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188-098
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Organization (done) ~r~wo-Sided RESCAN DIGITAL DATA ,~' Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES' '?c~ NOTES: ORGANIZED BY; E~EVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other /s/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ Scanned (done) PAGES' SCANNED BY~ (at the time of scanning) _...~.~-----.,~ BEVERLY BREN VINCENT SHERY~WELL RESCANNEDBY; BEVERLY BRE~.,~,HERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: PAG ES: Quality Checked (done) „(t)'\\\I/7; �� THE STATE I t a C:1 C J K fro, J j .d.��.� S t 333 west Seventh Avenuc- ”" GOVERNOR SEN P.ARNELi. Anchorage, Alaska 99501-35/2 - - main: 907.779 1,133 soMAY0 201 sato Dan Marlowe Operations Engineer g Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU D-30RD2 Sundry Number: 314-238 Dear Mr. Marlowe: 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, P7? „(1. - Cathy P oerster Chair DATED this Li— day of April, 2014. Encl. t . RECF D STATE OF ALASKA APF{ 14 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 07-5 4.111 Iq. APPLICATION FOR SUNDRY APPROVALS AOGCC 2QAAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool❑ Repair Well❑ 41.4/1•1`‘Change Approved Program❑ 44 Suspend❑ Plug Perforations❑ Perforate Q! Pull Tubing El Time Extension❑1 Operations Shutdown 0 Re-enter Susp.Well❑ Stimulate 0 Alter Casing❑ Other. ik �-•,. ,� ii; Ii., Operator Name: 4.Current Well Class: . t 5.Permit Drill mber. Hilcorp Alaska,LLC • Exploratory ❑ Development 0 ` 188-098 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6 API Number: Anchorage,AK 99503 50-733-20208-02 . 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No El - Trading Bay Unit/D-30RD2• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594 • McArthur River Field/Middle Kenai G Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,841 ' 8,896 ' 11,830 • 8,889 • 11,404(fill) N/A Casing Length Size MD TVD Burst Collapse Structural Surface 3,043' 13-3/8" 3,043' 2,631' 3,090 psi 1,540 psi Intermediate 10,130' 9-5/8" 10,130' 7,743' 6,870 psi 4,760 psi Liner 10,620' 7" 10,620' 8,091' 8,160 psi 7,020 psi Liner 1,514' 5" 11,535' 8,689' 8,290 psi 7,250 psi Liner 471' 3-1/2" 11,841' 8,896' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.2#/L-80 10,016 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Otis BWD Pkr&Otis Series 10BV SSSV 10,008'(MD)7,652'(TVD)&310'(MD)310'(TVD) • 12.Attachments: Description Summary of Proposal 2- 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/21/2014 Oil 0• Gas El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(cr�,hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature 111 Phone (907)283-1329 Date 4/14/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3v-l.- 1%13 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: RBDMS MAY 0 7 2014 Spacing Exception Required? Yes ❑ No IJ Subsequent Form Required: /6 —1 Oct APPROVED BY Approved by: PCley /` COMMISSIONER THE COMMISSION Date: 4_az-/ I Al Submit and Form 10-403(Revised 10/2012) Ap OPfp'�\plil aio T NI 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: D-030rd2 Hilcorp Alaska,LLC Date: 04/10/14 Well Name: D-30rd2 API Number: 50-733-20208-02-02 Current Status: Shut-in Producer(Gas- Leg: B-1 (SE) Lift) p 60 Estimated Start Date: April 21, 2014 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-098 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: -3,083 psi @ 9,073' TVD 0.34 psi/ft(2011 data on offset well G-26) Maximum Expected BHP: -3,083 psi @ 9,073'TVD 0.34 psi/ft(2011 data on offset well G-26) Max.Allowable Surface Pressure(Perf Job): 1,200 psi gas-lift pressure Brief Well Summary Well D-030rd2 is a shut-in producer in the TBU McArthur River G-zone Oil Pool.When spot tested in 2012 it produced —100 bfpd, 20 bopd on gas-lift. This well is intermittently lifted to"milk" as the platform doesn't currently have enough gas-lift volume to feed all of the wells. Re-perfs are proposed in the G- zone sands to identify if this well should be worked over as a producer or converted to an injector. Slickline Procedure: 1. MIRU Slick-line, PT lubricator to 2,500 psi Hi 250 Low. 2. RIH with slick-line and remove tubing patch at 2,553'-2,561'. 3. RIH with slick-line and clean out to 11,810'. 4. RIH with 2.50"x 20'dummy guns to+/- 11,804'. 5. RD Slick-line. E-line Procedure: 6. MIRU E-line, PT lubricator to 2,500 psi Hi 250 Low. 7. RU e-line guns. a. RIH and perforate G-zone intervals from 11,634'-11,808'. (Proposed perfs shown on the proposed schematic in red font) b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate with Gamma log dated. d. Peforate according to perf schedule. e. Record tubing pressures before and after perforating run. 8. RD E-line. 9. RIH with slick-line and re-install tubing patch at 2,553'-2,561'. 10. RD slick-line 11. Turn well over to production. Well Prognosis Well: D-030rd2 Hileorp Alaska,LLC Date: 04/10/14 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Dolly Varden Platform Well#: D-30RD2 SCHEMATIC Last Completed: 12/30/88 PTD: 188-098 Hik,,ra Ala4ka.1d.0 API: 50-733-20208-02 RKB to Hanger=41' CASING DETAIL o 1. I Size WT Grade Conn ID Top Btm 13-3/8" 61# K-55 Surf 3,043' 9-5/8" 47# N-80 Surf 10,130' 7" 29# N-80Surf 10,620' Tubing Path - 2,533'-2,',6T 5" 18# N-80 10,021' 11,535' 2 3-1/2" 938 N-80 2.992" 11,370' 11,841' TUBING DETAIL AB Mod Butt 3-1/2" 9.2# N-80 Tbg Surf 10,016' 1s a 3 JEWELRY No Depth ID Item 41' GIW"DCB"Tbg Hanger,4-1/2"8RD,Top(Type"H"BPV Prep)x-over, 4 4-1/2"Butt pin x 3-1/2"Butt pin 1 310' 2.813" SSSV Otis 3-1/2"Series 10 BV 2 2,555' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 16/64"Port 5 Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 3 4,953' 2.86" 16/64"Port 4 6,310' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 16/64"Port 6 Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 5 7,450' 2.86" 16/64"Port 6 8,474' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 7 16/64"Port 7 9 249 2 86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 8 20/64"Port Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches X 1 9 8 9,927' 2.86" 24/64"Port 9 9,978' 2.813" Otis"X"Nipple 10 10,008' Otis Straight Slot Locator w/8ft of seals and Mule Shoe Guide 171110 11 11 10,008' Otis BWD Packer w/8'SBE 12�] 12 10,020' 6'Pup jt. Q 13 13 10,026' Baker PBR Seal Assembly L 14 , 14 10,045' Half Mule Shoe Guide 9-5/8" L ' Note:PBR located on top of 5"liner 10,028'-10,043' 7" 11-08-90 Fill tagged @ 11,786'w/E-Line PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date G-1 11,580' 11,602' 8,719' 8,734' 22 4 TOF ii 404' G-2 11,634' 11,664' 8,756' 8,776' 30 4 A 5„ G-3 11,714' 11,756' 8,810' 8,839' 42 4 - G-1 G-4 11,772' 11,799' 8,849' 8,868' 27 4 G-2 G-4 11,772' 11,804' 8,849' 8,871' 32 4 G-3 -a G-4 3%" ,,,,Ak TD=11,841' PBTD @ 11,830' Updated by.ILL 03/08/13 Dolly Varden Platform H PROPOSED Well#: D-30RD2 Last Completed: 12/30/88 PTD: 188-098 Hil,mrn Alankn.LI C API: 50-733-20208-02 RKB to Hanger=41' CASING DETAIL 0 1 Size WT Grade Conn ID Top Btm 13-3/8" 61# K-55 _ Surf 3,043' 9-5/8" 47# N-80 Surf 10,130' Tubing Pa _7" 29# N-80 Surf 10,620' 2.533'-2,6t 5" 18# N-80 10,021' 11,535' 2 3-1/2" 9.3# N-80 2.992" 11,370' 11,841' TUBING DETAIL [- -1/2" 9.2# N-80 AB Mobd Butt Surf 10,016' g 13-3/8" 3 JEWELRY No Depth ID Item 41' GIW"DCB"Tbg Hanger,4-1/2"8RD,Top(Type"H"BPV Prep)x-over, 4 4-1/2"Butt pin x 3-1/2"Butt pin 1 310' 2.813" SSSV Otis 3-1/2"Series 10 BV 2 2,555' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 16/64"Port 5 Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 3 4,953' 2.86' 16/64"Port 4 6,310' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 6 16/64"Port 5 7,450' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 16/64"Port 6 8,474' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 716/64"Port 7 9,249' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 8 20/64"Port _ X 9 8 9,927' 2.86" Camco 3-1/2"Type KBUG GLM w/BST GLV 10-R valves&BK latches 24/64"Port 9 9,978' 2.813" Otis"X"Nipple 10 10 10,008' Otis Straight Slot Locator w/8ft of seals and Mule Shoe Guide 11 11 10,008' Otis BWD Packer w/8'SBE 12 12 10,020' 6'Pup jt. 13 13 10,026' Baker PBR Seal Assembly L 14 14 10,045' Half Mule Shoe Guide 9-5/8" . . , .. Note:PBR located on top of 5"liner 10,028'-10,043' 7" 11-08-90 Fill tagged @ 11,786'w/E-Line PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date G-1 11,580' 11,602' 8,719' 8,734' 22 4 Tor 11,404' G-2 ±11,634' ±11,664' ±8,756' ±8,776' 30 4 Future s' G-1 G-3 ±11,714' ±11,756' ±8,810' ±8,839' 42 4 Future G-4 ±11,772' ±11,804' ±8,849' ±8,871' 32 4 Future si G-2 G-3 G-4 3'A" TD=11,841' PBTD @ 11,830' Updated by.ILL 04/10/14 • • STATE OF ALASKA 0 'iii? i ; 20 13 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well El Plug Perforations Cl Perforate ❑ Other el Install Patch 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: Hilcorp Alaska, LLC Development CI Exploratory El 188 -098 A 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20208 -02 •■ CU 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 u' Trading Bay Unit / D -30RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Z° McArthur River Field / Middle Kenai G Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,841 feet Plugs measured 11,404 (fill) feet true vertical 8,896 feet Junk measured N/A feet Effective Depth measured 11,830 feet Packer measured 10,008 feet true vertical 8,889 feet true vertical 7,652 feet Casing Length Size MD TVD Burst Collapse Structural •-- -�-�^ Surface 3,043' 13 -3/8" 3,043' 2,631' 3,090 psi 1,540 psi Intermediate 10,130' 9 -5/8" 10,130' 7,743' 6,870 psi 4,760 psi Liner 10,620' 7" 10,620' 8,091' 8,160 psi 7,020 psi Liner 1,514' 5" 11,535' 8,689' 8,290 psi 7,250 psi Liner 471' 3 -1/2" 11,841' 8,896' Perforation depth Measured depth 11,580' - 11,804' feet SCANNED APR 19 2013 True Vertical depth 8,719' - 8,871' feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# N -80 10,016' (MD) 7,658' (TVD) 10,008' (MD) 310' (MD) Packers and SSSV (type, measured and true vertical depth) Otis BIND Packer 7,652' (TVD) Otis Series 10 BV 310' (TVD) SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,350 1,320 Subsequent to operation: 0 0 0 1,320 1,300 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development G ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil p GED WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUEJ 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: Contact Ted Kramer Email tkramer t�hilcorp.co m Printed Name Ted Kramer Title Sr. Operations Engineer J Signature � 4✓ � ' _ Phone 907 777 -8420 Date 3/13/2013 I$ D ' MS MAR 14 2013 c'�2, i t ii . /3 Form 10-404 Revised 10/2012 �! -` Submit Original Only • Hilcorp Alaska, LLC iiilcoip thi ka•LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D -30RD2 50- 733 - 20208 -02 188 -098 2/13/2013 2/18/2013 Daily Operations; 02/13/13 - Wednesday Rig up. Pressure test lubricator to 2,500 psi, good test. RIH w/ 2 -1/2" DD bailer from 11,072' to 11,087'. POOH w/ 1/2 full sand. RIH w/ 2 -1/2" DD bailer from 11,087' to 11,102'. POOH w/ 1/2 full sand. L/D lubricator. 02/14/13 - Thursday Rig up equipment. RIH 5 times w/ 2 -1/2" DD bailer from 11,134' to 11,240'. POOH each time w/ 1/2 full sand. L/D lubricator. 02/15/13 - Friday Rig up equipment. RIH 8 times w/ 2 -1/2" DD bailer from 11,242' to 11,404'. POOH each time w/ 1/2 full sand. Rig down. 02/16/13 - Saturday Rig up equipment. RIH 7 times w/ 2 -1/2" DD bailer from 11,270' to 11,340'. POOH each time w/ 1/2 full scale. Rig down. 02/17/13 - Sunday Rig up equipment. RIH w/ 3" Daniel's KOT to 2,555' KB tag mandrel to get right depth to set patch. POOH. Rig down. 02/18/13 - Monday Rig up equipment. RIH w/ 3" GS setting 3" AD -2 Stop @ 2,561'. POOH. RIH w/ 3" GS setting 3" B -Pack off @ 2,549'. POOH. RIH w/ 3" GS setting 3" T -Pack off at 2,536'. POOH. RIH w/ 3" GS setting 3" AA -Stop @ 2,533'. POOH. L/D and secure well. Standby to test patch. 02/19/13 - Tuesday Dolly Varden Platform �t • • Well #: D -30RD2 9 • SCHEMATIC Last Completed: 12 3I 88 PTD: -7 00 J i 1 - © � Nikon, Alaska. IAA: API: 50- 733 - 20208 -02 RKB to Hanger = 41' CASING DETAIL o (- 1 Size WT Grade Conn ID Top Btm 13 -3/8" 61# K -55 Surf 3,043' 9 -5/8" 47# N -80 Surf 10,130' 7" 29# N -80 Surf 10,620' 5" 18# N -80 10,021' 11,535' 2 3 -1/2" 9.3# N -80 2.992" 11,370' 11,841' 1 TUBING DETAIL flo - -- 3 -1/2" 9.2# N -80 AB M bg Butt Surf 10,008' 13 /' MD 3 JEWELRY No Depth ID Item 41' GIW "DCB" Tbg Hanger, 4 -1/2" 8RD, Top (Type "H" BPV Prep) x -over, _ 4 4 -1/2" Butt pin x 3 -1/2" Butt pin 1 310' 2.813" SSSV Otis 3 -1/2" Series 10 BV Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches 2,555 2.86" 16/64" Port - t - hQ`T -Gf _ 5 Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches 3 4,953' 2.86" 16/64" Port 4 6,310' 2.86" Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches MO 6 16/64" Port 5 7,450' 2.86" Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches 16/64" Port 6 8,474' 2.86" Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches , 7 16/64" Port 7 9,249' 2.86" Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches MID , 8 20/64" Port X I 9 8 9,927' 2.86" Camco 3 -1/2" Type KBUG GLM w/ BST GLV 10 -R valves & BK latches 24/64" Port 9 9,978' 2.813" Otis "X" Nipple 10 10 10,008' Otis Straight Slot Locator w /8ft of seals and Mule Shoe Guide �11 11 10,008' Otis BWD Packer w /8' SBE 12 10,020' 6' Pup jt. 13 13 10,026' Baker PBR Seal Assembly L , 14 10,045' Half Mule Shoe Guide 9 -5/8" L ' Note: PBR located on top of 5" liner 10,028'- 10,043' 7" 11 -08 -90 Fill tagged @ 11,786' w/ E -Line PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date ' - ' G -1 11,580' 11,602' 8,719' 8,734' 22 4 TOF 11,40.4' G -2 11,634' 11,664' 8,756' 8,776' 30 4 • 7 5 „ G -3 11,714' 11,756' 8,810' 8,839' 42 4 G-1 G -4 11,772' 11,799' 8,849' 8,868' 27 4 G -2 G -4 11,772' 11,804' 8,849' 8,871' 32 4 G -3 G -4 3W TD = 11,841 PBTD @ 11,830' Updated by JLL 03/08/13 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp,~ ~ ~. SUBJECT: Petroleum In~lztector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be Changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON'CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D- 11 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D- 18 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL ~~,; 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110i 110 80 70 P P 9 OIL D-48 1921540 110 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [-] 90 t)av Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jc 1 MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator J 5. Type of Well: UNOCAL (Marathon Oil Co - Sub OperatoF) D~%~oPr~oe?~---X 3. Address [ Stratigraphic_ P.O. Box 190247 AnChorage, AK 99519i Service_~. 4. Location of well at surface Leg B-l, Cond. #12 Dolly Varden Platform 680' FSL, 1,213' FWL, Sec. 6-SN-13W-SM 32-9N-13W-SM 32-9N-13W-SM 32-9N-13W-SM At top ofproductive interval 1,060' FSL, 860' FEL, Sec. Atf~'~§d~P~t, 700' FEL, Sec. At~°,t~l~pthFSL, 670' FEL, Sec. Stimulate __ Plugging __ Perforate _~X Other __ 6. Datum elevation (DF or KB) 106' KB above MSL z Unit or Property name Trading Bay Unit 8. Well number D-3ORD2 Permit number/approval number 90-824/f,- ~ f~.¢ 10. APl number 5O-- 733-20208-01~:Z- 11. ~O/~oP~ feet 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043 ' Surface 10,130' 10,620' Intermediate 1,514' Production 471 ' Liner Perforation depth:measured 11,841 ' feet Plugs (measured) 8,894' feet 11,830 ' feet Junk (measured) 8,886' feet Size Cemented Measured depth true vertical 13 3/8" 1,800 sx 3,043' 9 5/8" 2,500 sx 10,130' 7" 875 sx 10,620' 5" 146 sx 11,535' 3-1/2" 113 sx 11,841' Tubing (size, grade, and measured depth) 3 1/2" 9.2# N-80, AB Mod Butt. Tbg Packers and SSSV (type and measured depth) Ot i S 13. Stimulation or cement squeeze summary True vertical depth 2,631' 7,742' 8,091' 8,689' 8,894' 6-1 11,580' - 11,602' MD; 8,715' -8,730' TVD G-2 11,634' - 11,664' MD; 8,751' -8,771' TVD G-3 11,714' - 11,756' MD; 8,805' -8,833' TVD G-4 11,772' - 11,804' MD; 8,848' -8,869' TVD to 10,016' 3-1/2" SCSSV Series 10 BV (2.813" ID x profile) (a 31, Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/5/90 32 94 26 1040 100 Subsequent to operation 11/24/90 129 133 116 1080 100 15. Attachmen~ #2 116. Status of well classification as: Copies of Logs and Surveys run __ ~ Daily Report of Well Operations X I Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to tl~e best of ~y knowledge. ned ~, (:9,-~, ~. ~ ~::~ Title ~ e_~. ~ Form 10-404 Rev 0 Service Date SUBMIT IN DUPLICATE Attachment #1 TBU Well D-3ORD2 Summary of Daily Operations 11/6/90 RU CTU and equipment, PT CT reel, BOPE and lubricator to 2500 psi. PT pumping unit to CT reel to 4000 psi. RIH w/ CT dressed w/ 2 check valves and injection/wash nozzle. Start lift gas and RIH w/ CT injecting FIW w/3% KCl to 11,700 CTM. Pumped at 1.5 BPM. Continue RIH, wash through bridge at 11,746', tag ha[d fill 0 11,753' Wash through to hard fill @ 11,756'. Washed to 11,758 . Pumped pill a~d washed to 11,759'. Increase injection rate to 1.75 BPM. Wash for 90 min. @ 11,759' with no progress. Inject pill. Inject another pill after 22 bbls FIW. Broke through and tagged hard fill 0 11,767'. Washed for 40 min w/ no further progress. POOH. RIH w/ CT dressed w/ 1.75" drill w/ 2.25" bit, injecting @ 0.5 BPM to 11,600'. Increased rate to 1BPM. Milled down to 11,780' with tight spots 0 11,731' - 11,770'. Pumped 10 bbl pill washing up and down from 11,750' - 11,780'. RIH milling light scale 11,780' - 11,796'. Pump pill PU CT to 11,730' RIH to 11,797'. CT hung up at 11,790'. Pump several pilis and increase injection pressure attempting to unstick CT' 11/7/90 Pump friction reducer and free CT, POOH. SI lift gas. RD CTU, SI well. 11/8/90 RU E-line and PT lubricator to 2500 psi RIH w/ 20' dummy guns (1-11/1~" OD) and tagged fill 0 11,786' WLM. POOH. ~U and RIH w/ 1-11/16", 4 SPF, 0v phasing, hollow carrier perf guns, correlate and reperforate G-4, 11,772' - 11,786'. Flowed well 20 min to clean up. POOH. RIH w/ dummy guns. Unable to pass through obstruction @ 11,532'. PU to 5" liner. Opened well and flowed for one hour to clean up. RIH w/ dummy gun, unable to get past obstruction 0 11,525'. POOH. RU to reperforate the G-3 zone. 11/9/90 RIH w/ 1-11/16", 4 SPF, 0° phasing, hollow carrier perf guns. Correlate and perforate G-3, 11,734' - 11,756' POOH. RIH w/ same guns as before and reperforate G-3, 11,714' - 11,73~'. Flowed well 20 min to clean up. POOH. RIH w/ same guns as before, correlate and perforate G-2b 11,634' - 11,664'. POOH. RIH with 2nd string of guns as before, offser 30 to reperforate the G-2, 11,634' - 11,664'. POOH. Last 10' of guns did not fire. RU to perforate G-1. 11/10/90 RIH w/ 1-11/16", 4 SPF, 0° phasing, hollow carrier guns, correlate and perforate G-l, 11,580' - 11,602'. POOH. RD, place well on production. \ docs\ dvp\ d30 rd. doc STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ ,~timulale __ Change approved program __ Pull tubing __ Variance __ Perforate ~ Other 2. N~lr~pera(t~arathon 0il Co - Sub 0perato~)5' Type of Well: Development X -- J Exploratory ~ 3' A(i~.r~s.s BOX 190247 Anchorage, AK 99519 I StratigraphiC__service__ / 4. Location of well at surface Leg B-]., Cond. #12 Do]l.y Varden Platform 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SH Attop, DJ aroductive interval 1,060' FSL, 860' FEL, Sec. 32-gN-13W-SM 6. Datum elevation (DF or KB) 106' KB above HSL 7. Unit or Property name Trading Bay Unit 8. Well number D-30RD2 9. Permit number 88-98 feet Atle,ff~)~]i(~qd~tt, 700' FEL, Sec. 32-9N-13W-SM Atlt°,t~ll~¢thFSL, 670' FEL, Sec. 32-9N-13W-SM 10. APl number 5o- 733-20208-01 11. F, kelc~Pool b-Lorle 12. Present well condition summary Total depth' measured true vertical 11,841 ' feet Plugs (measured) 8,894' feet Effective depth' measured true vertical Casing Length Structural Conductor 3,043 ' Surface 10,130 ' 10,620' Intermediate 1,514' Production 471 ' Liner Perforation depth:measured true vertical 11,830 ' feet Junk (measured) 8,886' feet Size Cemented Measured depth ~ue ve~ical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' 6-3 11,714' - 11,738' MD; 8,809' 6-4 11,772' - 11,804' MD; 8,848' - 8,825' TVD - 8,869' TVD Tubing (size. grade, and measured depth) 3 1/2" 9.2# N-80, AB Mod Butt. Packers and SSSV (type and measured depth) 0t i S 3 - 1/2" MD; Otis BWD Pkr w/ 8' SBE @ 10~008' MD 13. Attachments 1 & 2 Description summary of proposal ~ Tbg to 10,016' SCSSV Series 10 BV (2.813" ID x profile) @ 31. BOP s ke~~,,~!!~~ Detailed operations program __ 14. Estimated date for commencing operation 15. Status of well classification October 30, 1990 If proposal was verbally approved Oil ~ Gas__ 16. Russ Douolas of AOGCC 10/25/90 Name of apprbver Date approved Service 17. I :ertify that the foregoing is true and correct to the best of my knowledge. Signed Title Date L~,-%_c~o Conditions Notify Commission so representative may witness ! Approval No. Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- 4'<:' fi Approved by order of the Commission ORIGINAL SIGNED BY LONNIE 6. SMITH Form 10-403 Rev 06/15/88 Approved Copy Returned ':fo ~missioner Attachment #1 TBU Well D-3ORD2 CLEANOUT AND REPERFORATING PROCEDURE 1) 2) 3) 4) 5) 6) 7) 8) 9) SI LIFT GAS AND LET WELL DIE. SI CHOKE AND MANUMATIC. RU COILED TUBING UNIT AND PUMPING EQUIPMENT. HOOK UP COMMUNICATION SYSTEM IN CT UNIT. RADIOS AND HEADSETS NEED TO BE AVAILABLE TO MAINTAIN COMMUNICATION BETWEEN THE CT OPERATOR, PUMP UNIT OPERATOR AND PRODUCTION ENGINEER. PRESSURE TEST LUBRICATOR AND BOPE TO 2500 PSI. PRESSURE TEST SURFACE LINES FROM PUMP UNIT TO CT UNIT TO 4000 PSI. LOCK OPEN SCSSV WITH A HAND PUMP AND MONITOR PRESSURE FOR BLEED OFF OR BUILD UP. ENSURE VALVES ARE LINED UP TO CIRCULATE RETURNS TO THE WELL CLEAN TANK. ALSO ENSURE PUMP AND CONTROLS ARE OPERATIONAL FOR PUMPING FROM THE WELL CLEAN TANK TO THE SURGE VESSEL. OPEN SWAB VALVE, CHOKE AND MANUMATIC. ESTABLISH CIRCULATION WITH 3~o KCL WHILE RIH WITH CT AND 2.25" JET NOZZLE. RIH W/ CT TO 11,300'. VERIFY RETURNS ON CT/TBG ANNULUS. OPEN LIFT GAS TO WELL IF NECESSARY TO MAINTAIN CIRCULATION. CIRCULATE 34 KCL AT 1.5-2 BPM. RIH WITH CT TO 11,700'. PUMP 10 BBL HEC-IO PILL ( APPROX. 30#'S/1000 GALS GEL). HEC-IO TO CONTAIN A 5 HOUR BREAKER. ONCE PILL IS CIRCULATED OUT THE CT TAIL, CONTINUE DOWNHOLE CIRCULATING FIW TO 11,800' OR PBTD. PUMP A 2ND HEC-iO PILL. ONCE THE 2ND HEC-IO PILL IS CIRCULATED OUT THE CT TAIL, PUMP A 3RD HEC-iO PILL. CIRCULATE BOTTOMS UP TWICE AFTER 3RD HEC-IO PILL IS AT THE CT TAIL. CONTINUE TO MOVE CT UP AND DOWN WHILE CIRCULATING. CAPACITIES: 1.5" CT=1.597 BBLS/IO00 FT. 1.5" CT X 3.5" CSG=0.00651 BBLS/FT 1.5" CT X 5" CSG:0.01557 BBLS/FT 1.5" CT X 3.5" TBG= 0.00651 BBLS/FT BOTTOMS UP VOLUME=90 BBLS START POOH WITH CT CIRCULATING AT 1/4-1/2 BPM. SI LIFT GAS IF GAS WAS USED TO MAINTAIN CIRCULATION. LEAVE WELL SI AFTER CT IS POOH. RD CT AND PUMP UNIT. SWITCH VALVING TO FLOW D-3ORD2 INTO G-ZONE GROUP SEPARATOR. RULuBRiCAToRE-LINE UNIT.AND BoPEHU COMMUNICATIONTo 2500 PSI. SYSTEM IN UNIT. PRESSURE Sm£CEiv£DM NOV I lg,c ,O "~"~ka Oil & Gas Cons. Com- ' gonmis AnChora~ ,Well D-3ORD2 Cleanout & Reperforating Procedure Page 2 10) WITH WELL SI, RIH WITH A 2-1/8" DUMMY GUN (30') AND TAG FILL. POOH. IF A DEPTH OF 11 '800' IS REACHED WITH THE 2-1/8" DUMMY GUN, RU A 2-1/8" HOLLOW CARRIER PERF GUN. IF A DEPTH OF 11,800' IS NOT REACHED, RU A 1-11/16" HOLLOW CARRIER PERF GUN. PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE NOTIFY LOGISTIC SUPPORT AND ESTABLISH THE COMMUNICATION BLACKOUT. RE-ESTABLISH THE COMMUNICATION BLACKOUT WHILE POOH. 11) RIH WITH 2-1/8" OR 1-11/16" HOLLOW CARRIER, 4SPF, O-PHASING AND PERF THE FOLLOWING INTERVALS UNDERBALANCED. SI WELL TO RIH AND POOH. RUN BENCH INTERVAL (PDK-IO0) FOOTAGE i G-4 11,772-11,804' 32' 2 G-3 11,734-11,756' 22' 3 G-3 11,714-11,734' 20' 4 G-2 11,634-11,664' 30' 5 G-2 11,634-11,664' 30' (OFFSET 30 DEGREES) TEST WELL FOR 12 HOURS 6 G-1 11,580-11,602' 22' NOTE: DURING RUN #1 FLOW WELL AFTER PERF GUN IS ON DEPTH. 12) RD E-LINE. FLOW WELL TO G-ZONE GROUP SEPARATOR AT A REDUCED RATE SLOWLY OPENING THE CHOKE COMPLETELY OVER ABOUT 4 TO 6 HOURS. PLACE WELL IN TEST AFTER 24 HOURS. NOTE: Maximum anticipated SBHP is 2500 psi. docs\dvp\3Ord, doc Attachment #2 Coiled DOLLY VARDEN PLATFORM TUbing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/2,' Rams 5000 psi WP HYDRAULIC RAMS 4'1/16, 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi~ , 2' 3000 13 3/8' CASING STATE OF ALASKA ~' AD~6KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown M Stimulate__ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: Development ~ UNOCAL (Marathon Oil Co - Sub Operator Exploratory__ 3. Address Stratigraphic_ P.O. Box 190247 Anchorage, AK 99519 ~ Service__~ 4. Location of well at surfac~-eg B-l, Cond. #12 Dolly Varden Platform 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SM /~top of productive interval ,060' FSL, 860' FEL, Sec. 32-9N-13W-SM A~e e iv~e ,~ C~¢¢~h, 700' FEL, Sec. 32-9N-13W-SM A~t,c~8~Iptl~'sL, 670' FEL, Sec. 32-9N-13W-SM perforate__ Notice of Other.~_.. Cancel lation 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-30RD2 9. Permit number/approval number 9.-559 ~o. APInumb _ __ _er 5o- 733-20208-01 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043' Surface 10,130' 10,620' Intermediate 1,514' Production 471 ' Liner Perforation depth: measured 11,841 ' feet Plugs (measured) 8,894' feet 11,830' feet feet 8,886' Size Junk (measured) Cemented Measured depth True vertical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' 11,738' MD; 8,809' 11,804' MD; 8,848' G-3 11,714' - true vertical G- 4 11,772 ' - - 8,825' TVD - 8,869' TVD 13. Tubing (size, grade, and measured depth) 3 1/2" 9.2# N-80, AB Mod Butt. Tbg to 10,016' Packers and SSSV (type and measured depth) 0t i s 3-1/2" SCSSV MD: Otis BWD Pkr w/ 8' SBE 0 10.008' MD Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Series 10 BV (2.813" ID x profile) @ 31( · 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil x Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Re~.~8/15/~ Date 1 o - t ~ "q~ ~ SUBMIT IN DUPLICATE ,,"'"/' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Ri Gl 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ At effective dep~th 1,090' FSL, 700' FEL, Sec. 670' rE , Se . Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __X Other __ 2. Name of Opera. tor I 5. Type of Well: UN06AL (Marathon 0i] Co- Sub 0perato ) Devel°pmentx 1 Exploratory __ 3. A d. rs .s Box Z90247AK 995Z9 / StratigraphiC__service__ / 4. Location of well at surfaceLeg B-]., 6ond. #].2 Dolly Varden Platform 680' FSL, 1,213' FWL, Sec. 6-8N-].3W-SM At top of productive interval 1,060' FSL, 860' FEL, Sec. 32-gN-13W-SM 32-9N-13W-SM 32-9N-13W-SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unitor Property name Trading Bay Unit 8. Well number D-3ORD2 9. Permit number 88-98 10. APl number 50- 733-20208-01 11. Field/Pool G-Zone feet 12. Present well condition summary Total depth: measured true vertical 11,841' 8,894' feet Plugs (measured) feet Effective depth: measured 11,830 ' true vertical 8,886 I Casing Length Structural Conductor 3,043 ' 10,130' Surface 10,620' Intermediate 1,514I Production 47 ]. ' Liner Perforation depth: measured [ ECE!VED feet Junk(measured) -~, ~ 2 feet :~! :,,,~,;~,,::, <';ii ~:~. G~s Cons,, Size Cemented Measured depth A.flCU:tC'2~icai' depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' G-3 11,714' - true vertical G-4 11,772' - 11,738' MD; 8,809' - 8,825' TVD 11,804' MD; 8,848' - 8,869' TVD Tubing (size, grade, and measured depth) 3 Z/2" 9.2# N-80, AB Mod Butt. Tbg to ].0,0].6' Packers and SSSV (type and measured depth) 0t i $ 3- ]./2" $C$$V MD; Otis BWD Pkr w/ 8' SBE 0 10,008' MD Series 10 BV (2.813" ID x profile) @ 31C 13. Attachments 1 & 2 Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation October 30, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/~.~.~,~¢- ~,~¢~.¢~ (~itle Environmental Engineer / /'/ U¢'~> ~3R COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test I Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ¥0¥ Original Signed By David W. Johnston Approved by order of the Commission Date 10/26/89 J Approval No. ~ _... ¢¢_--~,~-"-' Approved Copy Returned - Commissioner Date //~ -~ 7' 2 ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-3ORD2 Procedure 1. SI well 6 hours prior to perforating. 2. RU E-line. PT to 2500 psi. · Perforate the following intervals with 1-11/16" hollow carrier guns, 4 SPF. Run Interval (PDK-IO0) Feet Zone Phasin~q 11,798 - 11,824 11,772 - 11,798 11,730 - 11,750 11,714 - 11,730 11,634 - 11,664 11,634 - 11,664 26 G-4 0 26 G-4 0 20 G-3 0 16 G-3 0 30 G-2 0 30 G-2 30 4. POH. RD E-line. 5. Bring well on slowly over 24 hours. Note: Maximum anticipated SBHP is 2500 psi. docs\dvp\D3ORD, doc ~---, Attachment #2 OLLY VARDEN PL,~ .'FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) ------ LUBRICATOR 5000 psi CHISTMAS TREE POSITIVE CHOKE STATE OF ALASKA COMMk, JI' AI..~,,~KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPE 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Pull tubing __ Alter casing w Repair well __ 2. Name of Operator ~ 5. Type of Well: UNOCAL (Harathon 0il Co - Sub 0peratol ) 3. Address . P.O. Box 190247 Anchorage, AK 99519 J 4. Location of well at surfaceLeg B-l, Cond. #12 Dolly 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,060' FSL, 860' FEL, Sec. 32-gN-13W-SH At effective d¢.l~tlh 1,090' , 700' FEL, Sec. 32-gN-13W-SH Perforate _~_ Development _._X Exploratory __ Stratigraphic __ Service __ Varden Platform Attotal depth 1, I10 FSL, 670' FEL, Sec. 32-gN-13W-SM Other ~ 6, Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Tradin- n;,,, IIn-~'f- 8. Well ~cJr~er- -" ..... D-3ORD2 9. Permit number/approval number 9-559 ,, feet 10. APl number $o- 733-20208-01 11. Field/Pool 6-Zone 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043' Surface 10,130' Intermediate 10,620 ' 1,514' Production 471' Liner Perforation depth: measured 11,841' feet 8,894' feet 11,830' 8,886' Size feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' G-3 true vertical G- 4 11,714' - 11,738' MD; 8,809' - 8,825' TVD 11,772' - 11,804' MD; 80848' - 8,869' TVD Tubing (size. grade, and measured depth) 3-1/2" 9.2# N-80, AB Mod Butt. Tbg to 10,016' Packers and SSSV (typ. e and measured depth) 0t i S 3- ]./2" SOSSV MD; Otis BWD Pkr w/ 8' SBE @ 10,008' HD Series 10 BV (2.813" ID x profile) (a 316 13. Stimulation or cement squeeze summary 14. Intervals treatedf ..~, ..,4~~m......ur..,../ . Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 6/26/89 105 60 55 1020 120 Subsequent to operation 7/23/89 101 68 44 990 110 15. Attachment~ # 1 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations Z~. Oil X__ Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form lO-,O~"~v 0~~ s .// // Service Date ~ / 7 / 89 SUBMIT IN DUPLICATE Attachment #1 TBU Well D-3ORD2 Summary of Daily Operations 7/8/89 RU E-line and PT lubricato)~ to 2500 psi, OK. RIH w/ 2-1/8" hollow carrier perforating guns, 4 SPF, 0v phasing. Correlate at 3-1/2" liner lap w/ PDK-iO0 (file 5) log. RIH to 11,550'. tUnable to get past 11,550'. POH, disarm guns. RD to side of well. WO wireline uni . 7/9/89 RIH w 2.25" gauge ring to 11,710' WL.M, PO,O,H. wireline and PT lubricator, OK. - ~--'- ~ill samnle POH. RIH w/ 2..7,0, _ RU ' M RIH w/ 1-3/4" bailer to 11,782 WL ano ODl~al~m · v ' ' " au e ring and tag fill in 3-1/2 liner gauge ring to 10,150 WLM, POH.._ R~!,H' w/ 2.70. g _~, ~...i.~ ar to 11,753' WLM, POH at 11,695' WLM, POOH. RIH w/ 2.Zb gauge ring anu >,,,~- b ' RD. 7/11/89 RU E-line and PT lubricato~ to 2500 psi, OK. RIH w/ 2-1/8" hollow carrier perforating guns, 4 SPF, 0v phasing. Guns sat down at 11,552'. Made two (2) attempts to break through unsuccessfully. PU to 11,000' and flow well 1-1/2 hours. RIH and sat down at 11,557'. POOH, RD and disarm guns. Place well back on production. docs\dvp\D3ORD, doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Perforate Pull tubing __ Alter casing ~ Repair well ~ 2. Name of Operator .1 5. Type of Well: I!NOCAI_ (Marathon Oil Co - Sub Operato ) Devel°pmentX---- ~ ~ t Exploratory __ 3. ~ ....... Stratigraphic __ P.O. Box 190247 Anchorage, AK 99519 / Service__ Other __ 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Ray Ilnit 4. Location of well at surfac6L e g B-l, Cond. #12 Dolly Varden Platform 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,060' FSL, 860' FEL, Sec. 32-gN-13W-SM At effective depth 1,090' FSL, 700' FEL, Sec. 32-gN-13W-SM At total depth 1,110' FSL, 670' FEL, Sec. 32-9N-13W-SM Well number D-30RD2 9. Permit number/approval number 9-126 10. APl number $o- 733-20208-01 11. Field/Pool G-Zone feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043 ' Surface 10,130' Intermediate 10,620 ' Production 1,514 ' 471' Liner Perforation depth:measured 11,841 ' feet Plugs (measured) 8,894' feet 11,830' 8,886' Size feet Junk (measured) feet Cemented Measured depth True vertical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' G-3 11,714' - 11,738' MD; 8,809' - 8,825' TVD true vertical G-4 11,772' - 11,804' MD; 8,848' - 8,869' TVD Tubing (size. grade, and measured depth) 3 1/2" 9.2# N-80, AB Mod Butt. Tbg to 10,016' Packers and SSSV (type and measured depth) Ot i S 3-1/2" SCSSV MD; Otis BWD Pkr w/ 8' SBE @ 10,008' MD 13. Stimulation or cement squeeze summary 14. Series 10 BV (2.813" RECEIVED ID x profile) @ 31( Intervalstreated(measured) See Attachment #1 Treatment descriPtion including volumes used and final pressure ~i~]~,S](~ Dii & Gas Cons. C0mmissiort ...... i~i ~p.~_hnrnnl~' Representative Daily Average Production or Injectibn"l~'~' '" OiI-Bbl Gas-Mcf WateroBbl Casing Pressure Tubing Pressure Prior to well operation 2/14/89 69 10 9 1020 120 Subsequent to operation 3/4/89 93 19 79 1030 110 15. Attachment[ 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil ~ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢~,~,~. 4~,~.~/~, (/' Form 10-404 Rev 06/15/88 Title Environmental Engineer Service Date04/06/89 SUBMIT IN DUPLICATE Attachment #1 Daily Summary of Operations TBU Well D-3ORD2 2/18- 2/19/89 RU CTU and PT lubricator and lines to 4000 psig, OK. RIH w/ 2.25" Jet Nozzle w/ 5 - 3/8" ports. RIH, circ FIW @ 1/2 BPM, 1000 psi. Tagged fill @ 11,776' CTM. PU CT and increase rate to I BPM. Pump 120 bbls FIW and clean fill to 11,791' CTM. Mix and pump HEC pill @ I BPM, 1450 psig, and displace w/FIW. RIH w/ CTU and clean fill to 11,800 CTM - 11,830' ELM. PU CT, mix and pump 2nd HEC pill @ I BPM, 3000 psig. Displace HEC w/ FIW. Final pump rate I BPM, 3450 psig. Pump 34 bbls of FIW to establish injection. Began pumping acid treatment as follows: Rate Press. Volume Fluid (BPM) (psi) 1st Stage 1500 gal 7-1/2% HCL + additives 1.25 4000 1500 gal 12-6 HCL-HF + additives 1.25 4000 1500 gal 7-1/2% HC1 + additives + diverter 1.25 4000 2nd Stage 1500 gal 7-1/2% HCL + additives .50 4000 1500 gal 12-6 HCL-HF + additives .75 4000 1500 gal 7-1/2% HC1 + additives 1.00 4000 Displace CT w/ 16 bbls FIW, POOH. RD em/42B/DVP2 Gas Cons. Commission STATE OF ALASKA AL,-~KA OIL AND GAS CONSERVATION COMMI~. ,.~ON APPLICATION FOR SUNDRY APPROVALS Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate x Variance __ Pedorate __ Other __ 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading B~y Unit 8. Well number feet 1. Type of Request: Abandon __ Suspend__ Alter casing ~ Repair well ~ Change approved program .. Pulltubing ~ 2. Name of Operator ] 5. Type of Well: UNOCAL (Marathon Oil Company - Sub Oplrator)Development.X_ Exploratory __ 3. Address Stratigraphic ~ P.O. Box 190247 Anchorage, AK 99519 Service__ 4. Location of wetl at surfac~Leg B-l, Cond. ffl2 Dolly Varden Platform 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SM Attopofproductiveinterval 1,060' FSL, 860' FEL, Sec. 32-SN-13W-SM ~eflectivedepth 1,090' FSL, 700' FEL, Sec. 32-9N-13W-SM ~total d~th 1,110 FSL, 670' FEL, Sec. 32-SN-13W-SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043 ' Sudace 10,130' 10,620' Intermediate 1,514' Production 4 / 1 ' Liner Perforation depth: measured 11,841 ' feet 8,894 ' feet Plugs (measured) D-30RD2 9. Permit number 88-98 10. APl number 50-- 733-20208-01 11. Field/Pool G-Zone · , i~',;~ .~,,, ~.~, ~' '~ .f' ~.~ ~,~. 11 830' feet Junk (measured) i~k¢ 0il & Gas Cons, Co~',;~,~i~-~;.v~; · feet 8,886' ' ' Ar~cl]0rage Size Cemented Measured depth True vertical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,:i. 30' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' G-3 11,714' - true vertical G-4 11,772 ' - Tubing (size, grade, and measured depth) 3 1/2" 9.2~/ N-80, AB Mod Butt. Tbg to 10,016' .... Otis 3-1/2" SSSV _Packers_a.n.d S_S~V (typ~a~ measured ?~,~08' MD Otis BWO ~r w/o~ SBE ~ 11,738' MD; 8,809' - 8,825' TVD 11,804' MD; 8,848' - 8,869' TVD Series 10 BV (2.813" ID x profile) @ 310 13. Attachments 1 & 2 Description summaryof proposal x__ Detailed operations program __ BOP sketchX__ 14. Estimated date for commencing operation February 1989 16. If proposal was verbally approved I Name of approver Date approvedI Service .,,17r.~. I'bereby certify that the foregoing is true and correct to the best of my knowledge. ~'o,u,,ud Title Environment al ' - f/' FOR COMMISSION USE ONLY 15. Status of well classification as: Oil _z. Gas_ Suspended Conditions of approval: Notify Commission so representative may witness Engineer Date 2/14/89 Plug integrity __ BOP Test __ Location clearance -- //_~/j. Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner 0Rmt~.!~!- SIGNED BY LONNiE C. SNlIT~l .~pproved CopY Returned - ~G-~"~2' Date ~-"~-'// FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-30RD2 Procedure 1. MIRU coiled tubing unit, acid tanks, and pump skid. 2. RIH w/ CT to 11,738'. Circulate 15% HC1 across G-3 perfs from 11,738' to 11,714'. 3. Pull up hole w/ CT to 11,710'. SI tubing, squeeze first stage of acid treatment into G-3 perfs as follows: 500 gallons 15% HC1 with additives* 1500 gallons 12% HC1-6% HF with additives 500 gallons 7-1/2% HC1 or 2% Amonium Chloride 20 gallons Matri-Seal "0" 4. RIH w/ CT to 11,804'. Circulate 15% HC1 across G-4 perfs from 11,804' - 11,772'. 5. Pull up hole w/ CT and 11,800'. SI tubing, squeeze second stage of acid treatment into G-3 perfs as follows: 500 gallons 15% HC1 with additives 1500 gallons 12% HCL-6% HF with additives 500 gallons 7-1/2% HC1 or 2% Amonium Chloride displace CT volume with FIW *Additives to be determined by emulsion tests 6. Displace CT w/ diesel and POH. RDMO acidizing equipment. em/42B/DVP Attachment #2 ~- Coiled DOLLY VARDEN PLATFORM TUbing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 41716, 5000 psi CHISTMAS TREE POSITIVE CHOKE ~ 2' 5000 psi , 2' 3000 psi. 13 3/8' CASING ' 'W~ ?'-"~ STATE OF ALASKA .... ~~_~~~ ALASKA ~,~L AND GAS CONSERVATION CONIMISSlON LL COMPLETION OR RECOMPLETION REPORT AND LO , , 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNOCAL (Marathon Oil Co. Sub-operator) 88-98 3. Address 8. APl Number P. O. Box 190247 Anchorage, AK 99519 50- 733-20208-01 4. Location of well at surface Leg B-l, Cond. ~/12 Dolly Varden Platform 9. Unitor LeaseName 680' FSL, 1,213' FWL, Sec. 6 8N-13W-SM Trading Bay Unit At Top Producing Interval 10. Well Number 1,060' FSL, 860' YET,, Sec, 32 9N-13W-SM: D-30RD2 At Total Depth 11. Field and Pool 1.110' FSL, 670' FEL, Sec. 32 9N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSLI . G-Zone 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 9/18/88 12/4/88 1 / 1/89 132 feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 191 Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11,841' & 8894' 11,830' & 888.6' YES~ NO[--]I 310' feetMD N/A 22. Type Electric or Other Logs Run PDK-100 23, CASING, LINER AND CEMENTING RECORD ., , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED i3-3/8~: bi~ K-5b 0' 3,O43~'iT'i/Z~: l~UU sx C±ass G 9-5/8" 47¢f N-80 0' 10,130' 12-1/4" 2500 sx Class G N/A 7" 29~f N-80 0' 10,62'0' 8:1/2" 875 sx Class G N/A 5" 18¢f N-80 10,021' 11,535' 6" 146 sx Class G N/A '"3.5" 9.3¢! N-80 11,370' 11,841' ' 4-1/8" 113 sx Class G " N/A 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) C-3 11,714- 11,738' MD; 8809- 8825' TVD ' 3.5" 10,016' 10,008' 2-1/8" - 4 HPF G-4 11,773 - 11,799' MD;8849 - 8865' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETCi ' 2-1/8" - 4 HPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED G-4 11,772 - 11,804' MD; 8848 - 8869' TVD 2-1/8" - 4 HPF , 27. PRODUCTION TEST ,, Date First Production I Method of Operation (Flowing, gas lift, etc.) 1/2/89I Gas Lift Date of Test Hours Tested PRODUcTiON FOR OI L~BBL GAS'~MCF W'ATER-BBL CHOKE SIZE' 'I'GAS-OIL RATIO 1/9/89 -24 TESTPERIOD I~ .42 6 11 N/AI 143 r i Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 110 990 24oHOUR RATE I~ 42 6 11 34° 28. COP E DATA Brief description of lithologY, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,.~ ,-, .&fa~kaOil & ~as Cons. Comrr~i~io~ "~' ~,chorage .,, ...... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~/,-~, 29. i ..... 30. i.'" i ' 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. I G-Zone 11,579 ' 8,718 ' -- 31. LIST OF ATTACHMENTS Attachment #1 - Current Wellbore Diagram; Attachment //2 - Directional Survey 32.r.~l h,eir~by certify that the foregoing is true and correct to the best of my knowledge · ROV 5. Robo_rt+ /57 ~ ' '_~___ .,. 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, (:;as Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Attachment #1 MARATHUN Ii]IL COMPANY TRADING BAY UNIT lVe/l D-3ORD2 KB 0'-41' 13-3/8' Csg 61~ K-55 8 3,043' Completed 18/30/88 AIl measurements ~re RKB to top o¢ equipment. 41' CI~/ 'DCB' Tbg H~nger. 4-1/8f 8RD, Top (Type 'H' BP¥ Prep) X-over, 4-1/8' Butt pin x 3-1/8' Bu~ct pin. 310' SSSV O~ls 3-1/2' Series 10 BM (8.813' ID x pro?IleX Comple~lon String, 3-1/2% 9.~, N-80, AB Hod Bu~ Tbg. Al/ g~s ll?~ m~ndre(s ~re Otis 3-1/2' Type KBMG (8,86' Drift ID) w/ BST GLV 1,O-R v~lves ~nd BK L~tches, 8555' ~l 16/64' Port 4953' ~8 16/64' Port 6310' fi-3 16/64' Port 7450' #4 16/64' Par± 8474' ~5 16/64' Port 9849' ~6 80/64' Port 9-5/8' Csg 47# N-BO 8 10,130' 7' Csg 89# N-80 8 10,680' 5' Liner 18ff N-BO FL4S 10,081'-11,535' 3-1/8' Liner 9,3# N-80 11,370'-11,841' FIll *~gged 8 11,801, 1/4/89 as per PDK Los ?lle #5, G-3 G-4 9987' 9978' 10,008' 10,008' 10,080' 10,086' 10,045' NOTE,,. #7 24/64' Port Otis 'X' nipple pro?Re (8.813' ID) O±ls Stralgh± Sro± Loco. tor w/B?t o? se~ls o. nd Mule Shoe Guide. Btls B~/D Pkr w/8' SBE 6' Pup Baker PBR Seal Assembly, Hal? Mule Shoe Guide. PBR loco. ted on top o? 5' liner 10,088'-10,043'. G-3 G-4 G-4 Per?ore'clans (PDK) 11,714'-11,738' 4 SPF 0° Ph(zslng 1/4/89 11,773'-11,799' ' ' I/3/89 11,778'-11,804' ° 180° Pho. slng 1/8/89 .N(]TE! Alt above In-t:erv(zts perFora*ed and reported ets per PDK Log, ?lie ~:5. This was the second to991n9 pass and Is 3' shallow o¢ the CBL o. nd the ?Irs* pass o? the PDK tog, ~,le fi4.;?, i ~',,,.. PBTD 8 11,830' TD 8 11,841' Revision ~ate, i/S~ 0ii & ~3as Cons. - , Revised By, GDM/ne? ',' ' u~r~llora~e Re~son, ~ett w~s re~rl~teo ,. Pnevlous Revlslom · . WELL LOG INVENTORY PAGE I of' LOG LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) CFD (compensated formation density) BHC/SL (borehole compensate~l sortie) _. _ . LSS (long spaced sonic) · .. SSS (short spaced sonic) CYB (cyberlook) .. GCT (groscopic survey) DIPMETER SAMPLES: Require~i yes/~ Date Received : Comments: Attachment #2 SURVEY REPORT MARATHON OILCOMPANY D'30-RD-C2 TRADING BAY FIELD KENAI~ ALASKA DOLLY VARDIN 'JANUARY 4, 1989 A Gyrodata Directional for Survey MARATHON OIL COMPANY D-30-RD-C2 TRADING BAY FIELD, KENAI, ALASKA Date Run: 18-DEC-88 7:45:0 Job Number: AK1288Gl13 Surveyor: AL KUDRLE Calculation Method: RADIUS OF CURVATURE Survey Latitude: 60deg 48min 30sec N Bearings are Relative to TRUE NORTH Proposed Well Direction: N 75deg Omin Osec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference ~ARATHON OIL COMPANY D-30-RD-C2 FRADING BAY FIELD, KENAI, ALASKA Sob Number: AK1288Gl13 Gyr odata Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING £t deg min de9 min (: .0 0 0 100,0 0 22 200.0 0 20 300,0 0 26 400,0 0 44 500,0 0 38 600,0 2 26 700,0 7 35 800,0 10 6 900,0 11 32 1000.0 15 22 1100.0 18 34 1200.0 20 27 1300,0 23 18 1400.0 25 48 1500.0 28 39 1600.0 31 26 1700.0 33 18 1800.0 36 27 1900.0 39 i0 2000,0 39 35 2100.0 39 8 2200.0 39 13 2300.0 38 48 2400.0 38 54 2500.0 40 17 2600.0 42 19 2700.0 44 16 2800.0 46 13 2900.0 48 29 N 00E N 24 52 W N30 9W N 27 26 W N 38 18W DOG-LEG VERT VERT SEVERITY DEPTH 'SECTION deg/lO0' £t £t CLOSURE DISTANCE BEARING £t deg min .00 ,0 ,0 .0 N 0 0 MD REF TO DOLLY VARDEN RKB ELEV 106' TO MSL MULTISHOT GYRO RUN IN 7" AND 5" CASING ,36 100,0 -.1 ,3 N 24 52 ,05 200,0 -,2 .9 N 26..36 ,11 300,0 -.3 1.6 N 27 31-W ,31 400,0 -,7 2.6 N 29 36 N 26 45 W .17 500,0 -1.0 N 2 7 W 1,88 599,9 -1.0 N 9 23 E 5,21 699,5 1,8 N 11 i0 E 2.54 798.3 8.4 N 10 59 E 1.43 896,6 16.6 N 18 35 E 4.22 993.8 28.2 N 22 2 E 3.35 1089.4 45.0 N 20 24 E 1,95 1183.7 64.7 N 19 0 E 2.90 1276.5 86.0 N 17 19 E 2.60 1367,4 108,7 N 16 34 E 2.87 1456.3 132.9 N 15 39 E 2.82 1542.9 158.7 N 21 56 E 3,85 1627,4 188,5 N 22 47 E 3,19 1709,4 223,2 N 21 39 E 2,79 1788,4 260,3 N21 17E N21 28E N21 37E N21 30E N22 5E N22 OE N 2244 E N 22 23 E N 22 28 E N22 9E 3.8 N 30 31 W 6,4 N 23 53 W 14,7 N 7 58 W. 29.7 N 1 22 E 48,3 N 5 8 E 71.3 N 8 16 E 100.0 N 11 45 E 133.1 N 14 7 E 170.2 N 15 20 E 211.7 N 15 54 E 257,4 N 16 5 E 307,4 N 16 5 E 360,9 N 16 29 E 417.8 N 17 17 E 478,9 N 17 55 E · 49 1865.7 298.0 .47 1943.0 335.6 · 13 2020,5 373.2 · 42 2098.2 410.7 · 38 2176.1 448,2 542.2 N 18 20 E 605.6 N 18 39 E 668.7 N 18 55 E 731.6 N 19 9 E 794,2 N 19 21E 1.38 2253.2 486.6 2.09 2'328.3 -- 526.7 1.96 2401.1 568.5 1.96 2471.5 611,6 2.28 2539.2 656.2 857.9 N 19 33 E 923.8 N 19 45 E 992.3 N 19 57 E 1063.3 N' 20 7 E 1136.8 N 20 16 E HORIZONTAL COORDINATES £eet .00 N .00 E .29 N ,13 W ,82 N .41W 1,41N .73 W 2.26 N 1,28 W 3,26 N 1,92 W 5.84 N 2,59 W 14,54 N 2.03 W 29,65 N ,71E 48,06 N 4.31E 70,53 N 10,24 E 97,90 N 20,37 E 129.03 N 32,46 E 164,10 N 45,01 E 203.57 N 57.96 E 247,33 N 71,29 E 295,42 N 85,17 E 346,07 N 102,41 E 398,95 N 124,16 E 455,69 N 147.34 E 514,73 N 170.55 E 573,79 N 193.67 E 632,55 N 216,86 E 691,09 N 239.98 E 749,35 N 263,27 E 808,42 N 287,19 E 869,45 N 312,30 E 932,77 N 338,60 E 998,40 N 365,69 E 1066,45 N 393,61 E MARATHON OIL COMPANY D-30-RD-C2 TRADING BAY FIELD, KENAI, ALASKA Job Number: AK1288Gl13 A G y r od a t a Directional Survey Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 3000.0 50 20 3100.0 51 42 3200.0 51 27 3300,0 51 51 3400.0 51 54 3500.0 51 39 3600.0 51 36 3700.0 51 44 3800.0 51 26 3900.0 51 31 4000,0 51 56 4100.0 51 8 4200.0 51 8 4300.0 50 22 4400.0 49 49 4500.0 49 45 4600.0 47 32 4700,0 48 1 4800.0 44 28 4900.0 44 4 5000.0 44 5 5100.0 43 35 5200.0 43 12 5300.0 42 8 S400.O 42 38 5500.0 42 8 5600.0 42 35 5700.0 43 13 5800.0 43 52 5900.0 43 51 N22 15E N22 8E N22 4 E N 21 44 E N 21 21 E N21 7E N 20 43 E N 20 49 E N 20 57 E N 20 38 E N 20 46 E N 20 55 E N 20 6 E N 2O 5 E N 20 27 E N 20 52 E N 21 18 E N21 N 23 20 E N 29 58 E N30 5E N 29 57 E N 3O 33 E N 3O 27 E N 29 54 E N 29 39 E N 30 27 E N 34 42 E N 35 36 E N 35 23 E VERT VERT DEPTH SECTION ft ft 1.85 2604.3 702.1 1.37 2667.2 749.1 · 25 2729.3 796.4 · 47 2791.4 843.4 · 31 2853.1 890.3 · 31 2915.0 936.7 · 32 2977.1 982.7 .15 3039.1 1028.6 .32 3101.2 1074.5 .27 3163.5 1120.3 ,42 3225.4 1166.1 .80 3287,7 1211.9 · 63 3350.4 1257.1 · 76 3413.7 1301.7 .62 3477.8 1346.0 · 33 3542.4 1390.5 2.24 3608.5 1434.7 · 51 3675.7 1478.4 3.91 3744.8 1522.1 4.64 3816,4 1568.5 · 08 3888.3 1617.7 .50 3960.4 1666.6 .56 4033.1 1715.4 1.07 4106.6 1763.8 · 62 4180.5 1811.6 .52 4254.4 1859.0 .71 4328.3 1906.7 2.96 4401.5 1956,9 .90 4474.0 ~'2009.8 .16 4546.1 2063,3 CLOSURE DISTANCE BEARING ft deg min 1212.7 N 20 23 E 1290.4 N 20 29 E 1368.7 N 20 35 E 1447.1 N 20 39 E 1525.7 N 20.42 E 1604.3 N 20 43 E 1682.7 N 20 44 E 1761.1 N 20 44 E 1839.5 N 20 44 E 1917.7 N 20 45 1996,2 N 20 45 E 2074.5 N 20 45 E 2152.4 N 20 44 E 2229.8 N 20 43 E 2306.5 N 20 42 E 2382.9 N 20 42 E 2457.9 N 20 43 E 2532.0 N 20 44 E 2604,2 N.20 46 E 2673.6 N 20 55 E 2742.3 N 21 9 E 2810.7 N 21 22 E 2878,6 N 21 35 E 2945.~ N 21 47 E 3012.3 N 21 58 E 3079.1 N 22, '8 E 3145.8 N 22 19 E 3212.8 N 22 32 E 3280,1 N 22 47 E 3347,7 N 23 3 E HORIZONTAL COORDINATES feet 1136.76 N 422.30 E 1208.74 N 451.65 E 1281.33 N 481.12 E 1354.09 N 510.37 E 1427.26 N 539.26 E 1500,48 N 567.71E 1573.71 N 595,71 E 1647.06 N 623.52 E 1720.26 N 651.46 E 1793,40 N 679.23 E 1866.84 N 706.98 E 1940.01 N 734.84 E 2012.94 N 762.12 E 2085.67 N 788,73 E 2157.63 N 815.30 E 2229.08 N 842.24 E 2299,11 N 869.24 E 2368.15 N 896.03 E 2435.00 N 923.34 E 2497.35 N 954.63 E 2557.57 N 989.43 E 2617.53 N 1024.07 E 2676.86 N 1058.68 E 2735.25 N 1093.07 E 2793.52 N 1126,95 E 2852.02 N 1160.42 E 2910.34 N 1194.15 E 2967.70 N 1230.79 E 3024.03 N 1270.45 E 3080,45 N 1310.68 E A Gyrodata Directional Survey [ARATHON OIL COMPANY ~-30-RD-C2 'RADING BAY FIELD, KENAI, ALASKA Iob Number: AK1288Gl13 Page 3 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft de9 min deg min de9/lO0' ~000.0 42 56 3100.0 43 21 6200.0 41 43 6300.0 41 21 6400.0 40 31 6500.0 39 49 6600.0 38 31 6700.0 38 17 6800.0 37 12 6900.0 37 39 7000.0 38 28 7100.0 39 1! 7200.0 39 16 7300.0 39 11 7400.0 38 19 7500.0 38 31 7600.0 38 45 7700.0 38 31 7800.0 38 46 7900.0 38 25 8000.0 38 7 8100.0 38 8 8200.0 37 22 8300.0 39 14 8400.0 40 35 8500.0 41 7 8600.0 42 53 8700.0 45 8 8800.0 45 56 8900.0 45 58 N 35 33 E N35 9E N 35 47 E N 34 36 E N35 35 N34 13E N34 i6E N 34 47 E N 35 28 E N35 3E N 35 28 g N36 OE N 37 4E N 37 N 37 4E N 37 OE N37 5 E N 36 55 E N37 14 E N 37 56 E N 39 26 E N 41 12 E N 42 23 E N4341 E N44 13E N 45 32 E N45 12E N 46 17 E N 45 48 E N 45 37 E VERT VERT DEPTH SECTION it it .92 4618.8 2116.3 .49 4691.7 2168.9 1.69 4765.4 2221.1 .87 4840.3 2272.0 ,88 4915,8 2322,1 .89 4992.2 2371.2 1.30 5069.8 2419.0 .40 5148.1 2466.3 1.16 5227.2 2513.3 .51 5306.6 2560.0 .86 5385.4 2607.4 .78 5463.3 2655.9 .68 5540.7 2705.4 .11 5618.2 2755.4 .87 5696.2 2804.8 .21 5774.6 2853.7 .25 5852.7 2903.0 .26 5930.8 2952.2 .31 .6008.9 3001.4 .56 6087.1 3051.0 .98 6165.6 3100.9 1.09 6244.2 3151.6 1.06 6323.3 3202.8 2.03 6401.8 3255.4 1.39 6478.5 3310.4 1.02 6554.1 3367.0 1.78 6628.4 3425.1 2.37 6700.3 3485.7 .88 6770.4 --3548.2 .13 6839.9 3610.9 CLOSURE DISTANCE BEARING deg min 3414,8 N 23 18 E 3481,7 N 23 32 E 3547,9 N 23 45 E 3612,9 N 23 58 E 3677.3 N 24.10 E 3740,7 N 24 20'E 3802,9 N 24 30 E 3864,1 N 24 40 E 3924,3 N 24 49 E 3984,1 N 24 59 E. 4044.8 N 25 8 E 4106.4 N 25 18 E 4168.5 N 25 28 E 4230,4 N 25 38 E 4291,8 N 25 48 E 4352.7 N 25 58 E 4414.0 N 26 7 E 4475.3 N 26 16 E 4536.7 N.26 25 E 4597.9 N 26 34 E 4658.5 N 26 44 E 4718.5 N 26 54 E 4777.7 N 27 6 E 4837.3, N 27 18 E 4898.8 N 27 31 E 4961,3 N 27 44 E 5025,1 N 27 58 E 5091,3 N 28 12 E 5159.3 N 28 27 E 5227,9 N 28 41E HORIZONTAL COORDINATES feet 3136.40 N 1350.54 E 3192.18 N 1390.10 E 3247.23 N 1429.32 E 3301.41N 1467.53 E 3355,20 N 1504.94 E 3408.27 N 1541.61 E 3460.47 N 1577.14 E 3511.64 N 1612.34 E 3561.71 N 1647.56 E 3611.33 N 1682.64 E 3661,67 N 1718,22 E 3712,56 N 1754,84 E 3763,37 N 1792,49 E 3813.79 N 1830.65 E 3863.70 N 1868.42 E 3913,30 N 1905,85 E 3963,13 N 1943,46 E 4012,99 N 1981,04 E 4062.81N 2018.68 E 4112.24 N 2056.71 E 4160.58 N 2095.42 E 4207.66 N 2135.36 E 4253.30 N 2176.16 E 4298.60 N 2218.46 E 4344.79 N 2262.98 E 4391.14 N 2309.14 E 4438.15 N 2356.76 E 4486.64 N 2406.52 E 4536.18 N 2457.89 E 4586.36 N 2509.33 E [ARATHON OIL COMPANY ~-30-RD-C2 'RADING BAY FIELD, KENAI, ALASKA 'ob Number: AK1288Gl13 A Gyr od ara Directional Survey Page 4 MEAS INCL BORE HOLE DEPTH BEARING it deg min deg min ~000,0 45 36 N 45 46 E 3100,0 44 46 N 45 52 E 9200,0 '44 18 N 46 5 E 9300,0 43 20 N 47 3 E 9400.0 43 I3 N 47 32 E 9500.0 42 11 N 47 52 E 9600,0 41 i8 N 48 0 E 9700,0 40 3 N 48 48 E 9800,0 40 25 N 49 25 E 9900,0 41 39 N 50 21 E 10000,0 42 34 N 50 24 E 10100,0 41 48 N 51 0 E 10200,0 43 26 N 54 3 E 10300,0 44 20 N 55 25 E 10400,0 44 7 N 56 31 E 10500.0 46 5 N 56 45 E 10600,0 46 56 N 56 21 E 10700,0 46 30 N 67 35 E 10800,0 51 18 N 71 27 E 3900,0 51 22 N 71 22 E 11000,0 51 46 N 72 15 E 11100,0 50 1 N 73 5 E 11200,0 47 38 N 72 48 E 11300,0 48 32 N 73 5 E 11365,0 47 38 N 73 35 E Final Station Closure: 6788.2 feet DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' it it ,37 6909,6 3673,4 · 84 6980,1 3735.3 · 50 7051,4 3796,6 1,18 7123,6 3857.5 · 35 7196,4 3918.2 1,06 7269,9 3978,4 · 88 7344,5 4037,7 1.35 7420,3 4096.0 · 53 7496,7 4154,1 1,39 7572,1 4213,5 · 90 7646,3 4274,5 · 86 7720,4 4335,7 2,63 7794,0 4398,3 1,31 7866,0 4463,3 · 80 7937.7 4529,2 1,97 8008,3 4596,4 · 91 8077,1 4665,2 8.19 8145.7 4736.1 5.62 8211.4 4811.0 · 09 8273,9 4889.0 ,79 8336,0 4967,2 1.88 8399,1 5044.7 2,39 8464,9 5119,9 ,93 8531,7 5194,3 1,50 8575.2 5242,6 North 35 deg 33 min 45 sec East CLOSURE DISTANCE BEARING ft de9 min 5296.5 N 28 55 E 5364.4 N 29 8 E 5431,6 N 29 21 E 5497,8 N 29 34 E 5563.1 N 29'.46 E 5627,7 N 29 59 E 5691,0 N 30 12 E 5753,0 N 30 24 E 5814,2 N 30 36 E 5876.2 N 30 49 E. 5939,4 N 31 2 E 6002,7 N 31 15 E 6065,8 N 31 29 E 6129,6 N 31 44 E 6193,2 N 32 0 E 6257,7 N 32 16 E 6323,9 N 32 32 E 6387,3 N 32 51 E 6447,9 N.33 15 E 6509,4 N 33 41 E 6571,2 N 34 6 E 6632,1 N 34 31E 6691,2 N 34 55 E 6750,0' N 35 19 5 6788,2 N 35 3~ E HORIZONTAL COORDINATES feet 4636.43 N 2560,62 E 4685.87 N 2611.49 E 4734.61 N 2661,91 E 4782.21 N 2712,18 E 4828,71N 2762,54 E 4874.34 N 2812,70 E 4918.95 N 2862,13 E 4962,22 N 2910.87 E 5004.51 N 2959.69 E 5046.80 N 3009.90 E 5089.57 N 3061.54 E 5132.10 N 3113.50 E 5173.29 N 3167,23 E 5213,32 N 3223,82 E 5252,36 N 3281,63 E 5291,31 N 3340,78 E 5331,30 N 3401,30 E 5365,46 N 3465,46 E 5391,82 N 3536,01 E 5416.70 N 3610,02 E 5441,16 N 3684,44 5464.27 N 3758,51 5486,35 N 3830,46 5508,17 N 3901,60 5522,04 N 3947,94 HOUSTON INSTRUMENT AUSTIN. 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' : I 'T · ' :' ' : : :"I- "71:' :';: ::'-, ............... : ...... : ........ ::.: ...... ' : " ',~}:,~:::.!:~::i-.~.:[:,-:~ 4-:;i-~i-~ -~:-.i'~! ;!.:: ;:~: ::~; .;;:: :::4 .i.;~i ~;,;. :::: ::~: :;i::i::~ ~;;: : ii. i HOUSTON INSTRUMENT AUSTIN, T[XAS .---~ CHART NO. IOI5~ ~ .:LI-LI-: -.~:i ; .... ~ ...... --?H ii:,~-~t~: - -l~-l_!_b]_ I ii I ~ , ',, : ' : :{ ; ; j, ii: , : :~-: .''"--: ' ~' ': , ,' 4.4; ...... ~:..~ ..... ..... ~ .... :_; ..... ~ . ~ ~ ~ ~ ~ : ~ ~ ~ , , : , , -FJ '-{p-'4{--~-- []-'-]]411 '-'-f : ..... , ' ' '' ' ',' ', '' ~'' ' ', ' ' { { ii/ , . , , ; { , - -, -~ ..... ,~., _, . . , -- ~ ~ ...... ; , ......... ; ; ..... : . . / II /~;~ ~ ~ ~ , ~ '~ ' : : ', ' ' ' ' Ti-r? F'~- ']'' I ' ~' i i ' ' ' : ' ~ : ~ ' ~ ' ' ' , j.', il :~..'~ [iii:::., ',' ~: '~ ', -]'--I'-,'-"~ .... ~ I i ; ~ ~ ~ ~ ~ : : : ' ; /: ' : ; · : t : : ; ' : · . . ; : ; : · :. i : ......... : .......... ; , -~.~ .......... , t'~'~'~-b: ~*--,,~- ~ ':- ~ ............ ~.., ~ ......... { ......................... i : ~ ; ' j ~ ; ~ ~ ~ : ~ , ' ' ' . ~ -'~ ..... : ----~ ~ , ~ : '-'1'; .... 1 ._ 1~ ~ ~ i;':~; ~ ' ~1 ' :' :::'[:~ : ..... ; ...... : ........... I -: ':.i -~ ;- -F --l--bI'I ~-, '~-- ....... - ~- ! ..... ~_ l-'t_ ,"-y: .... -t~ , --[' , ........... ' ~ '. ~ ~ ' · : t- ~" , ~ · ' ' ' ...... ~-' ! -' '~ ...... ~ ....... i'-; . ' ~ ; .... ~ '- , i i . . i -~-I ;' " STATE OF ALASKA f-" ALA,... ,A OIL AND GAS CONSERVATION COM MIS~..~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing ~ Alter casing Stimulate __ Plugging __ Perforate __ Repair well __ Pull tubing __ Other ~ ;Redr il 1 2. Name of Operator ' ; t UNOCAL (Marathon Oil COmpany - Sub Op P.O. Box 190247 Anchorage, AK 9951 4. Location of well at surface Leg B-i, Cond. ~f12 Dolly 680' FSL, 1,213' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,060' FSL, 860' FEL, Sec. 32-9N-13W-SM At effective depth 1,090' FSL, 700' FEL, Sec. 32-9N-13W-SM At total dep_th ' l,ll0' FSL, 670' FEL, Sec. 32-9N-13W-SM 5, Type of Well: rat or)Development _.~ Exploratory __ Stratigraphic ~ Service ~ Varden Platform 6. Datum elevation(DForKB) 106' KB above MSL Z UnitorPropedyname Tradin~ Bay Unit 8Wellnumber D-30RD2 9. Permit number/approval number 88-98 10. APl number 50-- 733-20208-01 11. Field/Pool G-Zone feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 3,043 ' Surface 10,130 ' Intermediate 10,620 ' Production 1,514 ' 471' Liner Perforation depth: measured 11,841 ' feet 8,894 ' feet 11,830' 8,886' Size feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 13 3/8" 1,800 sx 3,043' 2,631' 9 5/8" 2,500 sx 10,130' 7,742' 7" 875 sx 10,620' 8,091' 5" 146 sx 11,535' 8,689' 3-1/2" 113 sx 11,841' 8,894' G-3 true vertical G- 4 11,714' - 11,738' MD; 8,809' - 8,825' TVD 11,772' - 11,804' MD; 8,848' - 8,869' TVD ~bing(size, grade, andmeasureddepth) 3 1/2" 9.2# N-80, AB Mod Butt. Tbg to 10,016' PackersandSSSV(typeandmeasureddepth) Otis 3-1/2" SSSV Otis BWD Pkr w/ 8' SBE @ 10,008' MD Series 10 BV (2.813" ID x profile) @ 31{ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 1/9/89 42 6 11 990 110 15. Attachmen~ ¢/1 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil __x Gas __ Suspended __ .t7; I hereby certify that the foregoing is true and correct to the best of my knowledge. Service // Form 10-404 Rev 06/15/88 / /,' Roy D. Rob~%s Date 2/2/89 SUBMIT IN DUPLICATE Attachment # 1 Well D-3ORD2 Summary of Well Operations 8/31/88 Activating Rig #76 & associated support equip. Skidded rig #76 over D-30RD2. Cut lines in MP #1 w/ torch. Changed swivel packing & filters on drawworks blowers. Cleaned screens for drawworks oil. Preparing to change bladders in Koomey unit. 9/01/88 Change out bladders on Koomey Unit. Start EMD's. Check out drawworks, replace several lights, offload boat. 9/02/88 Cont activating Rig #76. Hook-up flowlines. Repaired air tugger base. Installed 6-1/2" liners in mud pump #2. Put wooden setback platform from Rig #77 on Rig #76. Cleaned brake cooling tank. Checked brake linkage. Repairing & replacing saltwater lines in substructure. 9/3/88 Fin mobilizing Rig #76. Hook-up lines to 7" x 3-1/2" annulus. Release rig to D-30RD2 AFE 8228-8 @ 1200 hrs on 9/3/88. Accum total $45,700. Accept Rig #76 @ 1200 hrs on 9/3/88. Filled 7" x 3-1/2" annulus w/ FIW (418 BBL). RU lubricator. RIH w/ 1-11/16" tbg punch. Couldn't get below 10,580'. POH. Add more sinker bars. RIH. Shot holes in tbg @ 11,010' WLM. POH. Guns didn't fire. MU new guns, RIH, perf tbg @ 11,010', POH. Guns fired. RU to pump down tbg. Pump 30 BBL to fill tbg. Press increased to 1500 psi. No communication to annulus. Pumped total of 153 BBL FIW. Bled off press. Monitoring well. 9/4/88 Monitor well. RU & reverse circ to production clean tank. Circ 826 BBL FIW. Closed SSSV & set BPV. ND tree & NU BPV. Pump down tbg x csg annulus to fill csg. Losing 5.5 BPH to perfs. 9~5~88 Fin filling csg w/ 92 BBL FIW. Tested 3-1/2" PR's. HCR, choke mainfold, K&C lines to 3000 psi. Tested annular to 1500 psi. Filled tbg w/ 23 BBL FIW. Pulled seals out of pkr. Filled annulus w/ 88 BBL FIW. RU & circ through tbg (675 BBL total) losing 9 BPH. Spot 45 BBL pill of LCM @ tailpipe. Lost circulation slowed to 3-1/2 BPH. POH. LD tbg hanger, tbg, SSSV, & mandrels. Su~Amary of Well Oper~ions Well D-3ORD2 Page 2 9/06/88 Fin LD 3-1/2" tbg. RD tongs. Test BR's to 3000 psi. MU pkr retrieving assembly. Test Kelly cock & floor valve to 3000 psi. PU 3-1/2" DP. Attempt to break circ, plugged DP. POH. RIH OE to flush rust & scale. 9/07/88 Fin PU 3-1/2" DP & flush. PU milling BHA & RIH. Mill on pkr f/ 11,065'-11,067' DPM. 9/08/88 Fin milling over pkr @ 11,068' DPM. CBU twice. Had gas cut mud on first BU, POH. No recovery. LD PRT. PU spear. RIH. Engage pkr @ 11,225' DPM. POH. LD pkr & fishing assembly. 9/09/88 Fin POH. LD fishing assembly & pkr. MU 4-1/8" bit, 3-1/8" DCs & 2-7/8" DP. RIH to 11,225'. Circ at TOL. RIH tag soft fill @ 11,500'. Wash soft fill 11,500'-11,728'. Drill hard fill 11,728'-11,803', had good returns. Had shale, sand, rust in returns. CBU. Monitor well. No loss of fluid. POH. LD 4-1/8" BHA. RIH w/ OE 3-1/2" DP. 9/10/88 PU 11 jts 2-7/8" DP. RIH to 11,200' w/ OEDP, cut drill line. RIH & wash to 11,790'. Circ. RU BJ test lines to 3000 psi. Mix & spot 67 sx Class "G" w/ additives for a balanced plug. POH 10 stands. Closed pipe rams. Squeezed 5 BBL away. Final rate 1/4 BPM @ 3000 psi. RO 115 BBL. Had 45 BBL contaminated mud. POH. PU 6" bit & 7" csg scraper. RIH. Tag cmt @ 10,809'. Drill hard cmt to 10,859'. POH to LD scraper. 9/11/88 POH. LD csg scraper. RIH. Drill cmt 10,859'-11,034'. Wash 11,034'-11,214'. Drill hard cmt 11,214'-11,215'. CBU. Test csg to 3000 psi, 30 min OK. POH. PU 6" bit & 7" csg scraper. RIH to 11,183'. CBU. POH. LD bit, scraper. RIH w/ 7" EZSV. 9/12/88 PU 7" EZSV & RIH. Set EZSV @ 11,150'. Test below retainer to 1000 psi, OK. Mix & spot 11 sx Class "G" on top of EZSV. POH 4 stds. RO. POH. Test BOPE, C&K lines, C&K manifold to 250/3000 psi, OK. Test annular to 250/1500 psi, OK. MU TSA section mill. RIH. 9/13/88 Fin RIH to 10,620'. CBU. Mill section 10,620'-10,649. Pump hi-vis sweeps every 6 hrs. Clean flow line. Mill section 10,649'-10,650'. Pump hi-vis sweep. Mill section 10,650'-10,651'. Mill worn out. POH. Summary of Well Oper~ions Well D-30RD2 Page 3 9/14/88 POH w/ section mill, blades worn. PU 6" bit, RIH tag up in wellhead, POH. PU wireline spear, fish DP rubber. Push junk to 10,725'. POH. PU fish-tail bit & section mill. RIH. 9/15/88 TIH to 10,633'. Circ & work pipe to 10,651'. Mill section 10,651'-10,673'. Mill worn out, POH. 9/16/88 Fin POH w/ section mill. BHA. RIH w/ 6" bit. Wash f/ 11,065'-11,100'. CBU. POH. RIH to 11,620'. C&C mud. Ran leak-off test on 7" csg shoe @ 10,620' for an equivalant mud wt of 9.5 ppg. 9/17/88 POH. TIH to 10,620'. Mix & spot bal plug of 130 sx of Class "G" w/ additives. POH 8 stds. CBU. POH. TIH w/ 6" bit. WOC 5 hrs. RIH tag TOC @ 10,570'. Drl cmt 10,570'-10,627'. C&C mud. 9/18/88 C&C mud. POH. Found 3 stand error in tally. RIH. Drl cmt f/ 10,375'-10,627'. C&C mud. POH. PU diamond bit, mud motor, MWD. RIH. 9/19/88 Fin TIH. Orient mud motor. Time drill f/ 10,627'-10,639'. Motor stalling when weight put on bit, POH. BHA. TIH. Orient motor. Time drill f/ 10,639'-10,641'. 9~20~88 Dyna-drill f/ 10,641'-10,736'. Run gyro @ 10,650'. Dyna-drill f/ 10,736'-10,768'. CBU. POH. Testing BOPs. 9/21/88 Fin testing BOP equipment-pipe rams, choke, kill manifold valves, HCR, to 3000 psi. Annular to 1500 psi. MU BHA, RIH ream 10,620-10,768'. Dr]_ 10,768'-10,894'. Surveying w/ MWD. 9/22/88 Drl 10,894'-10,913'. CBU. Run gyro. CBU. POH. BHA. RIH. Wash & ream 29' to bottom. Drl 10,913'-10,960'. 9/23/88 Drl f/ 10,960'-10,979'. POH. BHA. TIH. Wash 40' to bottom, no fill. Drl 10,979'-11,014'. Still getting magnetic interferance on MWD. Summary of Well Oper~ions Well D-30RD2 Page 4 9/24/88 Drl 11,014'-11,042'. Circ. Take gyro survey. Drl 11,042'-11,105'. Survey. Make 6 stds short trip. Tight @ 10,995'. Hole falling in. Maximum gas: 150 units. Mud wt cut to 8.1 ppg. Raise mud wt to 9.4 ppg. Circ & reaming. 9~25~88 C&C mud. POH. BHA. RIH. Drl f/ 11,105'-11,190'. RIH. Orient motor. Wash 20' to bottom. Drl 11,105'-11,190'. 9/26/88 Drld w/ motor 11,190'-11,200'. Rotated f/ 11,200'-11,222'. Attempted gyro survey. Slickline broke while attempting to POH w/ DP to shoe. Unable to work slickline loose. POH cutting slickline. Retrieve gyro @ MWD. BHA. Set MWD housing to 3/4°. RIH. Wash 35' to bottom. Drld 11,222'-11,246'. 9/27/88 Drld w/ motor 11,246'-11,343'. CBU. POH. Test BOPE. 9/28/88 RIH. Reamed 11,065'-11,343'. CBU. POH. RIH w/ motor & MWD. Drld 11,343'-11,380'. 9 / 29/88 Drld 11,380'-11,450'. Motor quit. POH. BHA. RIH, hit bridge @ 11,068'. Wash & ream 11,068'-11,100'; 11,130'-11,257'; 11,320'-11,450'. Drld 11,450'-11,454'. 09/30/88 Drl f/ 11,454'-11,496'. Pump pill, POH to 6,227'. Lost motor on drawworks. Presently repairing rig. 10/01/88 Fin changing out drawworks motor. Fin POH. BHA. RIH. Wash & ream f/ 11,165'-11,496'. Drl f/ 11,496'-11,544'. 10/02/88 Drl f/ 11,544'-11,702'. Short trip to shoe. Hole OK. Drl 11,702'-11,770'. 10/03/88 Drl f/ 11,770'-11,890'. Pump hi-vis sweep. Run MWD survey. Pipe stuck @ 11,880'. Work stuck pipe, mixing mineral oil & "EZ Spot" for pill. Summary of Well Oper~-~ions Well D-30RD2 Page 5 lO/O4/88 Mix & spot mineral oil & EZ spot pill w/ 10 BBL pill around BHA & 18.6 BBL in DP. Work pipe every 15 min, jarred & attempt to free pipe every 6 hrs, no movement of fish indicated. Jars still functioning. lO/O5/88 Cont to move EZ spot pill 1/2 BPH until drl string plugged. RU E-line. Attempt to run free point. Started taking wt @ 2500'. POH. PU sinker bars, RIH to 3000' - unable to go deeper. PU chisel tool & spang jars. RIH to 10,204' - unable to go deeper. RU & attempt to circ past tool to free plug. No success, presently waiting on coiled tbg unit to arrive from North Slope to CO drl string. Fish, jar for 40 min, wait 1 hr for jars to cool down. lO/O6/88 Jar on stuck BHA. Attempt to work torque down hole. No movement. No status report on location of coiled tbg unit as of this report. ].0/07/88 Jar on fish. Work torque down hole. Unable to move pipe. Attempt to circ. Press up to 2000 psi had slight movement, increase press to 2500 psi, had some returns @ surface. Packed off in MWD, press increased to 3500 psi. Resumed jarring on fish. RU WL unit, make up free point assy w/ 35' sinker bar. RIH. Tool slowed down to a creep @ 3200'. POH. Remove free point indicator. RIH to top of MWD DC @ 11,806'. POH w/ sinker bars. lO18/88 Fin POH. LD 1-3/8" sinker bars & collar locator. PU 1" free point assy. RIH. Found free point @ 10,886' DIL @ the bottom of the up jar. MU & RIH w/ DC perf assy. Load w/ 5 shots, locate & perf 11,797'-11,799' WLM. POH. All shots fired. PU kelly. C&C mud. Isolate & capture mineral oil contaminated mud in reserve pit. Total captured, counting original 50 BBL, 214 BBL. Built volume. Jar on fish. RU WL & collar locator, & free point indicator. RIH. Found free point @ 10,886' at bottom of up jars. POH. PU string shot. RIH. Back off drill string @ top of the up jars @ 10,873' WLM, 10,879' DPM. POH & RD WL. POH w/ DS. 10/9/88 Fin POH. LD 102 jts grade E DP. PU S-135 DP. RIH to 10,811'. Wash f/ 10,811' to TOF @ 10,873'. Screw into fish. Jar on fish. RU WL. Run free point & string free @ 10,873'. POH. PU kelly, jar on fish while circ. 10/10/88 Jar on fish. Run free point, found free point @ 10,800'. Jar on fish. RIH w/ severing tool. Sever pipe @ 11,511' WLM. POH. Tool stuck in jars. Pull out of rope socket. Jar on fish. TIH w/ 1-5/8" bit. Jarred sinker bar to 11,035' Severing tool clear of jars. Circ & work pipe. RU cementers. Mix & pump ~4 sx cmt w/ additives, displace w/ 80 BBL mud. RIH w/ severing tool Summary of Well Oper~-~ions Well D-30RD2 Page 6 to 10,620'. Work to 10,780'. LD severing tool. PU 1-5/8" bit & 1-3/8" sinker bars. RIH w/ same on WL. 10/11/88 RIH w/ chisel & jars on WL, worked same to 10,825'. POH. Attempt blind back off, lost 25,000# from pick up wt, screw back in. RIH w/ string shot, attempt back off @ 10,852'. String shot failed. POH. RIH w/ new string shot. Back off @ 10,852'. POH. Left screw in sub, bumper jars, oil jars in hole. TOF @ 10,852'. RD WL. PU 6" bit, RIH. Wash & ream 10,584'-10,852'. C&C mud. POH. 10112188 PU plug catcher. RIH to 10,840'. Circ DP capacity. RU cementers. Mix & spot 31 sx of 17.4 ppg cmt. Displace w/ 81BBL 9.7 ppg mud. Pull 2 stds, shear plug. CBU. POH. Test BOPE equip. Test BOPEs to 3000 psi, annular to 1500 psi. Run 11 DC in hole. WOC. 10/13/88 WOC. TIH. CBU. Tag TOF @ 10,852', no cmt, POH. PU plug catcher. TIH to 10,845'. CBU. Mix & pump 31 sx Class "G" w/ additives @ 17.4 ppg for bal plug. Cmt in place @ 0330 hrs 10/14/88. Circ. POH. 10/14/88 Fin POH. LD plug catcher. TIH w/ bit. WOC. RIH tag cmt @ 10,811'. Drl cmt f/ 10,811'-10,835'. Cmt soft. POH w/ bit. RIH w/ plug catcher. Mix & spot 31 sx Class "G" w/ additives for hal plug. Cmt in place @ 0240 hrs 10/15/88. CBU. POH. 10/15/88 Fin POH. RIH w/ bit. Tag bridge @ 10,613'. CBU. WOC. RIH. Tag @ 10,835'. No cmt. CBU. POH. PU 2-3/8" tbg stinger. TIH to 10,832'. CBU. Mix & pump 41.5 sx Class "G" w/ additives for hal plug. 10/16/88 Fin laying hal plug. CBU. POH. PU 6" bit. RIH. WOC. TIH. Tag cmt @ 10,726'. Drl soft cmt to 10,730'. CBU. POH to 10,613'. WOC. Drl cmt to 10,750'. Cmt firm, CBU. POH. BHA. TIH w/ mud motor. 10117188 Fin RIH w/ mud motor & bit. Orient tool face. Drl w/ mud motor. 10/18/88 Drl w/ mud motor f/ 10,833'-10,840'. Short trip to shoe. Drl w/ mud motor f/ 10,840'-10,869'. POH. BHA. Summary of Well Open--ions Well D-30RD2 Page 7 10/19/88 Test BOP equip to 250/3000 psi. Test Hydril to 250/1500 psi. RIH w/ bit #15. Wash & ream 10,750'-10,869'. Drl 10,869'-10,975'. 10/20/88 Drl 10,975'-11,007'. Short trip to shoe, OK. Drl 11,007'-11,069'. 10/21/88 Drl 11,069'-11,128'. CBU. POH. RIH. W&R 11,079'-11,128'. No fill. Drl 11,128'-11,136'. POH. Looking for washout. 10/22/88 POH. Found washout in DC connection. RIH. Drl 11,138'-11,215'. 10/23/88 Drl 11,215'-11,279'. ST to shoe. Drl 11,279'-11,385'. 10/24/88 Drl 11,385'-11,430'. CBU. POH. Inspecting BHA. 10/25/88 Fin inspecting BHA. Test BOPE 250/3000 psi. Annular 250/1500 psi. BHA. RIH. 4' fill. Drl 11,430'-11,519'. 10/26/88 Drl 11,519'-11,610'. Drl 11,610'-11,696'. Reamln§ connections to drop angle. 10/27/88 CBD. POH, BHA. RIH. Ream 11,600'-11,646'. Dr1 11,646'-11,685'. 10/28/88 Dr1 11,685'-11,770' (top of G-zone). ?ump hi-¥is sweep. ?OH. ~D I~ & monels. MU minimal BHA. PU new jars. RIH. 10/29/88 RIH. Drl 11,770'-11,822'. POH to shoe so production can fix leaking cooling valve. RIH to 11,727'. W & R to 11,822'. Drl 11,822'-11,864'. 10/30/88 Drl 11,864'-11,925'. ROP dropped. CBU. POH. MU new bit. RIH. Summary of Well Oper~ions Well D-30RD2 Page 8 10/30/88 Fin RIH. Drl 11,925'-12,051'. POH to 7" csg shoe. Troubleshoot EMD. 11/01/88 Pull into 7" csg. Repair electrical system. RIH. Ream 11,719'-11,760'. Hole attempting to pack-off. Raise MW f/ 9.9-10.1 ppg. W&R 11,760'-12,051'. Drl 12,051'-12,127'. 11/o2/88 Drl f/ 12,127'-12,164'. DP stuck while PU after drlg 2' into a drlg break. Jar on stuck pipe. Spot mineral oil around BHA. Jar on pipe. Perform blind backoff. Retrieve DP screen. Screw back into fish. Appeared to have backed off @ 1725' & 2650'. Work pipe. RIH w/ 1-3/8", free point indicator, couldn't pump past 10,800'. POH. RIH w/ 1" free point indicator. 11/03/88 RIH w/ free point indicator. Drl string 90% stuck in down jars @ 12,028', 100% free at up jars @ 12,025'. Jar down attempt to free top stabilizer no success. RIH w/ string shot, attempt to backoff @ 12,025', no success. MU a new string shot backoff @ 12,006' to up jars. RU cementers. Mix & spot a bal plug of 62 sx Class "G" w/ additives. CIP @ 2000 hrs 11/3/88. Pull up to 7" csg. CBU. POH. Test BOPE to 3000 psi, annulus to 1500 psi. 11/04/88 PU BHA. RIH, WR 11,617'-11.730'. Hole bridged over. Worked pipe free. C&C mud. POH to 11,450'. WR to 11,758'. Drl cmt 11,758'-11,840'. Time drl 11,804'-11,853'. Drl 11,853'-11,867'. 11/05/88 Drl 11,867'-11,870'. Time drl 11,870'-11,879'. Short trip to csg shoe. RIH. Time drl 11,879'-11,890'. Drl 11,890'-11,896'. TOH to 7" csg shoe. RIH. Ream 11,828'-11,896' for safety. Drl 11,896'-11,903'. 11/06/88 Drl 11,903'-11,906'. POH to 11,892'. Ream 11,891'-11,906'. Time drl 11,906'-11,909'. Drl 11,909'-11,951' (sidetracking old hole). POH to 7" shoe. RIH. CBU. POH. BHA. RIH. 11/07/88 RIH to 11,876'. WR 11,876'-11,951'. Drl 11,951'-12,028'. Short trip to 7" shoe. Had 40,000# drag 11,095'-11,035'. RIH. WR 11,970'-12,028'. Drl 12,028'-12,066'. Short trip to 7" csg shoe. No tight spots. RIH. Wash 11,760'-11,769'. Summary of Well Oper~-~ions Well D-3ORD2 Page 9 111o8188 Ream @ 11,760'. Appeared to drl new hole 11,760'-11,810'. POH 2 stds. Work DP through tight spot. RIH to 12,034'. WR 12,034' - 12,066'. Drl 12,066'-12,117'. Short trip to 7" csg shoe. RIH. Tag @ 11,768'. PU kelly work pipe. Fell through to 11,810'. Work pipe & fell into old hole. Ream stabilizers through tight sopt. Drl 12,117'-12,145. Short trip. 11/09/88 Fin TOH to 7" shoe. RIH. Tag @ 11,771'. Work pipe to 11,781'. Attempt to work pipe deeper into long hole. Wash 11,778'-11,810'. Drl 11,810'-11,828'. Short trip to 7" shoe. RIH to sidetracked hole @ 11,828'. Drl 11,828'-11,846'. Short trip to 7" shoe. Drl 11,846'-11,874'. 11/10/88 Drl 11,874'-11,878'. Short trip to 7" shoe. Drl 11,878'-11,899'. CBU. POH. Test BOPE 250/3000 psi. Test annular 250/1500 psi. TIH. 11/11/88 TIH. Drl 11,899'-11,907'. Short trip to 7" shoe. Drl 11,909'-11,916'. Short trip to 7" shoe. Drl 11,916'-11,955'. 11/12/88 Short trip to 7" csg shoe, tight 11,626'-11,720'. Drl 11,955'-12,006'. Tag TOF @ 12,006'. Ream 11,884'-12,004' to undercut below TOF. No success. CBU. POH. 11/13/88 RIH w/ pendulum assy. Ream 11,880'-12,004'. Ream 12,004'-12,006' to get past TOF. Drl 12,006'-12,038'. 11/14/88 Drl 12,038'-12,042'. Short trip to 7" csg shoe. Drl 12,040'-12,048'. Stabilizers on fish & drillstring causing torque increase. Attempt to work stabilizers past TOF, no success. POH. Back ream 11,809'-11,789'. Back ream @ 11,523', 11,480', 11,422', & 11,274'-11,143'. 11/15/88 Back ream up to 10,995'. POH. Check BHA. PU bit & string reamer. RIH. Ream 10,934'-11,260'. 11/16/88 Ream 11,260'-11,440'. CBU. Short trip to 7" shoe. Ream 11,440'-11,475' Bit started taking out. Appears to be sidetracking. POH. PU 5 its 2-3/~" tbg & RIH. Wash 11,650'-12,000'. CBU. Summary of Well Ope ~r~ions Well D-3ORD2 Page 10 11117188 CBU. Mix & spot 187 sx Class "G" w/ additives for a bal plug 12,000'-11,400'. Pull 15 stds. CBU. POH. RIH. CO cmt stringers 10,300'-10,850'. 11/18/88 Wash 10,850'-11,479'. CBU. POH. PU 5 jts 2-3/8" tbg. RIH. Mix & spot 154 sx Class "G" w/ additives for hal plug. POH to 10,329'. CBU. WOC. 11/19/88 WOO. RIH. Tag cmt @ 11,077', CBU. Mix & pump 200 sx Class "O" for hal plug. POH. Inspect BHA. RIH. 11/20/88 TIH to 10,659'. Wash 10,654'-10,834'. Dr1 cmt 10,834'-10,838'. CBU. ?OH. RIH w/ OEDP. Mix & pump 112 sx Class "G" w/ additives for bal plug. POH to 10,150'. CBU. POH. RIH w/ bit. 11/21/88 C&C mud. Reduce mud wt 10.2-9.8 ppg. RIH. Wash 10,593'-10,700'. Drl firm cmt 10,700'-10,702'. CBU. POH. RIH to 10,697'. Mix & pump 140 sx Class "G" w/ additives for bal plug. POH 8 stds. CBU. 11/22/88 LD 47 jts DP. MU CO BHA. RIH. Wash 10,086'-10,317'. Drl cmt 10,317'-10,625'. CBU. POH. 11/23/88 POH. BHA. RIH w/ mud motor & MWD. Kickoff cement plug - drill 10625'-688'. 11124/88 Drilled w/ motor 10,688'-10,766'. POH. L/D motor. Test BOPE 250/3000 psi. 11/25/88 Test BOPE 250/3000 psi. Annular 250/1500. Run wear bushing. RIH. Ream motor run 10,625'-766'. Drill 10,766'-10,860'. 11/26/88 5rill 10,860'-10,868'. Short trlp to 7" csg shoe. Drill 10,868'-10,989'. Short trip to 7" csg shoe. Drill 10,989'-11041'. Summary of Well Oper~-~ions Well D-30RD2 Page 11 11/27/88 Drill 11,041'-11,049'. Short trip to 7" csg shoe. Drill 11,049'-11,104'. Short trip to 7" csg shoe. Drill 11,104'-11,195' CBU. 11/28/88 CBU. POH. M/U PDCs bit, MWD, Mud motor. RIH. Drill 11,145'-11,171'. Lost 1000 psi pump pressure. POH. Found washout in 7th std out of hole. Drill 11,171'-11,202'. 11/29/88 Drill 11,202'-11,203'. POH. MU bit #27. RIH. Ream 11,090'-11,203'. Drill 11,203'-11,299'. 11/30/88 Drill 11,299'-11,304'. Circ. Short trip to 7" shoe. Drill 11,304'-11,342'. Short trip to 7" shoe. Drill 11,342'-11,412'. 12/1/88 Drill 11,412'-11,433'. Short trip to 7" csg shoe. 15-20k drag first 4 stds. Worked thru tight spot @ 11,219' twice; no more drag. Drill 11,483'-11,506'. Short trip to csg shoe. No tight spots. Drill 11,506'-11,529'. 12/2/88 Drill 11,529'-11,615'. CBU. POH. Test BOPE to 5000 psi. L/D MWD, and monels, RIH. Wash through bridge at 11,214'. 12/3/88 Wash bridges 11,512'-11,615'. Drill 11,615'-11,676'. Short trip to csg. RIH, had tight spot @ 11,290' ream until clean. W/R 11,585'-11,676'. Drill 11,676'-11,700'. 12/4/88 Drilled 11,700'-11,748'. Short trip to 7" shoe. Drilled 11,748'-11,841' (8906'TVD) CBU. Short trip to 7" shoe. Pulled 20k over at 11,359' & 10,985'. C & C mud and raise wt. to 10.0 ppg. 12/5/88 POH. RU and run 5" liner. Centralizers hung up in 7" csg. POH. Left stop ring and 1 centralizer in hole. Fish centralizer. Lost stop ring. RIH w/BHA. Hit bridge at 11,534'. Circ. to 11,572'. Hole packed off. Jar up to 11,544'. No movement. Summary of Well Oper~ions Well D-30RD2 Page 12 12/06/88 Cont working stuck pipe. Est rotation. Worked pipe free. POH to shoe. Raised MW to 10.2 ppg. POH. Changed out jars. RIH to condition for running 5" liner. 12107188 RIH to 11,473'. Wash 11,473'-11,610'. Test hole on connection. W&R bridge 11,591'-11,595'. Wash 11,595'-11,841'. Circ hole clean. POH. Normal drag, no tight spots. MU & ran 5" liner. Hit bridge @ 11,535'. Stuck liner. Est circ & work pipe. No movement. 12/08/88 Cont to work stuck liner. Release setting tool. POH. MU speak fishing assy. RIH. Attempt to free pipe w/o success. POH. Test BOPE. PU csg setting tool. 12/09/88 RIH w/ liner setting tool. Stab in & CBU. Mix & pump 146 sx cmt. CIP 1400 hrs. POH 4 stds. CBU. POH. RIH. Tag TOC @ 10,019'. Drl 2' good cmt. CBU. Test csg & liner lap to 2825 psi. Bled to 2100 psi in 70 min. 12/10/88 Press test liner to 2825 psi dropped to 2050 psi. POH. MU mill & 3-1/8" DC's. RIH. CO 5" liner to 10,055'. CBU. RIH. Tag @ 11,407'. Drl cmt to 11,414'. Test liner lap to 3000 psi, lost 200 psi in 30 min. CBU. POH. 12/11/88 MU 7" RTTS & RIH. Set RTTS @ 10,018'. Test liner lap to 2000 psi, lost 525 psi in 30 min. Test 7" csg to 3000 psi for 30 min, OK. Circ. POH. PU 13 its 2-7/8" DP & 7" RTTS & RIH. Set RTTS @ 9608'. Est inj rate 1BPM @ 3250 psi. Mix & spot 50 sx Class "G" w/ additives. POH 5 stds. RO. Sqz 50 sx into liner lap. Final press 2750 psi. SI & monitor press. 12/12/88 Bled press. POH. MU bit & scrpaer. RIH. Tag TOC @ 9992'. Drl cmt to TOL @ 10,020'. Test TOL to 2000 psi for 30 min. Lost 30 psi. POH. PU 3-1/8" DC, 4-1/8" bit & 2-7/8" DP. RIH. CO liner 10,024'-10,090'. 12/13/88 CO liner to 11,414'. Drl cmt & float follar to 11,520'. Test csg to 5000 psi for 30 min, OK. Drl float shoe & CO to 11,540'. CBU. POH. MU bit & BHA. RIH. Summary of Well Oper~ions Well D-3ORD2 Page 13 12/14/88 RIH to 5" shoe. Break circ. W&R 11,524'-11,841'. CBU. POH to 11,802'. Pipe stuck, work pipe free. C&C mud. 12/15/88 Circ LD 9 singles. Wash to bottom. CBU. POH. LD first 9 singles. LD BHA. PU 3-1/2" liner. RIH. Wash liner to 11,841'. Circ. 12/16/88 C&C mud. Cmt 3-1/2" liner, w/ 93 sx Class "G" w/ additives. POH w/ 5 dtds. RO. No cmt to surface. POH. Test BOPE. MU 4-1/8" mill & 5" csg scraper & BHA. RIH. Polish 5" PBR 10,018'-10,043'. RIH. Tag to 3-1/2" line @ 11,370'. No cmt on top of liner. CBU to test TOL. 12/17/88 CBU. Test 3-1/2" liner lap to 2000 psi, lost 125 psi in 30 min. POH. RU E-line. Run CET 11,370' to surface. 12/18/88 Run gyro 11,370' to surface. PU 2.80" cmt mill & 2-3/8" slim hole BHA. RIH. CO cmt stringers 11,445'-11,757'. Drl firm cmt 11,757'-11,815'. 12/19/88 Drill firm cmt 11,815' - 11,836'. Test liner lap to 2000 psi. Lost 150 psi in 30 min. Displace mud w/ FIW. Circ FIW until clean. Test liner lap to 2000 psi. Lost 75 psi in 30 min. Circ FIW. Spot 40 bbl FIW w/ 3% KC1 11,836' - 9700'. POH. L/D 2-7/8" DP. 12/20/88 Fin POH. MU PBR polishing mill. RIH. Polish PBR 10,031'-10,050'. Well started flowing. Mix & pump 9.0 ppg NaC1 brine. Monitor well. No flow. POH. Run CBL 11,712'-11,366'. 12/21/88 Fin CBL. Monitor well. RIH w/ 7" RTTS & 2-7/8" stinger. Set RTTS @ 9992'. Attempt to est inj rate. Press up to 2300 psi. No leak off. Test 7" x 3-1/2" annulus to 2300 psi. POH. MU 5" RTTS & RIH. 12/22/88 RIH. Set RTTS @ 10,819'. Est inj rate 2/3 bpm @ 4400 psi. Mix and spot 50 sx cmt. Squeeze 20 sx behind 3 1/2" liner top. Final rate 1/9 bpm @4800 psi. Held 3000 psi on cmt for 4 hrs. Release.~pkr. RO. POH PU 4 1/8" mill & csg scraper. RIH. Summary of Well Oper.~ions Well D-30RD2 Page 14 12123188 Drl hard cmt 11,.084'-11,350' CBU. Test csg to 2000 psi 15 min. Lost 275 psi. Drl cmt 11,350'-11,360'. 12124188 Drl hard cmt 11,360'-11,370'. CBU. POH. Test BOPE. MU seal assy & DST equip & RIH. Unable to get seals into PBR. POH. Bullnose on bottom of seals = 4.25" OD same as PBR. RIH w/ 5" RTTS & DST tools. 12125188 Fin RIH w/ 5" RTTS & DST tools. Set RTTS @ 10,160'. Dry test 3-1/2" liner top. POH. No flow on dry test. PU 2.75" cmt mill. RIH. CO 3-1/2" liner, 11,373'-11,836'. 12/26/88 Circ to clean csg. Well started flowing from back side of 5" liner. WT up to 9.0 ppg w/ NaCl. Mix & spot 9.0 ppg FIW w/ 3% KCl across 3-1/2" liner. POH. 12/27/88 POH w/ 2.80" cmt mill. NU Otis "BWD" perm pkr and BOT seal assembly. RIH. Could not pass muleshoe more than 1' into PBR. Could not work deeper. POH. MU 4.176" polishing mill. RIH. Polish PBR. CBU. Had a fair amount of scale in returns. POH. 12/28/88 POH w/ polishing mill. RIH w/ 2.8" mill. Circ until fluid clean. Spot 20 bbl of 9.0 ppg brine w/ 3% KC1 in 3-1/2" and 5" liners. POH. MU pkr and PBR seals and RIH. 12/29/88 RIH w/ pkr assembly. String seals into PBR. Tested PBR seals to 2,000 psi. OK. Set pkr @ 10,008'. Shear out of pkr. Pressure tested pkr, PBR seals 5" liner, 3-1/2" liner to 2,000 psi w/ no bleed off. POH. L/D DP. MU completion string and RIH. 12/31/88 Ran total of 314 jts 3-1/2", N-80, ABN MOD Butt tbg. GLM's and SSSV-stab into packer & space out. Test hanger seals to 2,000 psi. ND BOPE. NU xmas tree. 01/01/89 Finish NU xmas tree and test to 2,000 psi. RELEASED RIG @1200 hfs 12-31-88. RU and run PDK-100 from 11,836' - 11,000'. RU to unload well. FINAL REPORT. em/42B/OE37 Unocal Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska District DOCUMENT TRANSMITTAL January 17, 1989 HANO DELIVERED TO: John Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COHMISSION Transmitting as Follows: ~e~ar,,di.n,g: Trading Bay Field - A-16RD ' ~'-.. One (1) cooy of listings for-'ta~es--~eviously sent (12/21/88) Regarding: Trading Bay Unit, HcArthur River Fie,~l~d - D-~~.D?~/2~___~ One (1) sepia and one (1) blueline: Acoustic Cement Bond Log/VDL/Signature/Gamma Ray PDK-lOO/Gamma Ray/CCL One (1) magnetic tape with listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THAI%I{ YOU. RECEIVED 8Y: , DATED: ...................... AII~sB .0il & Gas Co~. Commisslot~ ,,,t ~chorag~l ;" Unocal Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska District DOCUMENT TRANSMITTAL January 17, 1989 HAND DELIVERED TO: Oohn Boyle FROM: R.C. Warthen LOCATION: Anchorage LOCATION: Alaska District ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting as Follows: .R, egard, i,ng: Trading Bay Field - A-16RD ~.. One (1) copy of listings for tapes previously sent (12/21/88) ' Regarding: Trading Bay Unit. McArthur River Field - D-3ORD#2 One (1) sepia and one (1) blueline: Acoustic Cement Bond Log/VDL/Signature/Gamma Ray RDK-lOO/Gamma Ray/CCL One (1) magnetic tape with listing PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT DEC 03 '88 01:~3 MOC-DOLLY VARDOMSE 9075646579 P 1/1 ! ' ~(~' ~t't%~' ~lz~'u,~ .... ,,', TEST Kill Line '~ Choke ~ine .t Kill Vails : ' .,,Lower Kell~ Cock , .~- che~J~ ,'Valve Re~3te-Operate~ Choke o~ ' : ~o~i ~i v~ira Ch~e ~2~~~_. ' m, ' ' ,.,. ------r ,~ 'i" ~ ,.., ..... _. _= L~". .... ! Pi~a Ra:~ t Closin~ {ECEI VED DEC o ~ 1988 Closing Time Opening Pressure Gas Cons, COmml~ion Opening Ti~e Blind Rams Closing Pressure Cl om.t ng Time Opening Pze$~ urn. Opening Ti~ ,_ i' 5"'"' Condi tio, n of: Pi t Level Reoorder Rig's Pressure Gauges Drilli Rate Recorder T'T--- .,m~ ,, . . , Opening Tim~ RECEIVED NOV 2 6 19I:,i~! ~ .Oil & Gas Cons, Commissioil'°ndi C.i on or~ Driller RI'¢ No. __~._~ ' TEST PRESSURES , ~. ~111 'Line .:~~= ' , Choke Va! ve~ ~ ~ ~ , ,. .=.-. :: .- .... Chbke Lt~e ~ o~ ............... Kill Val~e .~~.. .. .... ' H~dril Bag /._~0 ~ _.. cho~ ~nl~Id .~ ~ 0..,~ .... .,. ............. - Che~ Val ye ~SCEL~EOUS . ...__= ............. ~.~ ..... ._. ~ ...... I., ~ ,~, . .............. ,~ , ,,~, _~ ............. ~ ~Bt Tool ..~~~ .......... , ~e-O~r~ed choke ,, ~t~~ ~.:~....: ....... , St ze of St ~e I ' ~ L...~-.: ....... .L_ _ .... [~: ...... ~;,.;---. ~:= .... .'".~-J ...... . .- , Pipe RamS t Clos~ng Pressure Closing T~me Open,ne Pressure , O£e ni ng Time Armular ~ag: Clo.~i,g Pressure Closing Time Openin~ Pressure Opening Blind Ra~ ~ Closing , Clusing Time Opening Pressure O~ning Condition oft Pi t Level Recorder Rig's Pressure Gauges Drtlling Rate Reoo£der 0..~__ ........... . .... : ..... .. ~-~ Hill ....... .-- _____~ __..?j,~_ '. ..... ,1 II.'~i:.__l. ....... :~ ....... .' ,' ...... r ..... ' ...... ' ' i I. :.:... , September I, 1988 Tele¢opy: (907)276-7542 Mr..Roy D. Roberts Enviro~entat Engineer Union Oil Company of California P. O. Box 190247 ~%chorage, Alaska 99502 Trading Bay State D-30RD2 Union .Oil Company of California Permit No. 88-98 Sur.. Loc. 680'FSL, 1213'FWL, Sec. 6, TSN, R13W, SM Btmhole Loc. 280'FEL, 1335'FSL, Sec. 32, TgN, R13W, SM Dear Mr. Roberts: Enclosed is the approved application for permit to redrtll the above referenced well. The permit to redrlll does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work,, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so ~bmt a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. :.t~ly z)~u=~S', / / .... i/ / .: ,,..~~ :: / ?:" ?~'/ .. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF .THE CO~.~MISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Bill H. Lamoreaux STATE OF ALASKA ALASKA t,.,_ AND GAS CONSERVATION CC...;VllSSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill E~I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenI~I Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL Marathon 0il Company-Sub Operator !~06'KB above MSL feet McArthur River 3. Address 6. Property Designation G-Zone P. O. Box 190247 Anchorage, Alaska 99519 ADL - 17594 4. Location of well at surface 7. Unit .or property Name 11. Type Bond (see 20 AAC 25.025) 680'FSL, 1,213'FWL Sec. 6-T8N, R13W. Trading Bay Unit Statewide At top of productive interval 8,741'TVD; ll,650'MZ)8. Well nu.mber Number B-55502/United 1,056'FSL, 693'FEL Sec. 32, T9N, R13W. D-30RD2 Pacific Insurance Co. At total depth 12,267'MD; 9,106'TVD 9. Approximate spud date Amount 280'FEL and 1,335'FSL Sec. 32; T9N; R13W. October 1, 1988 $100,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 9,106 'TVD 8,150' feet 500' feet 5,116 12,267'MD feet 16. To be completed for deviated wells 53.75° 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 10,6251:eet Maximum hole angle 0 Maximum surface 2~859 psig At total depth (TVD) 3,840 psig 18. Casing pro~'ram Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 5" 18 N-80 Flush 1987 10,370 7,915 12267 9,106 125sx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured 11,802 ' feet Plugs (measured) true vertical feet Effective depth: measured 11,738' feet ~ (measured) Fil~' true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 3,043' 13 3/8" 1,800sx 3,043' 2,639' Intermediate 10,130' 9 5/8" 2,500sx 10,130' 7,683' Production 12,210 ' 7" 875sx 12,210 ' 9,217 ' Liner 645 ' 5" 120sx 11,848 ' 8,969 ' Perforation depth: measured true vertical See Attachment #1 20. Attachments Filing fee ~ Property plat :BI BOP Sketch [] Diverter Sketch [] Drilling program Drilling fluid program [] Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the foreg¢ing is true and c¢rrect to the best of my knowledge Signed /~ /l~p'~ by ~.. Title Environmental Enqineer Date 8/15/88 R.D. Rob~s Date_~ _.~ ~q~---~ .... Commission Use Only Permit Number I APInumber JAp ~v¢!date I See cover letter ¢[F- $~ 50- 7~3- 2~ 2~ ¢,f ~ ~ --,~. 8~/ul/88 for other requirements Conditions of approval Samples required [] Yes '~j;~No Mud log required 2-3 Yes ~'No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required wor~ '~~~ [] 5M; [] 10M; [] 15M Other: by order of Approved by ~ . ,/ , Commissioner the commission Date Form 10-401 Rev. 12-1-85 Subrf n triplicate ATTACHMENT #1 WELL D-30RD EXISTING PERFORATIONS G-1 G-2 G-3 G-4 G-4 G-5 11,540' - 11,570' MD 11,600' - 11,617' MD 11,672' - 11,692' MD 11,733' - 11,753' MD 11,812' - 11,830' MD 11,954' - 11,974' MD 8,760' - 8,780' TVD 8,801' - 8,813' TVD 8,850' - 8,864' TVD 8,891' - 8,905' TVD 8,945' - 8,957' TVD below plug 9,041' - 9,055' TVD 0S13:78 MARATHON. OIL DOLLY VARDEN COMPANY PLATFORM BOP STACK Flowline U 13 5/8'x 5000 psi Annular Preventer o ~ Clamp Connector o o ' ~~1 ! i i ~ ~ iii i (~ 3" Howco Lo Torque 5000 psi Valve All Flanges are 3' 5000 psi Remote Adjus.table Choke 3/4' Manual Choke Pressure Sensor 'MARATHON OIL COMPANY DOLLY V ARDEN PLATFORM CHOKE MANIFOLD Valve 3' Vent Line I 1/2' Manual l_Choke . o 3' Bull Plug 2' Blind Flange 6' to Shaker Rig Floor Choke Line 3' 5000 psi MARATHON OIL COMPANY WELL PROGRAM Well: Dolly Varden Platform Well D-30RD2 Field: McArthur River AFE: 8228-8 Coordinates: Surface: Top of Objective: KB Elevation: Total Depth: Max Angle: Course: 680'FSL, 1,213'FWL Sec. 6, T9N, R13W, S.M. 8,741'TVD: 1,056'FSL, 693'FEL Sec. 32, T9N, R13W S.M. 106.2'MLLW 9,106'TVD, 12,267'MD 53.75° N56°E GEOLOGIC PROGRAM Coring: None Planned DST: Cased Hole DST of G-Zone for completion planning Logging: DIL/GR SP/LSS FDC/CNL DRILLING PROGRAM Pull Completion assembly. Abandon existing perforations. Mill section in 7" casing from 10,620' - 10,690'. Sidetrack and drill 6" hole to 12,267'MD. Run and cement 5" liner. DIRECTIONAL PROGRAM Kickoff at 10,625'MD. Build and turn to 48° at N56°E. Continue building to 53.75° at 8401'TVD (ll,075'MD). Hold angle to TD. CASING PROGRAM Size Set at Wt. Grade THD Hole Size Cement Production: Liner: 7" 10,620' 29 N-80 BTC In Place 5" 12,267' 18 N-80 Flush 125sx (25% excess over caliper vol.) with 250' lap into 7" csg. MUD PROGRAM From 10,625 To Wt. Vis. W.L. ,, 12,267 9.0-9.5 35-45 6-8 PH 9.0-9.5 .Type Mud Water Based Copolymer System 0S13:76 Trading Bay Unit Well D-30 RD Proposed Abandonment Schematic 13-3/8' 61 ~ K-55 ~ 3043' 9£5/8,. 47~ N-80 ~ 10,130' Window in 7'. csg. 10,620-10,690' Btm of Kickoff Plug 8 10,800' Top of Cement ~ .11,!00' EZSV. Retainer~ 11,150' Top of 5'. Liner.~ 11,203' Top of Cement 4 11,440' (-50sx) 5' 18~-N-80 FL4S Liner ~ 11,848' 7' 29~ N-8OBTC ~ 12,210' Perforation (DIL). 11,540-11,570' G-1 11,600-11,617' G-2 11,672-11,692' G-3 11,733-11,753 G-4 11,812-11,830'. G-4 11,802' PBTD (1.1,861' DIL) 11,895' Otis WD Pkr (Obstruction on Pkr) 11,908' Bell Guide 11,954-11,974' G-5. 12,108'-Initial PBTD 13 + 24 ............ W.~RILAId' UNIT-4 TRADING BAY UNIT BOUNOARY ,I- ............. * ......... * ................ ~ '--T ................... ~-- 15 t , -t- 'i' * I *i' $ + -t- 5 23 -t' 13 ARIA i..-, '~"~"~'~i~'~? ':'~ ....... :""~: _~ · -.- ,' . _ KU,YAYAN-IA .+ 20 ........... ..i r ............. 16 *i* I 'f' -t- i I I o WILL LOOATI(W )' IdlC~I GIL WILL I + ~ ~IW~ ~ A~~ ~ OIL IHOW ~ UktI IAI F~OD~U ~ DRY flOLI ~ ~TPORI MARATHON OIL COMPANY ,, TRADING BAY UNIT i:Mc*ARTHUR RIVER FIEI'D ii! '. ~ , · ; ~,~, HORIZONTAL VIEW MARATHON OIL COMPANY D20 REBRILL ~ CLOSURE: 7546 ft N 38,2 E SCALE i inch = 400 feet DRAWN 6-i5-88 7200 7000 6800 8600 6400 6200 8000 5800 ~ 5600 5400 5200 5000 4800 4800 4400 2800 ~800 3000 3200 3400 3800 3800 4000 4200 4400 4800 4800 5000 7800 7950 8t00 8250 8400 8550 8700 9850 9000 9t50 9200 9450 9600 9750 9900 5600 VERTICAL SECTION MARATHON OIL COMPANY 030 REDRILL 2 SECTION AT N 56.00 E TVD SCALE: i inch: 300 feet OEP SCALE: t inch: 300 feet DRANN : 6-t5-88 575O 5900 6050 6200 6350 6500 6850 6500 Oeparture 6950 7100 7250 740O CHECK LIST FOR NEW WELL ITEM APPROVE DATE (1) Fee (2 thru 8) (9 thru 13) (10 and 13) (4) Casg fff,~,/f/~, f-f~'-M~ (14 thru 22) (23 thru 28) (6) OTHER 'G~9 thru 31) (6) Add: Geolog.y: RPC~ BEW~~- EngSn~ee~ring: LCS BEW rev: 08/11/88 6.011 PERMITS 1. IS /~7/{(¢-~:t o;'/ ~x~. ~/~ ~~'- Lease & Well No. Company ~ YES NO the pe~it fee attached .......................................... ~ 2~ 3. 4. 5. 6. 7. 8. Is Is Is Is Is well to be located in a defined pool ............................. well located proper distance from property line .................. well located proper distance from other wells .................... sufficient undedicated acreage available in this pool ............ well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day.wait ...................... ~ e 10. 11. 12. 13. Does operator have a bond in force .................................. /~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... /~ - .. 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~f~_ Are necessary diagrams and descriptions of ~ a~ BOPE attached.~ Does BOPE have sufficient pressure rating - Test to ~O~o psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. POOL Additional requirements ............................................. Additional Remarks: ~A~^,~z~--,~ ~~-~/~-~ ~3 ~z~/~/~-/ INITIAL GEO. ~IT ON/OFF ~;~ rg~;~ ~ D~))- o. Lo~w~ ~;/7 s~:G /~-~ CLASS STATUS A~ NO. SHO~ 0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. PROGRAM: LIS REVISION: PART Start of ~xecution: Mort 9 ,J~N 8'~ 2:4to W=LL~ DATA, =ILE:, W!3366~..~. WDF ECC: 3662.00 CgMPANY NAME: MARATHON OIL WELL NAME: D.S. D-SO RD FIELD: TRDAING BAY LOF'~:TTnN:.. . ,~ 1472.. Too o'f Well: 1095'7.00q 8ottom of Well: 11a5q¢.O0n,~ Level Spacing: 0.500 NUMBER OF CURVES: 20 DEPTH ~-KL E;K~ rCL GR iSS LS MON RIN S G ~I ,~ SPD SS CSS G1 G2 G=IS MSD R~TO RBOR RICS COMP.,~NY: MARATHON OIL WELL:D.S. D-30 RD mEELO:TRADiNG BAY COUNTY: K ENA I STaTE:ALASKA · TAPE INFORMATION FTLE :PA.SS 1,001 .Oil & Gas Gens. '' ~mhorage miL= TNT¢-RVA~ : ST&RT= 11o55 00© '~"' BKL GR MON M % D $ 6 M~g C S$ I S S BKS q'~TO RIC$ RiN RBOR 0,000 47,187 523,948 849,915 !~,S05 11655.000 0.000 15.99~a 40.238 569.697 23a.077 t4.765 11455.000 1o 709 1 35 ~05 126.066 22.05? 11255.000 0.030 16.098 32.945 557.400 265.542 !4,300 11055.000 0.000 16.998 63.249 533.729 250 112 PO P2q 10267.000 0 000 1 o. o03 63.106 504,950 170.9E~2 23,695 WELL DATA FIL;:~ W0366~. _.',*in~u, ECC: 3562.C0 COMPANY N&ME: WELL N&ME: PlELD: LOCATION: Too of Well: Bottom of Well: Level Spacing: MARATHON OIL D.S. D-30 RD TRDAING 8AY 1472 !9973,000 11845.000 0.500 3sOo 670 ~7~75 270 O.1Sa t4,9~5 10.477 11.592 2964.753 &3955,770 0.113 15.340 t!,474 11.72~ 2!5~7.850 995C9.130 30947.000314798.600 1.355 18370. 79019010o. '?00 27760.75031 q5t ~. ?,OO 1 .365 1235.36'7 27215.660 7915.o14 81547.~!0 0.566 21.136 16861.7102952~6.600 17.512 14.587 I .51~ 2734.705 39363.030 ¢. f-i,-:; 7 14 55~ 13.476 11 .2t~ 15B5,037 32017.850 0.216 23.1S~ 17.001 11 .777 lP79 87~ ~0326 970 0.744 24.434 17.959 t1.$36 I 667o. 240104576. 600 2611 5 . 430331 043.700 1.502 881 S · 1 551 O~ 372 · 1 O0 205 ~4 · 3 90349948. 400 I ,557 7 5 ~_;,9 · 2421 09059 · 1 O0 I 959S. 040351 954. 900 1 .003 $200.1 '76 129.987 66&0. 746 51.94~ · ,.:~ . ~ 59.703 63~5.094 6~.105 1919.781 0S.204 1479.853 179.982 NUMBER. OF CURVEq:¢ 2nu DEPTH 8KL BKS CCL GR ISS LS MON RIN SGMA SPD SS C~S G1 G~ GE!S .. MSD RATO RBOR RiCS FiLE:PASS2 ,go2 FILE INTERVAL: START= 11845.000 ~N3= 10973.000 DEPT 11845.000 4 103 CCL BKS .000 .61° .896 SPD LS SS G! GElS MON MSD SGM~ CSS ISS R&TO RiCS RIN RBOR 15.99;3 3309.069 40335.370 55.945 ,9.!92 14.186 t4 ~P? 10 44'~ tl i . -- . ~ . , '..; 22367. 770103299 . 700 31 276. 88032661 7. 400 I .371 G ~ 8799.1 21 159.9&~4 270.8~7 11445,000 4 O.O 4.5 6.0 30 71 11245.000 33 5 · 0 1.0 O0 63 tt"345.000 7 ii Uw 0 I 0973. onou 000 r' ,x -- 074 NELL DATA FILE: ECC: COMmANY NAME: WELL NAME: rIEL[): LOCATION: Top of Well: Bottom of Well: Level .Spacing: NUMBER OF CURVES: 5 DEPTH rN ¢ 17 · :594 13,215 15,672 119o.222 272;-37.370 534,496 0,322 22,452 22. 240 I 7. ,542 1 4. 520 15 tom P~'11 324 400x5 070 . .~ . ~, .~ .2 i .-, i , 565·771 0.222 16.170 !5.901 13.679 11 .427 15.996 1406.704 51 77'9.6!0 546.704 0.443 25.155 2,2. 594 17. 600 I 2. ! 6~ 15.9~8 1390 .q60 ~x666 630 517 94~' 0 3~g 24 248 24,05~ 16 ~7¢ 12 35q W33642.WDF GR2 PORC MARATHON TRaDiNG BAY I OaO0 · 009 t I 900. 000 0.500 7869.070 8,2520.440 1692e.64©29802!.000 1.504 15761.070111245.900 262~0 6003586Ol 4nO _ · ~ · ..... 1.510 7778.305110068,S00 20163.e40354872.?00 1.574 8569.1 4111 7548. 400 21577. 849364053.600 I · 5 83 1'~.17.154 82.6 o & 5436.305 93,271 1 53= 660 11 5.055 1809.319 2o9.m79 FIL$:PORO, ,003 FIL~ INTERVAL: START= 11gOO.O©O ENO= DEPT CN PORC G;~ GR2 11900,000 mP,631~.~ -999. ,250 37,447. -99o,.~,~0 11700.000 54.253 35.774 ~9.126 54.100 t1500,000 27.696 35.049 $8,3i'~- ,51.~8'? 11300.000 22.~19 29.202 40.052 11100,000 10900 000 ~2 1 . . ~, ' i 10900,000 22.!'52 -g~o, ,.?,50 57.15'-'¢, , -90¢. .2~'''''..,,~ End o'f execution: Mon ~ ,JAN 1 0900. 000 Elapsed. execd+ion
