contaminants placed ir~~_~~ wooden box lined with plastic. FEB 1 3 1981 A DIVISION OF EXXON CORPORATION Alaska Oil & Gas Cons. Commission Anchorage Alaska Department of Environmental Conservation February 6, 1981 Page Two · Location, method and date of disposal of discharge and clean up material: Contaminants were incinerated on February 4, 1981 at Alaska State C-1. · Action taken to prevent recurrence: Mechanic was instructed to remove drained oil prior to moving equipment. . Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, JRH:sjm 240-910 cc: Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle RECEIVEO FEB 1 3 19 1. Alaslm Oil & Gas Cons. Commission A~chorage STATE of ALAS KA OIL & GAS CONSERVATION CO,HMISSION to: [- NOTIFICATIOX TO 06CCC Date & Time of :;otificatton: Person Notified: ~J~t~r c~J~,~_~_~_e Informatica required by !8 AAC 75.110 1.,, Da.te a,:d time of disch'.a, rge: -/%--e~. 3 ~- /I~. 0 (9 /9]1;t , Person or Persons causing, or responsible for the d/scha"~,.oe:~ 4. Type (~) and amount (s) of hazardous substance (s) discharged: 5. C~,.. Lscharge: tainab]e: · 8. Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials including data of disposal: 9. Actions taken to prevent recurrence of the discharge: Form No. P--4 R.~'V. ~- 1-70 STATE CJI' AJ.A,SKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1._, 0,,~ t~ G*, [] o?.,, Wildcat W~LL ~. NA/~. OF OP~IP.A~R Exxon Cgrporation 3. ADDRESS OF OPEP. A~R Pouch 6601, Anchoraqe, Ak. 99502 4 ~CA~ON OF WFJ~L Surface: 660' EWL & 660' SNL, Sec. R23E, U.M. BHL: 4250' EWL & 660' SNL, Sec. 14, U.M. SUBMIT IN DUPLICA~ 14, T9N, T9N, R23E, CONFIDENTIAL AP1 NI~fERZCA]L CODE 50-089-20011 LEASE DESiGI~A?ION AND SERIAL NO. ADL 28382 ~ IF INDIA)3'. ALOi li~l~ OR TRIBE NAME 8. L~IT F.~RA{ OR LEASE NA3~E Alaska State "C" 9 %V~LL NO No. 1 10 FIFJ~D AND POOL. OR WILDCAT SEC, T., R. M (BO~I'OM HOLE OBJ~T~ Sec. 14, T9N, R23E, Ak. PERiVIIT NO 80-46 "13. R~ORT TOTAL D~ AT ~D OF MON~. CH~NG~ IN HOLE SIZE, CASING A~ C~T!NG JOES INCLUDING DEPTH SET A/%TD VOLUMES USED, PERFO~TIONS. TESTS ANT) ~SULTS FISHING JO~ JUnK ~ HO~ AND SIDE-~CK~ HO~ A~D ~Y OTI-I~R SIGNIFICANT CI-LAHG~ IN HO~ ~ITIONS Spudded well at 2230 hours 12/3/80 w/17-1/2" bit. Drilled to 820' the following open hole logs: Dual InduCtion BHC Sonic Caliper Opened hole from 17-1/2' to 26". Set 20" casing at 813' 3500 sacks 15.0 ppg Permafrost cement. Cement circulated Drilled a 17-1/2" hole to 4000' and ran the following U.M. Dual Induction BHCSonic Caliper Set 13-3/8" casing at 3993' and cemented with 485 plus 500 saCks 15.8 ppg class G cement. A pressu performed below the 13-3/8" casing shoe at a dril occurred at 11.7 ppg equivalent mud weight. Set and squeezed the 13-3/8" casing shoe with300 sack out to a depth of 4022' and performed a pressure and r an and cemented with to the surface. open hole logs: 0 sacks 15.0 ppg Permafrost re integrity test was 1 depth of 4011'. Leak off a cement retainer at 3935' s class G cement. Drilled integrity test. Leak off occurred at 12.3 ppg equivalent mud weight. Set a cement retainer at 3919' and squeezed with 300 sacks class G cement. Drilled out to 4033' and performed a pressure integrity test. Leak off occurred at 12.2 ppg equivalent mud weight. Resumed drilling with a 12-1/4" bit. At 6431' the hole was. kicked off to the east using a Dyna Drill. At the end of the month a 12-1/4" hole is being directionally drilled at a measured depth of 6812' with 9.4 ppg mud. JAN'2 0 1981 Anonura~le ,.,h.~~_~[~.~3~o.~U_~~ Supervisor - s~~ .~V~~,% ~.~-~-"'~'~--n~ Operations Geology _ D*~, January 15, 1981 NOTE--Report on this form is required for each calendar month~, regardless of the status of operations, and ~ust I)e filod in duplicate with the oil and gas conservation committee by the 15th of the succeeding month, unless Otherwise ~rected. ~.O~.. COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowery December 30, 1980 COMM_~J ---[~M RES ENG :l 1 ~EOL 2 GE~ L.S'rAT T C__i Gentlemen: A diesel fuel spill occurred at E~xxon's Alaska State C-1 drill site location at 2115 AST on December 28, 1980. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Ms. J. R. Hinn to Ms. Lorraine Rohloff of the Alaska Department of Environmental Conservation at 1020 AST on December 29, 1980. The information required by 18 AAC 75.110 follows: 1. Date and time of discharge: December 28, 1980 at 2115 AST. ~ Location of the discharge: Exxon Alaska State C-1 drill pad. Sec. 14, T9N, R23E, UM. ~ Persons causing or responsible for discharge: Forklift operator with Parker Drilling Company. e Type and amount of discharge: Approximately six gallons of diesel fuel. --~-~ ........ Cause of discharge: Forklift struck and broke a 1" fuel line while pulling a wireline unit. . Environmental damage: None. Discharged fuel remained on the drill pad and did not reach navigable waters. ~ Cleanup actions undertaken: Discharged fuel was cleaned up with absorbent and contaminated snow and ice shoveled up. All contaminants were placed in ian empty barrel pending incineration, i 'REC[IVED; A DIVISION OF EXXON CORPORATION j AI~,I 2 1-0~1 Rlaslia 0il & Gas Cons. Commission Anchorage Alaska Department of Environmental Conservation December 30, 1980 Page Two · Location, method and date of disposal of discharge and clean up material: Contaminants will be stored at Alaska State C-1 pending Department of Environmental Conservation approval to incinerate on location. · Action taken to prevent recurrence: Fuel line has been shortened and clearly marked with a red "fuel line" sign. Please contact me at (907) 276-4552 for any additional information you may require. Very truly yours, . A. L. Hermann JRH:sjm 240-910 cc: Mr. Hoyle Hamilton AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 R. K. Riddle of ALASKA OIL & GAS CONSERVATIOn' ':OMMISSION TO: F- DA'rE: SUBJECT: OIL SPILL REi'ORT at (location) NOTIFICATION TO O&GCC Date & Time of Notification: Person Notified: Jr-- _.~x,~ ~'~'- Info~:mation required by 18 AAC 75.110 Date and time of discharge: / ~..._-2'$-~/ ~_~/oo 2. Location of Discharge: 3. Per,-on or Pea'sons causing or responsible for the di~harge: , . Cause of Discharge: Environmental damage cause by the d£scharge to the ext~nt asce~:- tainab le: .)d ~ ,,a ~- 7. .Cleaning actions undertaken: 8. Location and method Of ultimate disposal of the haza~-dous substance and contaminated clean-up ,naterials including data of disposal' 9. Actions taken to prevent recurrence of the discharge' 0(" :, b :Rev STATE of ALASKA OIL & GAS CONSERVATION COMMISSION DATE: SUBJECT' OIL SPILL R£PORT at (locat ion)~L _.J=.,. ,% t ~- NOTIFICATION TO O&GCC Date ~. Zime of ~otificatton: Person Notified: Informatioa required ~y 18 AAC 75.110 . , . . . · . Date a[~d time of discharge: .l~.~,~t~ , It'f ,~,l~ o Locat£on of Discharge: '1 Person or Persons causing or responsible for the discharge: Type (s) and amount (s) of hazardous substance (s) discharged: ~- ~ ~ o ~ {' Ca,, ~ scharge Environmental damage cause by the discharge to the extent asce~- tainab I e: Cleaning actions undertaken: . Location and method of ultimate disposal of the hazardous subs'tance and contaminated clean-up ma'terials including data of disposal: ~ Actions taken to prevent recurrence of the discharge: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto~ Chairman Thru: Lonnie C. Smith- "-'~d~' Commissioner Bobby Foster~~" . Petroleum Inspector December 23, 1980 Witness BOPE Test on EXXON ' S AK. STATE C-1 Sec. 14, T9N, R23E, UM Permit #80-46. Tuesday Dec.ember.' !.6,~.198...0: After completing the BOPE test on Arco's C-3 I traveled to EXXON'S C-1 to witness the upcoming BOPE test. Wednesday.December 1~7,.1980: Standing by for test. Thursday December 18, 1980: Standing by for test. Friday December 19, 1980: The BOPE test began at 5:00 pm and was compIeted at 1i~:00 am on December 20, 1980. As the attached BOPE test report shows the two failures were the annular preventer element which required 11 hours to be changed out and a flange on the choke manifold which was tightened and retested. The annular preventer element was changed and tested to 5,000 psig, a re- quirement of Exxon. After the first element failed I suggested to the Exxon representative the new element be tested according to test procedures outlined by the Hydril Company to test the GK model preventer. This was done and the preventer held. In summa~, I witnessed the ~PE test on EXXON'$ ALASKA STATE C-1. BF :mm O&G #4 4/80 STATE OF ;~LASKA ( ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector l~~. ~ ~/ :~.~- '~.~ Operator ~,'~'~ ~ O~ Well ~~ ~' ~7/~'~ ~i_d - ~ /4 T Drilling Con'tractor~~/~ Rig ~ ~ Wel 1 Representative Permit # _~) --+/"~ /y~Casing Set @ Representative ~ ft. Location, General Well Sign General Housekeeping Reserve pit , Rig BOPE Stack Annular Preventer / Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure.!T~~ psig Pressure After Closure /.~'~D psig 200 psig Above Precharge Attained: - Full Charge Pressure Attained: ~,? Controls: Master ~T~ Remote~:/~~/ : Blinds switch cover Kelly and Floor Safety Valves Test Results: Failures Upper Kelly, / Test Pressure Lower Kelly / Test,Pressure Ball Type / Test Pressure Inside BOP / Test Pressure min~ ~ se rain / .'7 s~ Choke Manifold ~_.~ Test Pressure~ 6 d No. Valves ///" Adjustable Chokes , H~'drauically operated choke .. T e s ~'-~?~-~-'- Y~e ..... :hrs. R&pai'r or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: ,'??,, ' ~ fL,'f:/~:' tt;i.,, . days and Distribution orig. - AO&GCC cc - Operator cc - Supervisor COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 907/276-4552 November 19, 1980 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowrey Gentlemen: A small hydraulic fluid spill occurred at Exxon's Alaska State C-1 drill site location at 1030 AST on November 18, 198-0.' -- Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755,' this letter constitutes written confirma- tion of the telephone report made by Ms. J. R. Hinn to Mr. John Janssen of the Alaska Department of Environmental Conservation at 1250 AST on November 18, 1980. The information required by 18 AAC 75.110 follows: le Date and time of discharge: November 18, 1980 at 1030 AST. · · Location of the discharge: Exxon's Alaska State C-1 drill pad. Sec. 14, T9N, R23E, UM. Persons causing or responsible for discharge. None. Discharge was due to equipment failure. ¸'4. · Type and amount of discharge: Three to four gallons of hydraulic fluid. _ -- Cause of discharge: A seal on the hydraulic system of a 966 forklift blew out. · Environmental damage: None. Discharged fluid remained on the drill pad and did not reach navigable waters. A DIVISION OF EXXON CORPORATION NOV ;? 1 1980 Alaska Oil & ~. a~Cons. Commission Alaska Department of Environmental Conservation Page Two November 19, 1980 ~ Cleanup actions undertaken: Ail contaminated snow, ice and gravel were shoveled up and placed in plastic bags. Bags were stored in an empty drum pending incineration. ~ Location, method, and date of disposal of discharge and cleanup material: Contaminants were incinerated at the C-1 location on November 18, 1980. Verbal approval to incinerate received from Mr. John Janssen on that date. ~ Action taken to prevent recurrence: Repaired and replaced the blown seal and inspected all other connections on the vehicle. Please contact me at 907-276-4552 for any additional information you may require. Very truly yours, ~ Hermann JRH:dag 240-910 cc: Mr. Hoyle Hamilton AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle ECEIVED NOV 1 1980 Alaska Oil & Gas Cons. Cornrni$$[o~ Anchorage COMPANY, U.S.A. ...... ~,; ~'~.~. - POUCH 660! · ANCHORAGE, ALASKA 99502 907/276-4552 November 14, 1980 Alaska Department of Environmental Conservation P. O. Box 1601 Fairbanks, AK 99701 Attention: Mr. Doug Lowery Gentlemen: A small hvdrs~] ~c fluid spill occurred 100' North of Exxon's ~ st~te ~rill site location at 1830 AST on ~r 8o. Pursuant to 18 AAC 75.100 under authority of AS 46.03.020 (10) (A) and AS 46.03.755, this letter constitutes written confirmation of the telephone report made by Ms. J. R. Hinn to Ms. Lorine Rohtoff of the Alaska Department of Environmental Conservation at 1040 AST on November 12, 1980. The information required by 18 AAC 75.110 follows: · Date and time of discharge: November 11, 1980 at 1830 AST. · Location of the discharge: 100' North of Exxon's Alaska State C-1 drill site pad. Sec. 14, T9N, R23E, UM. · Per.sons causing or responsible for discharge: None.. Discharge was due to equipment failure. · Type and amount of discharge: Approximately ~hree to four gallons of hydraulic fluid. · Cause of discharge: Broken hydraulic line on the steering pump on a rolligon. · Environmental damage: None. HYdraulic 'fluid was recovered and did not reach navigable waters. RECEIYED NOV 1 8 ]980 A DIVISION OF EXXON CORPORATION Alaska 0ii & Gas Cons. Commission Anchorage Alaska Department of Environmental Conservation Page Two · Cleanup actions undertaken: Contaminated snow and ice was shoveled up and placed in plastic bags. Contaminants were stored in a barrel on location pending incineration. · Location, method, and date of disposal of discharge and cleanup material: Contaminants were incinerated on location on November 13, 1980. Approval to burn received from Mr. Ron McCallister of the Alaska Department of Environmental Conservation on November 13, 1980. · Action taken to prevent recurrence: Hydraulic line has been repaired and all other hydraulic connections inspected. Please contact me at 907-276-4552 for any additional information you!may require. Very truly yours, jrh 205-910 cc: Mr. Hoyle Hamilton AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 R. K. Riddle RECEIYEO 'NOV 1 8 1980 Alaska Oil E Gas Cons. Commission ...... Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Files Exxon November. !0, 1980 John Levorse~ .~ Petroleum Geol~gxst Jan, with~, called NO?ember 6 t.o. r,epQrt, a.~ fuel line vibra'~-d Off a-~eldSng~,machin~?e~%'ne.,c°n=amlna=e°, sn=w was picked up and i E (ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: November 10, 1980 Exxon Alaska state "C" Well No. 1 Permit 80-46 ,/ . . StAT I[C _ STAT -I CONFER: Mr. Lonnie Smith Chief Petroleum Engineer Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached for your information and files is a Sundry Notice amending the Permit to Drill or Deepen Form 10-401 filed with you September 9, 1980 and approved by Hoyle H. Hamilton on September 24, 1980. Although triplicate filing is all that you require, we have included four copies of the notice so that you may return to us a signed copy for our files. Yours very truly, Robert K. Riddle RKR:et enclosure A DIVISION OF EXXON CORPORATION Form 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 proDosals.) 1. O,L I---I GAS ~ WELL L.J WELL OTHER ~/~i ldcat Texas SNL, 4250' 77001 2. NAME OF OPERATOR 3. ADDRESS OF OPER/~TOR P. O. BOX 2180, Houston, 4. LOCATION OF WELL At surface 660 ' EWL and 660 ' R23E, U.M. At Bottom Hole Location Sec. 14, T9N, R23E, U,M, 13. ELEVATIONS (Show whether DF, RT, GR, otc.) +25 MSL Sec. EWL, 14. 14, T9N, 660 ' SNL, Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-089-20011 6. LEASE DESIGNATION AND SERIAL NO. ADL 28382 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Al~=~ .q~ "(~" 9. W~E~I~ N-~[ ....... Exxon ~1 10. FIELD AND POOL, OR WILDCAT Wildc~ 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 14, T9N, R23E, U.M. AK 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent ¢let&il$, and give pertinent dates, including estimated date of · starting any proposed work. The previous plan was to set the 13-3/8", 72~, N-80, Buttress surface cas- ing at 3300'. We now propose to set this casing at 4000'. The following advantages result with the revised setting depth: 1. During production testing operations, a 5-1/2" circulating (heating) string is normally run to 4000' to prevent the formation of hydrates. In this well, the tubing string will be heated by injecting down the 13-3/8" X 9-5/8" annulus. This greatly simplifies production testing operations in that the 5-1/2" string is not run. It also allows a constant BOP ram size because 3-1,/2" tubing is used for testing (rather than 2-7/8") and 3-1/2" drill pipe is used for squeeze cementing, drilling cement, etc. 2. The revised surface casing depth will provide increased formation integrity while drilling the protective APPROVED CONO,T,ONSaY A,-:-.o-W~ ~__-'-: _- --_ OF kL, IF COMMi$SZONEII TITLE DATE See Instructions On Reverse Side ALASKA STATE "C" EXXON NO. 1 Surface Casing Design Criteria Set at 4000' Burst - Considers gas. gradient to the surface causing lost returns at the shoe assuming maximum expected leak- off gradient. External fluid weight 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (max. shoe leakoff gradient - gas gradient) casing depth = ((16.0 X .052)-0.10) (4000') = 2928 psi Permafrost Freezeback - Considers maximum external collapse gradient of 1.44 pSi/ft and minimum internal fluid density of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP = (max. external gradient - min. fluid gradient) max. permafrost depth = (1.44-(9.0 X .052) )2500 = 2430 psi m Permafrost Thaw Subsidence - 13-3/8", 729, N-80, Buttress Post yeild strain performance exceeds the requirements based on worst case well spacing. Minimum Safety Factors Burst 1.443 Collapse 1.00 Tension 1.50 Figure 5 Well Sketch Alaska Stote C-I 28"X 32"X 56" Refrigerated -Insulated Conductor ~ 85'-!-/- Permafrost Cement to Surface 2.0" L"~ 800' (94#H-40 ST tA C) PermafroSt Cement To Surface 13- 3/8'~ 72 #, NSO, BTC ~ 4,000' KOP-6,600' TOC ~ 7,000'MD 9-5/8"~i) I!,000' (10,{550' TVD) ( 0 :. 1,300' 47 # SOO - 9 5 B TC) (I,300LII,O0O' 47# RS - 90 BTC) TOC 500'Above Potential Hydrocarbon Producing Zone 7"~ 15,6OO'MD (14,800'TVD) ( 0'-12,400' 7", :52 #, PIIO, LTC) (12,4OO'-15,600'7'i :55 # PIIO, LTC) E ON COMPANY, U. SiA. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION October 30, 1980 Re: Exxon Alaska State "C" Well'No. 1 Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska LO/NS 80-169 (80-8.5) (80-42) Mr. Glenn Harrison Petroleum Engineer Division of Minerals & Energy Mgmt. 703 W. Northern Lights Blvd. Anchorage, Alaska 9.9502 Dear Mr. Harrison: Our plan of operations for the subject well provided for the construction of an ice landing strip, approximaaely 1800 to 2000 feet long southeast of the drill pad as depicted on Exhibit A of the plan. Circumstances have arisen which have caused an alteration in our plans requiring that the ice landing strJ.p be extended in a northeasterly direction (NNE 040©) an additional 3000 to 3200 feet as shown by dotted line on said plat. By approval of Exxon's NOTICE OF LANDING AREA n~OPOSAL FAA FO~ 7480-1 on October 27, 1980, the Fed. eral Aviation Authority has sanctioned the construction of this-extended .ice airstrip as described. Yours very truly, Robert K. Riddle RKR: et c: EPA, Region X; klaska Oil & Gas Conservation Commission; U. S. Army Corps of Engineers; Douglas Lowery; William Copeland; J. Scott Grundy; Shehla Anjum RECEIVED A DIVISION OF EXXON CORPORATION 14 LPRO POSED LOCATION ALASKA STA'FE C-I LAT.' 70°05' ?.3.60" LON6.:I46° 14 ' 2.9.89" X-' 469~9:52 Y-- 5~900~746 23 24 EXHIBIT '" P'ROPOSED ALASKA STATE C-I EXXON F. M~ LINDSEY t~ ASSOC. LAND 8~ HYDROGRAPHIC SURVEYORS 2502 West Nodhern Ltght~ Boulevard Box 4-081 ~ I COMPANY U.S.A. Anchorage, A~a~ka Chevron Chevron U.SA. Inc. 575 Market Street, San Francisco, CA 94105 Mail Address: P.O. Box 7643, San Francisco, CA 94120 J. J. Anders Manager, Alaska Division Land - Western Region i ?-I_I_ENG _.~ I September 22, 1980 i//t~.:~!.~;~' ~ ~'! I STA_TTEC:--j ~,.xon A'laska ,State "C" 'Nell No. 1 ~'-----'-'--~ Po~-"~.t r~'~.omson Area ,Section lq, TgN, ]:~.3E, U.M. ADZ., 28382 Arctic .Slope, Alaska Mr. Hoyle H. Harmilton, Chairman Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Reference is made to Exxon's letter to you dated September 9, 1980, regarding the subject well. Chevron U.S.A. Inc. hereby advises you that we concur in Exxon's location shown on the attachments to their September 9, 1980 letter. Very truly yours, JJA:dmh cc: Exxon Company, U.S.A., Anchorage September 24, 1980 Mr. Albert L. Hermann Drilling Manager Exxon Corporation P. O. Box 2180 Houston, Texas 77001 Re= Alaska State #C" Exxon No. 1 Exxon Corporation Permit No. 80-46 Sur. Loc.: 660~EWL, 660~SNL, Sec 14, T9N, R23E, UM. Bottomhole Loc.= 4250~EWL, 660'SNL, Sec 14, T9N, R23E, UM. Dear Mr. Hermann = Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated March 11, 1980, accompanying the original approved permit are in effect for this revision with the exception that a direction survey now required. Very truly yours, ]Bam~13R~ER~I..~ OF THE Chairman of Alaska Oil & Gas Conservation Commission Enclosure cc: Department of Fish & Game, Babitat Section w/o encl. COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: September 9, 1980 Exxon Alaska State "C" Well No. 1 Point Thomson Area Section 14, T9N, R23E, UM ADL 28382 Arctic Slope, Alaska Mr. J. E. Thoeni Chevron USA, Incorporated Box 7-839 Anchorage, Alaska 99510 Dear Jack: As discussed with you today, circumstances have required that we refile with the Oil and Gas Conservation Commission inasmuch as construction of the drill pad has long since been completed and the rig and camp are on location. Thus, to reach our revised location by directionatly drilling requires a refiling pursuant to 20 AAC 25.050. Accordingly, copies of today's letter to Chairman Hoyle H. Hamilton, the application for a permit to drill (Form 10-401) and the necessary plats are enclosed for your file. As several matters have occurred causing a number of delays we would appreciate your advising the commission of your concurrence with the operation in its present form at your early convenience. We greatly appreciate, Jack, your willingness to cooperate as you have in this matter. Sincerely, Robert K. Riddle RKR:~et -. A DIVISION OF EXXON CORPORATION E) g ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION September 9, 1980 Re: Exxon Alaska State "C" Well No. 1 Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska Mr. Hoyle H. Hamilton, Chairman Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: By our letter of February 5, 1980 Exxon Corporation submitted State of Alaska, Oil and Gas Conservation Commission Form 10-401 in triplicate with triplicate copies of the location plat, contingency plan and Exxon check No. EC 22174 in the amount of $100.00 in payment of the required permit ~fee. By your letter of March 11, 1980 you returned the fully approved permit and provided information and direction with respect to the operation. Subsequent to the above a determination was made to drill the well, not vertically as originally provided for, but directionally from the same surface location to a bottom hole location due east thereof. Accordingly in compliance with Oil and Gas Conservation Regulations, 20 AAC 25.050, we are by this letter withdrawing our previously approved permit and submitting a new application'for a Permit to Drill Form 10-401 with the surface and bottom hole locations ap- propriately noted. As there are no other well bores within the distances requiring a large scale plat showing the path of the well bore we have instead re-submitted herewith the survey plat which was included with our initial application and have depicted thereon the bottom hole location and proposed path of the well bore. In addition we submit a plat, 1"=8000', depicting the subject lease and the leases adjacent to it, Chevron USA, Inc. is the only lessee required by 20 AAC 25.050 to receive notice of this application, hence by registered mail a complete.copy of· this letter and its attachments has been sent to them with a request that you be notified of their concurrence. A DIVISION OF EXXON CORPORATION Mr. Hoyle H. Hamilton Page two September 9, 1980 As the U.S. Army Corps of Engineers permit referred to in our letter of February 5, 1980 has been issued and all state and borough permits required for the operations have been received as well, we anticipate an early commencement of drilling operations following your reissuance of the requested permit. Yours very truly, Robert K. Riddle RKR: et enclosures c- EPA Region Ten, Attn-' Danford G. Bodien, P.E. Form 10~401 REV. 9-1-78 SUBMIT IN T FE (Other instruct~ .... n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION~COMMISSlON PERMIT TO DRILL OR DEEPEN .... reverse side) la TYPE OF WORK DRILL [] DEEPEN [:] b. TYPE OF I/~ELL /: ! OIL GAS SINGLE MULTIPLE WELL [~ OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporation . 3. ADDRESS OF OPERATOR P. O. Box 2180, Houston, Texas 77001 4. LOCATION OF WELL At surface 660' EWL and 660' SNL, Sec. 14, T9N, R23E, U.M. Ak At proposed prod. zone 4250' EWL and 660' SNL, Sec 14, TgN, R23E: U.H. Ak 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 55 miles east of Deadhorse, Alaska API #50-089-20011 6. LEASE DESIGNATION AND SERIAL NO. ADL 28382 7. IF INDIAN, ALLOTTEE OR TRIBE HAME 8. UNIT FARM OR LEASE NAME Alaska State "C" 9. WELL NO. Exxon No. 1 I0. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 14, T9N, R23E, U.M.Ak 12. 14. BOND INFORMATION: Oil and Gas Conservation¢~/.n/,o TYPE Suretvand/orNo. ~o.v.~ State Bond File ~'~ "D---~ 15, DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT, (Als~) to neaxest drig, unit, if any) 6 6 0 ' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) +25 MSL 16. No. OF ACRES IN LEASE 2560 .19. PROPOSED DEPTH 14,800' TVD 15 ~ 600' MD Amount $100,000 17. NO:ACRES ASSIGNED TO THIS WELL 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START Location 4/1/80, Spud 10/80 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement . 40" 36x32x28 Insulated Refrigerated 85' To surface with permafrost cemen.t. 26~' 20 94 H-40 800' TO surface with Do_rmnFrc~.q~- oomtant- 17-1/2" 13-3/8" 72 N-80 3.300' ,~ Tn .m,rf~p'~ ~a~rh n,,"m~¢,-~o~- ~,m~,,V 12-1/4" 9-5/8" 47 Sooa~-130 D' RS-90 1300-11,000 Appr6x. ~0C'-7~J00~ .................... 8-1/2" 7" 29/32/35 P-il0 9300/12250/15600 500' above potential HC zone BLOWOUT PREVENTERS: A 20" annular blowout preventer with diverter lines will be installed on the insulated conductor, as shown on the attached sketch. The diverter will be removed while opening the 17-1/2" hole to 26" to.800'. The same diverter system will be used on the 20" conductor. A 13-5/8", 5000 psi WP annular BOP and three 13-5/8", 10,000 psi WP ram type. preventers will be.installed on the 13-3/8" casing as shown on the attached sketch, and will be used along with a 10,000 psi WP choke manifold during drilling and well. testing. BOP installation and testing will be in compliance with Alaska State Regulations effective April 13, 1980. Anticipated surface.pressures are shown in the casing design section. Pressure on the 5000 psi WP annular BOP will never be allowed to exceed its design working pressure. [eNwAB~ uVEct~v%i%En eD. ,FrS p%RolpBoEsa 1P irs t%POO~..E Do r%% e%%Rn %5 clt[ oPni aO117,mgll. ¢; ;%rdti~ ne ePne~ dagi~ae od ;t s%%~urplf~%nltoPc ~ toi%~t ia~ z~e%%;i%dd%? ,%Sueed /~ vertcal ~epths: Give bl°w°ut Prevente/Pmglam' 24. I hereby ce~ifY that/the Forello_ ilg isAue a~d Correct / / / ~ (This space for State office us~)~~ CONDITIONS OF APPROVAL, IF ANY: - SAMPLES AND CORE CHIPS REQUIRED I MUD LOG OTHER REQUIREMENTS: ~fYES [] NO I .,¢[:~ES [] NO DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE YES [] No 5-0- o %. o o i i PERMIT NO. ~ ~ - ~'~ ~ APPROVAL DATE A O' v~, - *See Instruction On Reverse Side DATE 09/24/80 FC~e~. CR-13 ~/72 ~,~o~, .. C ,~/,, CASING ~'fR TNG HOLE SIZ~ . CASING SI~ ~fJD WT. I . HYD GR. i ~fu.'D k~. II #/~. HYD. GR. II psi/fi, M.S.P. ,. Ih~ERVAL LENSTH. ' DE$CBTPTiOhr ~;EIGHT TENSION ~r:,~,~,z..~.,_..~,.~F COLL~SE COLL~,3SE CDP W/ BF 'top of ST~NG~H P~SS. ~ P~SIST. P~SS~ ~ttom Top Wt. Grade ~nread W/O BF - section TEIfSiON bott~ tension Y~LD lbs'-- lbs !O00 lbs psi ~si psi psi . ~3oo o ¢3oo ~9 9-t,o L~C ~~ ~Fl~ 7~7 , hg& 7173 .26,70 Y=Tensile L. oad/Pipe Yield Strength Co .2 .~: .6 .8 L.O 'F:.-:-:T:::~:-::-'.¥ :' :.:~:':,'~'-:]':::~ :".t, ~.. :::::::::::::::::::::: ll::.lk.::l;,l.,:;:;t' / i ~ ....... ~-- --i" :TI :':';:~;: ';;:~:.'. :-::1~::; ::::;' ::;: ,:'., ~1 ...... I ...,, ...,. I, '~?...:5 '~[.::;;.::.~::u':.'.?Tr.";:.::i::::l::: (:-~~ ~(~I~!~~.';;'-: 4! ;'~.'. ::'::::::','::: ;::',: ':i :' !:.' ' ~~;: i:i:i:;~., :-ii:;~ I ..... .... '.' ~ ____,;..;':'1,:;:,:";:.' i 1':; ...... .:';' :il.:: rr..--m-. .................. :4 ..... -:.:1 " .... ' ....... I' ' I /I ' , ; I-..~, · Cl;".'" ! ....... ,' ....... . ~ :'":'::," ..'~ l'., :': i . ~1::,' '%:.: .;. ;:~1 ;',;;'.. :: i " 7:r:".7.'-.:: ':.'J;.;'l."." '""'1 ;' ; .... :--'i ..... /~1 'll'-' I · Ot'' .... ' .......... '-" :"':':'"'F:t;f!" Formulae: Collapse resistance in tension = X (Collapse press,~re ratify) Burst Pressure = ~[SP + Depth ( }{yd. Gr. II --.5) BF (Bouyancy Factor) = ~.oo- (o.oz53 x ,~.~=a wt. T) -) BDF PP_~CZ PER CC/ 0,75-0,~/ o gS'/O /,,2. 7/73 llZZO /../~. /.3 ii,Bo /209?. /,o~ //q3o /ZToo /,/ Calculations: .,. TQLai Cost : ,o. 2q' X, = 0,8C _______--- &/2.. ~ ~r~ ~_.l~;~ to x lo TO ~ Incu 7 x ~o ~NCHES ~,.,'~: 1323 KEUFFEL & ESSER CO. MADE IN U.S.A. ALASKA ST. "C" EXXON NO. 1 SUBSURFACE INJECTION' After setting the 9-5/8" casing into the pressure tran- sition zone (ll,O00' MD), waste fluids and hydrocarbons will be injected into saltwater zones from 3300' to 7000' down the 13-3/8" x 9-5/8" annulus. CASING DESIGN CRITERIA: See attached Wellbore Sketch for design Surface - 13-3/8" @ 3300' · Burst - Considers gas gradient to the surface causing lost returns at the shoe assuming maximum expected leakoff gradient. External fluid weight 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (Max. shoe leakoff gradient - gas gradient) casing depth : (16.0 x .052- 0.10) 3300' = 2,416 psi · Permafrost Freezeback - Considers maximum external collapse' gradient of 1.44 psi/ft and minimum internal fluid weight of 9.0 ppg. Maximum Collapse Pressure (MCP) MCP = (Max. external gradient - min. fluid gradient) max. permafrost depth : (1.4~- 9.0 x .052) 2500' : 2,430 psi · Permafrost Thaw Subsidence - 13-3/8" 72#/ftN-80 Butt post yield strain performance exceeds the requirements based on worst case well spacing. · Safety Factors Burst 1.443 Collapse 1.O0 Tension 1.50 PROTECTIVE '9-5/8" @ 10,500' TVD = ll,O00' MD · Burst - Considers gas kick of sufficient intensity and volume to cause lost returns assuming maximum expected leakoff gradient and casing filled with water. External fluid weight 9.0 ppg. Maximum Surface Pressure (MSP) MSP = (Max shoe leakoff gradient water gradient) casing x .0 2 - 8.33 x .0 2) 0, 00' : 5,826 psi ALASKA ST. "C" EXXON NO. 1 Page 2 · Collapse - Considers surface pressure = 0 psi, internal fluid weight 8.33 ppg and external fluid weight 12.5 ppg Maximum Collapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing TVD - surface pressure : (12.5 x .052 - 8.33 x .052) 10,500' - 0 : 2,277 psi · Safety Factors Burst 1.39 Collapse 1.O0 Tension 1.50 PRODUCTION 7" @ 14,800' TVD = 15,600' MD · Burst - Considers shut-in gas well surface pressure on kill weight packer fluid and external fluid weight of 15.5 ppg. Maximum surface pressure (MSP) MSP = (Max. kill wt. fluid gradient - gas gradient) Casing TVD = (15.5 x .052 - 0.18) 14,800' j: 9,265 psi · Collapse - Considers surface pressure = 0 psi, internal fluid weight = 0 ppg and external fluid-weight : 15.5 ppg Maximum Col lapse Pressure (MCP) MCP = (External fluid gradient - internal fluid gradient) casing TVD - surface pressure : (15.5 x .052 - O) 14,800' - 0 : 11,929 psi · Safety Factors Burst 1.273 Collapse 1.098 Tension 1.50 TYPICAL 2000 PSI W.P. DIVERTER STACK AND LINE FOR USE ON 30" AND 20" CONDUCTOR CASING ALASKA STATE "C" EXXON NO. 1 Butterfly Valve Flowline _ ~k 2,000 Psi W,-P.- Annular BOP (]]) To Burn Pit Mi ni mum 6" Dive rter Li ne 20" Spool or 20" Casing To Reserve Pit 28" x 20" Swage Full opening hydraulically operated valves interlocked such that one diverter line valve will always be open before annular BOP is closed: KILL LI I TRIP TANK ANNULAR BOP RAM BOP 5000 psi W.P. Pipe lO,O00 psi W.P. Component Specifications SPOOL Pipe' lO,O00 psi W.P. ® -® ® CHOKE MANIFOLD 1. Screwed Plug or Gate Valve - 2" size provided with A-section 2. Screwed Plug Valve- 2" size 3. Screwed Tapped Bullplug with Needle Valve and Pressure Gage 4. Flanged Plug or Gate Valve - 2" size provided with wellhead 5. Flanged Plug Valve - 2" size with companion flange to protect valve flange face 6. Flanged Plug or Gate Valve - 2" minimum size 7. Flanged Tee - 2" minimum size 8. Flanged Flapper Type Check Valve - 2" minimum size 9. Flanged Hydraulically Controlled Gate Valve - 4" minimum size 10. Flanged Plug Valve - 4" minimum size. Gate valve not acceptable. ll. Top of Annular Preventer must be equipped with an API Flange Ring Gasket. All flange studs must be in place. 12. The I.D. of the Bell Nipple must not be less than the minimum I.D. of the BOP stack. NOTE: All valves on kill and choke lines lO,O00 psi W.P. TYPICAL ARRANGEMENT OF 13.-3/8" lO,O00 PSI W.P. BOP STACK FOR USE ON 13-3/8" SURFACE AND 9-5/8" PROTECTIVE AND 7" PRODUCTION CASING ALASKA STATE "C" EXXON NO. 1 TR 96 1,657.21 Ha )1 Ac SOHIO COMBINE 2-1-90 $400 1.00 pab SOHIO COMBINE 1 2-1-90 $1695.00 pab 9 Ac 30 30 +- ADL312848 5265.97 Ac ADL312649 4233.64 Ac R 110 R 111 EXXON DLICHE~S I. 408098 2-1-90 N. ~.~_ AR I. $9945.52 pab 18 Ac ,~0% )N 50% ARCO EXXON 408097 ,-~:, C.o ~ 3 0 2-1 - 90 $15,169.74 Dab ;~ - ~_ ~:' ~ ~_,~ ADL312863 75% 25% 816825 HBU 163.06 23 60Ac. DL47561 CHEVRON ~xk, oN' · 2 Pt.T. Un. HBU 14117~ 318.75 8-78~E 23 xxo.'-%6 ~i;, ICHEVRON 50% : ! 817185 564 EXXON /~OB -PHIL C~EV ~O°~!iCONOC025% .~ -';;:: I 8~7190 ~ I HBU 817191':; 23 ADL50983 ~ 816812 HBU HBU EXXON 5O% 131.00 ,TIPPERARY I e~ o~ 50% ~'~Ac. 817178 m, ~'~"-' HaU '-- I-Pt.T. Un, ,3, DL5t667 ADL47560 13,298 2560Ac. 12-77 EXXON 50% EXXON 50% CHEVRON 50% CHEVRON 50% 817186 HBU 817'187 ~xxo, ~o%I 835.40 HBU I 23 1060.94 CHEV } "3/0{ ~OS~L 50 ADL47569 23 PHIL. 2533Ac. 560Ac. )% )% PHILLIPS 50% 3-27-84 12.00 14 kDL28376 2560Ac. MOBIL PHILLIPS MOBIL ,~ PHILLIPS 13,329 CHEVRON 8-70 ~ oo $-:~7-84 14 MOBIL ~ MO-~' PHILLIPSIPHILLIPS SHELL I ! ADL28380~ 2-W.S.S. MOS 13,171 PHIL. ~,RCO 50% Tcl N -R23£ 815664 3-27-84 16.62 ADL28381 2560Ac: MOBIL PHILLIPS TR 112 113.72~hb 2,233.32 Ha TR 22 Ha EXXON 408099 2-1-90 $1422.10 pab 30 NO BID BF 652.47 Ha TR 113 NO BID 30 767 758 ADL312864 4683.02 A, 3,354.74 Ac TR 114 EXXON 408100 2-1-90 FL. AXMAN I. 30 MOB. 2,5% PHIL. 50% ~HIL. 250/0I 8171~77 I HBU 137.94 2.% ADL47558 1280 AC. 1280 AC. 25 T.V.D. MOBIL $875.00 pab 801 52.35200% NP ,' ,. ADL312866 4935.47 Ac 50% EXXON F 50% ALASKA St"A" 811 HBU ~SIP 9 -75 "),..~ '~. 209.31 859.68 : ~ 23 23 2523A CHEVRON HBU 1412.50 23 EXXON 50% ARCO 50% 815665 ADL28382 2560Ac: EXXON 50% ARCO 50% c. v.o. -Jr- / POINTTHOMSON MOBIL 500/0 MOBIL TeN-R2 T9 N - R25E =H~LL~PS ~/e ~-STA~..ES R. S* ,- ' [ ~ 'C HISIP ,3~ 258' ~ ADL47573 ~ ' · ASL ~TAKED T ION .... x--ALASKA STATE C- I T 9N o~,O, , I ~ ~_ ~ ~,.~ooo~.~o. , Il ~ 7~1~ ~~ Long. 146° 14' 29.89.' r-__._-' -- ,I i~~% ~ !~ -~ Y= 5900746 ,. / ~ 0~' Ground Elevetion 25 - ,, ',o. ,, . I . ~l~_ ~ .Lo~,~o~__ I.. ~ ~ ~ ........ I I ! , , , i ~ /..~. -- ;~.,........;W.~ t.. ~z ~;.. ~ , ..~,~. I": I Mi le · " ~ ..... A~d~a/Boftom Hole Loc~ti~n n~. ~ ,, , · --[~o~,,,,~~ ,,-~ ,~,,,.- ,,,. ALASKA STATE C-I CERTIFICATE OF SURVEYOR ~OCATED.I,,N ~ECTION I~i T 9 N.~,R ~3 E.lU,,.M. , I hereby certify thor I om properly registered ond licensed to practice Iond surveying in the store of' Aloska and fhot this plot represents o location survey made by me or under my direct supervision ond thor oil detoils ore correct. DATE SURVEYOR ANCHORAGE, ALASKA DAT.E i / 7/80 i SURVEYED FOR EXXON COMPANY i SURVEYED BY BESSE, EPPS & 9 -9-80 i U.S.A. i POTTS , , 3_44- Il I Ill I Ill Illl Il Ill l Illl Illl Il l[ l[ I Illlll I I Illl Illl IIII I WELLBORE & CASING DESIGN SKETCH ALASKA STATE "C" EXXON NO. 1 O' ~ 29#/ft P-110 LTC ,300' /ft P-110 LTC 2,250'--~ ~ft P-11C LTC .~°'::'" 36" x 32" x 28" 'l 20" 94#/ft H-40 Insulated Conductor @ 85' Conductor @ 800' 13-3/8" 72#/ft.N-80 Butt Surface Casing @ 3300' Waste fluids and hydrocarbon injection zone TOC @ approximately 7,000' 9-5/8" 47# S09-.95 '& RS-90 BTC Protective Casing @ 11000' MD 7" Production Casing @ TD . O'N COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Mr. John Miller Division of Minerals & Energy Mgmt. 703 West Northern Lights Blvd. Anchorage, Alaska 99503 August 21, 1980 Exxon Alaska State "C" Well No. 1 Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska LO/NS 80-42 - 80-85 Dear Mr. Miller: The subject plan of operation, which was approved July 21, 1980, provides on page 4 under "Drill Site Facilities - Water Supply", that potable water for the camp facilities will be hauled from state approved small lakes near the rig anda large, eight-foot deep lake in Sections 22 and 23, T9N, R23E, UPM, approximately 1.5miles southwest of the location. While we wish to utilize the approved "large, eight-foot deep lake" as our principal water source we would like to have your approval of a different method of transport of the water. Instead of hauling the water which would require initially the use of a Rolligon and after freeze-up an ice road, we would like to install a pipeline from the well location to the source lake following the route depicted on the attached plat and pump the water from the lake to the site. The pipe would be insulated to prevent freezing. No cut of any kind will be made in the tundra as the pipe will be laid atop the surface and .snow will be allowed to completely cover the line. We'do not anticipate :using pump machinery of any kind at the lake and thus no fuel will be stored off the drill site. We are confident ~_hat this me~hod for providing'water for the forthcoming operation will not only becost efficient, but will have demonstrably beneficial environmental results. As the laying of the line will have to be accomplished prior to freeze-up an early approval of the proposed plan will be sincerely appreciated. RKR: et cc: Yours very truly, EPA Region X, Alaska Oil & Gas Conservation Commission, U.S. Army Corps of Engineers, Douglas Lowery, William Copeland, J. Scot? .... Grundy, Shehla Anjum L ~ A DIVISION OF EXXON CORPORATION AU$ 3 5 1980 Anohur'aga 8 , . 28 32 \ \ ".,e 33\ ~/ ' '-0 *'- 14 ~.~.T E C 26 3~, 35 x 32 i ii i iii i II III III . III I II I III ' ': '"×: '~ ~' ~ ~ '33 .'".~ :~: ,... ;/' · ''.'? ~,,~'~ . 30 t ~ 66 '"-., 12 · 55 17 x I0 ~ ~60 4 Shoal ~ Q 23 · ' I10 / / 23 E) ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION J_/_/_/~l COMM J j~'J' 1 EN,~ ,.Tul~ 30 1980 f' J 3 .r....,,~<~, · I' 'J 4'EN~ Re: Alaska State "C" Exxon Permit No. 80-46 ,__,T_-=_=:!__i_~U~.~L~---- I ~ O~_OL ! STAT TEC-- I STAT T~C- ;' CONFER: i FILF: Mr. Lonnie C. Smith Chief Petroleum Engineer Alaska Oil & Gas Conservation Commission 3001 'Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached for your information and files is a Sundry Notice amending the Permit to Drill or Deepen Form 10-401 filed with you February 26, 1980 and approved by Hoyle H. Hamilton on March 11, 1980. Although triplicate filing' is all that you require, we have included four copies of the notice so that you may return to us a signed copy for our files. Yours very truly, RKR: et enclosure A DIVISION OF EXXON CORPORATION Form ! 0-403 REV. 1-10-73 Su~)mlt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL 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.} OIL I--'1 GAS I--1 WELLI---J WELL L-J OTHER Wildcat 2. NAME OF OPERATOR Exxon Corporation 5. APl NUMERICAL CODE 50-089-20011 6. LEASE DESIGNATION AND SERIAL NO. ADL 28382 7. IF INDIAN, ALLOTTEE OR TRIBE NAME N/A 8. UNIT, FARM OR LEASE NAME Alaska State "C" 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6601, Anchorage, Alaska 99502 Exxon No. i 4. LOCATION OF WELL At su.ace 660' SNL, 660' EWL Section 14, T9N, R23E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) +25' MSL 14. 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 14, T9N, R23E, UPM 12. PERMIT NO. 80-46 Check Appropriate Box To Indicate Nature of Notice, Re 3ort, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF., TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SNOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Other) (NOTE= Report results of multiple completion on. Well ComDletlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR, COMPLETED OPERATIONS (Clearly ~ate all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · i~a) Amend casing and cementing program in accordance with the attached Wellbore Sketch which differs from that originally'submitted as follows: (c) (1) 20" Conductor @ 1000', instead of 18-5/8" Conductor (2) Change TOC for. 7" casing to +-10,000' Change proposed depth to 14,800' TVD (.approximately 15,650' MD) Change from vertical to directional hole having a bottom hole location 4250' EWL & 660' SNL, Section 14, T9N, R23E, UPM ' hereby certlfYj' that/~ f(:~e~~ing / true and correct / (This space for Stat~[~'~) JUL 3 1 1980 Alaska 011 & r~ ~ ~,: An01~u~a~t~ APPROVED BY CONDITIONS OF APPROVAL, IF ANY: Drilling Manager COMMISSIONER TITLE ,, BY ORDER OF THE DATE July 25, ,,1980 DATE See Instructions On Reverse Side WELLBORE SKETCH ( · EXXON ALASKA STATE C, WELL #1 CEMENT TO SURFACE 36" x 32" x 28" INSULATED CONDUCTOR @ 85' CEMENT TO SURFACE 20" CONDUCTOR @ 1000' CEMENT TO SURFACE 13-3/8" SURFACE CASING @ 3500' WASTE FLUIDS AND HYDROCARBONS INJECTION INTERVAL TOC @ APPROXIMATELY 7000' TOC @ APPROXIMATELY lO,O00' 9-5/8" PROTECTIVE CASING @ + 10,500' 7" PRODUCTION' CASING @ TD .. RECEI JUL $1. 1980 Alaska Oil & G .~ , ,.,,~ ...... ~,~,:~,,, "----..'w-""" COMPANY. U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99.502 EXPLORATION DEPARTMENT ALASKA]PACIFIC DIVISION Re: J~e 24, 1980 ' on Wet ~a ~s~ S~e B-1 ..... J STATTE~ Drill~g P~ Cons~c~on J STAT TEC .J ~L 28382 'J ' ~-~-r~ - _. ~4 S~. 13, T9N, ~3E, ~M ~ ........ ~ctic Slo~, ~as~ Beaufort Sea 80, 071-0YD-4-800016 Colonel Lee R. Nunn District Engineer U.S. Army Corps of Engineers P. O. Box 7002 Anchorage, Alaska 99510 Dear Colonel Nunn: At the.beginning of the year Exxon applied to you for permission to construct two drilling locations designated Alaska State B-1 and Alaska State C-1 respectively, each situated upon the subject State of Alaska oil and gas lease. Although ~iately following your issuance of the permit designated _~071-0YD-4-800015, authorizing construction of the ~('S~operations were cor~nenced, no further t~ remained --t~0--1~in~- its completion for further construction work consistent with the conditions theretofore agreed to. Accordingly, we have abandoned for the present all plans to construct the Alaska State B-1 location and hereby withdraw the subject application. - RKR: et cc: Yours -¢e~-f t~uly, Robert K. Riddle Al~t~k,a Li,~ ~,: ' A..q~!lu J aq~ Alaska Oil & Gas Conservation Commission, Hoyle H. Hamilton, Chairman Division of Minerals & Energy Management, Dr. Ross H. Schaff, Director Department of Environmental Conservation C. Deming Cowles, Deputy Commissioner Douglas Lowery, Environmental Supervisor Department of Fish & Game, J. Scott Grundy, Regional Supervisor Division of Policy Development & Planning, Fran U1/~fr, Director Division of Forest, Land & Water Manag~t, William Copeland, Northcentral District Manager A DIVISION OF EXXON CORPORATION COMPANY, U.S".A. POUCH 6601 · ANCHORAGE, ALASKA 99502. EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Mrs. Ethel H. Nelson Leasing Manager Division of Minerals & Energy'Mgmt. 703 West Northern Lights Blvd. Anchorage, Alaska 99503 Dear Mrs. Nelson: The amended plan of operations LO/NS 80-85 filed with you on April 3, 1980 anticipated in paragraph 5. of the "Construction and Operat'.~n. g Plan" that upon cc~pletion of the drilling pad, Exxon would move in Parker .Drilling Company Rig No. 96, camp and all supplies except fuel. On May 3, 1980 the drilling pad was completed, following which the camp, certain cc~ponents of the Parker rig and all supplies then available, including 128,000 gallons of fuel, were moved over Beaufort Sea ice and a then existing ice road from Point Thomson Unit No. 3 to the completed drill site. At this point the site was secured until such time as available equipment and the condition of the tundra permit the transport of all of the remaining components and supplies to the location. We are by this letter requesting your approval of a further revision of the subject plan of operations to permit the transportation by tug and barge of approximately 600 tons of rig equipment including five 50,000 gallon tanks and an additional 250,000 gallons of fuel from the Prudhoe 'west dock to the Point Thomson Unit No. 3 well site. ~ne five tanks Will be temporarily set up at Point Thomson No. 3 in a provisional storage area lined with plastic and protected by a 2' gravel berm; following which all the fuel will be pumped into them from the barge. From Point Thomson Unit No. 3 the remainder of the movement to the subject location will be completed by Rolligon in strict accordance with the provisions of the Rolligon operator's Miscellaneous Land Use permit covering North Slope overland transport with fuel and tanks hauled, separately. A DIVISION OF EXXON CORPORATION Mrs. Ethel H. Nelson Page two June 23, 1980 As we are not at this time able to forecast either the precise date barge and tug transport will become available or the date the state will permit surface transport via Rolligon we have been intentionally imprecise as to the'time the movement of remaining equipment and fuel will take place. We do, however, intend to c~nce the operation as soon as possible~ If the move is no later than mid August we should be in a position to-commence drilling operations shortly after mid September in accordance with our' past discussions. Your early approval of the subject plan of operations as amended previously and further amended herein will be sincerely appreciated. Should there be any remaining questions unanswered by the foregoing please do not hesitate to let us know and ~;ery effort will be made to provide ~%atever is required. Yours very truly, RKR:et cc: EPA Regio~ X, Alaska Oil & Gas Conservation Commission, U.S. Army Corps of Engineers, Douglas Lowery, William Copeland, J. Scott Grundy, Shehla Anjum COMPANY, U.S.A. POUCH 6601., ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION Re: Mr. Tom Cook, Director Division of Minerals and Energy Management 703 West Northern Lights Blvd. Anchorage, Alaska 99503 April 3, 1980 Exxon Alaska State "C" Well No. Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska .... COMM-- COM~ 1 EN~ 3 ENG 4 ENG STAT STA~~ Dear Mr. Cook: Exxon's plan of operations for the subject well, filed with you February 5, 1980, contained the following footnote on page 2, Present shortage of rigs on the North Slope requires that Loffland Rig No. 162 be used in drilling Alaska State "C" No. 1 directly following completion of Point Thomson Unit No. 4. Should another rig become available in sufficient time to permit its movement to the location prior to spring breakup 1980, it will be substituted for the Loffland rig and the plan of operation will be revised accordingly. While circumstances existing at the time the plan was prepared required that Loffland Rig No. 162 be used in drilling the Alaska State "C" No. 1, we have since that time had the good fortune to contract with the Parker Drilling Co. for its Rig No. 96 and therefore wish to amend the segment of the plan of operations entitled the "Construction and Operat'..zn. g Plan" by deleting the first two paragraphs thereof as well as the proposed sequence for Preparation of the drill site, and substituting the following in lieu thereof: "Parker Drilling Company Rig No. 96 and its 70 man camp"'will be used in drilling Alaska State "C" No. 1. ~nis rig and camp will be moved 'from its present location at Pt. Thomson No. 1 via the Beaufort Sea ice road to Pt. Thomson No. 3 and thence via the ice road (item 1. below) to the drill site, the construction of which shall be accomplished as follows: Ae Construct an overland temporary ice road, connecting with Ocean Ice Road, extending from Point Thc~son Unit No. 3 to Alaska State "C" No. 1 as shown on Exhibit A. 2. Move in and activate mobile construction camp. 3. Move in equipment and construct drilling pad, Alaska State "C" No. 1. e Upon ccmpletion of drilling pad, demobilize construction camp and equipment. RECEIVFb A DIVISION OF EXXON CORPORATION Mr. Tom Cook Page tw~ April 3, 1980 5. Move in Parker Drilling Co. Rig No. 96, camp and all supplies except fuel. 6. Leave site in standby status pending freeze-up in fall of 1980. . After freeze-up in fall of 1980 reconstruct ice road extending from Pt. Thomson Unit No. 3 to Alaska State "C" No. 1 'and move in fuel and water. 8. Repair and maintain haul road as necessary using maintainer and water trucks." In addition we wish to amend the portion of the plan of operations entitled "Drill Site Facilities" by deleting items numbered 1., 2. and 3. and substituting therefor the following in lieu thereof: 1. Sewage Disposal A M~t-Pro 14000 Series independent physical-chemical sewage disposal unit.. owned by Parker, which complies with the requirements of the State of Alaska and the EPA for water quality in the area of operation will be installed for the treatment of sanitary sewage. Treated effluent from this unit and gray water, which is discharged from kitchen and shower areas, will be combined in a steel storage tank and used for drilling mud or rig wash water. A 25' x 60' x 6' deep earthen holding pit will be provided for the temporary storage of sanitary sewage in case of an upset of the treating unit. 2. ''_Water Supply Potable water for the camp facilities will be hauled from state approved small ~"lakes near the rig and a large, eight-foot deep lake in Sections 22 and 23, T9N, R23E, UPM, approximately 1.5 miles north of the location. A snow melter will be used to supplement the water requirements until shallow lakes closer to the rig thaw in the summer. The water will be processed through an approved water treating unit owned by Parker Drilling Company before use in the camp. Additionally, treated sewage effluent and gray water from the camp will be used for mud and rig wash water. 3. Gar ~bage and Waste Disposal Burna~_bie garbage and wastes Will be disposed of in a Smokatrol Incinerator Model 200 made by U.S. Smelting Furnace Company. Some of the more readily ccmbustible products, such as paper, wood, and cardboard, may also be open burned. Noncombustible wastes, such as scrap metal, tires, batteries, and drums, will be hauled to Deadhorse and final disposal will be in accordance with State Waste Manag~t requirements. We shall continue to advise you as work progresses under the plan of operations as revised. RKR: et c: Yours very truly, R E C E IV !.: APB 1 1980 Alaska Oil & EPA Region X, Alaska Oil and Gas Conservation Conxnission, U.S. Corps~ of Engineers, Douglas Lowery, William Copeland, J. Scott Grundy March 11, 1980 Mr. R. Bright Dril ling Manage r Exxon Corporation P. O. Box 2180 Houston, Texas 77001 Re~ Alaska State wC""Exxon No. 1 Exxon COrporation Permit No. 80-46 Sur. ~Loo.~ 660~SNL, 660~EWL, Sec. 14, TPN, R23E, UM. BottOmhole Loc. = SAME Dear Mr. Bright= Enclosed is the approved application for permit to dri1! the above referenced well. Well as., core chips and a mud log are required. A survey is ~ot required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity sur- veys and dipmeter surveys. in Alaska and their drat~nage ~ystems have been cia 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 Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. Bright Alaska State uC* Exxon No. I --2-- ' March 11, 1980 cc~r~ncing operations you may be contacted by a representative of the' Department of Environmental conservation. 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 this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the c.csamtssion may be present to witness testing of blowout preventer equipment 'before surface casing shoe is dr il led. In the event of 'suspension or abandonment, please give this office adequate advance notification so that we may have a Very truly yours, Hoyle H. Hami, lton Chairman of BY ORDER OF TH2 COMMISSION Alaska Oil & Gas Conservation Comaiss£on Eric losure cc: Department of Fish & Game, Habitat Section w/o eno1. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o eno1. E ON COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION February 5, 1980 Exxon Alaska State "C" Well No. 1 Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska Mr. Hoyle H. Hamilton, Chairman Alaska Oil and Gas Conservation Conlmission State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Exxon Corporation sut~ts the following in regard to the captioned well: (1) State of Alaska, Oil and Gas Conservation Committee Permit to Drill, Form 10-401, in triplicate with triplicate copies of the location plat and contingency plan. (2) Exxon Check No. HE 22174, dated February 6, 1980, in the amount of $100.00 in payment of tb~ required permit fee. Concurrently with this application, we are filing with the State Division of Energy and Minerals Management the following: (1) A plan of operation describing the drilling pad, rig, supply, waste and sewage disposal, and pollution prevention. (2) Vicinity and location plats. It is our plan to c~ce work in April, 1980 by the construction of the drilling pad in accordance with an application filed January 14, 1980 with the U.S. Army Corps of Engineers. We are presently unable to give precise dates for rig movement and co--cement of actual drilling operations, however such dates will be provided in a later filing as they become available. OCR:RKR:et enclosures c: Sincerely, Robert K. PH_ddle EPA Region X - Mr. Danford G. Bodien, P.E. U.S. Corps of Engineers - Colonel Lee R. Nunn A DIVISION OF EXXON CORPORATION &L'V.' I-- I-- .TI iiii DRILL · ,,~ OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT'"' TO".DRILL 'OR' m 77001 EXXON CORPORATION P. O. BOX 2180, HOUSTON, TEXAS ~^T,O.~'Or ~-~ '" WILDCAT EWL SEC. 14 TgN,R23E UM AK API #50-089-20011 ~n L ~ D~IGNATlC)N ADL 28382 55 MILES EAST OF DEADHORSE, ALAS~ ~ ~'A~O~ , ~u~~ m ............ OIL AND ~S CONSERVATION ~~ ..-~...,..~o 5134049 STATE BOND FILE B-l-4 ~STA~ FR~I P~OP~® z~ ~r ~ tN I ,~,. ,o ...,., ,,,~ ~.:,. ,, ..y, hbO' SNL I 2560 ~~-=o~ ..... ' ...... 12,000' N 14,650' + ZS' MS[ PAOPOSZD CASinG A~D C~IL~NG Wrl G h'2' P£R INSULATE~ 96.4# G.~AD£ ,---..--m.m,m--.m ~RIGERA1 ED 85' 1 000' . l_ UNIT rA~( OA ALASKA STATE "C" g~ W~m~m~, NO.IIII EXXON NO. 1 WILDCAT SEC. 14, TgN, R23E,.UPM 1. ,, ~,.,~ $100,000. O0 NC) ACRF..~ ASSIG'~£D TO ~S ROTARY OR CAB)..~ TOOL~ ROTARY ~ APPROX. DAT~. WORK WiL.L. ST~T' LOCATION 4/80 SPUD 12/80 q~o~tity of cemenf TO SURFAC~ I SUBSURFACE INJECTION: After setting the 9-5/8" casing into the pressure transition zone .(+ 10",500'), waste fluids and hydrocarbons 'Will be injected into saltwater from 3500' to7UO0' DOWN THE 13-3/8" X 9-5/8" annulus. BLOWOUT PREVENTERS:~A 20" annular blowout preventer with a diverter line will be installed on the insulated donductor; the diverter will be removed while o n' - " 2" , ~ . . e lng the 17 1/2 hole to _~6~nto.].~O,.O,,O :__.T.,h_e_s~m~ d~v.e.r.ter sj/_st_em_.w, ll] be used on the 18-~/8" conductor A 13-5/8". ..,u,.,u ~, ,r annu, ar uUY ana three 13 5 " ' " - ' · _ .1~ .......... - /8 , lO,O00 ps~ WP ram ty e reventers will be ~ns~ammeo on Erie IJ-J/~" casin ' .P P ,_:,,.. .... . ......... 9 a. nd.w.~]l.be used and a lO,O00 ps~ WP choke manifold during u,-,,,,,~ mno we~m Jesting. uuP ~ns[a))a[ion and testing will be in accordance with Exxon standards, which require pressure testing on initial installation, when any component is changed, and at least once weekly thereafter; all BOP's will be function tested .each trip. Dri)ling.cr~.w. prof.iciency tests of well shut-in procedures will be conducted at least once each week wl~n eacn crew (~ s~ f'or S~te o~.::~ .~, ¢OND;TIONS OF dkPPP. O%'AJ.. IF' AN"Y: ii ~~ ~ ~ ~~ ~a~ 03/11/80 COMPANY, U.S.A. POUCH 6601 · ANCHORAGE, ALASKA 99502 EXPLORATION DEPARTMENT ALASKA/PACIFIC DIVISION February 5, 1980 Exxon Alaska State "C" Well No. 1 Point Thomson Area Section 14, T9N, R23E, U.M. ADL 28382 Arctic Slope, Alaska Mr. Tom C. Cook, Director Division of Minerals and Energy Manag~t State of Alaska Department of Natural Resources 703 W.. Northern Lights Blvd. Anchorage, Alaska 99503 Dear Mr. Cook: Exxon Corporation filed today an application with the Alaska Oil and Gas Conservation Commission for a permit to drill and the contingency plan for the subject well together with our check in the amount of $100.00 in payment of the required permit fee. It will be drilled within lease, ADL 28382. Additionally, and in accordance with the requirements of the subject oil and gas lease and applicable regulations, we submit the following: (1) A plan of operations describing the drilling pad, rig supply, water supply, waste and sewage disposal and pollution prevention. (2) Plat showing the location and vicinity of the pad and well, scale 1" - 1 mile. Exhibit A - Location and area topography plat showing pad layout, scale 1" - 2,000' and pad detail, scale 1" - 100'. Exhibit B - Ice Road and RolligonHaul Route, scale 1:250,000. As stated, it is our plan, State and Federal approval permitting, to conmence initial operations in April by the construction of the drilling pad. As dates of rig movement and commencement of actual drilling operations, are contingent upon matters presently undetermined such dates will be provided in a later filing as they become available. Sincerely, Robert K Riddle ~-~ OCR:RKR:et enclosures c: EPA Region X - Mr. Danford G. Bodien, P.E. Alaska Oil & Gas Conservation Commission- Mr. Hoyle H. Hamilton U.S. Corps of Engineers - Colonel Lee R. Nunn A DIVISION OF EXXON CORPORATION PLAN OF OPERATIONS EXXON ALASKA STATE "C" WELL NO 1 Location: 660' SNL and 660' EWL Section 14, T9N, R23E UPM, North Slope, Alaska References: Exhibit A Proposed drill site layout, topography around location, location of water supply. Exhibit B: Proposed winter access routes from Prudhoe Bay to drill site. Natural Environment The proposed drilling location shown on Exhibit A lies approximately 2.2 miles southeast of Point Thomson Unit Exxon No. 3 and is situated 2.0 miles inland from the Beaufort Sea coastline. The surrounding terrain is a typical low lying coastal plain with scattered small lakes. Surface vegetation is typical tundra with mosses, lichens, grasses, and sedges being most dominant. Elevation of the proposed drill site is approximately 25 feet above sea level. The proposed well is in the continuous permafrost zone of Northern Alaska where the depth of permafrost is approximately 1,600 feet and the active surface layer or thaw zone is from one to three feet. Since the ground cover acts as insulation limiting the depth of the active layer, removal or damage to the ground cover, particularly in areas of any appreciable slope, is a major factor in causing erosion. Consequently, every possible effort will be made to protect the surface from unnecessary damage. There are no established roads, airstrips, housing, or other facilities in the area and, because of the nature of the terrain, heavy vehicular traffic can operate only during the winter season while the ground, streams, and lakes are frozen. Prudhoe- Deadhorse, located approximately 50 miles west of the location, is the nearest staging area and airstrip with facilities for handling cargo and housing personnel. Arctic climatic conditions include relatively cold temperatures year round. Strong winds, small annual precipitation, and visibility strongly influenced by the combination of winds and coastal sea ice condition are factors cOntributing 'to an extremely harsh environment. Page 2 Temperatures vary from a high in the 40 to 60°F range in the summer to a low of -50 to -60°F in the winter which, with the chill factor may reach -100°F or lower depending on the severity of winds. Surface winds are predominantly from the east at an average velocity of 12 miles per hour along the coast with a velocity range of 35 to 50 mph associated with winter storms. Total annual precipitation is in the range of 4 to 6 inches which includes 12 to 48 inches of snowfall. Various species of wildlife exist in the area. During the winter months, when the major part of activities are planned, wolves, wolverines, foxes, polar bears, and caribou may be present. Bird life is limited primarily to the raven and ptarmigan, with waterfowl and most other birds having migrated from the area for the winter. Constructi?n an_d Operating Plan Loffland Rig No. 162 and a 78 man Exxon owned camp will be used in drilling Alaska State "C", No. 1. This rig and camp will be moved from the Point Thomson No. 4 drill site which is approximately 9 miles northwest of the proposed location. Contingent upon regulatory approval, construction of~the drill site will be commenced as soon as possible following completion of the construction of the drill site for Exxon Point Thomson No. 4 so that construction of both drill sites will be complete prior to breakup in the spring of 1980. Tentative access routes are depicted on Exhibit B. The proposed sequence for preparation of the subject drill site is as follows:* lm Construct an overland temporary ice road, connecting with Ocean Ice Road, extending from Point Thomson Unit No. 3 to Alaska State "C" No. 1 as shown on Exhibit A. e · Move in and activate mobile construction camp. Move in equipment and construCt drilling pad, Alaska State "C" No. 1. · Upon completion of drilling pad, demobilize construction camp and equipment. · After freeze-up in fall of 1980 construct ice road from Point. Thomson Unit No. 4 to Alaska State "C" No. 1. · · Move in drilling rig and Exxon camp from Point Thomson No. 4. Repair haul roads as necessary using maintainer and water trucks. * Present shortage of rigs on the North Slope requires that Loffland Rig No. 162 be used in drilling Alaska State "C" No. 1 directly following completion of Point Thomson Unit No. 4. Should another rig become available in sufficient time to permit its movement to the location prior to spring breakup 1980, it will be substituted for the Loffland rig and the plan of operation will be revised accordingly. Page 3 ~,~.. The drill site layout for Alaska State "C" No. 1 will be approximately 720' x 570' as shown on Exhibit A. In constructing this site, a two inch thick preformed layer of polystyrene insulation will be placed on the tundra for thermal protection. A gravel pad, having a minimum thickness of 16 inches, will be constructed over the polystyrene. The gravel for this pad, totaling approximately 11,000 c~bic yards, will be salvaged from the pad at Point Thomson No. 3. Rubber-tired loaders and belly dump trucks will be used for the loading, hauling, and placement of this gravel at the new location. The planned drilling location will accommodate the rig and equipment, camp, and support facilities. The pad has been designed to act as an insulation barrier-to prevent thawing of the permafrost. Wooden piling and matting will be used under the drilling rig and mud pumps for stability and as a further aid in preventing permafrost degradation. Berms will be constructed around all pits. A 190' x 190' x 10' deep reserve pit will be used to retain cuttings, excess drilling fluid, and drainage around the rig. The level in this pit will be kept low to prevent migration of fluids and provide capacity in case of an emergency such as a severe well control problem. A 60' x 60' x 6' deep burning pit will be located a safe distance from the rig to permit routine burning of test gases and the emergency burning of test liquids and combustible waste materials. Welded steel tanks, located in a 60' x 130' x 6' deep plastic lined pit, will provide 425,000 gallons of fuel storage capacity. All tundra and topsoil excavated from the pits will be used as berms around these pits. This will expedite site rehabilitation. The proposed well will be desighed for annular injection Which will permit subsurface disposal of wash and melt water, sewage effluent, waste lube oil, excess drilling fluids, and well test liquids. An ice landing strip, approximately 2000 feet long, will be constructed with snow and water to facilitate air transportation during winter operations. Helicopters will be the primary mode of transportation during summer operations. The drilling and evaluation operations for this Well will require six to seven months. After completion of the well, the rig may be left on location until the following winter. - Major supplies of mud, cement, casing, and miscellaneous drilling supplies will be transported to the location and stockpiled before spring breakup so as to permit operations to continue through the summer. Sufficient fuel will be stored on site to permit operations to continue into spring breakup. .Additional fuel required for summer operations will be handled by Rolligon . ~.. Page 4 '~ '~- - or Barge. If bulky equipment must be delivered on short notice or large shipments can be accumulated, an ocean ice landing strip off the coast for Hercules aircraft may be constructed. After breakup, personnel and light consumables will be transported by helicopters or other State approved means. All support equipment not required for summer operations will be moved out before breakup. Drill Site Facilities The following described facilities will be provided to support camp and rig operations: le Sewage Disposal A Steel Fabricators, Inc. biological sewage disposal unit, owned by Exxon, which complies with the require- ments of the State of Alaska and the EPA for water quality in the area of operation will be installed for the treatment of sanitary sewage. Treated effluent from this unit and gray water, which is discharged from kitchen and shower areas, will be combined in a steel storage tank and used for drilling mud or rig wash water. A 25' x 60' x 6' deep earthen holding pit will be provided for the temporary storage of sanitary sewage in case of an upset of the treating unit. 2. Water SupplY . Potable water for the camp facilities will be hauled from state approved small lakeS near the rig and a large, eight-foot deep lake in Sections 22 and 23, T9N, R23E, UPM, approximately 1.5 miles southwest of the location. A snow melter will be used to supplement the water requirements until shallow lakes closer to the rig thaw in the summer. The water will be processed through a Steel Fabricators, Inc. water treating unit before use in the camp. Additionally, treated sewage effluent and gray water from the camp will be used for mud and rig wash water. . Garbage and Waste Disposal Burnable garbage and wastes will be disposed of in a McNaulin-Goder Model-1510 trash incinerator unit. Some of the more readily combustible products, such as paper, wood, and cardboard, may also be open burned. Noncombustible wastes, such as scrap metal, tires, batteries, and drums, will be hauled to Deadhorse and final disposal will be in accordance with State Waste Management requirements. · Page 5 Development Plans If oil is discovered in sufficient quantities to warrant future development, the Prudhoe Bay to Valdez oil pipeline will be the probable marketing outlet from the area. Oil and casinghead gas would be processed through central oil gathering facilities with oil being pipelined to the Trans-Alaska line passing approximately 50 miles to the west. If commercial quantities of gas are discovered, development of a gas market outlet will be related to studies to market gas from the Prudhoe area. Surface Protection and Restoration Plan As previously mentioned, precautions will be taken to protect the surface by not beginning operations until after freeze-up and by using snow and ice roads during winter. At the completion of the well, the location and adjoining area will be cleared of all waste materials. All pits will be back- filled and leveled. Special procedures for drilling and subsurface equipment are requlrea by the unique characteristics of the permafrost area. Casing cement used through the permafrost zones is of special composition to reduce possibility of freezing and other casing problems. Casing is run and cemented through the permafrost, and .in the event of production or interruption of operation, the uncemented casing must be protected by the use of non-freezing fluid. RDH:ljm 1-17-80 AS-STAKED /-ALASKA STATE C-I "" o ' " '*:"':" ~ Lot. 70 08 23.60 .- .,~'~/ L°ng' '46° '4'29'89" -::~'?~" - ,-,.. X = 469 932 ~ ""'" i~~~_~_~-'0'~)'~'"'~':' [6 'Ground E lev et ion. _ 25 ~-/.~.~j~ ~ 22~ 23 .. ! 27 26 I ! i 20 ' ,.~... ~. , :;..2 . "~ _ j~. ?- ~. AS- STAKE9 WELL LOCATION .. 'ALASKA STATE C-I LOCATE9 IN SECTION 141T9 N,~3E.~U.~. SURVEYED FOR . EXXON COMPANY U.S.A. 25 ,, · ,;,-. ~. ,,.- . ,.?~".: ~t~ I ~ . . , ~- :~'. CERTIFICATE OF SURVEYOR I hereby cerfif7 fhof Iota properly registered ond licensed fo procfice I~nd surveying in the Stole of Alosko ond f~f this 'pl~f represents o Iocofion survey mode by me or under my direct supervision ond fhof ull defoils ore correct. , = I Mile 30 SURVEYED BY BESSE,EPPS & POTTS . ' ANCHORAGE~ ALASKA 344 ' 1352 .......... :-::1 --:':":'::' DATE . I /7_/80 ,Argo I Dinkum Sands Narwhal i':" ,~:-v '.C_,ull I Jeanette Ij-' "V~z~O,~ · . Niakuk 15 ' ~ea'd '* C [ . ..:.f~:...., :~:.~??~.. ,....~.?:,.. . , X, · ~'.1~ C' "5 ~ · . .;.~ .:::~::.;. ' ~ Anxiety ~ . : ,~ ~ .... Pole ... ~:: :: .. .~ ..... ~ .... ~ · . ~ -- ~ ......... ~ ......... , ',~ .~:[:,: .,~: ?:~:.??' }'.~;l'. *.. ~ St~kton Islands : V'.,' :P?? APP,OX. rcE ,O D . · ? ....... ':~; - . ': ':;' . .F~:'=~[[~;~~[{' , 'logy ~- ._ '. ~ .::::~.:.~':'/ .... " . ' ' :;,~:' "'"" 2~:~:' ,% ~ ' · ..~, . ~ ......:.. ::. / · · ~:::... ,:~:....., ....... · ~ ,/ _ ~ ~ ~'~? · ' I ~ ~'-' .:,:.., ;:]?:~L;.. :~g'.T:/ ~ o_ I~-- Lion Pt ....... ~ ::: ' ..... , ~ ....... ~ .... ' EXXON No. ~ ~ . ~. · ' -, ~ / . : .':: .. =. · = ~e lance Ft ':' ' Wd~ *.~'~ ' .r'=. ' * .. '*.. '. ... ~_ PT. THOMSON .. '.-' [-. **[~lal .4' ,- "":': ...... x ~o} ,: ~ ] ,' : ..::: .. '~=~;~_ m~ R Gordon ~bin S~eney ,.~:'': , - .~ '~., ~*.... ... . ~ . ,~ ~ . ,' . .~-', ~ :..:"" '-:.."', '**....',~ eu,enR .~gen ..................... ~I'~,='~ ............... ~T;'~ ~' ~' ..... ~ ...... 'L ~ - N T -~[~ ~'elaxman .... ~ ....... PT-THOMSON U ~ , , _ ....... .. .. ,, ~ ,.. , i '. '-~ ~ · _. - ................ : r- ~-------- ' ". ' ' -- ':' ,." ~ --~ .... ' ' =' '" ~ ' ; ~' ' ' - ' ' " .... .& :~.~. ' , , · -~ ~-~.~ , ~?~.: , ~.~...: *-,,';, ... . ..:::... ~o., .::: ,,, ¢:~', ~ APPFOX.. ROLLIGON' .~' ' ............. ' ' .... : ' :' -': .?".~ HAUL. ROAD ..~.:r- .., ~'0_ ' :lveder~ ~O~ Island ~' ~ Alaska I Duchess I ~r Challenge I North Star I Maguire Islan(~s ROAD 8~ EXXON COMPANY U.S.A. ROUTI __ WELLBORE SKETCH EXXON ALASKA STATE-C, WELL CEMENT TO SURFACE 36" x 32" X 28" INSULATED CONDUCTOR 0 85' CEMENT TO SURFACE 18-5/8" CONDUCTOR @ 1000' CEMENT TO SURFACE 13-3/8" SURFACE CASING @ 3500' WASTE FLUIDS AND HYDROCARBONS INJECTION INTERVAL TOC @ APPROXIMATELY 7000' TOC @ APPROXIMATELY 10,000' 9-5/8" PROTECTIVE ~ASING'@ + 10,500' 7" PROTECTIVE CASING @ TD CONTINGENCY PLAN ALASKA STATE "C" NO. 1 ...... ~ The objective of this plan is to list major operating and ~o~ingency requirements to ensure a safe and~efficient operation throughout the drilling activity. The location has been designed to provide containment of' any drilling operation effluents that could be considered as pollutants. The 190' x 190' x 10' deep reserve pit will receive and contain all drill cuttings, excess mud material, wash and drain water from around the rig, and have the capacity for use in the event of a severe well control problem. Sewage and kitchen waste water will be processed through a Steel Fabricators, Inc. biological treating system with excess sludge being incinerated and the disinfected liquid contained in a steel holding tank. A separate .sanitary holding pit is provided to store the treating plant effluent in the event of a system malfunction. A burning pit is located clear of the rig to permit emergency burning of any produced hydrocarbons resulting from well testing or an upset. All fuel will be stored in steel tanks; primary fuel tanks will be located in a plastic membrane lined fuel storage area. A primary feature of the drilling plan is to provide 9-5/8" x 13-3/8" annular injection capability. The well casing program is designed to set 13-3/8" surface casing through the major gravel sections and below any possible fresh water zones. The 9-5/~" protective casing will be set into the anticipated pressure transition zone and cemented to isolate the saltwater sand sections from below the surface casing shoe to approximately 7000 feet for injection of lube oil, excess mud, melt water, waste' waters, and well test liquids. Liquid levels in the sanitary holding pit and burning pit will be maintained below ground level after breakup to prevent migration of any liquid out of the pit while the reserve pit will be maintained at a minimum level at all times to provide for. containment of well fluids in the event of an upset. All pits will be pumped out to a minimum level and waste water injected into the injection zone before abandoning the location. The entire operation is planned so that no fluids associated with the operation will be discharged on the surface outside the location. The drilling contractor will be required to develop a comprehensive SPCC Plan to prevent pollution as a result of any drilling rig operations. Drip pans will be installed under the engines and ' rig machinery. All oils, greases, and chemicals are to be stored within the protected areas. Good housekeeping will be stressed on all parts of the location with emphasis on minimizing contamination of the peripheral drainage from the pad. Any minor spill of oil will be collected using sorbent material for disposal in the incinerator. Page 2 Personnel safety and well control are the uppermost factors in well design and operational planning. Sufficient data are available to plan the well for evaluation of the geologic objectives, provide for subsurface disposal of waste water, and conduct a safe drilling operation. Advanced abnormal pressure technology will be used to predict and detect changes in formation pressure to permit adjusting the casing and drilling fluid program to control the well. Emphasis will be placed-on well control equipment and procedures to permit circulating out a formation "kick" in an orderly manner if it should be necessary; any hydrocarbons in the influx will be diverted to the burning pit and burned. In the event of an unplanned upset resulting in uncontrolled well flow, the following basic procedures will be followed: 1. Divert flow to burning pit as the first defense against a spill. Switch the flow to the reserve pit when the safe working level is approached in the burning pit.. The design capacity of the reserve pit is 64,000 barrels which will be maintained at a maximum, practical working capacity at all times by keeping mud and fluids use at a minimum and pumping fluids into the injection annulus when possible. 2. Prepare plans for drilling a relief well from an alternate location. 3. The well fluids will be ignited at the wellhead, if the situation warrants, only after discussion with proper governmental agencies and Exxon management. Major supplies of mud, cement, casing, fuel, and miscellaneous supplies will be transported over winter roads or flown directly to location. After breakup, light consumables will be transported by helicopters. A Rolligon will be on location for any local movement of water or fuel as permitted by land conditions. A Catastrophe Organization consisting of specifically designated personnel will be activated to cope with an emergency such as an out-of-control drilling well. The Drilling Section of the Catastrophe Organization is responsible for performing the well control function which includes all surface well control procedures as well as plans for a relief well. Immediate action will be taken to minimize environmental damage and institute cleanup operations. The basic relief well plan involves construction of another surface location approximately 2,000 feet upwind (east) of the original well's surface location. The most likely time for a severe well control problem to develop would be late March, which would Page 3 allow sufficient time to construct the location and spud the relief well before breakup. The planned relief well location would permit the relief wellbore to penetrate the flowing zone near the out-of- control well with a 2,000 foot horizontal displacement. In the event insufficient time is available to initiate the relief well, a barge rig operation could be mobilized after breakup to drill a relief well. Both relief well plans are predicted on emergency approval of all-phases of the operation by all state and'federal regulatory agencies. RDH: ljm 1-24-80 CHECK LIST FOR NEW WELL PERMITS Date Yes No / Lease & Well No. Remarks Item Approve (1) Fee ~/__ (3) Aimin. ~&F_ 1. Is the pemit fee attached .......................................... 2. Is w~ll to be located in a defined pool ... ............. ........... 3. Is a registered survey plat attached ................... i'''"'''"' ........... 4. Is well located proper distance frcm property line ...... 5. Is well located proper distance frcm other wells ................... / 6. Is sufficient undedicated 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 ......................... .~. 10 Does operator have a bond in force., ...... . 11. Is a conservation order needed ...................................... 12. Is administrative approval needed ................................... 13. Is conductor string provided ........................................ 14. Is enough cement used to circulate on conductor and surface ......... ~ (4) Casg. A~/P~ 15. Will c~ment tie in surface and intermediate or production strings ... ~ '16· Will cement cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... ~ (5)B OPE ~ 18. Will all casing give adequate safety in collapse, tension and burst.. · 5Z I/ · 19 Does BOPE have sufficient pressure rating - Test to~ ~/~ -,~,~opsig . ,A~proval Reccnm~nded: Additional Requirements: Geology: HWK /~ Engineering: rev: 03/05/80 CHECK LIST FOR NEW V~LL PERi,ITS Oompany Yes N© 1. Is. the permit fee attached .......................................... / 2. Is well to he located in a defined pool ............................. 3. Is a registered survey plat attached ................................ 4. Is ~ell located proper distance frc~ property line 5. Is well located proper distance frcm other wells .................... Is sufficient undedicated acreage available in this pool ............ e L0. L1. well to be deviated .............................................. .:s operator the only affected party ................................. Can permit be approved before ten-day wait .......................... / Does operator have a bond in force .................................. ~_~ Is a conservation order needed ...................................... L2. Is administrative approval needed ................................... [3. Is conductor string provided ........................................ ~ .Lease & Wel 1 /~o. Item (1) Fee [4. Is enough cement used to circulate on conductor and surface ......... ~ LS~ Will cement tie in surface and intermediate or prcduction strings ... ~ £11 cement cover all known productive horizons ..................... d~ Approve Date ,,, (2) T_~:x=. (~...~ 5-?' ~) / (4) Casg. L7. Will surface casing protect fresh water zones ....................... ~ LB. Will all casing give adequate safety in collapse, tension and burst.. L9. Does BOPE have sufficient pressure rating - Test to ~,~o .. ~ psig .. Approval Reccmmended: %dditional Requirements: rev: 12/12/79 Well Histo[y 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 APPE .NDIXi .. No special'effort has been made to chronologically organize this category of information. .o Company Well LIBRARY TAPE CURVE SPECIFICATIONS Exxon Company U.S.A. Alaska State C-1 Field Wildcat County,State North Slope, Alaska Date Sept. 14,1981 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale SP Spontaneo.us Potential. DI,FL various GRI Gamma Ray .DIFL 0-150 RXO, Shallow Focus DIFL .2-2000 RILM Medium Induction DIF, L .2-2000 ,,,RT Deep Induction ,, , DIFL .2-2000 ..... COND Conduct ivi ty DI FL 4000 - 0 GR Gamma Ray CN/CDL 0-150 CAL Caliper CN/CDL ' 10- 20 ,, DEN Bulk Density CN/'CDL 2- 3 CORR Correction CN/CDL .-. 25-. 25 · CN Comp. Neutron CN/CDL' 60-0 DENP Density Porosity CN/CDL 60-0 ,, GPA Gamma Ray BHC/AC . 0- 150 AC Acous tic BHC/AC 150 - 50 .... i~uchora~Je ., ( PAGE I EXXON COMPANY JSA .... ALASKA $.ATE C-1 ,ILDCAT .... NORTH SL'OPE, AL'~SKA ( SP SRI RXO RILH RT COND GR 75,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 CAL:: 0,00 DIN CORR DENP" 0.00 0~00~ 0200" 75.50 76,00 0,00 0,00 7~.5o o.oo o.oo 7~,~0 O, Oo 0.oo 77-50 0,00 0.00 78.00 0,00 0.00 78.50 0.00 0.00 o.oo o.oo o..o.0 0,o0 o.?.o0 0~.0_0 o.oo ....................... o.oo o.oo 0.~00- o~00:, o, oo o.oo o.oo o.oo o.oo o.oo . o...0o o.oo o,0o 0.0.0 ....... 0,00 0.00 0,00 0.00 0,00 0,00 0.00 o'00' o.0o 026'6 0.00 0o00 0,00 0.00 0,00 0,00 0.00 0.00 0.00 0o00 0o00 0o00 0.00 0,00 0.00 0,00 0.00 0.00 79200 ....... O"O'O' 0.00 0,00 0.00 O,-'d'O ...... 0200' 0.00 0.00 ?"~ 2-~0 ........ O-;-O'd ...... 0. o o o; o o' ' o,'o 0 0" 0'0 0; O0 ' o "OO o. ~o o BO,O0 0,00 0.00 0.00 0,00 0,00 0o00 0.00 0o00 80'50 0.00 0.00 0.00 0.00 0,00 0o00 0.00 0.00 81.00 0,00 0.00 0.00 0,00 0,00 0,00 0'00 0,00 81.5o o.oo o.oo o.oo o.oo o.oo o.oo o.00 o.~Oo 82.'0-0 0.00 0.'00 ' 0,'00 0.00 0.0'0 0'00 0.00 0.00 8~'2'5'0 0",0'0 0,0o :B-~O0':::'"":"~';O'O' o.00 8~50 0;~00 0,00 8~. ~0 O. 0.00 6'~-;'0'~ .......... 0'.'00 0200 o.o0 0'0o 020o 0"0o' o.o0 o.oo OOO0.: o.o'o o.oo o,oo o..oo :o o.'o'o o-oo 1oo o:oo o-oo o.oo U 0.00 0,00 0'.00 ' '.0.00 0.0.0 0,00 o.oo ,~ 0,0o 0.00 o.oo o.'0o o.0o o,00 0.00 0200~ 0.00 0,00 0,0.0 0-,00 0o00 0,00 0.00 0~0.0-' CN GRA AC 0~o 00: 18,5~ 18.05 57,22' 1~. 78 57. 58 0.00 0.00 18,06 57,63: 0",'00 o, 6o 1'~', 8~. - 57.7~~ 0.00 0,00 18.~7" 58~' 0'o00 0o00 18.#5 0.~00 0.00' 18,20 79.20 0.00 0.00 17.92 90.07' 0.00 0.00 0.00 0;00 ~7'27' 0.00 0.00 0'~00 0.00 16.6~ 129.29' 0.00 0,00 0,'00 0.00 16.67 129.51 0,00 0~00' 0':00 0.00 16.69 129,05: 0.00 0,00 0'.00 0.00 17,20 0.00 0,0'0 0',00 0,00 17.3~ 155o26 0.00 '0,0:0 O.~O0 0,00 17,57 155~20 o. oo'. o; o-o-' o:.,~ oo o. 00' 17'~9 0~. 0'0:;. O~ 00":, 0~.00 O. O0 17"'78,:~ 161- ~9'~' 0.:, O0 0,00'. 0'~, 00~ 0.00 17,59:: 0.00 0o00 0::, O0 0,00 17,99 155, 93.: 0.00 ' 0:~0-0 0,00 0,'00 ' 17'5'i 0.00 0.0:0 0.00 0.00 18.~A 159.11 ...... 13'~-', 5:0 ............. 0-; 0'0 0 ."00 0 . 00 '0, '00 0 . 00 0',-0'0 0 . 0'0-' 0"o'0 O:OO .... ' "O;dO'" O~";O':O o.oo 0'00 '~:.0.0o 0.oo 8~::2'50 ....... :'":'0 ; 'O"'Oi:i :" '" '".' ..... 0'":0'0:: ....... :0 ,'0'0': ...... 02 O0 '"' 0'200'"":" .... ':"'0~,00':' :':"~': '0',' 0'0' ".?":'"": 0" 0'0: : .:0-:00:; 0. O0 0 00 : 0 ,.00 0 ...0. 0 0.0.:0 0 '. 00 0.00 8~-';-0-0 ....................... 0'-,' 0'0 ......... 0'. '0'0 0 .'00 0 . 0 O- 0 .-0'0 0 . 00 0.00 0 . 0 O' 0 ° 00 .... 8'~.-5-0 .............. O";"O'O ........ O-;--O-O 0 . 00 '0', '0'0 ......... O',"d 0 ......... 0-'200 ......0','-0-0 ........ 0 . 0 0 0 .'00 . : :..:~':i;;o~o;i?!~: .;. ..:i : 0::;-:070:.:- o'0o 0:':o0 .o..o.0:. :0:.;~:0' 0:;::00 0:,'0:;0 ;:0...:0.,.0 o. oo 0.00 0~0:0 0,00 18-1~: :0.00 0'~;~0'~0:':'0;'00 '17o'28".' 0,00 0:-00 0,00 17'19 .- 0.00,'. 0'~0'0 0,00 17.66~' 17'0.9#~. o;"0'0~' 0..';"00 0'.00 172'87 '2o'0"57-- o.oo '0,;0'o '0'00 o 7 · ~.:8' 9 1 5,59 3.~81~7 .,'fi3': 1~,29 0.00 0.,,'0 0.00 9'-i25"0 ........ 3~-;-'~7 ......... 1'9r''I ~ ...... 3 219' '5A63 . A-8' S~'~--?':2-'i~ i S''~ 'r 3~" 0 . O0 '0 ' ~'0' 0 . O0 92*:50. ::i.:0':;;,0'0 0,0:0 . 0:; 0'0 0'0:0 : :.i.iO, 0'0 0:'00 O' O0 0.00 O, O0 0..'00' 0';:00: 0'.00' 1:8~.~,2:I9:1 0 · 00 '0 ~, 00 ~ '0 ';, 00. 0 :. 0 ' o.oo~ o;oO o;Oo 1 0. O0 0 '00 ' Oo 00' 17,'78.~' o.0o 0"~, oo 0'o0- 17.2~: o,0o:, 0-,00':'::' 0°00 :' ~62"~'. 0'~ 0'0 0 ~00:': ' 0:~00 17:"* 3':~~: 0""; 0:0:' 0, '00. 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