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176-075
STATE OF ALASKA • RECEIVED ALA KA OIL AND GAS CONSERVATION COMMISSION APR 18 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well El Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 5 Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 5 Exploratory ❑ 176-075 3. Address: 3800 Centerpoint Drive, Suite 100 StratigraphiC❑ Service ❑ 6. API Number: _ Anchorage, AK 99503 50- 733 - 20296 -00 9 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017595 A MGS ST 17595 (Baker) 18 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): .. Middle Ground Shoal Field / E,F & G Oil, B,C & D Oil and Undefined gas 11. Present Well Condition Summary: Total Depth measured 10,231' feet Plugs measured 5,700' feet true vertical 8,224' feet Junk measured 3,021' feet Effective Depth measured 5,700' feet Packer measured See Schematic feet true vertical 4,914' feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural 29' 30" 29' 29' Conductor 621' 20" 621' 621' Surface 3,500' 13 -3/8" 3,500' 3,296' 3,090 psi 1,540 psi Intermediate Production 5,983' 9 -5/8" 5,983' 5,137' 6,820 psi 4,230 psi Liner 4,397' 7" 10,107' 8,128' 9,690 psi 9,200 psi Perforation depth Measured depth See Schematic feet �y� True Vertical depth See Schematic feet SCANNED APR 2 3 2013 Tubing (size, grade, measured and true vertical depth) 2 -7/8" 29# / N -80 2,518' (MD) 2,128' (TVD) Packers and SSSV (type, measured and true vertical depth) See Schematic 12. Stimulation or cement squeeze summary: T Intervals treated (measured): 2,547' - 2,562' (15 feet) / 2,921' - 2,939' (18 feet) Treatment descriptions including volumes used and final pressure: Pumped 1500 gal of nitrified surfactant followed by 500 gal of 15% HCL followed by 3 tubing volumes of nitrogen. S/I well. S/I pressure is 990 psi. 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 25 0 Subsequent to operation: 0 0 0 25 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 5 '* Service ❑ Stratlgraphic Daily Report of Well Operations X 16. Well Status after work: Oil ❑ - Gas 5 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ 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: 313 -084 Contact Ted Kramer Email tkramer(a�hilcort).com Printed Name Ted Kramer Title Sr. Operations Engineer �` Signature Phone (907) 777 -8420 Date 4/17/2013 Form 10 -404 Revised 10/2012 IM S APR 2 2 201 ( Submit Original Only • Hilcorp Alaska, LLC Hi leorp Alaska, LLC Well Operations Summary Well Name API Number IWell Permit Number Start Date End Date BA -18 50- 733 - 20296 -00 176 -075 3/16/2013 3/17/2013 Daily Operations: 03/13/13 - Wednesday 03/14/13 - Thursday 03/15/13 - Friday 03/16/13 - Saturday Rig up to perform nitrogen acid job. 03/17/13 - Sunday Hook up acid tank and nitrogen tank to pumps and prime pumps. Low pressure test on pump lines to 400 psi, pressure up to 4,500 psi for high pressure test. Test good. Bleed lines back to 400 psi to match pressure on tubing. Open sub surface valve. Open tubing and flush tubing with nitrogen (30 gal). Pressure stable at 1,300 psi. Shut down and do fall off test, 130 psi fall off pressure, stable at 1,200 psi. Start backup pumping 1,500 gal of surfactant and nitrogen, pump total of 500ga1 15 %acid back to nitrogen over displace `s.ubirag about 3 times. Shut down. Well stable at 990 psi. Close well in, put well to test lines. Start flowing well through test pack, light kicks of fluid foamy surfactant acid. RDMO. Swapped flow to blow down tank. We were unable to see an accurate fluid level in the test separator due to the surfactant soap. The well slowly bled off and out bringing fluid to surface. Watch well. Open to tank until 6pm. Shut in for pressure build up, pressure build up to 88 psi. Open well to tank, bled right off. Close well in for the night. 03/18/13 - Monday No operations to report. 03/19/13 - Tuesday No operations to report. n • • Middle Ground Shoal SCHEMATIC well #: Ba -18 Hileorp Alaska, LLC Last Completed: 12/2012 RKEt MSL =101' Mudlne 203' Water Depth= 102' B: MSL ADL: 17595 PTD: 176 -075 , � ;.*-Mean Sea Level Le 1, Slot 3 API: 50- 733 - 20296 -00 ' - TOC "' Line 9 7 A 362' ; , Casing Detail cE i L veni dill,` 0` 1 tl Size Type Wt/ Grade / Conn ID Top Btm CMT Top B 20" ° firm o Boo • i 30" Structural Surf 29' Surf 621' s �e 2445 , �, E 2 0" Conductor 85 #, B, Welded 18.25 Surf 621 CBL -very E poor cement TOF x F 3021 �\ 13 -3/8" Surface 61, 68, K55, Buttress 12.415 Surf 3,500' 382' Temp \� # T -23 Log 10C3411 T -24 9 -5/8" Intermediate 40,43.5,S -95, Buttress 8.755 Surf 5,983' * *4400' CBL 1 '' N 1 - 7" Prod Liner 29 #, 595, Buttress 6.184 5,710' 10,107' 5,710' 13-3/8" 4 ,,, 3 Tubing Detail 3,464' ____ 4 = 12 -7/8" 1 1 6.4 # /N -80 1 2.875 1 Surf 1 2,518' 1 t 3,466- 3,468' Sgzd ' = 3,494 3,507 Jewelry Detail f 3,530 -3,532' Sgzd ry No Depth Length ID OD Item " 33' 0.7' 2.44 X -0 3 -1/2" EU 8RND P x 2 -7/8" Buttress Pin 6 A 312' 5.64' 2.313 4.650 TRSV Wellstar Perfs B 2,242' 6.03' 2.375 3.750 Sliding sleeve 3,710 - 3,712' Sgzd -- "'"7 3,720 - 3,761' Open C 2,286' .43' 2.500 5.500 X/0 2 -7/8" 8rd Box x 5 -1/2" STC Pin -..: 3,790' - 3,792' Sgzd D 2,287' 5.75' 5.000 8.125 VSIX 10K Packer E 2,292' 1.60' 2.500 6.090 X/0 2 -7/8" 8rd Pin x 5 -1/2" STC Box •, ' ' F 2,363' 1.21' 2.313 3.688 X- Nipple to 3 3,439' Bridge plug with +/ -25' cement on top +'"- ©6 = 3,990' - 3,9921 sgzd 3,453' 12.99' 4.75 8.38 Baker SAB -3 Packer 4,0133,031• open 3,486' 3.52' 2.313 3.76 Otis XA Sleeve y Perfs 4 3,656' 8.69' 2.44 3.25 Otis Locator Seal Assembly 4,089'4,094' Open 3,669' 13.11' 3.25 8.125 Otis BWH Packer 4,118 , 4,130' 6421° Otis XA Sleeve (set XA sleeve packoff) (has leaked, • 3,703' 3.52' 2.313 3.76 5 intended to isolate water zone) e 3,966' 8.69' 2.44 3.25 Otis BWH Packer TOC C 4.400 4,002' 3.42' 2.313 3.76 Otis XA Sleeve T -39 6 4,754' 0.95' 4.75 6.25 Baker Seal Locator 4,757' 3.85' 4.75 6 Baker Seals IN/ Baker F-1 Packer 8.125x6.00 �� *,'�� Otis XN nipple bored to 2.25 No -go profile from 2.313 7 4,790' 1.32' 2.25 3.25 (2.313" PXN plug & prong set w/1.375" fishneck OD) I I 4,823' 1.93' 2.44 3.68 Mechanical Gun Release mi . = 40 S 4,859' 1.72' 1.5 3.68 Mechanical Firing Head °o 4,8654,863'Cpen 7 4,865' 18' N/A 5 5" Baker Tubing Conveyed Perforating Gun (TOP) a� 4,883' - -- N/A 5 5" Baker Tubing Conveyed Perforating Gun (BTM) s 700' Cat retainer • 5,700' 8.755 Cement Retainer f/ 1992 Workover 5714 6,480' 6.125 Cement Retainer w/ Cement Cover t/ 6396' Liner Top L 9S8" - roc : 6396 PBTD Perforation Data 6480' cMr Retane, Top Bottom Top Bottom (MD) (MD) (TVD) (TVD) Interval Status 2,547' 2,562' 2,482' 2,496' T -23 Open 6,576 2,921' 2,939' 2,818' 2,833' T -24 Open Oil Top G&G ' ports 3,466' 3,468' 3,270' 3,272' Squeezed 6,680' 7,445' 3,494' 3,502' 3,292' 3,298' 31 Sand Open _ �� 3,530' 3,712' 3,319' 3,453' Squeezed Sand 7635 3,720' 3,761' 3,459' 3,488' 32 Sand Open a;°aldeBP 3,790' 3,992' 3,508' 3,647' Squeezed Leaks , 4,013' 4,094' 3,661' 3,716' 34/35 Open 7680 4,118' 4,130' 3,733' 3,741' Squeezed Ddllade BP 4,582' 4,594' 4,054' 4,063' T -39 Open 40 - Perfs 4,865' 4,883' 4,264' 4,277' Open 6,749' - 9,908 Sand 8,856' 6,680' 9,920' 5,635' 7,979' B /C /G Abandoned -Cmt FII Reported Rtnr @ 5,700' T' 9,641' L N otes: PBTD =5,700' TD= 10,231' 01/2013 - Fish = 388' of 2 -7/8" tubing & wireline entry guide 0 2/92 - Good test to 2,500 psi on tubing x 9 -5/8" annulus from 3,440' to surface. MAX HOLE ANGLE = 48.9 g.∎ moot * *2/92 - 9 -5/8" CBL shows TOC at 4,400' PRIOR to squeezes. No bond log ran after squeezes. Revised By: JLL 02/15/13 • 0,P* � � j 4 ' , v THE STATE Alaska Oil and Gas '�' °fALAS� Conservation Commission _ice: GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF r R' P Anchorage, Alaska 99501 -3572 ALAS • -� Main: 907.279.1433 Fax: 907.276.7542 Stan Golis Operations Manager 2��� Hilcorp Alaska, LLC sr AHED WAR 1 3800 Centerpoint Drive, Suite 100 ��'^" fi b `' 0 7 5 Anchorage, AK 99503 Re: Middle Ground Shoal Field, B, C, D, E, F, & G Oil and Undefined Gas Pool, MGS ST 17595 (Baker) 18 Sundry Number: 313 -084 Dear Mr. Golis: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, I i 704 Cathy P. oerster Chair hot DATED this day of February, 2013. Encl. • • RECEIVED STATE OF ALASKA FEB 15 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION f 7 2,2/ 4 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon El Plug for Redrill ❑ Perforate New Pod ❑ Repair Weft ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pun Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate G ' Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. /U3 / Hilcorp Alaska, LLC Exploratory ❑ Development El - 1.76 -A7G / 7< "O ?S A�� /' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20296 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No ❑ MGS ST 17595 (Baker) 18 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017595 • Middle Ground Shoal Field / E,F & G Oil, B, C & D Oil and Undefined gas • 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), 1. • 10,231 8,224 - 5,700 4,914 5,700 30z1 - N/A -- z(Ici) Casing Length Size MD TVD Burst Collapse Structural 29' 30" 29' 29' Conductor 621' 20" 621' 621' Surface 3,500' 13 -3/8" 3,500' 3,296' 3,090 psi 1,540 psi Intermediate Production 5,983' 9 -5/8" 5,983' 5,137' 6,820 psi 4,230 psi Liner 4,397' 7" 10,107' 8,128' 9,690 psi 9,200 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic - See Attached Schematic 2 -7/8" N -80 2,815' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See Attached Schematic See Attached Schematic 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development G • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 2/20/2013 Commencing Operations: Oil ❑ Gas WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Reid Edwards Email redwards @hilcorp.com Printed Name Stan Golis Title Operations Manager Signature ,SL- l■J ( (' t Phone 907 777 -8356 Date 2/15/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS FEB 2 5 201 4' , Spacing Exception Required? Yes ❑ No IZ( Subsequent Form Required: (6 - `rQ f APPROVED BY Approved by: �fj� COMMISSIONER THE COMMISSION Date: 2 -22„ — 1 3 z .zZ /3 //��' .,,, �¢- ��\Submit Form and SO .iti) 0 itiNiAlL Approved applicati is valid for 12 months from the date of approval. Attachments in Duplicate C�\'lY • Well Prognosis Well: MGS ST 17595 -18 Hilcorp Alaska, LL Date: 2/15/2013 Well Name: MGS ST 17595 -18 (Ba -18) API Number: 50- 733 - 20296 -00 Current Status: Gas well Leg: 1 Estimated Start Date: February 20th, 2013 Rig: Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 176 -075. First Call Engineer: Ted Kramer (907) 777 -8420 (0) (907) 229 -4824 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) AFE Number: 1222506 Current Bottom Hole Pressure: — 1,085 psi @ 2799' TVD (Water gradient (.44 psi /ft) to T -25 & SITP of 30 psi and fluid level at 400') Maximum Expected BHP: — 1,231 psi @ 2,799' TVD (Water gradient to surface (.44 psi /ft) Max. Allowable Surface Pressure: — 831 psi (Based on 0.047 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Hemlock in 1977. A workover was performed in 1982 to convert the well to Hemlock water injection. A subsequent workover in 1987 recompleted the well to a Tyonek B,C & D water injector. In 1992 all the open Tyonek oil sands were abandoned and the well was worked over as a gas producer from the Tyonek T -40A sand. A plug was set in the tubing to isolate the T -40A sand in 1997 and the T -39 sand was perforated through tubing. The well had remained shut in since 1997. Recently a recompletion attempt was made by setting an abandonment plug above the existing T -31 perforations and perforating up hole to shallower gas sands T -24 and T -23. No response was seen after the perforations were added. A pump in test was conducted and showed that there was communication with the reservoir. The current plan is to pump nitrogen followed by an acid treatment into the perforations to try and remove damage in the perforations and / or near wellbore damage. Notes Regarding Wellbore Condition • Well current well status is a shut in gas well. Brief Procedure: 1. MIRU Nitrogen unit and acid pumping equipment. 2. Connect treating lines for acid pumper and nitrogen pumper to treating/flow back manifold. -- 3. RU flow back line to working tank and test to 3000 psi. NOTE: Flow back line will handle compressible Nitrogen gas and must be secured to limit movement. (Connection bracelets required) 4. Record pressures on wellhead and treating pressures with pressure recorder with 12 hr chart rotation connected to treating manifold. Test all treating lines and manifold to well to 4500 psi for 5 minutes. 5. Open well and commence Nitrogen pumping operations to displace fluid from tubing to formation. Fluid displacement through open perforations at 2428 -2450' should be noted by decrease in tubing pressure while pumping Nitrogen. • Well Prognosis Well: MGS ST 17595 -18 Hilcorp Alaska, LL Date: 2/15/2013 6. As soon as surface pressure stabilizes after step 5, shut down nitrogen pump and conduct a pressure falloff test until surface pressure stabilizes. Isolate nitrogen pump during this step to eliminate flow back through pump but DO NOT ISOLATE THE PRESSURE RECORDER FOR TREATING PRESSURE. After pressure at surface is stable for 5 minutes proceed to step 7. 7. Open treating line from nitrogen pump and put back on line at rate established in step 5 above. 8. Maintain pump in rate constant throughout remainder of job. Recording injectivity tests for nitrogen. 9. Start injecting surfactant (after nitrogen is entering perforations) with acid pumper at % bpm with continuous nitrogen injection. Pump total of 150 gallons of surfactant and displace through perfs. Note: start and stop times on job log and pressure chart recorder on treating manifold. 10. Use acid pump to inject 500 gallons of 15% NE HCI acid with pH buffer through perforations as rates sufficient to maintain maximum treating pressure of 3000 psi. Over displace acid through perforations with Nitrogen pump rate established in step 5 above. Over displace with Nitrogen until nitrogen supply depleted after acid leaves perforated interval. 11. Shut down and isolate all pumps from treating manifold and record pressure falloff on chart recorder at treating manifold in like manner to step 6 above. Record and report isip and time when pressures fall off in 50 psi increments. This test should be shorter than the first fall off test land will provide a measure of treatment improvement. Forward pressure chart to asset team engineer. 12. Confirm that all treating lines are isolated from treating manifold and bled off. Shut down all pump systems and isolate /bleed treating lines from treating manifold. DO NOT rig down treating lines during fall off test. 13. Open flow back valve on manifold to vent pressure from well through well test equipment to working tank at maximum surge rate possible to back flush perforations. Neutralize flow back with soda ash as needed to neutralize spent acid in working tank. 14. Monitor well for cleanup and switch to test line for 2 hr flow test through orifice well tester as possible. 15. SECURE well and RDMO treating equipment. 16. Flow well to test system. Perform 4 point test on well. Attachments: 1. As -built Well Schematic • ill Middle Ground Shoal SCHEMATIC well #: Ba -18 Hiilcorp Alaska, LLC Last Completed: 12/2012 RKa MSL =101' Mudlirlc 203' \ Water Depth= 102' „ \ ,„ KB: MSL ADL: 17595 PTD: 176 -075 =;,! ' * -Mean Sea Level ' F ;. ud Line Leg 1, Slot 3 API: 50 733 - 20296 - 00 4 '1 TOC ©, 30" - A 367 __, Casing Detail very -- 'Millar NY . I i' ° Size Type Wt/ Grade / Conn ID Top Btm CMT Top B 20" , D MTN c Hoc ' 30" Structural 29 Surf Surf 2445 R ' r 621 :` ' • { ® ®� ''X44. „ r 20" Conductor 85#, B, Welded 18.25 Surf 621' CBL - very r e poor cement TcF F4'y�• ° © i j ti + 13 -3/8" Surface 61, 68, K55, Buttress 12.415 Surf 3,500' 3021 „, 382' Temp - -0 ° Log ri T-23 * *4400' TOC3411 T -24 9 -5/8" Intermediate 40,43.5,S-95, Buttress 8.755 Surf 5,983' CBL ,. as 4.4 :1 : 1 . „� * rr. A: 7" Prod Liner 29 #, 595, Buttress 6.184 5,710' 10,107 5,710' 13 -3/8' !„ p 3 yi Tubing Detail 3' i 4 '3,466 - 3.466' Spa/ 1 2 -7/8" 1 1 6.4#/N -80 1 2.875 I Surf I 2,518' 1 `'^ 3630 3,532' Jewelry Detail ' � �' ' No Depth Length ID OD Item 33' 0.7' 2.44 X -0 3 -1/2" EU 8RND P x 2 -7/8" Buttress Pin '.xy 5 A 312' 5.64' 2.313 4.650 TRSV Wellstar `= II A '(; 3,710' 3,7f - 3,717 Sgad 8 2,242' 6.03' 2.375 3.750 Sliding sleeve ,72a-37s1' Wr+ C 2,286' .43' 2.500 5.500 X/0 2 -7/8" 8rd Box x 5 -1/2" STC Pin .� - �..3 -a Sod D 2,287' 5.75' 5.000 8.125 VSIX 10K Packer E 2,292' 1.60' 2.500 6.090 X/0 2 -7/8" 8rd Pin x 5 -1/2" STC Box . s'/ `- F 2,363' 1.21' 2.313 3.688 X- Nipple .i t''+ EMI 1a F�rfs 3 3,439' Bridge plug with +/ -25' cement on top 6 3 990 - 3, 992' Sqzd 3,453' 12.99' 4.75 8.38 Baker SAB -3 Packer 4, Open 3,486' 3.52' 2.313 3.76 Otis XA Sleeve ° p 4 3,656' 8.69' 2.44 3.25 Otis Locator Seal Assembly 4,069'3,094Cpen 3,669' 13.11' 3.25 8.125 Otis BWH Packer ff f 4 4 Sq.rd A� 3,703' 3.52' 2.313 3.76 Otis XA Sleeve (set XA sleeve packoff) (has leaked, 5 intended to isolate water zone) 3,966' 8.69' 2.44 3.25 Otis BWH Packer TOC ar ' r !' 4,002' 3.42' 2.313 3.76 Otis XA Sleeve .'' .* rr° T -39 6 4,754' 0.95' 4.75 6.25 Baker Seal Locator -, .,�„ ,� 4,757' 3.85' 4.75 6 Baker Seals IN/ Baker F -1 Packer 8.125x6.00 . �"/ I�..w: '4.! 4,790' 1.37' 2.25 3.25 Otis XN nipple bored to 2.25 No -go profile from 2.313 1 7 (2.313" PXN plug & prong set w/1.375" fishneck OD) . x. 4,823' 1.93' 2.44 3.68 Mechanical Gun Release IIP Sand 7 4,859' 1.72' 1.5 3.68 Mechanical Firing Head w • ' 4'ess3'6ea'ope 4,865' 18' N/A 5 5" Baker Tubing Conveyed Perforating Gun (TOP) retri ner , 4,883' N/A 5 5" Baker Tubing Conveyed Perforating Gun (BTM) Cot retai s �° ,, -- 5,700' 8.755 Cement Retainer f/ 1992 Workover 0 � 571 ..� - r 6,480' - -- 6.125 Cement Retainer w/ Cement Cover t/ 6396' Liner Tapk, *li ( q TOC: 6396 PBTD cT *f A S Perforation Data 6,480 y „, a/. CMT Retainer 1r Top Bottom Top Bottom ' r 1' . (MD) (MD) RD) (TVD) Interval Status ' IM F Ir " s _ 2,547' 2,562' 2,482' 2,496' T -23 Open wok _ _ 6 . . .576 �'> 405 2,921' 2,939' 2,818' 2,833' T -24 Open amp G&G TA Pe'fs 3,466' 3,468' 3,270' 3,272' Squeezed 6,6e7 7,445' 3,494' 3,502' 3,292' 3,298' 31 Sand Open Sand one ' 3,530' 3,712' 3,319' 3,453' Squeezed 4 7 . 1'„ 3,720' 3,761' 3,459' 3,488' 32 Sand Open Divade BP t. - 3,790' 3,992' 3,508' 3,647' Squeezed Iv ir Leale ' -. � - : 4 1 . : ' . ,,j 4,013' 4,094' 3,661' 3,716' 34/35 Open 7,660' r •A981 19 . 1 %Al 4,118' 4,130' 3,733' 3,741' Squeezed Dillatle BP ,7 4,582' 4,594' 4,054' 4,063' T -39 Open Fein 4,865' 4,883' 4,264' 4,277' 4a Open - 6749 9908 Sand 6, y iz, 6,680 9,920' 5,635' 7,979' B /C /G Abandoned - Cmt FII Reported y r :x}�2�g,, Rtnr @ 5,700' t T' 9,641 Notes: PBTD x,700' TD = 10,231' 01/2013 - Fish = 388' of 2 -7/8" tubing & wireline entry guide 0 2/92 - Good test to 2,500 psi on tubing x 9 -5/8" annulus from 3,440' to surface. MAX HOLE ANGLE = 48.9 A moor "2/92 - 9 -5/8" CBL shows TOC at 4,400' PRIOR to squeezes. No bond log ran after squeezes. Revised By: JLL 02/15/13 RECEIVED STATE OF ALASKA • FEB 15 2013 AI& OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Perforate El Other El Run Completion Performed: Alter Casing ❑ Pull Tubing 0 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 El Exploratory ❑ 176 -07“O 75 a ' l 4 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: r Anchorage, AK 99503 50- 733 - 20296 -00 " 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017595 ' MGS ST 17595 (Baker) 18 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — Middle Ground Shoal Field / E,F & G Oil, B,C & D Oil and Undefined gas 11. Present Well Condition Summary: Total Depth measured 10,231' feet Plugs measured 5,700' feet true vertical 8,224' feet Junk measured N/A feet Effective Depth measured 5,700' feet Packer measured See Schematic feet true vertical 4,914' feet true vertical See Schematic feet Casing Length Size MD TVD Burst Collapse Structural 29' 30" 29' 29' Conductor 621' 20" 621' 621' Surface 3,500' 13 -3/8" 3,500' 3,296' 3,090 psi 1,540 psi Intermediate Production 5,983' 9 -5/8" 5,983' 5,137' 6,820 psi 4,230 psi Liner 4,397' 7" 10,107' 8,128' 9,690 psi 9,200 psi Perforation depth Measured depth See Schematic feet 2013 SCANNED MAR 1 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 29# / N -80 2,518' (MD) 2,128' (TVD) Packers and SSSV (type, measured and true vertical depth) See Schematic 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 60 25 Subsequent to operation: 0 0 0 0 25 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El 1 Service ❑ Stratigraphic ❑ Daily Report of Well Operations N/A 16. Well Status after work: Oil ❑ . Gasp WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPD 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: 312 -362 Contact Stan Golis Email sgolisAhilcoro.com Printed Name Stan Golis Title Operations Manager Signature e , .- W C Phone 907 777 -8356 Date 2/15/2013 MS FEB 192O1 u z•z 7. Form 10 -404 Revised 10/2012j' / Submit Original Only • 11 III Middle Ground Shoal SCHEMATIC Well #: Ba -18 Hilcorp Alaska, LLC Last Completed: 12/2012 RKa MSL =101' MudlIne 203' Water Depttr =102 aim B: MSL ADL: 17595 PTD: 176 - 075 -' -Mean Sea Level !#,,'; "Jvlud Line Leg 1, Slot 3 API: 50- 733 - 20296 -00 Casing Detail I e I, °ft Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 20 ' ,} D , .i 30" Structural 29 Surf Surf 621' i ' ""�' ®"'�� l' 20" Conductor 85 #, 8, Welded 18.25 Surf 621 poor cement TOF t''''4. t, © F P a ,, M :1 13 -3/8" Surface 61, 68 K55, Buttress 12.415 Surf 3,500' 382' Temp T-23 g - roc 311• -_ . L T -24 9 -5/8" Intermediate 40,43.5,5 -95, Buttress 8.755 Surf 5,983' * *CB00' ,t4 " a" - - r , .,., 5 V. -'' '� ' 7" P Liner 298, S95, Buttress 6.184 5,710' 10,107' 5,710' t�' ® � po i 13-318 '!rl 7 : 7 ., Tubing Detail 3,464' '' © _. Pefs 1 2-7 I l 6.4 # /N -80 I 2.875 l Surf 1 2,518' 1 et, = 3,466 -3,468' SId ;c', is 3,494'- 3,502'Open Jewelry Detail 3,530' -3,537 Sgzd ry ` ® =,,0 No Depth Length ID OD Item 33' 0.7' 2.44 X -0 3 -1/2" EU 8RND P x 2 -7/8" Buttress Pin '',4.1 ' A 312' 5.64' 2.313 4.650 TRSV Wellstar 6 1. } d 3,710' - 3,717 Sqzd rests B 2,242' 6.03' 2.375 3.750 Sliding sleeve _ . 3,720'3761' Open C 2,286' .43' 2.500 5.500 X/0 2 -7/8" 8rd Box x 5 -1/2" STC Pin .** 3,790' 3,792'Sgzd D 2,287' 5.75' 5.000 8.125 VSIX 10K Packer E 2,292' 1.60' 2.500 6.090 X/0 2 -7/8" 8rd Pin x 5 -1/2" STC Box _..., ®�, F 2,363' 1.21' 2.313 3.688 X- Nipple 4,0, ""�' © '�' + 3 3,439' Bridge plug with +/ -25' cement on top 3.99 ' - 3,997 Sqzd 3,' 12.99' 4.75 8.38 Baker SAB -3 Packer Pais a,o13�,o3t open 3,486 3.52' 2.313 3.76 Otis XA Sleeve e Pans 4 3,656 8.69' 2.44 3.25 Otis Locator Seal Assembly Ai_ ' %, 4 � o 5 3,669' 13.11' 3.25 8.125 Otis BWH Packer Otis XA Sleeve (set XA sleeve packoff) (has leaked, x' 3,703' 3.52' 2.313 3.76 intended to isolate water zone) 3,966' 8.69' 2.44 3.25 Otis BWH Packer TOC ar' -` ,* 4,002' 3.42' 2.313 3.76 Otis XA Sleeve •* T -39 6 4,754' 0.95' 4.75 6.25 Baker Seal Locator 4,757' 3.85' 4.75 6 Baker Seals IN/ Baker F -1 Packer 8.125x6.00 ' . 4,790' 1.37' 2.25 3.25 Otis XN nipple bored to 2.25 No -go profile from 2.313 (2.313" PXN plug & prong set w/1.375" fishneck OD) . , s, 4,823' 1.93' 2.44 3.68 Mechanical Gun Release till - ' 40S6nd 4,859' 1.72' 1.5 3.68 Mechanical Firing Head a 4.e664s63' 7 4,865' 18' N/A 5 5" Baker Tubing Conveyed Perforating Gun (TOP) I s 4,883' - -- N/A 5 5" Baker Tubing Conveyed Perforating Gun (BTM) 5,700' . c�tretainer 0 111 Li 5,700' 8.755 Cement Retainer f/ 1992 Workover sn0 '+ ›:',44 6,480' - -- 6.125 Cement Retainer w/ Cement Cover t/ 6396' 5 711 1, 9.518. TOC: 6396 PBTD 6490 * - i l >9 Perforation Data CMFR „ e1' .,, Top Bottom Top Bottom Interval Status ;,,I, ♦ (MD) (MD) (TVD) (TVD) _ * �"^^ 2,547' 2,562' 2,482' 2,496' T -23 Open 6,57 2,921' 2,939' 2,818' 2,833' T -24 Open oI Top cac � 1' 3,466' 3,468' 3,270' 3,272' Squeezed 16,660' 7,445' 3,494' 3,502' 3,292' 3,298' 31 Sand Open ` a, ', 3,530' 3,712' 3,319' 3,453' Squeezed Sand on 'f ,. 3,720' 3,761' 3,459' 3,488' 32 Sand Open oillatie *'4 •4' 6+} fir... « 3,790' 3,992' 3,508' 3,647' Squeezed w K Leap 1 z,, 4,013' 4,094' 3,661' 3,716' 34/35 Open ` _r. Paz <, r� 7560 ,r A►..,,' '°" /1 4,118' 4,130' 3,733' 3,741' Squeezed Drillar4e8P ; •e+ r x 4,582' 4,594' 4,054' 4,063' T -39 Open ' ' Pens 4,865' 4,883' 4,264' 4,277' Sand Open Y 6 ' 7 9 ' Abandoned - Cmt 6,856 t , , k -„ i t 6,680' 9,920' 5,635' 7,979' B /C /G Rtnr @ 5,700' Fill Reported . sr., , t. r .; 7" 9,641 - - spa" - " Notes: PBTD =5,700' TD= 10,231' 01/2013 - Fish = 388' of 2 -7/8" tubing & wireline entry guide 0 2/92 -Good test to 2,500 psi on tubing x 9 -5/8" annulus from 3,440' to surface. MAX OL HE ANGLE = 48.9 0)003c "2/92 - 9 -5/8" CBL shows TOC at 4,400' PRIOR to squeezes. No bond log ran after squeezes. Revised By: JLL 02/15/13 • • • Hilcor p Alaska LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date BA -18 50- 733 - 20296 -00 176 -075 10/10/12 1/20/13 Daily Operations: 10/10/2012 - Wednesday RU. RIH with 2.28" GR down to 3,500' RKB. RIH with wireline brush and brush XA Sleeve at 3,486' RKB. RIH with 2.31" PX plug and set in XA Sleeve t 3,486'. POOH. RIH with 5' PX prong and set in plug at 3,486'. POOH. RD slickline. Tubing pressure 90 psi. 10/11/2012 - Thursday No activity to report. 10/12/2012 - Friday TP - 0 psi, 9 -5/8" casing - 0 psi. Bled tubing down yesterday and still had pressure on 9 -5/8 ". XA sleeve is not open. Spot equipment and rig up E -line. RIH with 1- 11/16 "x5' tubing punch, tie into schematic dated 9- 13 -12, punch 10 holes in 2 -7/8" tubing from 3,415' to 3,418'. Lost 150 Ibs on wt indicator when fired. POOH. All shots fired. Rig lubricator off well and secure. Rig up equipment to fill tubing and annulus with high volume -low pressure diaphragm pump. Well took approx 1 bbl to fill up. Start pressure up tubing and annulus to 1500 psi with high pressure -low volume haskel pump for Jug test. 10/13/2012 - Saturday Rig up lubricator. Arm Jet cutter. RIH with 2 -1/4" Spectrue jet cutter. Tied into XA sleeve at 3,408'. Spot jet cutter at 3,438' and severed 2 -7/8" tubing. Felt the cut on the line and on the tubing. POOH. Pull up in lubricator and secure well. 12/05/2012 - Wednesday Rigging up. 12/06/2012 - Thursday Rigging up. 12/07/2012 - Friday Rigging up. 12/08/2012 - Saturday Rigging up. 12/09/2012 - Sunday Rigging up. 12/10/2012 - Monday RU compressor & air tank. Spot & hook up superchoke panel. MU 2 -7/8" test jt. RU to fill stack, compressor failed. RU pump off platform air, fill stack. Set test jt & fill stack. Fill stack to pipe rams, close & shell test. Pressure bled off at approx 300 psi per min. Inspect for visual Teaks found small drip from lock -down pin. Bleed down, tighten gland, re -try shell test. Same bleed rate no leak on lock -down. Isolate & double block at mud cross. Retry same bleed rate, no visual Teaks, no leak past rams. Drain down for freeze, protect & unload boat. Pull test jt & blanking plug xo. Shell test w/ blinds. Test BOP's as per Hilcorp -AOGCC SOP. Witness waived By Jim Regg 12 -10 -12 @ 9:30 AM (250 low, 3,000 high) chart 5 min ea. Test's good (had to increase annular closing psi t/2,200. Hand fire watch & monitor equalizer. 12/11/2012 - Tuesday Raise catwalk, install slide, RU compressor, RU line from choke manifold to tank, set up pipe rack, unload boat. RU Weatherford equalizer, pull LD screws, offload fuel rom boat. Pull hanger up 18,500 Ibs. Bleed down & disconnect control line from SSSV. Install valve pump, open SSSV & lock open. Break off hanger & LD. POOH & LD 8 jts & 4 pups, 1 SSSV w/ control line & 1 band on every jt. Continued POOH. Up wt 15,600 Ibs, 55 jt total out. Continued POOH, until tubing on bank. LD 109 jts total, 1 SSSV, 1 sliding sleeve. RD Weatherford tools. Secure well. Fire watch & maintain equalizer. • Hilcorp Alaska, LLC Weekly Operations Summary 12/12/2012 - Wednesday Clear used pipe from pipe rack, lay out pipe for completion & tally. Wire fire control panel to micro- turbine. Fuel & maintain equalizer fire watch. 12/13/2012 - Thursday RU a -line & prep tools. RIH w/ a -line from CBL log to 1,500', communication failure to tool. POOH. Troubleshoot issue, find short in line cut 100' + - off & re -dress line. Run CBL good, from 3,435' to surface. Breakdown a -line tools. Dump bail cmt on packer, tubing tail & tubing plug from 3,439' up to 3,414' + / -, AOGCC witness of plugging operations waived by Jim Regg 12 -11 -12 @13:50. Fire watch & service equalizer. 12/14/2012 - Friday RU a -line. RIH & tag cmt @ 3,411'. Total of 28' of cmt on packer & tubing plug. AOGCC witness of plugging operations waived by Jim Regg 12 -11 -12 @ 13:50. RD a -line & prep loads from boat. Mobe personnel to platform & orientate. RU to test casing. Test 9 -5/8" casing & plug to 1,500 psi, hold & chart for 30 min, good test. RU to PU tubing, RU pump, PU 2 -7/8" tubing assy & RIH as per procedure to 2,579', wt 14,000 lbs. PU TRSV. RU to run control line, function test sv, good. Continue RIH to 2,878'. PU & MU hanger & land @ 2,901'. PU 15,200 #. s/o 14,900 #. RU slick line & run in hanger. LD pins. 12/15/2012 - Saturday RIH w/ tubing plug, unable to pass through SSSV. POOH & PU gauge ring. RIH, no issue. POOH, PU plug. RIH & set PX plug @ 2,357'. RU Schlumburger to pump, line up down tubing psi up to 4,750 psi & lost psi. Investigate & troubleshoot issues, found fluid in stack, looked for leaks. Re- worked LD screws, able to drop hanger 2.5 ", line up on an attempt to psi up, no go. Close TIW valve pump on ann psi up to 350 psi & have communication w/ tubing, jug test tubing & ann to 1,500 psi, good. Pull wireline plug, no visable damage. RIH w/ plug, try to set above sliding sleeve but unable, run down below "x" nipple, set @ 2,373'. Pump on ann. & pressure up to 900 psi then saw pressure drop to 300 & get flow up tubing. Shut down & bleed off. POOH finding plug element damage, re- dress. RU & RIH w/ brush to re- establish & confirm depths finding the three "x" profiles & POOH. RIH w/ plug & set in "x" nipple @ 2,352'. Pump in ann, see communication in tubing, SD. RIH to retrieve plug, made several failed attempts, ordered new plug & tools. Fuel & maintain equalizer. 12/16/2012 - Sunday RIH w/ 2" GS to 2,352'. POOH, m /t, RIH w/ 2" GS to 2,352' sheared. POOH, m /t, RIH w/ 2" GS on KJ. Unable to go through SV stacking. POOH, RIH w/ braided brush to 2,352' wk & POOH. RIH w/ 2" GS to 2,352'. POOH, m /t, RIH w/ 2" GS to 2,352'. POOH, m /t, RIH w/ 2.25" LIB to 2,352'. POOH, impression on 1/3 outside edge. RIH w/ 2" GS & 2 -kj to 2,352'. POOH, m /t, RIH w/ 2" GS to 2,352'. POOH, m /t, RIH w/ 2.25" LIB to 2,352'. POOH, impression on 1/3 outside edge. RIH w/ 2.25" LIB on 2- kj to 2,352'. POOH, impression on 1/3 outside edge. RIH w/ 2.25" LIB w/ bow spring to 2,352'. POOH, impression on 1/3 outside edge. RIH w/ 2.25" braided brush to 2,352' wk & fell through. Continued to 2,375'. POOH, RIH w/ 2.25" LIB to 2,352'. POOH, impression on 2/3. RIH w/ 2.25" DR pt to 2,352'. POOH, m /t, RIH w/ 2.25" LIB to 2,352'. POOH, impression on 1/3 outside edge. RIH w/ 2.25" braided brush to 2,352'. Wk, POOH, m /t, RIH w/ tool to 2,352'. POOH, m /t. Secure well, fire watch & service equalizer. 12/17/2012 - Monday RIH w/ braided brush to 2,352'. POOH, RIH w/ 2.25" lib to 2,352'. POOH, RIH w/ braided brush to 2,352'. POOH, RIH w/ 2.25" lib to 2,352'. POOH, RIH w/ 2.25" magnet to 2,352'. POOH, RIH w/ 2.30" lib to 2,352'. POOH, inconclusive, re -run same. POOH, change tool string. RIH w/ 2.30" lib to 2,352'. POOH, RIH w/ 2.30" lib to 2,352'. POOH, RIH w/ 2.0" GS to ,2352'. POOH, RIH w/ 2.0" GS to 2,352'. POOH, RIH w/ 2.25" lib to 2,352'. POOH, RIH w/ k- kickover tool & taper tap to 2,352'. POOH w/ drag to 2,309' then lose drag. Set down & lose string wt. POOH, RIH w/ 2.0" GS to 2,309'. POOH retrieving plug. Fire watch, service & fuel equalizer. 12/18/2012 - Tuesday • • Hilcorp Alaska, LLC Weekly Operations Summary RIH w/ braided brush to 2,450'. POOH, PU AD2 stop. RIH to 2,352', unable to get through packer lower xo, wk several times. POOH, c/o tool string re -run , no go, POOH. Call & discuss options for w/I & research options for resolving issues. RIH w/ 2.25" lib to 2,352'. POOH, analyze block appears to have square edge on xo. Decision to POOH w/ completion to analyze. PU landing jt & MU, pull 1 /d's, pull hanger up wy 18,000 to free, pull to prep hanger from BOP test, re -land hanger. Test BOP's as per Hiolcorp -AOGCC SOP Witness waived By Jim Regg 12 -18 -12 @ 17:15. MU test jt, test gas alarms RU test pump. Fire watch, service equalizer. 12/19/2012 - Wednesday Cont. Test BOP's as per Hiolcorp -AOGCC SOP witness waived By Jim Regg 12 -18 -12 @ 17:15, test good. Pull hanger up wt. 15,200 #, 1/d & pooh t/ packer & I /d. Break out xo & inspect, found square edge on xo. 12/20/2012 - Thursday Break down packer assy & x nipple, wait on new xo. M/u packer assy w/ new 60 deg taper xo, & 30 top. P/u & m/u x nipple, p/u jt & try to m/u unable to m/u due to wind. Secure well wait on weather. Service eq ; Monitor wind for break. 12/21/2012 - Friday Rih, w /packer assy. to 693'. Rih w /completion f/693' t12,875' . P/u m/u hanger & Land at 2,906.53', up wt 15,200 #, dn wt 14,900 #. R/u wireline, Rih & set plug @ 2,363'. R/u & pressure up t/ 5,000psi t/set packer as per Tri -point rep. Hold 4,700 psi & chart f/ 30 min 50 psi drop, good test. W /I, Rih & pull plug. R/u & p/t t/ 1,500psi hold & chart 30 min. 12/22/2012 - Saturday Rig down Kt 1 work platform & eq. Install BPV, n/d BOP's. N/U tree & test tubing adapter t/250psi low /5,000psi high hold ea. f/15 min good test. Finish n/u tree, pull BPV, test tree to 250psi low and 5,000psi high hold ea. f/15 min good test. Prep loads f/ boat, service eq. service facilities, winterize test pump, demobe Drilling crew @ 19:30 12/26/2012 - Wednesday Cont. Test BOP's as per Hiolcorp -AOGCC SOP witness waived By Jim Regg 12 -18 -12 @ 17:15, test good. Pull hanger up wt. 15,200 #, l/d & pooh t/ packer & I /d. Break out xo & inspect, found square edge on xo. 12/27/2012 - Thursday Break down packer assy & x nipple, wait on new xo. M/u packer assy w/ new 60 deg taper xo, & 30 top. P/u & m/u x nipple, p/u jt & try to m/u unable to m/u due to wind. Secure well wait on weather. Service eq Monitor wind for break. 12/28/2012 - Friday Rih w /packer assy. to 693'. Rih w /completion f/693' t/2,875' . P/u m/u hanger & Land at 2,906.53', up wt 15,200 #, dn wt 14,900 #. R/u wireline, Rih & set plug @ 2,363'. R/u & pressure up t/ 5,000psi t/set packer as per Tri -point rep. Hold 4,700 psi & chart f/ 30 min 50 psi drop, good test. W /I, Rih & pull plug. R/u & p/t t/ 1,500psi hold & chart 30 min. 12/29/2012 - Saturday Rig down Kt 1 work platform & eq. Install BPV, n/d BOP's. N/U tree & test tubing adapter t/250psi low /5,000psi high hold ea. f/15 min good test. Finish n/u tree, pull BPV, test tree to 250psi low and 5,000psi high hold ea. f/15 min good test. Prep loads f/ boat, service eq. service facilities, winterize test pump, demobe Drilling crew @ 19:30. Turn over to production. 01/09/2013 - Wednesday Swab well from 675' to 2,050' = 11 runs = 20.75 bbls gain in RFR tank Let set 1 hr / level = 1990' 01/19/2013 - Saturday • Hilcorp Alaska, LLC Weekly Operations Summary Spot equipment and rig up lubricator. Run line thru grease tubes and put new rope socket on line. Pressure test to 250 psi low and 1,000 psi high. Lost power to platform. Tubing pressue 200 psi. RIH with a with 2 -1/8" blind box and found fluid level at 2,350'. Double check fluid level. POOH. Arm jet cutter. RIH with 2.25" Spectra jet cutter and tied into Pollard CBL log dated 13- Dec -12. Severed tubing at 2,518'. Went down hole logging casing collars and tagged top of cut tubing at 3,021'. POOH. Tubing pressure 100 psi. Build 15' of Titan Deep Penetrating 2 -1/8 ", 6 spf, 0 Deg Phase strip gun. RIH with gun and tie into Pollard CBL log dated 13 Dec 12. Spot gun across Tyonek 23S Ss zone from 2,547' to 2,562' per Final Approved Perf Request Form dated 12/14/12 and signed by Kevin Eastham. Tubing pressure 42 psi. Fired gun. No pressure change. POOH. RIH with a with 2 -1/8" blind box and found fluid level at 2,130' with 30 psi on tubing. Double check fluid level. POOH. Rig down Eline and clean up area. Fired perf gun at 0340 hrs with 42 psi and at 0500 hrs tubing pressure 23 psi. 01/20/2013 - Sunday Monitor well for build up. From 6:00 am til 12:00 noon pressure has increased 4 psi. From 23 psi to 27 psi. Send paperwork to OSK Heliport to fly perf pods out. Talk to Ops Mgr and decision was made to re-perf the lower zone Tyonek 24S Ss from 2,921' to 2,930' with Titan 2 -1/8" deep penetrating strip guns (4 spf), 0 deg phase. Then possibly re-perf the Tyonek 23S Ss. Build 18' long 2 -1/8" Titan deep penetrating strip guns (4 spf), 0 deg phase. Arm 2 -1/8 "x18', 4 spf, 0 deg phase Titan Deep Penetrating strip gun. Rig up lubricator pressure test to 250 psi low and 1,000 psi high. Tubing pressure 30 psi. RIH w/2 -1/8 "x18', 4 spf, 0 deg phase Titan Deep Penetrating strip gun and tie into Pollard CBL log dated 13- Dec -12. Spot gun from 2,921' to 2,939' per Final Approved Perf Request Form dated 12/14/12 and signed by Kevin Eastham. Tubing presure 11.8 psi. Fired gun. No pressure increase. POOH. Got hung up in the Sliding sleeve at 2,244'. Call Ops mgr and talked about options. Pulled 800 Ibs over tool wt and pop free. Saw fluid level about 1,700'. RIH with 2- 1/8" blind box to check fluid level and make sure tubing is clear. Tubing was clear but didn't see fluid level. Went down to 2,600'. Started back out hole and line came wet at 2,200'. Checked casing pressure and it was at 5 psi when it had been a steady 55 psi. We may have opened the sliding sleeve when we popped free. Fluid level is at 400'. Rigged lubricator down. Will have slickline out in the morning to close sliding sleeve and swab well. TP - 1 psi and casing - 5 psi. P"IT) 176&76-0 Regg, James B (DOA) From: Chad Helgeson [chelgeson@hilcorp.com] Sent: Tuesday, December 11, 2012 7:51 AM To: Regg, James B (DOA) Cc: Harold Soule - (C) Subject: BOP test on Baker 18 Jim, We were able to pull our blanking sub and got it to seat and test. We did not have to test against the casing. We will be sending in the report later. Thanks for your review. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 SCANNED AUG 2 0 2m 1 • .Regg,,James B (DOA) M %7wWo From: Chad Helgeson [chelgeson@hilcorp.com] Sent: Monday, December 10, 2012 5:03 PM To: Regg, James B (DOA) Cc: Harold Soule - (C) Subject: Casing pressure test Attachments: MGS_ _BA-18_Daily_Rpt_PDF_10132012.pdf; MGS_BA-18_Daily_RptPDF_10142012.pdf; Baker 18 Casing Pressure Test 10-11-12.pdf Jim, Attached is the casing pressure test completed in October after we set the plug in the tubing, but before we cut the pipe. They did not have the correct charts (pressure), but the pressure for each line was the following tubing — black 1,500 psi on chart = 4,000 psi on gauge casing — red 780 psi on chart = 2,000 psi on gauge It does appear that there is a slow leak (clock was accurate). I have also attached the daily reports on the work for the 2 days that this was done since it went past midnight. We are having another blanking sub brought out to try again, but if that doesn't work, we are hoping to be able to test the BOPs against the casing. If we do that I would like to just test the BOP's to 2,000 psi. Let me know if you have any questions or would like to discuss in further detail. Thanks Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907-777-8405 Mobile: 907-229-4824 3c-Vnr; Bz� &' 4 � � 6 AM A r ........... t f ;^%.fART NO, MP -2000 /o -t4- rt- � 1 YcS" tips BA -1P 44060 P -ON C P r !2 04.6 pe o 0 VJ z � • 9 HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. 2 DATE: 10/13/2012 ' JOB: 22 or over LEASE: WELL: I MQS BA -18 AFE/PROJ NO: 1 1222506 FIELD: I Middle Ground Shoals COUNTY / PARISH / API#: /507332029600 STATE: I AK PRESENT OPERATION AT REPORT TIME: DAILY COST: I CUM. COST: IAFE Amt. REPORTED BY: Bill lewhite CONTRACTOR REP: PHONE CONTRACTOR I RI #: II CASING DATA I —PRODUC TION TUBING SIZE:WT: DEPTH: ID: SIZENVT/THD: // RA ID: SIZE: WT: DEPTH: I ID: I SIZE: I IWT: DEPTH: I ID: I/1 SIZE: I I WT: DEPTH: I ID: I H E T DATA Packer: SIZE/DEPTH: I / NIPPLES: DEPTH:ID: SCSSV: DEPTH: ID: NIPPLES: DEPTH: ID: NIPPLES: DEPTH: ID: NIPPLES: DEPTH: I ID: TBG HD/FLANGE: PROD TREE: SMALLEST ID: I DEPTH: I IPBTD: I ELEVATION: WD: PRESENT PERFS: 0 to 0 Packer Fluid: M I TO ACTI)ATYSUMMARY lChronoloalcal order for the last 24 hrs. 10:30 11:30 SIMOPS, PTW and JSA. TP - 0 psi, 9-5/8" casing - 0 psi. Bled tubing down yesterday and still had pressure on 9-5/8". XA sleeve is not opera. 11:30 14:00 Spot equipment and rig up E -line. Wait on helicopter to bring out tubing punch charges. Load tubing punch gun. 14:00 15:30 RIH with 1-11/16"x5' tubing punch, tie into schematic dated 9-13-12, punch 10 holes in 2-7/8" tubing from 3415' to 3418'. Lost 150 lbs on wt indicator when fired. POOH. All shots fired. 15:30 16:30 Rig lubricator off well and secure. Moving to Ba -27. 16:30 22:00 Rig up equipment to fill tubing and annulus with high volume -low pressure diaphragm pump. Well took approx 1 bbl to fill up. 22:00 4:00 Start pressure up tubing and annulus to 1500 psi with high pressure -low volume haskel pump for Jug test. At 01:30 well is up to 1040 psi; 1270 psi at 02:30; 1360 psi at 03:10. At 04:00 hrs have 1500 psi on well, starting 30 min jug test. Will update later on how test went. Going to get some rest. A (DENT 9 I None 0 r1 LJ HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. 3=' rI DATE: 10714!2017 JOB: or over LEASE: WELL: I MGS BA -18 lAFE1PROJ NO: 1 122250 6 FIELD: I Middle Ground Shoals COUNTY / PARISH / API#: /50 3320 600 I STATE: I AK PRESENT OPERATION AT REPORT TIME: DAILY COST: I I CUM. ST: lAFE Amt. REPORTED BY: Billy Applewhite 1CONTRACTOR REP: PHONECONTRA TOR / RIG #: / D A,- R DU N SIZE: WT: DEPTH: ID: SIZENVTITHD: // DE ID: SIZE: WT: ID: // EEIDEPTH: SIZE: WT: DEPTH: ID: SIZE, WT: DEPTH: ID: UIP NDATA Packer: SIZEIDEPTH: I NIPPLES: DEPTH: ID: I SCSSV: DEPTH: 1 ID: NIPPLES: DEPTH: ID: NIPPLES: DEPTH: ID: NIPPLES: I DEPTH: I ID: TBG HD/FLANGE: PROD TREE: SMALLEST ID: I DEPTH: I IPBTD: I ELEVATION: WD PRESENT PERFS: 0 to 0 Packer Fluid: F MAR Chronola ical order for the last 24 We. 6:00 16:30 Started the 30 min jug test approx around 4:00 am. Lost 20 psi in 30 min and lost 100 psi in 6 hrs. Called test good. 16:30 23:30 Bleed annulus down to 80 psi. Tubing prressure followed annulus as it bled down. 0:00 1:00 SIMOPS, PTW, JSA. Rig up lubricator. Arm Jet cutter. 1:00 2:00 RIH with 2-1/4" Spectrue jet cutter, tied into XA sleeve at 3408'. Spot jet cutter at 3438' and severed 2-7/8" tubing. Felt the cut on the line and on the tubing, POOH. Cutter went off ok. 2:00 2:30 Pull up in lubricator and secure well. Note: Need to check tubing talley on packer depth. A C DENTS? None AV OF T�y� • • THE STATE Alaska Oil and Gas ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4' L S- Anchorage, Alaska 99501 -3572 AAS Main: 907.279.1 433 Fax: 907.276.7542 Chad Helgeson Operations Engineer Hilcorp Alaska, LLC f - 0 'Is- 3800 Centerpoint Drive, Suite 100 I '1 to Anchorage, AK 99503 Re: Middle Ground Shoal Field, B, C, D, E, F, G Oil Pool, MGS ST 17595 (Baker) 18 Sundry Number: 312 -362 Dear Mr. Helgeson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Fo rster Chair DATED this / Z d ay of October, 2012. Encl. ' e • RECEIVED . ��� 24 zo�z STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION t /"1V a` 6-8_ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrili ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations 0 • Perforate 0 • Pull Tubing 5 Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Run Completion • 2. Operator Name: 4. Current Well Class: 5. Permit to Orin Number: Hilcorp Alaska, LLC Development 0 . Exploratory ❑ 176 -075 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 733 - 20296 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. We Name and Number property line where ownership or landownership Ganges: ❑ MGS ST 17595 (Baker) 18 . Spacing Exception Required? Yes 9. Property Designation (Lease Number): 10. Field / Pool(s): • ADL0017595 • Middle Ground Shoal Field / E, F & G Oil; B, C & D Oil; Undefined Gas • 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): 10,231 • 8,224 • 5,700 4,914' 5,700' N/A Casing Length Size MD TVD Burst Collapse Structural 29' 30" 29' 29' Conductor 621' 20" 621' 621' Surface 3,500' 13 -3/8" 3,500' 3,296' 3,090 psi 1,540 psi Intermediate Production 5,983' 9 -5/8" 5,983' 5,137' 6,820psi 4,230 psi Liner 4,397' 7" 10,107' 8,126' 9,690 psi 9,200 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2 -7/8" N -80 4,883' Packers and SSSV Type: Baker SAB -3 ; 2 Otis BWH; Packers and SSSV MD (ft) and TVD (ft): 3,453' MD 3,260'TVD; 3,669' MD Baker F; Otis SSSV 3,422' TVD & 3,966' MD 3'630' TVD; 4,757' MD 4,184' TVD; 312' MD 312 TVD 12. Attachments: Description Summary of Proposal 5 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 . Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 10/2/2012 Commencing Operations: Oil ❑ Gas 0 ' WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature (,z Phone 777 -8405 Date 9/24/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i 2 -3Ct72. Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 Op C C o f X51 G 3 c U C) 7�1' S C., A / ( t / } ,v ✓7 (? C C 2 7 ti d J y ✓r G�-C` (7 ii p J t ./ 9 / 1-i y C i pt. r 1 - )v l d ,l J I Subsequent Form Required: I - 4 4 j . it APPROVED BY Approved by:; v ,f ` %�t= / -- 2J(_______ COMMISSIONER THE C( III ION Date: � /2 ; � j MS OL ► b o1z , Form 10 -403 Revised 1/2010 ` � Z / --� Submit in Duplicate P ORIGINAL • • Well Prognosis Well: MGS ST 17595 -18 Hilton) Alaska, LL Date: 9/26/2012 Well Name: MGS ST 17595 -18 (Ba -18) API Number: 50- 733 - 20296 -00 Current Status: Gas well Leg: 1 Estimated Start Date: October 2 " 2012 Rig: TK #1 Work Platform Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 183 -116 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Chris Kanyer (907) 777 -8377 (0) AFE Number: 1222506 Current Bottom Hole Pressure: — 1,986 psi @ 4,059' TVD (Water gradient (.44 psi /ft) to T -39 & current SITP of 200 psi) Maximum Expected BHP: — 1,986 psi @ 4,059' TVD (Same as above) Max. Allowable Surface Pressure: —1,795 psi (Based on 0.047 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Hemlock in 1977. A workover was performed in 1982 to convert the well to Hemlock water injection. A subsequent workover in 1987 recompleted the well to a Tyonek B,C & D water injector. In 1992 all the open Tyonek oil sands were abandoned and the well was worked over as a gas producer from the Tyonek T -40A sand. A plug was set in the tubing to isolate the T -40A sand in 1997 and the T -39 sand was perforated through tubing. This well has remained shut in since 1997. The current recompletion plan is to set an abandonment plug above the existing T -31 perfs, and the well will be recompleted to shallower gas sands. If successful flow testing occurs from these zones, the well will be flowed through modularized gas conditioning facilities. This new processing equipment and facilities will be used for long term flow. Notes Regarding Wellbore Condition • Well current well status is a shut in gas well. Brief Procedure: 1. Mob slickline, a -line, test equipment to the Baker Platform. 2. RU slickline. Pressure test lubricator 250psi low /2500psi high. 3. RIH w/ 2.25 - 2.30 "gauge ring to +/- 3,500'. / t vy 4. RIH and set plug in x- nipple at 3,486'. C/ti'`r h o ° �CvN tv� o� 5. Perform charted pressure test on casing & tubing (jug test) to 1,500psi for 30 min. 6. RD slickline. 7. RU Eline, pressure test lubricator, 250 psi low /2500 psi high. 8. RIH and cut 2 -7/8" tubing at +/- 3,440', (between sliding sleeve and packer). 9. RD Eline. 10. Circulate well with filtered Inlet water (FIW) / KCI blend. h' S 11. RU KT #1 work platform - No 17 f� L}aUC'C Z� 12. Set BPV in tubing hanger, ND tree, NU BOPS and test same to 250ps1 low/ 000 ski high. 13. POOH with 2 -7/8" tubing from +/- 3,440, LD tubing. 14. RU Eline. 15. Notify AOGCC 24hrs before plugging operations to witness. • • Well Prognosis Well: MGS ST 17595 -18 iiilcor,, Alaska. LU Date: 9/26/2012 16. Dump bail greater than 25' (2 bbls) of cement on top of packer /tubing plug at +1- 3,450'. 17. WOC. 18. RIH with CBL t ag TOC at +1- 3,425'. log with CBL from +/- 3,425' to surface. 19. RD Eline. 20. Perform char ted pressure test on casing (ju test) to 1,SO Opsi for 30 min. 21. RIH with new 2 -7/8" tubing, SCSSSV and packer to 2,900', (set packer at +/- 2,350' with tong tubing tail). 22. Test tubing to 3000 psi and chart for 30 min, test casing to150Qpsi chart for 30 min. 23. ND BOPE, NU tree and test same. 24. Install and test SSV and SCSSSV, RU temporary flowback /test equipment and vent stack. (notify AOGCC 24hrs before testing safety valves) 25. RU slickline. 26. Swab well to +/- 1500', RD slickline. 27. RU Eline. 28. RIH perforate T -25 from +/- 2,428' to +/- 2,450' w/ 2" guns w/ deep penetrating charges. 29. RD Eline. 30. Flow test well and vent gas to atmosphere. (If capable AOF well test will be completed). 31. Shut in well. 32. Pending successful flow test(s), hook up to modularized gas conditioning facilities. 33. Turn well over to production. Attachments: 1. As -built Well Schematic 2. Proposed Well Schematic 3. KT #1 Work Platform details a. Photos b. Engineering Design c. Lifting Upgrade Certification 4. BOP Schematic 5. Choke Schematic 6. Accumulator Specs • . • Middle Ground Shoal ` SCHEMATIC Well #: Ba -18 HilcorpAlaska,LLC Last Completed: 2 -28 -1992 RKEt MSL =101' Mutllne= 203' Water Depth= 102' S Mil 11111 — i _ r, ea Level ADL: 17595 PTD: 176 -075 , 11111M a_U L ° -t' ud Line Leg 1, Slot 3 API: 50- 733 - 20296 -00 ;t} 387 Casing Detail very acr, cnt Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 20" 30" Structural 29 Surf Surf 62T Doc CBL -very poor 2446 20" Conductor 85 #, B Welded 18.25 Surf 621' cement 61, 68, K55, 382' Temp 13 -3/8" Surface 12.415 Surf 3,500' Buttress Log AAA sad3 . la ,43.5,5 -95, * *4400' 3 Q 9 -5 /8" Intermediate 8.755 Surf 5,983' ��� . L��L Buttress an 13 _ "" , " l 7" Prod Liner 29 #, 595, Buttress 6.184 5,710' 10,107' 5,710' 3,464' --- �! - Psis — 3 - „ 68 , x , Tubing Deatail 3'4943,502' Cpen 2 -7/8" 6.4 # /N -80 /Buttress 2.875 1 Surf 4,883' 3,530' -3,537 Sczd 131431 Re . Jewelry Detail Psls b s 3,710- 3,717Sgzd No Depth Length ID OD Item . 3,720' - 3,761' Open - 3,790'3,792' Sgzd 33' 0.7' 2.44 X -O 3 -1/2" EU 8RND P x 2 -7/8" Buttress Pin 1 312' 5.65' 2.313 4.76 Otis Sub surface Safety Valve 2 3,408' 4.31' 2.313 3.76 Otis XA Sleeve (OPENED in 1996) - , 3,453' 12.99' 4.75 8.38 Baker SAB -3 Packer Bnrl - : ' 44 X 3,486' 3.52' 2.313 3.76 Otis XA Sleeve 3,966 © 3 3,656' 8.69' 2.44 3.25 Otis Locator Seal Assembly '° 3,990 Sqzd 4,013'4,031' Open 3,669' 13.11' 3.25 8.125 Otis BWH Packer Pens 3,703' 3.52' 2.313 3.76 Otis XA Sleeve (set XA sleeve packoff) (has leaked, , 4,0694,094' open 4 intended to isolate water zone) <a,11a,4 3,966' 8.69' 2.44 3.25 Otis BWH Packer ~ 4,002' 3.42' 2.313 3.76 Otis XA Sleeve TOC GEL 5 4,754' 0.95' 4.75 6.25 Baker Seal Locator 4400 4,757' 3.85' 4.75 6 Baker Seals IN/ Baker F -1 Packer 8.125x6.00 T -39 Otis XN nipple bored to 2.25 No -go profile from Baker Packer `� -"qilliPrIIIII 4,790' 1.37' 2.25 3.25 2.313 (2.313" PXN plug & prong set w/1.375" ., 6 fishneck OD) 4,823' 1.93' 2.44 3.68 Mechanical Gun Release {� - 40Sand 6 4,859' 1.72' 1.5 3.68 Mechanical Firing Head ■i[7 4'865''883Oce 4,865' 18' N/A 5 5" Baker Tubing Conveyed Perforating Gun (TOP) 5700 4,883' - -- N/A 5 5" Baker Tubing Conveyed Perforating Gun (BTM) cm retainer 5,700' 8.755 Cement Retainer f/ 1992 Workover 5,710 6,480' 6.125 Cement Retainer w/ Cement Cover t/ 6396' Liner Top , 94/8" TOC 5396' PBT Perforation Data 6,480 Top Bottom Interval Status cn4r "ef 3,466' 3,468' Squeezed 3,494' 3,502' 31 Sand Open 6,570 — • 3,530' 3,712' Squeezed 01 Top GBG Perfs 3,720' 3,761' 32 Sand Open — 6680 -7445 3,790' 3,992' Squeezed Sand on BP 4,013' 4,094' 34/35 Open 7.635' 4,118' 4,130' Squeezed Drillable BP 4,582' 4,594' T -39 Open ;680 4,865' 4,883' "40" Sand Open gillable BC' 6,680' 9,920' B /C /G Abandoned — Cmt Rtnr @ 5,700' — Peru Notes: 8 9 — 2/92 – Good test to 2,500 psi on tubing x 9 -5/8" annulus from 3,440' to surface. d 011 * *2/92 – 9 -5/8" CBL shows TOC at 4,400' PRIOR to squeezes. No bond log ran after squeezes. 4", 7" 9,641 PBTD = 5,700' TD = 10,231' MAX HOLE ANGLE = 48.9 (c) xxxx Revised By: TDF 9 -13 -2012 • . Middle Ground Shoal PROPOSED Well #: Ba -18 Hilcorp Alaska, LLC Last Completed: 2 -28 -1992 RKB MSL=101' Mudline 203' \ Water Depth= 102' F ' KB: MSL ADL: 17595 PTD: 176 -075 MOE - MM.' ',; '_Mud Line ' Sea Level Leg 1, Slot 3 API: 50- 733 - 20296 -00 -� �I TOC _' Casing Detail 30" 1 38Z �"° t Size Type Wt/ Grade/ Conn ID Top Btm CMT Top 20" 2 2°aas 30" Structural 29 Surf Surf 621 =, ®,= 20" Conductor 85 #, B, Welded 18.25 Surf 621' CBL -very poor cement 61, 68, K55, 382' Temp 13 -3/8" Surface Buttress 12.415 Surf 3,500' Log T - 25 40,43.5,5 -95, * *4400' 9-5/8" Intermediate Buttress 8.755 Surf 5,983' CBL ><.1' Q 3 ¢5 7" Prod Liner 29 #, 595, Buttress 6.184 5,710' 10,107 5,710' 13-3/8" 3 ` Tubing Deatail 3,464' 4 = perfs = 3,466- 3,46e'Sgzd I 2 -7/8" 6.4 # /N -80 1 2.875 1 Surf 1 2,900 3,494'- 3,502' Nen . ` 3,530- 3,532' Sqzd :›4( Jewelry Detail 5 No Depth Length ID OD Item _ parts 33' 0.7' 2.44 X -O 3 -1/2" EU 8RND P x 2 - 7/8" Buttress Pin -.= -r- 3,710'3,712' Sqzd _ -- 3,720'3,761' o 1 +1-300' SCSSSV 3 +/- 2,280' 2.313 Sliding sleeve 2 +1- 2,300' 2.44 Permanent packer +/- 2,310' 2.313 X Profile & WL Entry guide _ 6 - �- Perfs -- 3,990' - 3,992' Sqzd 3 3,450 Bridge plug with +1-25' cement on top / - 4,013 Open 3,453' 12.99' 4.75 8.38 BakerSAB -3 Packer Pais 3,486' 3.52' 2.313' 3.76 Otis XA Sleeve h - 4089'a,o9a' Open 4 3,656' 8.69' 2.44 3.25 Otis Locator Seal Assembly Sqzd y = x 3,669' 13.11' 3.25 8.125 Otis BWH Packer 3,703' 3.52' 2.313 3.76 Otis XA Sleeve (set XA sleeve packoff) (has leaked, r q TOC ceL ' ° l''''. � T -3B 5 intended to isolate water zone) 4 3,966' 8.69' 2.44 3.25 Otis BWH Packer 4,002' 3.42' 2.313 3.76 Otis XA Sleeve 6 4,754' 0.95' 4.75 6.25 Baker Seal Locator 7 4,757' 3.85' 4.75 6 Baker Seals IN/ Baker F -1 Packer 8.125x6.00 Otis XN nipple bored to 2.25 No -go profile from 4OSand 4,790' 1.37' 2.25 3.25 2.313 (2.313" PXN plug & prong set w/1.375" MEG a 5 4 '� 30p � fishneck OD) 5.700 _ ..--' 4,823' 1.93' 2.44 3.68 Mechanical Gun Release Cal retaner g 7 4,859' 1.72' 1.5 3.68 Mechanical Firing Head 5.710' 4,865' 18' N/A 5 5" Baker Tubing Conveyed Perforating Gun (TOP) liner Top 4,883' N/A 5 5" Baker Tubing Conveyed Perforating Gun (BTM) 9_,5/8" TOG' 6396' PBTD Perforation Data 6480' GMT Retainer Top Bottom Interval Status +/- 2,428' +/- 2,450' T -25 Proposed '/ 6.576 - • 3,466' 3,468' Squeezed aiTOpcac 3,494 3,502' 31 Sand Open Perfs 6,68G-7 445 1 3,530' 3,712' Squeezed Sand on BP \5e 3,720' 3,761' 32 Sand Open 7635 3,790' 3 Squeezed Wade BP 4 4,094' 34/35 Open ;680 4,118' 4,130' Squeezed Wade EP 4,582' 4,594' T -39 Open 4,865' 4,883' "40" Sand Open 8,749' -9,903 6,680' 9,920' B /C /G Abandoned - Cmt Rtnr @ 5,700' 8 ' 8 - - Notes: FII Reported - 2/92 - Good test to 2,500 psi on tubing x 9 -5/8" annulus from 3,440' to surface. r 9,641' L * *2/92 - 9 -5/8" CBL shows TOC at 4,400' PRIOR to squeezes. No bond log ran after squeezes. PBTD = 5,700' TD = 10,231' MAX HOLE ANGLE = 48.9 (a) xxxx Revised By: CVK 9 -13 -2012 • 0 Chevron Baker Platform Ba -18 Current 08/10/2010 Tubing hanger, TC- 1A -EN- 20 Baker #18 13 3/8 X 9 5/8 CL, 11 X 3'/2 tbg lift and susp, w/ 3" type ?? BPV X 3 /2 profile, 6'/4 EN, % non cont control line BHTA, CIW, 3 1/8 5M c*7 . ice ^ L.. / ® o o f of _ J6 •d o Tree assy, CIW -FL, 3 1/8 iiip 5M FE, HWO, EE trim 7 ti oo d W 6 o IH ram Adapter, FMC -ASP, 11 5M FE X _ -- - 31/85M,w/6'/4EN, 1 -'A ii Tubing head, FMC -TC, 13 5/8 � = u�^_, - ��c, control line exit 3M X 11 5M, w/ 2- 2 1/16 5M n„7I IIII. i V■= EFO, BG- bottom prep, 1 '/2 VR I1t1 _ 1.1 profile - Valve, OCT -20, 2 1/16 5M Valve, WKM -M, 2 1/16 5M r ° o i '' IF -- ° _ uu FE HWO, AA , FE, HWO, AA ' . °r� .' i i � I 1'Ilg il - *— �P ' -1 as .— i 1.1 .i. 1 Casing spool, OCT 22, Valve, OCT -20, 2 1/16 3M 21'/42MX135/83M,w/ M ill "' 2 2 1/16 5M EFO, 00 C> ' bottom prep -11 -1 ��� - 7. r.-, FE, HWO, AA ll r � Mi ,. X111 o - � ) � 11 - r !i BSI an '/4 IIII V alve, OCT 20, 2 1/16 2M Casing head, OCT -22, III IaI 21 2M X 20 SOW, ® 3 e �G' - • FE, HWO, AA w/ 2- 2 1/16 2M EFO, ;..1- I ®I��I ® r d� . B. limmiltke, e � – : � o 2 "LP — 7 • • ‘ ‘, Well Prognosis Well: MGS ST 17595 -18 Hilcora Alaska, LLC Date: 9/20/2012 Well Name: MGS ST 17595 -18 (Ba -18) API Number: 50- 733 - 20296 -00 Current Status: Gas well Leg: 1 Estimated Start Date: October 2 " 2012 Rig: TK #1 Work Platform Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 183 -116 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Chris Kanyer (907) 777 -8377 (0) AFE Number: 1222506 Current Bottom Hole Pressure: — 1,986 psi © 4,059' TVD (Water gradient (.44 psi /ft) to T -39 & current SITP of 200 psi) Maximum Expected BHP: — 1,986 psi @ 4,059' TVD (Same as above) Max. Allowable Surface Pressure: —1,795 psi (Based on 0.047 psi /ft gas gradient) Brief Well Summary This well was drilled and completed as an oil well in the Hemlock in 1977. A workover was performed in 1982 to convert the well to Hemlock water injection. A subsequent workover in 1987 recompleted the well to a Tyonek injection. q p Y B,C & D water injector. In 1992 all the open Tyonek oil sands were abandoned and the well was worked over as a gas producer from the Tyonek T -40A sand. A plug was set in the tubing to isolate the T -40A sand in 1997 and ✓ the T -39 sand was perforated through tubing. This well has remained shut in since 1997. The current recompletion plan is to set an abandonment plug above the existin: -31 perfs, and the well will be recompleted to shallower gas sands. If successful flow testing occurs from th- e zones, the well will be flowed through modularized gas conditioning facilities. This new processing ecVC• ent and facilities will be used for long term flow. Notes Regarding Wellbore Condition • Well current well status is a shut in gas well. 6/ ' 't. , Brief Procedure: nl - , ,1' , \ I 1. Mob slickline, a -line, test equipment the Baker Platform. 2. RU slickline. Pressure test lubricator 50psi low /2500psi high. 3. RIH w/ 2.25 - 2.30 "gauge ring to +/ ,500'. 4. RIH and set plug in x- nipple at 486'. 5. Perform charted pressure tes on casing & tubing (jug test) to 1,500psi for 30 min. 6. RD slickline. 7. RU Eline, pressure test lubricator, 250 psi low /2500 psi high. 8. RIH and cut 2 -7/8" tubing at +/- 3,440', (between sliding sleeve and packer). 9. RD Eline. 10. Circulate well with filtered Inlet water (FIW) / KCI blend. 11. RU KT #1 work platform 12. Set BPV in tubing hanger, ND tree, NU BOPE and test same to 250psi low /3000psi high. 13. POOH with 2 -7/8" tubing from +1- 3,440, LD tubing. 14. RU Eline. 15. Notify AOGCC 24hrs before plugging operations to witness. • , • Well Prognosis Well: MGS ST 17595 -18 Hilcorp Alaska, LLC Date: 9/20/2012 16. Dump bail greater than 25' (2 bbls) of cement on top of packer /tubing plug at +/- 3,450'. 17. WOC. 18. RIH with CBL, tag TOC at +/- 3,425', log with CBL from +/- 3,425' to surface. 19. RD Eline. 20. Perform charted pressure test on casing (jug test) to 1,500psi for 30 min. 21. RIH with new 2 -7/8" tubing, SCSSSV and packer to 2,900', (set packer at +/- 2,350' with long tubing tail). 22. Test tubing to 3000 psi and chart for 30 min, test casing to 1500 psi chart for 30 min. 23. ND BOPE, NU tree and test same. 24. Install and test SSV and SCSSSV, RU temporary flowback /test equipment and vent stack. (notify AOGCC 24hrs before testing safety valves) 25. RU slickline. 26. Swab well to +/- 1500', RD slickline. 27. RU Eline. 28. RIH perforate T -25 from +/- 2,428' to +/- 2,450' w/ 2" guns deep penetrating charges. 29. RD Eline. 30. Flow test well and vent gas to atmosphere. (If cap : AOF well test will be completed). Contingency (pending flow test results): 'J� a. [If water production from T -40] (,/ i. RIH LS and set plug at +/ -5, 8 ii. RIH LS and dump bail +/ -25' if cement on bridge plug. iii. RIH LS and perforate T -40 from +/- 5,371' to +/- 5,410'. iv. Flow test well. b. [If limited ( <500Mcfd) prod! ion from T -40] i. RIH LS and perf ' S T -40A from +/- 5,371' to +/- 5,410'. ii. Flow test well. 31. Shut in well. 32. Pending successful flow test : , hook up to modularized gas conditioning facilities. 33. Turn well over to produ '• . Attachments: y ti 1. As -built Well Schematic n�v 2. Proposed Well Schem tic a ' 3. KT #1 Work Platform etails L a. Photos b. Engineers g Design c. Lifting grade Certification 4. BOP Schemati 5. Choke Sche tic 6. Accumulat Specs C rane W ork Plat _.„... , .:,.._, , .. ., 4 „. r ` ' ______ scw .... e ..,, in Arl F f • t ''''7114 S �: �_ . ∎ • 2 - <w a ka �s frit. 9 s ; w w s -" X07 • . it ; ..ed il f I 111 1 i i fff ! . o- t Iy d 6; t, . • • 0 0 • .. T GENERAL NOTES `_ ,.' •' C HI4 VI? ON '1'YI R RIG ° . STRUCTURAL STS AND CONI€CTOR8 C hevron o ; :� A , 1) STEEL SHAPES, BARS, PLATE TO CONFORM TO ASTM A36 u I L? T T fy = 36 k.s.i. W 1 1 L� ® L. V I L ° Y Y 2) STEEL PIPE SHALL CONFORM TO ASTM A53 140 0 3) STEEL TUBE SHALL CONFORM TO ASTM A -500 GRADE B T\ 1 2 fy =46 ksi / J ec 4) STEEL TUBE SHALL CONFORM TO ASTM A -500 GRADE B fy =46 ksi 5) BOLTS AND NUTS SHALL CONFORM TO ASTM A325 CHARGE CODE- UWDAK- A1028 -ABN Approved for Construction gill I 6) WASHERS SHALL BE ROUND PLATE WASHERS, LOW CARBON STEEL EQUIPMENT # CVTR -001 CONSECUTIVELY ON EACH PIECE ID W 7) NEW LIFTING EYE PLATES SHALL CONFORM TO w z A572 fy =50 k.s.i. (MTR's REQUIRED ON ALL 50 ksi MATERIAL) w ht AS AN ALTERNATIVE TO SPECIFYING CHARPY IMPACT TOUGHNESS (C.I.T.) - -- m TESTING FOR THE WELD PROCEDURE. THE LIFTING EYE ATTACHMENT TO THE MAIN Signature z Ei > N a ST HAS BEEN DESIGNED WITH AND ADDITIONAL SAFETY FACTOR OF 3 inspections Department w v m ABOVE AND BEYOND THE REQUIREMENTS OF ASME —BTH -2008. THE INCREASE IN ' L WELD SAFETY FACTOR IS PROVIDED TO INSURE REDUCED DESIGN STRESSES IN z J Ma' � id � a mm z z LIEU OF C.I.T. TESTING FOR THE WELD PROCEDURE AND BASE MATERIAL. J Enc N z w 8) LIFTING WEIGHT FOR THE WORK PLATFORM SHALL NOT EXCEED ] o ° a 0 z 4,000 LBS, THIS INCLUDES THE SUPPORT LEGS HANDRAILS Z ] 10 a . N 0 N AND LADDER. MAX LOAD PER LIFTING EYE SHALL BE 1200 LBS 13 m "u J I- z J 9) LIFTING WEIGHT FOR BEAVER SLIDE SHALL NOT EXCEED INSPECTION: c� 1700 LBS, MAX LOAD PER LIFTING EYE SHALL BE 900 LBS 1) FABRICATOR WILL CONTACT CHEVRON INSPECTION FOR WELDING INSPECTIONS. • Z 10) BEAVER SLIDE TO BE LIFTED SEPARATE. BEAVER SLIDE SHALL NOT BE USED AS ACCESS TO PLATFORM. 3) UT LAMINATION SCANS ARE REQUIRED AT LIFTING EYE POINTS J z PRIOR TO LUG INSTALLATION. 12) NEW LIFTING EYE PLATES SHALL HAVE CHARPY V —NOTCH TOUGHNESS OF AT 4) 100% VISUAL INSPECTION WILL BE REQUIRED ON ALL COMPLETED WELDS AND MAG LEAST 32/25 (AVG. /MIN.) FT *LBS AT 10 DEG F. DESIGN MINIMUM AMBIENT PARTICLE INSPECTION ON ALL WELDS IN TENSION LOADS. SEE DRAWINGS. TEMPERATURE DURING SERVICE OF —60 DEG F. TEST TEMP FOR A36 AND 5) SUBMIT WELD PROCEDURES AND QUALIFICATIONS TO CHEVRON INSPECTIONS DEPT. A572 IS 70'F ABOVE LOWEST TEMP EXPECTED IN SERVICE FOR ZONE 3 (ALASKA) SERVICE TEMP IS —60T SO TEST TEMP IS — 60' +70' = +10. THE 5) INSPECTIONS SHALL VISUALLY EXAM ALL EXISTING WELDS FOR IMPERFECTIONS. CHARPY IMPACT TOUGHNESS REQUIREMENT HAS BEEN SPECIFIED FOR LIFTING STENCIL --I EYE MATERIAL TO PROVIDE COLD WEATHER FRACTURE TOUGHNESS. 1) TO DRAWINGS CO 1) IN 3" BOLD LETTERS WEIGHT AS SHOWN (SEE DRAWINGS) o 13) ALL CABLES, HOOKS, SHACKLES, SLINGS AND OTHER FITTINGS SHALL BE PROVIDED WITH CERTIFICATION TO MEET MINIMUM SAFE EQUIPMENT NUMBER NOTES Q WORKING LOADS ON DRAWINGS. 14) DESIGN FOR LIFTING HAS BEEN PERFORMED IN ACCORDANCE 1) NEED EPDXY 'PUCK SENSOR IDENTIFIER' AFTER J ( U WITH ASME BTH -1 -2008, USING NOMINAL DESIGN FACTOR PAINTING COMPLETE. LOCATION PER CHEVRON REP. TTTLE SHEET Y Q w CC GI (ND) =3.0 FOR STEEL MEMBERS AND 3.6 FOR STEEL CONNECTIONS. SPECFICATION /NOTESANDEX 1.0 3 0- 15) MAXIMUM LIVE LOAD CAPACITY FOR PLATFORM IN USE IS 100 P.S.F. 2) CONTACT McKINLEY SERVICE EQUIPMENT TO 0 S2 LOAD CAPACITY DETERMINED IN ACCORDANCE IN THE AISC STEEL INSTALL PUCK. VERIFY EQUIPMENT NUMBER WITH LEGEND /MATERIAL UST 1.1 - z CONSTRUCTION MANUAL 13TH ADDITION. McKINLEY SERVICE'S W ct Z Q 16) LIFT RIG WITH A 4 —WAY SLING WITH 60' SLING ANGLE. ASBULT PLAN VIEW 2.0 Lu 3) CONTACT INFORMATION FOR PUCK INSTALLATION ASBULT ELEVATION VIEWS 2.1 ~ F- Lu WELD FIG IS: KEITH HILBISH OFFICE 907 - 262 -2685 CELL ° Z 1) ALL WELDING SHALL CONFORM TO IBC CHAPTER 22 907- 398 -2295 NEW PLAN VIEW 3.0 Lw AND AWS D1.1. N EW LADDER ELEVATION VIEW AND DETAILS 4.0 2) ALL FAYING SURFACES SHALL BE CONTINUOUSLY WELDED WITH 1/4" FILLET MINIMUM UNLESS OTHERWISE NOTED. HANDRAIL REPLACEMENT FOR EXISTNVG CHAIN DETAILS 5.0 3) ALL FABRICATION TECHNIQUES SHALL BE IN ACCORDANCE WITH THE LING EYES / 51 APPLICABLE CODES AND STANDARDS AND REQUIREMENTS OF CHEVRONS PROJECT NO. STRUCTURAL FABRICATION SPECIFICATION MANUAL, SECTION 4.0. 4) FIELD /SHOP FABRICATION: (CHEVRON STRUCTURAL FABRICATION SPECIFICATION, SECTION 5.0) DRAWN SLR L� EYE 6.0 WELDING OF ALL COMPONENTS SHALL BE ACCOMPLISHED WITH 7018 -1 LOW HYDROGEN, DRAWN BY: SNUBBING POST PLAN VIEW AND DETAILS 7.0 "" "° MANUAL SHIELDED METAL ARC (SMAW) WELDING PROCESSES, WITH THE EXCEPTION CHECKED BY: OF THE ROOT PASS AND HOT PASS. WHICH WILL BE ACCOMPLISHED USING ` JN E8010 —G ELECTRODES ON FULL PENETRATION WELDS ACCESSIBLE FROM ONE DATE: 09/26/11 SIDE ONLY. SCALES: NOTED 5) ALTERNATIVE WELDING PROCESSES REQUIRE THE PRIOR APPROVAL OF CHEVRON'S DESIGNATED REPRESENTATIVE OR NELSON ENGINEERING. HORIZ. NOTED VERT. NOTED SHEET 810 I OF 10 i • . I I ..:r-a•••. WA4P H Q BEAVER SLIDE ESTIMATED WEIC -IT o MATERIAL NEEDED . MARK MAT'L LENGTH WEIGHT QTY TOTAL WT MARK MAT'L LENGTH WEIGHT QTY TOTAL WT UPGRADE TO EXISTING TYLER WORK PLATFORM BEAVER SLIDE ESTIMATED WEIGHT o QI C8x11.6 30 LF 11.6 LBS /LF ALL 348 LBS SYMBOLS QI HSS 4x4xV4" 10 LF 12.21 LBS /LF ALL 122 LBS ® L 3x3xV4" 25 LF 4.9 LBS /LF ALL 123 LBS m ® FB V2 "x2V2 42 LF 4.25 LBS /LF ALL 179 LBS D --■- te z ® L 4x4xVa" 31 LF 6.2 LBS /LF ALL 193 LBS w d ® IA" SCH 40 A53 7.8 LF 2.273 LBS /LF ALL 18 LBS n R V " 73 SF 10.21 LBS /SF ALL 453 LBS Z Li m ® We SCH 40 A53 WELD CAPS 2 1 LBS VIEW DIRECTION SYMBOL 6 a ® we SCH 40 A53 40 LF 2.273 LBS /LF ALL 90 LBS Z 0 < ® 3/4"0 ROUND 14.2 LF 1.5 LBS /LF ALL 21.3 LBS w U - ,1 2 Q EXPANDED METAL GRATE 20 SF 5 LBS /SF ALL 100 LBS ® L 4x4x1/4" 4.5 LF 6.6 LBS /LF ALL 30 LBS ® MISC 150 LBS Z Q m 0 '01 z p7 IW SCH 40 A53 20 LF 2.718 LBS /LF ALL 54 LBS r= ,z Y ® I 3 /8" A36 I SF 15.32 LBS /LF ALL 15.32 LBS ESTIMATED EXISTING MATERIAL WT= 1500 LBS -1 o 0 Z ® R 3/4" A572 L.E. .9 SF 30.63 LBS /SF ALL 28 LBS D SYMBOL ELEVATION VIEW Z E m Q °' N NZ W W 10 e 5 /6" 4572 L.E. .7 SF 25.52 LBS /SF ALL 18 LBS BEAVER SLIDE ESTIMATED WEIGHT NY II R V4" A35 I SF 10.21 LBS /SF ALL 10.21 LBS Q DETAIL L ETTER • • • 2 12 L 2x2xV4" 17.2 LF 3.19 LBS /SF ALL 55 LBS Ur SHEET NUMBER ■ 13 IV4 "x GRATE .7 SF 9.1 LBS /SF ALL 6 LBS ABBREVIATIONS J 2 14 WASHER GAVL. ND BOTH NUT, TYP OCK 20 4 LBS ASBUILT PLATFORM WITH OUT LADDER AND BEAVER SLIDE ` APRX. - APPROXIMATELY 5 /8 "0x3" GAVL. BOTH W /LOCK , CTR'D - CENTERED 15 WASHER, AND NUT, TYP. 4 1 LBS MARK MAT'L LENGTH WEIGHT QTY TOTAL WT CONN.- CONNECTION CJP - COMPLETE JOINT PENETRATION w Va' "0x3" GALV. CARRIAGE BOLT WITH PLATFORM ESTIMATED WEIGTH GALV - GALVANIZED o 16 20 3 LBS HORIZ - HORIZONTAL cc NUT AND LOCK WASHER 0 C8x8.2 48 LF 8.2 LBS /LF ALL 394 LBS MT - MAG PARTICLE INSPECTION a H PJP - PARTIAL JOINT PENETRATION Q V4'0x3" GALV. BOLT WITH NUT 20 3 LBS L 3x3x!/a" 98 LF 4.9 LBS /LF ALL 480 LBS REQ'D - REQUIRED -j AND LOCK WASHER ® IV4 "x GALV. GRATE 82 LF 9.1 LBS /SF ALL 747 LBS STIFF. - STIFFENER o J TYP -TYPICAL 18 5 /6' "0x6" GALV. BOLT WITH LOCK ® 6" SCH 80 6 LF 25.58 LBS /LF ALL 154 LBS VERT. - VERTICAL Q Or O WASHER AND HEX HEAD NUT 2 2 LBS ® 5" SCH 80 40 LF 20.78 LBS /LF ALL 831 LBS W/ - WITH Q Or 19 SAFETY GATE, COTERMAN SELF - CLOSING, 70 R V2" 8 SF 20.42 LBS /LF ALL 163 LBS --J Q MATERIALS ADJUSTABLE SAFETY SWING GATE ITEM #3VRX6 ® IV z" SCH 40 A53 160 LF 2.273 LBS /LF ALL 364 LBS PAGE 2194 FROM GRAINGER. g MISC 100 LBS S2 z O ����� STEEL ON EDGE ct Y Q ESTIMATED MATERIAL WT= 560 LBS ESTIMATED EXISTING MATERIAL WT= 3300 LBS Wz 0 STEEL FLAT SURFACE N w 0 Z w NEW MATARIAL NEEDED ASBUILT PLATFORM WEIGHT CC W 2 C-) PROJECT NO. Approved for Construction 628.8 DRAWN BY: WHe CHECKED BY: WJN DATE: 09/26/11 Signature SCALES: NOTED HORIZ NOTED inspections Department VERT. NOTED SHEET 81.1 2 OF 10 1 SIM. ,r •�Z 1 :;' - ,:: ' Yb �� C6x8.2x6" LONG, TYP. 9,-04 . .� 4 r 1'-10" 1' .'' 3' I' -10" FOR BEAVER SLIDE ~ 6" SCH 80 SLEEVE ° WITH 5" SCH 80 ICI 1 • • • • • • • / IC 4"E S �0 z PIPE LEG, TYP. - ' T— � FOR NEW LADDER o � % F SEE 84.0 • \ e0 TYP.® \\I 1 PERIMETER z 2" SCH 40, HANDRAIL SOCKET, TYP. • In IY w w W z Id Q `t v z _ m a c4 N I N J W J Z 3 N a IVa "x GALV. W U , to ' � ' " GRATE, TYP. Z Q m m m Z J I- < Y N W � � O —} �U 0 o -- — — ZEx m Q m m �_ D \ O I- 26 w W L 3x3xV4" \ L 3x3xV4 L 3x3xV4" U U1 - le i- z HSS 2.5x2.5xV4" 3' -I" • Q VERTICAL LADDER AND BEAVER SLIDE B SIM. itl ® SOCKET, TYP. 821 J Z5 -Id- i =1a o -----S —1----- REMOVE: EXISTING EXISTING o LADDER I Ell cr I \ o 0 L 3x3xV4" L 3x3xV4" L 3x3xV \ I Q w a" Q Cl- Qz - 0 O ,, Q O J S2 N I— Y W z CO • w a : I - Q N N Z CC R Ye" GUSSET I W BELOW, TYP. FB Vex4 ",- v a O TYP. ^ �.J Q \ 410,' PROJECT NO. ( —� 1128.8 REMOVE: I.I 1 • D RAWN BY: Approved for Construction EXISTING LIFTING ���///{{..��.•!!!! WH8 EYES., TYP. A- 6" -4' 4" 1' -10" —4' 4" 3 4' k I - IO" .1' 4"- 6" CHECKED BY: EXISTING PINS ARE 114"x8 FLANGE BOLTS. ASSUMED TO BE WJN _ e B7. WILL WORK AS IS. DATE: 09/26/11 Signa ture SCALES: NOTED Signature H RT. NOTED inspections Department A ASBUILT PLAN VIEW SHEET 82.0 82.0 SCALE:3 /4 " =1' -0" 3 OF 10 7. t' t 10'-1$ �• • 3' -10$"! a 0 z 0 / e/ �1/' " l l 1 Y S S S S Y S tO CE z W d W se Z in �� E9 J m . 5 EXISTING LIFTING 13=> Z 5 m Q EYES., TYP. W U m _.._ AV ER SLID OR F w Ile _ N I I-I LADDER WLL 9Er HERE — — _— — — =I Z < a rn N z C ; _ _ _ , \ _ _ I BEAVER SLID. ° I ° L - o �_ N U o 4 m z I pl _' 1 ` 1 m SCH 80 PERIMETER p I 1 ` C6x8.2, TYP. ® 6" Z m z . o W IA Li O I I � SLEEVE, TYP. O N Y N F Z O TYP. ®O6EO /C BOP p WAVHi81.D / ] • • • • ' Z 1 • 0 NOT USED AS PBIBOMB MBA LFWEI EYES UPGRADE OILY. O 5" SCH 80, 0 I AS 8 PER CFEVRON REP. 2W TYP. em 8HT 8.0 FOR COALS 8' -11 9I .. , � I Vz'x3 "x3" W/ o s/e'0 BOLT, 1 0 0 ojNT. ♦ 0 /� 07D CC . 4111 1 - L 3X3xV4" 114 � Q � > TYP. a Q z Y J O /410 11111 10 111. g. I 41111 11160 r 12 ;4- 1- /-- 4 W 5..- (./-) W No7Fs w z w Ct WELD DOWN LEGS TO � � � �� � I ii ..044 44144 IN3V2 x16 x16 ", �� O O ii \ DECKi Q I SO CI7 I Approved for Construction PROJECT NO. 1128.8 DRAWN BY: We " " "- '. CHECKED BY: Signature WJN A ASBUILT ELEVATION VIEW TYP. B ASBUILT ELEVATION VIEW TYP. Inspections Department DATE: 09/26/11 SCALES: NOM 321 SCALE:I /2' I' 0" 321 HORIZ. NOTED SCALE:I /2 " =I' -O" VERT. NOTED SHEET 82 40F 10 • 0 0 °N "' 7 /e" CROSBY �i �'• • / SHACKLE WITH I "0 B 4 i �s'' �.• PIN, TYP. ��` �..•••'• / / / /// 84.0 w to V o . . / >„\\ , . , y. LD • . ''. \ z NEW • GRADING CLIPS • / . w L 2x2xV4 ", TYP. INSTALLED AT EACH —/: ; cr r/ (WELD TO BOTTOM). INTERSECTING MEMBER. / \ FILLET, VT / / Z ROD / / W w / / W LI Y Z m Z > m � < NEW w 'o m BOLT ON HANDRAIL AND L ] U-43 w KICK BOARD. SEE SHE z Q m z S5.0 FOR DETAIL, TYP. F u N 6 j AT CORNERS AND h Q Q \ / , BEAVER SLIDE OPENING Z m Q m — w m NEW • ° 6_ "Y Z ACCESS LADDER '1 11—= • W Fe NEW \ Z L 4x4xV4x2' WI (3) Q Vz "m GALV. BOLTS HEX W /LOCK HEAD WASHNUT. ER AND E 84.0 t@ .,._z N 1 (EXTENDED STEP) / / \ NEW CLIPS a Q Lu 0 INS AT EACH ct I= 1( 0 I._ @ INTERSECTING MEMBER. =111■1 / o Q ‘ N ? Q Ll1 F Q / Y J / Y_ / \ , � / NEW ct BOLT ON HANDRAIL \ W AND KICK BOARD. SEE '' / \ \ S5.0 FOR DETAIL, TYP. / AT CORNERS. \ /, PROJECT NO. ` 1128.8 a Approved Approved fOr , �* prj$tructi0n DRAWN BY: W HO CHECKED BY: WJN DAT E: 09/26/11 A NEW PLAN VIEW _ -- S CALES: NDTED Signature HORIZ NOTED S3•0 SCALE: / " = - O" inspections Deportment SHEET NOTED 61 SHEET S 3 " 0 5 OF 10 o • ":* ° . . • e t i "- SAFETY GATE C "� fCAP j • • ° *� LADDER STRINGER END a a'b� °� + LADDER TYP. \ ° °. - 2" SCH 80 CUT IN RUNG \\ V4" �L� HALF TO MAKE — 1,_3c61 I II I a SADDLE, TYP. PER 2 , 7 „ / / 1 DETAIL S5.0 / Z 0 5 • v ( K/ `� M V +' SCH 40 M TYP. HOOP r MATERIAL o z M i r o 4,,,,5.„ Ex z M L 4x4xV4 "x2' `� W a FIELD FIT FB WITH IVa "x3 /w" Z J WITH" TALL Vz "x2Vz ", TYP. \ I' -4" GRATE ON TOP. , 2 j m a m li BOLD LETTER, TYP. WELD GRATE TO — W U - m @1 i� , V a ' l: ANGLE, 2 -6 E w ON EACH SIDE a _ `� , m J m w ' ■ \ ° z , a 0 N z �� MAX WT -4000 L B3 r ° ° - -1 a u - z as y . - FB Vz "x2Vi', N j m- 0 z L 4x4xV4 "x2' WITH BENT, TYP. Z E N z . m CI IVa "x /i6" GRATE ON U N N Y F z TOP. MATCH EXISTING I HOOP DETAIL GRATING LEVEL. 131 , --1.. C 0 5 /e "0x2" GALV. BOLTS • WITH LOCK WASHER S SCALE:1" =1' -0" 2 AND HEX HEAD NUT. 3 /4" ROUND co TYP. ` � FIELD FIT FB V2"x2V2", TYP. L 4x4xV4 "x2' J NE 71 V2"x2V2' IVz SCH 40 Q BOLTr WITH H HEX I / - HEAD NUT, TYP. TYP. ° / / Q w VT, Et 0 3 /1x TYP. 0 FB Vz "x2Vz FIELD ® ° VT, TYP. Z FIT AFTER x „ DRILL x/16 "0 FB V2"x2V2", V4 Q LADDER SET HOLE, TYP.-- TYP. (BELOW) I , 4„ .. LL Q r. / Q w l WO a" GAVL.� I -2 (� "' _I BOTH W /LOCK `" / R 3 /B "x3x4 I II • Q , I WASHER, AND 1O / L IA" SCH 40 Q z MT, VT TYP > V4'~ NUT, TYP. _ } ° I 2' _ 7" TYP HOOP a . - _ ...� io 3 - ~ OD 2,,,,-\- ® / / MATERIAL _ N � 1 (n , NEW HSS- -� c .c • Y w L 4x4xVa 4x4xVa" J TYP. L 4x4xV4', ° J z w " m TYP. )BEYOND) D LADDER PLAN VIEW ,_ c, c 0 0 NEW 1/2%3• GALV. Z BOLT WITH HEX L , HEAD NUT, TYP. ° N w �� S CALE:) " =1' -0" > CI 0 0 FIELD FIT 0 3" v e Wx3x4, TYP. ON w OPPOSITE SIDE OF z �iloo PLATFORM am °O Cot kr PROJECT NO. 1128.8 Approved for Construction VT, MT, VB "0x6" GALV. DRAWN BY: * 0 WHB TYP. V4 " ' BOLT WITH LOCK WASHER AND HEX CHECKED BY: HEAD NUT, TYP. WJN DATE: 09/26/11 A LADDER ELEVATION VIEW , -- B LADDER SIDE VIEW 5" SCH 80 ILEGI SCALES: NOTED Signature SECTION AA HORIZ. NOTED S4.0 SCALE:) /2 " =1' -0" 840 SCALE:) /2 =1-0 inspections Department " ' " VERT. NOTED SCALE:) " =1' -0" SHEET e4 6 OF 10 • • • • • •ip • •• v 4i-'7 �4i FIELD FIT / ° i -,,t; ; d p . MITER TO FIT EXISTING �rs �, s # �.• HANDRAIL, FLUSH 2" ' " ' A 11/2 SCH 40 4•41.. � V� "0x2V2" GALV. n CARRIAGE BOLT WITH (-- Cor LOCKING WASHER AND , I I NUT, TYP. N 2" SCH BO ° . IT 5 ��� SADDLE, TYP. 2" SCH 80 CUT IN IV2 SCH 40 EXISTING HANDRAIL • HALF TO MAKE 1/4'mx3" GALV. TYP. SADDLE, TYP. CARRIAGE BOLT WITH Z _i-----, NUT AND LOCK �- SECTION AA WASHER A325 MATERIAL. DRILL 5 ,16". F 1 Et HOLE, TYP. W Z A DETAIL FOR REPLACEMENT OF CHAINS AT CORNER ON TYLER RIG WORK PLATFORM m N J 2 5 m 4 85.0 SCALE:3 " =1' -0" W U - 8 Z Q mm m Z J CC IC ' w Z V D a NOTE Z ( Z . N 0 NZ J J THIS DESIGN IS TO REPLACE THE EXISTING CHAIN THAT IS a m Y F Z USED BETWEEN HANDRAILS AT EACH CORNER OF THE • • • 0 WORK PLATFORM. AND KICK BOARD 2 lb N USE THIS DESIGN TO SPAN ACROSS OPENING AT BEAVER 2 SLIDE. ► 6 MATERIAL NEEDED SHALL BE DETERMINED BY FABRICATOR W 0 Q CL c° Z Q 1- _ __1 0 m D: Q 0 Q V4"0xl" GALV. BOLT o Y H WITH NUT AND LOCK q6 WASHER A325 Q -J 2 MATERIAL. DRILL 5/6"0 a q W HOLE, TYP. 0 EXISTING HANDRAIL, , • Q J TYP. - fir- FB V4 "x4 ", TYP. _I-----___„___ TBPV4 "x4 ", I ^ Y_ W I" (D Cr 4fr`4 FB V4 "x4 "xIV2" mi J 1 WIDE, WELDED TO �' Va'0xl" GALV. BOLT B -� B POST, TYP. >- Q WITH NUT AND LOCK —� 0 o a WASHER A325 � Va'x4 "x ' z TOP OF �' o Q MATERIAL. DRILL 5 /16 " Q WIDE, WELDED TO EXISTING I EXISTING o =1v HOLE, TYP. -ce POST, T YP. HANDRAIL, TYP. W GRATING / ,„ PLAN VIEW BB PROJECT NO. 1128.8 DRAWN BY: W88 Approved for Construction CHECKED BY: B DETAIL FOR INSTALLING REMOVABLE KICK BOARD ON TYLER RIG WORK PLATFORM WJN DATE: 09/26/11 85.0 SCALE:3 " =1' -0" SCALES: NOTED HORIZ. NOTED Signature VERT. NOTED 7 SHEET 8 inspections Department 7 CIE 10 ■ mss;. . • 44 3 /e" A 57 2 / 5 „ / r� '.f.,',,1 I. tl 11 LIFTING EYE i VT, MT. '�*.` : ■. '�• TYP.. , \ fie, EXISTING > VT, MT. 14 1 " -----A WELDS, TYP. 3 /e' TYP. / a EXISTING C6. 0 ,ncL2 \ C; -- II, –Kr EXISTING 6" SCH -'� \` = 1� ° EXISTING W 80 SLEEVE ` N GUSSET PLATE. O e L, INSTALL LIFTING 1 R IB EYE OPPOSITE OF " GUSSET, TYP. EXIST C6� 3 /s' A572 to P ` IWO DRILLED TYP.. ING EYE 1 HOLE, TYP. F L. w W z /e' A572 Z N LI LIFTING EYE J m J Ihi V-BEVEL BOTTOM AND 51° BELVEL, I I TYP.. 1 v TOP FOR 3 /e" FILLET, TYP. $" W U m V TYP. (9 J w —�r— Z tt Q m N Z Y a J I-- 1YY r w U oao Z Z m m o to Q m 0 I- IN J J LI 0 Ell - Y I- Z LIFTING EYE PLAN VIEW SECTION AA LIFTING EYE DETAIL • • • z qb ® SCALE:3 " =1' -O" SCALE:3 " =I' -O' SCALE:3 " =1' -0" J2 6 w 0 Q a= cD a_ N I— J a I _ cc) w Q 0 ct Y w �Qw Q J 0 a Q Z_ - ~ o Y LL 3 J ct O ct w L- J 1 1 Q Z 0- O 0 W 2 C...) PROJECT NO. 1128.8 Approved for Construction DRAWN BY: Wne CHECKED BY: WJN DATE: 09/26/11 - - - - - - - SCALES: NOTED Signature HORIZ. NOTED I n spect ions Department VERT. NOTED P SHEET S5 °1 8 OF 10 t., ..... .,:. „, b , • S.. y�. t_ 0** w I4' -88" ° / / z 2 5 w cc �� 7' -6 "± N I L i INSTALL L.E. IN / WITH 2" TALL BOLD REMOVE EXACT PLACE AS OLD ONE z LETTER, ON EACH SIDE EXISTING LIFTING EYE -�� C8x11.5 R V4 " SEE B /56.0 FOR DETAIL w z re Li M AX WT -1700 LBS z N z> N a W U m L 3x3xV4 ", r, J N m m W TYP. 2 I C m N z p Y S ] • U 0 0 Z VI m 0+ 0 Q -J O � g J J U to NY I- Z A EXISTING BEAVER SLIDE SIDE ELEVATION VIEW • • • z 36.0 SCALE :3 /4 " =1' -0" • J a 6 w 0 Q e c, NEW 3 /4" A572 a LIFTING EYE. VT, MT, ALREADY CUT AND 0 --- \ 3 /e' TYP. 1.--- W MTR'S AVAILABLE AT m w PEAK FAB SHOP, Q 0 TYP. (2) REQUIRED Z Y z • (- EXISTING C8x11.5 Q Q J � Q w NEW 3/4" A572 �`J Y Lu LIFTING EYE. i " 3 -J cn o Cr 114" DRILLED Et W HOLE, TYP. W Q —I W > co I— Z 0 Cc 4" � Lu LIFTING EYE DETAIL PROJECT NO. 1128.8 Approved for Construction DRAWN BY: WHB CHECKED BY: WJN B NEW LIFTING EYE DETAIL DATE: 09/26/11 86 SCALE:3 /4 " =1' -O" HORIZ.: Signature HORIZ. NOTED Inspections Department VERT. NOTED SHEET 96 9 OF 10 0 0 ! • A. * ••h.. ire 67, Z 4" i 6 F 1 '4.h•: • 1 l A AI iV ° NEW R 5/e" z A572, TYP. i, CO La cc N C R5/e " A572 ..1.3 LIFTIN EYE, � ��� TYP w \ CO 1- De z v - IVe "0 DRILLED W VT, MT, , N \ TYP. 3/sV HOLE TYP. Z 6 J m � o W U - m < w LP - -t- 4" Zj mmm z P N C7 Fi I - «0 W z rip • M AX. 2500 LBS N U o Q N z � \ TORQUE AT CENTER, 16) REQUIRED Z N MAX. 0 I— in W W w U U] —le 1— z B SNUBBING POST LIFTING EYE ••• z -0 0, • EXISTING 4 " SCH 80S— 87.0 SCALE:3 " =1' -0" WEATHERFORD 15/55 Z POWER TONG WITH A53 SNUBBING POST INTEGRAL BACKUPS ' LAJ ca N O ROTATE PAD EYE ON SNUBBING POST AS c Q USE APPROPRIATE 33 SHOWN, TYP. W MIIP SAFETY LINE FOR O J p TENSION, TYP. PIN BELOW. m Z 0 Z Cr Q R5/e " A572 / /// o(./")iii LIFTING EYE, Q \ 5 "SCH80 Q J TYP. PIPE, TYP. a Q Z -Q U o cn o_ � J 5" SCH 80 - r_ Y I— y LEG, TYP. Z N O �F W D 2 J3 p - 0 SECTION AA m Z NEW PAD W z R 5 /6" A5 I SCALE:3 =1-0 EYE " ' " z N ( SNUBBING POST (4" PROJECT NO. SCH 80 A53 1128.8 DRAWN BY: Approved for Construction W „e CHECKED BY: WJN DATE: 09/22/11 A SNUBBING POST PLAN VIEW _ SCALES: NOTED Signature HORIZ. NOTED 87.0 SCALE:3 /4 " =1' —O” S HEET NOTED inspections Department 57 10OF 10 • • Chevron Tyler Rig Work P Lifting Up Lifting Certification . : 49 * * °` Willi J. Nelson • If a : CE - 5460 m� • ': 441 h •- rofessio 0 ... Nelson Engineering P.C. September 27, 2011 • • NELSON 155 BIDARKA STREINEERS STRUCTURAL CIVIL KENAN ALASKA 99611 ET ENGINEERING (907) 283 -3583 FAX (907) 283 -4514 September 27, 2011 Abraham Purugganan Chevron North American Exploration and Production 3800 Centerpoint Dr. Suite 100 Anchorage, Alaska 99503 Ph: (907) 263 -7603 RE: 13 5 -8 Lifting Plate Dear Mr. Purugganan; Scope: At your request we created detailed plans and performed structural calculations for the lifting and safety of the Tyler Rig Work Platform. Platform Design Asbuilt: The platform has a 10'x10' 6" channel iron framed deck the telescopes up and down on (4) 5" sch 80 vertical supports. Attached to the platform is a 15'x4' beaver slide and one vertical access ladder. In addition (2) 4" sch 80 vertical columns are used as snubbing post. Platform Upgrades: A new vertical ladder was designed and installed that meets Chevron Safety standards, along with a new HSS 4x4x1/4" member to support the bottom of the vertical ladder. New bolt -up handrails were installed at each corner. Grating Clips have been added to secure the existing grating. (3) New 5/8" thick A572 pad eyes were welded to the Snubbing post and (4) new 5/8" thick A572 lifting eyes were welded to the C6 platform frame. In addition, (2) new 5/8" thick A572 lifting eyes were welded to the existing beaver slide. (see drawings). Lifting Eyes: The (4) 5/8" thick A572 lifting eyes on the platform are capable of transferring the estimated wt of 4000 lb weight; this includes the support legs, handrails and ladder. Each lifting eye shall not exceed 1200 lbs. The estimated weight of the beaver slide is 1700 lbs, with a maximum load of 900 lbs per lifting eye. The Snubbing post (1) pad eye is designed for 833 lb. max tension (See attached drawings). Sincerely, . • . � • 1 S �4 : • 49m*': * • Willi J. Nelson . 1 CE 5460 4 ; 1• 4 ; ...... <6' # % professir0 1 September 27, 2011 • • Page 1 Wm, J. Nelson & Associates Project: Tyler Work Platform Structural Analysis CODE : IBC 2006 Unit definitions, k := 1000•lbf si := in 2 psi :_ — lbf ksi :_ — k psf :_ — lbf sf := ft 2 plf := — lbf Vertical Loads: in in ft ft Ground Snow Load: p := 50psf Is := 1.00t:= 1.1 C 1.0 pt':= 0.7•C Ct• Is. p Snow := 50psf Snow = 50psf pf= 39psf Wood Frame Walls Wa11Wt := Opsf Floor Dead Load: Floorwt := Opsf Occupancy Catagory 1I (Per Table 1604.5 page 281) Importance Factors ( PerASCE 7 -05 Tables 7.4, IE := 1.0 I := 1.0 I := 1.0 11.5 -1, 6 -1) Roof Pitch: Slope := 12 4) := atan(Slope) 4) = 0 deg Roof Dead Load: Roofdl := 20psf Building Diaphragm Dimensions New Canopy Building TransverseWidth: TA := 9ft Building Longitudinal Length: LA := 10ft Mean Roof Height: H := 10ft Seismic Loading 2006 IBC (ASCE 7 -05): Seismic Response Coefficient Site Data: Kenai, AK zip code 99611 Site Class Type D, For stiff soil profile. Short Period Spectral Response Acceleration per USGS Program S := 1.29 1 Second Period Spectral Response Acceleration per USGS Program S1 := 0.48 Site Coefficients per Table ASCE 7 -05 Table F := 1.0 F := 1.5 11.4 -1 and 11.4 -2 Max Considered EQ spectral response for short period: SMS Fa Ss SMS = 1.29 Per equation 11.4 -1, p. 115 Max Considered EQ spectral response for 1 second period: SMI Fv SMI = 0.72 Per equation 11.4 -2, p. 115 Design Spectral Response Accelerat ion for short period: SDS := 3 •SMS SDS = 0.86 Per equation 11.4 -3 p. 115 Design Spectral Response Acceleration for 1 second period: SD1 3'SMI SDI = 0.48 Per equation 11.4 -4, p. 115 Occupancy Category: 11 ( non- hazardous, non - essential) Seismic Design Category: D (per table 11.6 -2 pg 116) with Seismic Use Group I SDS = 0.86 and SDS >0.5 • Wm. J. Nelson & Associates Page 2 Structural System Response Modifi Coef per Table 12.2 -1, p.120: R := 3.25 (Non- Building Struct Simialr to Buildings Steel Orid. Conc. Braced Frames) SDS Calculation of Seismic Response Coefficient: Csl R C = 0.265 (Per ASCE 7 -05: 12.8.1.1, Equation 12.8 -2, p129) I Per equation 12.8 -2, p 129 Upper Limit on C.s per Equation 12.8 -3 Hra Height in ft above base to highest level of structure: h := — ft Coefficients from Table 12.8 -2, p 129 Ct :_ .02 x :_ .75 S Approximate Fundamental Period: T := Ct h T = 0.11 C := Dl Cs2 = 1.31 from Eq. 12.8 -7, p129 R I T C IEI a Per equation 9.5.5.2.1 -2, p 146 Calculate lesser of two values: For T< 16s per figure 22.17 C := min(C ,C Cs3 = 0.265 Lower Limit on Cs per Equations 12.8 -5, and 12.8 -6 i o.5.sl C := if S1 >_ .6, R ,.01 C = 0.01 \ lE Calculate greater of two values: C := max(Cs3 Cs4 ) C = 0.265 Load Combination for For Determination of Diaphragm and Shear Wall Shear Load per 16 -12, p. 282 : Load = D +0.7 *E +L + S Note: For shear loads applied to diaphragms and shear walls, only E is effective since vertical Dead , Live & Snow loads are carried by joists, and vertical capacity of walls. Therefore: Shear Loads for diaphragms and shear walls are simplified to: V= 0.7 *E Seismic Factor to be applied to building tributary weight to determine shear force is 'E': E:= C E= 0.185 EQ:= E A check of maximum allowable unit shear required for assumed redundancy factor 'p' is included in the shear calculations. Determine Seismic Lateral Forces andVertical Distribution to Roof and Floor Diaphragms 'A': Label Code: Shear V seismic at diaphragm A. grid A, floor 1, wall= VsAAlwa11 Length : LA = 10 ft Width : TA = 9 ft Roofdl = 20 psf Snow = 10 psf 5 Diaphragm A roof Weight with 1/5 Snow: Weight at Roof level: WsR := (LA + Oft)•(TA + oft + Snow 5 ) WsR = 2700 Wm. J. Nelson & Associates Page 3 Roof Height: hR := Hra hR = 10 ft Vertical Distribution Factors: Total Weight of Roof , second & first level floor and walls: WsA := WsR WsA = 27001bf Diaphragm A: Seismic forces: EQ = 0.185 Total Seismic Base shear: VsA WsA.EQ V = 500 lbf Seismic Shear at Roof VsAR VsA VsAR = 500 lbf Longitudinal VsLAR VsAR Transverse VsTAR VsAR A check of maximum allowable unit shear required for assumed redundancy factor 'p' is included in the shear calculations. • • Wm. J. Nelson & Associates Page 4 Hwi =1 • • Lifting Certification • Structural Analysis Nelson Engineering Project: Chevron- Tyler Work Platform (Lifting Design) Structural Analysis: Sept 22nd, 2011 2 lbf ibf 2 lbf Unit definitions, k := 1000.1bf si := in psi :_ — ksi := — psf := — sf := ft 2 :_ — Concept in in ft ft The Tyler Work Platform is 9'x10' in plan and stands on adjustable legs approx. 10' tall. Four lifting eyes are to be used to pick up the structure, one located on each corner. The structure is conservatively estimated to weigh 3500 lbs. The structural analysis is performed in accordance with the standard, ASME BTH -1 -2008 "Design of Below- the -Hook Lifting Devices ". Design Category (2 -2.2 pg 13) Design Category B - Designated when the Magnitude and Variation of Loads applied to the lifter are not predictable, where the loading and environmental conditions are severe, or not accurately defined. Safety Factors for Design category B lifting devices shall not he less than: Nd= 3.0 for limit states of yielding or buckling Ndc= Nd *1.2 =3.6 for limit states of fracture and connection design Cold Weather Conditions 1. Where cold temperature service conditions exist, including ambient temperature below 0 deg F during use, fracture critical tension materials shall be certified to exhibit minimum Charpy Impact toughness of 25 ft -lbs @ 10 deg F. 2. If Charpy values are not available, an additional safety factor of 3.0 shall be multiplied with the Nd safety factor in order to minimize stresses and potential for brittle failure. 3. Where ambient temperatures during use will not fall below 0 deg F special consideration of charpy impact toughness is not required and the additional factor is not used. Ndc=3.6x3.0=10.8 , for connections (welds and padeye) where material Charpy Impact toughness is unknown and ambient temperatures may reach -50 deg F. Ndc 3.6 Choose Ndc =3.6 or Ndc =10.8, depending on whether or not Carpy Impact toughness can be verified and ambient temperature below 0 deg F. N := 3 Choose Nd =3 or Nd =9, depending on whether or not Carpy Impact toughness can be verified and ambient temperature below 0 deg F. Service Class (2 -3 pg 13) Service Class 0 - Number of load cycles between 0- 20,000. Therefore no design for fatigue required. Materials Welds are made with Dual Shield 1I -70 Ultra electrodes in accordance Ft := 70ksi with AWS D1.1 specs. 1 • • Lifting Certification Structural Analysis Nelson Engineering A500 Strength: FYA500 := 46ksi FuA500 := 58ksi A992 Strength FyA992 50ksi FuA992 65ksi Pad eye plate material is A572 Steel: FYA572 := 50ksi FuA572 := 65ksi A53 Steel Pipe FyA53 35ksi FuA53 60ksi A -36 Steel Strength FyA36 36ksi FuA36 := 58ksi E := 29000000psi Calculations for Lifting Conditions: Total Loaded Lifting Frame Weight load := 35001bf Assume 1/4 of load per pad eye: VertLoad := — load VertLoad = 0.88 kip 4 Load on Padeye due to sling @ 60 degrees P := VertLoad P = 1.01 kip sin(60deg) P := VertLoad Ph := P•cos(60deg) Ph = 0.51 kip Ph := 0 Phx = 357.16 lbf Check Strength of Padeyes Ph := 0.707 Ph Ph = 357.16 lbf Lifting eyes are constructed of 5/8" x 4 "x6" plate and are attached with a 1/4" fillet weld, all around. Load Per Padeye: P := P P = 1010.36 lbf Padeye Material Properties Fy := FYA572 Fu := FuA572 Dimensions of Padeyes Defined Per Figure C3 -3 Thickness of Padeye Material t := 0.625in Diameter of Drilled Hole Dh := 1.125in Diameter of Pin D P := 0.44in Min Edge Distance a := 1M Width of Plate Beyond Hole b := 1.188in Distance of Edge of Plate from R := 2in CL of Hole Factor of Safety Nd := 3 Radius of Padeye r := 2in D :_ = 0.39 ph 2 • ' Lifting Certification . Structural Analysis Nelson Engineering D 2 C := 1 – 0.275 • 1 – C = 0.75 Di, \ Effective Width of Plate bar= min b 0.6• Fu Dh I F y b e beff = 0.9 in (- 2 Loss of Length of one Shear Plane Z' := r – r – • sin(4 )) if Padeye is Radiused 2 ) 11 A := 2.[a + =-• k 1 — cos (+))] — Zi.t A = 1.27 in Allowable Tensile Strength h the pinhole (eqn 3-45) Fu through P (q ) Pt := Cr' • ?•t.beff Pt = 15.2 k 1.2Nd Allowable Single Plane Fracture Fu r DDO 0.92b Strength beyond the pinhole (eqn 3 -49) := C • 1.13• R – — + •t r 1.2Nd 2) b 1 +— Dh Pb= 18.17k Allowable Double Plane Shear Strength beyond the pinhole (eqn 3 -50) Pv := 0.70 Fu Av P = 16.03 k 1.2Nd Find Allowable Load on Padeye Ps allow := min(Pt, Pb Pv) Ps_allow = 15.2 k Based on Plate Strength Allowable Bearing Stress of Pin on Hole Use Eqn 3 -53 for a pin that will not rotate F := 1.25 Fy F = 20.83 ksi under load Nd Check Allowable Bearing of Pin on Hole Pb := F Pb = 5.73 k Maximum Load on Padeye Based on 1 Plate Strength and Bearing Deformation Pallow min(Ps_allow Pallow = 5.73 k P Stress Ratio of Padeyes SR := a SR = 0.18 Pallow Therefore Use 5/8" A572 Plate with 1.125" diameter hole. Allowable Strength for Padeye Welds: Padeyes are made from 5/8" Plate with 1/4" Fillet Weld 3 • • Lifting Certification Structural Analysis Nelson Engineering Use Eccentrically Loaded Weld Group ICOR (Instantanious Center of Rotation) Table 8 -4 on Pg 8 -70 of AISC Steel Construction Manual Size of Weld t := 4 in Length of Vertical Weld L := 6in Length of Horizontal Weld Lh := Oin Eccentricity e := 4in a: =— a =0.67 L Lh Case k := h k = 0 L C := 2 (From AISC Table 8 -4) 70 Ksi Electrode C1 := 1.0 (From AISC Table 8 -3) t Min Size of Weld in 1/16 of an Inch D := w D = 4 Lin 16 L Allowable Strength R := C • C 1 • D• — •kip R = 48 kip (for two welds) R in Nominal Strength R := a R = 5.33 kip 3•Nd Check Stress Ratio of Weld SR := SR = 0.19 R check := if (SR <_ 1, "ok" , "NG ") check = "ok" Therefore 1/4" weld all around is sufficent when 5/8" plate is welded to the channel. Load Calculation Bending In Edge Channel Definitions: Applied Load P := Phx P = 357.16 lbf Dead Load DL := Okip Length L1 := 3ft Length to Padeye L2 := .5ft Bending Moment in Channel Mb := P L2 (L1 — L2) Mb = 148.82 ft•lbf Weak Axis L1 S := 0.488in Allowable Weak Axis Moment Mallow S y N F Nd M allow = 488 ft•lbf allow = d 4 • I Ax -i----,____ ..mr..... .,,,,,-.< ..1 , 1 1.... I A looliiiii,.. i ix r,4 / , ... _ . / . / I II ti f / I 1 ,■- i i SK -2 Sept 27, 2011 at 10:45 AM tyler Work Rig.r3d • I A .i.,..,, 4„,,,.. .........„,,, ill 111 1 4 , 1 „,„.„, , Res. la, 101. O. SK -1 Sept 27, 2011 at 10:38 AM tyler Work Rig lifting.r3d 0 • ' Company Sept 27, 2011 Designer 10:45 AM Job Number : Checked By: Basic Load Cases BLC Description C -te.o X Gravi Y Gravi Z Gravi Joint Point Distributed Area Me...Surface ... 1 Dead DL -1 4 2 Live LL 4 3 Seismic X ELX 2 _ 4 Seismic Z ELZ 2 5 BLC 1 Transient Ar... None 8 6 BLC 2 Transient Ar... None 8 Load Combinations Description Sol... PDelta SR... BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor 1 IBC 16 -8 (a) Yes Y DL 1 _ 2 IBC 16 - (a) Yes Y DL 1 LL 1 LLS 1 3 IBC 16 -10 (... Yes Y DL 1 4 IBC 16 -12 (... Yes Y DL 1 ELX .7 5 IBC 16 - 12 (... Yes Y DL 1 ELZ .7 _ 6 IBC 16 - 12 (... Yes Y DL 1 ELX - 7 IBC 16 - 12 (... Yes Y _ DL 1 ELZ -.7 8 IBC 16 - 13 (... Yes Y DL 1 ELX .525 LL .75 LLS .75 9 IBC 16 - 13 (... Yes Y DL 1 ELZ .525 LL .75 LLS .75 10 IBC 16 - 13 (... Yes Y DL 1 ELX -.525 LL .75 LLS .75 11 IBC 16 - 13 (... Yes Y DL 1 ELZ -.525 LL .75 LLS .75 12 IBC 16 (a) Yes Y DL .6 ELX .7 13 IBC 16 - 15 (b) Yes Y DL .6 ELZ .7 14 IBC 16 (C) Yes Y DL .6 ELX -.7 15 IBC 16 - 15 (d) Yes Y DL .6 ELZ -.7 Joint Boundary Conditions Joint Label X [k/in] Y [k/in] Z [k/in] X Rot.[k - ft/radl Y Rot.[k-ft/rad] Z Rot.[k-ft/rad] Footing 1 N23 Reaction Reaction Reaction 2 N24 Reaction Reaction Reaction 3 N18 Reaction Reaction Reaction 4 N17 Reaction Reaction Reaction Joint Coordinates and Temperatures Label X [ft] Y [ft] Z [ft] Temp [F] Detach From Diaphragm 1 N1 0 10 0 0 2 N2 10 10 0 0 3 N3 10 10 9 0 4 N4 0 10 9 0 5 N5 0 10 3 0 6 N6 10 10 3 0 7 N7 0 10 6 0 8 N8 10 10 6 0 9 N9 6.667 10 0 0 10 N10 6.667 10 3 0 11 N11 6.667 10 6 0 12 N12 6.667 10 9 0 13 N13 3.333 10 0 0 14 N14 3.333 10 3 0 15 N15 3.333 10 6 0 16 N16 3.333 10 9 0 17 N17 0 0 0 0 18 N18 10 0 0 0 RISA -3D Version 9.1.0 [S: \... \... \... \8. Tyler Rig Work Platform \Calcs \tyler Work Rig.r3d] Page 1 . ! 1 • Company Sept 27, 2011 Designer 10:45 AM Job Number Checked By: Joint Coordinates and Temperatures (Continued) Label X [ft] Y [ft] Z [ft] Temp [F] Detach From Diaphragm 19 N19 10 4.667 0 0 20 N20 0 4.667 0 0 21 N23 0 0 9 0 22 N24 10 0 9 0 23 N25 10 4.667 9 0 24 N26 0 4,667 9 0 25 N27 10 2.3335 4.5 0 26 N28 0 2.3335 4.5 0 27 N29 5 2.3335 0 0 28 N30 5 2.3335 9 0 Envelope Joint Reactions Joint X fk] LC Y [k] LC Z fk] LC MX fk- LC MY [k -ftl LC MZ [k -ft] LC 1 N23 max .196 6 2.852 2 .09 15 0 1 0 1 0 1 2 min -.081 12 .233 15 -.186 5 0 1 0 1 0 1 3 N24 max .083 14 2.852 2 .09 15 0 1 0 1 0 1 4 min -.198 4 .233 15 -.186 5 0 1 0 1 0 1 5 N18 max .083 14_ 2.852 2 .185 7 0 1 0 1 0 1 6 min -.198 4 .233 13 -.088 13 0 1 0 1 • 1 7 N17 max .196 6 2.852 2 .185 7 0 1 0 1 0 1 8 min -.081 12 .233 13 -.088 13 0 1 0 1 0 1 1 9 Totals: max .5 14 11.409 2 .5 15 10 min -.5 12 2.045 15 -.5 13 Member Primary Data Label I Joint J Joint K Joint Rotate(de...Section /Shape Type Design List Material Design Rules 1 M1 N1 N2 _ Channe Beam Channel A36 Gr.36 Tvoica 2 M2 N2 N3 _ Channe Beam Channel A36 Gr.36 Typica 3 M3 N3 N4 Channe Beam Channel A36 Gr.36 T •ica 4 4 N 1 - nn. B; - Ch- el A36 r 6 pica 5 M5 N5 N6 Channe Beam Channel A36 Gr.36 Tvoica 6 M6 N7 N8 Channe Beam Channel A36 Gr.36 Typical 7 M7 N9 N10 3x3 Anale Beam Sinale Anale A36 Gr.36 Tvoica • .; 1. 1 11 :.1L• - : -a '1•13 And.; , ; Gr • .' 9 M9 N11 N12 3x3 Anale Beam Sinale Angle A36 Gr.36 Tvoica 10 M10 N13 N14 3x3 Angle Beam Single Angle A36 Gr.36 Typica 11 M11 N14 N15 3x3 Anale Beam Single Anale A36 Gr.36 Tvoica 12 M12 N15 N16 3x3 Angle Beam Single Angle A36 Gr.36 Typica 13 M13 N1 N17 PIPE 5.0X Column Pipe A36 Gr.36 Typica 14 M14 N2 N18 PIPE 5.0X Column Pipe A36 Gr.36 Typica 15 M15 N17 N19 3x3 Angle Beam Single Angle A36 Gr.36 Tvoica 16 M16 N18 N20 3x3 Angle Beam Single Angle A36 Gr.36 Typica 17 M17 N4 N23 PIPE 5.0X Column Pipe A36 Gr.36 Tvoica 18 M18 N3 N24 PIPE_.5.OX Column Pipe A36 Gr.36 Typica 19 M19 N23 N25 3x3 Anale Beam Single Angle A36 Gr.36 Tvoica 20 M20 N24 N26 3x3 Angle Beam Single Angle A36 Gr.36 Typica 21 M21 N24 N19 3x3 Angle Beam Single Anale A36 Gr.36 Tvoica 22 M22 N18 N25 3x3 Angle Beam Sinale Angle A36 Gr.36 _Itpica 23 M23 N20 N23 _ 3x3 Angle Beam Sinale Anale A36 Gr.36 Tvoica 24 M24 N26 N17 3x3 Angle Beam Single An gle A36 Gr 36 Tvpica RISA -3D Version 9.1.0 [S: \... \... \... \8. Tyler Rig Work Platform \Calcs \tyler Work Rig.r3d] Page 2 £ 96ed [p£J' )IJoM J91l1 \soIe0\WJ0}}eId )IJ0m 6p iei i .8 \... \... \...\.s] 0'1:6 uoisJan a£-vsi i I "' 9L4'Z 1141 1. Z40' L£ 1991Z Z A 0 900' 9 91. 900' 4X£X£1 0 IA 4Z 4 - 9L4'Z 444'4 Z401£ 1.98'92 Z A 0 900' 9 91 900' 4X£X£l L W £Z L - ZH "' 9L42 4441 240' 4£ 499'9Z Z A C 900' 9 9'1 900' 4X£X£1 Z 1W ZZ 1 "' 9L4'Z 141'1 zv0' 4E 199'9z Z A £ 900' 9 91. 900' 4X£X£l 6141 1.Z 1. 9L4'Z 4441. z40'1E 199'92 1. A 0 100' 9 91. 900' 4X£X£l 14VII OZ 1 "' 9L4'Z 114'1 Zvo' L£ 1.9912 4 A 0 400' 9 9'1 900' 4X£X£l 811 61 4 - ZH °' ZZ£'Z 141.'1 zpo'L£ 908'14 4 A"'0'9 ZOO' L "'0'9 E£0' 4X£X£1 MN 84 1 - ZH "' ZZ£'Z 144'1 zoo' L£ 908'11 9 A "'o's ZOO' L "'o's ££O' 4X£X£1 4ZW L 1. 1. Z£'Z 441' 1 Mile 90814 9 A ZOO' 9 ££O' 4X£X£l £ZW 91. 1. °' Z£'Z 4411 zvo'4E 908'14 4 A"'o'9 Z00' 9 "'o'9 ££O' 4X£X£1 1ZW 91. 1. 6LZ7 441'4 z4o1.E L90'9L 9' "'9'9 Z00' 9"'9'9 6£0' 4XEX£l 61W 41 1 "' 18Z7 441' 1. zv0' L£ L90'91 L A Z00' 9 6£0' 4X£X£l 911 £ I 1. 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BLC Factor BLG Factor BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor BLC Factor 1 Dead Yes Y 1 1 2 Dead *1.8 Yes Y 1 1.8 Joint Boundary Conditions Joint Label X fk/in] Y [k/in] Z [k/in] X Rot.[k- ft/rad] Y Rot.[k- ft/rad] Z Rot.[k- ft/rad] Footing 1 N23 S.01 S.01 2 N24 S.01 S.01 3 N18 S.01 S.01 4 N17 S.01 S.01 5 N31 Reaction Reaction Reaction Joint Coordinates and Temperatures Label X fftl Y [ft] Z [ft] Temp [F] Detach From Diaphragm 1 N1 0 10 0 0 2 N2 10 10 0 0 3 N3 10 10 9 0 4 N4 0 10 9 0 5 N5 0 10 3 0 6 N6 10 10 3 0 7 N7 0 10 _ 6 0 8 N8 10 10 6 0 9 N9 6.667 10 0 0 10 N10 6.667 10 3 0 11 N11 6.667 10 6 0 12 N12 6.667 10 9 0 13 N13 3.333 10 0 0 14 N14 3.333 10 3 0 15 N15 3.333 10 6 0 16 N16 3.333 10 9 0 17 N17 0 0 0 0 18 N18 10 0 0 0 19 N19 10 4.667 0 0 20 N20 0 4.667 . 0 0 21 N23 0 0 9 0 22 N24 10 0 9 0 23 N25 10 4.667 9 0 24 N26 0 4.667 9 0 25 N27 10 2.3335 4.5 0 26 N28 0 2.3335 4.5 0 27 N29 5 2.3335 0 0 28 N30 5 2.3335 9 0 29 N31 5 21.65 4.5 0 30 N30A 10 10 .5 0 31 N31A 10 10 8.5 0 32 N32 0 10 .5 0 33 N33 0 10 8.5 0 RISA -3D Version 9.1.0 [S: \... \... \... \8. Tyler Rig Work Platform \Calcs \tyler Work Rig Iifting.r3d] Page 1 • 1 1 Company Sept 27, 2011 Designer 10:44 AM Job Number : Checked By: Joint Reactions (By Combination) LC Joint Label X [k] Y fk] Z [k] MX [k -ft] MY [k -ft] MZ [k -ft] 1 1 N23 0 _ 0 0 0 0 0 2 1 N24 0 0 0 0 0 0 3 1 N18 0 0 0 0 0 0 4 1 N17 0 0 0 0 0 0 5 1 N31 0 4.006 0 0 0 0 6 1 Totals: 0 4.006 0 7 1 COG (ft): X: 5 Y: 7.563 Z: 4.5 8 2 N23 0 0 0 0 0 0 9 2 N24 0 0 0 0 0 0 10 2 N18 0 0 0 0 0 0 11 2 N17 0 _ 0 0 0 0 0 12 2 N31 0 7.21 0 0 0 0 13 2 Totals: 0 7.21 0 14 2 COG (ft): X: 5 Y: 7.563 Z: 4.5 Member Primary Data Label I Joint J Joint K Joint Rotate(de...Section /Shape Type Design List Material Design Ru es 1 M1 N1 N2 Channe Beam Channe A36 Gr.36 Tvpica 2 M2 N2 N3 Channe Beam Channe A36 Gr.36 Typica 3 M3 N3 N4 Channe Beam Channe A36 Gr.36 Tvpica 4 M4 N4 N1 Channe Beam Channe A36 Gr.36 Typica 5 M5 N5 N6 Channe Beam Channe A36 Gr.36 Tvpica 6 M6 N7 N8 Channe Beam Channe A36 Gr,36 Typica 7 M7 N9 N10 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 8 M8 N10 N11 3x3 Angle Beam Single Angle A36 Gr.36 Typical 9 M9 N11 N12 - 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 10 M10 N13 N14 3x3 Angle Beam Single Angle A36 Gr.36 Typica 11 M11 N14 N15 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 12 M12 N15 N16 3x3 Angle Beam Single Angle A36 Gr.36 Typica 13 M13 N1 N17 PIPE 5.0X Column Pipe A36 Gr.36 Tvpica 14 M14 N2 N18 PIPE 5.0X Column Pipe A36 Gr.36 Typica 15 M15 N17 N19 3x3 Angle _ Beam Single Angle A36 Gr.36 Tvpica 16 M16 N18 N20 3x3 Angle Beam Single Angle A36 Gr.36 Typica 17 M17 N4 N23 PIPE 5.0X Column Pipe A36 Gr.36 Tvpica 18 M18 N3 N24 PIPE 5.0X Column Pipe A36 Gr.36 Typica 19 M19 N23 N25 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 20 M20 N24 N26 3x3 Angle Beam Single Angle A36 Gr.36 Typica 21 M21 N24 N19 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 22 M22 N18 N25 3x3 Angle Beam Single Angle A36 Gr.36 Typica 23 M23 N20 N23 3x3 Angle Beam Single Angle A36 Gr.36 Tvpica 24 M24 N26 N17 3x3 Angle Beam Single Angle A36 Gr.36 Typica 25 M25 N30A N31 _ BAR2 None None RIGID Tvpica 26 M26 N31A N31 BAR2 None None RIGID Typica 27 M27 N33 N31 _ BAR2 None None RIGID Tvpica 28 M28 N32 N31 BAR2 None None RIGID Typica Member Area Loads (BLC 1 : Dead) Joint A Joint B Joint C Joint D Direction Distribution Magnitude[ksf] 1 N1 N2 N6 N5 Y B -C -.02 2 N5 N14 N15 N7 Y B -C -.02 3 N10 N6 N8 N11 Y B -C -.02 4 N7 N8 N3 N4 Y B -C -.02 RISA -3D Version 9.1.0 [S: \... \... \... \8. 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I 13 5/8" -5000 Z. ■ Choke and Kill lines 21/165M w /uniboltconnections 1 /11.11$1 1!i Ill 11 *ill •lii lil ill 111 `.j - Ill lens! i111 I I 1 Riser 135/85MX` :5M 11.00' do V iii -I I 1 I IVlIII 1/I ill 1.00' to 3.00' Iii di III Ill III . • Bruce, Baker, and GPP project Choke Manifold Ililwirp tI.t.. r.i.c KT# 1 rig . 09/14/2012 To Gas Buster Blooey Line MIS ill'IIIII ar lei 1 I.I � I .. _ 0® `r IN 1.1 ,� ., 1. _ ,I .ter : i N _ El i _ _ :. a . is, III ( I. poni r CI %.,, I) ni el : 0 ; iiMM ®o /Q dii ©, o© ® e up„,,,,,i,,,,..... , 'el A ., MO — _.) - 0 0 i i 7. i i : 1 ;: . 7. 1 m 7 IA • A . i i A. Ir . 0 1r, ° 0 1 . 0 V Nio _ I IIII II I I " SWaCO : Q n Super Choke I. N 1.1 ilWilli 1+ • 1 (1194'03•0; ` Unibolt Connection ©O ,gam. r, 10' in length "— 9' in width 2 1/16 5M Gate Valves • 133451 240 GALLON SKID ACCUMULATOR 7 STATION PLC OPERATED MOTOR #1: US ELECTRIC MOTOR #2: WESTING HOUSE FRAME: 284T FRAME: 284T RPM: 1765 RPM: 1765 HP 25 250/460V HP 25 230/460V 60HZ 64.9/32.5A 60HZ 58/29A R9551- 02 -697MM XH02504TEZ STARTER #1: ALLAN BRADLEY STARTER #2: ALLAN BRADLEY 509CED 25HP 509CED 25HP OVERLOADS W66 OVERLOADS W65 COIL CC236 COIL CC236 PUMPS X2 UNION TX10 1" PLUNGERS CHAIN DRIVEN 16 - NIPPON 15 GALLON TOP LOAD BOTTLES 10 - NZ BACK -UP BOTTLES C/W GAUGES MANIFOLD - 1" BARKSDALE VALVES REGULATORS -1 -1" BARKSDALE MANUAL OPERATED 1 -1" BARKSDALE PLC HYDRAULIC OPERATED 1 - IA" BARKSDALE FOR PLC PANEL PRESSURE SWITCH - BARKSDALE BIX - 54855 -UL -50010 CORDS - MAIN 100A 4W 4P HEATER 60A 4W 4P GAUGES - 4 - 6" LOWER BACK MOUNT TANK VOLUME - #1 - 118"X365"X11" #2 - 118"X36"X14" TOTAL - 462 GALLONS ELECTRIC HEATER - RUFFNECK MODEL - FX416- 208360 -15 -4166 -1095 STEAM HEATER - ELECTRIC MOTOR - EMERSON TYPE KFU3 8.1/9.3A 1725RPM G56FR B2002B LENGTH: 10.5M WIDTH: 3.05M HEIGHT: 2.74M WEIGHT: • Ferguson, Victoria L (DOA) From: Bo York [byork @hilcorp.com] Sent: Friday, October 12, 2012 12:15 PM To: Ferguson, Victoria L (DOA) Cc: Stan Golis; Chad Helgeson Subject: RE: Hilcorp crane certs Attachments: Baker Crane 2012 Annual and Current Load Test pdf; GPP Linkbelt 2012 Annual and 2009 wire rope cert.pdf; GPP Seatrax 2012 Annual and rope certs.pdf Victoria - Attached is the information you requested for our SeaKing crane on the Baker Platform and the LinkBelt and Seatrax cranes on the Granite Point Platform. The current (i.e., 2012) annual inspection for each crane is included as well as a "pull test" or "load test" for the Baker Seaking crane. The LinkBelt and Seatrax cranes have not had an event /change that has required a pull test per API 2D Appendix E in the last five years so only the most recent wire rope certificates are attached for those two cranes. I do not anticipate performing a load test for either of the two Granite Point Platform cranes in preparation for the upcoming well work since the lifts we are looking at needing from either crane is no more than 10,000 pounds which is well within the capacity of the cranes. If you require any additional information or would like to discuss the attached files please feel free to give me a call or email. Regards. Bo York Facilities Engineering Manager byork0Hilcorp.corn 907.777.8345 907.727.9247 (cell) Original Message From: Ferguson, Victoria L (DOA) [ mailto :victoria.fergusonPalaska.gov1 Sent: Thursday, October 11, 2012 12:44 PM To: Bo York Subject: FW: Hilcorp crane certs Subject: P Original Message From: Ferguson, Victoria L (DOA) Sent: Thursday, October 11, 2012 12:43 PM To: 'Bo York' Subject: FW: Hilcorp crane certs Bo, Please provide copy of written reports of last load test and inspection by Qualified Crane Inspector. Thanx, Victoria 1 y • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, October 10, 2012 4:04 PM To: 'Chad Helgeson' Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: MGS Baker 18 (PTD 176 -075, Sundry 312 -362) Chad, Thank you for the information. We will need a copy of the latest certification for the crane. Thanx, Victoria From: Chad Helgeson [mailto:chelgeson@)hilcorD.comj Sent: Monday, October 08, 2012 7:51 PM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Regg, James B (DOA); Harold Soule - (C); Stan Golis Subject: RE: MGS Baker 18 (PTD 176 -075, Sundry 312 -362) Victoria, Attached are the following items. 1. Crane info attached (Vdata files) for the Baker platform and a Crane use minimum guideline for this well work with the KT #1. Crane are certified with inspections quarterly and annually. 2. Well Control cert for Harold Soule (Company Man responsible for this project) 3. Schematic of the rig and equipment layout. (very simple and minimal equipment) Please let me know if you have any additional questions on this Baker 18 project. I will also send you the crane info for the Granite Point platform, where we would like to repair some tubing with the crane and this KT #1 rig. Thanks Chad Helgeson From: Ferguson, Victoria L (DOA) J mailto :victoria.ferguson ©alaska.govj Sent: Friday, October 05, 2012 1:16 PM To: Chad Helgeson Cc: Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: MGS Baker 18 (PTD 176 -075, Sundry 312 -362) Chad, Since you will be using the rig crane for these operations we will need: 1. Proof of certification of the crane and load ratings information. 2. Certification that the crew is trained in well control as conventional BOP's are being used. 3. Provide a schematic of the BOPE , choke and kill lines , choke skid , tanks, as you propose setting on the platform deck. • • Victoria, 1.. Yes we are planning to permanently abandon the current perforations. a. We have considered cementing across the perfs, but in this completion, to effectively cement each perf, we would need to pull the entire completion. b. This abandonment plan meets the requirements in 20AAC 25.105 -172. (we will be setting the plug within 50ft of the top of the perforations. We will placed the cement with a dump bailer on e-line and tag the cement after it has hardened.) 2. Yes, we will be placing the cement directly on the plug up to the top of the packer and then 25ft of cement on top of the packer. 3. Attached is a wellhead schematic for this well. 4. We would like to complete this work ASAP and in October before it gets too cold. I would like to start the slickline and e-line work on Monday and the rig work part of it in about 2 weeks. Please let me know if you have any additional questions. Thanks Chad Helgeson From: Ferguson, Victoria L (DOA) jmailto:victoria.ferguson@ alaska.gov] Sent: Thursday, October 04, 2012 1:46 PM To: Chad Helgeson Cc: Schwartz, Guy L (DOA) Subject: MGS Baker 18 (PTD 176 -075, Sundry 312 -362) Chad, We had a couple of questions on this procedure: 1. Are you intending to permanently abandon the current perforations or is this a temporary abandonment? If this is a permanent abandonment have you considered cementing across the perforations versus the plug with 25' of cement? 2. After setting the plug in x- nipple at 3486'(step 4) we suggest dumping about 10' of cement on the plug as added security. 3. Do you have a wellhead schematic? 4. When is this work planned? Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victo ria.fe rg uson(c� aaska. qov 2 . • Hilcorp Alaska Offshore Platform Crane Workovers Well Considerations 1. Well cannot flow to surface if a crane is going to be used. 2. Work cannot exceed the limits certified on the crane. (provide specs for each crane w/ certificate) Crane & Operator requirements 1. Crane operator must be a certified crane operator 2. Crane operators must be trained on well work (understand how BOPE equipment works and well conditions.) 3. Cranes must be equipped with a Wylie weight indicator that is digital. It will be zeroed for the weight on the hook. All heavy picks will be made with the head block, lighter loads a whip line can be sued. 4. A GAI- Tronics system will be used between the crane operator and the KT #1 floor. Good communications between the crane operator and floor hands is critical to prevent any safety or well situations. 5. Any time jars are installed in the workstring, an accelerator or bumper sub will be used to absorb any shock to the boom on the crane. The cranes are built with significant dynamic weight ratings to handle the movement of boats. Any work that requires pulling something free in the well, and could be exposed to a dynamic load, will be maxed at the dynamic load ratings of the cranes. 6. All work will meet OSHA requirements and Crane certifications. ,,;. .• CI. W II cA p® 6p • ' ,,, t ' • 4 ', rL ILL/ I t { r a y it o� 5 M ,\Air IADC Well Control Accreditation Program :t J 1' i �' ! a ? et '1. „. , • �s n WEL CONTRO SCHOOL ,.. -, , Awards certification of completion to: Harold Ira Soule r , WCS200735199 <; This individual has successfully completed an interactive course in Well Control from a program accredited by the International Association of Drilling Contractors at the SUPERVISOR level in Well Control. . x Full Drilling, Workover /Completion Surface a t ,aurse Type Course Name Stack Qualification ' 0 F, N I NC 1N123225 W809 y :v 26 -Apr -2012 26 -Apr -2014 � ' • Certificate Number Program Number ber g 5 TEM : Completion D Expiration Date Date a Ex p - 7 /P 4 , 7117 i Wasirra, Arc Authorized Signature ,, p Course # - Localion Z; ? Questions or Concerns? Contact WCS at +1-713-849-7400 S • • KT RIG #1 RIG DIAGRAM NORMAL OPERATIONS ,,, / I► ,, , PANIC LINE PLATFOR CRANE 1_ I I + d ��n r KT #1 _ BOP STACK AUTOMATIC 'I■! MANUAL CHOKE ► I T I. \ 11% CHOKE RENTAL ,cam. MUD + 1 PUMP ► _ PUMP A MANIFOLD I � HCR VALVE LP --g SUCTION LINE • AI FLUID TANK - 11 ` • • 3/4/2010 , Seatrax Crane Data Sheet API Dynamic Rated Load Chart (Ref. API Spec 2C, Fifth Edition, 1995 par. 3.2.1a) Purchaser Specified Dynamic Conditions Sea State 2 -3 Winds peed= 12 knots Offlead Angle =3 deg.: Sidelead Angle = 2 deg.: Boat Deck Velocity = 2.28: 13/T Ratio = .46 SeaTrax Series 62 Model SK3500 130 Foot Boom Serial No. 3159 Identification 3159 Working 2 Part Line 4 Part Line 6 Part Line Single Line Radius M ain Hoist M ain Hoist M ain Hoist Auxiliary Hoist (feet) API Load (lbs.) API Load (lbs.) API Load (lbs.) API Load (lbs.) 20 27316c 53574c 78812c 16700b 25 27316c 53574c 74368d 16700b 30 27316c 53574c 68914d 16700b 35 27316c 53574c 64700d 16700b 40 27316c 53574c 61267d 16700b 45 27316c 53574c 58354d 16700b 50 27316c 53574c 55802d 16700b 55 27316c 53508d 53508d 16700b 60 27316c 51404d 51404d 16700b 65 27316c 49442d 49442d 16700b 70 27316c 47587d 47587d 16700b 75 27316c 45813d 45813d 16700b 80 27316c 44103d 44103d 16700b 85 27316c 42438d 42438d 16700b 90 27316c 40807d 40807d 16700b 95 27316c 39196d 39196d 16700b 100 27316c 37594d 37594d 16700b 105 27316c 35752a 35987d 16700b 110 27316c 33973a 34359d 16700b 115 27316c 32363a 32688d 16700b 120 26990a 30935d 30935d 16700b 125 25817a 29033d 29033d 16700b 130 24901a 26801d 26801d 16700b 135 22891d 22891d 22891d 16700b (1) Working radius is measured from the main hook to centerline of rotation (2) Static SWLs are to be used only for lifts from stationary platforms. Dynamic SWLs shall be used for lifts from vessels (3) Lower case letters after SWLs indicate the load limiting factor referenced in API Spec 2C, Sec 3, 3.1.2 (a) thru (f). (4) Rated loads are NET loads. A 1800 lb. main hook block &an appropriate overhaul ball have been deducted from gross loads (5) Main drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 1610 feet long (6) Aux. drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 500 feet long. (7) The specified hook travel for this machine is 240 feet. • • 3/4/2010 , Seatrax Crane Data Sheet API Static Rated Load Chart (Ref. API Spec 2C, Fifth Edition, 1995 par. 3.1.1) SeaTrax Series 62 Model SK3500 130 Foot Boom Serial No. 3159 Identification 3159 Working 2 Part Line 4 Part Line 6 Part Line Single Line Radius M ain Hoist Main Hoist M ain Hoist Auxiliary Hoist (feet) API Load (lbs.) API Load (lbs.) API Load (lbs.) API Load (lbs.) 20 27318c 53576c 78814c 16700b 25 27318c 53576c 78814c 16700b 30 27318c 53576c 78814c 16700b 35 27318c 53576c 78814c 16700b 40 27318c 53576c 75625d 16700b 45 27318c 53576c 70285d 16700b 50 27318c 53576c 65888d 16700b 55 27318c 53576c 62143d 16700b 60 27318c 53576c 58866d 16700b 65 27318c 53576c 55935d 16700b 70 27318c 53263d 53263d 16700b 75 27318c 50791d 50791d 16700b 80 27318c 48474d 48474d 16700b 85 27318c 46275d 46275d 16700b 90 27318c 44169d 44169d 16700b 95 27318c 42131d 42131d 16700b 100 27318c 40141d 40141d 16700b 105 27318c 38176d 38176d 16700b 110 27318c 36215d 36215d 16700b 115 27318c 34226d 34226d 16700b 120 27318c 32166d 32166d 16700b 125 27318c 29953d 29953d 16700b 130 27318c 27382d 27382d 16700b 135 22919d 22919d 22919d 16700b I I (1) Working radius is measured from the main hook to centerline of rotation (2) Static SW Ls are to be used only for lifts from stationary platforms. Dynamic SWLs shall be used for lifts from vessels (3) Lower case letters after SWLs indicate the load limiting factor referenced in APISpec 2C, Sec 3, 3.1.2 (a) thru (f). (4) Rated loads are NET loads. A 1800 lb. main hook block &an appropriate overhaul b all have been deducted from gross loads. (5) Main drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 1610 feet long. (6) Aux. drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 500 feet long. (7) The specified hook travel for this machine is 240 feet. • • • 3/4/2010 Seatrax Crane Data Sheet API Dynamic Rated Load Chart (Ref. API Spec 2C, Fifth Edition, 1995 par. 3.2.1a) Purchaser Specified Dynamic Conditions Sea State 1 -2 Winds peed =10 knots Offlead Angle = 2 deg.: Sidelead Angle =1 deg.: Boat Deck Velocity = 1.24: H/T Ratio = .25 SeaTrax Series 62 Model SK3500 130 Foot Boom Serial No. 3159 Identification 3159 Working 2 Part Line 4 Part Line 6 Part Line Single Line Radius M ain Hoist M ain Hoist M ain Hoist Auxiliary Hoist (feet) API Load (lbs.) API Load (lbs.) API Load (lbs.) API Load (lbs.) 20 27316c 53574c 78812c 16700b 25 27316c 53574c 78812c 16700b 30 27316c 53574c 75275d 16700b 35 27316c 53574c 69820d 16700b 40 27316c 53574c 65501d 16700b 45 27316c 53574c 61923d 16700b 50 27316c 53574c 58853d 16700b 55 27316c 53574c 56145d 16700b 60 27316c 53574c 53699d 16700b 65 27316c 51451d 51451d 16700b 70 27316c 49353d 49353d 16700b 75 27316c 47369d 47369d 16700b 80 27316c 45474d 45474d 16700b 85 27316c 43645d 43645d 16700b 90 27316c 41867d 41867d 16700b 95 27316c 40124d 40124d 16700b 100 27316c 38400d 38400d 16700b 105 27316c 36681d 36681d 16700b 110 27316c 34947d 34947d 16700b 115 27316c 33175d 33175d 16700b 120 27316c 31324d 31324d 16700b 125 27316c 29321d 29321d 16700b 130 26980d 26980d 26980d 16700b 135 22889d 22889d 22889d 16700b I (1) Working radius is measured from the main hook to centerline of rotation (2) Static SWLs are to be used only for lifts from stationary platforms. Dynamic SWLs shall be used for lifts from vessels (3) Lower case letters after SWLs indicate the load limiting factor referenced in API Spec 2C, Sec 3, 3.1.2 (a) thru (f). (4) Rated loads are NET loads. A 1800 lb. main hook block &an appropriate overhaul b all have been deducted from gross loads. (5) Main drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 1610 feet long. (6) Aux. drum cable is .875 dia. 18X19 DY -PAC, 88 kip. nom strength, 500 feet long. (7) The specified hook travel for this machine is 240 feet. • • Infor EAM Print Work Order Work Order 16289 GP CRANE. INSP ANNUAL. CRANE INSPECTION - LINKBELT (P- Scheduled Start 03/30/2012 ACRI -6) Scheduled End Date 04/05/2012 Created By TSCOTT Status WO (Open) Created 03/20/2012 Parent WO WO Type PM Department GPPF Class MICR Granite Point Platform Priority 0 PM Schedule A- GP- L- A-000S Warranty GP CRANE INSP ANNUAL CRANE INSPECTION - LINKBELT (P- ACRI -6) Safety Cost Code Equipment Criticality 1 Assigned To GP- MECHCR Problem Code Reported By Assigned By Project Multiple Equipment No Date Started Standard WO Date Completed Time Completed Campaign Campaign Event Equipment P-CR -4190 CRANE; LINKBELT WEST SIDE Manufacturer LINKBELT Model DET DIESEL 6 -71 ENGINE. Serial Number 186139 Location WO/PM Comments /MABRE'Y102/14f2012 74'102 COMpWd q lot, I tbt- M- GP -I -A -0005 �_ 1 7SCOTTI031J?J20i110.3PJ.a �� P '¢TEL• k-16 �t h�ort e (a;n sntt Cant *,`�,, perof'1 n od c1e. y S Print and complete the attached inspection forms. Create work orders for deficienies found during inspection. Close work order in EAM attaching completed inspection report to work order in the document section_ File orginal inspection in crane file on the facilitiy Send copy of inspection to Trudy Scott for crane file located at CIFO. 03/20/2012 07:26 HILCORP ENERGY COMPANY Page 1 • • Infor EAM Print Work Order "t1; Ai Work Order 16289 Activity 1 Trade MECHCRN Mechanic for Cranes Activity 5tart Date 03/30;2012 Estimated Hours 6 Activity Rid Date 03/30/2012 People Required 2 Booked Hours Employee/Crew Date Time On Time Off Total Time Type of Hours Instruction 1.15t 03/20/2012 07:26 HILCORP ENERGY COMPANY Tr 2 • • Perform Annual Crane Inspections Per API Speditcations RP2D (Latest Edition). C.4.1.2d - Annual Inspections (performed by a Qrialifled Inspector will include Pre - use, Monthly, and Quarterly Inspection, as well as inspections of critical crane components. A basic guideline `or Annual Inspections should consider. but act be limited to, the following. 1.Ot.Perform a 'walk- around' visual examination of the crane boom and support structure to ensure that no damage exists. 2.(' .Ensure the correct Load rating chart for the configuration in use is visible to the crane, operator at the primary Control station. 3.0'ire Visually check wire rope for evident deterioration and damage, or improper reeving. 4. (W, Visually check for loose, missing, or corroded bolts, pins, keepers or cotter pins. 5.1a Further check all control mechanisms for proper adjustment, excessive wear of coma rents, and contamination by foreign matter, 6.1, . Check electrical apparatus for proper function. 7. s, Check boom hoist limit and anti two block devices for proper operation. Care should be exercised to prevent damage to crane components. Boom should be inspected for bent chord members, missing or broker lacing and (reeked welds on critical members. Boom section end connections should be inspected tor cracked welds, deformation and corrosion. 9. t Check boom angle /radius indicators over full range for accuracy. 10 OK Sheaves should be irspected for wear, cracks, rope path alignment and bearin• condition. 11.03. Check power plants for proper performance compliance with safety rcquiraments. 12.C5' Check belts and chains for proper adjustment. 13 ( jK,Visuaily check crane hooks for deformation, and discard if deformations exCee: those manufacturer's recommendations. 14.14 Check lubnr ant level in all hoists and slew drives, including those not fitted with s ht glasses. 15.( We Foundation- Weldments in the cranes pedestal an suoportino deck stem - etre should he visually examined for fracture, deformation and corrosion. Sacral atte "lion should be paid to areas of rust and spilled parrt. 16,oa if Swing Circle Assembly -The swing circle assembly Ls the rnnnerting component between the crane revolving upperstructure and the pedestal. Consequently. regular inspections are paramount to insure a Iona and safe operational life. There are three (3) main types of swing circle assemblies typically used on pedestal moenteri cranes: Type 1. Hook and Roller Assemblies Type 2. King Posts {� Type 3. Bail /Roller Bearings 17.t,„14 Record the Slew Bearing information as follows: ENGINE HRS NORTH ., f 8._ SOUTH_ A)A EAST iv A WEST.,_) A The inspection procedure for each varies significantly and must be tailored, not only to fit the type of swing circle assembly, but also for Me physical and operetinnar environment of each particular crane and platform. Regardless of the type of swing circle assembly, the objective of any inspection is to determine and monitor wear, fatigue, corrosion, and the overall operational condition. The crane and swing circle assembly manufacturers are the best sources for information in developing the inspection program. The following are suggested inspection guidelines for each type of swing circle assembly. Type 1. Hook and Roller Assemblies Ring Gear: a. Center Pin and Bushing condition should he verified and monitored for wens, Center Pin wear is generally due to improperly or unevenly adjusted Hook Rollers. b. Proper lubrication of Center Pin Bushing should be verified. • c. Obvious wear between ring gear teeth and swing pinion gear would indicate Center Pin wear and improperly adjusted Hook Rollers. d. Excessive Lateral wallowing, wobbling, or loud popping noise of machine base for frame indicates Center Pin Bushing wear. e. Bearings ;houbd be well lubricated and should roll smoothly with no noticeable popping or g- inding noise. Hook Roller Brackets, Bracket Pads, and Bolts: a. Machine should be tilted Tully in both directions noting any deflection between the Hook Roller Bracket and the machined surface of the main frame pad where the Hook Roller Bracket mounts. Consult manufacturer for tolerances. NOTE: A forged casting that comprises Hook Roller Brackets very seldom bends or distorts i.e. the main frame generally yields thus causes obvious deflection or gap. b. Hook Roller bracket bolts should be checked for proper bolt torque, excess stretching, excess rust pitting, improper size, etc. Type 2. King Posts. Bearing areas of the crane should be inspected to assure that there is no significant wear or damage to either the rotating or stationary foal bearing members, that left uncorrected, might result in a !ass of structural integrity of the mounting system. The King Post crane inspection procedure will depend or the design of the crane being inspected. The inspection should include but not be limited to the following: Upper thrust bearing. * upper radial baring. " Lower thrust bearings or wear bands. * Kind pin wear and condition. " Lower King post wear bandy The wear band condition is critical as it protects the king post from the tower thrust rollers or wear bands. On cranes not equipped with a wear band or if the wear band is excessively worn, the wear one on the king post must be carefully monitored to insure the structural integrity of the king post. * King post to platform structural connection. • REFER TO LINKBELT CRANE INSPECTION FORM PREVENTIVE MAINTENANCE CHECK SHEET INTERVAL: @Hie Elul' 4 1 t•IANUF.: LINKBELT EQUIPMENT TYPE: MODEL NO.: HC -208 NO: 18T139 SERIAL NO: 18T131 Hour Meter Reading: j 1 ( Hour Meter Last Month's Reading: Total Months Usage: Date completed: L f" t vS inspector:, All inspections, adjustments, repairs, and lubrication must be performed ;n accordance with manufacturer's specifications and ANSI /OSHA regulations. Refer to applicable manuals. Symbols: OK = OK or Completed IN == Incomplete RR = Repair or Replace NA Not Applicable UN = Unsafe: IMMEDIATE PRIORI — Y XX = See Remarks CI Corrected by Inspector CAUTION: Serious or fatal injury can result if safety precautions which follow are not taken: "Stop engine and wait until all moving parts are co'np'etely stopped hefore servicing machine. **Attach CAUTION tag or " OUT -OF -ORDER" Sign to engine start controls in operator's cab and at each engine to warn Personnel that machine is being serviced and must not he started. *•Do not operate machine until all safety guards and covers are securely reinstalled and all maintenance equipmert is removed, 1. MAIN HOIST w ,, a. Frame Structure b. Dr+rrn Condition O c. Brake Band Condition d. Brake Band Adjustmen e. Brake Cam & Bushing 0 f. Brake Actuator Condition( q. Brake Actuator Operation ii.. h. Hoist shaft Retainers (1 Check two block warning device(' , j. Wedge /Socket/Cabte Dead End 01 k. Check Clutch for Operation and AojuStrnenta I. Check Drum Brake and Brake Pedal for Proper Operation QiL._ 2. Auxiliary Hoist a. Frame Structure 0 b- Drum Condition C, }C c. Brake Band Condition ilk d. Brake Band Adjustment ,�1C e, Brake Cam lk Bushing Ql. f. Brake Actuator Condrticr 1i g. Brake Actuator Operation h. Check twn hint* novice h. Hoist shaft Retainers � wedge /Socket /Cable Dead End eat,_ j. Check Clutch for Operation and Adjustment t k. Check Drum Brake rd flrake Pedal for Proper Operation (`)1 3. Boom Hoist • • a. Drum Condition (.2g b. Brake Band Condition c. Brake Band Adjustment 1 d. Brake Cam & Bushioo e. Brake Actuator Condition — f. Brake Actuator Operation ;fit( g. Horst shaft Retaine h. Wedge /Socket/Cable Dead End CW r. Check Clutch for Operation anc; Adjustment ea j. Check Drum Brake. and Brake Pedal for Proper Operation flit k. Boom dog Operation alL 1. Check Boom High Angie Li it Swrtch C Z m. Check Angle Indicator,-QA 4. SWING SYSTEM a. Drive Gear Condition 0.K_ b. Gearbox Oil Level (To Fill Plug) ALA c. Check Clutch for Operation and Adjustment (LS. d. Check Drum Brae•_ and Brake Pedal for Proper Operation {Q1 __ 5. CAB/TURNTABLE a. Glass Condition b. Controls Conditi c c. Controls Operation i, _ d. Seat Condition „,f...\ e. Gauges & Instruments OW- L Fuel Shutdown Operation 6 -L g, Have Electnclar. `heck Collector Ring For Proper Function `!!f _ L h. Throttle Operation law_ 1. Valves Condition S1'L j. Check Helicopter Wanting Light 54t. _ k. Clean All Debris From floor, Stairs and Catwalk IOC I. Check That All Machinery Guards Are In Place C: V m. Load Charts Condition, Correct Serial Number and Correct Chart for Parts of Lne Being Used C itZ n. Check That the Documents are Current and In Order 04__ 0. Load Indicator OK p. Hoses Condition _Qlt__ q, Swing Brake Operation , r. Bnom Foot Mounting Plates 64 s. Turntable to Gantry Bolting Pads ® t, House Bearings Condition 1, &: 6. ENGINE a. Engine Hours 1 X, b. Fuel Filters c. Air Breather r'?1 d. Radiator . e. Water Level: W ter condition S? Antifreeze r1 f. Oil Level +_) _ g. Oil Cooler h. an Belts s _ 1 i. `tarter Condition J. Hyd, Pump Fittings k. Hyd. Pump Hoses 1, Tachometer Drive S � m. Muffler . K 7. BLOCK & SPF FADER a. Structure b. Spreader Pin & Retaineiit& c. Sheaves C d. Sheave Shaft & Retainei 8. GANTRY D � a. Structure ,1ck • • b. Bolts /Nuts; LockwashersC ` __ c. Sheaves ` \C 0. Sheaves Shaft & Pit InerQA& e. Ladders & Decks � f. Wire Rape Dead End 9. Wire Rope a. Check critical wear points (1) Check wire rope that epeatedly is stressed from contact wit! sheaves , :1..__ (2) Check end attachments where fittings is attached to wire rope and where wire rope is attached to drum. (Limit of one broken strand near any attaching fitting) (')1l (3) Check for abused points where wire rope could be scuffing and scraping CAL b. Check wire rope Diameter (compare used rope with original measurement. Maximum rope reduction is 1/15 for 7/8" ano 1" rope6c. C. Check for broken wires Thoroughly dean the wire rope so breaks can be seen. Relax the rope, move the rope off "pick -up poirts," and flex the rope as much as possible. (1) Take out of service if exceeds; (i)RUNNING ROPES (working lines) 6 randomly distributed broken wires III one rope lay length, or three brr wires in one strand cf one rope lay length. k! (ii)STAND1NG ROPES (Pendants) It more than two broker wires in one rope lay Length in sections beyond the end attachment, .. more than one broken wire at the end attachment C \< d. Check for wear on individual wire strands. Replace if one -third the angina; diameter of outside individual wires elc e. Replace any wire rope that has kinks, crushing, birdcaging, or any other damage resulting in distortion of the rope structure K f. Replace . any evidence of heat damage from any cause g. Check each sheave, roller, and drum (I) Check the depth, wid, and contour of each sheave using a groove gauge. �j (2) Replace sheaves and drums t have broken flanges or cracks in the hubs, spokes, etc G (3) Check for defective bearings (4) Replace the drums to see if one wrap of wire rope veil contact the next wrap as the wire rope spools onto the drum. Q_ h. While ieelirg in and out wire ro ^.e watch the card length. Any change in the cord length will indicate possit:i'' ore damage and should immediately be investigates.. _.. 10.WIRE ROPE & PENDANTS a. Room Hoist: (1) Diameter/Condition .11 1 8k' b. Main Hoist: �I�b1�• � (1) diameter / Condltion i c. Auxiliary Hoist: �5 /6K (1) Diameter /Condition! d. Pendant Lines: (1) Diameter /Condition }.1 751G1 (2) Picts & Keepers C 11. BOOM a. Poise/Jib (I) Cords /Lacing (2) Bolts /Nuts /Lockwashers(1K _ (3) Sheave Shaft/RetAners Qom_ (4) Cable Guard R7 • • (5) Two Black Frame 9K (6) Wire Rope Dead End (7) General Conditior , 12. Butt Section a. Chords/Lacings )% b. Botts /Nuts /Lockw,Ishers c. Hoist Mounting ,_ d. Radius Indicator∎ e. Boom Foot Bushings f. Boom Foot Pins .� g. General condition 13. Strai ts: a. Qty: ... b. Chordsf Lacing c. Bolts /Nuts /Lockwashers d. Genera` Condition C,,Z 14. HEADACHE BALL a. Structure b. Hook condition c, Pin & Keeper ex d. Safety Latch Cl� 15, MAIN BLOCK a. StructureCy \k b. Hook & Safety Latch Q. _ c. Thrust Beanngt: d. Sheaves(T1k. e. Sheave Shaft F. Reta ner 16. HYDRAULIC SYSTEM a, Pump b. l=itter /Strainers ems_ C. Oil level /Conditic d. Hoses & Fittings �p�Ct. GA 4orcitu. ebnuerit[' E}1a W , ', n t S. , Gotrc1S .o^ - New o4ei 4o $r' �►p q,tt� - fit' N �cada� es Sho�tng trI ° i ' 4 Gari pins :5 n44 4 k, n9 rrasG -- 1.160 - Neeb +► Qtrpaa+ } ItISOe E01- Mr ;in -Nue tor toa oli +wr► or more . — 1NEW ta.'t d' r A PB, rtecst Q etve 84c* 441 y pao . - � • • Orientation -Shift Change Crane Inspection This Inspection Is to be performed by Qualified Personnel Critically 1 Equipment Link Belt pp Facility: e (_r=� ft. rl : n4 Engine room 1. Ca Check engine oil 2. fVe engine water 3. CA (Check that the water heater is working (winter) 4. g)Check oil lubricator oil level 5. OC,Check fuel and hydraulic oil 6. aCheck Accumulator fluid o First actuate any hoist function until hydraulic pressure drops to zero o Then check hydraulic dipstick tor proper lavr_i 7. Q Check for oil and fuel leaks around the engine 8. • c;ean up rags and tools 9 ki Cher* boom pawl 10. ,4heck torque converter Fuld c Location left hand side under radiator (Ntnnnpod) 11. 6 1 Check brake condition and adjustment. refer to service manual for correct adjustment 12. � Check of level in all gear boxes 13. j_ Check drive belt and sheave for hydraulic pump Operators cab 1 Cheek for oil leaks 2. 0 Clean up all rags and tools 3. .01C Start engine and watch oil pressure gauge 4. or Warrn up engine 5. 4e Check electrical apparatus for proper function 6. ,.aj?'Check all gauges for proper functions 7. f _Check the weight indicator function 8. LW Check hnnm angle indicator function 9. . for correct load rating charts and visihte to the operator 10. Check window. wiper and horn 11. o f :heck radio communications Visual Checks 1. QZFrom the platform deck visually check the cords and lacing for damage. check all boom section bolts and foot pins 2 C 4Check tor loose, missing, or corroded bolts, pins. keepers or cotter pins 3 04'Chr:r t the boom tip sneaves for damage, main toad limp dead end attachment. and that all cotter keys are in place 4. _ Ched the gantry sheaves. rope and boom wire rope dead end 5. Check the load block and whip sheaves and safety latches 6. aiK.Check the swing bearing. pinion. teeth and mounting bolts 7. Check the helicopter warning light 8. A4e.iher it an loose gear, such as slings. sting honks, shackles, line lubrication and end fittings Operational Test 1. OLFunction check main, whip, and boom hoist brakes, certches and actuators for proper operation and smoothness 2. ex Check that all controls return to neutral when released and operate freely 3- a - awing crane in both directions checking for roughness or excessive free play 4. ex Raise the boom up to the upper boom limit cut out. exercise care to prevent damage to crane components 5. a Function check main load block anti -2 -block alarm (CAUTION Alarm only) 6. a" Check whip anti -2 -block art -out --must disable both whip raise and boom down 7. MLower to the water the whip and main load blocks Check the rope ter damage or spoofing problems and at least 5 or more wraps of rope remaining on drum. 8. O1/ Over the water or platform deck lovref boom down to horizontal 9. ill. Raise boom to park position and dog in the boom pawl, slowly boom down against the pawl to assure the pawl is locked into the drum DISCREPANCIES/COMMENTS: . _$.Aat. in rev* C,Ntuer4er. r_ ele. sbn�win S: . of___ Caori^o s l o ,_[� in ps t fait: t .S.4.� Met,; ( clebte c.5 -5 I�AL2r t r+e�s>lr�h lc.±o, 1'roe� � r ! ocrte�lk]a.:11.- 4.;a 4►ve, wr'a f s o � t k kni► . Sat Zs aryrtt _ 02/16 /12 Rev 5 Foreo-d Completed ropy to: Cook Inlet Field Ounce w Link Belt Shift Change Inspection Page 2 Approximate time taken for inspection Crane Hours_ 118 EAM Equipment # (circle): , MP -West M -CR -2040 Crane Hours: CRANE OPERATOR SIGNATURE: d3.01:0 %oft &l u . — _ Date: _ 41-91- �a CRANE OPERATOR PRINTED NAME: ad`? p n L 1 ; if 4.; NOTES #f. Deficiencies found that cannot be connoted without additional resources require a Work Request written in EAM (fTt except for Priority 1 work. Priority 1: Requires immediate HES or has motor production loss. The repair will be completed followed by a Work Request. (Break -In Schedule). Priority 2: HES issue or moderate production toss. Repaired within the next 1 days (Break -In Schedule) Priority 3: Minor production Toss, repairs should to start within the next 14 days. Priority 4: Repairs should start within the next 30 days Priority 5: Facility shutdown or project work. For more details please see "Managing Priorities" listed in CRANES Shift Change Inspections folder, Check indicating that work requests were created for discrepancies listed. CHEVRON REVIEWER SIGNATURE: _ Date: 02/16112 Rev 5 Forward Completed coin w: Cook Inlet Field Office ' de / 3 49' 0 3 1 4.1 BRIDCJN AMERICAN CERTIFICATE OF EXAMINATION OR TEST OF WIRE ROPE WIRE ROPE DESCRIPTION: 3/4" DY34LR 2160 RLANG HPTP CUSTOMER: ARCTIC WIRE ROPE & SUPPLY CUSTOMER ORDER NO: 113401 BRIDON AMERICAN ORDER NO.: 566G7 DATE TESTED: 818/08 REEL NUMBER: 077615A00 MINIMUM BREAKING FORCE: 80,000 LBS. 36,286 KGS. ACTUAL BREAKING FORCE: 84,700 1-BS. 38,419 KGS. OFF TENSION DIAMETER: 0.778 DATE: 9/03/03 CO* 10 CHECK BY:DC — SIGNED: 4-401 TECHNICAL DIRECTOR Srldon Arnencan Ouahly Program Cert t1cattu t. American Petroleum institute Spec 01 and 9A, License #9A0058 t Inyds Register Quality Assurance -ISO 1)001:2000, t icense #101907 • I3ridon American wire ropes are Manufactured to the applicable roquirornonls of API 9A and ASTM1023 WARNING: Any warranties, expressed or Implied, concerning the use of this product apply only to the nominal strength of new. unused wire rope. All equipment using this product must be properly used and maintained. Wi'o rope must be properly stored, handled, used and maintained. Most Importantly, wire rope must be regularly inspected during use. Damage. abuse or nrproper maintenance can cause rova failure. Consult the AISI Wire Rope Usorc Manual, ASME or ANSI Standards, or Rridon Amerrrstn Corporation before usage. Wire rope removal criteria are based on the use of steel sheaves. It synthetic sheaves are used, consult the sheave equipment manufacturer WARNINGI RAMOON American Corporation ^1 Ne.v r :v i; er:r 50lAvard .'lit es-Cetry Piircisylvarilii 1070C t1,0 3« 3341 fax 147 Ot 03 • • Orientation-Shift Change Crane Inspection This inspection is to be performed by Qualified Personnel SeaTrax Facility O W ? 1 4. a , 'or a4. Engine Room 1. Qk Check engine oil 2. 0 Check engine water 3. LCheck water heater is working (winter) 4. jl{, Check oil lubricator oil lever 5. Q, _Check fuel level 6. ii,LCheck hydraulic oil level 7. .' =_Clean up rags and tools 8. _Check boom pawl 9. :heck all gear boxes for external leaks Operators Cab 1. 0(Check for oil leaks behind operators seat 2. (� Clean up all rags and tools 3. ( ___Stan engine and watch oil pressure gauges 4. o°` Warm up engine 5. 4., Check electrical apparatus for proper function 6. 4 L Check alt gauges for proper functions 7. el Check the weight indicator function 8. to Check boom angle indicator function 9. ♦ Check for correct load rating charts and visible to the operator 10. G1/ Check window wiper and horn 11, Ci K Check radio communications Visual Checks 1. OK From the platform deck or crane cab check the cords and lacing for damage, check boom section bolts and :t pins for irregularities 2. Check for loose, missing, or corroded bolts. pins, keepers or cotter pins. 3. ♦ [ Check the load block and whip sheaves and safety latches 4. b , Check all hydraulic hoses between the boom and car body for damage, visually check the swing gearbox for l ti a or missing bolts, and of leaks 5. r at Check the lower swing bearing wear pads, chain, teeth and mounting bolts 6. nspect boom pedestal, flanges, bolts, etc. 7. OK Check helicopter warning light 8. Check the gantry sheaves, rope and boom wire rope dead end and upper rotation bearing 9. Check all loose gear, such as slings, sling hooks. shackles, line lubrication and end fittings Operational Test 1. (Function check the main, whip, and boom hoist drums and brakes, brake actuators 2. OK Check that all controls return to neutral when released 3. jot( Swing crane in both directions checking for roughness or excessive free play 4. (,_Raise the boom up to the upper boom limit cut out. it should stop the boom 4 inches before the boom stop. Excr vise care to prevent damage to crane components. 5. taIC Function check anti -two block devices for proper operation. Exercise care to prevent damage to crane mts• 6. ( „ the engine at full RPM. rotate the Emergency spooling device. Watch the Main load line brake actuator arm, it should rotate to the released position. if brake actuator arm rotates to the released position quickly rotate the emergency spooling to the normal position. CAUTION: LOAD BLOCK WILL SLOWLY LOWER IF SPOOLING DEVICE IS OPERATING CORRECTLY. 7. ('54( Lower to the water the whip and main load blocks Check the rope for damage or spooling problems and at feast 5 or more wraps of rope remaining on drum. 8. Ilk . Over the water or platform deck lower boom down to horizontal 9. GY else the boom to parking position and dog in the boom pawl, slowly boom down against the pawl to assure the pawl is locked into the drum. illikSCREPANCIES/COMMENTS: ��//� 1, .. i i tor.) l:. . r3/ rH l . e.. l0 e • litre. ho4.4F "m on flya 2� t.. ., u . ' : „` 4.5 - O WI Q pp , , • • a skr►el a r .-r4r... r l c t_ C_ Sa f) _fl:'_E _Ubh a k -. 4 'fJl b <- __' 1 j G I' 410 02/16/12 Rev 5 Forward Completed copy to Cook Inlet Field Office • • a Print Work Order Work Order 1'_" (;I' ?"RAT V: tr p r N nd �w 1l 1 dtdi3fiL CRin�:'t � �P =„ f ICs .CF-F }PAX iF Sc eduied 'Start ACR! -51 Scheduled End Date ta;. }`..; 1 Created By TS (( Mr . Status 'tY : t.(:In r Created 0.,' U .2012 Parent WO WO Type PM Department GPPF Class MICR Granite Point Platform Priority 0 PM Schedule A- GP- 1- A-0004 Warranty GP CRANE INSP ANNUAL CRANE INSPECTION- SEATRAX (P- ACRI -S) Safety Cost Code Equipment Criticality Assigned To GP- MECHCR Problem Code Reported By Assigned By Project Multiple Equipment No Date Started Standard WO Date Completed Time Completed Campaign Campaign Event Equipment P -CR -4180 CRANE: SEATRAX EAST SIDE Manufacturer SEATRAX Model 6020 Serial Number Location WO/PM Comments JMABREY[02/1a/2072 14:101: COMP 1mac( 1 4 - t a- t a M-GP -l-A -0004 Cbdh Pk e , t etot i cot 04a - Tam i e„ 75C077103/12/2012 10.-501: 1:2 6n)11 n Print and complete the attached inspection forms. etetect 74 9 9 Create work orders for deficienies found during inspection. Close work order in EAM attaching completed inspection report to work order in the document section. File orginal inspection in crane file on the faciiifry _ Send copy of inspection to Trudy Scott for crane file located at CIFO. T5CO7T[03/12/2012 7320: Print and complete attached inspection forms. Close work order and attach completed inspection forms to work order in the document section of EAM. Create work orders for deficiencies found during inspection. File the completed inspection on the facility in the crane file. Send a copy of the completed inspection to Trudy Scott at CIFO for crane files in that location. 04/17/2012 12:08 HILCORP ENERGY COMPANY Page 17 • . SeaTrax Shift Change Inspection Page 2 Approximate time taken for inspection a r4 S EAM Equipment a (cede): Anna: A-CR -0650 Bruce: U-CR -0650 GPP: P-CR -4180 MP: M-CR -2020 Crane Hours. ` t3 ! ` CRANE OPERATOR SIGNATURE: "AO"; klet#7 4-altr..-- Date: Y" 14-142 CRAM OPERATOR PRINTED NAME: Tat^r f a.ctetta NOTES: Deficiencies found that cannot be corrected without additional resources re a +Nor{ nest written in EAM (but except for Priority ' work. Priority 1: Requires immediate HES or has major production loss. The repair will be completed followed by a Work Request. (Break -In Schedule). Priority 2: HES issue or moderate production loss. Repaired within the next 7 days (Break -In Schedule) Priority 3; Minor production loss, repairs should to start within the next 14 days. Priority 4: Repairs should start within the next 30 days. Priority 5: Facallty shutdown or project work. For more details please see 'tTar jir g P''_ _: ii.. _' listed in CRANES Shift Change Inspections folder. Check indicating that work requests were created for discrepancies listed CHEVRON REVIEWER SIGNATURE: __...__ Date: III 02/16/12 Rev 5 Forward Completed copy to Cook Inlet Field Office • • REFER TO SEATRAX CRANE INSPECTION FORM. PREVENT IVE MAINTENANCE CHECK SHEET INTERVAL: twAR.TateY QV ¢ t MANUF.: SEATRAX EQUIPMENT TYPE: CRANE MODEL NO.: 6020 LOCATION AND SERIAL NO: G.P.P East 4114 Mon�opOd`East 4149 Hour Meter Reading: 8 319 Hour Meter Last Month's Reading: Total Month's Usage: Date completed: 4 - tq - la _ Inspector: 321+,;. ;1. ' _"X - -- All inspections, adjustments, repairs, and lubrication must be performed in accordance with manufacturer's specifications and ANSI /OSHA regulations. Refer to applicable manuals. Symbols: OK = OK or Completed IN - Incomplete RR = Repair or Replace NA = Not Applicable UN - Unsafe: IMMEDIATE PRIORITY XX ., See Remarks CI = Corrected by Inspector CAUTION: Serious or fatal injury can result if safety precautions which follow are not taken: * *Stop engine and wait until all moving parts are completely stopped before servicing machine. * *Attach CAUTION tag or " OUT-OF -ORDER" sign to engine start controls in operator's cab and at each engine to warn personnel that machine is being serviced and must not be started. * *Do not operate machine until all safety guards and covers are securely reinstalled and all maintenance equipment is removed. 1. MAIN HOIST a. Frame Structure . b. Drum Condition CAL' c, Brake Band Condition d. Brake Band Adjustment �_ e. Brake Cam & Bushin f. Brake Actuator Condition 7e g. Brake Actuator Operation nY h. Hoist shaft Retainers O& i. Wedge /Socket/Cable Dead End CI< j. Hydraulic Motor ConditionQ k. Shaft Spline Condition 01 I. Gearbox Externals Condition (XL m. Gearbox Oil Level (To Fill Plug) 01- n. Drum RPM N14 o. Check two block device OK . 2. Auxiliary Hoist a. Frame Structure L h. Drum Condition f c. Brake Band Condition og d. Brake Band Adjustment nl1` e. Brake Cam & Bushing (� f. Brake Actuator Condition0V[ _ g. Brake Actuator Operation ( }( h. Hoist shaft Retainers OK i. Wedge /Socket /Cable Dead E [)K j. Hydraulic Motor Condltlon(9 k. Shaft Spline Conditior - I. Gearbox Externals Condition_ m. Gearbox Oil Level (To Fill Plug) ,( )1 • • n. Drum RPMQK o. Check two block devieeOk 3. Boom Hoist a. Frame Structure 3 b. Drum Condition O ( _ c. Brake Band Condition (31( d. Brake Band Adjustment s ag e. Brake Cam & Bushingok f. Brake Actuator Condition g. Brake Actuator Operation h. Hoist shaft Retainers('i4 i. Wedge /Socket/Cable Dead EndOk j. Hydraulic Motor Condition({1i k. Shaft Spline Condition I. Gearbox Externals Con ition )k. m, Gearbox Oil Level (To Fill Plug) n. Drum RPM NA o. Boom dog Operation and Visually Check Dog PawlC p. Check Boom High Angle Limit Switch (Move Boom to Just Slowly Close the Limit Switch Should Stop Boom) fix_ 4. SWING SYSTEM a. Drive Sprocket Condition b. Kingpost Sprocket Cond q'on je _ c. Sprockets Alignment() K. d. Gearbox Oil Level (fill 1.25 from top of case) OR e. Drive Motor Condition ok. f. Crossover Valve Operation (3k 5. CAB/TURNTABLE a. Glass Condition (! lL b. Controls Condition c. Controls Operation _ d. Seat Condition Q e. Gauges Instruments F. f. Fuel Shutdown Operation _Q g. Emergency S.D. Oper lion h. Throttle Operation i. Valves Condition C�1 j. Boom Relief Valve Setting (3200 psi) • __ k. Main /Aux. Relief Setting (3200 psi) ' 1. Swing Relief Setting (2000 psi) a, m. Co t ntrol ystem Relief Setting (500psi at Idle/600psi at Max. RPM) n. Two Speed Operation �] o. Load Charts Condition (3L__ p. Load Indicator q. Boom Dog Operation QM r. Hoses Condition %IL s. Swing Brake Operation t. Boom Foot Mounting Plates ( u. Turntable to Gantry Bolting Pads v. Lower Bearings Condition, 6. ENGINE a. Engine Hours • S( b. Fuel Filters i c. Air Breather 't d. Radiatoro_ e. Water Level f. Oil LevelCli( g. Oil Cooler &' h. Fan Belts i. Starter Condition • j. Hyd. Pump Fittings • r k. Hyd. Pump Hoses • t�// I. Hyd. Pump Gear Box Oil LeveeR m. Tachometer Drive Qtr_ • • n. MufflerOl< 7. GANTRY a. Structure _014_ b. Bolts /Nuts/L washers /4, c. Sheaves CAC- pp/ d. Sheaves Shaft & R t inept` e. Ladders & DecksQ)(. f. Wire Rope Dead End 8. Wire Rope a. Check critical wear points (1) Check wire rope tharepeatedly is stressed from contact with sheaves _ (2) Check end attachments where fittings is attached to wire rope and where wire rope is attached to drum. (Limit of gge broken strand near any attaching fitting)Q. _ (3) Check for abe�d points where wire rope could be scuffing and scraping O K- b. Check wire rope Diameter (compare used rope with original measurem J�t. Maximum rope reduction is 1/16 for 7/8" and 1" rope �')` c. Check for broken wires Thoroughly clean the wire rope so breaks can be seen. Relax the rope, move the rope off "pick -up points," and flex the rope as much as possible. (1) Take out of service if exceeds: (i)RUNNING ROPES (working lines) 6 randomly distributed broken wires in one rope lay length, or three broken wires in one strand of one rope lay length, O11. (ii)STANDING ROPES (Pendants) If more than two broken wires in one rope lay length in sections beyond the end attachment, or more than one broken wire at the end attachment NT., d. Check for wear on individual wire strands. Replace if one -gird the original diameter of outside individual wires e. Replace any wire rope that has kinks, crushing, birdcaging, or any other damage resulting in distortion of the rope structun4 V\„__ f. Replace if any evidence of heat damage from any cause g. Check each sheave, roller, and drum (1) Check the depth, width, and contour of each sheave using a groove gauge. C1 _ (2) Replace sheaves and drums that have broken flanges or cracks in the hubs, spokes, etc (3) Check for defective bearings 0' (4) Replace the drums to see if one wrap of wire rope will contact the next wrap as the wire rope spools onto the drum. (l? h. While reeling in and out wire rope watch the cord length. Any change in the cord length will indicate possibl Fore damage and should immediately be investigated, 117. WIRE ROPE a. Boom Hoist: 77/ C (1) Diameter /Condition ,_� 01 b. Main Hoist: MVO (1) diameter/Condition t M !O) c. Auxiliary Hoist: C 10 5 1 6 ) 16 - (1) Diameter /Condition 1 �t 11. BOOM Boom Connector Bolt Inspection Procedure (Series 60 Cranes with 1/34" Connector Bolts) Initial Installation & Inspection: • • 1. Visually check that boom section connector pads are flush. There may be some gap due to uneven surfaces between the two pads, but the gap should not be continuous throughout the entire pad area. 2. Insure bolt is tighten with hammer wrench in accordance with the attached "Turn- Of- Nut - Tightening Procedure or torque to 2,378 ft. lbs. During their original installation. Subsequent Inspections: 1. Visually check that hnom section connector pads are flush. There may he some gap due to uneven surfaces between the two pads, but the crap should not be continuous throughout the entire pad area. A good way to check the bottom bolts is to rise the boom slightly out of the boom cradle before checking for gaps. Check to see if gap closes when resting the boom back in the cradle. 2. Check the torque by attempting to tum the nut with a hammer wrench or by applying 2,378 ft. lbs. with a torque wrench. 0 the nut turns, record this condition and re -check after 12 to 24 firs operation. If the nut turns again, change the bolt, nut and lock washer. 3. the two main visual checks are that the lock washer compressed and that there is no continuous gap between the pads. a. Point/)ib M1 � (1) Cords /Lacings[ ►� (2) Bolts/Nuts/Lockwashers (3) Sheave Shaft/Retainers .n (4) Cable Guard CV, (5) Two Block Frame likit (6) Wire Rope Dead End (7) General Condition (1t3� 12. Butt Section a. Chords /Lacings(',,, b. Bolts /Nuts /Lockwashers(S . c. Hoist Mounting Qv. d. Radius Indicator aV e. Boom Foot Bushingspt . f. Boom Foot Pins l- g. General condition 13. Straights: a. Qty: N b. Chords /Lacingsc , c. Bolts /Nuts /l_rckwasher d. General Condition Cl 14. HEADACHE BALL a. Structure() K b. Hook condition [j :1 c. Pin & Keeper 14 d. Safety Latch 15. MAIN BLOCK a. Structure Q b. Hook & Safety Latch bit c. Thrust Bears g()l . d. Sheaves \' e. Sheave Shaft & Retainer[;\ 16. KINGPOST a. StructureOtC b. Pintel Condition QV c. Thrust Washer & Bearincd 17. HYDRAUL,IC SYSTEM a. Pump G b. Filter /Strainerstl\t- • c. Oil Level /Conditions' d. Hoses & Fittings 3\ 18. LUBRICATION a. Load block sheaves &swivel Bearings (8 hr_f4points,MPG /EP) CAL- b. Overall Ball (8 hr. /1point/MPG /EP) c. Boom Foot Pins (8 hr. /2points /MPG /EP) d. Engine Oil Level (Check Daily /8 hr.) c3 e. Boom Points. (1) Boom Susp. Sheaves (40 hr. /Spoints /MPG /EP) (2) Main Hoist Sheaves (40 hr. /5points /MPG /EP)t�_ (3) Aux. Hoist Sheaves (40 hr. /1point/MPG /EP) V L (4) Opt. Aux. Load Sensor (40 hr. /1pornt/MPGJEP)p f. Gantry Sheaves (40 hr. /Spoints /MPG /EP) ``_k- g. Kingposj Upper Bearing (40 hr. /lpoint/MPG /EP Use 5 Shots) • L h.Kipgpost Lower Bearing Shoes (40 hr /Brush on /MPG /EP) I. Main Aux. & Boom Hoist: (1) Hoist Shaft Bearing (40 hr. /1point each /MPG /EP) \ J. Pinion Gear /Swing (40 hr. /Brush on/MPG /EP) k. Main, Aux. & Boom Hoist Wire Rope (80 hr. /Brush on /WRLj`{ • Perform Annual Crane Inspections Per API Specifications RP2D (Latest Edition). C.4.1.2d - Annual Inspections (performed by a Qualified Inspector will include Pre - use, Monthly, and Quarterly Inspection, as well as inspections of critical crane components. A basic guideline for Annual Inspections should consider, but not be limited to, the following. 1.1 \Perform a 'walk- around' visual examination of the crane boom and support stnucture to ensure that no damage exists. 2. z �; nsure the correct load rating chart for the configuration in use is visible to the crane operator at the primary control station. 3.. 0 ..Visually check wire rope for evident deterioration and damage, or improper reevi 4.__KL. Visually check for loose, missing, or corroded bolts, pins, keepers or cotter pin�. 5. IT, Further check all control mechanisms for proper adjustment, excessive wear of cnm..nents, and contamination by foreign matter. 6. v Check electrical apparatus for proper function. 7.., Check boom hoist limit and anti-two block devices for proper operation. Care should be exercised to prevent damage to crane components. 8. (AL Boom should be inspected for bent chord members, missing or broken lacing and cracked welds on critical members. Boom section end connections should be inspected for cracked welds, deformation and corrosion. S. t- J Chedc boom angle /radius indicators over full range for accuracy. 10. CA. Sheaves should be inspected for wear, cracks, rope path alignment and bearing ondition. 11.LCheck power plants for proper performance compliance with safety requirements. 12. c ( Check belts and chains for proper adjustment. 13, SAIL Visually check crane hooks for deformation, and discard if deformations exceeci those manufacturer's recommendations. 14.C! Check lubricant level in all hoists and slew drives, including those not fitted with s ht glasses. 15 � Foundation- Weldments in the crane's pedestal and supporting deck structure should be visually examined for fracture, deformation and corrosion. Special attention should pe paid to areas of rust and spitted paint. 16.531_ Swing Circle Assembly -The sating circle assembly is the connecting component between the crane revolving upperstructure and the pedestal. Consequently, regular inspections are paramount to insure a long and safe operational life. There are three (3) main types of swing circle assemblies typically used on pedestal mounted cranes: Type 1. Hook and Roller Assemblies Type 2. King Posts Type 3. Ball /Roller Bearings 17.194 Record the Slew Bearing information as follows: ENGINE. HRS N .14 NORTH 19 K'? SOUTH N it EAST i'ciPt WEST Alt The inspection procedure for each varies significantly and must be tailored, not only to fit the type of swing circle assembly, but also for the physical and operational environment of each particular crane and platform. Regardless of the type of swing circle assembly, the objective of any inspection is to determine and monitor wear, fatigue, corrosion, and the overall operational condition. The crane and swing circle assembly manufacturers are the best sources for information in developing the inspection program. The following are suggested inspection guidelines for each type of swing circle assembly. Type 1. Honk and Roller Assemblies Ring Gear: a. Center Pin and Bushing condition should be verified and monitored for wear. Center Pin wear is generally due to improperly or unevenly adjusted Hook Rollers. b. Proper lubrication of Center Pin Bushing should be verified. • • c. Obvious wear between ring gear teeth and swing pinion gear would indicate Center Pin wear and improperly adjusted Hnok Rollers. d. Excessive lateral wallowing, wobbling, or loud popping noise of machine base for frame indicates Center Pin Rushing wear. e. Bearings should be well lubricated and should roll smoothly with no noticeable popping or grinding noise. Hook Roller Brackets, Bracket Pads, and Bolts: a. Machine should be tilted fully In both direr noting any deflection between the Hook Roller Bracket and the machined surface of the main frame pad where the Hook Roller Bracket mounts. Consult manufacturer for tolerances. NOTE: A forged casting that comprises Hook Roller Brackets very seldom bends or distorts i.e. the main frame generally yields thus causes obvious deflection or gap. b. Hook Roller bracket bolts should be checked for proper bolt torque, excess stretching, excess rust pitting, improper size, etc. Type 2. King Posts. Bearing areas of the crane should be inspected to assure that there is no significant wear or damage to either the rotating or stationary load bearing members. that left uncorrected, might result in a loss of structural Integrity of the mounting system. The King Post crane inspection procedure will depend on the design of the crane being inspected. The inspection should include but not be limited to the following: * Upper thrust bearing. " Upper radial hearing. * Lower thrust bearings or wear bands. * King pin wear and condition. * Lower King post wear band: The wear band condition is critical as it protects the king post from the lower thrust rollers or wear bands. On cranes not equipped with a wear hand or if the wear hand is excessively worn, the wear zone on the king post must be carefully monitored to insure the stnictural integrity of the king post. * King post to platform structural connection, p towel- ( 7 0 ,44 or w.roposi1- - ■la ui Detk Val M sparraers -A d+1a.n 1ro',. + 5a gS r+► • - ©1 b A • ■i,4 +. Rye p,f' 0+41/4 c6+ t 4t„r. tea, r•e‘eic on *Iry uaylIt Iota tell $ ki . 11)E W)O lUPc �o 4ral4C2 olS , BRIDON AMERICAN CERTIFICATE OF EXAMINATION OR TEST OF WIRE ROPE WIRE ROPE DESCRIPTION: 7/8" DY34LR 2160 RLANG HPTP CUSTOMER: ARCTIC WIRE ROPE & SUPPLY CUSTOMER ORDER NO 114075 BRIDON AMERICAN OkDER NO.: 60136 - DATE TESTED: 6/01/09 REEL NUMBER: 081646B00 MINIMUM BREAKING FORCE: 109,600 LBS. 49,714 KGS. ACTUAL BREAKING FORCE: 110,300 LBS. 50,032 KGS. OFF TENSION DIAMETER: 0.904 DATE: 6/03/09 SIGNED: i'G't. ! TECHNICAL DIRECTOR Bridon American Quality Program Certificates: American Petroleum Institute Spec 01 and 9A, License #9A0058 Lloyds Register Quality Assurance - ISO 9001:2000, License #101907 Bridon American wire ropes are manufactured to the applicable requirements of API 9A and AST M1023. WARNING: Any warranties, expressed or implied, concerning the use of this product apply only to the nominal strength of new, unused wire rnpe. All equipment using this product must be properly used and maintained. Wire rope must be properly stored, handled, used and maintained. Most Importantly, wire rope must be regularly inspected during use. Damage, abuse or Improper maintenance can cause rope failure, Consult the AISI Wire Rope Users Manual, ASME or ANSI Standards, or Bridon American Corporation before usage. Wire rope removal criteria are based on the use of steel sheaves. If synthetic sheaves are used, consult the sheave equipment manufacturer WARNJNGt BRIDON American Corporation 200 New Commerce Beirlevard Wibex -Barre Pennsylvania 18706 '370 022 3349 Pax 570 827 0180 • • r, I Oil States Industries, Inc. Phone # (985) 868-0630 I Fax # (985) 851 -0778 CRANE PULL TEST CERTIFICATE PULL TEST WILL NOT TO EXCEED 100% OF STATIC RATED LOAD LISTED ON LOAD CHART Company: CIIEVRON A1.ASKACrane Location: BAKER PI.AITFORM Crane Manufacturer: SEAKING Crane Model: 3500 Crane Serial Number: 3160 Main Boom Length: 130 FT. Auxiliary extension length: 5 FT. Load Hoist: Rated Load at test radius 50791 Pull- tested to 50, lbs. 4 Part line boom angle at 75 radius ft. and held for 5 Mins. 1900 PSI. to pull load (If equipped) Main Hoist Weight Indicator reading is N/A lbs. Aux. Winch: Rated Load at test radius N/A Test Load N/A N/A Part line N/A boom angle at N/A ft. and held for 5 Mins. N/A PSI. to pull load ( If equipped) Auxiliary Hoist Weight Indicator reading is NIA lbs. Check Radius or Angle Indicator: Indicator Reading Measured value Minimum _1 ft. /° Minimum / ft /° Intermediate / f t./ ° Intermediate / ft./ ° Intermediate / f t./ ° Intermediate / ftJ ° Maximum / ft./ ° Maximum / f t./ ° For Functional test of components, safety systems, engine shut downs, and relief valve settings see attached inspection form. The above referenced pedestal - mounted offshore crane has been pull - tested to 100% of the static rated load as listed on the load chart supplied by owner and posted at the control station. Dynamometer: SfN: t;OCL)2393 Calibration Due Date: 3 -7 -12 C'ompam Representative Date 5/28/2011 WO#: _2048236 - T 'f *sea EST Date OSI Qualified Inspector Form No: SS2R -0008 Date: 8/27/03 • • Infor EAR! Print Work Order Work Order 14190 BK CONT ANNUAL CRANE INSPECTION SEAKING WEST Scheduled Start 05/12/2012 Created By JMABREY Scheduled End Date 05/18/2012 Created 02/28/2012 Status CLOSED (History) Reprint Parent WO WO Type PM Department BAKER Class MICR Baker Platform Priority 0 PM Schedule A- BK -N -A -0002 Warranty BK CONT ANNUAL CRANE INSPECTION SEAKING WEST Safety Cost Code Equipment Criticality 1 Assigned To BK- MECHCR Problem Code Reported By Assigned By Project Multiple Equipment No Date Started 05/15/2012 00:00 Standard WO Date Completed 05/16/2012 Time Completed 10:40 Campaign Campaign Event Equipment B-CR -0651 CRANE; SEAKING WEST SIDE Manufacturer SEAKING Model 3500 Serial Number 3160 Location WO/PM Comments CL ? O R / O N 05/18/2072 701 - 371 . . COMPLETED ON 5 -16-12 COMPLETED BY CODY DOIRON AND JAMIE BONVILLAIN COMPLETED IN 2 DAYS NO DEFICIENCIES WERE FOUND AT THIS TIME JMABREY (02/14/201212 :'49) :• M BK - N - A - 0002 T 5 C 0 7 7 (03/08/2 01 217;42P Print and complete attached inspection forms. Close work order and attach completed inspection forms to work order in the document section of EAM. Create work orders for deficiencies found during inspection. File the completed inspection on the facility in the crane file. Send a copy of the completed inspection to Trudy Scott at CIFO for crane files in that location. 05/21/2012 13:42 HILCORP ENERGY COMPANY Page 1 , • • 1 , , i Perform Annual Crane lnstrcctiorrs Per API Specifications ;IP7[t (t. test Echt:on) C.4.1.2d Annual Inspections (performed by a Qualified Inspect will include Pre use, Monthly, and Quarterly inspection, as well ds inspections of rrtic:al crane components. A bask: guideline for Annual Inspections should co' :der, but not be limited to, the following. s 1.0/(Perform a "walk-around' visual examination of the r rant bion, and support struct to censure that no damage exists_ 2.(�j Ensure the correct load rating chart for the configuration i use is visible to the crane gperator at the primary control station. 3.0 Visually check wire rope for evident deterioration and darn ;ge, or improper reeving. 4,Gic Visually check for loose, missing, or corroded bolts, pins, epers or cotter pins. 5.0jFurther check all control mechanisms for proper ad,ustme t, excessive wear of components, and contamination by foreign matter. 6.0 Check electrical apparatus for proper function. 7.0 Check boom hoist limit and anti -two block devices for pro r operation. Care should be exercised to prevent damage to crane components. Boom should be inspected for bent chord members, miss:. or broken lacing and cracked welds on critical members. Boom section end conn ions should be inspected for cracked welds, deformation and corrosion. 9. Q/(theck boom angle /radius indicators over full range for acc racy. 10. .(''Sheaves should be inspected for wear, cracks, rope path -lignrnent and bearin condition. . 11.0C'�Check power plants for proper performance compliance th safety requireEpents. 12. k Check belts and chains for proper adjustment. 13. Visually check crane hooks for deformation, and discard i deformations exceed those manufacturer's recommendations. 14.0 )Check lubricant levet in all hoists and slew drives, rncludi those not fitted with sight glasses. 15.4qr Foundation- Wcldments in the crane's pedestal and suppo ing deck structure should be visually examined for fracture, deformation and corrosion. Special attention should be paid to areas of rust and spilled paint. 16. Q' Swing Circle Assembly -The swing circle assembly is the •.nnecting component between the crane revolving upperstructure and the p (festal. Consequently, regular inspections are paramount to insure a Ion + and safe operational life. There are three (3) main types of swing circle assemblies typrcali used on pedestal mounted cranes: Type 1. Hook and Roller Assemblies type 2. King Posts w, � Type 3. Ball /Roller Bearings 17 -, /44 Record the Slew Bearing information as follows: m ENGINE HRS j .3Q1 NORTH NA SOUTH/VA FAST A WEST Iva The inspection procedure for each vanes significantly and must be tailored, not only to fit the type of swing circle assembly, but also for the physical a d operabonad environment of each particular crane and platform, Regardless of the type of swing circle assembly, the objective of a y inspection .s to determine and monitor wear, fatigue, corrosion, and the overall 0 )redone ccuirlition, The crane and swing circle assembly manufacturers are the best ources for information in developing the inspection program. The fcttow; ^q d e suggested inspection guidelines for each type of swing circle assernb'y. Type 1 Hook and Rol :er Assernblies Ring Gear: a. Center Pin and Bustling condition shoved be verified and moritc ec'or .vca -. Center Pin wc'a- is generaliy due to improperly or unevenly ac:Ii :Ste . r'JOk PPn"e•s. b. Proper Itrbrcat on o' Center Pir Bushing should be verified • • PRFVFNiIVL MAINTE'NANCL CHECK SHFET INTI RVAL: ANNUA: MANUF.: SFAKING EQUIPMENT TYPE: CRANE MODEL NO.: 3500 LOCATION AND SFRIAL NO: Baker Platform 3160 Bruce Platform' Sim' Anna Platform 3161 Dillon Platform 3162 Q dour Meter Reading: 39 ` Hour Meter Last Month's Re .ding: Total Months Usage: Date completed: 6 - 16. "' 1 Inspector: ,)2Mr'4- & 3 V: I All inspections, adjustments, repairs, and lubrication must be per .rmcd ir ' accordance with manufacturer's specifications and ANSI /OSHA re. utations. Refer to applicable manuals. Symbols: OK - OK or Completed IN - Incomplete RR = Repair or Replace NA - Not Applicable UN = Unsafe: IMMEDIATE PRIORITY XX - See Remarks CI = Corrected by Inspector CAUTION: Serious or fatal injury can result if safety precautions ich follow are not taken: "Stop engine and wait until all moving parts are completely stopped before servicing machine. "Attach CAUTION tag or •" OUT -OF -ORDER" sign to engine start controls in operator's cab and at each engine to warn personnel that machine is being serviced and must not be started. "Do not operate machine until all safety guards and covers are securely reinstalled and all maintenance equipment is removed. 1, MAIN HOIST a. Frame Structureot.. b. Drum Condition Ok c. Brake Band Condition Ole d. Brake Band Adjustment e. Brake Cam & BushingQ f. Brake Actuator Condition ©g g. Brake Actuator Operatiop h. Borst shaft Retainers i. Wedge /Socket /Cable Dead E d I. Hydraulic Motor Condition( k. Gearbox Oil Level (To Fill Plug) � f{ 1. Drum RPM Indicator die m. Check two block device cv' 2. Auxiliary Hoist a. Frame Structurefi>e b. Drum Condition _ c. Brake Band Condition C> d d. Brake Band Adjustment e. Brake Cam & BushinV f Brake Actuator Condition eye g. Brake Actuator Operution{y/(Z h. Hoist shaft Retainers Ok- i. Wedge /Socket /Cable Dead I:nC OK I Hydraulic Motor Conditiond(. k. Gearbox Oil Level (To Fill lug) , ` Drum RPM Indic ok v m Check two block dev cc Q 3. Boom host a. frame Structure 0g. a • • c. Obvious wear between rung gear teeth and swung pinion gear ouid Inca; ate Center Pm wear and improperly adjusted Hook Rollers. d. Excessive lateral wallowing, wobbling, or loud pepping noise c t machine base H7 frame rndic:ates Center Pm Bushing wear c. Bearings should be well ruaricated and should roll smoothly w th no noticeable popping or grinding noise. Hook Roller Brackets, Bracket Pads, and Bolts: a, Machine should oe tilted fully in both directions noting any de'lectron between the Hook Roller Bracket and the machined surface of the main frame pad where the Houk Roller Bracket mounts. Consult manufacturer for tolerances. NO f f:: A forged casting that comprises Book Roller Brackets ver seldom bends or distorts i.e. the main frame generally yields thus causes obvious eflectior or gap. b. Hook Roller bracket bolts should be checked for proper bolt to que, excess stretching, excess rust pitting, improper size, etc. Type 2. King Posts. Bearing areas of the crane should be inspec ed to assure that there is no significant wear or damage to either the rotating or st.tionary load bearing members, that left uncorrected, might result in a loss of tructural integrity of the mounting System. The King Post crane inspection procedure d3 depend on the design of the crane being inspected. The inspection should incluc but not he !united to the following: Upper thrust bearing. Upper radial bearing, Lower thrust bearings or wear bands. King pin wear and condition, tower King post wear band: The wear band condition is critica as it protects the king post from the lower thrust rollers or wear bands. On cranes of equipped with a wear band or if the wear band is excessively worn, the wear zone on the king post must be carefully monitored to insure the structural integrity of t . king post. King post to platform structural connection. 1Jp VP; C-Ze-nt es w ert. a a+ 4.h -F:n�,�. • re k. Hyd, Pump noses OK I. Tachometer ED/wool( rn, Muffler& /C, n. 7. BLOCK & SPRIADER a. Structure 6 e b. Spreader Pi Retainer c. Sheaves d. Sheave Shaft & RctainerO/ 8. GANTRY a. Structure a h. Bolts /Nuts /LO kwasher$ /t c. Sheaves Cl / d. Sheaves Shaft & Retainci 7/< e. ladders & Decker/ f. Wire Rope Dead 'Encia,e 9. Wire Rope a. Check critical wear points t ,, �/ (1) Check wire rope that repeatedly is stressed from contact with sheaves C (2) Check end attachments where fittings is attached to wire ropy and where wire rope is attached to drum. (Limit of one broken strand near any attaching fitting) we (3) Check for abused points where wire rope could be scuffing an scraping' €, b. Check wire rope Diameter (cornpare used rope with original r measurement. Maximum rope reduction is 1/16 for 7/8" and 1" r.peQj<' c. Check for broker. wires. Thoroughly clean the wire rope so bre s can be seen. Relax the rope, move the rope off "pick -up points," and flex the r' pe as much as possible. (1) Take out of service if exceeds: (i)RUNNING ROPES (working lines) 6 randomly distributed broke wires in,gnc rope lay length, or three broken wires in one strand of one rope lay ler (ii)STANOING ROPES (Pendants) If rnore than two broken wires i one rope lay length in section bs�ond the end attachment, or more than one • token wire at the end attachment d. Check for wear on individual wire strands. ©�ptace if one-third the original . diameter of outside individual wires K c, Replace any wire rope that has kinks, crushing, birdc:aging, or any other damage resulting in distortion of the rope structure d f. Replace if any evidence of heat damage from any cause ©x g. Check each sheave, roller, and drum v (1) Check the depth, width, and contour of each sheave using a g oove gauge. Ci./1 (2) Replace heaves and drums that have broken flanges or crack. in the hubs, spokes, etc Ox (3) Check for defective bearings NZ, (4) Replace the drums to see if one wrapa wire rope will contact he next wrap az the wire rope spools onto the drum. ° h. While reelirg in and out wire rope watch the cord length. Any change in the cord length will indicate possible cgre damage and should immediately be investigated 0 10.WIRE ROPE & PENDANTS a. Boom Moist: �rA (1) Diameter /Condition • v 171eg b. Main Hoist: 406 /G� (1) Diameter /Condition • c. Auxiliary Hoist: 1b/G1� 9 (1) Diameter /Condition '916/0g t d. Pendant Lines: (1) Diameter /Condi;ronls2q0/0 e. (7) Pins & Keepers Qt 11. BOOM Point/.31b 11 Butt Section Genera+ condition f3 1 3. Straights: • a Qty: 5 b. Chords /Lacings oK c '3olrs /Nuts /Lockwushc�s d. General Condition(` 14. HLADACI- E a. Structure= (U• CC.. b. Hook condition c. Prn & Keeper d. Safety Latch 15. MAIN BLOCK Structure Q`( b. Hook & Safety t atc �K G. thrust Bcar�yyrgO,( d. Sheaves elf. , � , � 1 e. Sheave Shaft & Retainer x.11, 16. KINGPOST a. Structure V b. Pintel Condition dP c. Thrust Washer & BearingO \\ 17. HYDRAUC SYSTEM a. Pump Q b. Filter /Strainers 0 �J c. Oil Level /Condition d. Hoses & Fittingsex, 18. LUBRICATION a. Load block sheaves & swivel Bearings (8 hr. /4points,MPG /EP) ((( b. Overall E3a1, (8 hr. /lpoint/MPG /EP) c. Boorn Foot Pins (8 hr. /20oints /MPG /EP) k d. Engine Oil Level (Check Daily /8 hr.)J� e. Boom Points: IIJJ (1) Boom Susp. Sheaves (40 hr. /5points /MPG /EP) (2) Main Hoist Sheaves (40 hr. /Spoints /MPG /EP) (3) Aux. Horst Sheaves (40 hr. /lpoint/MPG /EP)© (4) Opt. Aux. Load Sensor (40 hr. /lpoint/MPG /EP) d( €. Gantry Sheaves (40 hr. /5points /MPG /LP)eg g. Kingpost Upper Bearing (40 hr. /lpoint /MPG /EP Use 5 Shots) Q , h. Kingpost Lower Bearing Shoes (40 hr /Brush on /MPG /LP)Q .. i. Main, Aux. & Boom Hoist: (1) Hoist Shaft Bearing j (40 hr. /lpoint each /MPG /EP)o1Z j. Pinion Gear /Swing (40 hr. /Brush on /MPG /EP) my.. k. Main, Aux. & Boom Hoist Wire Rope (80 hr. /Brush on /WRL) 19. Boom Hoist Hour «51 V 20. Whip l inc Hour J� 21. Load Block Hour NO ; &; f1c d , (.Jere ANA-AC dl'f " - 14 4 iS e . • • Davies, Stephen F (DOA) From: Chad Helgeson [chelgeson @hilcorp.com) Sent: Wednesday, September 26, 2012 4:02 PM To: Davies, Stephen F (DOA); David Buthman Cc: David Duffy - (C); Schwartz, Guy L (DOA); Chris Kanyer Subject: RE: MGS St 17595 -18 Perforations Attachments: Ba -18 WO Regulatory Procedure 9 -26 -2012 Rev 1.docx Steve, I accidently left in a step from a previous procedure (Baker 27) on this Baker 18 well procedure I submitted. There was a statement after step 30 labeled "contingency" which is from the procedure on Baker 27 with the wrong depths. Attached is a revised procedure where I removed the "contingency" statement. The interval we plan to perforate in the 18 well, T -25 sand, has not been perforated in the Middle Ground Shoal field and therefore should not require a spacing exception. I apologize for this oversight and mistake on this procedure. Please let me know if you need anything else from me. Chad From: Davies, Stephen F (DOA) [ mailto :steve.daviesCaalaska.gov] Sent: Tuesday, September 25, 2012 1 :24 PM To: David Buthman; Chad Helgeson Cc: David Duffy - (C); Schwartz, Guy L (DOA) Subject: MGS St 17595 -18 Perforations David and Chad: The proposed T -31 perforations in Baker 18 will be 1000' shallower than previous perforations in this well. What regulation or order governs spacing for the T -31 sands? Please list the nearest wells to Baker 18 that are completed in the T -31 sands. Please provide the distance from the T -31 sands open in those nearest wells to the planned T -31 perforations in Baker 18. Thanks, Steve Davies AOGCC 907 - 793 -1224 1 o-ZU-c1-5 Dale A. Haines Union Oil Company of California -' Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 -- = - Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, ,!-AUG 0 5 2009 Alklsk, 0 I & CIO's Cans, r�prmmi,�Riorl f?,nR,�Nsao•�sr� SCANNED OCT 0 0 21114 Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) "'e,1Jctk�_ Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of latform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of latform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil productio2 from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/I-Iemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 A r-8 Colla sed casin Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life N,"41 l' 1- '1 �M June 22, 2009 \ `l t- `- Q. `l Is SARAH PALIN, GOVERNOR 1 333 W. 7th AVENUE, SUITE 100 r ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCALOCT 0 9 2014, 3800 Centerpoint Dr. Ste 100 �Cp►NNED Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(cr)alaska.gov. Sincerely, 0 Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 _ Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 _ Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 _ Trading Bay Unit D-18 Union Oil Company of California 188-098 _ Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 _ Trading Bay Unit G-24 Union Oil Company of California 179-013 Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD Union Oil Company of California 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 _ Trading Bay Unit K-09 Union Oil Company of California 179-016 _ Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 _ Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 _ Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 _ Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 238-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 . Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 _ Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 _ Trading Bay St A-30 ) ) Chevron ., Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com ,,~-,.. October 10, 2005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary ~ 1.ß~'5;:'; \!\.'c~) ~O~ ~. .' sCPi~~"(\I[;..." J7'-07!; l?;r- I 8 Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13,28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BHP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. \"""'\ ~ Jn~ ,.r ^ T E '"" " t- t_1 ~~/ 1-\ t Union Oil Company of California I A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker SOland in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, ~&é_¿~~ Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California I A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Sa-4 Injector 27 -Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Sa-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Sa-8rd Injector 7-Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6..Juh05 Sa-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Sa -13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Sa-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Sa-16 Injector No survey Sa -17 Injector No survey f;:> Oa-18 Gas No survey Sa -20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Sa-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Sa-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Sa-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Sa-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba -30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 ~/ Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 Sa-32 Producer No survey ') ) .~~f~E C} ~:~~~~«~ AT/ASHA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker l1Vf!l19 Dear Mr. Cole: This letter confirms your conversation with COll1mission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made ~der the applicable Area Injection Orders (AIO 7 for Baker and AIO 8 for Dillon) and Conservation Orâers (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. ;:. Sincer~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SCANNED NO\! 2: 42004 Ene!. Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal 133/8" 3,500' 3,296' 4,397' 9S;" 15¿~~~, / :::::: Perforation Depth TVD (ft): Tubing Size: . /. ./.. Tubing Grade: 3,296 to 4,265 2 "Ø" 6.4# N-80 Baker SAB-3 Pkr@3'453';OtisBWHPkrj.packersandSSSVMD(ft): @3,669' and 3,967';' / Baker "F" pkr @ 4,757' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil D Gas 0 16. Verbal Approval: Date: WAG D GINJ D Commission Representative: 1 . Type of Request: 3. Address: 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 10,231' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 3,494 to 4,883 Packers and SSSV Type: ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMI~SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing D Perforate U Waiver U Annular Dispos. U Stimulate D Time Extension D Other 0 Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: 909 West 9th Ave. Anchorage AK 99501 Exploratory D 1760750 /,/_. D 6. API Number: /'" 50-733-20296-00/ / ./ /" / Effective Depth MD (ft): Effective Depth TVD (ft): ¡'ú9S (measured): / Development Stratigraphic 0 D Service 9. Well Name and Number: Ba-18 10. Field/Pools(s): MIDDLE GROUND SHOAL PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 8,223' Length Junk (measured): 6,480' 5,496' Burst Collapse Size MD 20" 621' 620' 3,094 psi 1,536 psi 6,822 psi 3,320 psi 9,685 psi 7,835 psi Tubing MD (ft): 4,883' 0 D Service Plugged WINJ D D D D Abandoned WDSPL BOP Test D Location Clearance D Contact 17. I hereby certify that the foregoing is true and correct to th Printed Nam/Î ,V.f.me D. ole. Signature_MvPa~ Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 27 -Sep-2004 Conditions of approval: Notify Commission so that a Sundry Number: 3c4- 4S3 - , Plug Integrity D Other: Subsequent Form Required: Approved by: D Mechanical Integrity Test RBDMS BFL l. NOV 2 2 20D4 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION RECEIVED OCT 1 2 2004 A\aska Oi\ & Gas Cons. Commi$sion Anchorage 0 R4~~'N=A 1._, BY ORDER OF THE COMMISSION Date: ~~ Form 10-4Q4-Revised 12/2003 Submit in Duplicate JAN-08-97 WED 10:49 F~M P, 01/05 STATE OF ALASKA ....... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR,SUNDRY APPROVALS i. Type of Request: Abandon: Suspend: Operation shutdown; Re-enter suspended well; Alter casing: Repair well: Plugging; Time extension: Stimulate: Chang.e. approved progr._a..m; Pull ruining: Variance; Perforate: x Other: '~2,' Name of Operator -" S. Ty'l~e Of well:.............6'D'~tum elevatk~'(DF or Kei ....... Unio._n.,Otl Company o.f .California (UNOC.A,,L) Development; x 7g,4 feet 3, Address Exploratory: ~ -~i uni/-o~ Prop;'r~ r~m-'~---"' .................. Stmtigraphic: P,O, Box 196247, Anchorag,e, AK 99519 Service; Middle Ground Shoal 4. Locat~-r~"'~f well at surface Baker Platform, '~g ~1, Slot #3 "' 8, WelJ number ......... 1937' FNL, $39' FWL, Sec. 31, TgN, R12VV, SM Baker 18 At top of productive interval 9. Permit number ............. 1100' FSL, 826' FWL, Sec. 30, TgN. R12W, SM 76-75 At effective depth 10. APl nu'mI~i; 17.54' FSL, 1006' FWL, Sec, 30, TgN, R12W, SM SO- 733-20296 At total depth 11. Field/Pool 3353' F,SL, 1697' FWL, ,Sec. 30, TgN, R12W, SM Middle Ground Shoal .... ,i ..,,,., ,,,., . ~ , ..... .,, ,,,, , .. ............. 12, Present well condition summary Total depth: measured I0231' feet Plugs (measured) Baker "F" pkr ~ 6500' true vertical 8223' feet Cmt plug ~ 5983'-6500' Drillable B.P. ~ 7635' Effective depth: measured 7~35' feet Junk, (measured) Drillabre B.P. t~ 7680' true vertical 6304' feet · Casin~ Length Size Cemented Measured depth True vertical depth Struotural Conductor 584' 20" 1400 sxs 621' 62I' Surface 3464' 13-3/8" 1800 sxs 3~00' 3296' Intermediale Production 59,~9' 9.5/8- 600 sxs 5983' 5139' '. Liner 4397' 7" 295 sxs 5710'-10107' 8126' Perforation depth; measured true vertica, See attachment I ORIGINAL Tubing (size, grade, and measure~l depth) 2-718", N-B0, 4883' Packers and SSSV (type and measured depth) Baker SAB-3 Pkr ~_. 3453'. Otis BWH Pkr ~) 3669' & 3~67', Baker' F Pkr ~ 4757' 13. Attach~nents D~ription summary of pl;~sal: x I~tailed operations program: BoP sketch: 14. Estimated date for cemmen~i~g oper~§~n "' 15, Status of wall classification as: Jan~,,a.,,~ 08, 199'7 16. If proposal well verbally approvea; Oil: Gas: x Suspended; Name ~,,a. ~_p_r._o_v~er Date approved Service: 17. I hereby certi~ that the f0'l;;~going i..s tr~ and corr~ to'{he best of my knowledge. Signe..~i' Dale Haines itle; Drilling Manager .... Date: January 7, 1997 ..... -" 'FOR COMMISSION USE OI~E~' ...... -Conditions;'~ api~'~'va,: Notify (~;'~mi'$sion so repres~,~ta,ive may witn,'~' '"" lApProv~a,' !~1~'. Plug integrity_ ..... BOP Test ~ Location cleararlceI ~''~ z,~ , Dot .,,_,' ............ ........ commi~m~ C~S. __A_pp_r..o~..__ed by order of the Commissi~one...r~ i~,e# ............l~.~)~_~.~,, ._.1 Phone Form 10.-403 Rev 06/i 5/88 Fax # ~UBMfT IN TRIPLICATE Original Signed By Oavid W. Johnston Approved Returned J~,N-08-97 WED 10:50 h~i P, 02/05 BAKER WF:LL NO, 18 LEG 1, SLOT 3 ADL 17'595 SPUD 1/01/77 COMPLEIION RECORD 2-7/8' ,6.4# N-80 TBG 1, 01]$ SSSV 31z & ~R S~ P~ ~' ~ O~S 'B~* P~ ~ & O~S ~ S~ 4~' 1 I. B~R ~' PERF GUNS TOC (IEMP) 4400' g 5f8' 40 & 43~5# $-95 @ 5983' CEMENTED W~H 600 $X$ POSSIBLE COLLAPSE 6664' MAX INCLINAYION 4~9 DInG 7' :29#, ~95 F/5710' - 10.10T CEMENTED WITH 295 SXS PBD 10,01 O' 20' CASING AT 621' CEMENTED W/1400 SX$ 13-~8' 6"1 &6a#, K-55 @ 3500' ~ CEMENTED WITH 1800 3466-3468 SQZ'D '31" SAND. 3494-3502 OFEN 353o-3,532 3710-3712 SQZ'D '32' SAND 3720-37151 OPEN 3790-8792 SQZ'D 399o-3992 SQZ'D "34' SAND 4013-404.1. OPEN '35' SAND 4089-.4094 OPEN 4118-4120 SQZ'D 41 ~8-4130 "40' SAND 4605-4883 OPI~N 7' UNER TOP 571 O' BROWN MC HYD HANGER 7' 2g, e x g-5/8' 43.5# 6' EXTENSION (ID '"' 7.5") BAKER MODEL *F' PACKER AT 8-1: 6680' - 6705' B-2: 6790' - 6838' B-3: 0886' - 6952' C-1: 7162' - 7212' C-2: 7255' - 7284' C~3: 7343' ~ 7380' C-4: 7416' - 7445' DRILLA8~ BP @ 7635' SAND ON TOP OF BP DRILLABLE BP (~ 7680' (t.F. AK9) G-1: 8749' - 0908' FILL AT 8856' SEE PERF DETAIL FOR EXAb--~F INTERVALS Alaska Oi~ & Gas Cons, Commissb3n ~chomg~ JfiN-08-9? WED 10:50 tql~ P, 03/05 ............... ~-~- .........- .... . t ......... i,~ ....... ~ BAKER WELL f/18 ADL 17595 PERFORATION RECORD Propose to perforate 'the following intervals on January 8, 1997: 4~4- q~'4~' ½ ~3~ 4~Sz-4~¢ .TRUE DATE 03,~092 03~,/92 03/11;:~ 03/11/92 03/11/92 03/07/92 03/14/~ 11/11/87 11/15/87 11/15/87 I1/14/~7 11/1587 1 Ifl~f87 11/15/87 11/15/87 lI/08,tg'7 11/14/g7 o6/15n7 o6/15m 02/'Z7/82 03~ ' 03't2S/zr" ' '31" $/uND "32". SAND "34" SAND "35" SAND "40" SAND B-I: B -2: B--3: C'-l: C-2: C-3: C-4: MEASURED DEPTH 3466-3468 34~4-3502 3530 -3532 3710 -3712 3720-376I 37c~-3792 3g~30..-3992 4013-~041 4118-4120 4128-4130 4865 -4883 668O -6682 6685-6705 6790-6792 6796 -6838 6886-6944 6836-~8 6948-6952 7162-7165 7170-7212 7255-7284 7343 -7380 7416 -7437 744I -7445 87O3~8705 8749-8751 8~r34-8936 9125-9135 9148-9153 '9162-9172 9212-9217 92~5-~256 9310--9334 9382-~R)4, 94?6-9494, 9610~9fi20 .. . ....., ~ 9660'-~70"' VERTICAL DEPTH ..REASON 3271-3273 REM CMT 3292 -3298 PROD 3319-3321 SQUEE7.~ 345'2-3454 SQUEEZE 3459-344~ PROD 3508-1510 SQUEF. ZE 3646-3648 sO~ 3662-3681 PROD 3713 -3718 PROD 3732-3734 REM CMT 3739-37~I SQUEF. ZE 4265-4~78 PROD 5636-5638 T~T I$OLAT 5641-5655 IN~ECTION 5713-5715 TSTI$OLAT 5719-57~a5 IN~ECTION 5783-5824 INJECTION 6445-6447 TST ISOLAT 5825-5829 TST I$OLAT 5907-5981 SQUEEZE 5983-6013 INJECTION 6041-6064 INJECTION 6105-6129 INJECTION 6156-6128 INJECTION 6172-6176 SQUEEZE 7055-7057 TST I$OLAT 7088-7091 7227-7229 SQUEEZE 737O-7377 INZECT/ON 7385-7390 INJECTION 7397-7404 INJECTION 7435-7437 II~.IECTION 744~.-7450. INJEC'HON 7459- 7,~9 IN3ECT/ON -:7509--752~' PROD' ..'.. 7543-7549 PROD 7564-?582. PROD 7618~,7628 ... PROD' . 'm3s.?r, s0 :. .. rt~9--~47."' 'PKOD' · '~.~,.' '".:'.'mom . ' .,., . ,. .... . ,'' ., , 77'/~7'/~ i "PROD-'. . ?Fait ...--7970': . 79'/i1~-7~79 'PROD. STATUS SQUEEZED OPEN SQUEEZED SOUEMT_~D OPEN OPEN OPEN SQUEF. Z~D SQUEEZED OPEN ABAND ABAND ABAND ABAND ABAND ABAND fi.BAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND ABAND" ABAND' ABAND J,qN-08-97 ~ED 10:50 P, 04/05 Baker 18: Created 1/7/97 Last update 1/7/97 ~ 5:00 PM Note: This procedure takes into account the condition of the well as of 1/7/97. We have already RIH w/1.9" gauge ring to 3,704' to a PXX plug. 2. 3. 4. 5. '6. 7. , 10. 11. 12. Close sleeve at 3486' KB. Pull 2.313" PXX plug in XA sleeve at 3,703 KB RIH w/2.25" gauge ring to XN profile at 4,790' KB. Verify that a plug is in the XN nipple at 4,790' KB. If not, set plug. Verify SSSV locked open. RU Eline. Run GR-CCL from 4,790 KB to 3,400' KB. Tie GR curve in to GR curve on PDK-100 log ran 2/23/92. (Note: the completion that the PDK-100 log was run in is not the current completion.) Perforate tubing using 2-1/8" non-retrievable enerjets 3 spf with zero degree phasing with magnetic orientation to low side of hole: 4582- 4594' Tyonnek 39 sand. Observe robing pressure and consult with Production Engineers about the advisability of rurming a bottom hole pressure survey and the need for swabbing. If step 8 is unsuccessful at producing commercial rates of gas, perforate 4,51.4-4,546' Tyonnek 38 sand with same type of guns. Observe tubing pressure and consult with Production Engineers about the advisability of running a bottom hole pressure survey and. the need for swabbing. If those perforations are unsuccessful, perforate 4,246'-4,268' Tyonnek 35B sand with same type of guns. Observe tubing .pressure mad consult with Production Engineers about the advisability of running a bottom hole pressure survey and the need for swabbing. Advise office of change in tubing pressure. If no rise in tubing pressure, a supplemental procedure with additional perforations will be prepared. Future perforations may be approximately 3,669-3,698 Tyonnek 32A sand; 3,616-3,669 Tyonnek 32A sand; 3,476-3,504 Tyonnek 3 lA sand, and 3,430-3,452 Tyonnek 31 sand. Test perforations. a) Install choke on well. Return SSSV to service. b) Install 24 hour chart flow chart to measure gas from well.. Install appropriate orifice. O:\mgs\b 18proc.doc JFIN-08-97 WED 10:51 Fill P, 05/05 13. c) Measure and record fluid level and SITP shut in tubing pressure. d) Open well to production system using choke. Flow well at no more than 1000 mcfd. Also do not allow flowing tubing pressure to decrease by more than 100 pounds less than the value measured in step c. Hourly check produced fluids for traces of water or solids. If traces of water or solids seen, notify Kriss Wegemer, Production Engineer ASAP (office x7655, home 248-7253). e) Record on well test hot sheet hourly values of choke setting, upstream pressure, downstream pressure, gas rate, solids or water traces. Fax in each morning to Production Engineer. f) Do not swab this well under any circumstances or surge the well. R/D Eline. O:\mgs\b 18proc.doc ALASKA DISPOSAL PROJECTS FOR AUGUST, 1996 DISPOSAL PROJECTS V BEA ER CRE~FIELD UNDEFINED ZC~ FIELD TOTAJ~ BELUGA RIVER FIELD UNI)EFINED ZONE FIELD TOTAL FLUIDS (BBL) DISP CUM FLUIDS WELLS (BBL) 187 1 318,308 187 1 318,308 752 1 .......... ~'~'0,472 752 1 ......... 130 472 ENDICOTT FIELD UN-DEFINED ZONE FIELD TOTAL KENAI FIELD UN/DEFINED ZONE STERLING 6 POOL FIELD TOTAL KUPARUK RIVER FIELD CRETACOUS LrNDEF ZONE FIELD TOTAL PRUDHOE BAY FIELD LISBUR_NE UNDEFINED ZONE PRUDHOE UNDEFINED ZONE FIELD TOTAL ~ SWANSON RIVER FIELD~ UN]DEFINED ZONE~ FIELD TOT~J~ W MCARTHUR RIV/FIELD UNI)EFINED ~NE FIELD TOTAL TOTAL ~TIVE FIELDS DAILY AVERAGE 6,086 1 ..... '~'/~ 5,818,440 ,086 1 _~- ......... 5,818,440 --' '-~ 487,391 64,651~~ 1 462,111 ...... ~...~.~.~_ 2 1,778,527 ~ ~'~'~. 4 14,876,835 131,324 ~ 14,876,835 3,125,056 2 ~ 47,044,504 4,900,409 12 ~ 898,851,384 372,920 2 ~ 26,783,066 372,920 2 ~6,783,066 81,457 1 ~80,975 81,457 1 2~ 0~975 8,683,325 26 997,682,~6~1 280,107 INACTIVE 340~63~-...~ ALL FIELDS 998,023,142 Unocal North Americ Oil & Gas Division _~_~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region June 29, 1992 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 MIDDLE GROUND SHOAL, BAKER #18 FLOW TEST Baker #18 was recompleted in March, 1992 in the Upper Tyonek sands. Four sands were tested in April, 1992 and the well is currently producing from the 40 sand which is the highest pressure and most productive. The remaining zones are isolated by a series of packers and sliding sleeves. Enclosed are the results of the test and a well diagram. Please direct any questions regarding this submission to the undersigned (907) 263-7678. si~'O~rely yo~rs,~ ~ Robert L. Shepherd Sr. Pet. Engr. RLS:rph Enclosures: GEOLOGIC DESCRIPTION Gas productive sandstones occur within the middle and upper portions of the Tyonek Formation at the north end of the Middle Ground Shoal Field, Baker Platform. The sandstones range in thickness from 10 to 50 feet, are interbedded with siltstones, shales and coals, and are interpreted as meandering fluvial channel sandstones. Good sorting and upper-medium to very coarse/pebbly grain size characterize the gas reservoirs which typically exhibit permeabilities in the range of several hundred to several thousand millidarcies. Porosity values are also high, usually 25 to 32 percent. The type log for the gas reservoir is the Pan American Petroleum Corporation Middle Ground Shoal State #4 well. Productive and potentially productive gas sands are present from the 1130' to 5147' measured depth interval of this well. Based on stratigraphic methods this extensive interval can be subdivided into four zones: Zone 1, from 1130'-2620'; Zone 2, from 2620'-3119'; Zone 3, from 3119'- 4330' and Zone 4, from 4330-5138'. Zones 3 and 4 are gas productive, Zone 1 is potentially gas productive and Zone 2 is wet. la. TEST: STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT J INITIAL I~1 lb. TYPE TEST/ STABILIZED l'-] NON STABILIZED ~] ANNUAL MULTIPOINT !~ CONSTANT TIME [~ · SPECIAL OTHER . ISOCHRONAL ~] 3. Address 5. Elevation in feet (indicate KB, DF etc.) 77-'/ 6. Lease Designation and Serial No. 7. Permit No. 8. APl Number so- 7L~- 9. Unit or Lease Name 10. Well Number 1 1. Field and Pool 12. Completion Date 13. Total Depth 114. Plugback T.D. 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. 17. Tbg. Size Weight per foot, lb. lB. Packer set at ft. 119. GOR cf/bbl. · ';/7 ~ 7 I 22. Producing thru: Tbg. [~ Csg. [") 23. Length of flow channel (L) F Iow Data I.D. in inches Set at ft. 20. APl Liquid Hydrocarbons Reservoir Temp. °F. /O3 Vertical Depth (H) I (30. 1% CO? 1 I , 1, I il 5, Type Completion (Describe) /aa/../'/ ~o,~//'J ~'/,"/i /~co4.,4F/~.J /O/f CW.~45' Perforations: From To 21. Specific Gravity Flowing fluid [G) Mean Annual Temp. °F. Barometric Pressure (Pa), psia Prover Line Size (in.) Choke Orifice Size (in.) /. ?S" /.,TY 1,','5' .~, ~-~o Pressure psig Diff. hw 7"/ mm , Temp. Tubing Data Pressure psig Temp. Casing Data Pressure psig Temp. Duration of Flow Hr. Basic Coefficient (24-Hour) Fb or Fp -'~ hwPm Pressure Pm Flow Temp. Factor Ft Gravity Factor Fg Super Comp. Factor Fpv Rate of Flow Q, Mcfd 307 7' Form 10-421 Rev 7-1-80 Pr Temperature T mr Critical Pressure Critical Temperature CONTINUED ON REVERSE SIDE / for Separatqr~ for Flowing G ~, 'it. . I ..... t.~ , Submit in duplicate m m ii ii - 59- , , Pc / ?,~ ~5~ PcZ Pf-,., ~? ~ pfz .... No. Pt Pt2 Pc2 - Pt2 Pw Pw2 Pc2 - Pw 25. Remarks: ./ I hereby certify th~rue a~orrect to the best of my knowledge AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-~ Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-~/1/Z dimensionless F lowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees Fo) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Alaska Oil & O~s Cons. Commission AnchOrage Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Test/ng Of Gas We//s, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 - 60 - 51nUTFIEF I I FLU111 CUI I A IE5 SOUTHERN FLOW JOHN P. SQUIER REPORT DATE: OS/05/92 VOLUME DATA FOR PERIOD: 04 -MONTH CUST: (9291-01) UNION OIL CO OF FIELD: (1393) MIDDLE GROUND SHOAL STATION:' {101 ) BAKER HP SALES #11 FLOW MEASUREMENT SMITH- GOODENOUGH 92-YEAR KIND: ORIFICE 7DAY:200": lO00~ CALIFORNIA TYPE: BELLOWS TAP/CONN: FLG -DN STATIC SET: PSIA O O HOURS INTEG ORIF DIFF PRES TMP .. N F FLOW EXT BORE WC PSIG F 40 10 292 43 60 280 33 60 269 31 O0 276 10 20 222 8 SO 232 OI-OG 113 06-08 16 08-15 97 15-88 159 88-89 t57 89-01 38 45 32 14 36 83 898 1 .750 30 138 2. SO0 44 681 8 ..SOO 26 1 083 P~ .SOO 75 SSG 8 .SO0 30 1P,.6 P_.SOO AVG- > 262 34 *TOT-) 582.88 3476 SOUTHERN FLOW DIVISION P,O. BOX 66190 HOUSTON, TX 77866-6190 (713)587-9591 BASIC. DATA TUBE-ID: 4.0860 C'=Fb,~,Ftb,IC TEMP R / 1 0 OF MOL% C08: .lO0. MOL% N8 ? 1 .T10 CSFACT: 1.00Q0 MCF-PB-CTR:I4.6SO MCF-PB-ATM: _MCF-TB: G0-F BTU-PB/C GAS BTU COEFF GRAV MCF Fr/y/a TIME_OR L M g/t/pv SPC FCT L 0 567 8.9300 S67 19.58GS 567 19.5865 S67 19.58G5 567 19.5865 S67 19.5265 I 3795 1 3599 1 39~S 1 4306 I 4095 1 3878 1,0000 S 1.0000 1.0000 1.0000 1.0000 1,0000 6 .567 *TOTAL VOL._ MCF 11064 3505 18596 15303 S414 82136 PEAK RATE : PEAK DATE : BETA RATIO : 30254 lS .621 S-FIRST G-LAST CHART CHART . t .. To: Well File Ba-18 From: Re; Bob Shepherd Evaluation of Baker 18 Gas Potential April 1992 Apr]] 14, 1992 Summary The above captioned well was recompleted in March 1992 to attain gas production from the upper Tyonek Gas Sands. Four zones were completed and evaluated. Two zones (the 40 sand and the 31 sand) tested gas productive. The 34-35 sands had Iow gas inflow but may warrant a future evaluation. The 32 sand was non-productive. The well is currently producing from the 40 sand which was the most productive and highest pressure zone. Each zone is isolated via a series of permanent packers and sliding sleeves. (see attachment #1) Testing 40 sand (4865-4883 ff MD) ''~ After completing the upper 3 intervals (31, 32, and 34 & 35 sands) by perforating at balanced pressure in completion brine the 40 sand was perforated March 15, 1992 with tubing conveyed guns at 700 psi underbalance. The well was produced to cleanup at rates of 1.5 mmscfd for several days through the test separator while arrangements were made to produce through the high pressure dehydrator. Production through the high pressure dehydrator commenced March 25, 1992. Almost immediately after placing the well on production high gas pipeline pressure forced a shut down of gas sales. The high pressure was due to a restriction or plug in the gas sales line between Shell's Platform 'C' and Dillon Platform. The nature of the plug or restriction has not yet been determined. Shell opened a former oil pipeline which runs parallel to the gas sales line April 02 to resume gas sales to the beach. A four point flow after flow test was conducted on the 40 sand (see Attachment #2) Apdl 03-06, 1992. The estimated tubing head AOF potential of the 40 sand is 2,_~ MMCFD. The peak rate dudng the test was .6 MMCFD at 12% drawdown ('I'HFP = 1528 psi). Shut in tubing pressure declined by 5 psi over the coU-r~- of the flow test (from 1742 psi to 1737 psi). Estimated reservoir pressure is 1928 psi (gradient = 0.45 psi/fi). Bottom hole pressure is an estimate. Downhole memory guages in place for the duration of the test failed (apparently due to excessive vibration according to Otis Wireline). Otis (Rahn) Kerkvtiet has offered to re-run the test at no charge. The estimated BHP is based upon a gas gravity of 0.57 (gas analysis was 96% methane) and assumes no liquid in the well (high flow rates should have evacuated liquids). Significant quantities of liquid (believed to be in part condensate) were recovered but were not measurable with existing equipment. Better estimates of liquid production will be obtained now that production from the 40 sand has been resumed. RECEIVED 0 Alaska 0it & Gas Cons. Commission Anch0~aoje April 07, 1992 A 2.25' plug was set in the Otis XN nipple. After bleeding the tubing head pressure from 1700 psi to 1450 psi the sliding sleeve opposite the 34 and 35 sands (4002 ft) was opened. No pressure change was observed Immediately after shifting the sleeve. At 5:00 PM the well was placed on production at a rate of 2 mmcfd. By 5:30 pm THFP had declined to 200 psi (pipeline pressure) and the well was shut in. Shut in pressure built up gradually (600 psi by approximately 9:00 PM) to 750 psi by the morning of April 07. Estimated reservoir pressure of the 34-35 sands is 912 psi based upon a fluid level (assume 3% KCl brine) of 3750 ft MD (3475 ft TVD). While running wireline Into the hole to pull the prong and equalize pressure across the plug (set in the XN nipple at 4790 ft) the wireline tools could not be lowered beyond 4250 ft (approx). It was determined that the pressure differential across the Baker 'F' packer and 6' O.D. seal assembly had caused the tubing shift upward and deform. The XA sleeve at 4002 tt was closed and the well was left shut in for 2 hours. The tubing deformation was not permanent and the subsequent wireline run with guage ring reached the plug at the XN nipple. ~2 Sand (3720-3761 ff MD) April 09, 1992 The prong was pulled from the plug at 4790 ft, the tubing was rePressured to 1500 psi and the prong was reset. The XA sleeve opposite the 32 sand (3703 ft MD) was opened and the well was placed on production on a choke setting of 8/64'. THFP decreased to 65-70 psi (flowing through test separator). Some liquid was produced and samples were recovered. The well was left open for 2 hours and no response was observed. During the subsequent run to pull the prong and repressure the tubing the fluid level was estimated by wireline operators to be 3500-3700 ft indicating very Iow bottom hole pressure. It is suspected that the zone is tight (possibly wet) and probably underpressured (ie deple!ed). 31 Sand (3494-3502 ft MD) April 10, 1992 Apdl 10, 1992 The prong was pulled from the plug at 4790 ft, the tubing repressured to 1500 psi and the prong was reset. The well was placed on production and the following pressure response was observed: . Time Choke Pwf (psi) 0 0 1420 5 min 8/64 1220 1 hr 24/64 1000 2 hr 24/64 900 3 hr 24/64 800 3 hr 10 0 _ ,~2 1120 (10 min shut in) Flowed well for 10 hours at 2.1 MMCFD (THFP = 550-600 psi). Choke = 10/64. Shut in well @ 7:00 AM April 11, 1992 ('rHFP= 520 psi). Plhr= 1260 psi P2hr= 1260 psi (Pr = 1362 psi approx., gradient = 0.414 psi/fi) Shut in well April 11, 1992. Closed XA sleeve @ 3480 ft. Pulled prong and plug from XN nipple and place 40 sand on production at 6 mmcfd, THFP = 1600 psi (6% drawdown). R£C[IVED JUN $ 0 199 . Alaska Oil & C~-~ C;0!~s, Commission AnChorage BAKER WELL NO. 18 ADL 17595 LEG 1, SLOT 3 SPUD 1/01/77 COMPLETION RECORD 2-7/8' ,~4~ N-80 TBG 1. OTIS SSSV 312' ~- OTIS XA SLEEVE 3408' & BAKER SAB-3 PKR 3453' 4. OTIS XA SLEEVE 348~ 5 OTIS 'BWI-I' PKR 36~g' & OTIS XA SLEEVE 3703 7. OTIS ~WH' PKR 3967' & OTIS XA SLEEVE 403Z. 9. BAKER 'F' PK]:I 475Z~ O. OTIS ~N' PROFILE ?_25' 4790' 11. BAKER 5' PERF GUN~~--- TOC CEMP) 44(X7 9 5/8' 40 & 4&5~ S-95 @ 5983' CEMENTED wrrH 6oo sx$ POSSIBLE COE. APSE 6664' MAX ~NCUNA~I 4~g OEG 7' 29~, 8-95 F1 5710' - 10,107- CEMENTED WITH 295 SXS I~BD 1 o, 01 0' 'ID lO,231' ////2///// 2O' CASING AT 621' CEMENTED W/1400 SX$ 13-3,/8' 61 & 68,~, K-55 @ 3.500' CEMENTED WITH 1800 SX$ 3466-3468 SQZ'D "31" SAND 3494-3502 OPEN 353O-3532 SQZ~ 3710-3712 SQZ"D .... 32' SAND 3720-3761 OPEN 3790-3792 SQZ'D 3990-~ SQZ'D '34' SAND 4013-4041 OPEN '35' SAND 4O89-4O94 OPEN 4118-4120 SQZ'D 4128-4130 SQZ~ 7' UNER TOP 5710' BROWN MC HYD HANGER 6' E3CrENSlON (113 = 7.5') BAKER MODEL 1:' PACKER AT 6500, ',rvo. 3~g 3' vO -- B-l: 6680, - 6705' B-2: 6790' - 6838' B-3: ~ - 6952' C-1: 7162' - 7212' C-2: 7255' - 7284' C-3: 7343' - 7380, C-4: 7416' - 7445' DRILLABLE BP @ 7635' SAND ON TOP OF BP G-l- 874g' - 9908' FIll AT JUN } 0 Alaska Oil & Gas Con~. ,,.~ ~horage G-~ ~IZ -~ SEE PERF DETAIL FOR EXACT INTEFNAL$ GFI8 4r//92 1800 1750 1700 1650 1550 1500 1450 1400 Baker 18 Flow Test- Tyonek 40 Sand (April 1992) I 1.5 mmcfd shut in iill~,.-I-m m m ~mmmm mm ~lm I lll -- m_ mm 3.J mmcf, t mmmmmmmm~mmmmmmmm ! mm mmmm.-- - m Nm i m i 5.~mmcfd illlalll/mlllll · ............. ~ 6o.05' .8~ ~mcfd II 10 20 30 40 50 60 70 ~ ~ ~ ' c.O Time (Hours) ~ ~o ~ Flow Test Baker 18 Tyonek 40 sands (4865- 4883 ft) Date Time of Day Hrs 04-Apr- 92 14 04-Apr- 92 15 04- Ap r- 92 15 04- Apr- 92 16 04- Apr- 92 17 04-Apr- 92 18 04-Apr- 92 19 04-Apr-92 20 04-Apr-92 21 04-Apr-92 22 04-Apr-92 22 04-Apr-92 23 04-Apr-92 23 04-Apr-92 23 05-Apr-92 0 05-Apr-92 1 05-Apr-92 1 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05-Apr-92 2 05- Apr- 92 2 05-Apr-92 4 05-Apr-92 5 05- Apr- 92 6 05-Apr-92 7 05-Apr-92 8 05-Apr-92 9 05-Apr-92 10 05-Apr- 92 11 05-Apr-92 12 05- Apr- 92 13 05-Apr-92 14 05-Apr- 92 14 05-Apr- 92 14 05-Apr- 92 14 05-Apr- 92 14 05- Apr- 92 15 05-Apr-92 15 Min 53 1 11 11 11 11 11 11 11 11 31 1 21 41 41 41 51 1 3 7 11 13 15 17 19 59 0 0 0 0 0 0 0 0 0 0 0 57 59 3 11 Tubing Head Pressure (PSI) 1742 1742 psi 1725 1725 1726 1726 1725 1725 1725 1726 1725 1.5 mmcfd 1724 1724 1724 1723 1723 1723 1723 1704 1647 1645 1645 1663 1677 1689 1689 1689 1689 1689 1689 1690 1689 1689 3.5 mmcfd 1689 1688 1689 1687 1687 1687 1687 1621 1648 1613 1609 1609 Time on Tes (hrs) 0 0.133333 0.3 1.3 2.3 3.3 4.3 5.3 6.3 7.3 7.63,3,3,33 8.13,3,3,33 8.466667 8.8 9.8 10.8 10.96667 11.13333 11.16667 11.2'3,3,.13 11.3 11.3,3,3,33 11.36667 11.4 11.43333 11.6 12.1 13.11667 14.11667 15.11667 16.11667 17.11667 18.11667 19.11667 20.11667 21.11667 22.11667 23.11667 23.95 24 24.06667 24.1 24.16667 24.3 RECEIVED d U t',l ~ 0 199;~ Alaska 0il & Gas Cons. Commission Anchorage 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05- Apr- 92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr-92 05-Apr- 92 05-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06- Apr- 92 06-Apr- 92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06 - Ap r - 92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06 - Ap r - 92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 15 15 15 15 15 15 16 16 16 16 16 17 18 19 20 21 22 23 0 1 2 3 4 5 6 7 8 9 9 9 9 9 9 10 10 10 10 10 10 10 10 10 10 11 11 12 13 14 15 16 17 17 23 25 27 33 53 4 14 24 34 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 47 49 51 55 1 5 11 21 25 37 41 45 1 5 5 5 5 5 5 5 1610 1610 1612 1614 1615 1616 1617 1619 1620 1620 1621 1621 1622 1622 1622 1623 1624 1624 1625 1625 1625 1626 1626 1626 1626 1626 16'26 1626 1507 1556 1495 1532 1524 1522 1519 1517 1518 1519 1520 1521 1522 1523 1524 1525 1525 1528 1528 1529 1529 1529 1525 5.5 mmcfd 8.5 mmcfd ...... · 24.4 24.5 24.5,3,3,33 24.56667 24.66667 25 25.18333 25.35 25.51667 25.68333 25.85 26.85 27.85 28,85 31.85 32.85 37.85 41.85 42.85 42.9 42.93333 42.96667 43 43.03333 43.13,.3,33 43.2 43.3 43.46667 43.7 43.73333 43.8 43.86667 44.13333 44.2 45.2 46.2 47.2 48.2 49.2 50.2 aiaska Oil & ~as Co~-~s. Commi~l¢~ Anchorage 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-g2 06-Apr- 92 06-Apr- 92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 06-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr- 92 07-Apr-92 07-Apr-92 07-Apr-92 07-Apr-92 18 19 20 21 22 23 23 23 23 23 23 23 23 23 0 0 0 1 1 3 3 5 5 5 6 7 7 5 5 5 5 5 1 3 5 7 9 11 13 15 29 1 27 29 39 41 8 18 8 18 28 58 8 18 1526 1528 1528 1528 1528 1528 1729 shut in 1729 1730 1730 1731 1731 1732 1732 1733 1733 1734 1734 1735 1735 1736 1736 1737 1737 1737 1737 1737 51.2 52.2 53.2 54,2 55.2 56.13333 56.16667 56.2 56.3 56.6 57.13333 57.56667 57.6 58.76667 58.8 60.25 60.41667 62.25 62.41667 64.25 64.41667 RECEIVED JUN ~ 0 1992 Alaska Oil & Gas Cons. Commission Anchorage Baker 18 Flow Test, April 03-07, 1992 12 Hour Flow Rates, Flow after flow Run ID (inches) Static Range (psi) Diff Range (Inches Water) 4.026 1000 200 PERIOD ORIFICE 1.75 1.75 1.75 2.5 BASE FACTOR 634.39 634.39 634.39 1387.2 Tyonek Gas Sand - #40 Fb, Fy, Fa, Fg, Ft, Fpv 1.3795 1.3795 1.3795 1.3795 DIFF STA'RC RATE 19 290 74 290 192 300 56 310 1559.068 3O76.834 5040.812 6051.275 C:~FIE LDS~ GS\B18AOF.VVK3 06/01/92 Well I de~ tific&tion Static Reser~k Pressure Surface Shutin Pressure Baker 18 Tyonek 40 Sand (April 1992) 1.928.00 psla 1.740.0 psig Test Q Ptf Pwf LOG(Q) LOG(Pterm) Pt [M C FI:)! psig psie San(Ifa&ce I 1.559 1.725.0 1,915.00 3.193 4.699 2 3,077 1.689.0 1.888.00 3.488 5.184 3 5,041 1,620.0 1,843.00 3.703 5.50~ 4 6.151 1,529.0 1,812.00 3.789 5.637 LOG (Ptefm) Surface 4.719 5.246 5.609 5.843 F~m Linear Regression' ** Don'tlorget to re-regress! (Alt - R) llSIope (n) - 0.6357 psia "2,/MCFD Coeff. (C) =, 1.591E+00 MCFDIpsie AOF = 23.9 MMCFD Sandface Regression Output: Con start Std Error Y Est R Squared No. of Observations Degrees of Freedom -0.31714 0.011633 0.999483 Wh&t Ifs: Hypo Pwf Delivery 1750 7,923 Hypo Delivery I Pvvf 8000 1,747 Surf Orawdown I Delivery 10.0% 5,802 OH Drewdov~ I Delivery 10.0% 6,314 1735 psia Pwf X Coefficient(s) Std Err of Coef. 1.573050 0.025292 P~)jected Pterm $1ndface 4.705 5.170 5.507 5.643 Surface Regression Output: Con start t Std Err of Y Est R Squared No. of Obse~ations Degrees of Freedom X Coefficient(s) Std Error Coef. 1.838673 0.082744 - 1.16017 0.038058 0.995966 4 2 l/Slope (n) = Coeff. (C) - AOF " 0.5439 psia ^ 2/M CFD 4.275E +00 M CFDIpeta 14,4 MMCFD %DD 9et 0.67 2.07 4.41 6.02 Future Dellverabl#y Pn)jecllon ** Asaumel C md n remain oo~ltmt through projection re#~ok ppe#ure %D0 Surf 0.86 2.93 6.90 12.13 Projected Static Re~e~olr Pr~mm =, 1928 %DD Point Pvvf [p~la] Q [MCFD] -0.0% 1 1928 ERR 2.0% 2 1689 3068 4.0% 3 1851 4736 6.0% 4 1812 6089 8.0% 5 1774 7263 10.0% 6 1735 8314 12.0% 7 1697 9273 14.0% 8 1658 10159 16.0% 9 1620 1O983 18.0% 10 1581 11755 What ifs: Input Pvvf 2OOO Input Q 4600 Input % DD I 0.0% Output Q ERF 1854 4 Outl~l t C 8,314 $,"f ¢.8 ,C,'~F IE L D,~ Id e ~J 1 IA 0 I~, ItE,I Baker 18 Flow Test, April 03-07, 1992 12 Hour Flow Rates, Flow after flow Run ID (inches) Static Range (psi) Diff Range (Inches Water) 4.026 1000 200 PERIOD ORIFICE 1.75 1.75 1.75 2.5 BASE FACTOR 634.39 634.39 634.39 1387.2 Tyonek Gas Sand - #40 Fb, Fy, Fa, Fg, Ft, Fpv 1.3795 1.3795 1.3795 1.3795 DIFF STATIC RATE 19 290 74 290 192 300 56 310 1559.068 3076.834 5040.812 6051.275 C:~=IE LDS~ G S\B 18AOF,WK3 Well I d~rt tiflcM Static Reser~ if Pressure Surface Shutk~ Pressure Baker 18 Tyon®k 40 Smd (April 1992) 1.928.00 piti 1.740.0 psig Tea O PIf Pwf LOG(Q) LOG(Pterm) Pt [MCFD] psig psia Sandf&ce I 1,559 1,725.0 1,915.00 3.193 4.699 2 3,077 1,689.0 1,888.00 3.468 5.184 3 5,041 1,620.0 1,843.00 3.703 5.506 4 6,151 1,529.0 1,812.00 3.789 5.637 LOG(Ptefm) Surface 4.719 5.246 5.609 5.843 From L~ear Regression: ** Don't Iorget to re- regress! (Alt - R) ll,~ope (n) = 0.6357 psia ^ 2./M CFO Coeff. (C) = 1.591E+00 MCFD/psia AOF = 23.9 MMCFO Sandface Regressi:)n Output: Constant $ld Error Y Est R Squ&red No. of O bsefvations Degrees of Freedom -0.31714 0.011633 0.999483 4 2 What ifs: Hypo Pwf Delivery 1750 7,923 Hypo Delivery / Pwf 8000 1,747 ' Surf Drawdown / Delivery 10.0% 5,802 BH Orewdo~f~ / Delivery 10.0% 8.314 1735 psi~ Pwf X Coefficient(s) Std Err of Coef. 1.573056 0.025292 Projected Pterm $andface 4.705 5.170 5.507 5.643 Surface Regressbn Output: Constant Std Efrof Y Est R Squared No. of O bsewationl Degrees of Freedom X Coefficient(s) $td E~Tof Coef. 1.838~73 0.082744 -1.16017 0.038058 0.995966 4 2 l/Slope (n) = Coeff. (C) - AOF 0.5439 psia "2/M CF D 4.275E+00 M CFD/psia 14.4 MMCFD ROD Bot 0.67 2.07 4.41 6.02 Fulure Oellverablily P~oje,,"lion ** Alsume~ C and n remain eonstltt through projection resen~oi~ pressure % DO Projected Static Surf Reser~ok Pressure 0.86 2.93 % DO Poker Pwf [pli8] 8.90 1928 O [MCFD] 12.13 -0.0% 1 1928 ERR 2.0% 2 1889 343~8 4.0% 3 1851 4736 6.0% 4 1812 6089 8.0% 5 1774 7263 10.0% 6 1735 8314 12.0% 7 1697 9273 14.0% 8 1656 10159 16.0% 9 1620 10983 18.0% 10 1581 11755 Input Pwf OqJtput Q Input O Output Pwf 4600 1854.4 Input %DD Output O 10.0% 8.314 Bmk~ 11 TI,~.~_ k 40 Suod(Apnl t)92) $ I D,~,mbol. FI~ artec FI,0., J.t 3.1 ~.S L~( I~ h,,IUC~l) ~'~ S.~ ~.t J.t ¢.~ i~LD~,MOSdIIAOf. WrJ & 9 6 'N'd 9 Gas Meter r tort Unocal North American"O'il/&" - Division UNOCAL~) ..... i ,, OATE METER NO. z./--~ ,_,~ z_ //~ / .... . .... , FIELO MAKE OF METER L~SE TYPE OF METER ~ MERCURY ~LOWS ~ VOLUMETRIC ....... FROM TYPE TAPS GAS TO STATIC CONNECTION , ,,, CHANGES CALIBRATION / INSPECTION EFFECTIVE OATE ~ CALIBRATION ~ INSPECTION DATE .... .... ~.~. ~,, ,u, .......... ~.o. s~z~ ~, 0 ~ o~c~ ....... SIZE ORIFICE ..... er STATIC STATIC SIZE ~ ............. SPRING SIZE 0~ ~ 0 ~ DIFFERENTAL RANGE ........ DIFFERENTAL ..... RANGE REMARKS .............. FACTOR (VOLUMETRIC) .................. CLOCK ............ TEMPERATURE ......... Anchorage , , , GRAVITY ,, , ,, , , , ......... , ,, PREPARED BY / 6 'H'd 9 STATE OF ALASKA 0 ~ ,~ ~3 ~ A ~ ALAsK )ILAND GAS CONSERVATION COM[ SION WELL COMPLETIO OR REOOMPLETION F: PORT AND LOG 1. Status of Well Classification of Service Well 2. N~e of Oper~or 7. Pe~it Number UNION OIL ~M PANY OFCALIFORNIA (UNOCA~ 76-75/92-029 3. Address 8. APl Number P.O. BOX 196247, ANCHO~GE, AK 99519 733--202~ 4. ~c~ion of well ~ su~ace 9. Unit or Le~e N~e 1937' FN~ 539' ~L, SEC. 31, TgN, R12W, SM ...... .~ MIDD~ GROUND SHOAL At T~ Producing Inte~al 10. Well Number 11~ FSL 826' ~L, SEC. 30, T9N, R12W, SM " ;; ~ 18 At T~ Depth ~ ~.._ ~ 11. Field ~d Pool ~' FS~ ~' ~L, SEC. ~, ~N, R12W, SM ~ ~_~ ~ ~ ~ .........'-"' ~ MIDD~ GROUND SHOAL 5. El~ation in feet (indicate KB, DF, etc.) ~6. Le~e Designation and Serial No. 79.4 KBJ ADL 17595 12. D~e Spud~d 13. D~e T.D. Re~hed ~ 14. Dine Comp., Susp. or Aband. ~ 15. W~er Dep~, E offshore ~ 16. No. of Completions 1~7 3/14~7~ 3/15~2~ 79.4 Feet MSLJ 1 ~7.~a~pth~M~+~)~.~~kD~pth~MD+~)~.D~r~ct~nal~u~eg~2~.D~pthwher~888V`~t~2~.~h~ckn~`~~a~r~t~23~ &8,223 7635 &63~ I~s ~ NO~ 312 IootMD N/A 22. Type Electric or Other Logs Run CB~GR/CCL 23. CASING, MNER AND CEMENTING RECORD CASING SIZE ~. PER ~. G~DE TOP BOSOM HOLE SI~ CEMEN~NG ~CORD AMOUNT PU~D 20" 37 5~ 26" 14~ SXS NON E 13-3/8" 61 & 68~ K-55 36 35~ 17-1/2" 18~ SXS NONE 9- 5/8" 40- 43.5~ S-95 33 5~ 12-1/4" 6~ SXS NON E 7" 29~ S-95 5710 10,107 8-1/2" 295 SXS NONE 24. Pedorations open to Production (MD+~D of T~ and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE J DEPTH SET (MD) ~ PACKER S~ (MD) 4757, 3~7 SEE A~ACHMENT 1 2-7/8" 47~' ~69, 3453 26. ACID, F~CTURE, CEMENT SQUEEZE, ~C. DEPTH INTERVAL (MD) ~ AMOUNT & KIND OF MATERIAL USED SEE A~ACHMENT 2 27 PRODUCT~N TEST Date Fimt Production ~ Method of Oper~ion (Flowing, gas lift, etc.) 03/14~2J FLOWING Date of Test Hours Tested PRODUC~ON FOF OIL-BBL GAS-MCF WATER-BBL C~KE SIZE J GAS-OIL~TIO I TEST PE~OD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OILG~VI~-API (corr) Press. 24-HOUR ~TE 28. CORE DATA Brief description of lithology, porosi~, fractures, appare~ dips ~d presence of oil, g~ or w~er. Submit core chips. RECEIVE Alaska Oit & Gas Cons. ~t~!O¢ ' cho. Form 10-407 rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. 31. lIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed GARY S. BUSH . 'Rtle REG. DRLG MANAGER Date MAY4, 1992 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 measure ments given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. RECEIVED BAKER WELL #18 ADL 17595 PERFORATION RECORD J~A¥ 1 ,~ 1992 AJaska Oil & Gas Cons. Comn~JsSJ!)~ TRUE MEASURED VERTIC~ ~homga DA~ IN~RV~ DEP~ DEP~ REASON STA~S 03/08/92 34~-~68 3271-3273 REM CMT SQUEEZED 03/11~2 "31" S~D 3494-3502 3292-3298 PROD OPEN 03/08/92 3530-3532 3319-3321 SQUEEZE SQUEEZED 03/08~2 3710-3712 3452-~54 SQUEEZE SQUEEZED 03/11~2 "32" S~D 3720-3761 3459-~ PROD OPEN 03/07~2 37~-3792 35~-3510 SQUEEZE SQUEEZED. 03/04/92 39~-3~2 3~-~ SQUEEZE SQUEEZED 03/11/92 "34" S~D 4013-~1 3~2-~1 PROD OPEN 03/11/92 "35" S~D 4089-~94 3713-3718 PROD OPEN 03/07/92 4118-4120 3732-3734 REM CMT SQUEEZED 03/03/92 4128-4130 3739-3741 SQUEEZE SQUEEZED 03/14/92 "40" S~D 4865-~3 4265-4278 PROD OPEN 11/11/87 B- 1: ~80- ~82 5636- ~38 TST ISO~T ~~D 11/15/87 ~85-6705 5641-5655 INACTION ~~D 11/12/87 B-2: 67~-6792 5713-5715 ~T ISO~T ~~D 11/15/87 6796-~38 5719-5746 INACTION ~~D 11/15/87 B - 3: 6~6 - 6944 5783 - 5824 INACTION ~~D 11/14/87 ~36-~38 6~5-~47 TST ISO~T ~~D 11/11/87 6948- 6952 5825- 5829 TST ISO~T ~D 11/08/87 C- 1: 7162-7165 5~7-5981 SQUEEZE ~D 11/15/87 7170-7212 5983-~13 INACTION ~~D 11/15/87 C-2: 7255-7284 6041-~4 INACTION ~~D 11/15/87 C-3: 7343-7380 6105-6129 INACTION ~~D 11/15/87 C-4: 7416-7437 6156-6128 INACTION ~~D 11/08/87 7~ 1 - 7445 6172- 6176 SQUEEZE ~~D 11/14/87 8703-~05 7055-7057 TST ISO~T ~~D 06/15~7 G- 1: 8749-~51 70~-7~1 SQUEEZE ~~D ~/15~7 8934-~36 7227-7229 SQUEEZE ~~D 02~7/82 9125-9135 7370-7377 INACTION ~~D 02/27/82 9148-9153 7385-7390 INACTION ~~D 02~7/82 9162 - 9172 7397- 7404 INACTION ~~D 02~7/82 9212-~17 7435-7437 INACTION ~~D 02~7/82 9222-~32 7~2-7450 INACTION ~~D 02~7/82 9246-~56 7459-7469 INACTION ~~D 03~5~7 9310-~34 7509-7528 PROD ~~D 03/25~7 9354-~62 7543-7549 PROD ~~D 03/25~7 9382-~04 75~-7582 PROD ~~D 03/25~7 9452-~ 7618-7628 PROD ~~D 03~5~7 9476-~94 7635-7650 PROD ~~D 03/25~7 9610-~20 7739-7747 PROD ~D 03/25~7 9632-~52 7756-7772 PROD ~D 03/25~7 9~0-~70 7778-7785 PROD ~D 03~5~7 9742-~8 7~1-7970 PROD ~~D 03~4~7 G-2: ~12-~20 7974-7979 PROD ~~D BAKER WELL #18 ADL 17595 SQUEEZE RECORD TRUE CEMENT MEASURED VERTICAL DATE VOLUME DEPTH DEPTH REASON STATUS 03/08/92 300 SXS 3466-3468 3271-3273 REM CMT SQUEEZED 03/08/92 200 SXS 3530-3532 3319-3321 SQUEEZE SQUEEZED 03/08/92 200 SXS 3710-3712 3452-3454 SQUEEZE SQUEEZED 03/07/92 200 SXS 3790-3792 3508-3510 SQUEEZE SQUEEZED 03/04/92 300 SXS 3990-3992 3646-3648 SQUEEZE SQUEEZED 03/07/92 200 SXS 4118-4120 3732-3734 REM CMT SQUEEZED 03/03/92 300 SXS 4128-4130 3739-3741 SQUEEZE SQUEEZED BAKER WELL NO. 18 LEG 1, SLOT 3 ADL 1 7595 SPUD 1/01/77 COMPLETION RECORD 2-7/8' ,6.4# N-80 TBG 1. OTIS SSSV 312' 2. OTIS XA SLEEVE 3408' 3. BAKER SAB-3 PKR 3453' 4. OTIS XA SLEEVE 3486' 5. OTIS 'BWH" PKR 3669' 6. OTIS XA SLEEVE 3703 7. OTIS 'BWH' PKR 3967' 8. OTIS XA SLEEVE 4002' 9. BAKER "F' PKR 4757' 10. OTIS 'XN' PROFILE 2.25' 4790' 11. BAKER 5' PERF GUNS TOC (TEMP) 4400' 9 5/8' 40 & 43. 5# S-95 @ 5983' CEMENTED WITH 600 SXS POSSIBLE COLLAPSE 6664' MAX INCLINATION 48.9 DEG 7' 29#, S-95 F/571 O' - 1 O, 107' CEMENTED WITH 295 SXS PBD 10,01 O' TD 10,231' 20" CASING AT 621' CEMENTED W/1400 SXS 13-3/8" 61 & 68#, K-55 @ 3500' CEMENTED WITH 1800 SXS 3466-3468 SQZ'D "31" SAND 3494~3502 OPEN 3530-3532 SQZ'D 3710-3712 SQZ'D "32" SAND 3720-3761 OPEN 3790-3792 $QZ'D 3990-3992 $QZ'D "34" SAND 4013-4041 OPEN "35" SAND 4089-4094 OPEN 4118-4120 SQZ'D 4128-4130 SQZ'D "40" SAND 4865-4883 OPEN 7" LINER TOP 571 O' BROWN MC HYD HANGER 7" 29# x 9-5/8" 43.5# 6' EXTENSION (ID = 7.5') BAKER MODEL 'F' PACKER AT 6500' B-1: 6680' - 6705' B-2: 6790' - 6838' B-3: 6886' - 6952' C-1: 7162' - 7212' C-2: 7255' - 7284' C-3: 7343' - 7380' C-4:7416' - 7445' DRILLABLE BP @ 7635' SAND ON TOP OF BP DRILLABLE BP @ 7680' (LEAKS) G-1: 8749' - 9908' FILL AT 8856' Go2: 9912' - 9920' SEE PERF DETAIL FOR EXACT INTERVALS GRB 4/7/92 DATE BAKER #18 WORKOVER JOB HISTORY ETD COMMENTS 02/28/92 02/29/92 03/01/92 03/02/92 03/03/92 03/04/92 7635' 7635' 7635' 7635' 6480' 3965 SKIDDED RIG TO WELL#18. KILLED WELL WITH 10.2 PPG NaC1/NaBr BRINE. RIH WITH WIRELINE AND PUNCHED THE TUBING FROM 6460-64'. POOH AND RIGGED DOWN WIRELINE. KILLED THE WELL USING 10.2 PPG BRINE. RIH AND SET DW PLUG AT 500'. REMOVED TREE. INSTALLED BOPE. TESTED 13-5/8" 5M BOPE TO 5000 PSI. CONT'D TESTING BOPE TO 5000 PSI, OK. RIH AND RETRIEVED DW PLUG AT 500'. UNSTABBED FORM THE BAKER "F" PACKER AT 6500'. POOH WITH 3.5" TBG. TESTED BLIND RAMS TO 5000 PSI. RAN CBL/CCL/GR FROM 5704' TO SURFACE. CONT'D RUNNING CBL/GR/CCL. RAN 8.5" GAUGE RING - JUNK BASKET TO 6100', STOPPED. RAN 8.5" GAUGE RING - JUNK BASKET TO 6102', STOPPED. RIH WITH A 7" CEMENT RETAINER AND SET AT 6480'. TESTED THE RETAINER AND ANNULUS TO 2000 PSI, OK. OBTAINED AN INJECTION RATE OF 1-BPM AT 1800 PSI. ABANDONED THE "B,C, AND G" ZONES THROUGH THE RETAINER AT 6480' WITH 200 SXS (230 CF) OF 15.8 PPG NEAT "G" CEMENT. PULLED UP TO 6396 AND REVERSED OUT. REDUCED MUD WEIGHT FROM 10.2 TO 9.0 PPG. RIH WITH WIRELINE AND PERFORATED FROM 4128-30'. POOH. ATTEMPTED TO CIRC 9-5/8" x 13-3/8" CSG STRINGS, NEG. RIH AND SET A 9-5/8" CEMENT RETAINER AT 4089'. TESTED THE ANNULUS AND RETAINER TO 2000 PSI, OK. RIGGED UP B.J. AND PUMPED 200 SXS (236 CF) 15.7 PPG "G" CEMENT AT 500 PSI. PULLED UP TO 4032' AND REVERSED OUT. RIH WITH WIRELINE AND PERFORATED FROM 3990-92'. BROKE CIRCULATION DOWN THE 9-5/8", THROUGH THE PERFORATIONS AND OUT THE 13-3/8" x 9-5/8" ANNULUS. RIH AND SET A CEMENT RETAINER AT 3965'. PUMPED A 90 BBL SWEEP FOLLOWED BY 300 SXS OF CEMENT DOWN THROUGH THE PERFS AT 3990-92' WHILE TAKING RETURNS UP THE 13-3/8" x 9-5/8" ANNULUS, FULL RETURNS. PULLED UP TO 3908' AND REVERSED OUT. POOH. TESTED BOPE TO 5000 PSI. DATE BAKER #18 WORKOVER JOB HISTORY ETD COMMENTS 03/05/92 03/06/92 03/07/92 03/08/92 03/09/92 03/10/92 4201' 5700' 3750' 3435' 3735' 4200' DRILLED CEMENT AND THE RETAINER AT 3965' FROM 3944' TO 4065' WITH AN 8- 1/2" BIT AND SCRAPER. TRIP FOR BIT. RIH WITH 8-1/2" BIT. TESTED SQUEEZE FROM 3990-92' TO 1000 PSI, OK. DRILLED CEMENT FROM 4065' TO 4089'. DRILLED RETAINER AT 4089'. DRILLED CEMENT FROM 4092'-4169'. CLEANED OUT CEMENT STRINGERS FROM 4169' -4201' DRILLED CEMENT STRINGERS FROM 4201' TO 4287'. RIH TO THE TOL AT 5710'. CIRC. POOH. RAN CBL/GR/CCL FROM 5700' -100'. RIH AND SET A CEMENT RETAINER AT 5700'. PRESSURE TESTED BELOW THE RETAINER TO 2000 PSI, OK. RIH WITH A BIT AND SCRAPER TO 5700'. CIRC. POOH. SET CEMENT RETAINER AT 4150' DIL. RIH AND PERFORATED FROM 4118-20' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 4090'. SQUEEZED PERFORATIONS FROM 4118-20' WITH 200 SXS OF CEMENT. FINAL PRESSURE 900 PSI AT 1-1/2 BPM. SET A CEMENT RETAINER AT 3820'. RIH AND PERFORATED FROM 3790-92 W/ 4SPF. SET CEMENT RETAINER AT 3750'. SQUEEZED PERFORATIONS FROM 3790-92' WITH 200 SXS OF CEMENT . RIH AND PERFORATED FROM 3710-12' W/ 4SPF. RIH AND SET CEMENT RETAINER AT 3666'. SQUEEZED THE PERFORATIONS FROM 3710-12' WITH 200 SXS OF CEMENT. RIH AND PERFORATED FROM 3530-32' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 3500'. SQUEEZED THE PERFORATIONS FROM 3530-32' WITH 200 SXS OF CEMENT. RIH AND PERFORATED FROM 3466-68' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 3435'. ESTABLISHED CIRCULATION THROUGH THE PERFORATIONS AT 3466-68' AND OUT THE 9- 5/8" x 13-3/8" ANNULUS. PUMPED 300 SXS OF CEMENT WHILE TAKING RETURNS OUT THE 9-5/8" x 13-3/8" ANNULUS DRILLED CEMENT AND RETAINERS FROM 3432' - 3735'. RETAINERS AT 3435', 3500', AND 3666'. POOH FOR BIT CHANGE. DRILLED CEMENT AND RETAINERS FROM 3735' - 4090'. RETAINERS AT 3750' AND 3820'. TRIP FOR BIT. DRILLED CEMENT AND DATE BAKER #18 WORKOVER JOB HISTORY ETD COI~ENTS 03/11/92 03/12/92 03/13/92 03/14/92 03/15/92 5682 ' 5682' 5682' 5682 ' 5682' RETAINERS FROM 4090' -4150'. RETAINERS AT 4090' AND 4150'. CHASED RETAINER FROM 4150' -4200'. POOH. CONT'D POOH. RIH WITH A BIT AND 9-5/8" CASING SCRAPER TO 5682'. CHANGED HOLE TO CLEAN NaC1/3% KC1 BRINE. POOH. MADE AN 8.5" GAUGE RING RUN TO 4958'. RIH AND SET A BAKER MODEL "F-i" PACKER AT 4753'. RIH AND WIRELINE PERFORATED THE FOLLOWING ZONES. "35" 4089-94', "34" 4013-41', "32" 3720-61', AND "31" 3494-3502' WITH 4SPF. RIH WITH AN 8.5" GAUGE RING AND JUNK BASKET TO 4300'. RIH WITH TCP GUNS , 2-7/8" TBG, BLAST JOINTS AND AN OTIS HYDRAULIC SET PACKER. HYDROTESTED THE COMPLETION TO 4000 PSI. STABBED INTO THE 9-5/8" BAKER PACKER AT 4735' AND SET THE OTIS PACKER AT 3954', LEAVING THE GUNS ACROSS THE "40 SAND" FROM 4865'-4883'. RIH HYDROTESTING 2-7/8" TUBING BLAST JOINTS AND SET OTIS HYDRAULIC SET PACKER AT 3954'. CHANGED THE RAMS TO 2-7/8" AND TESTED TO 5000 PSI. RIH WITH 2-7/8" TUBING BLAST JOINTS A BAKER SBA-3 PACKER WHILE HYDROTESTING TO 4000 PSI. LANDED THE COMPLETION. TESTED THE TUBING HANGER TO 3000 PSI, OK. INSTALLED BPV AND REMOVED THE BOPE. CONT'D REMOVING BOPE. INSTALLED 3" 5M CIW SINGLE TREE AND TESTED THE HANGER TO 5000 PSI, OK. TESTED THE TREE TO 5000 PSI. RIH AND SET AN X PLUG IN THE XA SLEEVE AT 3485'. PRESSURED UP ON THE TUBING AND SET THE BAKER SAB-3 PACKER AT 3440'. TESTED THE 9-5/8" ANNULUS TO 2500 PSI, OK. OPENED THE XA SLIDING SLEEVE AT 3407' AND CHANGED THE ANNULUS OVER TO INHIBITED FLUID. DISPLACED THE TUBING VOLUME TO 2070' THROUGH THE SLEEVE AT 3407' WITH 850 PSI OF NITROGEN. RIH AND CLOSED THE "XA" SLEEVE AT 3407'. DROPPED BAR AND FIRED THE GUNS FROM 4883-65' WITH 4SPF. FLOWED WELL TO PRODUCTION. ON AN 8/64" CHOKE WITH 1730 PSI TBG PRESSURE AT 750 MCFD. RELEASED RIG AT 1200 HRS. Unocal North Americ; Oil & Gas Division Unocal Corporation .... P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region May 6, 1992 Joan Miller Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 MIDDLE GROUND SHOAL 17595 ~18 Dear Joan: The attached form 10-407 is in response to our conversation last week. As you pointed out a 10-407 form was the appropriate form. I apologize for the confusion. If you have any questions please call me at 263-7865. Sincerely, George R. Buck Drilling Engineer MAY 1 ) 1992 ,Alaska Oil & Gas Cons. ~umrniss'ton Anchorage STATE OF ALASKA AI~ ~ OIL AND GAS CONSERVATION COMk ,ION ~ REPORT OF SUNDRY WELL OPERATIO 1. Operations performed: Operation shutdown Stimulate __ Pull tubing __ Alter casing__ Plugging __ Perforate X Repair well __ Pull tubing Other__ 2. Name of Operator 15. Type of Well: Development X Union Oil Company of Caifornia (Unocal) Ex,~or. tory 3. Address Stratigraphic P.O. Box 196247 Anchorage, AK 99519-624 s~ce 4. Location of well at surface 1937' FNL, 539' FWL, Sec. 31, T9N, R12W, SM At top of productive interval 1100' FSL, 826' FWL, Sec. 30, T9N, R12W, S.M. At effective depth 7635' 1754' FSL, 1006' FWL, Sec. 30, T9N, R12W, S.M. At total depth 10,231' 3353' FSL, 1697' FWL, Sec. 30, T9N, R12W, S.M. 6. Datum elevation (DF or KB) 79.4 7. Unit or Property name MGS State 17595 8. Well number Well No. 18 feet 9. Permit number/approval number ~-~92- 029/92- 017 10. APl numb~er ~ 50-733-20296 11. Field/Pool Middle Ground Shoal 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured 7635' feet true vertical 6304' feet Length Size 584' 3464' 5949' 4397' Perforation depth: measured 10,231' feet Plugs (measured) 8823' feet Junk (measured) Drillable B.P. ~ 7635' Driilable B.P.@ 7680' Cemented Measured depth True vertical depth 20" 1400 sxs 621' 621' 13- 3/8" 1800 sxs 3500' 3296' 9- 5/8" 600 sxs 5983' 5139' 7" 292 sxs 5710'- 10,107' 8126' See attachment 1 true vertical Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80, 4790' Packers and SSSV (type and measured depth) Baker "F" 4757', Otis "BWH" 3967', Otis "BWH" 3669', Baker SAB-3' 3453', Otis $SSV 312' 13. Stimulation or cement squeeze summary ~,ECE iV ~['~ 14. Intervals treated (measured) Treatment description including volumes used and final pressure Alaska ~0ii.& Gas O0~s. C0mm[ss[0~ Representative Daily Average Production or Injection Data ~!~.[;[[0_i'5§6 Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 0 250 0 1.5MMSCF 0 0 1725 15. Attachments Copies of Logs and Surveys runX_ Daily Report of Well Operations X_ 16. Status of well classification as: Oil__ Gas X Suspended__ Service 17. I hereby certi~at the foregoing is true and correct to the best of my knowledge. ~us~~ ~ ~'~"' Title Reqional Drillinq Manager Signed Gary Form 10-404 Rev9.6/15/88 Date SUBMIT IN DUPLICATE DATE BAKER #18 WORKOVER JOB HISTORY ETD COMMENTS 02/28/92 7635' 02/29/92 7635' 03/01/92 7635' 03/02/92 7635' 03/03/92 6480' 03/04/92 3965 ":i ~,?,: SKIDDED RIG TO WELL#18. KILLED WELL WITH 10.2 PPG NaCl/NaBr BRINE. RIH WITH WIRELINE AND PUNCHED THE TUBING FROM 6460-64'. POOH AND RIGGED DOWN WIRELINE. KILLED THE WELL USING 10.2 PPG BRINE. RIH AND SET DW PLUG AT 500'. REMOVED TREE. INSTALLED BOPE. TESTED 13-5/8" 5M BOPE TO 5000 PSI. CONT'D TESTING BOPE TO 5000 PSI, OK. RIH AND RETRIEVED DW PLUG AT 500'. UNSTABBED FORM THE BAKER "F" PACKER AT 6500'. POOH WITH 3.5" TBG. TESTED BLIND RAMS TO 5000 PSI. RAN CBL/CCL/GR FROM 5704' TO SURFACE. CONT'D RUNNING CBL/GR/CCL. RAN 8.5" GAUGE RING - JUNK BASKET TO 6100', STOPPED. RAN 8.5" GAUGE RING - JUNK BASKET TO 6102', STOPPED. RIH WITH A 7" CEMENT RETAINER AND SET AT 6480'. TESTED THE RETAINER AND ANNULUS TO 2000 PSI, OK. OBTAINED AN INJECTION RATE OF 1-BPM AT 1800 PSI. ABANDONED THE "B,C, AND G" ZONES THROUGH THE RETAINER AT 6480' WITH 200 SXS (230 CF) OF 15.8 PPG NEAT "G" CEMENT. PULLED UP TO 6396 AND REVERSED OUT. REDUCED MUD WEIGHT FROM 10.2 TO 9.0 PPG. RIH WITH WIRELINE AND PERFORATED FROM 4128-30'. POOH. ATTEMPTED TO CIRC 9-5/8" x 13-3/8" CSG STRINGS, NEG. RIH AND SET A 9-5/8" CEMENT RETAINER AT 4089'. TESTED THE ANNULUS AND RETAINER TO 2000 PSI, OK. RIGGED UP B.J. AND PUMPED 200 SXS (236 CF) 15.7 PPG "G" CEMENT AT 500 PSI. PULLED UP TO 4032' AND REVERSED OUT. RIH WITH WIRELINE AND PERFORATED FROM 3990-92'. BROKE CIRCULATION DOWN THE 9-5/8", THROUGH THE PERFORATIONS AND OUT THE 13-3/8" x 9-5/8" ANNULUS. RIH AND SET A CEMENT RETAINER AT 3965'. PUMPED A 90 BBL SWEEP FOLLOWED BY 300 SXS OF CEMENT DOWN THROUGH THE PERFS AT 3990-92' WHILE TAKING RETURNS UP THE 13-3/8" x 9-5/8" ANNULUS, FULL RETURNS. PULLED UP TO 3908' AND REVERSED OUT. POOH. TESTED BOPE TO 5000 PSI. DATE BAKER #18 WORKOVER JOB HISTORY ETD COMMENTS 03/05/92 4201' 03/06/92 5700' 03/07/92 3750' 03/08/92 3435' R C E ] V ~[aska uij & 8as Oons. 03/09/92 3735' 03/10/92 4200' DRILLED CEMENT AND THE RETAINER AT 3965' FROM 3944' TO 4065' WITH AN 8- 1/2" BIT AND SCRAPER. TRIP FOR BIT. RIH WITH 8-1/2" BIT. TESTED SQUEEZE FROM 3990-92' TO 1000 PSI, OK. DRILLED CEMENT FROM 4065' TO 4089'. DRILLED RETAINER AT 4089'. DRILLED CEMENT FROM 4092'-4169'. CLEANED OUT CEMENT STRINGERS FROM 4169' -4201' DRILLED CEMENT STRINGERS FROM 4201' TO 4287'. RIH TO THE TOL AT 5710'. CIRC. POOH. RAN CBL/GR/CCL FROM 5700' -100'. RIH AND SET A CEMENT RETAINER AT 5700'. PRESSURE TESTED BELOW THE RETAINER TO 2000 PSI, OK. RIH WITH A BIT AND SCRAPER TO 5700'. CIRC. POOH. SET CEMENT RETAINER AT 4150' DIL. RIH AND PERFORATED FROM 4118-20' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 4090'. SQUEEZED PERFORATIONS FROM 4118-20' WITH 200 SXS OF CEMENT. FINAL PRESSURE 900 PSI AT 1-1/2 BPM. SET A CEMENT RETAINER AT 3820'. RIH AND PERFORATED FROM 3790-92 W/ 4SPF. SET CEMENT RETAINER AT 3750'. SQUEEZED PERFORATIONS FROM 3790-92' WITH 200 SXS OF CEMENT . RIH AND PERFORATED FROM 3710-12' W/ 4SPF. RIH AND SET CEMENT RETAINER AT 3666'. SQUEEZED THE PERFORATIONS FROM 3710-12' WITH 200 SXS OF CEMENT. RIH AND PERFORATED FROM 3530-32' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 3500'. SQUEEZED THE PERFORATIONS FROM 3530-32' WITH 200 SXS OF CEMENT. RIH AND PERFORATED FROM 3466-68' W/ 4SPF. RIH AND SET A CEMENT RETAINER AT 3435'. ESTABLISHED CIRCULATION THROUGH THE PERFORATIONS AT 3466-68' AND OUT THE 9- 5/8" x 13-3/8" ANNULUS. PUMPED 300 SXS OF CEMENT WHILE TAKING RETURNS OUT THE 9-5/8" x 13-3/8" ANNULUS DRILLED CEMENT AND RETAINERS FROM 3432' - 3735'. RETAINERS AT 3435', 3500', AND 3666'. POOH FOR BIT CHANGE. DRILLED CEMENT AND RETAINERS FROM 3735' - 4090'. RETAINERS AT 3750' AND 3820'. TRIP FOR BIT. DRILLED CEMENT AND DATE BAKER #18 WORKOVER JOB HISTORY ETD COMMENTS 03/11/92 5682' 03/12/92 5682' 03/13/92 5682' 03/14/92 5682' .Oil ,& Cons. ~nchorag~ 03/15/92 5682' RETAINERS FROM 4090' -4150'. RETAINERS AT 4090' AND 4150'. CHASED RETAINER FROM 4150' -4200'. POOH. CONT'D POOH. RIH WITH A BIT AND 9-5/8" CASING SCRAPER TO 5682'. CHANGED HOLE TO CLEAN NaC1/3% KCl BRINE. POOH. MADE AN 8.5" GAUGE RING RUN TO 4958'. RIH AND SET A BAKER MODEL "F-I" PACKER AT 4753'. RIH AND WIRELINE PERFORATED THE FOLLOWING ZONES. "35" 4089-94', "34" 4013-41', "32" 3720-61', AND "31" 3494-3502' WITH 4SPF. RIH WITH AN 8.5" GAUGE RING AND JUNK BASKET TO 4300'. RIH WITH TCP GUNS , 2-7/8" TBG, BLAST JOINTS AND AN OTIS HYDRAULIC SET PACKER. HYDROTESTED THE COMPLETION TO 4000 PSI. STABBED INTO THE 9-5/8" BAKER PACKER AT 4735' AND SET THE OTIS PACKER AT 3954', LEAVING THE GUNS ACROSS THE "40 SAND" FROM 4865'-4883'. RIH HYDROTESTING 2-7/8" TUBING BLAST JOINTS AND SET OTIS HYDRAULIC SET PACKER AT 3954'. CHANGED THE RAMS TO 2-7/8" AND TESTED TO 5000 PSI. RIH WITH 2-7/8" TUBING BLAST JOINTS A BAKER SBA-3 PACKER WHILE HYDROTESTING TO 4000 PSI. LANDED THE COMPLETION. TESTED THE TUBING HANGER TO 3000 PSI, OK. INSTALLED BPV AND REMOVED THE BOPE. CONT'D REMOVING BOPE. INSTALLED 3" 5M CIW SINGLE TREE AND TESTED THE HANGER TO 5000 PSI, OK. TESTED THE TREE TO 5000 PSI. RIH AND SET AN X PLUG IN THE XA SLEEVE AT 3485'. PRESSURED UP ON THE TUBING AND SET THE BAKER SAB-3 PACKER AT 3440'. TESTED THE 9-5/8" ANNULUS TO 2500 PSI, OK. OPENED THE XA SLIDING SLEEVE AT 3407' AND CHANGED THE ANNULUS OVER TO INHIBITED FLUID. DISPLACED THE TUBING VOLUME TO 2070' THROUGH THE SLEEVE AT 3407' WITH 850 PSI OF NITROGEN. RIH AND CLOSED THE "XA" SLEEVE AT 3407'. DROPPED BAR AND FIRED THE GUNS FROM 4883-65' WITH 4SPF. FLOWED WELL TO PRODUCTION. ON AN 8/64" CHOKE WITH 1730 PSI TBG PRESSURE AT 750 MCFD. RELEASED RIG AT 1200 HRS. BAKER WELL NO. 18 LEG 1, SLOT 3 ADL 1 7595 SPUD 1/01/77 COMPLETION RECORD 2-7/8" ,6.4# N-80 TBG 1. OTIS SSSV 312' 2. OTIS XA SLEEVE 3408' 3. BAKER SAB-3 PKR 3453' 4. OTIS XA SLEEVE 3486' 5. OTIS "BWH" PKR 3669' 6. OTIS XA SLEEVE 3703 7. OTIS "BWH" PKR 3967' 8. OTIS XA SLEEVE 4002' 9. BAKER "F" PKR 4757' 10. OTIS "XN" PROFILE 2.25" 4790' 11. BAKER 5" PERF GUNS TOO (TEMP) 4400' 9 5/8" 40 & 43. 5# S-95 @ 5983' CEMENTED WITH 600 SXS POSSIBLE COLLAPSE 6664' MAX INCLINATION 48.9 DEG 7" 29#, 8-95 F/571 O' - 10,107' CEMENTED WITH 295 SXS PBD 10,01 O' TD 10,231' 20" CASING AT 621' CEMENTED W/1400 SXS 13-3/8" 61 & 68#, K-55 @ 3500' CEMENTED WITH 1800 SXS 3466-3468 SQZ'D "31" SAND 3494-3502 OPEN 3530-3532 SQZ'D 3710-3712 SQZ'D "32" SAND 3720-3761 OPEN 3790-3792 SQZ'D 3990-3992 SQZ'D "34" SAND 4013-4041 OPEN "35" SAND 4089-4094 OPEN 4118-4120 SQZ'D 4128-4130 SQZ'D "40" SAND 4865-4883 OPEN 7" LINER TOP 571 O' BROWN MC HYD HANGER 7" 29# x 9-5/8" 43.5# 6' EXTENSION (ID = 7.5") BAKER MODEL 'F' PACKER AT 6500' B-1: 6680' - 6705' B-2: 6790' - 6838' B-3: 6886' - 6952' 0-1: 7162' - 7212' 6-2: 7255' - 7284' 6-3: 7343' - 7380' 0-4:7416' - 7445' DRILLABLE BP @ 7635' SAND ON TOP OF BP DRILLABLE BP @ 7680' (LEAKS) R CEIVED FILL AT 8856' APR G-2:9912'-9920' Alaska Oil & Gas CONS, (;ornm, issio~ nchorage SEE PERF DETAIL FOR EXACT INTERVALS' GRB 4/7/92 STATE OF ALASKA ALASK~ iL AND GAS CONSERVATION CC..,~;.vllSSlON ^PPLIC^ ION FOR SUNDRY APPROVALS 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247, Anchorage, AK 99519-6247 1. Type of'request: Abandon __ Suspend __ Operations shutdown M Re-enter suspended well__ Alter casingM Repair well __ Plugging __ Time extension ~ Stimulate ~ Change approved program X Variance Perforate Other Type of Well: 6. Datum elevation (DF or KB) Pull tubing Development X Exploratory Stratig raphic Service 79.4 7. Unit or Property name MIDDLE GROUND SHOAL 8. Well number 18 9. Permit number 76 -75 10. APl number 50 -733 -20296 feet 4. Location of well at surface 1937' FNL, 539' FWL, SEC 31, 'I-gN, R12W, SM At top of productive interval 6680' 1100' FSL, 826' FWL, SEC 30, T9N, R12W, SM At effective depth 7635' 1754' FSL, 1006' FWL, SEC 30, T9N, R12W, SM At total depth 10,231' 3353' FSL, 1697' FWL, SEC 30, T9N, R12W, SM feet Plugs (measured) feet 11. Field/Pool MIDDLE GROUND SHOAL 12. Present well condition summary Total depth: measured 10,231' true vertical 8,223' Effective depth: measured 7635 feet Junk (measured) true vertical 6304 feet DRILLABLE B.P. @ 7635' DRILLABLE B.P. @ 7680' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 584' 20" 1400 SXS 621' 621' Surface 3464' 13-3/8" Intermediate 1800 SXS 3500' 3296' Production 5949' 9-5/8" 600 SXS 5983' 5139' Liner 4397' 7" 295 SXS 5710' - 10,107' ,.~126' Perforation depth: measured REcEIV~[, true vertical SEE A'I-I'ACHMENT 1 FEB 2 6 1992 Tubing (size, grade, and measured depth) 3-1/2", N-80, 6515' Alaska 0il & Gas Cons, Commiss~O~ Packers and SSSV (type and measured depth) BAKER MODEL "F" PACKER AT6500' Anchorage 13. Attachments Description summary of proposal __ Detailed operations programX BOP sketch X ORIGINAL Approved by the order of the Commission LONNI5 c ~'~-:.': Commissioner Form 10-403 Rev 06/15/88 14. Estimated date for commencing operation 5. Status of well classification as: FEBRUARY 27, 1992 16. If proposal was verbally approved Oil __ Gas Name of approver Date approved Service INJECTOR 17. I hereby certify that the~/~going~,c~u~ and correct to the best of my knowledge. S~i°n~ee; Gar SBus'/'///~'''-''~/'//'''~- ,,v'? T.tle Re.ona'Drlhn 'a 'g y . 17' ,~/~r~f,,,..~ ~ · g' ~ i'g M nager I~ ' /'/~' ,,,~/' FOR COMMISSION USE ONLY Conditions of approval: Notify Coda'miss~n,)so representative may witness I Approval No. Plug Integrity _ BOP Test_ Location clearance __ ,~ _~. ~,:,,~1~, /'"~::~'~' -- ~;' Mechanical Integrity Test Subsequent form required 10- Date ~/o~/c] ~ SUBMIT IN TRIPLICATE i · · BAKER WELL # 18 PROCEDURE MIDDLE GROUND SHOAL MOVE RIG OVER MGS 17595 #18, LEG#l, SLOT#3 KILL THE WELL WITH COMPLETION BRINE. 3. INSTALL BPV, REMOVE TREE. 4. INSTALL AND TEST THE BOPE TO 5000 PSI 5. PULL AND LAY DOWN THE SINGLE STRING COMPLETION. 6. RUN A CEMENT BOND LOG FROM 5700' TO SURFACE. · RIH WITH A CEMENT RETAINER AND SET AT 6490'. ABANDON THE B, C AND G ZONES. (A RESTRICTION HAS BEEN TAGGED WITH WIRELINE AT 6664' INDICATING A CASING COLLAPSE.) PUMP 220 CU FT OF CEMENT THROUGH THE RETAINER. THIS IS ENOUGH VOLUME TO FILL THE 7" CASING TO 7545', 100' BELOW THE LOWEST PERFORATION IN THE C-4 ZONE. 9. PERFORATE FROM 4155' - 4157'. 10. RIH WITH A CEMENT RETAINER AND SET AT 4150'. 11. ESTABLISH CIRCULATION AND PREFLUSH THE ANNULUS OUTSIDE THE 9-5/8" CASING. 12. PERFORM A SECONDARY CEMENT JOB FROM 4180' TO SURFACE. 13. RUN A CEMENT BOND LOG FROM 4100' TO SURFACE. 14. RIH WITH AN 8-1/2" BIT AND CLEAN OUT TO TH 7" LINER TOP AT 7510' 15. PERFORATE 3450' - 3507' 3718' - 3758' 4014' - 4040' 4088' - 4096' 4866' - 4884' "31" SAND "32 - 1" SAND "34" SAND "35" SAND "40" SAND 16. KILL THE WELL WITH CLEAN, LOW CALCIUM BRINE CONTAINING 3% KCl. 17. RUN A SINGLE STRING 2-7/8" COMPLETION WITH FOUR HYDRAULIC SET PACKERS. 18. REMOVE THE BOPE. INSTALL THE TREE. 19. KICK THE WELL OFF USING NITROGEN AND A SLIDING SLEEVE. 20. RELEASE THE WELL TO PRODUCTION. RECEIVED F~ B 2 6 199?- Alaska Oil & Gas Cons, Anchorage BAKER WELL #18 ADL 17595 PERFORATION RECORD MEASURED DEPTH TRUE VERTICAL DEPTH DEPTH STATUS B- 1:6680-6682 5636-5638 OPEN 6685-6705 5641 - 5655 OPEN B-2:6790-6792 5713-5715 OPEN 6796-6838 5719-5746 OPEN B-3:6886-6944 5783-5824 OPEN 6948- 6952 5825- 5829 OPEN C- 1:7162-7165 5907-5981 OPEN 7170- 7212 5983-6013 OPEN C-2:7255-7284 6041-6064 OPEN C-3:7343-7380 6105-6129 OPEN C-4:7416-7437 6156-6128 OPEN 7441 - 7445 6172-6176 OPEN G- 1:8749-8751 7088-7091 ISOLATED 8934-- 8936 7227-- 7229 ISOLATED 9125- 9135 7370- 7377 ISOLATED 91 48- 9153 7385- 7390 ISOLATED 91 62- 9172 7397- 7404 ISOLATED 9212-- 9217 7435- 7437 ISOLATED 9222- 9232 7442- 7450 ISOLATED 9246-- 9256 7459-- 7469 ISOLATED 9310-- 9334 7509-- 7528 ISOLATED 9354-- 9362 7543-- 7549 ISOLATED 9382-- 9404 7564-- 7582 ISOLATED 9452- 9466 7618- 7628 ISOLATED 9476- 9494 7635- 7650 ISOLATED 9610 - 9620 7739 - 7747 ISOLATED 9632- 9652 7756- 7772 ISOLATED 9660-- 9670 7778-- 7785 ISOLATED 9742- 9908 7841 - 7970 ISOLATED G-2:9912-9920 7974-7979 ISOLATED RECEIVED FEB 2 6 1992 AJaska 0il & Gas Cons. Commissio~ Anchorage BAKER WELL NO. 18 ADL 17595 LEG 1, SLOT 3 CURRENT SPUD 1/Ol/77 20" CASING AT 621' CEMENTED W/1400 SXS 13-3/8" 61 & 68#, K-55 @ 3500' CEMENTED WITH 1800 SXS COMPLETION RECORD 1. SINGLE 1 O" OCT STAINLESS HNGR @ 32' 2. 3-1/2' BU'I-rRESS PUP 3. 3-1/2' N-80 TBG W/BUI-I'-ABC CPL @ 6511' 4. 3-1/2. BUI-I' PUP 6515' 5. BAKER SEAL ASSEMBLY AT 6530' TOC (I'EMP) 4400' 9 5/8" 40 & 43.5# S-95 @ 5983' CEMENTED WITH 600 SXS POSSIBLE COLLAPSE AT 6664' MAX INCLINATION 48.9 DEG 7" 29#, S-95 F/571 O' - 1 O, 107' CEMENTED WITH 295 SXS PBD 10,01 O' TD 10,231' 7" UNER TOP 571 O' BROWN MC HYD HANGER 7" 29# x 9-5/8" 43.5# 6' EXTENSION (ID = 7.5") BAKER MODEL 'F' PACKER AT 6500' B-1: 6680' - 6705' B-2: 6790' - 6838' B-3: 6886' - 6952' C-1: 7162' - 7212' C-2: 7255' C-3: 7343' C-4: 7416' DRILLABLE BP @ 7635' SAND ON TOP OF BP DRILLABLE BP @ 7680' (LEAKS) G-1: 8749' - 9908' RECEIVED F7 - 7284' B 2 G1992 -7380' AJaska 0ii & Gas Cons, Cornm~ss~O~ - 7445' Anchorage FILL AT 8856' G-2:9912' - 9920' SEE PERF DETAIL FOR EXACT INTERVALS GRB 1/7/92 BAKER WELL NO. 18 ADL LEG 1, SLOT :3 PROPOSED 17595 SPUD 1/01/77 2(7 CASING AT 621' CEMENTED W/1400 SXS 13-3/8' 61 & 68#, K-55 @ 350(7 CEMENTED WITH 1800 SXS 31 SAND: 3450' - 3507' 32-1 SAND: 3718' - 3758' 34 SAND: 4014' -4040' 35 SAND: 4088' - 40g~ TOC (TEMP) 4400' 9 5/8' 40 & 43.5~ S-95 @ 5983' CEMENTED WITH 6OO SX$ POSSIBLE COLLAPSE AT 6664' MAX INCMNATION 48.g DEG 7, 29~, S-95 F/571(Y - 10,107' CEMENTED WITH 295 SX$ PBD 10,010' TD 10,231' L 40 SAND: 4866' - 4884' 7, LINER TOP 571 O' BROWN MC HYD HANGER 7' 2g~ x 9-5/8" 43.5~ 6' EXTENSION (ID = 7.5) BAKER MODEL 'F' PACKER AT 65(X)' B-l: 6680' - 6705' B-~- 6790' - 6838' B-3: 6886' - 695Z C-1: 7162' - 7212' C-2: 7255' - 7284' C-3: 7343' - 7380' C-4: 7416' - 7445' DR~.LABLE BP @ 7635' SAND ON TOP OF BP DRELABI F BP @ 768~ (LEAKSJ~ FILL AT 88.58' ,: Anchorag~ G-2: 9912' - 992O' SEE PERF DETAIL FOR EXACT INTERVALS GRB 1/20/92 PLATFORM BA. KER DRILLING STACK III PITCHER NIPPLE- 16' ID W/lO' FLOWLINE ANNULAR BOP 'NL SHAFFER° 13 5/8' 5000' PS! BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP 'NL $HAFFIER°' 13 5/8' 5000 PSI BX-160. A88Y WT, 16,500 LBS. MUD CROSS- 13 5/8' BORE'- WI4' 5000 PS! VALVES SGL,. GATE BOP 'NL SHAFFER'" 13 5/8' 5000 PSI BX-160 AShY WT. 9100 LBS. -RISER- 18°OD. 13 5/8' 5000 FL~..-. FEB '2 5 t99~ Alaska Oil & Gas Cons, Ancborag~ LOWER' RISER: 11' ID ........... W/lO' 5000 PSI FLG.(RX-54) ' STATE OF ALASKA AND GAS CONSERVATION APPLIC, ATION FOR SUNDRY APPR 1. Type of request: Abandon _~\~':~ Suspend __ Operations shutdown __ Re-enter suspended well__ 2. Name of Union Oil 3. Address P.O. Box Operator Company of California (UNOCAL) 196247, Anchorage, AK 99519-6247 Alter casing__ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing__ Variance __ Perforate X_._ Other__ 5. Type of Well: 6. Datum elevation (DF or KB) 79.4 7. Unit or Property name MIDDLE GROUND SHOAL 8. Well number 18 9. Permit number 76 -75 10. APl number 50 -733 -20296 11. Field/Pool MIDDLE GROUND SHOAL 4. Location of well at surface 1937' FNL, 539' FWL, SEC 31, T9N, R12W, SM At top of productive interval 6680' 1100' FSL, 826' FWL, SEC 30, T9N, R12W, SM At effective depth 7635' 1754' FSL, 1006' FWL, SEC 30, T9N, R12W, SM At total depth 10,231' 3353' FSL, 1697' FWL, SEC 30, T9N, R12W, SM Development X Exploratory Stratig mphio feet 12. Present well condition summary Total depth: measured 10,231' true vertical 8,223' feet Plugs (measured) feet DRILLABLE B.P. @ 7635' DRILLABLE B.P. @ 7680' Effective depth: measured 7635 feet Junk (measured) true vertical 6304 feet Casing Length Size Cemented Structural Conductor 584' 20" 1400 SXS Surface 3464' 13-3/8" 1800 SXS Intermediate Production 5949' 9-5/8" 600 SXS Liner 4397' 7" 295 SXS Perforation depth: measured Measured depth True vertical depth _ e.r 4~3~ _ , 621 ~;,~';-,.,( ~l~ ~ ;~ ~1' , ~ ~ ~ ( ~%~( ' , 3~0 ~ ~~ 3~6 5~3' ~ ~ ' 5139' 5710' - 10,107' 8126' RECEIVED true vertical SEE A'FI'ACHMENT 1 Tubing (size, grade, and measured depth) 3-1/2", N-80, 6515' Packers and SSSV (type and measured depth) BAKER MODEL"F" PACKER AT6500' JAN 2 ? t997. Alaska 0il & Gas Cons. bummiss'to~ Anchorage 13. Attachments Description summary of proposal __ Detailed operations programX__ BOP sketch X 14. Estimated date for commencing operation FEBRUARY 10, 1992 16. If proposal was verbally approved Name of approver Date approved 5. Status of well classification as: Oil Gas Service INJECTOR Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Gary S. B ush~,~,.~ ~_~. (~,,.~,. Title Regional Drilling Manager (~ .d~ FOR COMMISSION USE ONLY Conditions of approval: NOtify C-~mmission so representative may witness Plug Integrity _ BOP Test Location clearance Mechanical Integrity Test.)[ Subsequent form required 10- q0~ Date I -z{ -~z_ IApproval No. Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Commissioner Date /.o 3- SUBMIT IN TRIPLICATE B-l: B-2: B-3: C-1: C-2: C-3: C-4: G-l: G-2: MEASURED DEPTH DEPTH 668O-6682 6685-6705 6790-6792 6796-6838 6886-6944 6948-6952 7162-7165 7170- 7212 7255- 7284 7343-7380 7416-7437 7441-7445 8749-8751 8934-8936 9125-9135 9148-9153 9162-9172 9212- 9217 9222-9232 9246-9256 9310-9334 9354-9362 9362-9404 9452-9466 9476-9494 9610- 9620 9632- 9652 9660-9670 9742-9908 9912-9920 BAKER WELL #18 ADL 17595 PERFORATION RECORD TRUE VERTICAL DEPTH 5636-5638 5641-5655 5713-5715 5719-5746 5763-5824 5825-5829 5907-5981 5983-6013 6041-6064 6105-6129 6156-6128 6172-6176 7088-7091 7227- 7229 7370-7377 7385- 7390 7397-7404 7435-7437 7442-7450 7459-7469 7509-7528 7543-7549 7564-7582 7618-7628 7635-7650 7739-7747 7756-7772 7778-7785 7841-7970 7974-7979 STATUS OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED RECEIVED JAN 2 ? ~992 Alaska Oil & Gas Cons. Commission Anchorage BAKER WELL # 18 PROCEDURE MIDDLE GROUND SHOAL 1. STOP INJECTION ONE MONTH BEFORE MOVING ON THE WELL. MONITOR PRESSURES AND FLUID LEVELS. 1. MOVE RIG OVER MGS 17595 #18, LEG#l, SLOT#3 2. KILL THE WELL WITH COMPLETION BRINE. 3. INSTALL BPV, REMOVE TREE. 4. INSTALL AND TEST THE BOPE TO 5000 PSI 5. PULL AND LAY DOWN THE SINGLE STRING COMPLETION. 6. RIG UP ELECTRIC LINE AND PERFORATE FROM 4180'-4190' WITH BIG HOLE CHARGES. 7. RIH WITH A DRILLABLE BRIDGE PLUG AND SET AT 4150'. · ESTABLISH CIRCULATION PREFLUSH THE ANNULUS OUTSIDE THE 9-5/8" CASING. 9. PERFORM A SECONDARY CEMENT JOB FROM 4180' TO 1000'. 10. RUN A CEMENT BOND LOG FROM 4150' TO SURFACE. 11. RUN A THERMAL DECAY LOG FROM 6000' TO 1500'. 12. PERFORATE 3450' - 3507' 3718' - 3758' 4014' - 4040' 4088' - 4096' 14A-14B SAND 14C-15 SAND 16 -17 SAND l! t! 13. KILL THE WELL WITH CLEAN, LOW CALCIUM BRINE CONTAINING 3% KCl. 14. RUN A SINGLE STRING 2-7/8" COMPLETION WITH THREE HYDRAULIC SET PACKERS. 15. REMOVE THE BOPE. INSTALL THE TREE. 16. KICK THE WELL OFF USING NITROGEN AND A SLIDING SLEEVE. 17. RELEASE THE WELL TO PRODUCTION. TIME: 13 DAYS RECEIVED JAN 2 ? 1992 Alaska Oil & (Jas Cons. ~ummissio,; Anchorage BAKER WELL NO. 18 ADL 17595 LEG 1, SLOT 3 CURRENT SPUD 1/ol/77 2(7 CASING AT 621' CEMENTED W/1400 SXS 13-3/8" 61 & 68#, K-55 @ 3500' CEMENTED WITH 1800 SXS TOC (TEMP) 4400' 9 5/8" 40 & 43.5# S-95 ~ 5983' CEMENTED WITH 600 SXS COMPLETION RECORD 1. SINGLE 1 (7 OCT STAINLESS HNGR ~ 32' 2, 3-1/2" BUTTRESS PUP 3. 3-1/2" N-80 'I'BG W/BUTT-ABC CPL @ 6511' 4. 3-1/2" BUTT PUP 6515' 5. BAKER SEAL ASSEMBLY AT 6530' RECEIVED JAN 2 7' t992 Alaska Oil & Gas Cons. l~ummtssion Anchorage 7" UNER TOP 571 O' BROWN MC HYD HANGER 7" 29# x 9-5/8" 43.5# 6' EXTENSION (ID = 7.5") BAKER MODEL 'F' PACKER AT 6500' MAX INCLINATION 48.9 DEG 7" 29#, 8-95 F/571 O' - 10,107' CEMENTED WITH 295 SXS PBD 10,01 O' TD I 0,231' B-1: 6680' - 6705' B-2: 6790' - 6838' B-3: 6886' - 6952' C-1: 7162' - 7212' C-2: 7255' - 7284' C-3: 7343' - 7380' C-4:7416' - 7445' DRlU_ABLE BP ~ 7635' SAND ON TOP OF BP DRILl_ABLE BP @ 7680' (LEAKS) G-1: 8749' - 9908' FILL AT 8856' G-2:991 2' - 9920' SEE PERF DETAIL FOR EXACT INTERVALS GRB 1/7/92 BAKER WELL NO. 18 ADL 17595 LEG 1, SLOT 3 PROPOSED SPUD 1/Ol/77 20" CASING AT 621' CEMENTED W/1400 SXS 13-3/8" 61 & 68#, K-55 @ 3500' CEMENTED WITH 1800 SXS 14A-14B: 3450' - 3507' 14C-15 · 3718' - 3758' TOC (TEMP) 4400' 9 5/8" 40 & 43.5# S-95 @ 5983' CEMENTED WITH 600 SXS 1 § - 17 · 4014' - 4040' 4088' - 4096' RECEIVED JAN 2 ? ~992 Alaska Oil & Gas Cons. burnmissio~ 7- ENER TOP 571 O' BROWN MC HYD HANGER Anchorage 7' 29# x g-5/8" 43.5# 6' EXTENSION (ID = 7.5") BAKER MODEL 'F' PACKER AT 6500' MAX INCLINATION 48.9 DEG 7- 29#, 8-95 F/571 O' - 10,107' CEMENTED WITH 295 SXS PBD 10,01 O' TD 10,231' B-1: 6680' - §705' B-2: 6790' - 6838' B-3: 6886' - 6952' C-1: 7162' - 7212' C-2: 7255' - 7284' C-3: 7343' - 7380' C-4:7416' - 7445; DRILLABLE BP @ 7635' SAND ON TOP OF BP DRILl_ABLE BP @ 7680' (LEAKS) G-1: 8749' - 9908' FILL AT 8856' G-2:9912' - 9920' SEE PERF DETAIL FOR EXACT INTERVALS GRB 1/20/92 PLATFORM BAKER .DRILLING : STACK RECEIVED JAN 2 7 t992 Alaska 0il & Gas Cons. (.;ommissJon Anchorage PITCHER NIPPLE- 16' ID W/10" FLOWLINE ANNULAR BOP 'NL SHAFFER' 13 5/8' 5000' PS! BX-160 ASSY WT, 13,650 LBS. DBL GATE BOP "NL SHAFFER'' 13 5~8' 5000 PSI BX-160. ASSY WT. 16,500 LBS. MUD CROSS- 13 5/8' BORE: WI4' 5000 PSI VALVES SGL,. GATE BOP 'NL SHAFFER' 13 5'/8' 5000 PSI BX-160 ASS¥ WT.' 9100 LBS. . - RISER' 18'OD 13 5~8' 5000 LOWER RISER' 11"ID ' Wi10' 5000 PSI FLG..(RX-54)' STATE OF ALASKA ~,~.,S KA OIL ANd GAS CONSERVATION CON SION 'L"~ APPLfCATION FOR SUNDRY APPROV/ Type of Reques[. Abanao¢, ~ Susc~end ~ OIDerat,on shutdown ~ Re.enler suspended ,,,ceil __ Alter cas, rig __ Reca,r ~t __ Plugging __ T~me e~ens,on __ Sbmulate __ Charge aporo~d pr~ram __ Pull tu~ ~ Vana~e __ Pedorate ~ ~her ~ 2. Name of Operator Union Oil Com~ of California (UNOCAL) 3. Address PO Box 196247, Anchorage, AK 99519-6247 i 5. Type ot Well. Oe,cCopment Exp~oca~or¥ StratigraDhlC Serwce ,, , _ 4. l_c~at~on of well a~ surfaC[eg #1, Cond. #3, Platform Baker 1937' FNL, 539' FWL, Sec. 31, T9N, R12W, SM At top of producbve interval 2442' FNL, 1509' FWL, Sec. 30, T9N, R12W, SM At effecbve depth At total depth 1924' FNL, 1697' FWL, Sec. 30, T9N, R12W, SM ,, 6. Datum elevation (DF or KB) 79' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number ADL-17595, Well Ba-18 ,, 9. Permit number 7~'-7,5 , '10. APl number 50--133-20296 il. 'Field/P~i ...... Middle Ground Shoal 12. Present well condition summary Total depm: measured 10,107' true vemcal 8,125' feet 'feet Plugs (measured) Effective depth: measured 7,635' feet true vemcaJ feet Junk (measured) Cas4ng Length ~ Size Cemented Structural Conductor 621' 20" 1,400 sx Surface 3,500' 13 3/8" 1,800 sx Intermediate Producbon 5,983' 9 5/8" 600 SX Liner 4,397' 7" 1,120 SX Perforabon depth: measured SEE ATTACHED true verbcal Tubing (.~ze. grade, and measured depm)3 1/2" N-80 @ 6,530' Packers and SSSV (type and measured depth) Baker Model "F" @ 6,500' 7635', 7660' Measured depth 621' 3,500' 5,983' 5,710'-10,107' True vertical depth 620' 3,296' 5,136' 4,921 '-8,125 RECEIVED DEC - 2 t991 Alaska Oil & Gas Cons. Comm'tss[eft Anchorage 13. Attac.~ments Oescrption summary of proc, Dsal __ Deta~lecl operations program __ BOP sketc~ .._ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Se~ce 1Z I hereby cerafy that the foregoing is true ancl correct to me best of my knowledge. Signed.Gary S. Bush, .~~ ,,~, ~ ,_,~, Title Re,qion.al D.rill!p,q Manager FOR COMMISSION' USE ONLY Conditions' of approval: No'~ Commiss~°n so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechar. caJ Integnty Test __ Subsequent form required 10- ,,, ~..~.- Approved by order o~ the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY I n~.,,r- n r',BIIITI,i, LUi't, II'~il.. ~.~, ~,Jt¥1! I II , Date ' j App,ov-- ,,No, ~ ~C"ommissioner SUBMIT IN TRIPLICATE Platform Baker ADL 18595 Middle Ground Shoal Field Well Ba- 18 Existing open perforations: BENCH MD B-1 6680- 6682 6685-6705 B-2 6790- 6792 6796-6838 B-3 6886-6944 6948-6952 C~1 7170-7212 C-2 7255-7284 C-3 7343-7380 C-4 7416-7437 TVD 5634-5636 5638-5651 5711- 5713 5715-5745 5780-5821 5824-6011 5981-6011 6041 - 6061 6102 - 6128 6153 - 61 67 RECEIVED DEC - 2 t991 Alas~ Oil & Gas Cons. 6ommJssio~ Anchorage Middle Ground Shoal ADL 17595 Platform Baker Well Ba-18 Perforating procedure: 1. Pull Kobe pump and standing valve. 2. RU slick line, run gauge and tag bottom. 3. RU electric line unit. 4. Pressure test lubricator to 2500 psi for five minutes. 5. Shut down all welding and radio transmissions. 6. RIH and perforate intervals as instructed by Unocal representative. (When gun is 200' below surface, welding and radio transmissions may resume.) 7. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 8. Repeat steps 5,6 and 7 as needed to perforate the following: BENCH MEASURED TVD TOTAL B1 6770 - 6850 5697 - 5754 80 B2 6885 - 6965 5779 - 5836 80 C1-1&2 7160 - 7230 5974 - 6023 70 C1-3 7260 - 7315 6044 - 6083 55 C1-4 7335 - 7380 6097 - 6128 45 C1-4 7390 - 7400 6135 - 6142 10 C2 7420 - 7435 6156 - 6166 15 C2 7445 - 7450 6173 - 6176 5 FT. (MD) 360 RECEIVED DEC - Alaska .Oil & Gas Cons. OommissiO~ Anchorage 1. Operations pedormed: STATE OF ALASKA AL~KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL Operation shutdown __ Stimulate .~L Plugging Pulp tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: Amoco Product-ion Company I Development__ Exploratory __ 3, Address Stratigraphic_ P.O. Box 800, Rm. 1846, Denver, CO 802 1 ServiceX' 31-T9N-R12W 30-T9N-R12W 4. Location of well at surface 1937' FNL x 539' FWL, Sec. At top of productive interval 2442' FNL x 1509' FWL, Sec. At effective depth Perforate __ Other __ 6. Datum elevation (DF or KB) 79.4' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number 18 9. Permit number/approval number 76-75 / ~,_ ~__ 10. APl number 50-- 733-20296 11. Field/Pool Middle Ground Shoal At total depth 1924' FNL x 1697' FWL, Sec. 30-T9N-R12W 12. Present well condition summary Total depth: measured true vert~]- Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 10231 feet Plugs (measured) 8223 feet 10 2 31 feet Junk (measured) 7 6 3 5 feet (Hemlock) Size Cemented Measured depth True vertical depth See Attached 6138-6150' 6210-6260' 6305-6330' 6352-6370' Wellbore Diagram 6416-6440' 6462-6476' 6560-6610' 6690-6710' 3-1/2" N-80 6511' 6500' Baker Model "F" packer Tubing (size, grade, and measured depth) 6740-6800' 6830-6882' 7030-7084' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Stimulation Intervals treated (measured) 6680-7437 ' Alaska 0il & Gas Cons. Treatment description including volumes used and final pressure HCL 15% - 3780 gal, Polymer Citric Ac-id - 76 lbs, Rock Salt - 500 lbs~ f-inal pressure 3750 PST Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 259 1205 2937 WG17 - 15 lbs. 14. 0 0 1068 797 2745 ...~_Su hse~operation 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WIW d Surveys run Daily Report of Well Operations Date 6/14/89 SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed...~.rr~-~~.~"~~~Z./_ ~ Title Sr. Admin. Supv. Form 10-~i4' e~v06/15/8~--' '~--~".~. Ham~ Pea'rotations: 8-1: 8880--~882' G..-1: 874g-8751' 8685--6705' 8934---8938'e* B-2: 879Q-879Z' 9125--9135' 6796-8838' 91 ~-9153' B-3: 8886-89~' 9182-917~' 69~-~952' 9212-921 C-1; 7182-7185'. 9222-92~2* 7170--7~12' C-2: 7~5-7~8~' 9310--9334' C-3: 73~3-73a0' 935~9362' C-4:7~16-7~ 9382-9~4' 7~1-7~5'* 9~2-9468' 1006 BWPt3 None None GROUND SHOAL 759,5 WE.L, NO. 18 P~AITORU ~J<~---~ Comole~on Record 4. 3 1/2" guttmaa 5. Bakm' Seal A~aem~ly anct Iocotor shoe (:.~ mn 1 0-1: 9478--9494' g610--96?.0' 963:Z--9852' 9880--9670' 97~2-9908' ~ g912--g920' not hailing ~hen O zone an H~illbut+~n Odlloble Bridge i=lug ~t ~t 763.5' X~n O~lable BHdge Plug ~t ~ 7660' - fe~ed ~ ~ ~ ~ s~te ~unt~ a~ 8856' 1~7 -- not ~.on~ out 13 ?./~", lg ~", ~ ~ ~ g~k~ Model ~e680, . ~ ss3s' ~ 71 e=-7~ ~7170-~t 2' ~4~7~80' 7~1-7~ 874g-8791 · ~ ggos' 10010' ~ 9912-99~' 1010~ = ~ ' PMd Treatment (LIM ~ ~e~'d} grllkd~wfl O,D, Tubing I,~, fluH P.3 5 · AQId Ih'ia 7 · Anld 4 Trgg1~tnt I:.~l~pl~M~tl Ind/Ot Addltlv. ILl. ~5 Rl~l'~) , :.: l 4 AOI~ ~ ~ale t~h~bltot or T~lr ~ttr~l P.Z Amoco Produc~,ton Company DRODB Comp!~tlon or Repair Report Denver Region ~,g/f'Z'/~' ....... In~Ul of mat I. Ine .: = ,.::..:~ ......... J, Other I ..'~ I _ ~ ,.., , ......... ~..~:.::::,, /,, /,, ...,_ ~ Horl~ofl J~b Rwi~lt) (Lln~ 91 R~'d) ~ ............... I,t J~ I ~ - ~,, ~r~ ' ,~.,, ........... j.~~. I, ,,,l, ... I,.... ................. : ....... -~, Oil Wirer Hr, ~fab, F"tP P BHP ~ 1,0 I~,, - I~= ..... 11~ J I _I,, ...... .Itt, * .., J,..,: l,, ..-- ............ ' '~: .... I Houri MJn,I [ Houri ~ln, I Pdrr~P ~~r ~rcP P,4 3 · '.::'?_. ., · , DEC 14 '88 22:54 , ANCHORAGE DISTRICT Acid Stimulation OU~'llty Control ' Checkl t st ~u~ /~ ' / /' "' Unless othe~tse Indicated, all 1terns are to be suppl~ed by service company represen[attve on location, These date should be measured under supervision of Amoco pe~sonne]. A, ACl~ DESCRIPT. ION " , , X, Acid Type and Volume ./~.~z .... · .[ ........ . .............. , . Addltives and Loading. , 3, Acid Concentration ./~, Tu ne ae[erm~nea D~'nyurometer or t.itra[ton 5. Check pit, of returned flutd (Either circulated or. pumped ou~. 'To be completed by Amoco personnel tf pumped oub). ~ .Ii,me/_ D~t~. ,. 6. EDTA is to be filtered to ;I-5 microns before pumping,. ,'~, SERVICE COHPAN¥ COMMENTS ...... STATE OF ALASKA ~.- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate Change approved program ~ Pull tubing __ Variance ~ Perforate __ Other __ 2. Name of Operator ! 5. Type of Well: Amoco Production Company P. O. Box 800, Room 1831, Denver, CO 802 1 Development __ Exploratory __ Stratigraphic __ Service __X 4. Location of well at surface 1937' FNL 539' FWL Sec. 31, TgN, R12W At top of productive interval 2442' FNL 1509' FWL, Sec. 30, T9N, R12W At effective depth At total depth 1924' FNL 1697' FWL, Sec. 30, T9N, R12W 12. Present well condition summary Total depth: measured true vertical 10231 feet 8223 feet Plugs (measured) 6. Datum elevation (DF or KB) 79.4' KB 7. Unit or Property name Middle Ground Shoal 8. Well number 18 9. Permit number 76-75 10. APl number 50--733-20296 11. Field/Pool F_l_atl-orm Baker Middle Ground Shoal H~mluck - Pool Effective depth: measured 10231 true vertical 7635 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size See Attached measured feet Junk (measured) feet Cemented Wellbore Diagram Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation Upon approval 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service WIW 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Administrative Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORICII~!^~. S!GNED BY Approved by order of the Commission LONNIE C. SMITH &po"o,/ed Copy Returned -~.~"'/~'"-~"~om m i ssio n e r I Approval No. ~7~',,2, Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE I~IDDL~ GROUND SHOAL ADL 17595 ?/D,L. NO. 1 KENAI CC)NGLOME,RATE PLATFORM BAKET~ 621' Per~.nent Data.* Spud Date: Surface Subau~face L~¢ofJon: Elevation: PgO: Perforation,,: lni~al Potent, Iai: IniUal SfJmulaUom Reseevolr Cored Interval,: DST ln~ervala Log Inv~n~ry: l. ag 1. S10t: ;3. P~atform Boker ~ -- 1924' ~ 189~ ~ ~ 30: ~N. R12W. 7g.~' KB 10107 10010' 20" ~,lng se{ a~ 621' ~, 29~ s--g5 Un~ .e~ at 10107' " B--1:e880-~882' G--1: 8749-8751' 6685-$705' 8934--sg36'ee B-2: 6790-8792' 9125-g135' 6796-883~' 914.8-g 1,55' B-3: 6886-694.4' 9182-9172' ~94.8-6952' 9212-g217' C-1: 7162-71SS'e g222-9232' 7170--72.12' g?.~.8--92.56' C--2: 7255--72~4,' 9310--g334' C-3: 73~,3-7380' 9354--g362' C--4:7¢16-7.1,27' - 9382-9404' 744.1-7445'*, g452--g468' 10060'~1=0 None None OIL, Sonic, Density, Dlpmeter, C~L. _Com,leflon Eecord I. Slngle 10" OCT S~olnlee, hanger 2. 3 1/?." Butt~3s pup 3. 3 1~" N-SO Bu~. ~g ~C 5. Bak~ Seal ~semb~ and ~epf. h 8511' (A~ r~n 11/15/87~ (3--1: g476--g494' g610--967.0' 9632-g652' g880--g670' 974.2--9g08o G--2: gg12--9920' · Squeezed not holding when G zone was on Injection. Halltburf~n Drlllable Bridge Plug ~et et 7635° .Sand Halflbu~n D~lable Bddge Plug ~t at 7660' - fa~ed ~ t~ 1~7 -- nat ~ean~ out P~D 1 O01 O' 10 10107' 13 =v'~", 81-,lc ea~ csA 3500' 7" Une~ t~a ~.5~ c~ sma3' , E~oker Model 'F' Packer at 6500' 6680' 8705' 87g0' 6838' '~ 6886' 69,52' 7162-7185' 7170-7212' 7255-7284' 7343--7380' [17~18--743~ 7441-74~\ ~ $74g-8751 ' ggos' gg12-gg20* Workover Procedure' Middle Ground Shoal Well No. 18 Pleame perform tile following workover for the above mentioned well. Tile authorized gross cost of the workover is $20,000 and should be charged to well repair expense. Also, fill out tile attached Acid Stimulation Quality Control checklist and return it to Denver following the completion of tile procedure. The purpose of this procedure is to open all perforations and increase injection iuto tile well. The procedure is as follows: 1. Shut-in tile well 7 days prior to the workover and backflow. 2. Rig up tile service company and test tile equipment to 5000 psig. A 2-5 micron cotton filter is to be used to filter the acid before it is pumped down hole. 3. [Iix 3780 gallons (90 barrels) of 15% tlCl with 15 gallons corrision inhibitor and 76 pounds of citric acid. Test tile strength of tile acid by tritration. Circulate the tank thoroughly before pumping tile acid. Mix 1000 gallons (23.8 barrels) of filtered Cook Inlet water with 15 pounds of polymer gel to make 15~ pound gelled water. 4. Pump 420 gallons (10 barrels) of 15% HCl down the tubing. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 5. Pump 5 barrels of 15 pound gelled water with 21 pounds of rock salt per barrel added on the fly or 105 pounds of rock salt. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 6. Pump 630 gallons (15 barrels) of 15% ttCl down the tubing. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 7. Pump 5 barrels of 15 pound gelled water with 21 pounds of rock salt per barrel added on the fly or 105 pounds of rock salt. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 8. Pump 630 gallons (15 barrels) of 15% HC1 down the tubing. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 9. Pump 5 barrels of 15 pound gelled water with 21 pounds of rock salt per barrel added on the fly or 105 pounds of rock salt. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 10. Pump 1050 gallons (25 barrels) of 15% HC1 down the tubing. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 11. Pump 5 barL_.s of 15 pound gelled wate~_~,~ith 21 pounds of rock salt per barrel added on the fly or 105 pounds of rock salt. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 12. Pump 1050 gallons (25 barrels) of 15% tlC1 down the tubing. Do not exceed a rate of 4 BPM or a pressure of 5,000 psig. 13. Flush acid to the perfs with 95 barrels filtered Cook Inlet water. 14. Shut-in well for one hour to allow acid to spend. Monitor and record initial shut-in pressure and pressure every 15 minutes during the one hour s h u t -.,i n. 15. Attempt to back flow the well to recover 205 barrels of load. Back flow well for 24 hours, only if the well back flows a pencil stream amount of water or greater. If well does not back flow, leave the well shut-in for an additional one hour to allow the acid to fully spend before returning the well to inflection. 16. Return the well to water injection service at a maximum rate of 1000 BWPD or a pressure of 4,000 psig. J. D. Hamrick Division Production Manager May 3, 1988 Amoco Production Company Northern Division 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303-830-4040 C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: GLH-712-WF Well Recompletion Report and Log Middle Ground Shoal Well 18 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-407 to notify you of recompletion work recently completed on the above referenced well. If you have any questions please contact Bruce Frye or Mark Glover of this office. BAF:at STATE OF ALASKA U ~:" ~ '~; ;~ ALASKA ~ AND GAS CONSERVATION COk~:~IlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Re comp le t ion Water Injection OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE E~ 2. Name of Operator 7. Permit Number /ApProval # Amoco Production Company 76-75 7-825 3. Address 8. APl Number P.O. Box 100779 Anchorage, AL 99510 50-733-20296 , 4. Location of well at surface 9. Unit or Lease Name 1937' FNL 539' FWL Sec. 31, T9N, R12W Middle Ground Shoal At Top Producing Interval 10. Well Number 2442' FNL, 1509' FWL, Sec. 30, T9N, R12W 18 At Total Depth 11. Field and Pool 1924' FNL, 1697' FWL, 'Sec. 30, T9N, R12W Platform Baker 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Middle Ground Shoal 79.4' (KB)[ ADL 17595 Hemlock - Pool 1~. Date S~;~ recomF 13. JDate T.I~. Reached 14. Date Comp., Susp. ~)r Ab~cot~15. Water Depth, if offshore 116. No. of Completions began 11-2-87 or~_g~_nai 3-15-77 orig, 6-28-771/ 3-31-8~ feetMSL I 17.~]~ta~_ D~p(~t~ (~Ei+TV D)]~Plu!=~0~e~h (MD+TVD)19. Directional Survey L 20.~Depth where SSSV set 21. Thickness of Permafrost ' YES [] NO [] | 6500 feet MD N/A TVD = 8223' D= ~ac~er ~ 22. Type Electric or Other Logs Run Gamma Ray, CBL 23. CASING, LINER AND CEMENTING RECORD. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED No bhange from previous records 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval size and number) TVD~ 4'~ ~un at 4,.TSP~ SIZE DEPTH SET (MD) PACKER SET (MD) ' perf diam. .510" 6680 ' -6705 ' 3½"9.2¢~But t 65~D ' R 5DD ' 6790'-6792' 7343'-7380' 6796'-6838' 7416'-7437' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6886'-6944' 7441-7445' DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED 6948'-6952' 7195' ' 3 CMT.SQZ, w/CLASSG CMT, - 7162'-7165' Dispersent, + Friction Reducer .. . 7170',7212' 7255'-7284' . 27. PRODUCTION TEST Date First I~:~rt~rr~ Injection Method of Operation (Flowing, gas. lift, etc.) .. 85 DEL/Day ii/21/87, 50BBL/Day @,~2z000 Stabilized Injection Rate @ 4000 PSI Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OILRATIo 2/28/88 TEST PER~OD I~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing .Pressure CALCULATED Press. 24-HOUR RATE 281 CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . · . ~as~ 0il & Gas Cons. C0mmissi0~, A~chorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '30. GEOLOGIC MARKERS FORMATION TESTS -- NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ Title Manager Date 4/22/87 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).. Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 October 20, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton, Chairman File' FEW-132-WF Application for Sundry Approval MGS 17595 Well No. 18 Platform Baker, Cook Inlet, Alaska Attached in duplicate for your approval is a State Form 10-403, Application for Sundry Approval, outlining our plans to recomplete MGS 17595 Well No. 18 as a "BCD" injection well. MGS No. 18 is currently shut-in because of a communication leak between the tubing and annulus (reference our Application for Sundry Approval dated January 23, 1987, File: FEW-O17-WF). Our recompletion plans consist of temporarily abandoning the "G" zone perforations, squeezing to ensure isolation in the "BCD" interval, and perforating select intervals in the "B" and "C" zone. Recompleting Well No. 18 as a "BCD" injector is necessary to provide injection support for MGS 17595 Well No. 17 and will allow recovery of significant reserves which remain north of Well No. 17. We anticipate beginning operations on Well No. 18 on November 1, 1987. Any questions concerning this application can be directed to K. W. Unger at our Anchorage office at 562-2147, extension 211. Very truly yours, W. G. Smith District Manager Attachments 2, ~s Anchorage KWU/dds STATE OF ALASKA AL/ OIL AND GAS CONSERVATION COl.. 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension !'] Change approved program [] Plugging ~ Stimulate [] Pull tubing 1~ Amend order [] Perforate ~ Other [] 2. Name of Operator Amocd Prndl~ctinn C..nmpany 3. Address P.O. Box 100779, Anchoraqe, Alaska 99510 4. Location of well at surface 1,937' FNL, 539' FWL, Sec. 31, T9N, RI2W At top of productive interval 2,442' FNL, 1,509' FWL, Sec 30, TON, R12W 5. Datum elevation (DF or KB) 79,4' (KB) 6. Unit or Property name Hiddl e Gr'ound Shoal 7. Well number 18 8. Permit number 76-75 feet At effective depth 2,054' FNL, 1,654' FWL, Sec. 30 At total depth 1,924' FNL, 1,697' FWL, Sec. 30 _ 11. Present well condition summary Total depth: measured 10,231 true vertical 8,223 Effective depth: measured 10,010 true vertical 8,049 Casing Length Structural Conductor 621' Surface 3,500' Intermediate Production 5,983 ' Liner 4,397' Perforation depth: measured true vertical , T9N, R12W , T9N, R12W 9. APl number 5o-- 733-20296 10. Pool Hemlock feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth 20" 1,400 sx 621' 13 3/8" 1,800 sx 3,500' 9 5/8" 600 sx 5,983' 7" 1,120 sx 5,710-10,107' (See attached) Tubing (size, grade and measured depth) 3½" N80 @ 8,863 feet Packers and SSSV ,(type and measured depth) BaKer Model F-1 @ 8,844 feet True Vertical depth 620' 3,296' 5,136' 4,921-8,125' RE ]E VEI) Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation November' 1, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Si g ned ',~../~'~-'~ ~~~.~ , Title District Mana§er Commission Use Only Date 10/19/87 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner I Approval No..~.... ~~.-- by order of the commission Date /(~ Form 10-403 Rev 12-1-85 Submit in triplicate Perforation Data Sheet MGS 17595 No. 18 Zone G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-1 G-2 Measured Depth 9,125 - 9,135 9,148 - 9,153 9,162 - 9,172 9,212 - 9,217 9,222 - 9,232 9,246 - 9,256 9,310 - 9,334 9,354 - 9,362 9,382 - 9,404 9,452 - 9,466 9,476 - 9,494 9,610 - 9,620 9,632 - 9,652 9,660 - 9,670 9,742 - 9,908 9,912 - 9,920 True Vertical Depth 7,367 - 7,377 7,384 - 7,389 7,395 - 7,405 7,433 - 7,438 7,440 - 7,450 7,459 - 7,469 7,507 - 7,530 7,383 - 7,391 7,562 - 7,579 7,613 - 7,626 7,636 - 7,654 7,738 - 7,746 7,756 - 7,771 7,779 - 7,788 7,840 - 7,969 7,973 - 7,981 Description Summary of Proposal 1. Skid rig to Leg 1, Slot 3. 2. Set back-pressure valve (BPV), nipple down tree, nipple up BOP's. Pressure test BOP's to 3,000 psi. Pull BPV. 3. Pull 3½-inch tubing. 4. Mill and retrieve Baker Model F packer, set at 8,844'. 5. Make 6" bit x scraper run to approximately 8,600'. 6. Set drillable bridge plug at approximately 7. Test casing to 2,000 psi. 8. Squeeze interval 6,680'-7,444' to provide isolati n for ne perforations. 9. Perforate the following intervals: II B II -- 6,680 - 6,705' 6,796 - 6,838' 6,886 - 6,944' II C II 7,162 - 7,212' 7,255 - 7,284' 7,343 - 7,380' 7,416- 7,444' 10. Set packer in 7" liner at 6,500' md. 11. Run 3½" tubing and seal assembly. Sting into packer and land tubing. 12. Set back-pressure valve. Nipple down BOP's. Nipple up tree and test to 5,000 psi. 13. Place well on injection. MGS 17595 Well N Wel lbore Diagram KLS/bes ~ 3-25-82 © ® 13-3/8" Casing Record 20" 13-3/8" 61 & 68# K-55 9-5/8" 40 & 43.5# S-95 7" 29# S-95 Tubing & Bottomhole Assbly O 3½" 9.2#/ft. ti-80 Butt G Col lar Q Otis 'X' Nipple G 3½" Butt Tbg. pup G Baker Locator G Bake~ Model 'F' Packer Q Seal Assembly (Baker 4") G 3½" Muleshoe 621' 3500' 5983' 10,107' Depth 8837 8838 8846 8847 8844 8862 8863 Perforations 'G' Zone 9912-9~20' 9632-9652' 9452-9466' Liner top @ 5710' 9246-9256' 9162-9172' 9354-9362' 9-5/8" 9742-9908' 9660-967'0' 9610-9620'j 9476-9494' 9382-9404' 9310-9334' 9222-9232' 9212-9217' ' 9148-9153' 9125-9135' Squeeze Perforations ~89_3_~8g~-6-' 35 SX -8749-8751 Never Squeezed PBD - i0,010' TD - 10,231' TVD~8000' SHEET NO. ~'~- Amoco Production Comi ~1~' ENGINEERING CHART APPN I NNDLhR BGP/,J. · F,/',,r"~ TX rE · - c/? L.//I~' · I [ 3000 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaskas 99501 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 File' FEW-O17-WF Application for SuD.d~_~Approval MGS 17595 Wel 1 -N'°~~ 18~) Platform Baker, C6~6~"~Inlet, Alaska Attached for your approval is a State Form 10-403 to keep Well No. 18 shut in until a plan of repair is formalized. The well is shut in because of a communication leak between the tubing and annulus. Very truly yours, W. G. Smith District Manager Attachments JCB/dds 029/jcb STATE OF ALASKA ALA,' OIL AND GAS CONSERVATION CON ,SION APPLICATION FOR SUNDRY AP'"PROVALS 1. Type of Request: Abandon E] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [.] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator Amoco Production 6ompany 3. AddreCSO. . BOX 100779, Anchorage, Alaska 99510 4. Location of well at surface 1937' FNL, 539' FWL, Sec. 31, T9N, R12W 5. Datum elevation (DF or KB) 79.4' (KB) 6. Unit or Property name Middle Ground Shoal 7. Well number 18 feet At top of productive interval 2442' FNL, 1509' At effective depth 2054' FNL, 1654' At total depth 1924' FNL, 1697' FWL, Sec. 30, 11. Present well condition summary Total depth: measured 10,231 true vertical 8,223 FWL, Sec. 30, T9N, R12W FWL, Sec. 30, T9N, R12W T9N, R12W 8. Permit number 76-75 9. APl number 5o- 733-20296 10. Pool Hemlock feet feet Plugs (measured) Effective depth: measured 10,010 true vertical 8,049 Casing Length Size Structural Conductor 621' Surface 3,500' Intermediate Production 5,983 ' Liner 4,397' Perforation depth: measured feet feet Junk (measured) Cemented Measured depth True Vertical depth 20" 13 3/8" 1400 sx 621' 620' 1800 sx 3,500' 3,296' 600 sx 5,983' 5,136' 1120 sx 5,710-10,107' 4,921-8,125' 9 5/8" 7" (See Attached Perforation Data Sheet) true vertical Tubing (size, grade and measured depth) 3½" N-80 at 8,863 feet RECE VEP Packers and SSSV (type and measured depth) Baker Model F-1 at 8,844Af~'~.$0il. .. & ,:,a~; ~ .... ;"",r.,"~.,:~ ,,~., Co~;'i!'nissi0~ ~ ~_r~h~ r.~r~ 12.Attachments Description summary of proposal.~(.. Detailed operations program [] 'BOP'stretch 13. Estimated date for commencing operation February 10, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby c,,ert'fy th~,e., for, e;Coing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date 01/23/87 Approved by Form 10-403 Rev 12-1-85 ~ "' y~ 27 by order of ..... ~°'r~ r~i;'s i~Og ;'~; the commission Date Submit in triplicate Perforation Data Sheet MGS 17595 No. 18 Measured Depth (Feet) True Vertical Depth (Feet) 9,125 - 9,135 9,148 - 9,153 9,162 - 9,172 9,212 - 9,217 9,222 - 9,232 9,246 - 9,256 9,310- 9,334 9,354 - 9,362 9,382 - 9,404 9,452 - 9,466 9,476 - 9,494 9,610- 9,620 9,632 - 9,652 9,660 - 9,670 9,742 - 9,908 9,912 - 9,920 7,367 - 7,377 7,384 - 7,389 7,395 - 7,405 7,433 - 7,438 7,440 - 7,450 7,459 - 7,469 7,507 - 7,530 7,383 - 7,391 7,562 - 7,579 7,613 - 7,626 7,636 - 7,654 7,738 - 7,746 7,756 - 7,771 7,779 - 7,788 7,840 - 7,969 7,973 - 7,981 Description Summary of Proposal MGS 17595 Well No. 18 is shut-in because of a communication leak between the tubing and annulus. Amoco proposes to leave the well shut in until a formal plan to repair the well has been made. At that time, Amoco will resubmit an Application for Sundry Approval. L. A. Darsow District Superintendent March 24, 1982 File' LAD-304-WF Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907- 272-8471 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Report MGS 17595 Well No. 18 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our recent work to convert MGS 17595 Well No. 18, Platform Baker, Cook Inlet, from a shut-in producing well to a water injection well in the G-2, G-3, and G-4 zones of the Hemlock Conglomerate. The well is currently injecting 1834 BWPD at 3775 psi. Yours very truly, L. A. Darsow District Superintendent Attachment BFS/kl t STATE OF ALASKA ALASKA Orr_ AND GAS CONSERVATION CO~fVIISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL[] OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 76-75 3, Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 995]0 50- ]33-20296 4. Location of Well Leg l, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' RKB HSL I 6 . Lease Designation and Serial No. ADL ] 7595 12. 9. Unit or Lease Name MGS ] 7595 10. Well Number 11. Field and Pool Middte Ground Shoal, Hem1 ock Conq] omerate Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate L-~ Alter Casing [] Perforations E~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state att pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 2/14/82 - 2/20/82' 1. Killed well and pulled tubing. 2. Milled and retrieved packer at 8645' MD. 3. Cleaned out to 9935' MD. 4. Test casing for leaks; no leak found. 5. Set packer at 8844' MD. 6. Run 3-1/2" N-80 9.3// tubing. 7. Rig down; shut-in well to wait on perforating unit. 2/27/82' Perforate with 2-5/8" thru-tubing gun, 4 JSPF' 9125-9135'; 9148-9153'; 9162-9172'; 9212-9217'; 9222-9232'; 9246-9256'. 2/28/82' Commence injections. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Title District Superintendent Date 3/24/82 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent February 8, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 ~ 272-8471 File- LAD-137-WF Fir. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r' Notice of Intent MGS 17595 Well No. 18 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our change of plans for MGS 17595 Well No. 18, Platform Baker. We had previously planned to recomplete this well as a 'BCD' zone producer. However, in light of losing our only water injection well for the 'G' zone in this part of the field due to collapsed casing (MGS 17595 Well No. 14), we plan now to convert this well to an injection well in the 'G' zone. This work will entail pulling the tubing and bottomhole assembly currently in the well, milling the packer, cleaning out to PBD (10,010'), setting a packer at 9290', reperforating intervals in 9125-9256', and running new tubing. Estimated starting date for this work is February 15, 1982, Yours very truly, /' L. A. Darsow District Superintendent Attachment BFS/klt RECEIVEO F E B 1 o 1982 Al3.sks Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ALASKA t:::rfL AND GAS CONSERVATION COlv1MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 779, ^nchoracl_e, Alaska 99510 4. Location of Well Leg 1, Slot 63~ MGS Platform Baker 1924' FNL, 1 7' FWL, Section 30, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 79.4' RKB 6. Lease Designation and Serial No. ADL 1 7595 7. Permit No. 76-75 8. APl Number 50- 733 202 9600 9. Unit or Lease Name HGS 17595 10. Well Number 18 11. Field and Pool Middle Ground Shoal, Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate Lq Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans ~] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. Kill well and pull tubing. 2. Mill out packer. 3. Clean out to PBD (19-~' MD). 4. Set packer at 92.941'. 5. Run new tubing. 6. Reperforate intervals in 9125-9256'. 7. Commence injections. Estimated starting date: February 15, 1982 RE£EIVE[ F E B 1 o 1982 Su~seau. ent Wor~ ~epo!"tec~. ' - o~ ~'o~ No. ~ ~t~ ~~~.i~sk~ Oi~ & sas Cons. ...... ~chorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,./ "IL ~'/_/~'.~,~,/'L--~~(.. Title District Superintendent The space beTow f~r Commission use Date 2/8/82 Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907-272-8471 December 9, 1981 File' LAD-1320-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r' Notice of Intent MGS 17595 Well No. 18 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, regarding our plans to plug back MGS 17595 Well No. 18 (currently a shut-in 'G' zone producer) and recomplete to a 'BCD' zone producer. Yours very truly, ~ ~"$:" ,-~ / ,'~ i, L.'~'~. / L. A. Darsow Di stri ct Superintendent Attachment BFS/klt RECEIVEI) DEC 1 4 1981 Alaska Oil & Gas Cons. CommJssio~ Anchorage STATE OF ALASKA ALASKA-~L AND GAS CONSERVATION C~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETEDWELLY~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 76-75 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 5o- 133-20296 9. Unit or Lease Name Middle Ground Shoal 4. Location of Well Leg l, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) __ 79.4' RKB MSL 12. I 6 . Lease Designation and Serial No. HGS 17595 10. Well Number 18 11. Field and Pool Middle Ground Shoal Middle Kenai Sands Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate L~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We plan to recomplete MGS 17595 Well No. 18 to a 'BCD' zone producer by' 1. Pulling the tubing currently in place and setting a bridge plug at 8660', above the packer currently in place. 2. Run a compensated neutron gamma ray log over the interval 6450-7600'. 3. Do a remedial cement squeeze behind casing over the intervals picked from the logs to be perforated. 4. Perforate indicated intervals at 4 JSPF with 4" casing gun. 5. Ru Ty Estimat n dual string (2-7/8" and-2-3/8") tubing and a Kobe 2-1/2" pe 'B' hydraulic lift comPletion. ed starting date' December 20, 1981 REEEIVED 14. I hereby certify th~.~._~~g is true and correct to the best of my knowledge. DEC1 4 I98t Alaska 0il & Gas Cons, Commi: A~uhu~a§~ The space below for Commission use Title District Superintendent Date 12/9/81 Conditions of Approval, if any' Approved by.__ By Order of COMMISSIONER the Commission Date :s~o~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. D~rsow District Superintendent December 13, 1978 File: LAD-1142-WF Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 Dear Mr. Hamilton: Notice .of Intent .MGS.17595 Well No. 18 platform Bake~'~'C~'o~R'~Trtlet~ Alaska Attached for your approval is State of Alaska Form 10-403. This is a Nolice of Intent to pull the tubing and bottomhole assembly and set a bridge plug above the "G" zone at 8460'. After being drilled in 1977, Well No. 18 tested all water and was completed as a dry hole. The well has remained shut-in since completion. After the proposed workover, Well No. 18 will remain classified as an unsuccessful drilling well and held for possible use in the future. Yours very truly, L. A. Darsow District Superintendent Attachment DRR:sls Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OIL r--) GAS [---] WELL WELL OTHER Dry 14ole ~ NAMEOFOPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 1, Slot 3, MG$ Platform Baker 1936' FNL, 539' FWL, Sec. 31, TgN, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 79.4' Rf~ MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MGS 17595 g. WELL NO. 18 10. FIELD AND POOL, OR WILDCAT liiddle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, ILI2W, S.M. 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Pull BI~A & set CIBP SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letalls, and glve pertinent dates, including estimated date of starting any proposed work. The following is our proposed procedure to set a bridge plug above the "G" zoneY . . e '4. Kill well with filtereU Inlet water. Pull 3-1/2" tubing string and Kobe cavity. Set CIBP above the "G" zone at 8460' and cap with cement Run 2-7/8" tubing to 1000 feet for kill string. 16. I hereby certify that the foregoing is true and correct Orlglnal Slgned by SIGNED. L A. DARSOW TITLE District Superintendent DATE December 13, 1978 CONDITIONS OF APPROVAL, I~ ANY:~- - Petroleum Engineer See Instructions On Reverse Side December 18, 1978 DATE ~Oved .,Dp ~ L. A. Darsow Ama Superintendent October 12, 1977 File: LAD-825-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Completion Report MGS 17595 Well No. 18 Platform Baker Attached is your Form P-7 in duplicate for the completion of drilling MGS 17595 Well No. 18. Also attached is a copy of the chronological history and the directional survey on this well; the open hole logs have previously been forwarded to your office. This form has been transmitted late due to an oversight on our part. We apologize for any inconvenience that this late response might have created. Very truly yours, L. A. Darsow Area Superintendent Attachments JDM:klt Form P--7 SUBMIT IN D!r} / STATE OF ALASKA (s m- structl,}ns on reverse side) OIL AND GAS CONSERVATION COMMITTE[~ WELL cOMPLETION OR. RECOMPLETION REPORT AND LOG* _ WELL WELL b. TYPE OF COMPLETION: ,~w~ WORKE: ,EEP-[ ,LU~[] DIFF. [] %YELL OVER EN BACK RESVR. Other NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779~ Anchora~e~ Alaska 99510 ~. LOCATION OF WELL (1~e~ort location clearly and in accordance with any State requirements~ ~t surface Leg 1, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. At top prod. interval reported below 2442' FNL, 1509' FWL, Sec. 30, T9N, R12W, S.M. At total depth 1924' FNL, 1697' FWL, Sec. 30, T9N, R12W, S.M. ORIGii A[ 8. UNIT,FARR1VI OR LEASE NAME MGS State 17595 9. WFJ,L NO. 18 10. FiELd) A.ND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. (BOTTOM HOLF. OBJECTIVE) Sec. 30, T9N, R12W, S.M. 12. PERA/IIT N'O. 76-75 1-1-77 ~ 3'15-77 . ~ 6,28-77 .... ~ RKB 79.4' MSL~.. ~ $3:~ RKB INTERVALS DRILLED 10.231'MD 8223'TVDI10.010'MD 8049'TVD.| -- i 0 - TD ~ ------ NAL 22. PRODUCING INTErVAL(S), OF THIS COMPLETIO'N--TO1~, BOTTOM, NAME (MD AND TVD)* ' !23. WAS DIRECTIO I SURVEY MADE 9310-9920 ' MD ] Lower Kenai Conslomerate (State "G" zone) 7487-7978' TVD i Yes 24. TYPE ELECTRIC AND OTHE~ LOGS RUN DIL-SP, BHCS-G.R~ F...DC-GR and Dipmeter CASING RECORD (Report all strings set in well) C~%SLNG SIZE WEIGH~C, LB/FT. DEPTH SET. (MD) HOLE STT. E C~EhXILNTING RECO~D ! AMOUNT PULLED 20" 600 sacks 26. LINER RECO~ 7'"'" [ 5710' [ 10,107' [ 1120 28. pEI{FORATIONS OPEN TO PRODU~?I;iOl~ (Interval, size and number) 9310-9334' 9354-9362' 9382-9404' 9452-9466 ' 9476-9494' 9610-9620' 9632-9652' 9660-9670' 9742-9908' 9912-9920' with 4 JSPF 27. SCREEN (MD) 29. DF~TIi TUBING lq ~7 C~ O FJ3 SET (MD) [ PACKER SET (MD) .35" Holes 30. PllODUCTION DATE FIR,ST PI~ODUCTION I PRODUCTION MI~TI{OD (Flowing, gas lift, pumping--size and type of pump) 3-26-77 ~ PumPi_ng 2-1/2" x 1-3/4" Type "E" Kobe ACID, SHOT, F~.~CTURE, C~VIENT SQUEEZE, ETC. , INTF-~VAL (MD) ] ANIOUN'£ £~ND KIND OF MA~AL US~ i i . i i ] il . i *~ i IV~<~i~'~TATUS (Producing or sue'L-in) Shut-in DATA OF TEST, [I-iOURS TESX~iD [CHOXE SIZE P~D'N FO.l% 7-31-77 2~ -- "' ~OW, WBING' ICA~WG PRESSM ICALC~T~ OI~BBL. I o [ o 31. ~isrosITms o~'oxs (Sold, used for ]uel, vented, etc.)' OII~--B~L. G~IS--MCF. V~A'I Er~--BBL. [ GAS-OIl, F~,~TIO I-o I o i -- GA$---~IC~. WA'r~--BBL. ] OIL GRAVITY-API (COP~.) ITEST WITNESSED BY None LiST OF ATTACHMENTS Chronological History and Directional Survey 33. I hereb~ certify that thel foregoing and attached information is complete and correct as determined from all-available records SIGNED ~~ ~~/]~ff~'~'- TITLE Area Superintendent DAT]c0ctober 12, ~_9.77 ~ *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRU'CTIONS General: This form is designed for submitting a complete and correct ,~,ell completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any ettachr'nents. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJucing interval, or ~tervats, .top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately producsci. (See instruction for items 20 and 22 above). 34. SUMIV['A_I~'~r~0bTM F'ORMATION TF25'I'S INcLuDIN(; IN{'EFI. VAL TESTED, F'HESSURE DATA AND 'p..~COVERIE.S OF Of'L, GAS,- .......... WATEI~ AND MUD NAME M~AS. D~P~ TIIRUE VERT. None Kenai Sands State "B" 6645' 5610' State "C" 7112' 5941' State "D" 7450' 6~97' State "E" 8050' 6591' ~ ,, ,,, , ,,, ~. con.m v^~'^, ^~r^c~ nm~ v~sc~o~s o~ ~v~o~o~¥. ~o~oslv¥, ~^cw~s. A~V Ores State ~'F" 8401' 6838' :" ': ' · ...................... State "G" 88~5' 7Z36' ' ~one .. ...... ~ ..... ~ ........... Eastman REPORT of SUB-SURFACE DIRECTIONAL SURVEY Amoco Production COMPANY Middle Ground Shoal #18 WELL NAME Cook Inlet LOCATION ,JOB NUMBER A277 G0272 TYPE OF SURVEY Gyro-scopic DATE 3-24-77 SURVEY BY Shyam Talwar OFFICE Alaska CONPLETTON R~POR¥ MAR~i-'~ 77 'A~IOCO--PROI)UC T [ ON COMP A N Y GYROS COP ~~ E Y RADIUS-~UR~A-~~~HOD OF C~T~~ RECORD OF $URVEY TRUE M'E'~S'~-OI~I ~~B'' DRTF T DEPTH--ANG LE-~d>T-H ' SEA~' D I R EC ~N DEGi 0 0 0 0.00 -7~' N20.00W --~ 0 [5 99~99 20.59 N20 ~00W '--z-bb 0 3o 199.9~---q}-C;-.5-9--N29.00w 300 ! 0 299.98 220.58 N 15,-0-0W 600 2 0 599.85 520.45 N24.00W 700 3 0 699.75 620.35---N-2I,-00w 8O0 4 5 .... 7-99.56 ---~-2~.Tt~ N13.00W 900 4 30 899.28 819,88 N26,-Oow 1000__5 5- 998.93 919.~3 N29.00W _._~200 6 39 1197.91 1118.56' N24.00W 1300 7 24 1297.15 1217.75 N16.00W TOT'AL COORDINATES C L O D rST-AN~E U R E $ SEV'B~'rl'7 SECTION----- A ~-------D E-G/1.-OO FT------D-I-,.STAN Ci~---- D M S .0.00 $ 0.00-W 0.00 $ 0 0 0 W 0.000 0.00 0.20 N 0.07 W 0.2.! N 19 59 59 W 0.250 0.18 0-'~?~- N 0.34 W 0.87 N 23 22 27 W 0.250 0.70 2~01N 0.83 W 2.17 N 1400 8 30 1396.19 1316.79-- 1500 10 5 1494.87.1~5..47 1600 11 35 1593.08 1513.68 1700 13 5 1690.76 __~800 1~ 45 1787.82 1708.42 1900 16 30 1884.12 1804.72 N 6.OOE 22 33 0 W 0.500 1,78 4.~4 N 1.69 W 4.57-~ 21 44 17--W 0.750 3.78-- '7~'~"~ N 2.'73 W T, 68 N 20 49 52 W 0.081 6,43-- 10J35 N 3.76 W 11.01N 19 58 27 W 0.171 9.31-- 14.38 N 5.43 W 15.37 N 20 41 26 W 1.000 1-2-'11- 20.30 N 7.24 W 21.55 N 19 37 54 W '1.101 18~%' 27e35 N ~ 9.73 W ' 29.03 N 19 35' 52 W · 0.408 2~.63 34.77 N t3.60 W 37.34 N 21' 21 47 W 0.600 31~ · 43.09 N 17.93 W 46.67 N 22 ~5 36 W 0.561 3~-.~'----~ 52.81 N 22.46 W 57.39 N 23 2 ~5 W 1.000 46.78 64'.31 N 26.65 W 69.61 N 22 ~0 31 W 0.762 57.12 __N13.00W 77.71 N 30.11 W 83.3~ N 21 10 59 W 1.092 69.47 N 9.00W 93.57 N 33'.19 W 99.~8 N 19 32 4 W 1-605 84.30 N 5.OOW 112.25 N 35e49 W 117.72 N 17 32 46 W le509 102.06 N O.OOW 133.61N 36.42 W 138.'~8 N 15 1~ 57 W 1.522 122.72 N 3.00E 157.66 N 35.79 W 161.67 N 12 47 28 W 1-661 1~6.36 184.51 N 33.68 W 1833__5_6 N 10 20 ~3 W 1.767 173.03 __N 7eOOE 214.30 N 30.28 W 216.43 N 8 2 39 W 1.903 __N 8.00E 246.98 N 25.98 W 248.35 N 6__0 20 W 1.704 235.71 N 9.00E 282.71 N 20.64 N 8.OOE 321.75 N 14.81 2OO.O_~8 23 1979.52 1900.12 2100 20 5 2073.92 1994.52 '-~00 22 15 2167.16 2087,76 ___2300 24 15 2259.04 2179.64 _240~,_~7 0 2349.20 2269.80 W 283.46 N 4 10 36 W 2.155 271.75-- W 322.09 N 2 38 8 W 2.007 311.13 N 9.005 364.51 N 8.41 W 36~.61 N 1 19 23 W 2.758 354.28-- RECORD OF SURVEY A~L CAiLCULATj~__P_ER__FORM_ ~D BY ! B N ELECTRONIC CONPUTE,R TRUE DOG LEG MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S U. R E S SEVERITY SECT .DEPTH ANGLE DEPTH SEA DIRE¢ DISTANCE ANGLE DEG/IOOFT DISTA 2500 24 k5 DEG, D M 5 243~,35 2359,95__N ~3~OE 407,50 N 3,90 W. 407__,~2 N 0 32 54 W 2.930 2530,62 245t,~2 ~...$_900W 448,32 N 4.97 w' 448,35 N O 38 6 W 1,~.1_0 _ 2621,52 2542,12__~_2.00W 489,9~ N 0 55 16 W 2711.24 2631.8~ N 1,OOE 3..~j'j 2 4 .~O024 0 _~7002515__ 2800 27 9 ~89.87 N 53~,02 N 2900.29 39 2799.~9 2719,79 N O,00E 581~60 N 3000 29 30 2~6,15,,,_~2~96'_!5_N__O'~0E 6~'~ N 3200 33 19 3056.73 297!,33__ N O*OOE 735,31 N 3300 36 0 3138.97 3059.57 N 1.OOW 792.18 N 7.87 W 8.26 W 7.84 W 7.84 W 6,93 W 7.~3 W 3400 37 45 3218,96 3139,56 N !.OOW 852,17 N 8.47 W 3500 41 15 3296.11 3216.71 N 2.00E 915.76 N 7~_W 3600 41 30 3371~15 3~9~__N 6.00E 981.69 N -3.31W -%~6-~-~ 0 344~.58 3365.~8__N 6.00E 1049.19 N 3.78 E 3515.13 3435.73 N 6,00E 1119.66 N__11.18 E 8.52.,22 N 034 12 W 3800 46 15 3900 46 45 3583,96 119t.73 N 19.39 E 981.69 N 0 11 36 W 1.77~ 1049,2Q N 0 12 23 E 2,.5_Q_0 1119.72 N 0 3~-20 E 2,_~_2.~ 1191,89 N 0 55 57 E 0.729 892_,_8~ ..... · 1025~ 1168.30 4000 47 0 3652,32 4100 47 17 3720,33 43004853 3854.02 4400 45 30 3921,96 3572,92 N 7,00E 1~i}7 N--28.29 E 3640.93 ..... N..8.,999 1}).§~86 N__37.86 E 3708.30 N__9~995 l~9_gm~._~ ..... 3~_-3~ E 3774.62 N 9.00E 1483.87 N__60,49 E 3842.56 N 9.00E 1556.32 N 71.96 E 1264.49 N 1337.40 N i 1655 E 13720 E 1~10.79 N 1 58 54 E 1485.10 N 2 20 4 E 1557.99 N 2 38 51 E 0.250 1R40.97__ 0.618 1314,02 o.892 1,3~3~]b 0,900 1~62,47 3.40.0 1535.70 2,543 1605.~ 1627.28 N 2 56 26 E 4500 43 0 3993,58 3914,18 N10,OOE 1625,14 N 83,48 E 4600 42 0 4067.31 3987.91 NIO.OOE 169'1.67 N 95.21 E 1694.35 N 3 13 17 E 1.000 1672.89 4700 42 30 41~1.33 4061.93 Nll.OOE 1757.78 N__107.46 E 1761.06 N 3 29 55 E 0.677 17~.09 4800 42 17 4215.18 4135.78 Nll.OOE 1823.97 N 120.33 E 1827.94 N 3 ~6 28 E 0.200 1807.50 _ 4900 ~_2 0 4289.32 4209,_92 NI_ke_OOE 1889.85 N 133.14 iE 5000 38 30 4365,63 4286,23 NI~.OOE 1953.04N 146~5~ E 5100 38 0 4444,16 4364.76__N 7.00E 2013.98 ~ 157.31 E 5200 37 30 4523.23 4443.83 N 8.00E 2074.67 N 165.30 E 195__8.5.~ N 4 17. 30 E 3.5~5 2020.,11__N 4 27 59 E Z. 329 2081.25 N 4 33 20 E 0,622 19393_19 ..... 20g~3~ ..... 2062,02 RECORD Of SURVEY AJ~J.,,._CA~L_~CULATION_S PERFORMED BY I B N E_I,.EC~I'RObiIC CgMPUTER T_P._U_E j~E_~_S~. DR !_F_? V_E~T_I_CAL ,DEPTH A N.~L_~ D. DOG_LEG SUB DRZFT TOTAL C_O_ORD._I__NATF.._S C__L__O $ _U ~_E._S_. -_S_E_V_ERLTY SEC_T_ION SEA __P_ IJ~E.C DISTANCE ' AJ~LG LE DEG/IOOFT D I &T A~ICE .__~__0_0__3_9 O. 4_6.9_0_,02 ~_60_0_,_62 N__9_,_O_O_E _5_5_0_0 3_9___3_0. 4_7_5_~_,45___<+.67.8_,_Q5- Ni_L,D_OE __5600 39___3_0 48_3_~,_6.2_ 4Y_5_5_,_22 N 'L~._O_OE 2~_2__2_;_6_6 N 19_4J_ll___E 22_6_8 .,_LT__~ 4__.5_4__3~__E oj.9~51 2_04 ,D_6.__E 2_2L3_,l.._,_6_lN.__.5 1__15 E 2 .THE FO_LLOWI. J3_G I_$ ~AGN_E_T_I_C S_IN~_G_LE S_HOT SURV_EY D_ATA ....~_6.2_6 3_9 .~ 0 ~.8~,9_,!5 4_7!5_,~9. _N_3_,_O~_E 2_~:3_8_,_99_j~ 2_O_6_,_O_~__E..._......2~.,.O.~____N __5_73_1 ~_5 ~5 4~8.,_1_8 4_85_8__,7_8 _N__2.~._0_0.E 2kO2.,_50__H _2,_1_1_,_0_6 E 2_~!~_,3_5__N 5_1_1_~ E - 3,_~_6 __582_! ~_7 ~._5 5_0_10,_2_9 4930,89 N _3_,_OOE 2456.30 N 2_~_3_,41_E 2465--~5_5 'N 4 57 --53_5.2__3_8 45 5_L1_~,3.~7 5033 ,7_7 ._~ N_ __4. mD_O_ .E2_5_3__?,~__~N 2_.1.8_._,36 E ~_._6_2__6J. ~._5~5 __6_13__0~ .1_5 527~_,_9_2 _%195,52 N 7,00E 26812'.76 N__230,25 E 2692,62 N 4 5~ 20 E 2__0__24 6~I5 44 ~0 ~78.56 5299,16 N 8,00E 278~.,29 N 24~.49 E 279~e92 N 4 59 59 E 23_92,0 5 2 ~2_5__, 2.3_ 2._6_0~_,,_86_ 2_6_6-9_ ,~_ 2_ . 2'/'/0.9_6 6489 45 0 5502.13 5422,73 N 9,00E 2904,44 N 261.60 E 2916.20 N 5 8.48 E 0,406 2893.1_8~ 6638 47 0 5605.63 552.6.2~ N12,00E 3009,81 N 281,13 E 3022,91 N 5 20 10 E -" 1,721 6860 44 0 5~_~1_..2~ 56~.8~ N13,00E 3~64.38 N ~315,39 E 3~80.06 N ~_~1 ~0 E 1.~69 6956 44 45 5829.83 5750~43 N13,00E 3229,80 N ~30-50 E 3246,66 N 5 50 3~ E 0.781 7112 44 45 5~e~.2 .5~6i~2"2 N16eOOE 3336,11N 357,99 E 3355.27~'N 6 7 29 E__~,354 7304 46 0 6075.49__5996.09 N17.00E 3467,13 N 396.80 E 3489.77 N & 31 44 E 0.7~5 34~1.77 3000,29 7452 46 $0 6177.83 6098.43 NtT.00E ~56.9,37 N 428,06 E 3594,95 N 6 50 19 E 0.338 7618 ~6 30 7728 47 0 6292.10 6212.70 N18,00E 3684,21 N__464,27 E 3713.35 N 7 10 56 E__0,4~7 3698~2A 6367,47 6288.07 N19,00E 3760,19 N' 489,69 E 3791.94 N 7 25 11 E 0,666 ~777,9.~ 7968 45 45 6533,05 6453,65 N22,00E 3922,89 N __550.52 E 3961,33 N 7 59 18 E 0,826 39~9,86 8186 45 0 6686.19 6606,79 N23,00E 4066,23 N 609,90 E 4111,72 N 8 31 48 E 0.4~3 4102,59 8426 ...4_5_._3_0 6_8_5_5._~__5. 6775,75 N2~,005 42_2_0__,_6_.8_ N 68.],_~9__~__E 427_.5._~_!. N 9 1_0_~39, E 8657 43 30__703.9,9.0 6940,50 N30,OOE 4362,9~ N 759, 6],~£ 442_8_,_5_0_.N.. 9 52 14 E 887!__~I 45 71_7_7._3_6 7097,96 N30,OOE 44,88,44 N ' '83_13~_Z ~E; 45_~,83_ N_kO 2_9. 485 9177 ~+1 15 7406,54. 73~7--_1.{+ N_2~_,O__O.E 46_~_8_,_24 N 9_~.~_._2j,_E 4759,_04 N l_l__k2._~_7__E 9467 39 30 7627,_4_~ .75_4t~,_0_~ NZi_e_O_OJ5 , 4_841e12 N 998.59 F 4943.04 N 11 39 __ 1 ;0_~.2 4_4_Z_4_,_3_ 5_ 0_, 8 Z8 4.562_,_~,5___ RECORD OF SURVEY AL,.L _CAL.CU.L_A_T_LO_N_S ~E. BF~O_R_~.E_D BY L_B M F.,_I.,_E_CTRONIC C_OMPU_T_ER -T.R_U_E MEA$, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES CLOSURES DEPTH ANGLE DEPTH SEA DIREC D N DEG. D~STANCE .ANG%E D M S DOG LEG ~F_._~ _~ I TY.. S_F._~T_I.O N D_EG/iOOFT D_I_,.Sj_~_I~LC.E : ~HE FOL~OW]NG LS EE~.BAPO. LA_..T_ED FRPB THE D~$T~ S~UJ~Y_EY O.L_Q_Z_3_/__37.3_O 82Z2.~_96 8.1__~__3__,_5__6 N_L_8~_OOE 52,.9_?,_,_2,8 N 115_7_,~_6 _E: 54,17'a,~0 31 e 0~373 J)_OTTOM HQLLCLO,S_HI~E___5_~_kT_~_~LS_FEE_T...AT N__122_0 · MF_A~UEED_ DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE , , Mt'ASURED VERT..I~SIIB M_D-TVD VERTICAL . DEPTH DEPTH SEA.__D_I~EERENCE CORRECTION TOTAL COORDINATES XT~ 179. 100 0 0 0,64 N 0,26 W 279 279. 200 0 0 1,68 N 0,72 W 379 379, 300 0 O /+79 479. /+00 0 0 580 5_7~. 5OO 0 0 $80 6793 6_QQ 0 0 7_~0 779,__700 0 0 3,69' N. 1,43 W 6,52 N ' .2757 W 9,69 N 3,._/+8 W 13., 42 N .I!,_9_2 N - 6,89 W 880 879. 800 980 979- ~9_0 1081 1079, !O_O_O_ 1181 1179, 1100 1282 .i279____, L_2.00 1383 1379. 1300 1/+79, 1400 1586 1579, 1500 6 1688 1679. 1600 8 -:> 1791 1779. 1700 11 25,92 N 9,09 W 3.~,~2 N 12,75 W 41.39 N - . 17,09 W 50,~2 N 62~1.0 N 25m91 W 75,28 N - 2_9,!9_~ W 32.74 W 1 90,83 N 109..4~ N 130,88 N 36,~_0__W 155,37 N ~5,90 W 1895 1879. 1800 15 /+ 183,10 N 33,82 W 2000 1979. 1900 20 5 214,25' N 20.29 W 2106 2079, 2000 26 6 248,97 N 25,70 W 2213 2179, 2.100 3~ 7 287,60 N !9,87 W 2~22 2279, ~200 42 9 330,80 N 13,52 W 243/+ 2379, 2~00 54 12 379./+5 N 6e32 W 2544 2/+79. 2~00 64 10 ~ /+25.~42 N' 2e'3/+ W 2653 2579, 2500 74 10 470.08 N 6,'8/+ W 2764 2679.__2600 .8~ _ 10~ 517,79 N 8,37 W 287? 2779. 2700 97 13 570,3.1N 7,87 W 2992 2879, 2800 112 15 627.,01N 7.8/+ W 3108 2979. 2900 128 16 685,90 N 7,33 W ~22! }~o 3~78 3611 3149 3893 AND O.IHEE_~kT_A FOR_~.ERY__E_V~O~EET O~ ~UB SE_A OEPTH_- TRUE MEASURED VERTICAL SUB MD-TVD VERTICA~ DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATE~ 4040 36!P_, ~6o0 360 4187 3779, 3700 407 4338 3879* 3800__458 4480 3979, 3900 500 48_8_6 5017 5145 5399 5528 ._~079_, 4000__53.6 ~12%, . 4j00_._..3__72 4278,_ _~[00' 607 4379. 4300 638 4479. 4400 665 45~9_, 4500 691 4699. 4600 71~ 4?79. 4700 768 5657 4879, 4800 777 5782 4979, 4900 802 5079, 50qO 829 6039 5179o 5100 859 6176 5279. 5200 896 5909 2 9 Z_ ~77.!,~_6_.N_____~%7_,_3.3_ E_ 29 23__5_8_.~_8 H ,. 25 243 2 · 6 8 N 2_~_2 ,__2_7 E 27 2510,3_6,N ~.16,56 30 2593,,33 N 222,28 37 2686,91 N 230.77 E 6316 6457 5479, 5400 977 40 2783,99 N 243,59 E 41 2882,02 N 258,08 E 6600 5579, 5500 1020 43 2982,70 N 275,57 E 6745 5679, 5600 6885 5779, ~700 7026 7167 5979, 5.900 1105 40 3181,33 N 319,31E ...... ~46 41 3277,54 N 342,1!_E 1187 41 3373,43 N 368,79 E 7399 6079, 6000 1230 43 3470,57 N 397,85 E 7454 6179, 6100 1274 44 3570,76 N 428,48 E 7599 6279, 6200 1319 45 3~7__~,10..N 460,02__E 7745 6379, 6300 1365 46 3771,93 N 493,76 E 7891 6479, 6400 1411 46 3871,30 N 530,16 E 8_0_3.4 6_53_93 6_5~93 4__54 . 4 8176 _6_633_, 6_6 O0. l_zL~6 42 40_5_9_.~ 6_0_7_._1& E 8318 6779_, 670_0 1_~3_8 . ::42 . ~_1_5_1_,_6_3__N 648_,_1_0--5 8660 687_9, 6--8_0_0 k5_8_0 8601 6979, 6_9_0_0. ~6.21 41 4329 ,.2._6__N 73_R,_~_7__E 8739 7079_, 70_0_0 1 _6~5_9 3_8 4411,27 N 787.0_6 A_ND O_T~E~ OAA_T__A FOR _E__V_ER_YE__V_EN 1__0_0 FEET OF SU_B,,5_E_A DEPTLI:I~. TRUE M E A$.~U_R_E 0 V E_R~T~I~_L__SU_B ~D_-_T_V D VER T r~..__~A__~ D_EP TH DEPTH SEA_D_X FFERENCE CORRECTION TOTAL i 875*26 E 8874 7179, 710~ 1694 35 4490_,~Z N 9007 7279, 7200 1727 33 4567,56 N 9141 7379, 7300__1761 34 4646.69 N 9273 9405 7579, 15_3~ 7679. 9664 7779, 472~_,_8._6 N 48_8_0_,3_~ N 9793 7879, 7800 1913 29 5035,55 N 9922 7979, 7900 1942 29 51-1_k~53 N 10049 8Q!9~89P9 1~69 27 5186~_N 8179, 8100 1996 10176 9 7479, 7400 1793 75 0 0 .18~5 3_~ 9_8A,_O.5_F-._ 760.0 18_5~ 23 7700 ' 1884 30 L(~2_,_6_SE - ko_7_o_.~_2_~ · .1_o 9 27 1_!_4 I -~LT-~POLATED VALUES FOR EVEN IO00--F-F.-E-T--OF~D DEPTH: TRUE MEASURED DEPTH VERTICAl,, ,5_UB DEPTH SF..A TOTAL COORD_I!~'AT E5 ~,000 998_, 2000 3. g.T_9_.__..__~gD.O 3_QO0 28_8A. _4_OOD 36 ~ 000 43A5, 6 0 QO 515 O) 7000 586__i. 80,00 6555 · Z0000 8040,, 13.59 W 3~.2R W 7.8/+__W 28.29 E 1A~.57 E 220_L49 E ~3_7_._a- :- . 4O0 I r- : ..... i t * j_ ................................. 1 ~ ~ADlUSi-OF CU ~VATURE GYROSCOPIC $ .... 6800. 6000, ! -" L. A. Darsow Area Superintendent September 22, 1977 File: LAD-770-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natura~ Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.o. Box 779 Anchorage A aska 99510 Dear Sir: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of August, 1977. Very Truly yours, L. A. Darsow Area Superintendent Attachment JDP:mls Form No. P- 4 I~[{V. 3- 1-70 SUBMIT IN DUPLICATE STATE-~O F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. API NUMERICAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 779 Anchorage, Alaska 99510 18 4. LOCATIONOFWELL Leg 1, Slot 3, MGS Platform Baker, 1936' FNL 538, FWL, Sec. 31, T9N, R12W, S.M. 10. FIELDANDPOOL, ORWILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of July 31, 1977: August 1-19 PBD 10,010' August 20-31 PBD 10,010' Status as of August 31, 1977: PBD 10,010', well pumping Well pumping Well shut-in PBD 10,010' well shut-in. Well completed September 1, 1977 as a dryhole. 14. I hereby cert~fy~hat/~h. ~rrf~c'~.,m true and c~ s,OnED .Z7~! d-/ /~Ji./'(~'Z?-g~'v~ ' T,TLE Area Superintendent DATE .... Septembe:r 22, 1977 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. (AMOCO) L. A. Darsow Area Superintendent August 18, 1977 File: LAD-668-WF Mr. O. K. Gilbreth, Jr., Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of July, 1977. Very truly yours, L. A. Darsow Area Superintendent Attachment JDP:srb I:orm No. I'-4 REV. 3- 1-7(} SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. 2. NAMEOFOPERATOR Amoco Production Gompan¥ 3. ADDRESSOEOPERATOR P. O. Box 779, Anchorage, AK 99510 4. LOCATIONOFWELL Leg 1, Slot 3, MGS Platform Baker, 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. 5. API NUME~CAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME MGS State 17595 9. WELL NO. 18 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of June 30, 1977: PDB 10,010' testing well , July 1 - 31 PBD 10,010', well pumping all month. Tests indicate 100% water. Status July 31, 1977: PBD 10,010', well pumping. SIGNED-~', ///~/' ~_/~,~Z~~ TITLE Area Superintendent DATE August 18, 1977 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 1§th of the succeeding month,unless otherwise directed. L. A. Darsow Area Superintendent July 19, 1977 File: LAD-568-WF Mr. O. K. Dlvisio~'-~£ Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Com P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of June, 1977. Very Truly yours, L. A. Darsow Area Superintendent Attachment JDP:llb Form No. I'- 4 RI'iV. 3-1-7(I SL1BMIT IN I)LIPI.I('A1T] STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAMF. OF Oi'ERAI'(IR Amoco Product±on Gompany 3. ADi)Ri'~SS OF OPI'~RATOR P. O. Box 779~ Anchorage, Alaska 4. LOCATION OF WELL 5. APl NL1MF. RICAL CODE ,. 50-133-20'296 6. LEASE DESIGNATION AND SERIAL NO. · ADL 17595 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME MGS State 17595 9.WELI~ NO. 99510 18 10. FII'_'LD AND POOL, OR WILDCAT Leg 1, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T 9 N, R 12 W, S.M. Middle Ground Shoal · 11. SEC. T, R. M. (BOTTOM itOLE OBJECTIVE) Sec. 31, T 9 N, R 12 W, S.M. 12. ?F. RMIT NO. 76-75 13. REPORT TOTAL. I)EFI'tl AT I'.'NI) OF MONTll, CIIANGES IN HOLE SIZE, CASING AND CEMENTING .JOBS' INCLUDING DEPTtl SET AND VOI.UMES USI{I),PERI:ORATIONS, TESTS AND RESULTS FISIIlNG .IOBS JUNK IN tlOLE AND SIDE-TRACKED ilOLE AND ANY OTIIER SI(;NIFICANF CIIANGES IN IIOLE CONDITIONS, Status as of May 31, 1977 June 1-15 June 16-18 PBD 10,010' PBD 10,010' PBD 10,010' June 19-20 PBD 10,010' June 21-25 PBD 10,010' June 26-27 June 28 June 29-30 PBD 10,010' PBD 10,010' PBD 10,010' Status as of June 30, 1977 PBD 10,010' Well shut-in. Well shut-in. Skid rig from MGS 17595 Well #16, and rig up. Pull 3-1/2" tubing & Packer seal assembly. Set bridge plug at 9200'. Squeeze perforations 8934-35 with 100 sx. class 'G' cement, Clean out h°le. Run 3-1/2" tubing & Kobe BHA & pump. Release rig, well on test. Pumping 100% water. Well on test. Testing well. 14. ! hereby certif~,thj,,,~-I~?fl~going is true and correct SIGNED ~/'.t' [, //~.~./_/~ff_~-:~r'--~//"}/' ~ TITLE Are~ Superintendent _DATE July 19. 1977 NOTE-Report on this form is required for each calendar month, rogardle~ of tho status of operations; and mt, st bo filed in duplicate with tho oil a.d gas conservation committee by tho 15th of the succoodin§ month,unless otherwise directed. L. A. Darsow Area Sui')erintendo, nt June 21, 1977 File: LAD-483-WF Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 i 1 ~AFT J FILE, Fl Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of May 1977. Very truly yours, ..':lb L/ t '' ": L. A. Darsow Area Superintendent Attachment JDP:srb Form No. REV. 3- 1-70 SUBMIT 1N DUPLICATE STATE OF ALASKA AND GAS CONSERVATION GOMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. API NUMERICAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [] CAS [] 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 779, Anchorage, Alaska 99510 18 4. LOCATION OF WELL Leg l, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. 10. FIELDANDPOOL, ORWILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CItANGES IN HOLE CONDITIONS. Status as of April 30, 1977: PBD 10,010', well shut-in. May 1-31 PBD 10,010' well shut-in 14. I hereby certify_~hat.ttle fo~ true and correct~ SIGNED ' '.'.~, TITLE. Area Superintendent DATE June 21, 1977 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A. Darsow Ar(;a Sul')erintendent Amoco Production Company P.©. Box 779 Anchorage, Alaska 99510 May 13, 1977 File: LAD-392-WF Mr. Hoyle H. Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of April 1977. Very truly yours, L. A. Darsow Area Superintendent Attachment RECEIVED 1. 6 1977, Divi¢...,n ol 0ii &. Oas Oonsei"v~tion Anchorage Form No. REV. 3- ! -70 SUBMIT IN DUPL1CA~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP1 NUMERICAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, AK 99510 18 4. LOCATION OF WELL Leg 1, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. 10. FIELDANDPOOL, ORWIL~AT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of March 31, 1977: PBD 10,010' well on test , April 1-9 April 10 April 11-17 April 18 April 19-30 Status as of April 30, 1977: PBD 10,010', well on test. PBD 10,010', ran temperature survey 6500-TD. PBD 10,010', well shut-in. PBD 10,010', ran pressure bomb at 9922'. PBD 10,010', well shut-in. PBD 10,010', well shut-in. MAY 1 6 97'7 14. I hereby certify, AJ~at the foregoing is true and correct SIGNED~~"-°~/ ~~ ~ TITLE Area Superintendenl; DATE May 13, 1977 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and oas consorvation committo~ by the l~Sth of the succaodin{.I month,unless otherwise directed. Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 L. A. Darsow Area Superintendent April 15, 1977 File: LAD-301-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of March 1977. Very truly yours, , L. A. Darsow Area Superintendent Attachment ~ I'Lorll~ No, I~ .I R I' V. Y 1-70 NUIIMIT IN I)UIq. I(?ATI,~ STATE O'1~ ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I. WELL WELL OTIIER 2. NAME OF OPERATOR Amoco Product±on Company 3. ADDRESS OF OI'ERATOR P. O. Box 779, Anchorage, AK 99510 5. APl NUMER1CAI~COI)E 50-13-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 4, LOCATION OF WELL Leg 1, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. 7. IF INDIAN'ALOT'I'EE.OR TRIBE NAME 8. UNIT FARM OR LEASE NANtE .MOS State 17595. 9. WELL NO. 18 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAl. I)EI'TII AT END OF MONTtt, CtlANGES IN ttOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOI. UMES USED, PF. RFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTIIER SIGNIFICANT CIIANGES IN ltOLE CONDITIONS. Status as of February 28, 1977: TD 8456' drilling 8'1/2" hole , March 1-15 TD 10,231', drilling 8-1/2" hole. March 16 Logging. March 17-18 TD'10,231' 29# S-95 Butt csg. , run 100 jts 7", , Land at 10,107', top 5710', cement with 1120 sx Class G cement. March 19-21 PBD 10,010', clean 7" liner and run Gyro Survey. March 22-23 PBD 10,010', run 3-1/2" Butt tubing. Land at 8681'. March 24-25 PBD 10',010', perforate well at the following intervals 9912-9920 9476-9494 9742-9908 9452-9466 9660-9670 .9382-9404 9632-9652 9310-9334 9610-9620 9354-9362 March 25-31 PBD 10,010', testing well 100% water. MGS 17595 Well No. 16, 3-25-77. Status March 31, 1977: PBD 10,010', well on test. Rig released to RE'CEIVED Divi$IO~ ~ ~ii & Gas Conservation 14. I hereby certify ~{~,a,. ,.. ,.~,~, o.~,~u ~ Area Superintendent April 15, 1977 SIGNED t... ~. ~tar.A k3O&l~lt~ ·, TITLE DATE ~OTE--~eport on this form is required for each calendar month, ro~ardlo~ of tho status of operations, and must bo filed in duplicate with tho oil and oas consorvation committee by tho lfith of tho succoodin~ month,units otherwise directed. L. A. Darsow Area Superintendent March 11, 1977 File: LAD-205-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Compan~t-~i P.O. Box 779 Anchorage, Alaska 99510 '~ Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of February 1977. Yours very truly, L. A. Darsow Area Superintendent Attachment Form No, I)- 4 REV. 3-1-70 SUBMIT IN DUPLICATE STAT E"~'F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. API NUMERICAL CODE 50-133-20296 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 18 4. LOCATION OF WELL Leg 1, Slot 3, MGS Platform Baker 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Status as of January 31, 1977: TD 6000', drilling 12-1/4" directional hole. February 1: February 2-6: February 7-9: February 9-21: February 21-28: Status as of February 28, 1977: TD 6000', logging. TD 6000', run 143 jts 9-5/8" 40# and 43.5# S-95 butt csg. Land at 5983'. Cement with 600 sx Glass G cement. Drilling 8-1/2" hole to 6809' TD. TD 6809', stuck pipe, fishing and recovered fish. TD 8456', drilling 8-1/2" hole. TD 8456', drilling 8-1/2" hole. 14. I hereby certify, that ~~-is true and correct SIGNED TITLE Area Superintendent DATE March 11, 1977 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A, Darsow Area Superintendent February 16, 1977 File: LAD-126-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Monthly Report of Drilling and Workover Operations Middle Ground Shoal 17595 Well No. 18 Please find attached State of Alaska Form P-4 summarizing drilling operations on Middle Ground Shoal 17595 Well No. 18 for the month of January 1977. Yours very truly, L. A. Darsow Area Superintendent Attachment I:orm No. 1'-4 REV. 3- I SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS S. API NUMERICAL CODE 50-133-20296 LEASE DESIGNATION AND SERIAL N°. ADL 17595 1. 7. IF INDIAN-ALOTTEE OR TRIBE NAME OIL [~] GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Amoco Production Company MGS 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 18 4. LOCATION OF WELL Leg 1, Slot 3, MGS Platform Baker, 1936' FNL, 539' FWL, Section 31, T9N, R12W, S.M. 10. FIELDANDPOOL, ORWILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, R12W, S.M. 12. PERMIT NO. 76-75 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. January 1, 1977: January 1-3: January 4: January 5: January 10-14: January 15-17: January 18-21: January 22-31: Spud. Drilling, TD 650'. Run 621' of 20" casing and cement with 1400 sacks Class G cement. Temporarily suspended drilling'operations, rig released for workover. Drill 12-1/4" directional hole to 3529' TMD. Open 12-1/4" hole to 17-1/2", TD 3529'. Run 3500' of 13-3/8", 61# & 68# K-55 Buttress casing and cement with 1800 sacks Class G cement. Drill 12-1/4" directional hole to 6000' TMD. RECEIVED 14. I hereby certify that the foregoing is true and correct SIGNED ~. ~.~~--~ TITLE Area Superintendent DATE February 16, 1977 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. L. A. Darsow Al¢,a Superintendent February 4, 1977 File: LAD-iO5-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company Anchorage, Alaska 99510 --' Dear Sir: Re: Casing Program Change MGS 17595 Well No. 18 Reference is made to the telephone conversation of February 1, 1977 between Mr. John Miller and Mr. Bill Halvorson of this office, during which verbal approval was given to change our original casing program for the subject well. Formation leak-off tests recently run at the 13-3/8,' casing shoe indi- cate that the formation fracture pressure at this point is significantly lower than that required for a drilling mud sufficiently weighted to contain the anticipated pressures in the State "B" zone (estimated 6580' TMD). In view of the fact that the State "A" zone (estimated 6050' TMD) may contain similar pressures, we have set 9-5/8" protective casing at 6000' TMD. We plan to drill 8-1/2" hole to total depth, estimated at 11,400' TMD, and set a 7" x 5600' liner. A completed Form 10-403 is attached for your reference. Yours very truly, L. A. Darsow Area Superintendent Attachment RECEIVED Form 10-403 REV: ~-10.73 Submit "Intentions" In Triplicate & "Subsequent IRei)orts" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) O,L 17/I GAs [--] WELLIA I WELL. OTHER 5. APt NUMERICAL CODE 50-133-20296 4. LOCATION OF WELL At surface T,eg 1, Slot 3, 1934' F:NL, 544' FWL, Section 31, T9N, R12W, S.M. 6. LEASE DESIGNATION AND SERI'AL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR 8, UNIT, FARM OR, LEASE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. ]Box 779, Anchorage, Alaska 99510 18 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 79.4' KB - MSL Check Appropriate Box To Indicate Nature of Notice, Re 14. NOTICE OF INTENTION TO: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS TEST WATER SHUT-OFF L---J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 30, T9N, R12W, S.M. 12. PERMIT NO. 76-75 3orr, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) casing program change (NOTE: Report results of multipl'e completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Wellhead pressures from a shut-in offset water injection well indicate that mud weights in excess of 12.5 ppg will be required to safely con- tain pressures in the State "B" zone. (estimated 6580' TMD). Data re- ceived during formation leak-off tests indicate that the formation fracture pressure at the 13-3/8" casing shoe approximates a 12 ppg equivalent mud weight. Pressures' in the State "A" zone (estimated 6050' TMD) are unknown; however, considering the possibility of communi- cation between the "A" and "B" zones in the offset injection well, the operator has set'9-5/8" prOtective casing at the present depth of 6000'. The well will be drilled to total depth, estimated 'at 11,400', and will be cased with a 7" x 5600' liner consisting of 26# and 29#'N-80 and S-95 Buttress casing designed for maximum mud weights.required, and considering the appropriate design safety factors. RECEIVED FEB "" ? 1977 16. I hereby certify that the foregoing Is true and correct SIGNED . _ ., "' .... TITLE Area Superintendent DATE February 4, 1977 (This space for State office use) A PP R O V E D B Y ~' - _. IT LE~ ( ,~'-~.~,~/L . BAT E CONDITIONS OF//~ROVAL, IF ANY: A~r~ed Copy ,. R~U~d ~e InstrUctions On Reverse Side 02~)01B STATE of ALASKA DEPART~EqT OF ~ATI.!RAL RE.)OURCE~ Division of Oil and Gas Conservation TO: : Hoyl e ti Hami 1 ton :, ~:, .::\~"J"ig '£~ ']:~'~' ~li rector .,tru. Lonnie C. Smith Chief Petroleum Engin~ FROM~ Ben LeNorman Petroleum Inspector DATE ., January. 25, 1977 SUBJECT: Attempted BOPE Tests on A~oco's ~GS #18 - Platform Baker Thursday, January 20, 1977 - I departed my home at 9:30 ,q¢~i for a lO:O0 A?~ showup and 11:00 departure via A.A.I. Tv,tin Otter for Kenai. ! arrived in Kenai at 11'~n o~ A['q rented a car and proceeded to the Amoco heliport on ~ick Road where ! was informed I was to call Jim HcMaster, Amoco drilling foreman on Platform Baker. Jim advised they would most probably have to do a top cement job and BOPE tests ~ould be delayed until Saturday morning. I relayed this information to Lonnie Smith and it v~as agreed I should return to Anchorage. I departed the heliport at 12:30 PM, arriving in Kenai at l:O0 PM and returned to Anchorage via A.A.I. Twin Otter, arriving at 2:20 PH and at ~y home at 2:5(.) PM. In sum~ary: No BOPE tests were witnessed on Amoco's MGS #18 due to cementing problems delaying nippling up of the stack. 02..001B STATE of ALASKA DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO.. Di rector Thru: Lonnie C. Smith Chief Petroluem Engineer FROAA: John C. Mi 11er ~¢ iii Petroleum Engineer DATE : January 28, 1977 SUBJECT: BOPE Test at 2m~oco -17595 No.- 18 Platform Baker, Cook Inlet Frid. ay, January 21, 1977 - I traveled to Platform Baker to test BOP eqUip~nent- on A~n~oco's 17595 No. 18 drilling well.~' I traveled to Kenai by commercial aircraft departing at ll:O0 AM. I drove to the Wik Road heliport in a Hertz rented car and then flew to the platform in a company helicopter, arriving at 12:35 PM. I met the Amoco drilling foreman, Jim McMaster, and Parker Drilling Company tool pusher, Wade Pace. Jim explained that nippling up was nearly complete and testing would soon start. At 4 PM the crew had set the test plug. in the well head with a joint of drill pipe modified with a pressure gage and valved connection to allow pumping into the pipe above the rotary floor, The drill pipe safety ball type floor valve had been screwed into the bottom of the test plug in the closed position. The test plug had a port drilled above the seal so fluid pressure could be pumped from the drill 'pipe · into the space above the test plug. The kelly with lower kelly valve open and kelly cock closed was connected into the modified joint of drill pipe. The lower pipe rams and outside choke manifold valves were closed. A 3000 psig test pressure was applied using water and the BJ cementing pumps, to the floor valve, bottom pipe rams, kelly, kelly cock, and outside choke manifold valves. The lower kelly valve, top pipe rams, Swaco superchoke, choke manifold valveS, and flanges were systematically tested with several delays to tighten flange connection bolts and replace a choke manifold plug valve that was leaking. The choke line and kill line valves were tested to 3000 psig with a plug removed upstream from the check valve flapper. The plug was replaced and the check valve was also tested at 3000 psig. The hydril was tested at 2500 psig. The drill pipe was removed and the blind rams were tested at 3000 psig. BOP's were actuated by remote and master controls. The dart floor valve and valve wrench were properly located. The accumulator pressure was 2500 psig and the four N2 backup bottles were manifolded together with 2000 psig in each bottle. All other items, including housekeeping, were sari sfactory. H. Hami 1 ton Amoco 17595 No. 18 -2- January 28, lg77 The test was complete at 8:30 PM. I completed a satisfactory "Field Inspection Report". I left a copy with Jim McMaster, sent a copy to Bill Halvorson, Amoco area drilling foreman in Anchorage, and a copy is attached. I witnessed a 30 minute 1500 psig casing pressure test starting at 9:00 PM. Sa._tu_rday, January 22,.]977 I departed Platfom Baker by company helicopter at 8:48 'AM and arrived on shore at 9:00 AM. ! returned ~ Kenai in the rented car and flew to Anchorage by c~q~ercial aircraft, arriving at 10:35 AH. In smmnary: BOP equipment and drilling operations were checked on the cap'ti~ned-well and were in satisfactory condition. JilM:bJm~ Attachment Oil and Gas Conservation Commit Field Inspection Report Well/Platfm Sec~OTi~ R~W,~ M Represented byb~/t~/~'~ ?,i~,-~-~Name & NumberAf~S .~,~.?~.~ ~,' '~'~' ~,~ x,/~,,~/~ Satisfactory Yes No Item ~.~)' () (~¢ () (~) () () () () () () () () () () () () () () () () () () () Type Inspection (~' koCati on'~:~eneral 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4.' Rig ( ) Safety Valve Tests 5. SUrface-NO. Wells 6. Subsurface-No. Wells ( )Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. B~-- F~~ ( ) ',. i n a~a n--8-6-~-men t 11. P&'A M~rker Satisfactory Type Inspection Yes No Item (~)~ BOPE Tests f'~) () (~-) () (~ () (~) () (v~ () (~) () (vi () (~/~c) (v~~ () (~ () (~ () (~ () (~) 12. Water well-( )capped( )plugged (~,~t ( ) 1.3.' Clean-up (~,) ,( ) 15.13)<~"Casin.q set @ ~ 1 6. ~ fluij-(V~wtr.---~T )mud ( ) 17. Master Hyd. Control Sys.~Soo psig i 8. N2 btl s .~,~.~,'.~ ,z~o o ,~.~,,:~o ,~,,o ps i g 19. Remote Controls 20. Drilling spool- ~ "outlets ' 21. Kill Li.ne-(~ Check valve 22. Choke FlOwline ( ) HCR valve 23. Choke Manifold No, valvs~flgs/~ 24. Chokes-(v')Remote(v')Pos. (-)~A-dj 25. Test Plua-(~We~ihd( )csg( )none 26. Annul ar Preventer 27. B1 ind Rams,~m~a psia 28. Pipe Rams,~siq 29. Kelly & Kelly-cock 3or;m psig 30. LoWer Kelly valve '~e60psi ( ) ( ) 14. Pad 'leVeled (~'~ (~) 31. Safety Flo'or valves--Z-(-~BV (~Dart Total 'inspection obServation t ~ ime L~hrs/~ Total number leaks and/or equiP, failures Remarks ~-~/~ 'cc.,~l/ ~"/~'/v~/"$ot~_ Not~fyl ~.n _ days or when ready] ] Ins ected b ..~ ..i ,;'i'....,...'...~..;...']"; z;i) ...... _Da. t~.~ .~__r .'.:.~,:']_~ '-":"._'_ ._ ~' ~ DEI,IVIaR DIVISI()i',I .,.,.,--x- AI',ICilf)R,'~,.;,:: A[?'..:^ .~-x-, I0-'I0-'1/ *** COi:IPAN¥ ().PFRATE[)--DRII.LIN.:3 -DEVEL()Pi,IdNT :.,:..~-:,- ~'*. *' O 2-O4.1:.71 .t ,';iG:5 17:.595 .I,.:LL" Ilr). 13 IHC, :.~'Ii) G[?()-UN,)' b~l():~[.., t-;,",~?:(.r::~. ~ I ~.; 1 _':5.'('), II.)'iz}',l:l.' :,"12/32-02-3, AUTI,t TI) l l4,")O, 6000, A-LO [t!'tA X v,l()C,. O, SPUD 01-01-t'1, 34 9.1, 39 CLiO & C},'IT 5, aVAL 5,.' rIDXNU-11.5, COSTS I I0:.), I V4"14, AU:I.'[t I TI:/i4P 38, i-)Rt::C CLR', v~Ii',lt.) N.-IO.~ VIS '/0 P,a~-t' [:)AT'A: cC 12-3 I-'16 .,<...,, · '...D,t' . Co(.,,. ()i.) 9'.625, IU ,ti 1"";[:: SET AT. 5")83~ TOP :5, I.:)AT~: S~:':T 02-',)3-77 R,;ll<o. 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JJl, f. 06-24' I D ~i'.,IT ""' u . . v t~.7:'J2-O2-B~ A'UT}1 TU 11400, [:~);,KSt ~-~1.'31.)' IO,OI'OFT. CLE/~.J:,II.I.,h,5 F I'i>IiSH TI I'I(}L.~. 'fAt.5 ,JEA. i.i;4.i' - * ..... ~J:i: ,,.. ()t',l ~,~.zt.~.i.:S. "t4R '2(:.)()0 i..'S.I, i i~:~Ll., F()I:? 3o i tl'~. ()iCA'f.' i() 1.1():1...2, 71i JUNK'' ........... ~.);~ 1...-[);.! IL)E,i 9't2't82-02-'-1~ AUI',I 'I:'1 1.1:400, t.?,.i[.(S~ l'-)l.~. IO,~'()lO 1':'1', ,":.; ! ;. ~ (.; ~'~',.!L.L, Ii()L~. T.O it()LE. Tf I.t()Lr' X 5-7/8" ,_;['1' X LASt' 0 ST~¢,,'lt)~ T() lO,O00'F'l' ...... CII'~C lie)f;: . DP '. "D) LD Dt¢. i'U '~.tUL;; .>~t<" 9t~,S:=.&L A""''oo,.=,,;'~i.'f {)TIS HI'I3~.'L,.~· ,VI' ,-:'-i/2 TYt->,~ "~':" .,,(}t,..: SA¢I'fY. '1713(} Al' ~J053 t-T ['3'~','~ Vr}l'3,: ;.; [~t, ,'k't' . ..... ){:~'i fsi" CIVIC ~'I,zLL X SALT ¢:AI'L~ ~ -. · ** () O- d ,. ~- 1 '[ ** * ~ ;'~iO3 1'169'9 It:LL' !',IO !,3 [:?~,'?',(S: 'i~[iD l(.),O'lt)F'I', i:;b[.L Vi.¢ UP ]:() 900 t.)l.l()F ;'¢. t':Sf "t'() 2000 :';!~ IilSTALL l(()!~[i. Pi:ii.~. ()O-JO-71 *':.'-*" :: CU,,U. LA'I.'IVis l~,.:.i-)!)l~'l' C(}' i)I,."L-L)..:V X.-i,! SP~ $2,2~2,()00 ,,I0o I"15'~:5 4i.:-LL J.i'(). 1'3, ;iI[)L)J.izL !JP, FD S[[()AI,~ ,,.;~:.~,,,,., ':.ti',..'; I Di':J:'i'f >>'12-I~J2-02-3, AJ.[ it 'FiD '114.0C), J)l.?'l.-i)i'"V, Ri.i I,','o ~ ~-'.i.;.D 1 d, O1 0 F'i". ~.~ '.[.i:~ ?.',K; .. I 50, *** 07' 13' 7 l*;w¢ ALJ"I.'['t.. T I::.) !" 14 ~':':)(]), 't.)R l..-..)i .J V, I.:' I G 1 [5 C:,, 07-14' 7./'?~, ...... ,, ,?~ .. ' ' 1'/595 ,~.::tl t.[() · 1'.' '"" ' : ....... ~,, :~,.'tI ,..,l.)I...h !:3[~'I.:[) 5i t'().AI.. DH'I'.Ti'-2":°1~_ ..../o,:_-O,,--o"u'-) "~, AU'f[.{ TD 114:)0,.. : I?iSD:. 1(),O 10 'FT, ~ P,,.il-~ l',l(~. (..) '1- l 5' 'I"/* ** ': ti.lOS 171595 ;~'hI..L' HI). l.l:.~, ~ I'Dd i :!'T ';.,. 7 2':1 i3 2-02 -.3, '1.~ti(35: l-~i~.[): !0,01 A[J'I':i:'J 'l'[) ] I 4:")(') ~ "~r~[.-.;;i '7. ~ P 'ii:' i',kJ, l .,:')01:~ ,,iA iLL I.~o I '{.:} (), tlI(.~ 15!), I 0'7-,'21 - 77* .,'~';'~ ',: " '." ',?,;n L~',!~.:'.,','"~ l-tit3 1;.~OS 17595 ;.lEU, N'r).., 1.ti', r,~'I....OL)L,.:: 5,~,,, Si'IOAI.~.. , ,,,~,,,,..,, , ~ D H NT 9 7 2 7 ;3 2- 0 2- 3. A o'fi:'l T i3 . I 1 4 ,),. ~ ,), ~ L-, ).,.:: ¢ ~ ~,. 7-25- 7:1' ** -2.0 -'/'/ ..........,, ,., I ;...; I ()i':l .[)izTA I L Ci iA HG,.z L;.'71'i) L);,:: o': 17595 I [)hl.Tf" ?"/21~:t2-02-3 Pi4E$~ ?t3'D 10~O10'FT.' 'P;..iF 14O.- T()"F,.'~L cOS'l' "i7(} [)AFL: ~2,225, OOO' lOt..?.ff 9121.32-t)2-'3, AU"I'H R/...1K L~: P }..~ D t u ,. ,J 1 O F '_r. P ?.117 ?,1 w * * O 'l - 2 9.- ~ i ':," >* ., 11~ ,,IGU 1-i39'.~. ,;,.:l.l.. Ik). .1 ~,~.;I!;')I.. It)~:IJT '-.,' 121G2-02-3, .,.'~.U'i'l'l .l:il~Ko* I-:'BD 1O,OlO FTi Pqi,-' -,,','** O,5-t~ 1-'71 .. II~. ;.,..V3.5 175.95 ,,t.::!..L N(). id, ;...{IDL)Ld :..;I-~i,.:D Si{().AI.., PAl:.ii(.,.:i.e RI(3 lb(.), fUEl,ri' v'/2./J2-02-3, AL/Ti'{ TL) :ll40U, [~3..'11<:5 ,~' :'"."Mr ,..,._, I..o, :.)10 F: f. 24--F11-',~'.'"'i o"i' :"' 7 W4 3,1t"' 1".), I '30;; ' ,.I.A i:L::J-?"~ 1 0©0 _Jim(Jr"{.) AT 3300 i-'S.I~ 31 3Pi.il. l:SO.O PSI LSH. * * ,;,' 00 - O. 2 - 77 ** * c"' ,, ~) t,"'. i ", :) (" '~';;C3S 17595 ,~.,'"-I._L~'~'"")'.,,. . 1,3, I.[II:.i)DLE OR;"',I[) ol"'l(.),\.L,~ ~..AR:x.L:Jl r,t,.: 15L) t 3.', .WGS 1759:5. ~,~dLl. t",,V). 1,!3, /'.,{ID,_)Lu. 'OI?I"ZD o}i,)AL, .}i.,.L...L:f'.~ R'IG 150, I DL.:}tT '-2'"l,_:. ':~ -'/,..,2-02-.3:"', :'\UTI'l. TI)'.. 1.'.i 4-00:, ,]LL.-...)i.' V, ?:,~: ' ,',. :o,,.' 010 FT ' "' ~' . .R.t,'I L S: t ~:~ U 10, · t'),.'I,' 1',,~ O. · "~ ' T()TAL <:r)ST To).[)ATE. S2, .... .,:.:o,,000 *** ' 08',:)5-7'1.i:,'* · bIOS 175'95 ,I.ELL ;i).. I , . '"(' !3 ;,t.l:.i]t..)L't.i:. ORL~D $tt()AL, P;\[?K it~"l:~IO 150, I Dt.:~NT" .9 727;32-02-3, AUi"H TL)..l 1400~, DI'?.L-J;)i:~V, , ,,..¢. 010 FT. P~!'I.~ ['¢'d Ri',~Ko, 't?[:iD I O, .... ) I O EN I' 272732-02-:3, . A U'ft't TD 114(')0., I:)F~ L'~ i..)1: V, '"'.5 P 01 O FT t'-~,',ii~ [,IG R~..,i,: [3i.J 10, . . _ ;.'26 0'('~0 T()I'AJL C()'ST T() DA]'i-;: s2~ _ ;.I.GO 1'759-5 ~.i?'L !to) i.3, ]:lJdt.[l' ,,' 127,.;2-O2-3, I ~ ~'," e · )'r'~ R, !l.,o · 'i o, . l- .~U 'JlO FT ;'~" l',IO6 1'}'5':)5 ,~':LL H() liB, R rJ K"" ' w.,w? (..) :.'~- 1.6- / /.A-.-;:~.e I'DEi~'~T 9727[J2-02-3 ~ AU:'ft,I T'D I 1.400 I'?~',KS:. t-~20 I0 ~)10 FT" ee ,':* 0 ~',-" I 7-'17 '",,., .... .' CUfIULA'fI I'?~-.:P()l,.'f C()- -i.)I,~L-I. Ji:~V Ai ~C}.I() R ,:'",.5 c UI'ITI L F:UR'fili~!~ W()RK. ,.;~--i- 09-0 I -77 ~:'~.* TI) P'EI~'I' OATA; ~C 12-31-"fo, !.(d I..).4, RIG l.?r'I..;.-._A$...:U O6-23-t'7, C5,J.': ()L) '7, 5i::T AT 1o107,. l'()~-~ 05'/10. OR'I'd 5,.:'I' 03-'1 /-.77 R,.;KS'. TI) 10;231 FT i.~lSt. J' !0,()10' FT, Tills ,.i£LL ;.'t:5 D[~r.)?I-'L:L) FI~'<)?~ "fill ~.Ir?~_: [)~I C'():~.ll:'I.,~f'[._:D AS A I_)RY i-l()Ll:! I..[',l TI. IE l_.i:tR. K~2i',!AI 9- 1-7'/. SURF.. L()C: L..,.._'(~ i , SL~)"f' 3, ~d.5,.'VI'F()i.~ [JA.I(F~.~, 1930 t:..:L'~ 539 }::WL, S.i._"C'. 3.1, .T'.)i",.[., I~.1:.-_~'~, [3ii'L: 1924 Fi/L, i6'~"t.I':'~L,..$~JC. 3~)~ fg;t', I.~1."..,, '.2_4 i'll:? T:b'f = ' ['1-3 !-7'? ] 0 B()I°L)~ I 005 i.5.'li-~J.), O. ".iCi':}) SS: ,.,, ,i 1007~; 'd/l(()?3r," F?'Ii~" i ('.)i'.),'.) Bi.>()pO Alt ,.~.3..)0 i-'~'.3'I, , LS F? I .i.~.J (,) i-~ 51. /dELL ~]I!.L ;315Z KkP"F II'-i A SI.tUT-IN S'l"/'lT:tJ5 'F()R. ,5. i.~ ~ ? a R I ()D. t,'I(30C': . 0(,01 1'2-3.1-7o RIG R.EL= 2490 3-2.4- (,.)C.::':~AOA't H :,:..F:~, fi,i!' -' S OUEtE"E~i~'.','..'J; O,:D ':.~ :.',,,~,~, 2'~.~)0.:t '~: :. 5'-' 1':5:,~-.~7.;:t',''~ .'~:.':.-. i.;:!..:I','3 Amoco ~'roduction Compa: SCOUT TICKET s~-T~'lc(~'u'n'tY I .. uniqu. COUNTY STATE . PARISH __ AREA __ FIELD BLOCK SECTION TWP COMPANY___._A}.JO_~_O__P_RODUCTION CO~{PANY SURVEY RANGE AFE NO. & TYPE_ WELL NO:' 18 LOCATION FEET FROM LINE: N E S DATE SPUDDED DATE COMRLETED PFS CH. PFS CH CASING: OTHER PROPOSED DEPTH GOR GOR IP · --IP WITH, WITH WITH , ELEV TD _ GTY GTY .SX SX SX wl J--1 OWWO i O,FSET W, [] AFE OFFSET' Ri IMP PROPERTY NO. QTR MAP NO. SAMPLE TOPS FORMATION DEPTH FORMAT!ON ELECTRIC LOG TOPS DEPTH OPERATOR PAN AM INITIAL REPORT FLAC #9727827, AP1 '#50,133'20296 1-3-77 MGS i7595 Well No. 18 Inc. Middle Ground Shoal Platform Baker, Leg 1, Slot 3, 1936' FNL, 539' FWL, Sec. 31, T9N, R12W, S.M. TD 650, opening 17-1/2" hole to 26", 0'0-116'297, clay and coal, 2, 11,400. Mud 9, 39, 20, 9, 7, 18, 10/32, 4, 825, 180, 0. , , NC, 18, 22, 0, desand 9, 13.9, 3.3. PP 500., 741, 1, 65, 7x8x95, 7x8x95. Bit 1, 17-1/2, OSC3A, 3-20, 650, 396, 24, 16.5, 10-15, 70-90,-3E/~-I. 2, 22", K2P, open, no drlg time, just gauge run. I{.O. 1, 26", security hole opener, 159, 5, 31.8. Survey 364, 1-3/4, N5E; 395, 2, N; 457, 2, N12W; 550, 2-1/2, N10E; 626, 2-3/4, N] BHA 17-1/2" bit, 26" hole opener, bit sub, 3 steel D.C., xo, 50,000#. 1)rlg 24, trip 6-1/2, survey 3-1/2, circ 3, other 21-1/2, RURT 19-1/2. Rig OC 0001 hrs 12-31-76, spud 1030 hrs 1-1-77, elev 79.4', 30~', 266', 7-19-65. Mud'cost 0-$778-$3567-$541, $4886. Rig OC 0001, 12-31-76, skid rig to leg 1 slot 3, RURT x mix mud. Displace well x bit at 254', drlg junk at 254-258 x 17-1/2" bit x 26" H.O, TO x remove H.O. x TI x 17zl/2" bit. Drlg x work past junk from 258'-293'. TO x LD 17-1/2" bit, PU 22" bit x TI to 293'. TO x LD 22" bit. TI x 17-1/2" bit-x 26" hole opener. Drlg junk at 258', TI to 293'. TO x LD tt.0. TI x jetting assy. 1 hr jet x drl to 327', 1 hr circ, 1/2 survey at 281', drlg junk at 323','TO x inspect B}-IA. TI x dr±g on junk. Survey at 333', drlg, survey, TO', PU BHA '~ ' ~!'~ ~' I 7 t ,/'"" t~1,, ~ , '~'"'" ANCHORAGE AREA MGS 17595 WEKK NO. 18 PAGE 2 1-4-77 1-5-77 1-6-77 1-7-77 MGS 17595 Well No. 18 Inc. TD 650' , coal-clay, 3 , running 20" csg, open 228' · Mud 9..1, 39, 20, 8.5, 6, 23, 8/28, 5, 6500, 160, O. , 19.5, 21.5, 0., desander 9.1, 13.4, 2.7. PP 5 0, 741, HoO· 1, 21, 7x8x95, 7xSx95. · 26" Security hole opener, 0-0-28, 650, 387, 14-1/?, 26.6, 5/15, 70, H.O 1, , - good condition· BtLt same, 50,000#. Drlg 9-1/2, trip 2, circ 2, csg x cmt 8-1/2, other 2. Mud cost $105, $4991. Finish opening 17-1/2" to 26" hole to 650'. Circ,.trip to 30" piling, circ x cond hole .for csg. TO x LD H.O., RU to run 20" csg. .Run 20" csg. x stopped x 294', worked × washed for 40' x freed up, trouble x make-up on several j ts, continue running 20" csg. MGS 17595 Well No. 18 Inc. (PDC Rig 150, Baroid, Amoco 25PC) Total cost to date $227,000. TD 650 ' · , cut off 20" csg, , , 4, 11,400 .Trip 1-1/2, circ 1, csg x cmt 5-1/2, WOC 6, log 3-1/2, other 6-1/2. Mud cost $O, $4991. 20" csa 621' 1-4-77 Finish running 20" csg to 621' RDB, TI x DP x stinger x Stab into shoe· Circ, mix x pmp 900 sx Class G + 2% prehydrated gel, 13.5 ppg, lost returns after 900 sx. Mix x pmp 500 sx Class G + 3% CaCt2, 15.8 ppg, no returns. CIP x 1330 hrs, 1-4-77, floats held. Unsting from shoe, TO × DP, ND x cut 30" riser x flowline. WO.C x install BJ liquid additive tank. Run temp survey x misrun, run CBL x found cmt top x 298', ND x cut off 20" csg. MGS 17595 Well No'. 18 Inc. TD 650', rig rel for comp, , , ~5. Other 6.. Mud cost $0, $4991. Suspended date 1200 hrs, 1-5-77, RREL. ND x cut off 20" csg'x remove 30" riser. RD x skid rig to MGS Well No. 9 RD 2 for comp· MGS 1175.95 Well No. 18 Inc. TD 650' RREL for comp, , , 6. , SuspcndCd date 1200 hfs, 1-5-77, R[~EL. ANCtlORAGE AREA MGS 17595 WELL NO. 18 PAGE 3 1-10-77 1-11-77 1-12-77 MGS 17595 Well No. 18 Inc. TD 650' drlg 20" shoe., , , 6 , Mud 9.1, 40, filtered seawtr. Bit iR, 17-1/2, OSC3AJ, 3-20, Inc-drl float shoe ,x cmt. Btbk bit, bit sub, three 8" DC, XO, 2 jts HWDP, Dailey jars, HWDP. Drlg 2-1/2, trip 1/2, circ 1, other 32. Mud cost $0, $0, $4991. Resumed date 1800 hrs, 1-8-77. Skid rig x RURT, TI x 17-1/2" bit, circ x 618' drl 20" shoe x cmt , MGS 17595 Well No, 18 Inc. TD 850', drlg, 200, gumbo-coal-sh, 7. Mud 9, 36, 28, 7, 6, 14, 11/31, 4, 7500, 200, 0~ , , , ].5, 25, 0, desander 9,.13.7, 2.2, desilter 9, 10.1, 15. ~ PP 700, 507, 2, 96, 7x8x70, 7x8x70. Bit 2, 12-1/4, MX3A, 3-20, 752, 102, ~2, 51, 5-15, 90-100. Bit 2R, 12-1/4, MX3A, 3-20, 834, 82, 6-1/2, ~12.6, 8-10, dynadrl. Bit 2R, 12-1/4, MX3A, 3-20, Inc, 16, 1/2, 32, 5-15, 90-100. Surveys 724, 3-1/4, N6E; 764, 3-1/2, N13W; 794, 4, N; 851, 4, N26W. BIN bit, 12-1/4" stab, 2 monel DC, 1 steel DC, 12-1/4"'stab, 2 steel DC, XO, 2 jts ltWDP, Dailey jars, 20 jts HWDP, 70,000#. Drlg 11, trip 10, survey 2, other 1. Mud costs $105, $5096. Drl cmt x fill to 650', drl 2' new hole to 652', TO x run. magnet for junk x rec double handful of small pieces of junk x metal. PU BHA x TI, drl~to 752', circ x survey x 724', TO for dynadrl, TI x orient tool x dynadr! 752-834', trip for bit, ream dynadrl run 7522834', drlg. MGS 17595 Well No ' 18 Inc. (PDC Rig 150, Baroid, Amoco 25 PC) Total Cost to Date $324,281. TD 1813' survey 963 gumbo-coal, 8, 11,400 Mud 9.1, 35, 30, 7, 6, 18, 11/30, 5, 6750, 200, 0. , , , 16 5, 31.5, 0, desander 9.1, 14.2, 2.5, desilter~9.1, 10.9, 15. PP 2000, 5~6, 3, 96, 7x8x70, 7x8x70. ~ Bit 2R, 12-1/4, MX3A, 3-20, 1721, 887, i3, 68.2, 35-40, 80-100, 3-5-0, 1/4" under. (total bit run 1071', 21-1/2 hfs, 49.8 FPH) Bit 3, 12-1/4, DS, 3-13, Inc, 92, 1-]./2, 61.3, 30, 75, Inc. Surveys 851, 4, N26W; 937, 4-3/'4, N27W; 1091, 6-1/4, N21W; 128.1, 7-1/2, NllW; 1471, 9-3/4, N12W; 1691, 13-1/2, N4E; 1783, 14-1/4, N7E. Bt~ same, 72,000#. Drlg 14, trip 2-1/2, rig rep 1/2, survey 6-1/2, circ 1/2. Mud costs $267, $5363. Drl, circ x survey x 851', drl, survey x 937', drl, survey x 1091' , drlg, survey x 1281', drl, survey x 1471', drl, survey x 1691'., TO x change out stab sleeve No. 2 x change bits, slip drlg line, TI x ream 70' to btm, drl, survey x 1783'. ANCHORAGE AREA MGS 17595 WELL NO. 18 PAGE 4 1-13-77 1-14-77 MGS 17595 Well No~ 18 Inc. TD 2525', dynadrlg, 712, sn-coal, 9. Mud 9.1, 34, 31, 7, 5, 15, 10/26, 5, 8000, 200, 0. , 15, 38, 0, desander 9.1, 13.8, 2.5, desilter 9.1, 10.7, 10. PP 900, 406, 4, 71, 7x8x52, 7x8x52. Bit 3, 12-1/4, DS, 3-13, 2376, 655, 10, 65.5, 35/45, 65/75, 3-4-0, 1/8" under. Bit 4, 12-1/4, ~fX3A, 3-20, Inc, 149, 4, 37.2, 10, , dynadrl run No. 2- Inc. Surveys 1941, 17-1/2, N8E; 2096, 20-1/2, N12E; 2220, 23-1/4, NilE; 2346, 25~3/4, N14E. BtLA bit, dynadrl 20.60 x 7-3/4 x 1-3/4,.1-1/20 bent sub 1.20 x 7-3/4 x 1-3/4, XO 2.87 x 7-5/8 x 2-7/8, 2 monel DC 54.05 x 8 x 3, XO 2.08 x 7-5/8 x 2-7/8, 2 jts HWDP 61.13 x 5 x 3, Dailey jars 34.10 x 6-1/4 x 2-1'/4, 20 jts HWDP 609.77 x 5 x 3, 75,000#. Drlg 12-1/2, trip 2, survey 7-1/2, circ 1/2, other 1-1/2. Mud costs $105, $5468. Survey x 1783', drl, circ x survey x 1941', drl, survey x 2096', drl, survey x 2220', drl, survey x 2346', slug pipe x TO. . Change BHA x PU dynadrl, TI x orient tool, dynadrl, survey'x 2403' dynadrl survey x 2433' dynadrl , , , , survey x 2463' dynadrlg , · MGS 17595 Well No. 18 Inc. TD 3067', drlg, 542, sn-coal, 10. Mud 9.1, 34, 7.5, 5, 19, 10/30, 5, 7750, 280, 0. , , , 15 33, 0 desander 9.1, 14.4, 4.3, desilter 9.1, 10.2, 10. PP 2000, 5~6, 5, ~5, 7x8xT0, 7x8xT0 Bit 4, 12-1/4, P~3A, 3-20, 2587, 211, 6-1/2, 32.5, 10, DD, 3-3-0, 1/8" under - dynadrl No. 2. Bit 5, 12-1/4, SDS, 3-13, Inc, 480, 8-1/2, 56.5, 30, 80, Inc. Surveys 2598, 25, N; 2724, 26-3/4, N2E; 2881, 30, N3E. B}~ bit, 12-1/4" stab 4.07 x 8 x 2-7/8, 2 monel'DC 54.05 x 8 x 3, 1 steel DC 31.22 x 7-7/8 x 2-7/8, 12-1/4" stab 5.60 x 7-7/8 x 2-7/8, 2 steel DC 62.13 x 7-7/8 x 3'3/8, XO 2.08~ x 7-5/8 x 2-7/8, 2 jts HWDP 61.13 x 5 x 3, Dailey jars 34.10 x 6-1/4 x 2-1/4, 20 its HWDP 609.77 x 5 x 3, 80,000#. Drlg 11, trip 3-1/2, rig rep 1-1/2, survey 6-1/2, other 1-1/2. Mud costs $237, $5705. Survey x 2463', dynadrl, survey x 2512', dynadrl, survey x 2542', TO x LD dynadrl x PU BtLA. TI x ream dynadrl run 2376-2587', drl, survey x 2598', drl, survey x 2724', drl, survey x 2881', drl. Mud pmps down 1-1/2 hr, fuel. ANCHORAGE AREA MGS 17595 WELL NO. 18 PAGE 5 1-17-77 1-18-77 1-19-77 bIGS 17595 Well No. 18 Inc. TD 3529' open hole to 17-1/2" at 2810' 462 (1185, 975, open hole) sn-coal, 13 Mud 9.2, 34, 38,-7, 6, 15, 11/30, 6, 8250, 300, O.~~ .~ , 16.5, 37.5, 0, desander 9.2, 13.5, 2.75, desilter 9 2, 10 2, 10. PP 500, 546, ti.O. 2, 45, 7x8x70, 7x8x70. Bit 5, 12-1/4, SDS, 3-13, 3097, 510, 9,. 56.6, 30, 80, 5-4-0, 1/4,' under. Bit 6, 12-1/4, .S33S, 3-13, 3529, 432, 13, 33 2, 40, 80, 6-5-0, 1/4" under· Bit tt.O. 1, 17-1/2, Grant, open, 2034, 1384, 22, 62'.9, 20, 100, 3-4-1, Bit H.O. 2, 17-1/2, Grant, open, Inc, 776, 14, 55.4, 20, 100, Inc. Surveys 3067, 31-3/4, N; 3251, 35-1/4, N; 3499, 41-1/2, N3E. B~ bull~ nose 2' 17~1/2'' H.O. 3 80' bit sub 2 87' 3 Steel Dc 93 35' xo 80' , · , , , , , · , 17-1/2" stab 6.10', XO 2.08', 2 its HWDP 61.13', Dailey jars 33.90', 20 jts HWDP 609.77', 75,000#. Drlg 49-1/2, trip 11, rig rep 2, survey 2-1/2, circ 1,1/2, other 5-1/2. Mud costs $105, $156, $267; $6233. Drl, circ x survey x 3067' T© x change BHA, slip drlg line, TI, ream 3050-3097' drl, survey x 3251' drl, tighten Kelly swivel, drl, circ x survey x 3499'. TO x LD BItA x PU 1711/2'' H.O., TI to 622', open 12-1/4". hole to 17-1/2" to 672', hit boulder. TO x LD 17-1/2"~ stab x ck cutter's, ok. TI x H.O., oPen hole to 2034', circ, TO for new H.O. Change x strap bull nose x H.O., PU 17-1/2" stab, change out jars, cut drlg line,' TI x ream 700-800' open hole MGS 17595 Well No. 18 Inc. TD 3529, open hole to 17-1/2" at 3366', 556 (open hole), Sn-coal, 14. Mud 9.2, 34, 38, 7, 5, 15, 10/28, 6, 8500, 300, 0.. , , , 16.5, 37.5, 0, desander 9.2, 14.2, 1.76, desilter 9.2, 10.1, 6. PP 700, 546, H.O. 1, 45, 7x8x70, 7x8x70. H.O. 2, 17-1/2, Grant, open, 2949, 915, 19, 48.1, 12, 100, 3-6-1. H.O. 1, 17-1/2, Grant, open, Inc, 417, 13, :32, 25, 100, Inc. B}~ bull nose 2, 17-1/2" HO 3.80, bit sub 2.87, 3 steel DC 93.~5, XO .80, 17-1/2" stab 6.10, 3 steel DC 92.89, XO 2.08, 2 jts hS~DP 61.13, Dailey jars 33.90, 20 jts HWDP 609.77, 90,000#. Drlg 18, trip 3-1/2, circ 1/2, other 2. Mud costs $243, $6476. Continue open 12-1/4" hole to 17-1/2", circ, TO, change H.O. x bull nose, PU 3 steel DC, TI x ream 2890-2949', open hole. MGS 17595 Well No. 18 Inc. (PDC Rig 150, Baroid, Amoco 25PC) Total cost to date $559,000. TD 3529', run 13-3/8" csg, 154' (open hole), sn-sh, 15, 11,400. Mud 9.2, 33, 39, 7, 5, 15, 8, 26, 6, 8500, 300, ~0, , , , 15, 39, 0,. desander x desilter off. PP 700, 546, H.O. 6B, 45, 7x8x70, 7xSx70. Bit 6B 17-1/2", Grant H.O., open, 3520, 571, 23, , 25, 100, 3-7-1. BHA same, 95,000#. Drlg 10, trip 7, circ 3, csg x cmt 3, other 1. Mud costs $818, $7294. Open hole 12-1/4" ~to 17-1/2" to 3520', circ hole cleam, short trip x first 13 stnds tight, circ hole clean, TO x LD stab x H.O. PU DP x stand back in derrick for inner string cmt job. RU x run 13-3/8" csg. 1-20-77 1-21-77 1-24-77 MGS 17595 Well No. 18 Inc. TD 3529', WOC, , , 16. Mud 9.1, 30, 46, 7, 4, 9, 7/16, 5, 6250, 280, 0. , , , 13.5, 31.5'. Csg x cmt 18, WOC 6. Mud cost $105, $7399. Run 86 its of 13-3/8", 61# x 68# K-55 Buttress csg. Land at approx. 3500'. Cmt x 1500 sx Class G cmt + .23 gal/sx Lodense. Lost returns after pumping 1500 sx. Tail in x 300 sx Class G neat. Mix at 16.0-17.0#/gal. No returns while pmp. CIP 2130 hrs, 1-17-77. Float's held. WOC. MGS 17595 Well No. 18 Inc. TD 3529', NU BOP's, , , 17. WOC 3, other 21. Mud costs $105, $7504. 13-3/8" csa 3501', 1-19-77. WOC, RU Dresser'x run temp survey x Eastman gyro survey, indicated cmt top 382'. PU 20" riser x Hydril x set 13-3./8" hanger. ND 20" riser x Hydril, install 20" x 12" spool x tst x 2000 psi, ok NU 12" 3000# BOP's x riser. · , MGS 17595 Well NO. 18 Inc. TD 4332' survey, 0-295-408, sn-sh-coal, 20. Mud 8.9, 39, 14, 9, 10, 10, 5/12, 4, 625, 40, O. 2/32, 175, 42, 15, 23, 0, desander 9, 12.2, 2, Sweco operating. PP~2100, 465, 9, 87, 6xSx88, 6x8x88. Bit 7, 12-1/4, SDGH, 13-20-20, 3529, 110, 5-1/2, 20, 10-15, 50, 8-8,1, drl cmt, float x shoe. Bit 8, 12-1/4., SDS, 3-12, 3859, 330, 9-1/2, 36, 40, 80, 6'2-0, 1/8" ont, pull for B~A. Bit 9, 12-1/4, S3, 3-12, Inc, 473, 12-1/2, 38, 35-40, 85-110, Inc. Surveys 3626, 41, N6E; 3815, 46-1/2, N6E; 3847, 46-1/4, N6E; 3973, 46-1/2, N7E; 4130, 47-1/4, N8E; 4289, 48-3/4,~N9E' Bt~ bit, 12-1/4" stab, lead collar, monel DC, 12-1/4" stab, monel DC, 12-1/4" stab, 6 steel DC, XO, 2 jts HWDP, Dailey ]ars, 18 j'ts HWDP, 100,000#. Drlg 27-1/2, trip.15-1/2, rig rep 1, survey 4-1/2, circ 5-1/2, other 18. Mud costs $1550, $1454, $805; $11,313. 1-25-77 1-26-77 MGS ].7595 Well No. ~18 Inc. TD 4550', drlg, 218, sn-sh-coal, 21. Mud 9, 40, 14, 9, 11, 13, 5/20, 4, 625, 40, 0. 2/32, 175, 42, 15, 30, O, desander 9.2, 12.8, 2.25, Sweco 'running. PP 2100, 465, 10R, 87, 6xSx88, 6xSx88. Bit 9, 12-1/4, S3, 3-12, 4332, 473, 12-1/2, 38, 35-40, 85-110, 4-5-0, 1/8" out. Bit 10, 12-1/4, $3, 3-12, 4506, 174, 5, 34.8, 40, 80, 2-2-1, pull for BHA. Surveys 4415, 45-1/4, N10E; 4476, 43,~ N10E. BHA bit, 12-1/4" stab 4.07 x 8 x 2-7/8, lead collar 9.20 x 7-3/4 x 2-7/8, 12-1/4" stab 5.60 x 7-7/8 x 2-7/8, monel DC 29.68 x 8 x 2-7./8, 12-1/4" stab 4.60 x 7-3/4 x 3, monel DC 24.37 x 7-3/4 x 3, 6 steel DC 187.22 x 7-5/8 x 2-7/8, XO 2.08 x 7-5/8 x 2-7/8, 2 its HWDP 63.00 x 5 x 3, Dailey jars 33.90 x 6-1/4 x 2-1/4, 18 its ~P 546.71 x 5 x 3, 103,000#. ' Drlg 6-1/2, trip 7-1/2, rig rep 1, survey 2-1/2, circ 1/2, csg x cmt 3-1/2, other 2'1/2. Mud costs $744, $12,057. Finish survey x 4289', circ, TO to 13-3/8" shoe, tst fm x held 11.0 ppg equivalent mud wt, bled to 10.2 ppg equivalent when .SI. TO, tst 13-3/8" x 20" annulus x took fluid, cmt x 80 sx neat Class G, 16.5 ppg, disp x 150 psi x 1-i/2 BPM x 100 psi final pr, slip line, TI, drl, survey x 4415' drl, survey x 4476' TO x change BHA. TI, slip drlg line, finish TI x drlg MGS 17595 Well No.' 18 Inc. (PDC Rig 150, Baroid, Amoco 25PC) Total cost to date $719,00'0. TD 4990', drlg, 440, sn-sh-coal, 22, 11,400. Mud 9, 38, 10.2, 9, 12, 10, 2/17, 4, 660, Tr, 0. 2/32, 175, 17, 15, 30, 0, desander 9.2, 12.8, 2.4, desilter 9, 11.8, 8.5. PP 2100, 465, 11, 87, 6x8x88, 6x8x88. Bit 10R, 12-1/4, S3S, 3-12, 4800, 294, 12, 24.5, 45, 85, 5-7-0, 1/4" out. Bit 11, 12-1/4, SDS, 3-12, Inc, 190, 5-1/2, 34.5, 50, 90, Inc. Surveys 4567, 42-1/4, N10E; 4724, 42-3/4, N12E; 4907, 42-1/4, N12E.. BHA same, 106,000#. Drlg 16, ~trip 3-1/2, survey 3, other 1-i/2. Mud costs $1033, $13,090. Drl 12-1/4" directional hole to 4800', TO x change stab sleeve, TI x ream 70' to btm. Drl x survey to 4990'. 1-27-77 1-28-77 MGS 17595 Well No. 18 Inc· TD 5111', trip, 121, an-ah-coal, 23. Mud 9, 40, 10.2, 9, 12, 13, 3/17, 4, 660, Tr, 0. 2/32, 175, 17, 15, 30, 0, desander, desilter. PP 1000, 400, 12, 75, 6x8x75, 6x8x75. Bit 11, 12-1/4, SDS, 3-12, 5111, 311, 8-1/2, 36.6, 50, 90, 6-2-0-1/4, pull for dynadrl.. · Bit 12, 12-1/4, SDGH, 3-20,/5111,/0, attempt to dynadrl x stalled out x pinched bit. · Bit 13, 12-1/4, SDGH, 3-2 Inc, TI x turbodrl. Survey 5065, 37-1/2, N13E.' B}tA bit:, b±t sub, 6-3/4" turbodrl, 1-1/2°' bent'suB, ×0 sub, 2 monels, 3 XO, 2 its lg4Dl:', jars, 18 .]'TS HWI)P, string ~t 98,000¥~. Drlg 3, tr-[p 6-1/2, rig rep 1, survey 2, circ 1, other 10-1/2. Mud cost $1093, $14,182. Drl 12-1/4" hole to 5111' x circ x survey x TO to PU dynadrl~ ~o turn hole lef't x build angle. PU dynadrl x TI x orient x attempt to dynadrl. TO x dyna- drl x found dump valve stuck x bad bottom bearing. WO turbodrl from Anna x TI x turbodrl. MGS 17595 Well No. 18 Inc. TD 5178' survey 67 an-ah-coal, 24 , , , · Mud 9, 40, 11.2, 8.5, 13, 12, 2/15, 4, 660, Tr, O. 2/32, 175, 15, 15,~30, 0, desander 9.2, 12.4, 2.5, desilter 9.1, 11.8, 3. PP 1750, 501, 14, 94, 6x8x95, 6xSx95. Bit 12, '12-1/4, SDGH, 3-20, 5111, 0, 4-1/2, 0, 5/15, dynadrl, 0-4-0-1/16"- pinched, dynadrl run No. 3. Bit 13, 12-1/4, SDGH, 3-20, 5139, 28, 6, 4.6, 5/15, turbo, 5-7-0, 1/4" out- turbodrl run No. 1. Bit 14, 12-1/4, SDGH, 20-20-14, Inc, 39, 3-1/2, 11.1, 6/8, turbo, Inc- turbodrl run No. 2. B~bi bit, bit sub, turbodrl, 1-1/2° bent sub, bit sub, 2 monel DC's, xO, ~2 jts HWDP, Dailey jars, 18 jts HWDP, 98,000f/. Drlg 9-1/2, trip 5, rig rep 1/2, survey 1-1/2, other 7-1/2. Mud costs $4.41, $14,622. TI x turbodrl, ream 120' to btm, orient tool x turbodrl, survey, TO x change BHA, slip drlg line, TI x turbodrl x ream 30' to btm, orient tool x turbo- drl to 5178' survey , 1-31-77 MGS 17595 Well No. 18 Inc. TD 5688' trip 225-192-63, sn-sh-cgal, 27 , , · Mud 9, 41, 11.5, 7, 14', 14, 4/16, 5, 525, 45, 0. 2/32, 175, 26, 16.5, 28.5, 0, desander 9.1, 13.4, 3.3, desilter 9.1, 10, 12; PP 1700, 502~, 18, 87, 6x8x95,~ 6x8x95. Bit 14, 12-1/4, SDGH, 20-20-14, 5179, 40, 5-1/2, 7.2, 6-8, turbo, 7-8-0, 5/8" out - turbodrl No, 4. Bit 15, 12-1/4, SDGH, 3-12, 5433, 254, 10-1/2, 24.2, 45-50, 80-90, 6-2-0, 1/4" OUt · Bit 16, 12-1/4, SDGH, 12-13-13, 5583, 150, 3-1/2, 42.8, 50-80, 2-2-I, pull for turbodrl. Bit 17, 12-1/4, MX1G, 3-20, 5625, 42, 4, 10'.5, 4-10, turbo, 7-8-0, 5/8" out- turbodrl No. 5. Bit 18, 12-1/4, S13G, 3-20, 5688, '63, 5-1/2, 11.4, 4-10, turbo, 4-8-0, 1/8" out- turbodrl No. 6. Bit 16R, 12-1/4, SDGH, 12-12-13, Inc- TI. Surveys 5137, 37, NllE; 5187, 36-3/4, NilE; 5315, 38-1/4, N8E; 5387, 38-3/4, NgE; 5538, 39-3/4, N12E; 5626, 39, N7E. BHA bit, 12-1/4" stab 4.07 x 8 x 2-7/8, 2 monel DC 54.05 x 8 x 2-7/8, 2 steel DC 62.17 x 7-7/8 x 2-7/8, 12-1/4" stab 5.10 x 7-3/4 x 3, steel DC 31.18 x 7-7/8 x 3-3/8, 12-1/4" stab 5.60 x 7-7/8 x 2-7/8, 3 steel DC 93.87 x 7-9/16 x 2-7/8, XO 2.08 x 7-5/8~x 2-7/8, 2 its HWDP 63,0 x 5 x 3, Dailey jars 33.50 x 6-1/4 x 2-1/4, 18 its HWDP 546.71 x 5 x 3. Drlg 25-1/2, trip 19, rig rep 1, surveys 14, circ '1, other 11-1/2. Mud costs $579, $946; $986; $17,133. Turbodrl x survey to 5179', TO x LD.turbodrl, change BHA x TI, ream 68' to btm, drl x survey to 5433', TO x change BHA, TI x ream 100' to btm, drl to '5583', TO x PU turbodrl x ck out same, TI, turbodrl x survey to 5688', TO x change B~L~, TI. 2-2-77 2-3-77 , 2-4-77 MGS 17595 Well No.~18 Inc. (PDC Rig 150, Baroid, Amoco 25PC) Total cost to date $858,000. TD 6000', logging, , , 29, 11,400. Mud 9.1, 38, 13, 7, 13, 11, 3/14, 5, 600, 40, 0. 2/32, 175, 29, 15, 36, 0, desander x desilter down. PP 2200, 475, 16R, , 6x8x90, 6x8x90. Bit 16R, 12-1/4, SDGH, cond run. BHA 115,000¥~. Trip 6, rig rep 1/2, circ 3-1/2, other 14. Mud costs $736, $18,779. TI to 13-3/8" shoe, slip.drlg line, RU BJ x run fm leak-off tst. Pr t° 475 psi x fm started taking fluid, equivalent mud wt 12 ppg x shoe, 10.8 ppg x 6000'. TI, circ x cond hole to log, TO. Run 1ES 5993- 3504', GR-Sonic 5980-3503'. MGS 17595 Well No. 18 Inc. TD 6000', circ 9-5/8" csg, , , 30. Mud 9.1, 39, 12, 7, 13, 12, 3/14, 5, 600, 40, O. 2/32, 175, 28, 15, 36, 0, desander x desilter down. Trip 4-1/2, rig rep 1/2, circ 4, csg x cmt 11-1/2, log 3, other 1/2. Mud costs $590, $19,369. Finish logging x dipmeter, TI x bit x slick BHA, slip drlg line, circ x cond hole for csg, TO, pull wear bushing. RU x run 143 jts 9-5/8", 40 x 43.5# S-95 Buttress csg, land approx 5983' x circ. MGS 17595 Well No. 18 Inc. TD 6000', LD BtL~ x WOC, , , 31. Mud 9.1, 39. Csg x cmt 5, tog 5, oth'er 14. Mud cost $105, $19,474. 9-5/8" csa 5983', 2-3-77. Cmt 9-5/8" csg as follows: pmp 10 BFW x 10 bbls mud flush x drop btm plug. Plug did not leave cmt head x rnptured. Rep plug x drop same. Mix x pmp 600 sx Class G + .75% D31L, avg 15.8 ppg. Lost'.returns for short time before cmt reached shoe, regain after losing 60 bbls x full returns thru remainder of job. Drop top plug x disp, bump plug x 2t00 psi x floats held, CIP 1100 hrs, 2-3-77. ND 12" riser x BOP stack x install 9-5/8" x 12" hanger. Cut off 9-5/8" csg x install 12" x 10" spool x tst x 3000 psi, ok. NU riser x BOP stack. Run Eastman gyro survey x SWS temp survey, est cmt top 4400'. Tst BOP's to 3000 psi~ Hydril to 2500 psi. Prep to LD BHA for 12-1/4" hose. October ! I, I~76 Re: MGS State 17595 lg Amoco Product I on C~any State Peml t No. 76-75 George ,I. Ross Area Superintendent Amoco Production Company P. O. Box 779 Anchorage, Alaska Dear Sir: Enclosed Is the approved application for permit to drill the above referenced well at a location In Section 30, To~nshlp ~N, Range I2~, S. Pi. Veil samples, core chips and a mud 1~ are not required. A dlrectlonal survey Is required. Hany rivers In Alaska and their drainage systems have been classified as Important for the spawning or mlgratl~ of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coord. I~tor~s office, ~part~ ment of Fish and Game. Pollution of any waters of the State is prohibited by AS ~(~, Chapter 03, Article 7 and the regulations promulgated thereunder (Tltle 18, Alaska Admlnlstratlve Code, Chapter 70) and by the Federat t~ater Pollution Control Act, as amended. Prior to ~ctng ~ratlons yc~J may ~ contacted by a representative of the Department of Environmental Conservation. Pursuant to AS )8./~O, Local Hire Under State L~ses~, the Alaska Oepartment of Labor Is being nottfled of the Issuance of this pemlt to drill. To ald us In scheduling fleldwork, we~1d apprectate your notifying this office wlthln q8 hours after thew el! Is spudded. ~ ~ould also like to be notified so that a representative of the Otvlsl~ may :bepresent to witness testlng of blowout preventer equipment before surface caslngshoe is drlI1~. G. J. Ross -2- O~tobe~ 1 !, lg76 In the event of suspension or abandonment please give thts office ~equate . advance notification so that ~e may t~rve a wttness present. Very truty yours, loyle H. H~llton Cha I rman A14ska 0tl and Gas Conservation Co~mlttee Enclosure Department of Fish and Game, P~abltat Section w/o er~l. Department of Envlronmenta! Con~rvatton w/~o encl. Department of Labor, Su~r'vlsor, Labor La~ Comptl~ca Division ~/o encl. G. J. Ross Area Superintendent October 11, 1976 File: GJR-753-WF Mr. Hoyle Hamilton Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Dear Sir: Re: Application for Permit to Drill MGS 17595 Well No. 18 Please refer to our Application for Permit to Drill MGS 17595 Well No. 18, submitted on September 29, 1976. As requested in telecon of October 6, 1976 between Harry Kugler and I, attached is a corrected plat showing the location of MGS 17595 Well No. 18. Yours very truly, George J. Ross Area Superintendent Attachment I% T i OCT DI~$iON OF OIL AND GAS Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent September 29, 1976 File: GJR-733-WF Mr. Hoyle Hamilton Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: FILE: Re: Application for Permit to Drill MGS 17595 Well No. 18 Attached is the State Form 10-401 requesting a permit to drill MGS 17595 Well No. 18. The well is to be directionally drilled from Leg 1, Slot 3 of Platform Baker to a target at the top of the'Lower Kenai conglomerate G-5 zone, 1550' FNL, 2000' FWL, Section 30, T9N, R12W, S.M. Total depth will be achieved when thetotal G-5 zone has been penetrated. This well is required to recover previously unrecoverable reserves north of MGS 17595 Well No. 14, which is a water injection well. Also attached are a draft in the amount of $100 for the filing fee, a BOP sketch, and a plat of the proposed bottom hole location relative to Platform Baker. Yours very truly, George J. Ross Area Superintendent Attachments Form IO-401 REV. 1-1-71 la. TYPE OF WORK STATE OF ALASKA SUBMIT IN TRIPI (Other instr uction~-~,,..~ reverse sid e) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL [~ DEEPEN [--] b. TYPE Oi: WELl/i Oil. [~] (;AS E~ WI£LE WELL OTI I I';R :~. NAME OF OPERATOR · Amoco Production Company 3. Al)DRESS OF OPI';RATOI>, P. O. Box 779, Anchorage, Alaska SINGLE MUUFIPLE ZONE Sa ZONE I--1 99510 4. LOCATION OF WELL A,~uaace Leg 1, Slot 3, 1934' FNL, 544' FWL, Section 31, T9N, ' R12W, S.M. At proposed prod. zone 1550' FNL, 2000' FWL, Sec. 30, T9N,.R12W, S.M.~ 8730 13. DISTANCE IN MILES AND DIRECHON FROM. NEAREST TOWN OR POST OFF1CE* TVD 2-0 miles NW of Kenai, Alaska 14. BOND INFORMATION: Blanket bond in force TYPE Surety and/or No. APl No. 50-133-20296 6, LI~ASF, DI{SIGNATION AND SI:,P, IAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNH' FARM OR LEASF, NAME, MGS State 17595 9. WELL NO. 18 10. FIELD AND POOL, OR WILDCAT Middle Ground S.hoal 11. SEC., T., R., M., (BOTTOM ttOLE OBJECTIVE) Sec. 30, T9N, R12W, S.M.. 12. AmountS100,000 15. I)ISTAN('E FROM PROI'OSED * ] 16. No. OF ACRES IN LEASE LOCATION TO NEAREST PROPER'rV OR LEASE LINE, FT. 3280' FEL 5160 (Al 'o to nearest drig, unit, if any) ' 18. DISTANCE I:ROM PROPO~H) LOCATION ' 19. PROPOSED DE~lt TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1091' ENE of Well No.10 12,000~ 17. NO,ACRES ASSIGNED TO TttIS WELL 8O 20. ROTARY OR CABLE TOOLS /8" casing Rotary 21. ELEVATIONS (Show whether I)1:, RT. CR, etc.) 22. APPROX. DATE WORK WILL START 79,4' KB- MSL November 1~ 1976 23. PROIK)SEI) CASING AND CEMF, NTING PROGRAM SIZE OF llOLl£ SIZE OF CASING WEIGIIT PER FOO'I' GRADE SETTING [)E~tl . Quantity of cement 26" ...20'.! 91.4# X-52 600' Cement to surface 17-1/2" 13-3/8" 68,61,&54.5# K-55 3,500' Cement to surface - 12-1/4" 9-5/8" 43.5 & 40# S-9~ & 9,000' Cement with 1000 sx Class G ., N-80 ..... 82122'''' 7" 26'&'29# S-95 12,000' Cement back to liner hanger in 9- Operator plans'to directionally drill hole from Leg 1, Slot 3 of Platform Baker to described target at the top of the lower .Kenai G-5 zone at 8730' TVD, plus sufficient hole to allow log eValua- :: tion of the G-5. Zones of interest will be perforated, S!timulated if necessary, and produced. There are no affected operat°rs.c.:A~ plat and BOP drawing are attached. ~ IN ABOVE SPA('E I)ES('RIBI~ PRO~)SEI) PROGRAM: If propo~l is to deepen give data on present productive zone and prop6sed new productive zone. If proposal is to drill or deepen dircctionatly, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. l hereby_ccgtify that thc l:oregoing~True and Correct (This space for State office usc) i SAMPLES AND (.'ORE CIIlPS REQUIRED I MIlD LO(; []yES []NO [ []yES DIRECTIONAL SURVEY REQUIRED ~ YES [] NO DATE September 29, 1976 Area Superintendent 'HTLE ('ONI)H'IONS OF APPI*,OVAL IF ANY: OTttER REQUIREMENI'S: )~ NO A.P.I. NUMERICAL CODE 50-133-20296 PERMIT NO .... 76-75 APPROVAL DATE APPOVED BY i TITLE Chairman ~/ -~ *See Instruction On Reverse Side 0trebor Il 1976 DATE October 11, 1576. I J U- C.. T'/oN __ . 1 Amoco Preduction Compan,.,~_~ ENGINEERING CHART S H L E FILE OF" APPN , . .3000 1 i ~ooo .I;"- db O(;~ ' ~Z--O 0(7., DATE Amoco ProduCtion Compa'6~~' ENGINEERING CHART ' x, O)h SHEET'NO. FILE OF APPN 't _ . CHECK LIST FOR NEW WELL PERniTS Company -_ Yes - No Remarks Is the pe..rmit fee attached ............ Is 'well to be located in a defined pool ......... Is a registered survey plat attached ........... Is well located oroD~r distance from proper,~v line , ... , · ,... ~.,~ Lease & Well No. Is well located proper distance from other wells .......... ~ . Is sufficient undedicated acreage available' in this pool ~-'well to be deviated . ,- ......... perator the only affected party ............... ~_~.: Can permit be approved before ten-day wait .' - Does operator have a bond in force . . . ts a conservation order needed ....... Is administrative apFroval needed ....... Is conductor string provided .... ; ..... . . . t . Is enoueh cement used to circulate on conductor and surface . cement tie in surface and intermediate or production strings cement covet- all known productive horizons . . . '.~ ..Will surface casing protect fresh water zones . . . ; .... W. ill all casing give adecuate safetv in collapse, tension & burst P. DDroval Recom~en.[eS' ~'di tional Requirements' Geol onv T R,~ ~ H!i K . JAL Enoir,=¢ -inQ OKG ECS Revised 1/15/75
