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183-010
Ima~broject Well History File' CoverOge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 2~- -b/O Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) D Color items: [] Diskettes No. c] Maps: ID Grayscale items: [3 Other. No/Type D Other items scannable by large scanner ID Poor Quality Originals: OVERSlZ£D (Non-Scannable) [] Other: NOTES: [] Logs of va~rious kinds [] Other Project Proofing Scanning Preparation .~ x30: _ + / : TOTALPAGES . 7 .r r Production Scanning ' Stage 1 PAGE COUNT FROM SCANNED FILE: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES __ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND; YES NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScan ned.wpd • • , rc / s 333 Wesi Scvcr'ir Avenue CGOV"ilt eR Si,,AN P1 R\ L Arcrorace Aiasko 995G'-3572 mom 9)7.2-'0 1t22 ra>,. 27, 7. Dan Taylor %WO AUG 1 4 2014 l Operations Engineer O Hilcorp Alaska, LLC ` 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, Trading Bay Unit G-03RD2 Sundry Number: 314-353 Dear Mr. Taylor: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 'e)/ Daniel T. Seamount, Jr. Commissioner DATED this/a day of June, 2014. End. • STATE OF ALASKA VAI"`1 ALASKA OIL AND GAS CONSERVATION COMMISSIONI U N 0 4 2014 u. APPLICATION FOR SUNDRY APPROVALS 2QAAC 25.280 AO C C 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well 0 Stimulate❑ Alter Casing❑ Other. Convert to Injector 0 2.Operator Name: 4.Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0 183-010 " 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20049-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit/G-03RD2 I 9.Property Designation(Lease Number): 10.Field/Pool(s): , Piq ADL0018730 McArthur River Field/Middle Kenai G Oil Pool t iJcJ 011 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,050 " 9,787 - 10,870 — 9,631 ' 10,165&10,870 10,627 Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13-3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9-5/8" 7,670' 6,886' 6,870 psi 4,760 psi Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 2-7/8" 6.4#/L-80 9,493 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker D-ESP Dual Packer/SSSV: N/A 5,390'(MD)4,938'(ND)&9,485'(MD)8,433'(ND)/ NA 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 Service 0' 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/18/2014 Oil 0 Gas El WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ 0' 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 Dan Taylor Email dtaylortu7hilcorp.com Printed Name D.• = for Title Operations Engineer Signature Phone (907)777-8319 Date 6/3/2014 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' 1-1.- '3S- Plug -L- 3S3Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ' Location Clearance ❑ Other: Ope-ra � � ) ©f wt,R i n. a CC wife A k © S, o 00 an 4 any weir S jOec,f t c, AkYl i cl i s- -t-r v e, r ra va,ca° Spacing Exception Required? Yes ❑ No Subsequent Form Required: C y C LI Approved by: APPROVED BY /�// COMMISSIONER THE COMMISSION Date: 52—"" ii, G ./o-/41 fp,bsi/l ye /v W Submit Form and Form 10-403(Revised 10/2012) ApprOdRIG NA � onths from theof approval. q104 : = IgluJl 111 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 II 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 May 29, 2014 Chris Wallace Alaska Oil and Gas Conservation Commission 333 W 7th Ave#100 Anchorage,AK 99501 Dear Chris: c z-J G-O 3 R PZ CDW 33- 610 Hilcorp requests an Administrative Approval to allow seawater injection into wellc3-RD1 (API#50-733-20049- 01, PTD#01-4110)to determine the economic benefits to workover the well for long-term injection in the Middle Kenai G pool. An AA is needed due to the current wellbore configuration with an upper packer approximately 4,386ft above the top of the proposed injection interval✓ In 2013 the Hemlock was isolated in G9; 3R-E3and corroded 7in casing was isolated by straddle packers at 5,390ft and 9,485ft. The small wellbore volume below the lower packer limited the ability to control drawdown with an ESP and production from Middle Kenai G pool was too low to run the ESP so the well was subsequently shut-in after the ESP failed. Containment of fluids to the middle Kenai G pool will be maintained by the 7in primary cement job with a 5-4-83 /--- CBL showing good cement to approximately 7,300ft, state witnessed MIT's of the tubing above the lower packer Ccs L fe. at 9,493ft and in the 7in inner annulus above the upper packer at 5,390ft. To verify that the lower packer is rj/ holding, a temperature survey would be run to-9,525ft before and after injection commences.After injection c, ' commences, rates& pressures will be monitored closely in offset wells including injector G-23RD which is within 1L`- a 1/4 mile radius and was shut-in in July 2013 due to a warming irregularity at the top of the packer that is being . `' evaluated for repair or P&A. ✓I,X411 It is requested that approval be granted for a 1 year injection test to determine the injectivity and benefits to offset producers in the Middle Kenai G pool. Maximum expected tubing pressure during this period would be 2,500psig to stay below the pressure rating on the packers. p 1 Coat GUI //'.Io. to ief if /' "—i it "/'seta br Sincerely, !' tveI( !ca o('q y'eW r0 (efs Jim Young rp�� i�j,1 `%7,i Reservoir Engineer-Cook Inlet Offshore Assetyuan y0 ott p 4,..�r4 a arts✓ Co,- 4< ti rQ� Attachments /✓ C04 ter r,9 Tic X01/ To GA /Valor ANicti AOR Map&Cross Section Screen Shots:G-Zone 0ti tow .41., /.41/9, /'d.•ea 1eCo1 v j *DA 14. Current Wellbore Schematic Ae WV Link to file Page 1 of 5 Hilcorp Alaska,LLC Pressures: Current BHP: "'3251 psi @ 8415'TVD/9563' MD .39 psi/ft., (7.4 ppg)at ESP intake gauge Max. Expct'd BHP: —3,440 psi @ 8850'TVD/9960' MD .39 psi/ft. (7.4 ppg, G-Zone perfs) Max. Possible SP: 2555 psi Using 0.10 psi/ft back to surface Justification, Rate&Reserves Summary G-03RD2 is a shut-in G-Zone producer located just south of the crest of the mid-field ridgeline. Prior to the 2013 workover, it had been shut-in for 8 years. This dedicated G-zone injector, can positively impact G-zone production in offset producers G-02RD, M-31B and G-26RD, D-30RD2 when returned to production. Link to file Page 2 of 5 Hilcorp Alaska, LLC Area of Review Map: G-zone, G-03RD2 Area 09 _. HILCORP ALASKA,LLC MCARTHUR RIVER FIELD T 28 1 8 , FEET A DWELL SYMBOLS l -4—AbaMonea Water Inlector G 0 RD l* A :neat.wan Lease gas well • al wau r aged a nba ao-a o11 7}� sn bGa:well REM Ql Wall G-05 snwb tomer Injector CII!.....ewarlREMP.RKS &ack Dot by G Zorn \ WNI Symtwl-base Fbmbck IMaY 1d,2Jtd411 • G-03D2 Measured Distances —iftw�! tri 20 \ ----- r Top Middle Kenai G From -West Section Line 133' \-••••, \. South Section Line 3488' \ ,,,, I G-10 Bottom Hole Location From \ West Section Line 553 /iksipp. -D Ir South Section Line 3091' 1�-4RD\`��''/ G-21RD �ir.I�`,� `,� clit os 00= s . A r. =aaaRo G 1_ G• G ' RD SRD ..1 — j EA r \ i \t` 8 D-40RD 0-28 D-42 I G-26-. o1 G-, RD °- s-31. .i.32 /��p_07 1 D-47 D-01 e ••DPN 0-29 I 1 RD2 -43Rp i 13-27,/ D-31121 ■ .c' 1 :. - dr/ D-26 s I 2 M./14/2014 t3701 PIA Link to file Page 3 of 5 �S. Hilcorp Alaska, LLC 1 ��,j - G-Zone Cross Section: GRAYLING WORKOVER PROJECT /r , G 22 G-11 G 02RD G 03RD2 G 08RD COAEOIL COREOIE COALPL WAlOR COALOIL 1,00 1 0 1 [ I I I I SRI PSI NEW SPN PHIE NEW SPN PHIE NEW SPN FINE NEW SPN PHIE NEW ��_..�...._..._ 1 0 4a o , C IW 1 , 5 440 [ I 0 100 AWE OHM PE ASH SHEW FES VSH SHEW RES EWE KW RES AWE SKEW AES 0 I 4 IPC 0 1 0 170 0 I 0 170 I 0 IDE 0 I 0 I1€ CA DEEP AES OR DEEP RES GA DEEP RES G9 DEEP AES GA DEEP AES 20 I 0 IDE 70 IOf 0 Ito 70 10E 0 IN A III 0 120 70 100 0 121 - .. 1 �, IT PIMSTRf- -GIT MASTRP -�1T MASTA-- � � � � �i1T AlASTR ...:: ( ozT�MASTRF .. .•• 1. OCT IMASTR] �' .. ... jG2n1MASTR 1 �� ITTIMASTRI--- 4- ,.?----1,,. i , ;71 _ . - .,ST PMASTRP— !1tTi- j' t� ,,3T PMASTR f �� - / tfl �iAS' ! - - GSTPMASTRP— • �R� .,4f PMASTRP 4T IMASTR I r L.: :.:.. ! 71 I . ::::: .::::: 111 I 119 la .. ___._ a � .:.:.: : 4T IMASTR1-: 351 M4sn F------_, mania s WM 7 is_i _____ I kill -. i 1:II i‘ ' ...i i..:.:: ' .....::::: Jim.. f _ ATPMAs R�L &114� ` ir , ` 17 .....,010.1111 -G6T PM4GTR�; � - I - i ,,IT PAST M, I .IWASIR1/ G7TPMAsrRP-- ... --- -- •. [ G7f::: It IF.-- , 'N _R �'` _____ ,IXITPMAST' MIDDLEKENAIG JW:9,177,183 MIDDLEKENAIG 0:347,229 os Link to file Page 4 of 5 ' Hilcorp Alaska, LLC Existing Wellbore Diagram III McArthur River Field,TBU SCHEMATIC Well:G-03RD2 ilih„r,51,-ku.I.I.I. RKB to MSL ELEV=103.0' CASING DETAIL RKB to TBGHngr=40.90' t.=;,DE CONN I ID PTIS1 X 2F' surf. 343' 26j 1 L 2 XO 13-31861 1-55 Butt 12.515 Surf. 2209' 9-5/6" 47 0-110 Butt 8.681 Surf. 78' 3.3/8 40 N-80 8.835 78' 4,614' 43.5 P-110 8.755 4,614' 7,670' ' ,DV @ 7` 29 N-80 Butt 6.184 Surf. 7,295' 3,421' P-110 7,295' 11,045' TUBING DETAIL 2.7/S" 6.44 I t-60 8rd 2.441 I Surf. l 9,493' DV Collar @ 3,421'to 3,423' JEWELRY DETAIL NO. Dal:t'l Item 40.9' 3-1/2"Hanger Asst'. 1 42' 3-1/2"I8T Box X Pin 2 49' 0/0 3-1/2"IBT Box X 2-7/8''EU Pin 3 1 3 5,390' Baker D-ESP Dual Packer 4 9,412' 2.7/8"Sliding Sleeve w/2.31"Prefile 5 9,485' Baker D-ESP Dual Packer • 6 9,493' X Nipple 7 9,525' Head Bolt On Discharge B 9,526' Pump SLB 835005-5 sections 9 9,463' Pump Intake 10 9,646' Protectors-Maximus LSBPB-UT(21 9-5/8 000 4 L 11 9,662' Top of Motor SIB 456,18,4183 Maximus-2 motors 5 12 9,729' Bottom of ESP 1 ":..I, Sx I 13 10,165' CIBP on top of old packer X 6 14 10,627' Junk Packer / 15 10,870' Cement Retainer 8 9 10 PERFORATION DETAIL 11 Zone Interval(MD( rterra'(TVD) Arra Date Status 0 0-1 9,776' 9,794' 8688' 8,705' 18' 4/27/2013 Open 13-2 9,824' 9,642' 8,731' 8,747' 18' 4/27/2013 Open 12 =G-1 G-3 9,899' 9,935' 8,797' 8,629' 36' 4/27/2013 Open G-2 -G-3 G-4 9,960' 10005' 8,850' 8,890' 45' 4/27/2013 Open s 0-4 10,088' 10,102' 8,961' 8,973' 14' 4/27/2013 Open -,---G-5 G-5 1310,120' 10,138' 8,989' 9,004' 18' 4/27/2013 Open - 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed perfs =HB-1 10,307' 10,337' 9,148' 9,173' 30' 5/11/1983 Isolated =HB-2 Ho-1 4/20/1991 Isolated 10,310' 10,311 9,150' 9,151' 1' 5/9/1983 Squeezed perfs 10,317' 10,344 9,156' 9,179' 27' 12/22/1989 Isolated Mill = 14 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated a HB-4 10,365' 10,388 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB 2 15 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated �• i. HB-4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed perfs TD=11,050' Max Angle=34.8°@ 7,600MD/6,828TVD 05/16/13-Note.There is a 30'discrepancy between the tubing tally and the ESP string diagram provided by Schlumberger Link to file Page 5 of 5 STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM IONJ 201 REPORT OF SUNDRY WELL OPERATIONS JUL L'`� 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other❑ V `-'' Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El . Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development p' Exploratory❑ 183-010 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20049-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018730 Trading Bay Unit/G-03RD2 r 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G Oil Pool • 11.Present Well Condition Summary: Total Depth measured 11,050 feet . Plugs measured 10,165&10,870 feet true vertical 9,787 feet Junk measured 10,627 feet Effective Depth measured 10,870 feet Packer measured 5,390'&9,485' feet true vertical 9,631 feet true vertical 4,938'&8,433' feet Casing Length Size MD ND Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13-3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9-5/8" 7,670' 6,886' 6,870 psi 4,760 psi Production Liner 11,045' 7" 11,045' 9,78xr3,' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet c���� U\ID True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80 9,493'(MD) 8,440'(ND) Baker D-ESP Dual Pkr 5,390'(MD)4,938'(ND) Packers and SSSV(type,measured and true vertical depth) Baker D-ESP Dual Pkr 9,485'(MD)8,433'(ND)SSSV-N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treated tubing to 9,580',perforations from 9,776'-10,138' Treatment descriptions including volumes used and final pressure: Pumped 4310 gallons(715 gal PAO-0100,165 gal PAO-0072,165 gal WAW-5206,165 gal WLC-179,1,000 gal diesel,2,100 gal 15%HCL)followed by 80 bbls FIW. Ending pressure 800 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 0 720 60 Subsequent to operation: 17 8 575 82 82 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p. Gas ❑ WDSPLEI 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: 313-329 Contact Dan Marlowe Email dmarlowe @hilcorp.com Printed Name /Damon Marlowe Title Operations Engineer Signature 4/4, Phone 907 777-8420 Date 7/22/2013 Form 10-404 Revised 10/2012 VLF RBDMS JUL 2 4 201 nit Original Only 14 • • Hilcorp Alaska, LLC • Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G-03RD2 50-733-20049-01 183-010 6/27/2013 6/27/2013 F6/27/13.- r3day . Rig-up. Mix Chemicals. Pressure test treatment lines. Begin pumping pill#1(715 gal PA0100/110 gal PA072).Pill started at 0 psi and ended at 400 psi tubing pressure. Begin pumping pill#2(1000 gal Diesel/55 gal PA072)Pill started at 0 psi and ended at 400 psi tubing pressure. Begin pumping pill#3(165 gal WAW5206/165 gal WLC179/2100 gal HCL). 11:40 400psi @ 34gpm 11:43 500psi @34 gpm 11:49 Switch to HCL S80psi @ 34 gpm 11:55 550psi @ 30 gpm 12:00 400psi @ 30 gpm 12:21 440psi @ 40 gpm(HCL half done)) 12:55 Finish pumping 56 bbl pill of HCL-400 psi @ 40 gpm,Pump 80 bbl FIW Overflush 13:15 15 bbl FIW pumped 540 psi @ 40 gpm 13:56 45 bbl FIW pumped 620 psi @ 34 gpm 14:16 60 bbl FIW pumped 700 psi @ 32 gpm 14:40 80 bbl FIW pumped 800 psi @ 3g pm Soak. • • • McArthur River Field, TBU . 14 SCHEMATIC Well: G-03RD2 ,,em",Alaska,,,,,,: Completed: 05/2013 CASING DETAIL RKB to MSL ELEV=103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr=40.90' 26" Surf. 343' 26" 1 13 3/8" 61 J 55 Butt 12.515 Surf. 2209' 2 47 P-110 8.681 Surf. 78' 9-5/8" 40 N-80 Butt 8.835 78' 4,614' 13-3/8" 43.5 P-110 8.755 4,614' 7,670' 7" 29 N-80 Butt 6.184 Surf. 7,295' P-110 7,295' 11,045' I ,421'@ 33,421' TUBING DETAIL , 1 2-7/8" I 6.4# L-80 8rd I 2.441 Surf. 9,493' DV Collar @ 3,421'to 3,423' i ° JEWELRY DETAIL No Depth Item T, 40.9' 3-1/2"Hanger Assy. 1 42' 3-1/2"IBT Box X Pin , 2 49' X/O 3-1/2"IBT Box X 2-7/8" EU Pin 3 5,390' Baker D-ESP Dual Packer E 3 4 9,412' 2-7/8"Sliding Sleeve w/2.31"Profile mi. 5 9,485' Baker D-ESP Dual Packer 6 9,493' X Nipple 7 9,525' Head Bolt On Discharge 1 8 9,526' Pump SLB D3500N-5 sections 05/16/13-Note:There is a 30' 9 9,463' Pump Intake discrepancy between the tubing 10 9,646' Protectors-Maximus LSBPB-UT(2) tally and the ESP string diagram 11 9,662' Top of Motor SLB 456,18,4183 provided by Schlumberger Maximus-2 motors 9-5/8" 'DO 11 4 12 9,729' Bottom of ESP 5 13 10,165' CIBP on top of old packer MI14 10,627' Junk Packer j 15 10,870' Cement Retainer X : 6 aim- 7 PERFORATION DETAIL 8 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition Ki 10 G4 9,776' 9,794' 8,688' 8,705' 18' 04/27/13 Open ii 11 G-2 9,824' 9,842' 8,731' 8,747' 18' 04/27/13 Open G-3 9,899' 9,935' 8,797' 8,829' 36' 04/27/13 Open 12 =G-1 04/27/13 G-2 G-4 9,960' 10,005' 8,850' 8,890' 45' Open G-3 04/27/13 =G-4 10,088' 10,102' 8,961' 8,973' 14' Open =G-5 G-5 10,120' 10,138' 8,989' 9,004' 18' 04/27/13 13 Open IMMO 111111111111111- HB-1 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed perfs 5/11/1983 Isolated o HB-2 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Isolated H B-1 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Squeezed perfs 14 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated HB-4 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated 15 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB-2 1 TD=11,050' 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated Max Angle=34.8°@ 7,600MD/6,828TVD 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated HB-4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed perfs Revised by JLL 05/16/2013 • . STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS - , 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Qperat. Shutdown❑ Stimulate - Other CI Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development CI • Exploratory ❑ 183 -010 1 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20049 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 Trading Bay Unit / G -03RD2 . 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Middle Kenai G Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11,050 feet Plugs measured 10,165 & 10,870 feet true vertical 9,787 feet Junk measured 10,627 feet Effective Depth measured 10,870 feet Packer measured 5,390' & 9,485' feet true vertical 9,631 feet true vertical 4,938' & 8,433' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760 psi Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED JUL True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / L -80 9,493' (MD) 8,440' (TVD) Baker D -ESP Dual Pkr 5,390' (MD) 4,938' (TVD) Packers and SSSV (type, measured and true vertical depth) Baker D -ESP Dual Pkr 9,485' (MD) 8,433' (TVD) SSSV - N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treated tubing to 9,590', perforations from 9,776' - 10,138' Treatment descriptions including volumes used and final pressure: Pumped 1,855 gal. (55 gal. WAW -5206 & 330 gal. Xylene & 1,500 gal. 7.5% HCL) followed by 80 bbls FIW. Ending pressure 1,550 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 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IS " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil p • Gas ❑ 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 -139 Contact Ted Kramer Email tkramerAhilcoro.com Printed Name Ted Kramer Title Sr. Operations Engineer P Signature �� ��� Phone 907 777 -8420 Da a 7/2/2013 7 Form 10 -404 Revised 10/2012 3 -/3 RBDMS JUL - 3 2Q 1 bmit Original Only • • • McArthur River Field, TBU ini SCHEMATIC Well: G -03RD2 Hilcorp Alaska, LLC Completed: 05/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' 1 - X 26" Surf. 343' z6' 13 -3/8" 61 1-55 Butt 12.515 Surf. 2209' 2 xo 47 P -110 8.681 Surf. 78' 13 -3 /s" 9 - 5/8" 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' II ' DV @ P -110 7,295' 11,045' 3,421' TUBING DETAIL 2 -7/8" 1 6.4# L -80 8rd 2.441 Surf. I 9,493' DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth Item 40.9' 3 -1/2" Hanger Assy. 1 42' 3 -1/2" IBT Box X Pin 2 49' X/O 3 -1/2" IBT Box X 2 -7/8" EU Pin 3 5,390' Baker D -ESP Dual Packer _ 3 4 9,412' 2 -7/8" Sliding Sleeve w/2.31" Profile ® 1,�® 5 9,485' Baker D -ESP Dual Packer 6 9,493' X Nipple 7 9,525' Head Bolt On Discharge 8 9,526' Pump SLB D350ON -5 sections 05/16/13 - Note: There is a 30' 9 9,463' Pump Intake discrepancy between the tubing 10 9,646' Protectors - Maximus LSBPB -UT (2) tally and the ESP string diagram 11 9,662' Top of Motor SLB 456, 18, 4183 provided by Schlumberger Maximus - 2 motors 9 - 5 / 8 " 000 4 12 9,729' Bottom of ESP Z. 5 13 10,165' CIBP on top of old packer 0�111 ►® 1 14 10,627' Junk Packer � 15 10,870' Cement Retainer X 6 - 7 PERFORATION DETAIL 9 8 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition in 10 G -1 9,776' 9,794' 8,688' 8,705' 18' 04/27/13 Open II 11 G -2 9,824' 9,842' 8,731' 8,747' 18' 04/27/13 Open G -3 9,899' 9,935' 8,797' 8,829' 36' 04/27/13 Open 12 = G - 1 G -2 G -4 9,960' 10,005' 8,850' 8,890' 45' 04/27/13 Open = G -3 04/27/13 =G -4 10,088' 10,102' 8,961' 8,973' 14' Open G-5 / / 13 -G 5 10,120' 10,138' 8,989' 9,004' 18' 04 27 13 Open "SIM 1=411W c HB -1 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed perfs 5/11/1983 Isolated Sa HB -2 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Isolated HB -1 `` �► 14 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Squeezed perfs 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated HB - 4 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated - w'.1' n__ 15 '" 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB-2 TD = 11,050' 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated Max Angle =34.8° @ 7,600MD/ 6,828TVD 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed perfs Revised by JLL 05/16/2013 • S Hilcorp Alaska, LLC Hilcorp LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 6/3/2013 6/3/2013 .., 06/03/13 - Monday R/U Williams 404 rig pump and hose to acid tank, batch tank and transfer pump. Mix 1 drum Baker Petrolite WAW -5206, 1 tote Xylene from Univar, 5 totes 7.5 HCL Acid from Univar. Pump 1855 gallons chemical pill from batch tank, pump 80 bbls FIW overflush and soak for 6 hours. oF 0,, 7, 4 , 9 THE STATE Alaska Gil and Gas GOVERNOR SEAN PARNELL 333 West Seventh Avenue O n h. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 scam MAY 31 2013 Ted Kramer Fax: 907.276.7542 G u Sr. Operations Engineer Hilcorp Alaska, LLC 3 _ Q 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU G -03RD2 Sundry Number: 313 -252 Dear Mr. Kramer: 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 P. 'oerster Chair DATED this G-7 day of May, 2013. Encl. • (1,13P .,,.,, t,-,..v !-- :,, :,,, i r:, n 'ilil e STATE OF ALASKA '� `j` 2 ' ?913 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG CC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El ' Alter Casing ❑ ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development p , 183 -010 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20049 -01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit G -03RD2 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018730 r McArthur River Field / Middle Kenai G Oil Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,050 • 9,787 ,. 10,870 - 9,631 '' 10,165' and 10,870' i 10,627' Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760' Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2 -7/8" 6.4# L -80 9,493' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker D -ESP Dual Packer (x2) and SSSV - N/A 5,390' (MD) 4,938' (TVD) / 9,485' (MD) 8,433' (TVD) and SSSV - N/A 12. Attachments: Description Summary of Proposal El '' 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 05/22/13 • Commencing Operations: Oil El • 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 Ted Kramer Email tkramerahilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature "?��2/ Phone 907 - 777 -8420 Date 5/20/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: MI T E NW SWasL � Spacing Exception Required? Yes ❑ No U� / Subsequent Form Required: /6 - `i 0 I f t APPROVED BY Approved by: �� �rti i / �fai/ L COMMISSIONER THE COMMISSION Date: ,) Z 7 — / /// "` 1�1 (/1� NA X ,52-`(% Submit d �� \ '►-3 Form 10 -403 (Revised 10/2012) Approted apt�it�G if months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: G -03RD2 Hilcorp Alaska, LL Date: 05/20/13 Well Name: G -3 RD2 API Number: 50- 733 - 20049 -01 Current Status: SI Leg: Leg #4 (SW corner) Estimated Start Date: 05/22/13 Rig: Williams Rig 404 Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 183 -010 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) Current Bottom Hole Pressure: 2,213 psi @ ESP Intake Maximum Expected BHP: 2,800 psi @ ESP Intake From Phoenix Gauge Max. Allowable Surface Pressure: 0 Psi static, 2,500 psi pumping during treatment Brief Well Summary G -3 RD2 was recently completed as an ESP lifted G -zone oil producer. The inflow from the reservoir is such that the ESP cannot stay running. The well does build up good pressure but when brought on at a 200 bpd rate, the bottom hold pressure drops to less than 1,000 psi in less than 16 hours. Job Summary a° It is believed that Skin is preventing the reservoir fluid from gaining entry to the well bore. ° 3 Io This treatment is designed to remove the damage and allow greater inflow. Brief Procedure: 1. Contact TBPF 48 hours in advance. Complete Non - Produced Fluids Transfer and fax to TBPF prior to shipping any fluid. 2. Verify that MSDS sheets are onsite for all chemicals and that safe handling procedures are followed. 3. Shut in well to allow fluid level to build. 4. Conduct safety meeting with platform foreman, operators, and pumping personnel to ensure safe operating procedures are followed. a) Review mixing and pumping procedures prior to rigging up and complete JSA & Work Permit. b) All hot work to be shut down on drill deck during pumping operations. c) Implement Safe Practices Standard 7.16 "Well Servicing Operations" including the safety checklist. 5. Send Non - produced fluids transfer form to TBPF. 6. Rig up pump, and tanks. a) Install a check valve in the treating line as close to well head as possible. b) Monitor tubing pressure, casing pressures, pump rate. c) Ensure that all equipment is grounded and bonded prior to any pumping or chemical transfers. 7. Pressure test lines first at low and then high pressure. Use a low pressure of 500 psig and a high pressure of 2000 psig. a) Test from pump to swab valve. b) Pressure test from pump to master valve and production wing valve. c) Bleed off pump pressure to verify that check valve holds. 6 . 3,. 8. Mix chemicals in 2000 gallon batch tank a. 1 drum Baker Petrolite WAW -5206 (ground tote while transferring) b. 1 tote Xylene (ground tote when transferring) • • Well Prognosis Well: G -03RD2 Hilcorp Alaska, LL Date: 05/20/13 c. 5 totes 7.5% Hydrochloric Acid 9. Record pump rates and pressures throughout the job. Do not exceed 1500 psi annulus pressure (when annulus is shut -in). Reservoir pressure is estimated to be 3,500 psi. a. Pump 1855 gallons chemical pill from batch tank b. Pump 80 bbls FIW over flush and soak for 6 hours 10. Shutdown pumping, ensure all tanks, lines, etc. are thoroughly rinsed. 11. Rig Down, Blow -down pump, drain all lines, and turn well over to Production. Attachments: 1. As -built Schematic • . . • McArthur River Field, TBU SCHEMATIC Well: G -03RD2 Hiloorp Alaxka, LL : Completed: 05/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' 26" Surf. 343' 26' 1 _ X [L 1 9 3 :5 3 :87 61 J -55 Butt 12.515 Surf. 2209' 2 xo 47 P -110 8.681 Surf. 78' 13 - 3/8' 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' ' ' DV @ P -110 7,295' 11,045' 3,421' TUBING DETAIL 2 -7/8" 6.4# L -80 8rd 2.441 Surf. 9,493' DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth Item 40.9' 3 -1/2" Hanger Assy. 1 42' 3 -1/2" IBT Box X Pin 2 49' X/O 3 -1/2" IBT Box X 2 -7/8" EU Pin 3 5,390' Baker D -ESP Dual Packer � 3 1 4 9,412' 2 -7/8" Sliding Sleeve w/2.31" Profile 5 9,485' Baker D -ESP Dual Packer (x � 6 9,493' X Nipple 7 9,525' Head Bolt On Discharge 8 9,526' Pump SLB D3500N -5 sections 05/16/13 - Note: There is a 30' 9 9,463' Pump Intake discrepancy between the tubing 10 9,646' Protectors - Maximus LSBPB -UT (2) tally and the ESP string diagram 11 9,662' Top of Motor SLB 456, 18, 4183 provided by Schlumberger Maximus - 2 motors 9 /$' Opp 4 12 9,729' Bottom of ESP 5 13 10,165' CIBP on top of old packer >/ 14 10,627' Junk Packer //'` \� 15 10,870' Cement Retainer X 6 ril 7 PERFORATION DETAIL 9 8 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition 10 G -1 9,776' 9,794' 8,688' 8,705' 18' 04/27/13 Open 11 G -2 9,824' 9,842' 8,731' 8,747' 18' 04/27/13 Open G -3 9,899' 9,935' 8,797' 8,829' 36' 04/27/13 Open 12 - G -1 04/27/13 G -2 G -4 9,960' 10,005' 8,850' 8,890' 45' Open = G -3 04/27/13 -G -4 10,088' 10,102' 8,961' 8,973' 14' Open =G -5 G 5 10,1 10,138' 8,989' 9,004' 18' 04/27/13 13 .. - -_ . -- _ ___ Open =Et= CiEll1= c HB -1 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Isolated 5/11/1983 Isolated a HB -2 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Isolated HB -1 ��� 1 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Isolated 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated HB -4 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated 1...._ 15 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB-2 TD = 11,050' 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated Max Angle =34.8° @ 7,600MD/ 6,828TVD 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Isolated Revised by JLL 05/16/2013 JD STATE OF ALASKA • ALMA OIL AND GAS CONSERVATION COMAION MAY i 7 20 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate a Other et Install ESP Performed: After Casing ❑ Pull Tubing El Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El • Exploratory ❑ 183.010 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20049 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018730 • Trading Bay Unit / G -03RD2 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Middle Kenai G Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11,050 feet Plugs measured 10,165 & 10,870 feet true vertical 9,787 feet Junk measured 10,627 feet Effective Depth measured 10,870 feet • Packer measured 5,390' & 9,485' feet true vertical 9,631 feet true vertical 4,938' & 8,433' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760 psi Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED MAY 3 0 2013 Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# / L -80 9,493' (MD) 8,440' (TVD) Baker D -ESP Dual Pkr 5,390' (MD) 4,938' (TVD) Packers and SSSV (type, measured and true vertical depth) Baker D -ESP Dual Pkr 9,485' (MD) 8,433' (TVD) SSSV - N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 265 70 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development D ` Service ❑ Stratigraphic Daily Report of Well Operations X 16. Well Status after work: Oil p • Gas ❑ 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 -139 Contact Ted Kramer Email tkramer @hilcorp.com Printed Name / Ted Kramer Title Sr. Operations Engineer Signature ,.. `` L. , G � -••---- Phone 907 777 -8420 Date 5/17/2013 Form 10 404 Revised 10/2012 � 1 ' 13 RBDMS MAY 2 0 2013* ` ��� /j Submit Original Only • • • McArthur River Field, TBU SCHEMATIC Well: G -03RD2 Hilcorp Alaska, LLC Completed: 05/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' _ X 26" [L 26" Surf. 343' 1 13 3/8" 61 1 -55 Butt 12.515 Surf. 2209' 2 xo 47 P -110 8.681 Surf. 78' 9 -5/8" 40 N -80 Butt 8.835 78' 4,614' 13 - 3/8" 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' P -110 7,295' 11,045' DV @ 3,421' TUBING DETAIL 2 -7/8" 6.4# L -80 8rd 2.441 I Surf. 9,493' DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth Item 40.9' 3 -1/2" HangerAssy. 1 42' 3 -1/2" IBT Box X Pin 2 49' X/O 3 -1/2" IBT Box X 2 -7/8" EU Pin 7 3 5,390' Baker D -ESP Dual Packer 3 53 ° 4 9,412' 2 -7/8" Sliding Sleeve w/2.31" Profile MR = b/. 5 9,485' Baker D -ESP Dual Packer 6 9,493' X Nipple 7 9,525' Head Bolt On Discharge � p ) �� 8 9,526' Pump SLB D3500N - 5 sections `� G S Sl 05/16/13 - Note: There is a 30' 9 9,463' Pump Intake discrepancy between the tubing 10 9,646' Protectors - Maximus LSBPB -UT (2) tally and the ESP string diagram 11 9,662' Top of Motor SLB 456, 18, 4183 provided by Schlumberger Maximus - 2 motors 9 - 5 / 000 4 12 9,729' Bottom of ESP 5 13 10,165' CIBP on top of old packer �r =' 1 `1.1 14 10,627' Junk Packer 15 10,870' Cement Retainer X i 6 PERFORATION DETAIL 7 9 8 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition I 10 G -1 9,776' 9,794' 8,688' 8,705' 18' 04/27/13 Open Q 11 G 2 9,824' 9,842' 8,731' 8,747' 18' 04/27/13 \�- Open G -3 9,899' 9,935' 8,797' 8,829' 36' 04/27/13 Open 12 = G-1 04/27/13 G-2 G-4 9,960' 10,005' 8,850' 8,890' 45' Open = G -3 04/27/13 -G -4 10,088' 10,102' 8,961' 8,973' 14' Open 13 G 5 G-5 10,120' 10,138' 8,989' 9,004' 18' 04/27/13 Open ^131■1 =BIC c HB -1 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Isolated 5/11/1983 Isolated HB -2 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Isolated HB-1 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Isolated ® ® 14 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated FE HB -4 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated 15 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB-2 TD = 11,050' 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated Max Angle =34.8° @ 7,600MD/ 6,828TVD 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Isolated Revised by JLL 05/16/2013 ' • . Hilcor p Alaska, LLC • HIh.oi.,, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 4/23/2013 5/4/2013 Daily Operations: r _ 04/23/13 - Tuesday Skid rig to G- 03RD2. Store Jacks and skid manifold. Set walk ways to rig floor. Clear well bay of old tree parts. Stage New tbg for G -03 in well bay. Check Well pressure. Tbg and Csg static. Fluid @ surface. N/D 4- 1/16" X 2" flange from Dry hole tree. N/U 2- 1/16" X 1502 flange on Prod csg valve. Set 2 -Way check. N/D Dry hole tree. 04/24/13 - Wednesday Cont N/D Dry Hole Tree. N/U 11" 5k riser and BOP's. Function test BOP's. Change out rental Super Choke for Hilcorp Super Choke. N/U Mud cross on top of Hydril. Test BOP's. Pipe Rams, Blind Rams, Choke Manifold, Kill Line, Choke Line, 2 TIW valves, IBOP, and all valves 250 psi low and 3,000 psi high. Test Hydril 250 psi low and 2,500 psi high. All test recorded on chart. B/D & L/D test jt. Pull 2 -Way check. M/U Landing jt into hanger. Back out hold down pins. Pull Hanger to rig floor and L/D same. POOH with 2 stds. Gather, measure and caliber X -0 subs to mate 3 -1/2" IF drill collars to 2 -7/8" EUE 8rd. M/U X -O subs. TIH P/U 5 jts 4 -3/4" drill collars. M/U 7" RTTS and SSC valve. TIH with same on 2 -7/8" EUE 8rd. Set Storm Pkr @ 165'. Release from storm pkr. POOH with 5 jts of 2 7/8" EUE 8rd tbg. Closed blinds & tested casing t/1500 f /10 min good. 04/25/13 - Thursday R/D rig floor and drip pan. R/U pump line and drain BOP's and riser. N/D riser at well head. P/U BOP stack and riser N/U New tbg spool on top of existing tbg spool. N/U riser. Pressure test breaks to 1,500 psi for 10 min. Good test. R/U rig floor and drip pan. Make trip and retrieve storm pkr @ 165'. L/D 5 jts 4 3/4" Drill Collars and X -0 subs. Pooh standing total of 41 stds 2 -7/8" EUE 8rd tbg in derrick. Weather delay. High winds. 75+ MPH. M/U 6" Bit 7" csg scraper and TIH with same on 2 -7/8" L -80 EUE 8rd tbg from derrick. Drift each std to 2,606'. Cont TIH S.L.M, Drift and P/U 2 7/8" tbg. 04/26/13 '• Y Continue in hole with csg scrapper PU 2 -7/8" tbg from rack and rabbiting same to 5,267'. Work scrapper from 5,267' to 4,900' three times. Continue in hole with csg scrapper PU 2 -7/8" tbg from rack and rabbiting same from 5,267' to 9,667' & work scrapper from 9,665' to 9,450' three times. Rev Circulate and condition fluid at 9,667'. Continue rev circ while w/o balance of 2 -7/8" tbg. Off load 2- 7/8" tbg and S.L.M. same. Cont TIH P/U and drift 2 -7/8" 6.5# L -80 EUE 8rd tbg. Tag @ 10,165' D.P.M. R/U and rev circ unable to wash any deeper. Cont rev circ total of 3 bottoms up. Returns clean. R/D circ hose. POOH standing 2 78" tbg in derrick. 04/27/13 - Saturday Continue POOH with 2 -7/8" tbg, bit & scrapper. PU & MU TCP gun assy and RIH with same. Continued in hole with TCP assy( 4.5" 5 spf 45051 Omega guns) Tag CIBP @ 10,165' P/U to 10,157'. R/U E -Line and correlate guns on depth. ( Send data to Radu Girbacea for verifcation) R/D E -Line. P/U 1.5' and spot top shot @ 9,776' with bottom shot @ 10.138'. Break circ. Test lines to 3,000 psi. Drop 5/8" steel ball and pump same on seat. Pressure up to 2,200 psi and fire guns. Fill hole with 3 bbls FIW and monitor well. Fluid level falling slowly. POOH with 10 stds. Fill hole with 2 bbls FIW. Monitor well for 30 min. Fill hole with .5 bbl FIW. Cont POOH with spent TCP guns. 04/28/13 - Sunday Continue POOH with TCP assy. BO & LO spent TCP guns. Load out Schlumberger Equip. M/U test jt. Land test plug in tbg hanger. Fill stack lines and manifolds with FIW. R/U test pump. Start testing BOP's. Test pump went down. Change out test pump. Test BOP's. Pipe Rams, Blinds Rams, Choke manifold, Kill and choke lines, TIW valve, IBOP, and all valves to 250 psi low and 3,000 psi high for 5 min each. Test Hydril 250 psi low and 3,000 high for 5 min each. All test recorded on chart. Witness waived by Jim Regg AOGCC 4- 27 -13. Pull test plug. B/D and L/D test jt. Clean on rig and do rig maintenance while W/O ESP and equip. 04/29/13 - Monday W/O ESP Ass'y. Off load Schlumberger, Baker, Cameron, and Pollard ESP Equip. Spot Equip and R/U to run ESP ass'y. 04/30/13 - Tuesday Continue rigging us i .u, - _ • nnin: e.uirm- n . PU & MU ESP pump & RIH to lower ESP packer. PU & MU lower ESP packer, connect flat -pack elec. cables, injection and capillary lines to same. TIH with Schlumberger ESP Motors and pumps and Baker ESP pkr on 2 -7/8" L -80 6.5# EUE 8rd tbg. ( Install Sliding Sleeve one jt above lower pkr) Install cannon clamps as per detail and clamping 3/8" vent tube with 3/4" S.S. bands above each cannon clamp. 05/01/13- Wednesday Continue RIH with ESP pump and packer assy. • • Hilcorp Alaska, LLC Hileorp Alaska, LLC: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 4/23/2013 5/4/2013 Daily Operations: 05/02/13 - Thursday Continue RIH with ESP equipment & packers to hanger. Cut flat pack and steel lines and run thru hanger. Land hanger and back out landing jt. Set BPV & run in hold pins. Rig down wind walls, rig floor, Nd bop'S & NU tree. R/U pump and return lines to tree. Start displacing well to fuel oil. 05/03/13 - Friday Continue displacing well to fuel oil. R/U slickline, test lubricator to 3000 psi. RIH and close sleeve @ 9,411.62', set plug and prong in X- nipple @ 9,493.31. Set ESP packers with 3000 psi on tbg (held pressure for 5 min.) & test same to 1000 psi on csg for 10 min on chart. V Pull prong & plug from X- nipple & R/D slick line. R/D all lines from well G3RD2 & turned well over to production. 05/04/13 - Saturday Standing by while down hole pump electrical controls are hooked up & pump is tested. • gw1�� \, � j j --. THE STATE Alaska Oil Gas (ALASKA - Conservation Commission "ma GOVERNOR SEAN PARNELL 333 West Seventh Avenue 9 Anchora e, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer SCANNED APR 0 3 an Sr. Operations Engineer ©1 0 Hilcorp Alaska, LLC \C6 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 • tr. t3 Re: McArthur River Field, Middle Kenai G Oil Pool, Trading Bay Unit G- 03RD/2 • Sundry Number: 313 -139 Dear Mr. Kramer: 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 P. roerster Chair DATED this 3 day of April, 2013. Encl. • t 0 • tl. ` A y F t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A( `_; 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod M • Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing p Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install ESP a 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development p . 183 -010 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20049 -01 -00 • 7. If perforating: 8. WeN Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO No, 80,090 Will planned perforations require a spacing exception? Yes ❑ No El Trading Bay Unit G -03RD2 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018730 McArthur River Field / Middle Kenai G Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,050 9,787 10,870 9,631 • 10,165' and 10,870' . 10,627' Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760' Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic . See Schematic 2 -7/8" 6.5# L -80 EUE 2,643' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packer: Junk Packer and SSSV: N/A Packer - 10,627' (MD) 9,421' (TVD) and SSSV - N/A 12. Attachments: Description Summary of Proposal M 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 03/25/13 Commencing Operations: Oil M - 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 Ted Kramer Email tkrameratilcorp.com Printed Name ./ Teed Kramer Title Sr. Operations Engineer • Signature )/6 "L Phone 907- 777 -8420 Date 3/18/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: N ^ s / J` Plug Integrity ❑ BOP Test EY Mechanical Integrity Test ❑ Location Clearance ❑ Other: g6 t ie-5, Z50 s� �� 7c "S RSDMS APR 03 Zl3� Spacing Exception Required? Yes ❑ No Subsequent Form Required: ) d — L./ in l APPROVED BY Approved by: ‘:Y--Iti7 {� // i_l/ ( 7 /(_,-k COMMISSIONER THE COMMISSION Date: 4 3 -/3 0 � 0 I Fommane � 1- (e i AOL Approved application is valid for 12 months from the ate of approval. Attachments in Duplicate '�� • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage, Alaska 99501 Re: THE APPLICATION OF Hilcorp ) Conservation Order No. 80.090 Alaska, LLC to re- complete the TBU G- ) 03RD2 development oil well within 1,000 ) Trading Bay Unit G -03RD2 feet of, and within the same governmental ) McArthur River Field quarter section as, wells that are, or may be ) Middle Kenai G Pool capable of, producing from the same pool. ) Hemlock Oil Pool ) January 3, 2013 IT APPEARING THAT: By a letter received November 12, 2012, Hilcorp requests an order allowing re- completion of the TBU G -03RD2 development oil well within 1,000 feet of, and within the same governmental quarter section as, wells that are, or may be capable of, producing from the same pool. FINDINGS: 1. Hilcorp is the operator of the Trading Bay Unit and is the operator of the proposed TBU G -03RD2 development oil well that is located on the west side of the Cook Inlet, Kenai Peninsula Borough, Alaska. 2. The TBU G -03RD2 well is an offshore, deviated development oil well with a surface location 1833 feet from the south line and 1480 feet from the east line of Section 29, T9N, R13W, Seward Meridian (S.M.). The projected bottom -hole location is 2218 feet from the north line and 586 feet from the west line of Section 33, T9N, R13W, S.M. 3. The TBU G -03RD2 well is located entirely within State of Alaska Leases ADL -17594 and ADL - 18730. 4. The TBU G -03RD2 well is currently completed in the Hemlock Oil Pool. This well will be re- completed in the Middle Kenai G and Hemlock Oil Pools within an area governed by Conservation Order No. 80. 5. The TBU G -03RD2 well is located within 1,000 feet of, and within the same governmental quarter section as, wells that are, or may be capable of, producing from the Middle Kenai G or Hemlock Oil Pools. 6. Regulation 20 AAC 25.055(a)(3) specifies that the drilling unit for an oil pool is a governmental quarter section, and that a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool. However, Rule 5 of Conservation Order No. 80 specifies in part that the AOGCC "...may authorize the conversion or drilling of any well at any location...reasonably designed to further the purposes of the project" 7. The re- completion of TBU G -03RD2 is designed to maximize recovery from the Hemlock and Middle Kenai G Oil Pools at McArthur River Field by accessing un- drained reserves in both oil reservoirs that cannot be reached by wells conforming to applicable spacing restrictions. 8. In conformance to Rule 5 of Conservation Order No. 80, Hilcorp has given notice of this request to all potentially affected landowners, owners and operators —those within 1,000 - foot radius of the TBU G -03RD2 well —the State of Alaska, Pacific Energy Alaska r • • AA 80.91 Amended January 3, 2013 Page 2 of 2 foot radius of the TBU G -03RD2 well—the State of Alaska, Pacific Energy Alaska Operating, LLC, and Hilcorp Alaska, LLC. Hilcorp sent notice of its application to the State of Alaska and Pacific Energy Alaska Operating, LLC by certified mail in November 13, 2012. The AOGCC received no objection or comment regarding Hilcorp's request. CONCLUSIONS: 1. An exception to the well spacing provisions of 20 AAC 25.055(a)(3) is necessary to allow re- completion of the TBU G -03RD2 development oil well in order to maximize recovery of reserves. 2. Under 20 AAC 25.055(a), drilling unit and well spacing requirements prescribed by AOGCC pool rules —Rule 5 of Conservation Order No. 80— supersede the statewide spacing requirements of 20 AAC 25.055(a)(3). 3. A spacing exception to allow re- completion of the TBU G -03RD2 development oil well is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. NOW THEREFORE IT IS ORDERED: Hilcorp's November 12, 2012 application for an order granting an exception to the well spacing requirements of 20 AAC 25.055(a)(3) to allow re- completion of the TBU G -03RD2 development oil well is approved. Hilcorp may proceed as long as it complies with the terms of the Trading Bay Unit agreement, applicable Alaska laws, and all other legal requirements. DONE at Anchorage, Alaska and dated January 3, 2013. 8 0.OIL, Jo V 1 orman Daniel T. Seamount, Jr. Co sstoner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. ell Work Prognosis Il: App G -03RD2 Date 3/ 18/2013 Hikerp Alaska, LLC Well Name: G -03RD2 API Number: 50- 733 - 20049 -01 Current Status: Oil Producer Leg: Leg #4 (SW corner) Estimated Start Date: March 25, 2013 Rig: Williams Rig 404 Reg. Approval Req'd: 10 -403 Date 10-403 submitted: 3/18/13 Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 183 -010 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second CaII Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: 1221773 Budgeted Cost: Status: Shut -in producer since Sept 2004. A workover from January 15, 2013 to February 25, 2013 involved running a casing inspection log which determined that the well had bad casing in the 7 inch liner from 5,803' to 9,202' (This was confirmed by a pressure test). A CIBP was set above the perforations, a kill string was ran, and the well was suspended until a new forward plan could be developed. Objective: To perforate G -zone, and isolate the bad section of casing from 5,803' to 9,202' between two packers and run an ESP completion. Pressures: The perforations in the well were isolated in February 2013. Therefore, current bottom hole pressure is attributable to hydrostatic fluid left in the well. The maximum g -zone anticipated bottom hole pressure is derived by looking at offset g -zone only wells where static bottom hole pressures were taken during the Redoubt volcano shut -in in 2009. The closest g -zone only well (G -21RD) had a corrected for depth mid g -zone pressure of 3236 psi. Given the lack of G -zone injection support in this area, the pressure is not expected to be more than 3,236 psi. Current BHP: ^' 3,500 psi @ 9,196' TVD/10,365' MD .38 psi /ft., (7.3 ppg) at mid -perf of Hemlock Max. Expct'd BHP: ^' 3,236 psi @ 8,850' TVD /9,960' MD .367 psi /ft. (From offset well G -21RD) Max. Possible SP: 0 psi using 7.05 ppg fluid back to surface Procedure: Rig Work 1. Release rig from previous well. 2. Notify AOGCC of upcoming BOPE test (give 24 hours' notice to AOGCC to provide opportunity to witness) 3. Skid the rig over the G -03 well slot. 4. Bleed pressure down from 2 -7/8" kill string. Insure well is dead. Zg `� / 5. Set BPV in profile. ND Well head, NU BOPE and Test 200 psi low / 3,000 psi on blind rams. - o Note: If the BPV will not seat, shoot fluid again to confirm well is static. Test BOPE either on top of 2 -way check (per standard test procedure) or with a rolling test as described in Attachment #1. 6. POOH with 2 -7/8" kill string. 7. PU RIH with gauge ring to CIBP @ 10,165'. POOH with same. • ell Work Prognosis II: G -03RD2 !carp Alaska, LLB Application Date: 3/18/2013 A 8. PU RIH with Schlumberger TCP guns. Space out according to the Final Approved Perforation Request Form dated 9/6/2012. Fire Guns. 9. Circulate out perf gas and shut down to monitor fluid loss. Shoot fluid levels to insure well is static, POOH with TCP guns. Proposed Perforations Intervals To Be Perforated DIL Depths (Do Not Shoot) Tie -In Log Depths (Shoot These) Bench Top MD Btm. MD Top MD Btm. MD Feet GZN 1 9,776 9,794 18 GZN 2 9,824 9,842 18 GZN 3 9,899 9,935 36 GZN 4 9,960 10,005 45 GZN 5 10,088 10,102 14 GZN 5 10,120 10,138 18 10. PU ESP and dual packer completion. RIH making ESP cable continuity checks every 1,200' and spacing out packers so the bottom packer lands at 9460' ( + / -) and the top packer lands at 5,780'. 11. PU and RIH with plug to X nipple at 9475' ( + / -). Pressure up on tubing to set packers. 12. Pressure up on back side to-500 psi and monitor for5 min. to test top packer. 13. ND BOP, NU wellhead and te came. ' 0 14. Turn well over to production. Attachments: As -built (Old) Wellbore Schematic Proposed (New) Wellbore Schematic BOP Schematic Attachment #1 . • . H , • McArthur River Field, TBU SCHEMATIC Well: G -03RD2 Nilcorp Alaska, LLC Completed: 02/24/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. Note RKB to TBG Hngr = 40.90' 26" Surf. 343' 2611 L 13 -3/8" 61 J -55 Butt 12.515 Surf. 2209' 47 P -110 8.681 Surf. 78' 13 -3/8" 9 -5/8" 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' ,2 04 7" 29 N -80 Butt 6.184 Surf. 7,295' ' 111 DV @ P -110 7,295' 11,045' 3,421' TUBING DETAIL 2 -7/8" I 6.5 I L -80 I EUE I 2.441 I Surf I 2,643' I Kill String DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth OD ID Item 1 10,165' CIBP 2 10,627' N/A N/A Junk Packer 3 10,870' N/A N/A Cement Retainer PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition p 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed 5/11/1983 Squeezed 1 10,307' 10,337' 9,148' 9,173' 30' > 4/20/1991 Open 9 - 5/8Z Pi" > ' HB -1 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 DST- Squeezed Gssa „J 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Open r 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Open cr l 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Squeezed 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Open HB-2 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Squeezed 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Squeezed 1 FIB-4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed HB -1 o HB -2 2 3 z TD = 11,045' ETD = 10,130' Max Angle =34.8° © 7,600MD/ 6,828TVD Revised by JLL 03/04/2013 • S McArthur River Field, TBU PROPOSED Well: G -03RD2 Hilcorp Alaska, Lit Completed: 02/24/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' 26" Surf. 343' 1 L 13 -3/8" 61 1 -55 Butt 12.515 Surf. 2209' z6" 47 P -110 8.681 Surf. 78' 13 - 3/8" 9 S/8" 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Surf. 7,295' - Butt 6.184 . ' ,DV @ P -110 7,295' 11,045' 3,421' TUBING DETAIL 2 -7/8" I 6.4# L -80 I 8rd I 2.441 I Surf. ±9461 DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth Item 1 40.9' 3 -1/2" Hanger Assy. 2 ±5,860' Packer 3 ±9,430' Packer 4 ±9,461' X Nipple 2 Mli I= 5 ±9,462' Head Bolt 0 0 N - 5 s 6 ±9,464' Pump D3500N SLB D350 5 sections 7 ±9,580' Pump Intake 8 ±9,583' Protectors - Maximus LSBPB -UT (2) 9 ±9 599 Top of Motor SLB 456, 18, 4183 Maximus - 2 motors 10 ±9,667' Bottom of ESP 11 10,165' CIBP on top of old packer 12 10,627' Junk Packer 9 - / 13 10,870' Cement Retainer 3 MI ® PERFORATION DETAIL X 4 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition 5 G -1 ±9,776' ±9,794' ±8,688' ±8,705' ±18' Future Open 6 H G -2 ±9,824' ±9,842' ±8,731' ±8,747' ±18' Future Open 8 G -3 ±9,899' ±9,935' ±8,797' ±8,829' ±36' Future Open ii G -4 ±9,960' ±10,005' ±8,850' ±8,890' ±45' Future Open 10 - G -1 ±10,088' ±10,102' ±8,961' ±8,973' ±14' Future Open G-2 G-5 ±8,989' ±9,004' ±18' Future - G -3 ±10,120' ±10,138' Open = G-4 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Isolated - G -5 11 5/11/1983 Isolated ■ 10,307' 10,337' 9,148' 9,173' 30' HB -1 4/20/1991 Isolated HB -1 HB -2 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Isolated 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated 12 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated E HB -4 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated 13 H B -2 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated TD = 11,050' HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Isolated Max Angle= 34.8° @ 7,600MD/ 6,828TVD Revised by JLL 03/04/2013 • • Grayling Platform Williams Rig BOP (rental) 1/18/2013 H;Mnrp ,Uarka.1.1A: Grayling Platform 2013 Workovers BOP Drawing (Williams) 0 111 il I - I ISIJ I I v v MI MI I I I 1 1111 IQ t 1 3.42' Shaffer 11" _ Iil 11i1 411111 1i1 Ii, 1/11/1111 III 4.54' ii 1 _ . - 41 I Booster bonje on botto — M„ Ii&i ail dl I I I;1 Kill Side 2 1/16 5M wl check valve Ie1 W M IP 1111, Choke side . 2.00' ��� { } f ' d {' ��} and Unibolt line •, c , >... > . ' II 'I' lit i ; I ,;,' I' r ` ` ;il 2 1/16 5M wl HCR and �' ' Unibolt line connection connection 1.00' to 2.00' 11 Iii III III Iii Drill deck ' Riser 11 5M FE X 16.00' 11 5M FE 111 Iii ill T;1111 111 III 111 111 111 Spacer spool 3.00' 11 5M FE X 11 5M FE ill , 11 ■II 1I IiI • ell Work Prognosis ell: G -03RD2 Hilcorp Alaska, LLC Application Date: 3/18/2013 Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) • Ake II Work Prognosis Well: G -03RD2 Hilo p Alaska, LLC Application Date: 3/18/2013 d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C -1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C -1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. • Alien Work Prognosis Well: G -03RD2 Hilcarp Alaska, LLC Application Date: 3/18/2013 iv) Valves, 7, 8, 9. After test, open all valves. e) Close C -2. This is the HCR (the hydraulic controlled remote) valve just outside C -1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C -1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K -1, K -2, and K -3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure ". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi "). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut -off after the pressure to builds back to original pressure ( +/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto ", not "Manual" so the pumps will kick -off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Juanita Lovett. /10II Work Prognosis • - II: G -03RD2 xneo.Pni.oia,iic Application Date: 3/18/2013 Diagram A -1: Grayling BOP stack and Riser Arrangement — Typical for Single Completion Grayling Platform 2013 Workovers BOP Drawing (Williams) MEW 0 i lil ii lil 1 1 3.42' lil iil I ItI i iii wail 4.54' — _ al 8U . _. _ - II Booster bon, -ts on bo • _- i III lil lit iii Kill Side Choke side 211165Mwl check valve : "''!' ! ! !' and Unibolt line 2.00 Ig N{ • f II { } II { t f ( �{ � F''DII;�I; 2 1/16 5M w/ HCR and Unibolt line connection connection ' ' '' 1.00' to 2.00' Drill deck Riser 11 5M FE X 16.00' 11 5M FE ni 1 1 iu n. Spacer spool 3.00' 11 5M FE X 11 5M FE i wit H . II Work Prognosis Il: G -03RD2 Hilcorp Application Date: 3/18/2013 Diagram A -2: Grayling BOP stack and Riser Arrangement — Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 1.44' ItIHtjHIItiUHI t 13 5/8 5M Spacer spool 2 00' I .I I.Iiidi1.tt O i O III 11111 1 II W..therferd R.nt.l BOP Width 4.16' 3.74 Shaffer 135/8 684 j liti at elan 7 —1 Shaffer LWS ` � 1 3 618 6M LWS 13 5/8 5M lops Length Length ions' — 3 00 Width across body 2.72' 0 -1 ) Width across flanged r ` outlets 4.00' _ _ _ •■••• .' I u - L ] I l I. C ~ ] ~ � y I ~ � tiI! I = III III :. ' r}' 174' �t 441.1 ,,�.I 111 1i1 i ' / l�' . K -3 K -2 K -1 C -1 C - "HCR' Mud Cross ` RI ser above deck This number will drill vary from well to well 1 00' to 3.00' Drill Deck 13 5//8 6M Riser 85001bs 13 5/8 5M X 15.00 3 1/8 5M EFO III III III III Spacer Spool 136/86M X 136/86M 1.85' 18001bs III III III . Crossover Spool 136/85M X 11 6M 18001bs 2 83' III II Top of Wellhead H . Al p ll Work Prognosis ell: G -03RD2 Application Date: 3/18/2013 rid. . p U:rka.LLC Diagram B: Grayling Choke Manifold illy To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves - nrw+r 2 cm a w in . I Chokes are 90 degrees off in drawing in order to show i 1 detail 2 - ll 1 11 :11 , , III • 4 II , ' I., 16: _EliEsis E t lull 161 i 41 „ - „ t III - . . , - Swaco . ,, :I, .. .- i : le I 10 Lill 1 1 ' I _ IT i Ithill 1 I ' lt ■ 8 4 - i l l I III II III III I MM— IX I I r i t i :i From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3 1 /4' Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3 1 /4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 1 /4" Ball port, 6000psi working pressure #10 National Ball Valve 81560, 1 1 /2" Ball port, 6000psi working pressure 9 WILLIAMS RIG #104 FLUID FLOW DIAGRAM — NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" _ STANDPIPE P ;=N11 C 1 _ . / I LINE 1 • L_I__H i� ! I I I ____ , � STR e PER .. , HFRD ' LP .: BOP ORN UA L --" — AUTO NATO C ' STACK CHOKE CHO FE C 0 1'1 • 1�I = o : c - 1=1k •)1=_I: MUD PUMP - -fir X. :.. .'' PUMP C MANIFOLD `— NCR VALVE "" LP GAS SUCTION e USTER \ LINE /1 D co co F" G LU FLUID TPNK�PIT ' O O O j 3 w a.) 0 O O N 3 O I I w H \ Vf N c0 N O N W WILL TAMS RIG #404 - FLU ID FLOW DIAGRAM NORMAL OPERATIONS E. CIRCULATING DOWN TUBING, UP CASING ANNULAS 'THE LONG WAY" STANDPIPE /1 11 UNE I • )o r 1 a I , /--3T NEh PE D II O. :— -... -- BOP MANUAL — nuro 11...x1- : 0 : C STACK - CHOKE IN. p 11 II J MUD 0 I - 1-q�•�U'I PUMP ., PUMP C MANIFOLD , - Ci A LP OAS SUCTION II USTER \ LINE /' _ _ 1 I D -a CD m n v 1 FLUID TANK/PIT C C O '' z w x 0 0 O '* N Dti fD 3 .. C km 0 \ N 1-+ oz N O r w WILLIAMS RIG #404 9 FLUID FLOW DIAGRAM = WELL CONTROL OPERATIONS KILLING WELL - DOWN TUBING, UP CASING ANNULAS STANDPIPE A ! PANIC LINE IC: • .. 0 I I I I l� BTRI /IER oC O _ MEAD BOP ■ MANUAL I C O ` AUTO UATC 0 oC STACK CHOKE C HO YE C C oC C ICI III MUD Ina • :I PUMP 0.- PUMP ■ MANIFOLD _ ncR VALVE Lw� LP GAS _.II ■ T1 OH B U5TEH \ LINE / • . i FLUID TLNH-PIT p O - 3 x- 0 0 O v (D - N QV 3 0 HJ LA • Ln' N 00 NJ O F+ W Grayling Platform G -03RD2 Proposed 03/27/2013 11skrn -p . b,Mk..1.l.t. Grayling Tubing hanger, FMC -TC -B- G -03RD2 ESP, 11 X 3 1 /2 NSCT lift and 13 3/8 X 9 5/8 X 7 X susp, w/ 3" type H BPV 2 7/8 profile, 2- control lines, 4- 400 seal pocket, ported for BIW mandrel BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union Valve, swab,WKM -M, 3 1/8 5M FE, HWO, T -24�i ITV UI Valve, WKM -M, 3 1/8 5M FE, w,f .rl MA -16 operator N - \\. Valve, wing, WKM -M, ® te a` 2 1/16 5M FE, HWO, t3 ° i o , ° O - + I w : T -24 >>w. Valve, lower master, :,,r D -1 WKM -M, 3 1/8 5M FE, HWO, p 0 40 T -24 III is Adapter, FMC -ESP, 11 5M Rotating Flange X 3 1/8 SM Attachement spool, u, ��� Rotating flange, w/ 2- control FMC TC - ET, 11 5M FE ��l,I line exits, 4-400 pocket prep, — . I� alloy material btm X 11 5M FE -; — I `- �_ . Spool is used for space lli • to get extra flex in tubing °.� for27/8 @3 %ESP hanger in 7" casing eapl tie= Tubing head, CIW -DCB, 'el s. Valve, wing, WKM -M, 13 5/8 3M X 11 5M, - 2 1/16 5M FE, HWO, w/ 2 2 1/16 5M 550, o no ® �■ T-24 X- bottom prep, o& ill • P .> l 1 % VR profile it 111 al] Casing spool, CIW -WF, 1 135/83M X 135/83M, 1 / 1n w/ 2- 2 1/16 5M EFO, X bottom prep I,I I i'' e� GLF CiW bail valve =LJI t .71 111 * 1st Casing head, Shaffer KD, 13 5/8 3M X IN NI 13 3/8 SOW, w/ 2- 2" q � � LPO, 1.11 I'n lift" r • • Schwartz, Guy L (DOA) From: Ted Kramer <tkramer @hilcorp.com> Sent: Tuesday, March 26, 2013 10:55 AM To: Schwartz, Guy L (DOA); Ferguson, Victoria L (DOA) Cc: Juanita Lovett Subject: G -3RD2 Sundry Application Guy and Victoria, I wanted to give you both a heads up that the above well is going to be the next Grayling well we go to after the G -7 (Currently on). We anticipate being off of the G -7 in seven to ten days. Any help you could give us in expediting the Sundry application would be appreciated. This Sundry application was sent over to the AOGCC on 3/18/2013 and represents the new plan forward for theG -3 RD2 well. Background: Hilcorp was on the G -3 RD2 from mid - January 2013 to February 25, 2013. During this workover it was determined by a casing inspection log that the 7 inch casing was damaged due to corrosion. After examining the options to repair this well it was determined that the best option to repair the well would be to run an ESP with two DESP packers and isolate the bad casing section between the two packers. Prior to getting off of the well, Hilcorp confirmed that the casing was good (via 15 minute pressure tests) from 9,203' down to the CIBP at 10.165'. And from 5,882' up to surface. The long section of damaged casing (3,321') created several issues with the main two being: 1. The section was too long to run a casing patch because there is not enough patch material available, and with this long section of patch, the ESP would have to be banded instead of clamped through this section. This long area causes problems with the bands catching and being torn off on the entry point and exit point of the patch. 2. Running a conventional liner is not an option because the internal diameter of the liner would be too small to run an ESP through. Hilcorp believes that the best option for returning the well to production is to install the ESP as mentioned above and in the Sundry application. Thanks for your time and consideration, and please let me know of any questions or concerns you may have. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 -867 -0665 1 STATE OF ALASKA , ,;., � 1 . - i.Js3 ALA KA OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS A0000 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing IS Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weill] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development J Exploratory ❑ 183 -010 ' 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20049 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: -, ADL0018730 ' Trading Bay Unit / G -03RD2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): McArthur River Field / Middle Kenai G Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,050 feet Plugs measured 10,165 & 10,870 feet true vertical 9,787 feet Junk measured 10,627 feet Effective Depth measured 10,870 feet Packer measured 10,627 feet true vertical 9,631 feet true vertical 9,421 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760 psi Production Liner 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED APR 1 9 2013 True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 EUE 2,643' (MD) 2,566' (TVD) 10,627' (MD) Packers and SSSV (type, measured and true vertical depth) Junk Packer 9,421' (TVD) SSSV - N/A C li'; /4 0 /O 1 /CS . 12. Stimulation or cement squeeze summary: C. Intervals treated (measured): t i_? 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 0 200 300 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 12 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . p Gas ❑ 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: 312 -421 Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature .:4 / Phone 907 777 -8420 Date 3/15/2013 RBDMS MAR 15 2 y•(4.13 Form 10 -404 Revised 10/2012 Submit Original Only • • McArthur River Field, TBU SCHEMATIC Well: G -03RD2 Hamrp Alaska, LLC Completed: 02/24/2013 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. Note RKB to TBG Hngr = 40.90' 26" Surf. 343' 26j L 13 -3 61 J -55 Butt 12.515 Surf. 2209' 47 P -110 8.681 Surf. 78' 13 -3/8" 9 -5/8" 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' ' 'Dv@ P -110 7,295' 11,045' 3,421' TUBING DETAIL 2 -7/8" I 6.5 I L -80 _ EUE I 2.441 I Surf I 2,643' I Kill String DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth OD ID Item 1 10,165' CIBP 2 10,627' N/A N/A Junk Packer 3 10,870' N/A N/A Cement Retainer I PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed 5/11/1983 Squeezed 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Open 9 - 5/8Z ' HB - 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 DST- Squeezed 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Open 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Open 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Squeezed 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Open HB-2 P 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Squeezed L k,G 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Squeezed 1 HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed HB -1 E HB -2 2 3 L TD = 11,045' ETD = 10,130' Max Angle =34.8° @ 7,600MD/ 6,828TVD Revised by JLL 03/04/2013 • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 Daily Operations: 01/14/13 - Monday Leg move - Rigging up. 01/15/13 - Tuesday Leg move - Rigging up. 01/16/13 - Wednesday Rigging up. 01/17/13 - Thursday 48 hours notice provided to State for BOPE testing. Set BPV. Nipple down & remove wellhead. Install riser & BOPE. Continue with winterizing rig. 01/18/13 - Friday Continue Rigging up and winterizing rig. 01/19/13 - Saturday Preparing to test BOP. Pulled BPV & installed 2 way check. Closed in blind rams & tested to 200 psi low, tested ok. Increased pressure to 3,000 psi, had leak at the graylock connection. Repaired & retested. Lost 100 psi in 5 mins. no visual leaks seen. Pulled 2 way check & re- installed BPV. Continue with winterizing unit & assisting welders on pipe rack. 01/20/13 - Sunday Continue Rigging up and winterizing rig. 01/21/13 - Monday Continue Rigging up and winterizing rig. Prepare crossovers for BOPE testing. 01/22/13 - Tuesday Preparing to test BOP. Pulled BPV & installed 2 way check. Installed the 4 -1/2" EU X 3 -1/2 Butt Crossover below landing joint & screwed same into hanger. Fill stack with water. Close in pipe rams & attempt to test 200 psi low & 3, 000 psi high. Test failed on high side. Leaking connection on test pump. Repaired & re -test. Continue to try & test BOPE. Backed test joint out. Test joint broke at pup jt not at hanger. Still below blinds. Closed in blinds & retest. Low test ok but lost 100 psi on high test. Found leak on riser flange. Bleed off & attempt to tighten same. Removed all bolts from flange . Re- tighten same with Hyd torque wrench to spec. Attempt to retest Blind rams. Got good test on blinds & C -1. Belts on accumulator pump broke, no replacements on board. Using air pumps for pressure. Installed test joint. Attempt to test Hydril to 200 psi, no test. Continue to work air out of system. Pulled pipe rams & inspected same. Changed door seals & button up same. Close Hydril & test to 200 psi low, held good. Increased to pres to 2,500 psi. Lost approx. 100 psi in 10 mins. No visible leaks seen. Bleed pressure off & circulate through stack to make sure all air is out of same. 01/23/13 - Wednesday Continue preparations for BOP testing. 01/24/13 - Thursday Winterize rig. Continue preparation for BOP testing. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 Daily Operations: 01/25/13 - Friday Pulled BPV & set 2 way check. Closed blinds & test 2 -way check, no test. Pulled Check & found rubber seal missing. Replace seal & reset 2 way check. Closed blind rams & retest, good test. Open blind rams & install test joint. Standby for State rep for BOPE test. Continue with cleaning of rig & work areas. Received go ahead to begin BOPE testing before State Inspector arrives. Begin testing BOPE. State Inspector (John Crisp) on board to observe BOPE test. Tested BOP 250 psi low / 3,000 psi high. Test completed with no issues. Rig down testing unit. Pull 2 way check. Screw in landing jt with TIW valve to hanger. Back out hold down pins. Work hanger free with 98,300 Ibs of pull. Pipe appears free, pulled hanger to surface, 67,3601bs hanging weight. Estimated pipe to be parted @ 7500' + / -. Rig up hyd tongs, slips & safety equipment. Set up to POOH with tbg. Removed hanger & cross over. Begin pulling out of hole, laying down tbg & rolling up control line. 3 jts out found control line parted (90' out). Do not see control line attached to tbg. Continue pulling tbg. Pulled 16 jts out, bundle tbg to move same with crane. Crane broke down (2 -blk switch). Standby for crane to be repaired. Continue pulling tbg. Keeping hole full with inlet water. 50 jts out at report time. 01/26/13 - Saturday Install TIW valve & hose. Circulate well out. Only a trace of oil seen in returns, mostly gray dirty water. Drain All lines after circ., Continue POOH with tbg. Tbg. is severly pitted with several large holes begining @ jt# 161. POOH with parted tbg. Jt # 203 parted leaving a 5' stub above GLM # 4 @ 6,389'. Recovered 202 full jts, 3 GLMs & 2 6' pups, 6,338' OAL. Moved fishing tools over to catwalk & prep same. Change out the 3 -1/2" pipe rams for 2 -7/8" pipe rams. Set test plug in hanger. Fill stack with inlet water & re -test 250 psi low & 3,200 psi high. Held each test for 5 mins. Tested good. Bleed off pressure. Drain lines. Remove test plug & installed wear bushing. 01/27/13 - Sunday Begin making up fishing tools, 5.75" OD with a 3.50" catch, overshot, 5.75' of extension, jars , 4 4 -3/4" DCs & 4 -3/4 Jar Slinger. Cannot get tongs to properly engage workstring. Working on power tongs. On downtime. Made up BHA & 4 DCs. Handled BHA in hole. Found a way to make tongs grip DCs & Jar. Made up BHA. Pick up the 2 -7/8" IF DP W /S. Cannot get tongs to grip tool joints. Back on downtime. 22 hrs down for the day. 01/28/13 - Monday On downtime waiting on parts for power tongs and or Hawk Jaw Jr Tongs. Offloaded Hawk Jaw tongs from workboat. Rig up Hawk Jaw tongs. Extend hyd control hoses & fab new and longer hoses for lift cylinder. 01/29/13 - Tuesday Rig up Hawk Jaw Tongs & power supply. Attempt to use Hawk Jaws, could not get lift cylinder to work properly. Rig Hawk Jaw tongs down & set out of the way. Rig up Williams Foster tongs with the correct tong dies. Continue in hole with BHA# 1, drifting & measuring workstring. Attempt to work overshot over fish & latch same. 01/30/13 - Wednesday Tagged up @ 6,294' DPM worked pipe down to 6,317' DPM. TOF should be 6,372'. Rig up kelly hose. Reversed circulated @ 2 bpm 500 psi. Recovered fill & crudy water. Rigged up power swivel. Rotated & washed down to 6,392' DPM. Rig swivel down. POOH standing back doubles. String is pulling wet. Rig up Kelly hose. Pressured up to 2,500 psi on tbg cannot break circulation. Rig down hose. Rig up mud bucket & set up to pull wet string. POOH with workstring, pulling wet. Handle BHA out of hole found 1 jt & top DC plugged up. Laid out same. Broke down over shot, no fish inside. Cannot tell for sure if fish ever went inside overshot. Paint is worn off on leading edge of overshot. Work at unplugging drill collar & jt of tbg. Found a stainless steel band, rocks & a chunk of Hydril rubber in pipe. • Hilcorp Alaska, LLC • p , Hil *rp Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 Daily Operations: 01/31/13 - Thursday Set test plug in hanger. Close in Hydril & test, 250 low & 2,000 psi high. Tested good. Pull test plug. Make up BHA, 5.75" Overshot dressed with a 4.25" catch & 10.5' of extension. Handle BHA in hole with jars & DCs. Found debris in DCs, cleaned out same & continue. RIH with work string. Tagged up on Jt 197 @ 6,392' DPM. Rigged up power swivel. Unable to rotate over fish. L/D 2 jts & make up 3 drill pipe pups to move tool joint away from Hydril while washing. Begin washing / rotating above fish. Slacked off slowly & set 5K down, stalled out Swivel. Picked up on fish to 90k, good engagement of fish. Pulled up slowly to 136k in 3 -4 K increments. Fish broke free. Gained 3 -4K Ibs of weight. Rigged Power Swivel down & removed DP pups fron string. Start POOH slowly with fish. 8 stds out, stopped to adjust brakes on rig. Continue POOH slowly with fish. Rack back DCs & lay out BHA. 02/01/13 - Friday Out of hole with fish. Recovered GLM # 4. Cross over directly below GLM had parted. Shuck fish from overshot. Fill hole. Set 9 -5/8" test plug in hanger. Begin testing BOPE. 250 low & 3,000 psi high. Witness of test waived by Jim Regg, AOGCC. Pull test plug from hanger. Drain test pump & lines. Make up BHA #3, 5.75" X 3 -7 8 Catch Overshot with jars & DC's. Handle same in hole. Tripping g p p P " " ' / jars pp g in hole. Rig up power swivel to tag. Closed hydril & began circ down tbg. Tagged up on fish @ 6,405' DPM. Washed / rotated over fish. Shut down swivel & slacked off to latch fish. Straight pull on fish up to 50K over pickup weight in 3K increments. Fish is not moving. Began jarring with 20K over. Increased jarring to 45K loads, straight pull to 50K over. Made numerous jar attempts. Rigged swivel down. Increased jar hits to 70K over with a dead pull to 90K over pipe weight. After several hits either slipped off or parted fish. Picking up @ 81k (normal) with workstring. POOH standing back workstring. Stand back drill collars & handle BHA out of hole. Pipe parted at crossover that was below GLM. Leaving a special clearance collar looking up. 02/02/13 - Saturday Recovered Buttress crossover sub in overshot. Clean up work area while Knight service techs work on Accumulator system. Make up BHA #4, 5 -3/4" OD wave shoe, 7 jts of 5 -3/4" wash pipe, oil jar, (4) 4 -3/4" drill collars, 4 -3/4" slinger jar, 2 -7/8" IF box X 3 -1/2" IF pin x- over, total length= 389.14'. RIH with BHA # 4 and 2 -7/8" DP to 6,388'. P/U & M/U power swivel & washed over top of fish @6,405' DPM while reverse circulating. Continued reversing and had fine scale in returns at bottoms up. Continued washing over production tbg to 6,629' Note: reverse bottoms up at each DP connection total length washed over = 224'. Rig down power swivel, POOH with 2- 7/8" DP to BHA #4 ( washover assy.). BO & LO 5 -3/4" od wash pipe. 02/03/13 - Sunday Continue LO 5 -3/4" washpipe. PU and MU BHA #5 -- 5 -3/4" overshot, 4 -3/4" bumper sub, 4 -3/4" oil jar, (4) 4 -3/4" drill collars, 4 -3/4" slinger jar, 2 -7/8" IF box 3 -1/2" IF pin x -over, total length = 161.45. RIH to 6,405' DPM and latch 3 -1/2" production tbg. Jarred on fish with 60k to 85K over PU wt & straight pulls of 170K to 180K while pumping down DP at 1 -1/2 bpm 1100 psi. Fish came free with a jar of 85K & straight pull of 185K. POOH to surface with 2 -7/8" DP, BHA #5 and fish, gained additional wt of 28K of pipe weight. B/0 and L/0 jars and 5 -3/4" overshot. Change out tbg tongs & continue POOH laying out GLM's and production tbg. Recovered 66 jts. of 3- 1/2" tbg, 3 GLM's & 1 x -over, total length recovered = 2,090.73'. Clean rig floor and change out handling equipment to run back in hole with 5 -3/4" wave shoe & wash pipe. 02/04/13 - Monday P/U and M/U BHA #6. RIH with 2 -7/8 DP and BHA #6 to 8,336' DPM and string took weight (4k down ). P/U & M/U power swivel and rotate & wash from 8,336' to 8,347' & started getting gas back in returns. Continue circulating gas out of well on choke. Continue washing down from 8,347' to 8,600'. Washed over top of 3 -1/2" production tbg @ 8,494'. 02/05/13 - Tuesday Continue washing down to 8,632' and power swivel shut down. P/U off bottom and continued circulating well. Continue washing down from 8,632' to 8,718' DPM. P/U off bottom 20' and set slips. Circulate well clean @ 2 -1/2 BPM, 1100 psi. Breakout power swivel and POOH with washover assy. B/0 and L/0 washpipe shoe and jars. Clean rig floor and rigup to RIH with fishing assy. P/U and M/U BHA #7, 5 -3/4" overshot, 4 -3/4" bumper sub & overshot, (4) 4 -3/4" drill collars, 4 -3/4" slinger jar, 2 -7/8" IF box x 3 -1/2" IF pin x -over. RIH with BHA # 7 to 8,494' DPM, tagged top of 3 -1/2" tbg with 10K down, Jarring on fish with 60k over PU wt. (PU wt = 108K, SO wt = 74K) • • Hilcor p Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 02/06/13 - Wednesday Continue jarring on fish with 60k over pull. POOH with fishing BHA and 3 -1/2" prod. string. Break out collars and jars. Break overshot from 3 -1/2" production tbg fish and change out tongs. POOH laying down 14 jts of 3 -1/2" tbg and 1 GLM total length laid out = 446.35'. Slip and cut drill line. Service rig. PU & MU wash over BHA #7, 5 -3/4" wave shoe, 5 jts of 5 -3/4" washpipe, 4 -3/4" bumper sub & oil jar, 4 jts of 4 -3/4" drill collars, 2 -7/8" IF box x 3 -1/2" IF pip x -over, total length = 357.01. RIH with 2 -7/8" DP and BHA #7 to 8,914' DPM. PU & MU power swivel. Attempted to break circulation in reverse and down the drill pipe w/o success. RD power swivel. 02/07/13 - Thursday Work pipe up hole to 8,869'. PU power swivel and circulate well while trouble shooting draw works motor. Wash and rotate from 8,869' to 9,134' ( washed over top of fish 8,941'). Circulate well bottoms up at 2.8 bpm, 1000 psi. 02/08/13 -- Friday Continue circulating bottoms up. BO and LO power swivel. POOH with 2 -7/8" DP and washpipe. BO jars and bumper sub, stood washpipe back in derrick. Test manifold lines, valves and pipe rams to 200 psi low / 3,000 psi high on chart for 5 min, test annular to 200 low for 5 min test ok. Attempted to test annular to 1500 high w/o success, function & washed inside of annular and unable to get test. RD down tongs, wind walls rig floor, walls around BOP stack, drip pans & ND Annular. Change out annular rubber and start NU same. 02/09/13 - Saturday Finished NU annular, installed floor and wind walls. Test annular to 250 low and 1,500 psi high on chart for 5 min. Tested ram 200 psi low / 3,000 psi high. Witness of test waived by Bob Noble, AOGCC. Rig up tongs & slips. Change drag blocks in Foster tongs. PU and MU BHA #9, 5 -3/4" overshot, bumper sub and oil jars, (4) 4 -3/4" drill collars, slinger jar, 2 -7/8" IF box x 3 -1/2" IF pin x -over. RIH with BHA #9 2 -7 " drill pipe 7 K 80K v 9 & /8 d I p pe to 8,944' and latched onto 3 -1/2" production tbg, jarring on fish with 0 to 80 over PU wt PU wt = o e 110K ). Hook up Kelly hose and circulate @ 3 -1/2 BPM with 1000 psi while jarring with 80K to 90K over PU wt. 02/10/13 Sunday - Continue jarring on 3 -1/2" fish with 80K to 90K over PU wt. Rotate off fish and RD power swivel. POOH with 2 -7/8" DP and BHA #9. Changed dies in power tongs & adjusted brakes on draw works. Continue POOH with BHA #9. BO & LD BHA #9 ( jars & over shot ) recovered 3 jts of 3 -1/2" tbg total length= 93.45'. PU & MU Outside cutter assy, 6" wave shoe, 5 -3/4" friction cutter, (6jts) 5 -3/4" washpipe, 5 -3/4" bumper sub & oil jar, (4) 4 -3/4" drill collars, 4 -3/4 slingerjar, 2 -7/8" IF box x 3 -1/2 IF pin x -over, total length 362.10'. RIH with cutting BHA. PU and MU power swivel. Repairing HCR valve. 02/11/» - Monday Continue in hole with BHA #9 to 9,114' and unable to work pipe deeper. Attempted to work deeper by pumping at 3 BPM @ 1200 psi and rotating pipe at 55 rpm ( power swivel stalling out at 5500 ft /Ibs of torque). PU off bottom putting knives at 9,107' started rotating at 50 rpm 5200 ft/lbs, ( rotating wt = 90K ,circulating at 3 bpm, 1200 psi ). Hydril started smoking shut down pump and opened same & continued cutting tbg. Torque dropped off to 4500 to 4800 ft/lbs, pulled 3 joints attempting to located tbg collar w/o success. RD power swivel and POOH BHA #9. BO & LO same. Found wear on 1 knife in cutter indicating cutting of tbg, 2nd knife had no wear and 3rd knife broke off at weld & lost in hole. PU & MU BHA #10, 5 -3/4" overshot, 4 -3/4' bumper sub & oil jar, (8) 4 -3/4" drill collars, 4 -3/4" slingerjar, 2 -7/8" IF box x 3 -1/2" IF pin x -over, Length = 287.08'. RIH to 9,037' DPM and latch fish with 10K down (SO wt = 60k , PU wt = 120K). RU & start jarring on fish with 60 to 75K over PU wt, oil jars stopped hitting after 14 hits. Work pipe attempting to get jars working again w/o success. Mechanical jar and dead pull on fish with maximum pull of 200K. PU power swivel and rotate off fish. LO power swivel POOH with BHA #10. 8r- TR:it Continue POOH with BHA #10 ( overshot, jars & collars ). BO & LO BHA #10. Change out HCR valve and test same 1800 psi. Tack weld hand rails down around pipe rack. PU and MU BHA #11, 6:00" OD wave shoe, (7jts) 5 -3/4" OD washpipe, 4 -3/4" OD bumper sub & oil jar, (4) 4 -3/4" OD drill collars, 2 -7/8" IF box X 3 -1/2" IF pin x -over, total length of BHA = 379.21'. RIH with 2 -7/8" DP and BHA #11 to 9,000'. Swap out power swivels. PU and MU power swivel and circulate down from 9,000' to 9,037' dpm. • 1 • Hilcorp Alaska, LLC Hileorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 Daily Operations: 02/13/13 - Wednesday Circulate well at 9,037' at 2 -1/2 to 3 bpm with 1000 psi on DP while changing out control panel on power swivel. Continued rotating and washing from 9,037' to 9,150' pumping at 2 -1/2 to 3 bpm 1000 psi. Increase torque on power swivel and lost all rotation when 5000 ft /Ibs of torque achieved. Circulate bottoms up and pull up to 9,032' and change out power swivel. RIH to 9,130' and rotate and wash down to 9,264'. Circulate bottoms up and 2 -1/2 bpm with 1000 psi on DP, at bottoms up, had gas bubble, max gas = 30 %. Continue circulating gas out of well at 2 -1/2 bpm with 1000 psi on DP while hold 150 psi back side pressure. Shut down pumps opened annular and monitored well for flow for 30 mins. (NO FLOW). RD power swivel, lay out 1 single & POOH with 2 -7/8" DP and wash over assy. 02/14/13 - Thursday POOH with wash over assy. Break out and lay out jars wash pipe and wave shoe. PU & MU BHA #12, 5 -3/4" overshot, 4 -3/4" bumper sub and oil jar, (4) 4 -3/4" drill collars, 4 -3/4" slingerjar, 2 -7/8" IF box x 3 -1/2" IF pin x -over, total length = 161.97'. RIH with BHA # 12 to 9,037' latched & jarred on fish 4 times with 75K over PU wt, fish came free, pipe wt. increased 14K, POOH with 2 -7/8" DP and BHA #12. BO and LO BHA # 12 jars, bumper sub and overshot. BO and LO 12 jts of 3 -1/2" production tbg & 1 GLM with pups & x -over. Total length recovered this trip = 385.01'. Estimated top of fish now at 9,422.46'. PU & MU BHA #13, 6 "od shoe, (7jts) 5 -3/4" wash pipe, 4- 3 /4 "od bumper sub & oil jar, (4) 4- 3/4" drill collars, 2 -7/8" IF box x 3 -1/2 IF pin x -overs total length = 379.50. RIH with 2 -7/8" drill pipe and BHA #13. 02/15/13 - Friday Continue RIH with BHA #13 (5 -3/4" wash over assy) to 9,346'. PU power swivel, rotate and wash from 9,346' to top of fish 9,422, went over top of fish w/o any problems and continued rotating and washing to 9,646'. Circulate well clean. Fine scale in returns. Shut down pumps check well for flow. L/O power swivel. POOH with 2 -7/8" DP and BHA #13. BO and LO BHA #13. RU to test BOP's, manifolds, safety valves & lines. 02/16/13 - Saturday Test TIW valve. IBOP to 250 psi low and 3000 psi high on chart for 5 min. Test BOP's pipe, blind rams, manifolds, lines & Kelly valve to 250 psi low & 3000 psi high for 5 min on chart. Witness of test waived by Jim Regg, AOGCC. Pulled test plug and installed wear bushing. PU & MU BHA #14, 5 -3/4" od overshot, 4 -3/4" od bumper sub & oil jar, (4) drill collars, 4 -3/4" od slingerjar, 2- 7/8 "IF box x 3- 1/2" IF pin x -over. RIH with 2 -7/8" drill pipe & BHA #14 to 5,000'. Air lines froze up to valve bank on drillers console that operates power tongs, cat lines winches. Relocated heater hoses and thawed out same. Continue in hole to 9,422' DPM and latch fish with 10K down. Jarred on fish with 40 -75K over PU wt ( 102K ) and fish came free after 6 hits of jars. Gained 28K in pipe & drag. POOH with 2- 7/8" DP, BHA #14, & 3 -1/2" production fish. 02/17/13 - Sunday Continue POOH with fishing BHA and 3 -1/2" production tbg fish. Circulate and balance well bore fluids. Continue POOH with DP and BHA #14. BO & LO jars & overshot, 7 jts. of 3 -1/2" tbg, 2- GLMs assy., locator seal assembly, x- nipple and w/I entry guide. total recovered this trip = 867.94. RIH with 5 -3/4" washpipe and POOH. LO same. MU BHA # 15 6 "od bit, 4 -3/4" od bit sub, 3 -1/2" IF box x 2- 7/8" IF box x -over, (2) string mill 6.125" OD, total length = 15.77. RIH to 2,250' and tagged up with 15k down. PU & MU power swivel. Slack to 2,250' and attempt to break circulation w/o success. POOH checking for plugged pipe. OOH with 2 -7/8" DP, did not find pipe plugged at depth, pumped thru Kelly hose found it open, check power swivel and found kelley valve closed and goose neck froze up. PU and MU BHA # again while thawing out swivel with heater. RIH to 2,540'. PU & MU power swivel. Circulating at 2 bpm, rotating with 65 rpm and 1 -2K wt down. 02/18/13 - Monday Rotate and wash thru tight spot from 2540 to 2590', Continue in hole to 4720' and tagged up with 10k down rotated and washed thru with 60 rpm, 2 -1/2 BPM, 2 -5k down, Continued in hole working thru tight spots to 10,210', reversing bottoms up every 15 stands, PU 2' off bottom to 10,208' and while reversing out DP plugged, pulled 1 std and attempted to clear DP by pressure up on same to 2000 psi and surging same with out success. POOH wet with bit and string mills. • • Hilcorp Alaska, LLC Liilcorp.11aska.LL Well Operations Summary Well Name API Number Well Permit Number Start Date End Date G -03RD2 50- 733 - 20049 -01 183 -010 1/14/2013 2/24/2013 Daily Operations: 02/19/13 - Tuesday Continue POOH with string mills and bit, found bottom joint plugged with scale. Rig up wireline & ran 5.90 gauge ring and junk basket 8 to 10,172' WLM & POOH with same. Unable to confirm depth due to no gamma ray tool ran with junk basket. RIH with gauge ring �� and junk basket to 10,172' & POOH with same. MU bridge plug and setting tool. RIH and log same on depth and set at 10,165'. POOH li and rig down W/L setting tool & BO same. RU MSC logging tool, RIH to 10,165' and log up to surface. RU CIT logging tools, RIH to to OA 10,165' and log up to surface. RD logging and E -line. 02/20/13 - Wednesday Continue rigging down a -line unit. PU and MU Tri Point test packer and RIH to 6,005'. Attempt to test casing at 6,005', 5,978', 4,760', 3,495', 2,231'. Continue out of hole and changed out test packers. RIH to 9,366' and test down drill pipe to 1500 psi, for 15 min csg test ok. PU to 9,208', 9,203' DPM and retested to 1500' test OK. PU to 9,198', 9,196' DPM and attempted to test casing to 1500 psi below packer and test failed. POOH to 7,915' attempted to test casing with out success. 02/21/13 - Thursday POOH to 1,348' and attempted to test csg to 1500 psi w/o success. Continue out of hole to surface BO test packer and inspect same, no problems found. Wait on Retrivable BP to arrive location. PU and MU Retrivable BP and RIH to 1,534' and attempted to test csg from service to plug with 1500 psi and lost 200 psi per min. PU to 1,029', set plug attempted to test csg to 500 psi w/o success. PU to 500' set plug & attempted to test csg to 1000 psi w/o success. POOH to 60' set plug and attempted to test csg w/o sucess. POOH with Retrivable BP. PU and MU Retrivable BP & Test packer, RIH to 3,627' set plug released test packer and PU to 3,369'. Attempted to test csg to 1500 psi w/o success. Attempted to test csg at 3,558', 3,595' w/o success. Latch BP with test packer and RIH to 3,630' and reset BP and set packer at 3,625' pressured up on tbg to 1,000 psi testing csg below packer, good test. Latch Retrivable BP and POOH with plug and packer. 02/22/13 - Friday MU Champion packer & RIH t/ 1,516' dpm. Set & test packer t/1,500, test good. Move packer to 2,149' dpm test t/ 1,500 good. Move packer to 3,662' dpm test to 1,500, test good. Move packer to 6,314' dpm attempt to test packer, fluid coming up DP no test. Move packer to 6,882' dpm attempt to test, fluid coming back up DP no test. Move packer to 7,198' dpm test to 800 psi equal pressure on 9- 5/8", no increase on 13 -3/8 ", bleed down line up & test down DP w/ no pressure build. Move packer to 5,554' dpm test t/1500 good. Move packer to 6,061' dpm test t/1,500 had communication with 9 -5/8 ". Move packer to 5,871' dpm. 02/23/13 - Saturday Set packer @ 5,882'. Test t/1,500 psi hold for 30 min., good. Move & set packer t/5,944' attempt to test, no go. RIH t/ 9,156' set packer & test t/1500, slow leak. Move & set packer t/ 9,030' test t/ 1,500 w /slow leak. Move packer t/ 9,230' test t/ 1,500 w/ slow leak. POOH t/7,250'. L/D 2 -7/8" work string. (Note weekly BOP test 24 hr extention approved by Jim Regg on 2 -23 -13 @ 4:46 pm ), Continue L/d 2 -7/8" work string. Run stands in hole f /derrick. Pooh L/d pipe. L/D champ packer. Run 2 stands of collars in hole. POOH L/d collars. 02/24/13 - Sunday Finish L/D collars and clear rig floor. Change out handling equipment f/ 2 -7/8" kill string & prep to PU /MU mule shoe & RIH w/ 2 -7/8" kill string. MU hanger, xo & landingjt, land hanger, install TWC, run in L/D & packing, test t/ 5,000 good. R/d wind walls, floor & misc. Prep to N/D BOP's. Break bolts & remove drip pan. N/D BOP's, riser & equipment. N/U tree & test void t /5,000 psi. Continue prep rig f /skid. • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 22, 2013 2:31 PM To: 'Ted Kramer' Subject: RE: Grayling Well G -03 RD2 - Sundry # 312 -421 Ted, PTP Thanks for update... submit a 10 -404 with the work completed summarized. When you have a plan forward submit a new sundry as you mentioned below. Guy Schwartz From: Ted Kramer { a i,p_tkramer. 3:t?ijco p.corn] Sent: Friday, February 22, 2013 10:23 AM To: Schwartz, Guy L (DOA) SCANNED APR 0 9 2013 Subject: Grayling Well G -03 RD2 - Sundry # 312 -421 Guy, Hilcorp has found an unexpected amount of corrosion in this well bore in the 7" Casing String. We will most likely need to suspend operations on this well until a new forward plan can be completed and materials and equipment procured. To date we have set a bridge plug above all perforations at 10,165'. We plan to complete some additional diagnostics this weekend and then run a 2,500 ft kill string of 2 -7/8" tubing and then secure and move off of the well. An amended sundry will be filed once the forward plan is finalized. Please let me know if this is acceptable to the AOGCC or if we need to discuss further. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985 - 867 -0665 1 w w �����s, THE STATE Alaska Oil and Gas °ALASKA Conservation Commission c GOV ERNOR SEAN PARNELL � T , ,, 333 West Seventh Avenue p•- Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Ted Kramer Senior Operations Engineer 0 ! D Hilcorp Alaska, LLC 4 v 3 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G Oil Pool, TBU G -03RD2 Sundry Number: 312 -421 Dear Mr. Kramer: 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 ' . Foerster Chair DATED this 27 day of November, 2012. Encl. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'i�"" OCT 3 I, 20)2 APPLICATION FOR SUNDRY APPROVALS \\' 1)73 111E11 l a 20 AAC 25.280 AOGC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod 0 Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations El Perforate ❑ PuH Tubing El Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install ESP p 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development p 183-010 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic El Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20049 -01-00 ' 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? 76ii X ( 2- . C > �✓ Z (2.-- Will planned perforations require a spacing exception? Yes ❑ No p rf' Trading Bay Unit G -03RD2 • 9. Property Designation (Lease Number): 10. Field /Pool(s): / ` � /7 6:),' ///4.0(...)/ / ADL0018730 • McArthur River Field / c Oil Pool • C� r 6 • 5 /(- 7. / L. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,050 • 9,787 • 10,870 9,631 10,870' 10,627' Casing Length Size MD TVD Burst Collapse Structural Conductor 373' 26" 373' 373' Surface 2,209' 13 -3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,670' 9 -5/8" 7,670' 6,886' 6,870 psi 4,760' Production 11,045' 7" 11,045' 9,783' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3 -1/2" 9.2# L -80 10,285' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis BWH Perm Drill Packer and Otis SSSV Packer - 10,250' (MD) 9,100' (TVD) and SSSV - 344' (MD) 344' (TVD) 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch p Exploratory ❑ Stratigraphic ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 12/1/2012 Commencing Operations: Oil g • 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 Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone 907- 777-8420 Date 10/30/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ _ �� I Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ L Other: 8(43 /c5/ 3LU & A25 6 Spacing Exception Required? Yes ❑ No i Subsequent Form Required: / Li — U L APPROVED BY Approved by: 46 ,, COMMISSIONER THE COMMISSION Date: 1/— 2, -72— ', JE .6 PlOY 0 0RI al ■ I - /f� �ubmit Form and IV Ale ( is 012 Approve app lication is valid f • r 12 months from the date of approval. Attachments in Duplicate 1 `' ` ell Work Prognosis • ell: G -03RD2 xiiaia ®�,r.r� Application Date: 10/29/2012 Well Name: G -03RD2 API Number: 50- 733 - 20049 -01 Current Status: Oil Producer Leg: Leg #4 (SW corner) Estimated Start Date: December 01, 2012 Rig: Williams Rig 404 Reg. Approval Req'd: 10 -403 Date 10 -403 submitted: 10/29/12 Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 183 -010 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Mike Dunn (907) 777 -8382 (0) (907) 351 -4191 (M) AFE Number: 1221773 Budgeted Cost: Status: Shut- in.prbducer since Sept 2004. Tubing has multiple holes below 4,700'. Objective: Pull 4- 1 /2 ")GL completion, Isolate Hemlock, Perforate G -zone, Run 3 -1/2" tubing and ESP. Pro -zone at approximately 2,000 bfpd and less than 93% water cut. 1 Colic✓", // fld'CPd / or /Pt; 'p' ?r t (4 C � /911 Pressures: fn. ", / /c.V/ OP ,r5offar /fvelet .ov, 49 oeiT 754 e 7 ' Co yokie. +yea q cf /fit' - mr o^ s, /d D iv -. lc cOve,p A*4 14 e AViti The well has been shut -in since September 2004. The estimate bottom hole pressures are based on A. surrounding wells and the I/W ratio in the area. Recently the well was loaded with water. Based on the fluid � 2 depth of FIW, the reservoir and surface pressures are estimated and shown in the table below: Current BHP: - 3,500 psi @ 9,196' TVD/10,365' MD .38 psi /ft., (7.3 ppg) at mid -perf of Hemlock Max. Expct'd BHP: ^' 3,500 psi @ 8,850' TVD /9,960' MD .40 psi /ft. (7.6 ppg, G -Zone to be perforated) Max. Possible SP: 2,615 psi using 0.10 psi /ft back to surface Procedure: Pre -Rig Work 1. Load well with FIW. Shoot fluid levels on at least two occasions, at least one day apart. Note fluid level, calculate bottom hole pressure using 8.4 ppg. 2. RU E -line. Make impression block runs and /or dummy runs to determine where tubing can be cut with split shot, radial cutter, and /or jet cutter depending on well conditions. The objective is to cut as deep as possible, just above the seal assembly if possible, to make fishing junk tubing easy as possible. 3. After cut is made, circulate FIW around to displace any hydrocarbons that may be near the surface. Rig Work 1. Release rig from previous well. 2. Notify AOGCC of upcoming BOPE test (give 48 hours' notice to AOGCC to provide opportunity to witness) 3. LD mast. Skid the rig over the G -03 well slot. 4. Circulate FIW down annulus and up the tubing to kill well and displace all oil and gas from well. Allow well to stabilize. Shoot fluid level. 5. Set BPV in profile. ND Well head, NU BOPE and Test 200 psi low 3 000 •si on blindra o Note: If the BPV will not seat, shoot fluid again to confirm well is static. Test BOPE either on top of 2 -way check (per standard test procedure) or with a rolling test as described in Attachment #1. 6. Close blind rams. Raise Mast, secure guy wires, function test equipment. Prepare to pull completion. • e Il Work Prognosis ell: G -03RD2 fiaamew,.�.rc Application Date: 10/29/2012 7. MU to lifting threads and pull hanger and tubing. CBU. If a rolling test was done to test the BOP, LD one joint of tubing, MU new hanger or a test plug and conduct a full BOPE test per standard procedure. 8. Pull the tubing string as deep as the cut was made with E -line. Make overshot and E -line runs as necessary to recover all tubing. It is expected to have multiple holes which may present recovery challenges. Pull the seal assembly to recover all junk and expose the top of the packer. The packer can be left in the hole. 9. Make bit and scraper run to the top of the packer to prepare casing for a CIBP. 10. MU CIBP and RIH on workstring. Set same at 10,240' just above the BWH permanent packer. Pressure test bridge plug and casing to 1,500 psi. Circulate hole with clean FIW and prepare for perforating. Pump sweeps as necessary to clean up the wellbore. 11. MU SLB tubing conveyed perforating guns and perforate the G -Zone with SLB PURE (Dynamic Underbalance) TCP guns per perf design. Circulate out perf gas if necessary. PU perf guns above top perforation. Proposed Perforations Intervals To Be Perforated DIL Depths (Do Not Shoot) Tie -In Log Depths (Shoot These) Bench Top MD Btm. MD Top MD Btm. MD Feet GZN 1 9 , 175 `: 7 94 9,776 9,794 18 GZN 2 9,824 5,'64' 9,824 9,842 18 ® - _.. 9,899 9,935 36 10, 09'5 9,960 10,005 45 GZN 5 ',1 10,088 10,102 14 GZN 5 ru, !;," 10,120 10,138 18 149 ft. 12. Monitor well for no flow. Shoot successive fluid levels to determine new bottom hole pressure. When well is stable, POOH, LD workstring and spent perf guns. 13. MU motor and pump and cable spooling equipment and run ESP and 3 -1/2" tubing. Place bottom of pump within 100' of the top G -zone perf at approximately 9,700' MD (8,621' TVD). Run SSSV nipple and control line to a depth of 300'. Land hanger and secure all penetrations. ND BOP, install new tree. Turn well over to Production Supervision for final hookup of ESP. Place well on production. /Vn F/c t' i• 5 t rr t _ , --t d 4-0 Will ,--/- b l 6 .5, O G� C � / u I.✓ r T S 5 1 0 [ o w' .5 `* N • 0 ell Work Prognosis ell: G -03RD2 HilcorpAlseke,l.1.0 Application Date: 10/29/2012 As -built (Old) Wellbore Schematic C4SING DETAIL PKeto tot I.ELEV= 103.0' SIZE 'PST GPN.DE CONN ID TO P ETM. RYE toTM Hrrr =40.97 26' Surf. 343' 1 1 L 13•x" 81 155 Eutt 12515 _turf. 2203' .•�, 47 P.110 1 .N1 Surf. 73' 9.5 / 1" 40 1430 Eutt 3235 73' 4,814' 13-313:, b.. 43.5 P110 3.755 4,614 770' 1430 Surf. 7,235' 7" ro P110 Butt 6 184 7,2235' 11,045' �DVP • •A21' TUBING DETAIL I' 3.1/2" I 9.2 I L -30 I TOSSC. I 2992 I Surf. I 10,214' 2 0 7,421'to 3.427' JEWELRY T 1 DETAIL No Depth OD ID Item 4093 CIWTM ring (4-1 /2 " ETC Top Y.4.1 /2"Srd btm) r 409' 4.25" 2992" 4.1/2"3 rd Pin X 34 /2' Pin pup 1 333' 3275' 2.750' 31 /2 "SSSV Nippur if 6XE EbllVake 2,291' 5.25" 299 3-1/2' PT4 " DSO' Gas-Lift Mandrels 3954' 5 25' 2992" 31/2' PTA 'DSO Gas•tift MannreIs 5,299' 5._5 2992' 31/: PTA ° U 0` Gas - lift Manlre Is . 6,x..4' 5.25" 2992' 3.1 / " PT4'PM'Ga1• Lift r 7,273' 5.25" 299 31/2 " PT4 " 32 Cas- lift rotaMrels 2 3,309' 5.25" 2992" 34/2' PT4 "DSO "Ca5• Lift Mar I9IS 3,435' 5.25' 299 31/2 "PT4 'D0 Gal' lift Ma ni re Is 3930 5.25" 7 799 2" 31/2" PT4 "1300'Ca1 -lift ManlreIs 9,105' 5 . 2992" 3-1/2' 914 "1790 "C92. Litt Ma Mrels 9,343' 5.25' 2992' 31/2'914 "P.3'Ca2. Mandrels 10,135' 5 25' 2992' 31/? PTA "oiT Gas -Litt Mandrels 3 10,174' 450' 2.750' 026X4596'? 4 10,X6' 444' 2992" Ot6StraigMSbt tcrator MOO 5 10 ' 0' 7' Ot6EWMPenns Drill Paclr r.,6;:SEE 9.5/SZ , 6 10,10' 400" 2992" 0te10'e4 "Sealassembty 7 10,251' 7,750' 31/2' 016 "k' Nipple 3 10,734' 3375' 299 31 /2'WLRG 9 10,677' W4 N/A Junk. Pat ker 10 10,370' WA N/A Cern_nt Retainer W. - _ - 4 PERFORATION DETAIL a raP(P'lD Present . i ...mow ' ,; ® Zone ) Etm(fv1D) Top(TVD Etm(TVD) Amt Date Condition 10,294' 10, 9 1 3 j' 9 ,1 2' 5/5/1933 Squeezed 3 Ee HEi-1 5/11/1933 Squeezed 10,307' 10,337' 9,143' 9,173' :0' 4/20/1991 0 91 n - HB-2 HE - ' 10,310' 10,11' 9,150' 9151' 1' 5/9/1933 DST- Squeezed 10,317' 10,344' 9,158' 9 ,179' 12/22/1939 0915 " 10,332' 10,337' 9 ,199' 9 ,173' 5' 3/11/1934 Open 10,365' 10,.43' 9 ,197' 9,217' 73 5/10/1933 Sgtvezel 10 -, - -" - - 10,3■Z' 10,422' 9,197' 9,246' 57' 111/1939 Own H &2 • 10,3M' 10,373' 9 r7 9,:31' 5' 3/10/1934 5(4 Ue9 e r Z TD. 11,045' ETD =10 ,1 3' 10,332' 10,422' 9,220' 9,246' 37 12121/1939 Squle:ej Max Angle= ?4,8 ° @7,6COMD /=STUD 1 10,682' 10,654' 9,443' 9,445' 2' 5/4/1933 SgUeeled Revise d by TDF 10/3/2012 �Q( Work Prognosis • e G -03RD2 , . , H ,, Hiko.pAlaeke,LLC Application Date: 10/29/2012 . Proposed (New) Wellbore Schematic CASING DETAIL " - _ -- -- -" -- - SIZE Os GRADE COA ID TOP BT7v I I 25• Surf. 3 =3 .eJ I l U_ LL 13 -318" 51 3-55 Butt 12515 Surf. .._- 47 a -111 3 581 Surf. 3 -5,1' 4C 4•33 butt 3935 78' _ __- - -- c 433 9755 4.554' 7 5 7 1 29 - bun 5.184 :-11: rf' 7295' B 7,295' 11,.045" I3 TUBING DETAIL ' ) 3-1/2" 1 92 1 1-3C 1 IDS sC. 1 2.992 1 Surf. 1 ±9,720' I I DV Ca @x @ 3A21'to3,423 JEWELRY DETAIL No Depth Item 1 103" 3 -1f2• Hanger Azov. 2 3500' Rap* for' 5554' 3 39,396 Head Bak On 0 iscirarge 39,395 Pump SLb D35CON -5 sections :3 514 Punt's Intake ±9 ,517 9rotectars- Mammas 1.5690 -U7f21 Top a Mawr 5L0455, 18, 4153 7 49,533 Macimus - 2 mown ±9.600' Bettor, of EsP ±10240. cc* an tap of old packer L - _ _ 10927' )wr4 Parke r __ 10970' Cement Retainer PERFORATION DETAIL Zcne - - 'iiD) MD) Top[TVD .El, VD i Cate PresentCondi0or • 5 -1 39,776 39,794' ±8,688 '18 Future t}pen B v 2 39924' ±9,342' ±5,731 _3,74' ±18' Future Open _ 2 -3 ±9999" ±9,935' ±8,797 '8929 ±36' Future Open G' 2-4 ±9,950' 310,005' ±8 ,350 -3991 245" Future Open 3 • - ±10,389 ±10,102' 38,951 _5,973 ±14' future Open 9 — G-5 G-5 ±10,120 ±10,135' ±8,989 :9,084 218' Future Open — 1$t 10294' 10296' 9,137' 3.139 2' 5/511983 Isolated 5/11/1983 Isolmd e FFB 10,307' 10,337' 9.148' 9.173 30' 4/2011991 Isolated 95-1 _ _ 10 10910' 10.311' 1.150 9.151' 1' 5/9/1933 'solaced 4 10317' 10,344' 1,154 3179' 27' 12/22/1939 related 10932' 10,33?' 9.159' 9173' S' 3/11/1984 solaced 11 10365' 10,338' 9.197' 9217' 23' 5/10/1983 Isolated 10 ,365' 10,422' 9,197' 9245' 57' 12/21/1989 °salated TD= 11,350' 10,358' 10,373' 9200' 9204' 5' 3/10/1954 crated V aX AngLe= 342° 1 7,5X4AD' 0,828TVC _1 592 10 ,422' 9,220' 9246' 30' 12 ?21;1999 sc ated - _- e,_ 18.834 9 A13' 9,,145' 2' 5 :4:1953 sc'oted dell Work Prognosis • ell: G -03RD2 1li lrnnp,�laH�a,1,�,� Application Date: 10/29/2012 Williams Workover Rig l 1 Grayling Platform 0 BOP 2012 ��I1 fI I[i1 III�Lllll ti l €71 Weatherford Rental BOP Width 4.16' 174' Weight 13,100# Shaffer 111 111 111 111 111 Shaffer LWS Total BOP height above 135 /85M - doll deck 135 /B 5M LWS L -® - ® .. 948' min . dimensions \ - - 11.48' max Length 7.73' ) - _ 100' Width across body 2.72' Width across flanged - outlets 4.00' Weight9500Ibs 9.00'_._ 111 1!11!1 111 III , ♦1 Mud Cross 'p 2850Ibs w/ valves 1� k !� . e� I ` f 140'4 1.74' ILk • a � I11 111 111 - • Riser above drill deck I t I (11 This number will vary [ from well to well 1.00' to 3.00' Drill Deck 13 5/8 5M Riser 85001bs 15.00' 111 111 Spacer Spool 13 5/8 5M X 13 5/8 5M 1 . 95 ' 1800lbs I Iii il� 111 Crossover Spool 135/85M X115M 18001bs 2.83' I I1 Top of Wellhead , eii Work Prognosis ell: G -03RD2 xii Alaska, Application Date: 10/29/2012 • Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Williams Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND /NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and /or corroded and BPV cannot be set with tree on, Profile and /or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. Conduct Rolling Test. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift- threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift- threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify office via e-mail that neither profile will allow for a test of the BOP. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid /pump rate into the well. Record the pumping rate and pressure. • AO Work Prognosis ell: G -03RD2 Application Date: 10/29/2012 Hilcorp Alaska, LTA: e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger /BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C -1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C -1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. We ll Work Prognosis ll: G -03RD2 x,Paiaa�,i.�c Application Date: 10/29/2012 e) Close C -2. This is the HCR (the hydraulic controlled remote) valve just outside C -1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C -1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K -1, K -2, and K -3 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure ". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2 set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi "). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut -off after the pressure to builds back to original pressure ( +/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto ", not "Manual" so the pumps will kick -off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10 -424) in Excel Format and e-mail to AOGCC and Juanita Lovett. ell Work Prognosis • II: G -03RD2 xclnl.•k,,4rc Application Date: 10/29/2012 Diagram A -1: Grayling BOP stack and Riser Arrangement — Typical for Single Completion Williams Workover Rig Grayling Platform BOP 2012 • • III III IiI lil iii III IiI III Width 4.76 ' 374 III III III III IIf1 • • 135 /85MLWS dimensions Length 7.73' - 3.00' Width across body 2.72' Width across flanged . - outlets 4.00' II �f 1 � � > }► �� T'g ��� �fI 6 M , 1.74' 4.014! =V III III K -3 K -2 K -1 C -1 C- 2'HCR' Mud Cross Riser above drill deck This number will vary from well Sow w ell 1.00'103.00' Drill Deck 13 6/8 6M Riser 86001bs 13 5/8 5M X 15.00' 3 1/8 5M EFO III 111 • • Ill III Spacer Spool 135/86MX136/86M 1.85' l 1800Ibs III III • ►il II I Crossover Spool 136/8 SM X11 6M 1800Iba 2 83' III III Top of Wellhead ell Work Prognosis • • II: G - 03RD2 Hikeralaska,c( Applicati Date: 10/29/2012 Hiker!' .0 Diagram A -2: Grayling BOP stack and Riser Arrangement — Typical for Dual Completion Williams Workover Rig Grayling Platform BOP 2012 13 5/8 5M " " " - - - "— - -i 144' i ®! III III III III 2.00' I I I III III III III Ills III 111 III in Iii Width 4.16' .:.. ....... .... 3 74 ItI III Iii III iii Shaffer L t 13 6/8 6M LWS 1,1 13 5/e 6M dimensions ® ' Length 7.73' — � � _ r y a==\/ m 3.00' Width across body 2.72' Q� - Width across flanged — outlets 4.00' ®' 1 �1 {�, ,� '�j�����?�'' ''t,�7�om I >E 1 s 1 0 q C � �/ � !'�` 74' I II - i tI III l K -3 K -2 K -1 C -1 C- 2'HCR' Mud Cross Riser above drill deck This number will vary from well to well 1.00' to 3.00' Drill Deck 13 6/8 5M Riser 86001bs 13 5/8 5M X 1500' 3 1/8 5M EFO II I II III III Spacer Spool 135/85M X 135/85M 1.95' 1800lbs 1 1I ill • Ill Crossover Spool 13 6/8 5M X 11 5M 1800lbs 2.83' Top of Wellhead H ell Work Prognosis .. . H • Well: G -03RD2 Hileorp Alaak:y LLC Application Date: 10/29/2012 Diagram B: Grayling Choke Manifold To Gas Buster All National type To Panic line 2 1/16 5M 1502 Union ball valves ® I IIllfi 4 _ ®: mom ii.3..,. Chokes are 90 degrees off in drawing in order to show I detail li,: Arimp I : I I I iii ' ' a 1111" . 1 ' ( 1 r 7 1 . 1 , ,I. 6,116 lop odi ac .14 = ______p. _ 1 , 1 _ - 7. . i ‘. in 4A0 . „ ,. _ " .„ _ Swaco 1 la III r, _. • 11 04f I 11 , li I II In v n in lif in I ll ' From Bop Choke Line 2 1/16 5M Unibolt Flange Valve Type #1 National Ball Valve B3260, 3'/4" Ball port, 6000psi working pressure #2 National Ball Valve B3260, 3 '/4" Ball port, 6000psi working pressure #3 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #4 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #5 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #6 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #7 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #8 National Ball Valve B2650, 2 9/16" Ball port, 5000psi working pressure #9 National Ball Valve B3260, 3 ' /4 " Ball port, 6000psi working pressure #10 National Ball Valve B1560, 1 ' /2" Ball port, 6000psi working pressure a Z1 WILLIAMS RIG #404 '/ a FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DOWN CASING, UP TUBING "REVERSE CIRCULATING" _. s TANDPIPE P PNIC LINE ❑ • c I *r I I '. 5TRIPPER a R MEAD / f V. 41 rt• x .5: BOP 0. 1101 E AUTO MATC C. �a GMD kE CHO1E 'STACK ••••- 111. 0 G C 0 1 =_I 1 =1 h4UD T 1=1 i � 1 rt PUMP 1 .� ,. PUMP A C \ A MANIFOLD L M'-R 1 +.6 l +AL`uE LP OAS SUi_TI _N II U5TER LINE `/"'* O n C FLUID TANK/PIT 0 O O - O w x v o N 0M fD 3 O I N o y NJ L.0 N O N NJ e. 1 0 , WILL IAMS RIG #104 l FLUID FLOW DIAGRAM NORMAL OPERATIONS h CIRCULATING DOWN TUBING, UP CASING ANNULAS 'THE LONG WAY" STANDPIPE PPNIC LINE El r 1 4 ,-- I /r -3TR ERO ERPER :. MI H BOP RAN URIJ ; . AUIOUATC O C CHORE CHO kE ST.Ac k ■ aC C 0 0 j i? ill MUD purip 4 40 rlo PUMP k __ C MANIFOLD I HC.R ' •••d VAL'dE LP ORs 'SUCTION EUSTER� LINE f1 f > . a f f C , - FLUID T= NKiPIT 0 p 0 ' C" O W 0 o r N 0'Q • 3 O o y N tD NJ 0 N NJ 3 I al WILLIAMS RIG #404 I F r FLUID FLOW DIAGRAM WELL CONTROL OPERATIONS KILLING WELL — DOWN TUBING, UP CASING ANNULAS STANDPIPE I PANIC LINE ❑ • I C _ - / I _ - - l 0 ST RIP PER 7-2: C ._ so BOP n4D `\ IIAN UAI� C `AUTO URIC ' 0 : C STACK cnoKE cnor� 1 0 0 lel'��I °I muD I _I _. �I_I P Utvl P FLI t:dP C ' � A MAtfFC LLD MCR VALVE I. LP CAS SUCTION IUSTER\ LINE I'M - -it > ilk 0 cu Q FLUID T'NK.PIT E W —, 0 7J - 0 C) 0 o (D N 3 0 I—' vf O LA N lD N 0 I' NJ • • M cArthur River Field, TBU SCHEMATIC Well: G -03RD2 Hilcorp Alaska, LLC Completed: 4/23/91 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' 26" Surf. 343' z6 Ili' 1 L 13 -3/8" 61 1-55 Butt 12.515 Surf. 2209' 47 P -110 8.681 Surf. 78' 13 -3/8" 9 -5/8" 40 N -80 Butt 8.835 78' 4,614' 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' ' ' Dv @ P -110 7,295' 11,045' 3,421' TUBING DETAIL I • 3 -1/2" I 9.2 I L -80 TDS SC. I 2.992 Surf. 10,284' I 2 DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth OD ID Item 40.9' CIW Tbg Hngr (4 -1/2" BTC Top x 4 -1/2" 8rd btm) c/w 40.9' 4.25" 2.992" 4 -1/2" 8rd Pin X 3 -1/2" TDS Pin pup 1 303' 3.875" 2.750" 3 -1/2" SSSV Nipple w/ BXE Ball Valve 2,291' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 3,954' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 5,299' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 6,394' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 7,273' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 2 8,009' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 8,485' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 8,930' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 9,405' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 9,848' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 10,135' 5.25" 2.992" 3 -1/2" PTA "DSO" Gas -Lift Mandrels 3 10,174' 4.50" 2.750" Otis XA Sleeve 4 10,209' 4.44" 2.992" Otis Straight Slot Locator 5 10,250' 7" Otis BWH Perma Drill Packer w/ SBE (DIL) 9-5 , 6 10,210' 4.00" 2.992" Otis 10' x 4" Seal assembly 7 10,251' 2.750" 3 -1/2" Otis "X" Nipple 8 10,284' 3.875" 2.992" 3 -1/2" WLRG 9 10,627' N/A N/A Junk Packer 10 10,870' N/A N/A Cement Retainer 0 XA 3 4 PERFORATION DETAIL 5 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition 6 a 0 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Squeezed x 7 5/11/1983 Squeezed 8 = HB t 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Open HB -1 m HB_2 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 DST- Squeezed 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Open 9 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Open 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Squeezed -- 10 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Open HB-2 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Squeezed 10,392' 10,422' 9,220' _ 9,246' 30' 12/21/1989 Squeezed TD = 11,045' ETD = 10,130' HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Squeezed Max Angle= 34.8 @ 7,600MD/ 6,828TVD Revised by TDF 10/3/2012 • McArthur River Field, TBU PROPOSED Well: G -03RD2 Hilcorp Alaska, LLC Completed: 4/23/91 CASING DETAIL RKB to MSL ELEV = 103.0' SIZE WT GRADE CONN ID TOP BTM. RKB to TBG Hngr = 40.90' 26" Surf. 343' 1 2 13-3/8" J -55 Butt 12.515 Surf. 2209' 26, 47 61 P -110 8.681 Surf. 78' 9 -5/8" 40 N -80 Butt 8.835 78' 4,614' 13 - 3/8" 43.5 P -110 8.755 4,614' 7,670' 7" 29 N -80 Butt 6.184 Surf. 7,295' P -110 7,295' 11,045' I IDV@ 3,421' TUBING DETAIL I 3 -1/2" 9.2 L -80 TDS SC. 2.992 Surf. ±9,720' DV Collar @ 3,421' to 3,423' JEWELRY DETAIL No Depth Item 1 40.9' 3 -1/2" Hanger Assy. 2 ±300' Nipple for WR SSSV 3 +9,396' Head Bolt On Discharge 4 +9,398' Pump SLB D3500N - 5 sections 5 +9,514 Pump Intake 6 ±9,517 Protectors - Maximus LSBPB -UT (2) Top of Motor SLB 456, 18, 4183 7 ±9,533' Maximus - 2 motors 8 +9,600' Bottom of ESP 9 - 5/8" 9 +10,240' CIBP on top of old packer 10 10,627' Junk Packer 3 Cement Retainer 4 11 10,870' 5 6 PERFORATION DETAIL � 1 7 Zone Top(MD) Btm(MD) Top(TVD Btm(TVD) Amt Date Present Condition ' G -1 ±9,776' ±9,794' ±8,688' ±8,705' ±18' Future Open 8 G -2 ±9,824' ±9,842' ±8,731' ±8,747' ±18' Future Open G -3 ±9,899' ±9,935' ±8,797' ±8,829' ±36' Future G -1 Open - G -2 G -4 ±9,960' ±10,005' ±8,850' ±8,890' ±45' Future Open = G-3 -G -4 ±10,088' ±10,102' ±8,961' ±8,973' ±14' Future Open 9 G - G -5 ±10,120' ±10,138' ±8,989' ±9,004' ±18' Future Open - _= HB -1 10,294' 10,296' 9,137' 9,139' 2' 5/5/1983 Isolated 5/11/1983 Isolated HB -2 10,307' 10,337' 9,148' 9,173' 30' 4/20/1991 Isolated HB-1 10,310' 10,311' 9,150' 9,151' 1' 5/9/1983 Isolated 1110M4 10 10,317' 10,344' 9,156' 9,179' 27' 12/22/1989 Isolated E HB -4 10,332' 10,337' 9,169' 9,173' 5' 3/11/1984 Isolated 11 10,365' 10,388' 9,197' 9,217' 23' 5/10/1983 Isolated 10,365' 10,422' 9,197' 9,246' 57' 12/21/1989 Isolated HB-2 TD = 11,050' 10,368' 10,373' 9,200' 9,204' 5' 3/10/1984 Isolated Max Angle =34.8° @ 7,600MD/ 6,828TVD 10,392' 10,422' 9,220' 9,246' 30' 12/21/1989 Isolated HB -4 10,652' 10,654' 9,443' 9,445' 2' 5/4/1983 Isolated Revised by JLL 10/23/2012 • Ferguson, Victoria L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Tuesday, November 27, 2012 10:33 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy 1- (DOA); Juanita Lovett Subject: RE: TBU G -03RD2 (PTD 183 -010, Sundry 312 -421) Victoria, We plan to perform the workover, place the well on production until the well stabilizes, and then schedule and perform the no flow test. My understanding of the rule is that the no flow test needs to be performed within 14 days after the Y g p well stabilizes. This is consistent with how we have performed no flow tests in the past. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985- 867 -0665 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferquson ©alaska.govl Sent: Tuesday, November 27, 2012 8:51 AM To: Ted Kramer Cc: Schwartz, Guy L (DOA); Juanita Lovett Subject: TBU G -03RD2 (PTD 183 -010, Sundry 312 -421) Ted, What are your plans for a no flow test? Thanx, 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 victoria.ferquson a(�alaska.gov 1 • • • , Davies, Stephen F (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Friday, November 02, 2012 12:16 PM To: Davies, Stephen F (DOA) Cc: Larry Greenstein; Juanita Lovett Subject: RE: Sundry Approval Applications Steve, The pool is the Middle Kenai G pool and the governing rule is 20 ACC 25.055. That is what should have gone in Box 7. I hope this clarifies this for the State. If not, please let me know. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 From: Davies, Stephen F (DOA) [mailto:steve.davies@ alaska.gov] Sent: Thursday, November 01, 2012 11:19 AM To: Ted Kramer Subject: RE: Sundry Approval Applications No, an email would be fine stating which pool the proposed TBU G -03RD2 G -zone perforations will lie in and which order /regulation governs those perforations. Thanks, Steve Davies AOGCC From: Ted Kramer jmailto:tkramer@ hilcorp.coml Sent: Thursday, November 01, 2012 11:14 AM To: Davies, Stephen F (DOA) Cc: Juanita Lovett; Larry Greenstein Subject: RE: Sundry Approval Applications Thanks Steve, I will do that. Do I need to make a correction for this well? G- 03 Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 1 • • From: Davies, Stephen F (DOA) [ mailto :steve.daviesalaska.gov] Sent: Thursday, November 01, 2012 11:10 AM To: Ted Kramer Subject: FW: Sundry Approval Applications Ted, I'm reviewing Hilcorp's Application for Sundry Approvals for TBU G- 03RD2, and I noticed that you didn't fill in box 7 completely. AOGCC's Form 10 -403 has been recently been updated, and a question was added to box 7 : "What Regulation or Conservation Order governs well spacing in this pool ?" The purpose behind asking this question is to ensure that every engineer is aware that there are spacing rules that govern every pool (statewide regulation 20 AAC 25.055 unless an over - riding conservation order is in place). AOGCC also wants to ensure that everyone is familiar with those spacing rules so that perforating operations 1) do not inadvertently result in a spacing violation, and 2) do not cause unplanned delays while the 6- to 8 -week spacing exception process runs its course (public notice, 30 -day public comment period, hearing (if requested), and order writing /approval). So, in the future please review the spacing rules for each of the pools that you are responsible for, and be sure to fill out box 7 in its entirety. Please pass these thoughts along to other engineers who also submit sundry applications to AOGCC. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907- 793 -1224 Fax: 907 - 276 -7542 2 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMII~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubins0 Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^~ Re-enter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q ~ Exploratory^ 183-010 3. Address: P.O. Box 196247, Anchorage, AK 99519 Stratigraphic^ Service^ 6. API Number: 50-733-20049-01 ` 7. KB Elevation (ft): 9. Well Name and Number: 103' MSL Trading Bay Unit G-03RD2 8. Property Designation: 10. Field/Pool(s): ADL0018730 [Grayling Platform] McArthur River Field /Hemlock Oil ' 11. Present Well Condition Summary: Total Depth measured 11,050' feet Plugs (measured) 10,870' (cement retainer) true vertical 9,786' feet Junk (measured) 10,627' (Packer) Effective Depth measured 10,870' feet true vertical 9,630' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 332' 26" 373' 372' Surface .2,168' 13-3/8" 2,209' 2,181' 3,090 psi 1,540 psi Intermediate 7,629' 9-5/8" 7,670' 6,885' 5,750 psi 3,090 psi Production 11,009' 7" 11,045' 9,782' 8,160 psi 7,020 psi Liner Perforation depth: Measured depth: See Attached Schematic ~y ~°~ 4 r`~` ~` c; ~~~~ True Vertical depth: See Attached Schematic ~ y Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 10,285' .~' ~ ~ ~ / ' Packers and SSSV (type and measured depth) Otis BWH Perm Drill Packer @ 10,250 / N/A ' ~ ~ ~ ~ . ~i~ ~`~g - 12. Stimulation or cement squeeze summary: N/A ~7S ~~/t:> ~0~ ' ~~ /~Sl Intervals treated (measured): ~ st1t~~/~,/ , a ~~~, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation; 0 0 0 150 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development^ Service ^ Daily Report of Well Operations X 16. Well Status after work: OiIO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 305-292 Contact Steve Tyler 263-7649 Printed Nam imothy C. Brandenburg Title Drilling Manager Signature / "' ° Phone 263-7600 Date 10/15/2008 .~- /dam 2o.~a$ Form 10-404 Revi ~ ~ ~~~. ~` [ '"'" ~ ~~ ~ ~~ ~ Submit Original Only ~C~~i',` ~: 2Q08 .. ~.. ~~ ~HO~`® . • Trading Bay Unit Well # G-3RD2 RKB to TBG Hngr = 40.90' Junk I ~ 108 Ceme ~ 708 SI7,F. WT CASING AND TUBING DF,TAIL GRADE CONN ID MD TOP MD BTM. TVD BTM 26" Drive 1" wt Welded 41' 373' 13-3/8" 61 J-55 Butt 41' 2209' 9-5/8" 47 N-80 Butt 41' 78' 9-5/8" 40 N-80 Butt 78' 3421' DV ('ullar -------------------------------------------------- --------------------------------- 3x21' 3423' 9-5/8" 40 N-80 Butt 3423' 4614' 9-6/8" 43.5 N-80 Butt 4614' 7670' 7" 29 P-110/N-80 Butt & Srd 36' 11045' 3-l/2" 9.2 L-80 TDS 36' 10285' Sp. CL Cpl. 40.9' 1 303' 2 3-U2" PTA "Dti0" Gas-Lift >landrels #1 2291' #2 3954' #3 5299' #4 6394' #5 7273' #6 8009' #7 8485' #8 8930' #9 9405' #10 9848' #11 10135' 3 10174' 4 10209' 5 10250'(DIL) 6 10210' 7 10251' 8 10284' 9 JEWELRY DETAIL Item CIW Tbg Hngr (4-1/2" BTC Top x4-1/2" Srd btm) c/w 4-1/2" Srd Pin X 3-1/2" TDS Pin pup 3-1/2" SSSV Nipple w/ BXE Ball Valve 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" CLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM 3-1/2" GLM Otis XA Sleeve Otis Straight Slot Locator Otis BWH Perma Drill Packer w/ SBE Otis 10' x 4" Seal assembly 3-l/2" Otis "X" Nipple 3-1/2" WLRG PERFORATION f)A"1'A Zone Top Btm Arrt SPF Da6e Present Candfion HB-1 10294 10296 Squersd HB-1 10307 10344 Open HB-2 10366 10422 Open HBd 10662 10664 Squersd G-3RD2 Schematic 7 18 OS.doc REVISED: 7/18/05 DRAWN BY: LWB TD = 11,050' ETD =10,130' Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G-03RD2 TRADING BAY UNIT G-03RD2 ADL0018730 5073320049 AR4251 100.00 Jobs - --_ __ Primary Job Type Job Category Objective Actual Start Date Actual End Date Completion -Reconfigure Major Rig Authority is requested to pull the existing tubing, mill and recover the 12/3/2005 Work Over packer, run a new packer and tubing in preparation to perforate the (MRWO) G-Zone and to continue producing from the Hemlock Fm. In Well G-3RD2 Grayling Platform, Trading Bay Unit, McArthur River Field, Cook Inlet, Alaska. Primary WellboreAffected Wellbore UWI Well Permit Number G-03RD2 5073320049-01 1830100 Dai O erattons 1 213/2005 00:00 - 12!412005 00:00 - _ --- --- -- -- Operations Summary Prep for workover operations. RU for wireline operations. Ran 2.80"gauge ring (GR) to 41', no go. POOH. 12/412005 00:00 -12/5/2005 00:00 -_ _ ~ _ . Operations Summary Ran 2.60" impression block to 61'. Shows wire/fish. Ran several fishing attempts to pull junk out of hole. No success. 12/5/2005 00:04 -:1216/2005 00:00 _ _ _ _ - --- Operations Summary Ran 2.73" GR to 41', ran 2.55" GR and set down on SSSV at 303' POOH. Ran 2.70" broach from 42' and beat down to 303' .POOH and found ice & scale. Flowing well to clear scale. 22.37' (~8' wire 8r tool string) fish left in hole. .12/6/2005 00:00 -.12/712005 00:00 - - - _ - Operations Summary Continued fishing operations. Recovered fish. RIH w/ 2.75" GR & 2.79" boach, unable to work past 94', POOH with scale on tools. ___ _ _ _ 12/7/2005 00:00 - 12/8/2005 00:00 _ _- Operations Summary Water flood tubing and pressured up on 7"x 3-1/2" annulus to 500 psi. Ran 1.75" bailer to top of SSSV (303' SLM). Ran multiple GR 8r brush runs., unable to get past SSSV. Flowed well. Latched onto SSSV at 307', unable to pull SSSV. 12/8/2005 00:00 -12/9/2005 00:00 _ _ _ -- --- - __ - Operations Summary Continued attempts to pull SSSV. Latched & beat up at 6,000Ibs, came free and recovered fish neck off of SSSV. Ran impression block and found packing mandrel still fishable. Rig down to wait on slickline tools. - - - - .. - -- - 12/9/2005 00:00 - 12/10/2005 _00:00 _ _ _ Operations Summary Continue to wait on slickline tools. ---- - - __ 12/10/2005 00:00 - 12/11/2005 00:00 __ __ _ _ Operations Summary Continue to wait on slickline tools. 12/11/2005 00:00 - 12/12/2005 00:00 -- _ _ __ Operations Summary Continue to wait on slickline tools. _ ---- - --- 12/12/2005 00:00 -_ 12/13/2005 00:00 Operations Summary Continue to wait on slickline tools. __ 12/13/2005 00:00 - 12/14/2005 00:00 _ _ _ - - - ----- ' Operations Summary Continued fishing operations. Speared into fish, pulled out of fish several times, unable to recover. ---_ 12!1412005 00:00 - 12/1512005 00:00 _ _ _ _ _ _ -- . _. _ _ _ ___ Operations Summary Continued fishing attempts, no joy, rig down braided line. - -- 12/15/2005 00:00 - 12/16/2005 00:00 Operations Summary Wait on materials, rig cleanup. _ _ _ _ 1 211 612005 00:00 - 12/17/2005:00:00. _ ___ _ _ Operations Summary Rig up wireline. RIH w/ 2-1/2" beat down tool, sheared off same on top of SSSV. RIH w/dump bailer to 303' and drop 19 gal 30% hydachloric acid solution. Soak acid, beat down, latch and recover SSSV after multiple attempts. Ran 2.63" GR to top of gas lift mandrel (GLM)#3 at 5,300', unable to pass this past identified problem area. 1 211 712005 00:00 -12/1$/2005'00:00 Operations Summary Made wireline run w/ 2.26" impression block. Set down at 5,318'. No impression. Rig down wireline. - - - - ---- 12/18/2005 00:00 - 1211 9/2Q05 00:00 _ _ _ _ _ _ __ ___ ___ _ _ __ Operations Summary Rid down/cleanup. 12/20/2005 00:00 - 12/21/2005 00:00 _ _ __ __ _ _ _ Operations Summary Wait on equipment to run back pressure valve (BPV). Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) G-03RD2 TRADING BAY UNIT G-03RD2 ADL0018730 5073320049 AR4251 100.00 Daily Operations _-~ - - - - - - - - ___ 12/30/2005 00:00 -12/31I2005A0:00 __ _ ___. __ - --.. uperations Summary lCleaned out scale & prep to run BPV. - - - 12I31Y200$ OOc00 -.1/1/200600:00 _ _ _ _ _ Operations Summary Cleaned out scale & prep to run BPV. Set two-way chech valve, tested to 1220 psi, held, pulled same. Demob and shut down operations. WO discontinued at this time due to economical infeasibility, because of present well conditions and expense of currently planned WO. Will evaluate for future well-work oppurtunities. ) \ , ;r;::.' rJ :~, ,'''',,~¡\.::;;, -.;:TI.M'i 1.1 r':l. :,1<:<: i: ¡ /b\¡ ! i !Il~ : 1\ '¡ I i ,I' \ f! i! i@U!¡Ub.J:~b I-:::;J ! ¡I I '1 ¡ ;=:A IJ: [" ' (n) II. ., " ",,- cQ) FRANK H. MURKOWSKI, GOVERNOR AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 \1b?AÙ\D Re: Trading Bay Unit G-03RD2 Sundry Number: 305-292 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~NNEU NO\f Ð ~3 200~ ---- Encl. ...'('. Ct?;}- /o~t-a( k-\O I 015 /()/9/.> ~ ) STATE OF ALASKA) ALA;:>t<Ä OIL AND GAS CONSERVATION COMMI~~ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Other U Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PerforateL::J Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to ~umber: Exploratory 0 183-010 o 6. API Number: / 50-733-20049-01 .../ 1. Type of Request: Suspend U Repair well 0 Pull Tubing [] Development Stratigraphic o o Service PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to tbg hanger 40.90' 8. Property Designation: Grayling Platform, Cook Inlet 11. Total Depth MD (ft): 11,050' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10,294 to 10,654' Packers and SSSV Type: Total Depth TVD (ft): 9,786' Length 9. Well Name and Number: Trading Bay Unit G-03RD2 /' 10. Field/Pools(s): McArthur River Field/Hemlock Oil PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10,130' 8,997' Plugs (measured): 10,870' Burst Size MD TVD 26" 373' 372' 13-3/8" 2,209' 2,181' 9-5/8" 7,670' 6,885' 7" 11,045' 9,782' 332' 2,168' 7,629' 11,009' 3,090 psi 5,750 psi 11 ,220 psi Perforation Depth TVD (ft): 9,136 to 9,444' Tubing Grade: Tubing Size: 3-1/2" L-80 Otis BWH perma drill packer with SBE; 3-1/2" Packers and SSSV MD (ft): Nipple w/ BXE ball valve 10,250' 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: 12/1/2005 Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Larry Buster 263-7853 Printed Name . Timothy C. Branden~rg .-----; Title Drilling Manager Signature ~ 4 cþ ~. o~e. 907-276-7600 Date r ~ .....-7 . COMMISSION USE ONLY c..-- Junk (measured): 10,627' (packer) Collapse 1,540 psi 3,090 psi 8,510 psi Tubing MD (ft): 10,285' Service 0 Abandoned D D WDSPL 10/3/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,J.{J t::J ", ~q ::¿, Plug Integrity 0 Other: BOP Test .~ Mechanical Integrity Test D Location Clearance 0 .\? \\::: S\-O-. '> ~ \ G.. t'-..IC\.. Q~ . C\ ~ ,~S\- <è"t- \-<t ~ c:.,. \ 0" f"Û+ ù.\,\,~ UQ-èJ . ~_ RBDMS BFL ocr {} ~ 700J COMMISSIONER APPROVED BY THE COMMISSION Date: Form 10-403 Revised 07/2005 >' \, AFE 164548 OR\G\NAL t(l/~ Submit in Duplicate RECEIVED SEP 2 9 2005 ') STATE OF ALASKA ) ALA.....'\Ä OIL AND GAS CONSERVATION COMMI__"ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Alaska Oil & Gas Cons. Operational shutdown U Perforate ~ WaAndMr e Plug Perforations 0 Stimulate 0 Perforate New Pool D Re.,.enter Suspended ell 0 4. Current Well Class: 5. Per . to Drill Number: Suspend U Repair well 0 Pull Tubing 0 Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): RKB to tbg hanger 40.90' 8. Property Designation: Grayling Platform, Cook Inlet 11. Total Depth TVD (ft): Effective Depth MD (ft): Effective Dep TVD (ft): length9,786' Size 10,130' ð\ -'l/7L ~'J TVD 332' 26" "3~3\(:) . \372' 2,168' 13-3/8" 9 2,:;/ \I ì). ( ~,181' 7,629' 9-5/8" ~- 7/370' 6,885' 11,009' 7" ~ /11 ,045' 9,782' Perforation Depth TVD (ft): T~' Size: Tubing Grade: 9,136 to 9,444' (;:'l ~ ~ Otis BWH perma drill packer Nipple w/ BXE ball valve :> C/J 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch 0 Commission Representative: 17.1 hereby certify that the foregoin9 is true and'. d orrect to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg/ Title Drilling Manager Signature ? _ ~~ C¡:J ß~~ne 907-276-7600 Date L) ~ COMMISSION USE ONLY 1. Type of Request: Total Depth MD (ft): 11,050' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10,294 to 10,654' Packers and SSSV Type: 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Development 0 Stratigraphic D Exploratory Service D D . API Number: / 50-733-20049-01 9. Well Name and Number: Trading Bay Unit G-03RD 10. Field/Pools(s): Plugs (measured): Junk (measured): 10,627' (packer) Collapse 10,870' Burst 3,090 psi 5,750 psi 11 ,220 psi 1,540 psi 3,090 psi 8,510 psi L-80 Tubing MD (ft): 10,285' Packers and SSSV MD (ft): 10,250' 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: 12/1/2005 Oil 0 . Gas D WAG D GINJ 0 0 Service 0 D Abandoned D 0 WDSPL D Plugged WINJ Larry Buster 263-7853 9- '2-<¡-0S"" Conditions of approval: Notify Commi ion so that a representative may witness Sundry Number: :3 (.? S- - ~.;) Ý ::L- Plug Integrity 0 Other: Mechanical Integrity Test D Location Clearance D ,.."', r"¡ \ (., , Í' t r\ \ ¡ \ \." I \ -1 \ t \ \, I-~ \,' t\l 'v':, (I, <.1- COMMISSIONER APPROVED BY THE COMMISSION Date: Approved by: Form 10-403 evised 11 /2~~~' ."7 ----- AFE 164548 Submit in Duplicate : UNOCAL RKB to TBG Hngr == 4().9()' ~TM 26" Drive l"wt Welded 41' 373' 13·318" 61 J-55 Butt 41' 2209' 9·518" 47 N-80 Butt 41' 78' 9-518" 40 N-80 Butt 78' 3421' 9-518" 40 N-80 Butt 3423' 4614' 9-518" 43.5 N-80 Butt 4614' 7670' 7" 29 P-110IN-80 Butt & 8rd 36' 11045' DV@ 3-112" 9.2 L-80 TDS 36' 10285' 3421' S1'. CI. Cpt Cement Rei. @10870' Junk Packer @ 10627' G-3RD2 Schematic 7 18 05 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 3954' 5299' 6394' 7273' 8009' 8485' 8930' 9405' 9848' 10135' 10174' 10209' 10250' (DlL) 10210' 10251' 10284' 3 4 5 6 7 8 9 x 4-112" TDS Pin pup 3-112" SSSV Nipple wi BXE Ball Valve 303' 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3·112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM Otis XA Sleeve Otis Straigbt Slot Locator Otis BWH Perma Drill Packer wi SBE Otis 10' x 4" Seal assembly 3-112" Otis "X" Nipple 3-112" WLRG ZorIe Top Btm Date Present Condition HB-1 10294 10296 Squeezed HB-1 10307 10344 Open HB-2 16365 10422 Open HB4 10652 10654 Squeezed REVISED: 7/18/05 DRAWN BY: L WB UNOCALti> RKB to TBG Hngr == 40,90' 26" Drive l"wt Welded 41' 373' 13-3IS" 61 J-55 Butt 41' 22119' 9-5IS" 47 N-80 Butt 41' 7S' 9-5IS" 40 N-80 Butt 78' 3421' 9-518" 40 N-811 Butt 3423' 4614' 9-5IS" 43.5 N-811 Butt 4614' 76711' 7" 29 P-11I1IN-80 Butt & Srd 36' 111145' 3-1/2" 9,2 L-811 BTC Mod 36' 10285' Junk Packer ,@ 10627' Cement Rat. @ 10870' RKB to MSL ELEV == 103,0' TD == 11,050' ErD == 10,130' G-3RD2 Proposed WO Schematic 7_18_05 3113' #2 #3 #4 #5 #6 #7 #8 #9 #1\1 #11 3 4 5 6 7 8 9 4·112" TDS Pin pup 3-112" SSSV Nipple wi Ball Valve 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-112" GLM 3-1/2" GLM 3-112" G LM 3-1/2" GLM Otis XA Sleeve Otis Straight Slot Locator Otis BWH Perma Drill Packer wi SBE Otis 1\1' x 4" Seal assemhly 3-112" Otis "X" Nipple 3-112" WLRG last~. Present Condition ~~ ~~ ~~ ~~ Open SqueelEd REVISED: 7/18/05 DRAWN BY: LWB ~ Upper well aay Floor G-03RD2 II ~ , . ') ') Grayling Platform Well G-3RD2 Workover& New Perforations . UNOCALe OBJECTIVE: Pull the existing tubing. Run a single production packer to above the G-Zone. Run a 3-1/2" gas lift mandrel completion. Perforate the G-3, 4 and 5 sands. PROCEDURE SUMMARY: 1. Rig up on Well G-3RD2. 2. Fill tubing and casing with Filtered Inlet Water (3% KCL). 3. Set BPV and N/D tree on Well G-3RD2. NIU and test 13-5/8" BOPE (see attached diagram) to .~50/3,OOO psi. ~ ___ , ~ ~) Note: We would like to request a waver in our BOPE test. Specifically, we would like a seven ~ day extension on the normal seven day period for a total of 14 days between tests. The well is ) sub-no~ally pressured and ~n extended fishing job could easily take us over the no~l ,se~n / daypenod between tests. E>"'f~"~\o~~ \0. ~ ¿;~'( ~c)"\-C<>\-~ o..~cc~~\ð"-~·cl o"~ . "- ............ ~c."*- ~...... <:"'0.. '"-:.<è. D~~ "\ ~ CJ.. S C ~t"ù...~ ~ o...~" Ù ~tJq:t'~ 4. Venfywelldead. ~¿,~,,~<t. <t~\'-~'C~'~ ~ \" \>Cs<>'"\ <t, 5. Rill with tubing cutter and cut tubing above the existing production packer. ~::!1, L.( Note: This tubing string is corroded with holes in it. We don't want to part the tubing when trying to pull it, so we may have to fish it out in several runs. 6. Work tubing and attempt to pull. If unable to pull the tubing. RIB and make an intermediate cut on the tubing. 7. Pull tubing and engage tubing stub with overshot. Attempt to pull tubing. If unable, RIH and a .;;~~~~~.i..ªte-GUt and repeat llæ fishiugiQb. ______ ~~ (" // Note: It is possible that the corroded tubing will prove to not be fishable within the economic \ limits of the existing reserves. Should that determination be made during the workover \ operations, the decision may be made to suspend the operations. Should that point be reached, \ we will notify the AOGCC with an update of the situation and a proposed plan forward. 8. R/U and run 7" pro~-: +/-9,80~·---·~- Note: a bit and scrapper clean-out run may be made prior to running the packer. 9. Run a 3-1/2" tubing gas lift mandrel completion. Space out and land the hanger. AOGCC G-3RD2 Workover Summary 10f2 September 27,2005 ... . , ') ) Grayling Platform Well G-3RD2 Workover& New Perforations . UNOCALe 10. Install BPV. N/D BOPE. NIU and test tree. 11. RIU E-Line and perforate the G-Zone as follows: G-3 9888' to 9936', G-4 9945' to 10003' G-5 10080' to 10100' G-5 10112' to 10140' AOGCC G-3RD2 Workover Summary 20f2 September 27, 2005 ~lI~lIŒ (DJ~ ~~~~æ~ , ¡ l I ! I / AI1ASIiA OIL AND GAS í CONSERVATION COMMISSION / May 4, 2004 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verifications Well G-03RD2, PTD 183-010 Well G-04RD, PTD 181-183 Well G-13, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-13. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results of these no-flow tests, the subsurface safety valves may be removed from service in Wells G-03RD2, G-04RD, and G-13. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, J~ ~~ \ a1!~D~~&9 James B. Regg 7 ( Petroleum Inspection Supervisor cc: Bob Fleckenstein ~lI~lIŒ (ill~ / AI1A.SIiA ORAND GAS I CONSERVATION COMMISSION / April 26, 2004 l~\ ~ I~\ C§. ítZ !~ LFU lb u u Q¿J U~ LrU ¡ ¡ / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson Field Superintendent Unocal 260 Caviar Street Kenai, Alaska 99611 RE: No-Flow Verifications Well G-03RD2, PTD 183-010 Well G-04RD, PTD 181-183 Well G-13, PTD 168-057 Dear Mr. Johnson: On April 23, 2004, AOGCC Petroleum Inspector Chuck Scheve witnessed 3 "no flow tests" on Unocal's McArthur River Field, Trading Bay Unit, Grayling Platform: Well G- 03RD2, Well G-04RD, and Well G-13. Each well was opened to atmosphere through flow measurement equipment with suitable range and accuracy after being shut in and monitored for several hours. There was no flow of gas or liquid to surface during the tests. Based on the results ofthese no-flow tests, the subsurface safety valves may be removed ffom service in Wells G-03RD2, G-04RD, and G-13. Fail-safe automatic surface safety valve systems capable of preventing uncontrolled flow must be maintained in proper working condition in each of the wells as required in 20 AAC 25.265. The subsurface safety valve must be returned to service in any well that demonstrates an ability to flow unassisted to surface. Please retain a copy of this letter on the Grayling platform. Sincerely, ~..-;7~ ~'b Cl- Jame~. R~gg 7 Petroleum Inspection Supervisor cc: Bob Fleckenstein MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~eqq tt/ã:>/CIr P. I. Supervisor ( DATE: April23,2004 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: No Flow Trading Bay Unit G-03 RD2 183-01 0 G-04RD 181-183 G-13 168-057 Friday. April 23. 2004: I traveled to Unocal's Grayling Platform and witnessed no-flow tests on wells G-O3 RD2, G-O4RD and G-13. I arrived on location and found all three wells bled off and opened to atmosphere with no flow of gas or fluid evident. All three wells were shut in and observed for several hours with no pressure build up observed. I recommend Wells G-03 RD2, G-04RD and G-13 on the Grayling Platform be approved no flow status for the purpose of removing the Sub Surface Safety Valve. SUMMARY: Wells G-O3 RD2, G-04RD and G-13 meet the AOGCC requirements for no flow status. Attachments: Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNO .AL February 29, 1996 Alaska Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Re: Grayling Platform Well, G-3RD2 APl Number 50-733-20049-01 On July 5, 1993 a coiled tubing unit cleaned out scale, performed a scale inhibiting squeeze, and acidized well G-3RD2. After cleaning the tubulars, a packer on coil tubing was set between HB-1 and HB-2. The scale inhibitor package was pumped into HB-2; a ball was dropped isolating HB-1 from HB-2 and acid was pumped down to stimulate HB-1. Very truly yours, ,,~ G. Russell Schmidt Drilling Manager --' STATE OF ALASKA ' ALASKA O~L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulat.__e _X Plugging Perforate Pull tubing After casing Repair well Pull tubing Coil tbg cleanout Other X 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519- 6247 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface Leg 4, Cond. 18 1833' N, 1480' W F/S.E. cor. of Sec. 29, T9N, R13W, S.M. At top of productive interval 2012' S, 273' E of NW corn., Sec. 33, T9N, R13W, S.M. At effective depth At total depth 2271' S, 550' E of NW comer, Sec. 33, T9N, R13W, S.M. 6. Datum elevation (DF or KB) RT 103' MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number G-3RD2 9. Permit number 83-10/93-155 10. APl number 50-733-20049-01 11. Field/Pool McArthur River/Hemlock 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,050 feet Plugs (measured) 9,768 feet 10,870 feet Junk (measured) 9,609 feet Casing Length Size Cemented Measured depth True vertical depth Structural 373' 26" Driven 373' 373 Conductor 2209' 13-3/8" 2500 sx 2209' 2179' Surface 7670' 9-5/8" 2725 sx 7670' 6802' Intermediate Production Liner Perforation depth: 11,045' 7" 975 sx 11,045' 9765' measured true ve~cal Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 10307'-10344' DIL; 10365'-10388' DIL; 10392'-10422' DIL 9139'-9172' DIL; 9190'-9209' DIL; 9213'-9238' DIL 3-1/2", 9.2# N-80 Otis Ball valve ~ 322', Baker "F-l" pkr ~ 10237', Baker "F-I" pkr ~ 10344' 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation ._Subsequent to operation 273 248 1748 1200(gas lift) 207 ~ 533 2123 1230(gas lift) , J15. I16. Status of well classification as: Oil X Gas Suspended 120 110 Attachments Copies of Logs and Surveys run Daily Report of Well Operations Service J17. I hereby certify that the forf,~g is tru~ {lni?0'~ best of my knowledge. Signed G. Russell Schmidt ~~.//~Y.~Title Drilling Manager Form 10-404 Rev 06/15/88 Date '~/~/C~ 6 SUBMIT IN DUPLICATE Alaska Unocal Corporatio, , Oil & Gas Operations 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOFJtL February 29, 1996 C0MM ~ COM~ .-- RES Er',!G J Mr. Dave Johnston, Commissioner Alaska Oil & Gas Conservation Corem: 3001 Porcupine Drive ~-'" .... Anchorage, Ak. 99501-3192 I--- Re: Grayling Platform, Well G-3RD2 APl Number 50-733-20049-01 Status Report This is to inform you that the coil tubing cleanout/perforating Sundry Request, Approval No. 95-002 was abandoned on 1/6/95 after coil tubing cleanout tagged an obstruction at 10,460' and could not clean past it. The operation is no longer considered practical, please cancel this Sundry Request. Very truly yours, -. / / Candace Williams .~.. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI~. .)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing __ Alter casing__ __ Plugging __ Perforate __ Repair well __ Pull tubing __ OtherX 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of Well: Development Exploratory Strafigraphic 4. Location of well at surface Leg #4, Conductor #19, Grayling 1833' FSI_ & 1480' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 10,307' MD 1986' FNL & 334' FWL, Sec. 33, T9N, R13W, SM At effective depth 10,870' MD 2182' FNL & 544' FWL, Sec. 33, T9N, R13W At total depth 11,050' MD 2244' FNL & 606' FWL, Sec. 33, TgN, R13W, SM 6. Datum elevation (DF or KB) RT 103' MSL 7. Unit or Property name TRADING BAY UNIT 8. Well number G-3RD2 feet 9. P-er. mit.aum~/approval number 95-002_ 10. APl number 50-733-20049-01 11. Field/Pool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 11050' feet Plugs (measured) 10957' 9780' feet Effective depth: measured true vertical Casing Length Structural 373 Conductor 2209' Surface 7670' Intermediate Production Liner Perforation depth: measured 10870' 9624' feet Junk (measured) 10463' feet Size Cemented Measured depth 26" Driven 373' 13-3/8" 2500 sx 2209' 9-5/8" 2725 sx 7670' 11045' 7" 975 sx 10307'- 10344' DIL: 10365'- 10422' D Il_ 11045' True vertical depth 313' 2179' 6877' 9780' true vertical 9139'-9172' DIL; 9190'-9238' DIL Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 TDS 10,284' Packers and SSSV (type and measured depth) Otis Ball Valve @ 322', Otis BWH Perm Pkr @ 10,210' DIL 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A RECEIVED FEB - 6 1995 Atas[~ Oil & Gas Cnn~ n~,,~,~... 14. Prior to well operation N/A Subsequent to operation N/A _R..epresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Anch0r~., Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas __ Suspended __ Service 17. I here~e~ th~ fo~ue and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE AB150-755-20049-02 Grayling PeEform Leg 4, Conductor i9 G-,3RD2 Trading _Bay Uni[ M~hur River Reid .~KB £1ev. 105.0 Ft. 'l'bcl He,,,., ,'lg Depth 40.9 FL Mid-Perf Deviofion 52 Deg. ~,~j~,~ - 10141.6' ¢.¢~tJFT VAL~ t11, PTA DSO Gl~ 10210.7 - 10220,1' PACER Otis ~ Pkr 10294.0 - 10296.0' ,SQUFF7E PERFS 10501,0 - I0870.0' Fill ~/6/9~, f~]ggecl Bottom 10627.0 - 10627,0' FISH Packer A~d ~unk 10652.0- 10654.0' SQU~[ PERFS ':':':":':':': 'i'i'i'i'i'i'i 'i'!'i'i'i'!'i '!'i'i'!'!'i'! ":':':":":':': ':':':":':':': ;:::::;:]:::;: ~ ELEV: 103' PB~: 10870' B: 11~' l'""/J- fi _ ,ui,-,,,, lO178.1':~VE Otis i~09,0 - 10220.I' ~ALS S 1/2" threads, box up, pin dow, 1~.09,0 - 10210.7' L~TOR d01~ Otis Straight 1~1.0 - 10252.4' LANDINQ NIPPLE Oh's "X" 10284..0 - 10284.6' R~Y JOINf Wireline re-entry guide !E87.0- 10557.0' PERFS HB1, 4HPF, 50', 111/16" PDt Gun ReperPd 5/11/95 !~7.0 - 10~44.0' PBFS HB1 ~i HPF, I®t reperf 7/22/91 1~5.0 - 10422.01 PERFS HB2 24 HPF, last reperf 4/2¥91 RECEIVED FEB --6 !995 Aiaska Oil & Gas Cons. Commission Anchor: . Oil ~11 Redri~ No. 2 Completed 5/11/85 DAY 1 (01105195) 9-5/8" @ 10,090' 7" @ 9962'- 10,754' G-3 RD #2 MOVE C.T.U. FROM EAST TO WEST PIPERACK. MAKE UP TBG CONNECTOR & PULL 20K UP. TEST OK. MAKE UP BIT & BHA. HELD SAFETY MTG W/ALL PLATFORM PERSONNEL. PRESS TEST BOPE TO 3000 PSI. RIH W/2.70" BIT & 2-118" MOTOR ON 1.5" COIL TBG. ClRC PRESS WAS 3000 PSI @ .7 BMP (FIW). UNUSALLY HIGH. POOH CHECK PRESS IN COIL. CHANGE OUT MOTOR & TEST. DAY 2 (01/06/95) 9-5/8" @ 10,090' 7" @ 9962'- 10,754' RIH W/2.7" BIT 2-1/8" MOTOR ON 1-1/2" COIL TBG. PUMPING FIW @ .9 BPM. STOP @ 10,460' ATTEMPTED TO CLEAN OUT PAST 10,460' W/NEG RESULTS. BIT STALLING ON BTM. BIT SHOWS EVEN WEAR ON OUTSIDE EDGES. RIG DOWN C.T.U. RIG UP MYERS W.L. RIH WI2.25" lB. SET DWN @ 10,463' WLM. NO MARKS ON lB. RECEIVED FEB -.6 1995 Ai~s!~a 0il & Gas Cons. Commissio[~ Anchor; - ,~---, STATE OF ALASKA AL KA OIL AND GAS CONSERVATION CON, ,~SION APPLICATION FOR SUNDRY APPROVALS 1, Type of request: Abandon __ Suspend __ Operations shutdown __ Re-enter suspended well Alter casing__ Repair well __ Plugging __ 'nme extension __ Stimulate Change approved program Pull tubing _ _ Variance m Perforate X OtherX 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 5. Type of Well: Development X Expk)mtory __ Strafigraphic __ Location of well at surface Leg #4, Conductor #19, Grayling 1833' FSL & 1480' FEL, Sec. 29, R9N, R13W, SM At top of productive interval 10,307' MD 1986' FNL & 334' FWL, SEC. 33, T9N, R13W, SM At effective depth 10,870' MD 2182' FNL & 544' FWL, SEC. 33, T9N, R13W, SM At total depth 11,050' MD 2244' FNL & 606' FWL, Sec. 33, T9N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 1105_0~. feet Plugs (measured) 11430' 9780' feet Effective depth: Casing Structural Conductor Surface measured 10870' true vertical 9624'i~ Length ::-~ 373' ' 2209' - 7670' Intermediate Production Liner 11045' Perforation depth: measured true vertical- feet Junk (measured) 11376' feet 6. Datum elevation (DF or KB) RT 103' MSL feet 7. Unit or Property name TRADING BAY UNIT 8. Well number G-3RD2 9. Permit number 10. APl number 50-733-20049 -01 11. Field/Pool MCARTHUR RIVER/HEMLOCK ORI61NAL S~e Cemented Measured depth True verticaldepth 26' DRIVEN 373' 313' 13-3~" 2500 sx 2209' 2179' 9-5/8" 2725sx 7670' 6877' ._ ' 7" 975 sx 10307'-10344' DIL; 10365'-10422' DIL . · 91'39'-9172' DIL; 9190'-9238' DIL Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 TDS 10,284' Packers and SSSV (type and measured'depth) RECEIVEJ ,,o, JAN - 4 1995 Naska Oil & Gas Cons. Commission Anchorage 13. Attachments Otis Ball Valve @ 322', Otis BWH Perm Pkr @ 10,210' DIL Description summ~ of proposal _ _ Detailed operations programX BOP sketch X_ 14. Estimated date for commencing operation: 115. January 2, 1995 , !" 16. If proposal was verbally approved Oil X_ Gas Name of approver BI'~- L~J~,,~,~/',~.lJ Date approvea Service 17. I hereby certEy that the foregoing.is true andr~orrect tQ the best of my knowledge. Signed G. Russell Schmidt~~_~~~V~{"~l'~Je Drilling Manager FOR COMMISSION USE ONLY Status of well classification as: Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug Integrity __ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approved by the order of the Commission Original Signed By David W. Johnston Approval No. Approved Copy Returned Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE McArthur River Field Grayling G-3RD2 Short String Coiled Tubing Clean -Out Procedure Page: 1 Note: 2) 3) 4) 5) 6) 7) 8) Note: 9) lOa) 10b) 11) BOP Shear Test was completed (witnessed by Mitchell Damm) on 12/07/94 Verify tree/CT BOP connections before moving CTU to the Grayling Platform. (Thread: 4-1/2" 8rd; Flange: 4-1/16 RX-39 5M psi) Hold safety meeting and discuss procedure w/coiled tubing personnel and production personnel before starting job. Fill out CT pre-job checklist. Review CT's working history before using coil. RU Dowell CTU, Nitrogen Unit, pump skid, choke line, double choke manifold, kill line, flow tank, and return tank. The Production Foreman and Engineer have allowed taking returns to the separator. Mix-up _-- 70 BBLS of 3% KCI water using FIW. NU BOP on G-3RD Short String (located in Leg 4). Flanged connections will be used. Pressure test BOP, 1-1/2" CT, and all surface lines to 3~000 psi for 10 minutes. Use Nitrogen - for pressure test. Complete BOP Inspection CT BHA #1 as follows: 1) 1-1/2" wash nozzle 2) 1-1/2" tandem check valve RIH 1.5" CT w/BHA #1--do not exceed 100 FPM. Maintain gas injection while RIH. Begin pumping KC1 water as soon as CT enters the well. Take returns to the separator. While cleaning-out, keep well slightly underbalanced to aid clean-out. Monitor weight indicator and pump pressures while RIH. Scale obstructions might be encountered throughout tubing. Wash scale from 0'-10~284'. Use gas lift to assist solids removal. Discuss alternative plans w/office if wash nozzle is ineffective removing scale, fluid Make several passes to ensure scale has been removed. R~C~I~D If wash nozzle is ineffective, RIH w/BHA #2: 1) 1-5/8" mill 2) 1-11/16" motor 3) 1-11/16" tandem check valve aaa cons. c0mmi 0n Mill scale 0'-10~284'; pump 3% KC1 water for fluid Make several passes to ensure scale has been removed. After tubing is thoroughly clean, wash fill from 10~425'-10~627'. Use Nitrogen and gas lift to assist solids removal. Pump water pills periodically to aid in the cleanout. Discuss alternative plans w/office if Nitrogen clean-out is ineffective. MWD G3RD2PRO.DOC 12/27/94 12a) 12b) 13) 14) 15) McArthur River Field Grayling G-3RD2 Short String Coiled Tubing Clean -Out Procedure Page: 2 If there are no fill returns, attempt to clean-out using foam. (Surfactants F52.1 & F75N will be available.) Use suffactant F75N first. If F75N is not working, dicuss w/office about using the F52.1 surfactant. If foam does not lift solids effectively, POOH w/1-1/2" wash nozzle and RIH w/motor and 2-5/8" mill. Pure Nitrogen can be used w/the motor; however periodically pump water pills. POOH w/BHA and 1-1/2" CT. RD CTU. ND BOP. Move CTU to G-15 Before slickline work, keep well shut-in. After Coiled Tubing Operations: Slickline: 1) 2) RU slickline unit. Test lubricator to 3,000 psi for 10 minutes. Lubricator shall have a pump-in sub. RIH w/2.75" tubing scratcher.. Run entire assembly outside of tubing (TBG Tail ~ 10284') plus another 5'. Verify tubing is clear for GR run. POOH. 3) RIH w/2.70" GR--dummy gun needs to be _= 30' in length. Minimum restriction is 2.75". 4) Run GR assembly outside of tubing plus another 5'. If GR does not pass or hangs ups, discuss w~ office. 5) POOH w/dummy. RD slickline. 6) Before producing the well, discuss producing the well with the office. Wireline Perforating: Hold wireline pre-job safety meeting. l) 2) ~) 4) 5) RU Schlumberger wireline unit. Test lubricator to 3,000 psi for 10 minutes. Lubricator shall have a pump-in sub. RIH w/Schlumberger 2-1/8" strip guns ( 45° - 6 SPF) and make tie-in pass w/CCL. Reperforate Hemlock Bench 4: 10~535'-10~587' EL. Well will be shut-in during perforating operations. POOH w/Wireline. RD wireline unit. Turn well over to production. Gas Cons. Commission gnchora~e MWD G3RD2PRO. DOC 12/27/94 RKB '- 0.00' 'rBG HGR O 40.90' 7 x 8 9 / 10 : : : : Fill 61# J-55 @ 2209' Z ; 9-5/8" 47, 43. :, & 47#, P- 110 N-80, WlNDO' @ 7670'- 7725' PKR JUNK @ 10627' RET @ 10870' 7" 29#, P' 110 & N-80 @ 11045' 11 HB- 1 HB-2 TUBING DETAIL' 3-1/2", 9.2#, L-80 TDS TUBING WITH SPECIAL CLEARANCE CPLGS 1) 4-1/2 EU 8RD PIN x 3-t/2 TDS PIN X-OVER 2) OTIS SSSV NIPPLE W/ BXE BALL VALVE · 303.29' 3) PTA "DSO" GASLF'I' MANDRELS AS FOLLOWS: GLU #1 Q 2291.64' MD GLM #2 t~ 3954.43' MD GLM #3 ~ 5299.05' MD {2_M #4 ~ 6394.22' bID GLM ~5 ~ 7273.43' MD GLM #6 ~ 8009.48' MD Q..M ~!7 I~ 8484.66' kid (2.M #8 ~ 8930.35' MD GLU ~19 ~ 9404.99' MD # 10 e 9848.27' UD CLU # 1 ~ e ~0135.70' UD 4) OTIS "XA" SLIDING SLEEVE ~ 10174.19' 5) ONE (1) dOl~ 3--1/2" mS ~BING 6) 4" ~ S~ A~ W/ ~ ~OT LO~T~ ~ 10209.0~~ (~-1/2 ~S BOX-UP x PIN-D~) ~ ON[ (0 ao~m =-¥2- ~s ~ 8) ~S ~ ~DINO N~E O 10251.07 9) ONE (~) ~0~ 3-¥2' mS ~N~ 10) ~~E RE-E~ ~=E O 10284.6¢ (a~)~ 11) ~s ~- P~M P~ AT 10,210' DL HEk~OCK PERFORATIONS: 10294'- 10296' 10307'- 10344' 10365'- 10422' 10652'- 10654' TOP HB-1 SQZ PROD - OPEN PROD - OPEN BASE HB-4 SQZ RECEIVED JAN - 4 1995 Alaska Oil & {~as Cons. Commission ~choraje UNION WELL TBUS G-3RD2 COMPLETION SCHEMATIC OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN" DAC SCALE: NONE DATE: 4-25-91 iSectton 310.1, I ~age 2 of 38 ,. · Rev/~ March 1992 The BOP commonly found on Doweii Schlur~ berger (Ob") cotlea tubing un~ (CTU$) is manuf~a ~/Texu Oil Tools (TOT). This is available in a range of :fize~ (bom), pressure ~ and,=ervk;es (e.g., H.~, ~ or Standa~ service). The model most commonly usea is me 3-in., 10,000-1:~ Worldng PreaaJre, H~$ aervtce Quail BOP. It is this model on whtch the cllagrams and text in thts section are based. Stud-Up Flat,ge Top Conneclion~ Ski. Port (Kill Port) COILED TUBIIK~ OPERATORS MANUAL [ The following componem are identlfiad in F'~jum 1 anO 2. · BOP · Blind Rams · Sllp Ran~ · Pipe Rams Pressure Port Blind-Ram Equa~Jng Valve Manual Lock Handle Blind Rams (RamNo.~) (Ram No. 2) · .~------- S~ Ram~ (R.m No. 3) (n~mgo.4) wtlh~ Podiion Imlioa~ Bottom Pln ami Collar Conne~on JAN -4. 1995 Dii & Gas Cons. Commission Anch0ra:je .,..' .... STATE OF ALASKA -'-'-- ALAL , OIL AND GAS CONSERVATION COMM. .ON APPLICATION FOR SUNDRY APPROVALS Operations shutdown Re-enter suspended well__ Plugging __ Time extension __ Stimulate __ Pulltubing __ Variance __ Perforate __ OtherX_ 5. Type of Well: 6. Datum elevation [ Development X_ I Exploratory __ RT 103' MSL I Stratigraphic __ 7. Unit or Property name I Service __ TRADING BAY UNIT 1. Type of request: Abandon __ Suspend ~ Alter casing Repair well Change approved program __ 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99,519 4. Location of well at surface Leg #4 Conductor #19, Grayling Platform 1833' FSL & 1480' FEL, Sec. 29, R9N, R13W, SM At top of productive interval 1986' FNL & 334' FWL, Sec. 33, T9N, R13W, SM At effective depth 2182' FNL & 544' FWL, Sec. 33, T9N, R13W, SM At total depth 2244' FNL & 606' FWL, Sec. 33, T9N, R13W, SM 8. Well number G-3 9. Permit number ~"~,-/~, 10. APl number 50 -733 -20049 - 1 11. Field/Pool MCARTHUR RIVER/HEMLOCK 12. Present well condition summary Total depth: measured true vertical 11,050' feet Plugs (measured) 9,780' feet Effective depth: measured 10,870' feet Junk (measured) true vertical 9,624' feet Casing Length Size Cemented Structural 373' 26" D rive n Conductor 2209' 13-3/8" 2500 sx Surface 7670' 9-5/8" 2725 sx Intermediate Production Liner 11045' 7" 975 sx Perforation depth: measured 10,307'- 10,344', 10,365'-10,422' true vertical 9,139'-9172', 9190'-9238' Tubing (size, grade, and measured depth) 3-1/2" 9.2, L-80 TDS Packers and SSSV (type and measured depth) Otis "BXE" Ball type 303.29' Measured depth 373' 2209' 7670' 11045' True vertical depth 373' 2179' 6877' 9780' RECEIVED JUN 1 4199 Alas[~ 0il .& 6as Cons. ~ctl0rage 13. Attachments Description summary of proposal X Detailed operations programX BOP sketch X 14. Estimated date for commencing operation 115. 16. If proposal was verbally approved I Oil X_ Gas Name of approver Date approved Service 17. I herel~er~and correct to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Status of well classification as: Suspended Date June2, 1993 Conditions oi: approval: Notify Commission so representative may witness Plug Integrity BOP Test Location clearance -- __ Mechanical Integrity Test__ Subsequent form required 10- Original Sig~ed Approved by the order of the Commission David IApproval No. Approved ~opy ~ ~R',../,,~',~'-'-- Returned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 61# J-55 @ 2209' t 9-5/8" 47, 4-5.5 47#, P-!10 &: N-80, WINDOW 7670'- 7725' RKB = 0.00' T'B6 HGR O 40.90' TUBING DETAIL' 5-t/2", 9.2#, L-80 IDS TUBING WITH SPECIAL CLEARANCE CPLGS ~,..uI / 10 i PKR JUNK @ 10627' RET @ 10870' I~1 7,, P-t &: N-80 1 045' 11 10) WIRE:LINE RE-ENTRY GUIDE O 10284.60' (BOTTOM) 11) OTIS "BIIt/H# PERM PKR AT 10,210' OIL HB- 1 HB-2 HEMLOCK PERFORATIONS: 10294'- 10296' TOP HB-1 SQZ 10.307'- 10.344' PROD - OPEN 10.365'- 10422' PROD - OPEN 10652'- 10654' BASE HB-4 SQZ RE£E]VED d UN 1 4 ~99~ Alaska Oil & Gas Cons. Corn~$¢°~ WELL TBUS G-3RD2 DRAWN: DAC COMPLETION SCHEMATIC SCALE: NONE UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DATE' 4-25-91 GLM #2 O 5954.45' kid GLM #3 O 5299.05' MD GLM #4 ~ 6394.22" kiD (;Lid #5 · 727:3.43' kid (A_Id #6 ~ 8009.48' kid CLid ~17 ~ 8484.66' kid (;Lid #8 O 8950.35' kid GLM #9 ~ 9404.99' kid GLM # 10 ~ 9848.27' kid ~LU # 11 e lO 1~5.70' UD 4) OTIS '"XA" SLIDING SLEEVE e 10174.19' S) ONE (1) JOINT `3--1/2' TDS TUBING 6) 4" OD SEAL ASSY W/ STR SLOT LOCATOR O 10209.0~3' (.3--1/2 TDS BOX-UP x PIN-DOWN) 7) ON£ (1) JOINT 2-1/2" TDS TUBING 8) OTIS "X" LANDING NIPPLE · 10251.07' 9) ONE (1) JOINT .3-1/2" TD$ TUBING k {~ &RD PiN x 5-1/2 TD9 PiN X-OVER 1) ~,- 1/2 EU 2) OTIS SSSV NIPPLE W/ BXE BALL VALVE · 503.29' I GASLIFT MANDRELS AS FOLLOWS: 3) PTA I GLU #1 O 2291.64' MD General Work Procedure Coil Tubing Cleanout & Acid Stimulation. G-3RD2 1. RU & test 1-1/2" coil tubing unit (maximum depth 10,475'). . RIH w/jet nozzle & wash tubing to 3-1/2" tubing tail at 10,285'. Heavy scale deposits in recent slickline operations may require milling. . Trip out & pick up Baker packer for 7" 29# liner (Drift = 6.059"). Run packer & set at 10,355' for isolation during stimulation treatment. Mix and pump acid treatment for upper perforations from 10,307' - 10,344' (HB1). 4. Release packer & POOH. RD & move to next well. RE( EiVED J U N 1 4199~ Alaska 0il & Gas Cons. Commission Anchorage .,3' U N ~ 8--93 TUE ARCTIC PIPE INSP -~ECOIL Arctic Recoil, inc. (907) 283-1980 P.O. Box 2595 Kenai, Alaska 99611 RE([EIV£D JUN 1 4.199;~ Alaska Oil & Gas Cons. Comm~Ss~or~ ;Anchorage STATE OF ALASKA ALASKF~--"L AND GAS CONSERVATION COI~-~41SSION REPORT JF SUNDRY WELL OP._ 'rATIONS '-'/"F'/' 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X - 6 / -- .u,, -- O, o. 2. Name of Operator -- -- 5. Type of W-~: -- 6. Datum el-;-vation (DF' or KB) Union Oil Company of Califomia (Unocal) Oeve~oprnent X_ KB: 103' fee/~/r 3. Address P.O. Box 196247, Anchorage, Alaska 99519-6247 Stratig raphic ~ 4. Location of well at stxface Grayling Platform, Leg #4, Condu.~tor #19 1833' FSL and 1480' FEL, Sec. 29, T9N, R13W, SM At top of productive interval 1986' FNL and 334' FWL, Sec. 33, T9N, R13W,! SM At effective depth 2182' FNL and 544' FWL, Sec, 33, T9N, R13W, SM At total depth 2244' FNL and 606' FWL, Sec. 33, T9N, R13W, SM Explorat(xy __ 7. Unit or Property name Trading Bay Unit 8. Well number G-3RD2 9. Permit number/approval number 83-10 / 10. APl nur~ber 50-733 -20049-0~ 11. Field/Pool o - · McArthur River/Hemlock 12. Present well condition summary Total depth: measu'ed 11,050 feet true vertical 9780 feet Effective depth: = Casing Structural Conductor Surface Intermediate Production Liner measured 10,870 true vertical - 9624 Length Size 373' 26" 2209' 13 3/8" 7670' 9 5/8" 11,045' Perforation depth: measured Plugs (measured) feet feet Junk (measured) Cemented Measured depth True vertical depth Driven 373' 373' 2500 sx 2209' 2179' 2725 sx 7670' 6877' 7' 975 sx 11,045' 10,307'-10,344'; 10,365'-10,388'; 10,392'-10,422' 9780' true vertical 9139'-9172', 9190'-9209', 9213'-9238' Tubing (size, grade, and measured depth) 1/2', 9.2#, N-80 Buttress Packers and SSSV (type and measured depth) Otis BV@ 322', Baker F-1 packer @ 10,237', Baker F-1 packer @ 10,344' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Representative Daily Average .Production or Ir~ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure RECEIVED MAR 0 199 A!a~E~ !Oil & Gas Cons. C;omrn~ssio~ Anchorage Tubing Pressure 299 3~ 1~9 1~0 110 Subsequent to operation 261 5O5 1917 1245 120 15. Attachments Copies of Logs and Surveys run__ Daily Report ct Well Operations __ 16. Status of well classification as: Oil X Gas Suspended Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~ STATE OF ALASKA · . ALASKA" . AND GAS CONSERVATION COI',~-'":SSION -. ' APPLICA I ION FOR SUNDRY APl-¢iOVALS./,, Operations shutdown __ Re-enter suspended well__ Plugging __ Time extension Stimulate Pull tubing __ Variance__ Pe-~orate X__ Ot-~'e r __ f~"~ ~. 5. Type of Well: . 6. Datum elevation (~). Development /~ RT 103' MSL Exploratory __ t Type of request: Abandon__ Suspend__ Alter casing ~ Repair well Change approved prog ram __ L- 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247, Anchorage, Alaska 99519-6247 4. Location ofwell at sudace Leg #4, Conductor #19, Grayling Platform 1833' FSL & 1480' FEL, SEC. 29, T9N, R13W, SM At top of productive interval 1986' FNL & 334' FWL, SEC. 33, T9N, R13W, SM At effective depth 2182' FNL & 544' FWL, SEC. 33, T9N, R13W, SM At to~al depth 2244' FNL & 606' FWL, SEC. 33, T9N, R13W, SM Stratigraphic __ 7. Unit or Property name Service Trading Bay Unit 8. Well number G-3RD2 9. Permit number 83-10 10. APl number 50-733-20049-~, ~ ~, 11. Field/Pool McArthu' River/Hemlock 12. Present well condition summary Total depth: measured 11050 feet true vertical 9780 feet Plugs (measured) Effective depth: measured 10870 'feet true vertical 9624 feet Junk (measured) Casing Length Size Cemented Structural 373' 26" Driven Conductor 2209' 13 3/8" 2500 sx Surface 7670' 9 5/8" 2725 sx Intermediate Production Liner 11045' 7" 975 sx Measured depth True vertical depth 373' 373' 2209' 2179' 7670' 6877' Perforation depth: measured 10307'- 10344', 10365'- 10388', 10392'- 10422' MAR 0 3 1993 true vertical 9139'-9172', 9190'-9209', 9213'-9238' Alaska 0ii & Gas Cons. 0ommission Tubing (size, grade, and measured depth) 3 1/2", 9.2#, N-80 Buttress Anchorage Packers and SSSV (type and measured depth) Otis ball valve @ 322', Baker F-1 packer @ 10237', Baker F-1 packer @ 10344 13. Attachments Description summary of proposal__ Detailed operations prograrnX__ BOP sketch _ 14. Estimated date for commencing operation ]15. 3/93 16. If proposal was verbally approved Oil X_ Gas __ Name of approver Date approved Service 7. I herel~ ~ce, Ft~fy t/t~a~s true and correct to the best of my knowledge. .SignedV//~P ~/~,/.~./m~-.,w.~ Title '~ ~LCU[~ k~'~/4CkC--~(~--, Status of well classification as: Suspended Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug Integrity ~ BOP Test Location clearance Mechanical Integrity Test_ Subsequent form required !0- Approved by the order of the Commission Original $~9ned By David W. johnston JApproval No.~ , ' -:'0 y Commissioner Date~,~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE February 25, 1993 G.rayling, Well G-3RD2 perforating procedure 1. Hold safety meeting. 2. RU electric line unit. 3. Pressure test lubricator to 2500 psi for five minutes. 4. Shut down all welding and radio transmissions. 5. RIH and perforate intervals as instructed by Unocal (When gun is 200' below surface, welding and radio transmissions may resume.) 6. POOH. (When gun is 200' below surface, shut down all welding and radio transmissions.) 7. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH MEASURED TRUE VERTICAL TOTAL FEET HB1 10,307'-10,337' 9129'-9158' 30' TOTAL: 30' /~laska Oil & G~s Oozes. ALASK~.~..QIL AND GAS CONSERVATION COM~MISSlO!~ R ~ G i ~ ,'~ L - · , ' APPLIC. .'ION FOR SUNDRY A[ _'ROVALS . .. 1. Ty~3e of request: Abandon Suspend __ Operations shutdown Re-enter suspended well Alter casing__ Repair well Change approved program .. 2, Name of Operator Union Oil Company of California (Unocal) 5. 3. Address P.O. Box 196247, Anchorage, Alaska 99619-6247 Plugging ~ Time extension __ Stimulate __ Pull tubing __ Variance ~ Perforate X_ Other__ Type of Well: 6. Datum elevation (DF or KB) Devek)pme~ X RT 103' MSL ~tory 4. Location of well at surface Leg #4, Conductor #19, Grayling Platform 1833' FSL & 1480' FEL, SEC. 29, T9N, R13W, SM At top of produclive interval 1986' FNL & 334' FWL, SEC. 33, T9N, R13W, SM At effective depth 2182' FNL & 544' FWL, SEC. 33, TgN, R13W, SM At total depth 2244' FNL & 606' FWL, SEC. 33, T9N, R13W, SM 12. Present well condition summa'y Total depth: 7. Unit or Property name Trading Bay Unit 8. Well number G-3RD2 9. Permit number 83-10 10. APl number 50-733-20049-/~ I r'~' "~'~' 11. Field/Pool McArthur River/Hemlock feet measured 11050 feet Plugs (measured) true vertical 9780 feet Effective depth: measured 10870 feet Junk (measured) true vertical 9624 feet Casing Length Size Cemented Structural 373' 26' Driven Conductor 2299' 13 3/8' 2500 sx Surface 7670' 9 5/8' 2725 sx Intermediate Measured depth 373' 2209' 7670' True vertical depth 373' 2179' 6877' Production Liner Perforation depth: Tubing (size, grade, and measured depth) 11045' 7" 975 sx 11045' measured 10307'- 10344', 10365'- 10388', 10392'- 10422' true vertical 9139'-9172', 9190'-9209', 9213'-9238' 31/~", 9.2#, N-80 Buttress RECEiV I NOV 2 0 1992 ol o_[aga -' Packers and $$SV (type and measured depth) Otis ball valve @ 322', Baker F - 1 packer @ 10237', Baka' F- 1 packer @ 10344 13. Attachments Description summary of proposal __ Detailed operations prograrnX__ BOP sketcfl __ 14. Estimated date for commencing operation November 17, 1992 16. If proposal was verbally approved Name of approver I 5. Status of well classif'cation as: Oi~ x__ Gas __ Date approved Service Suspended__ 17. I hereby ce/~y that the foregoing is true and correct to the best of my knowledge. ~'~ ~ FOR COMMISSION USE ONLY Conditions of apl~r~va'k-l~oUfy Commission so representative may witness Plug Integrity m BOP Test_ Location clearance m Mechanical Integrity Test Subsequent form required 10- Approved by the order of the Commission Form 10-403 Rev 06/15/88 Date IApproval No. Returned . Commissioner Date SUBMIT November 11, 1992 · 1. Hold Safety meeting. 2. RU electric line unit. 3. PreSsure test lubricator 4. Shut down all Welding a to 2500 Psi for five minutes. transm{o_~ zs 200, ~, ~-Vals ac -. ns. -~ons m=.. ~=~ow sur~_~ lnStru~__ 6. POOH. (~en un ~elding an~ g .~ ~esume.) ~ce, . .~n~3 is 200, below su~fa~,' ShUt ~°w~ all ~ "~"ceevals: to ~eefo~ate the HB1 10,305,_10,335 , 9128 ''9154 , TOTI~L 30' RECEIVED NOV 'Z 0 1992 Alaska Oil & Gas Cons. Comm'tsslot't '._Anchorage. 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 ODera~o-[¢t'~ ~'~''z~; 5. Type of Well: 6~D..atu~m. elevation (DF or KB) Jnlon Oll Company of California Development.M_ t('l' ±03 MSL feet Exploratory __ . Stratigraphic __ 7~;~ert~a,~n eUNI T P~ddr~x 190247, Anch., AK, 99519 Service__ 4. Location of well at sudace Leg #4, Conductor #19, Grayling Platfc)~%mwellnumber ~833' FNL & 1480' FEL, Sec 29, T9N, R13W, SM G-$~RD#2 At top of productive interval 10,307' MD (9139' TVD) HB-1 9. Permit number ~986' FNL & 534' FWL, Sec 33, T9N, R13W, SM 83-10 At effective depth 10,870' MD (9624· TVD) 10. APInumber 2.182' FNL & 544' FWL, Sec 33, T9N, R13W, SM 50-- 733-20049-02 At total depth 11,050' TMD (9780' 'ZSID) 11. Field/Pool 2244' FNL & 606' FWL, Sec 33, T9N, R13W, SM MCARTHUR RIVER/HEMLOI 12. Present well condition summaryRECEIVED Total depth: measured 11,050 ' feet Plugs (measured) true vertical 9,780 ' feet J U L 5 t991 Effective depth: measured 10,870 · feet Junk (measured) true vertical 9,624 ' feet Alaska 0il & Gas Cons. C0mmlssiO~ Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural 373 ' 26" DRIVEN 373 ' 373 ' Conductor Sudace 2209' 13-3/8" 2500 SXS 2209' 2179' Intermediate 7670' 9-5/8" 2725 SXS 7670' (WINDOW) 6877' Production 11,045' 7" 975 SXS 11,045' 9780' Liner Perforation depth: measured 10,307·-10,344· DIL; 10,365·-10,422' DIL true vertical 9,139'-9,172' DT'I'.2 9,190'-9,238' DIT."'~'" ---~¢r Tubing (size' grade' and measured depth')3-1/2 " 9.2# '1'.-80, TDS TUBING @ 10,284' Packers and SSSV (type and measured depth) 3-1./'~" OTIS SSSV @ 303'~ OTIS "B~-{" ~E:R_M ~R ~ 10210' D~ 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: July 22, 1991 Oil ~ Gas__ Suspended __ 16. If proposal was verbally approved 7 / 22 / 91 Name of approver 'f,. C · Sm±th Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S. BU~ 5. (~.~.Title Regional Drilling Mater Signe~-,ary ~ FOR COMMISSION USE ONLY I Approval No. Conditions of approval: Notifyk.C~mm~ssion so representative may witness Plug integrity __ BOP Test __ Location clearance __ I Mechanical Integrity Test_ Subsequent.form required 10- Approved uopy Original Sig,ed BY David W. Johnston ~ , , -- e-'] Approved by order of the Commission Commissioner Dat~---~/ I~rm ~ n.,m.q m~ n~/t~/RR SUBMIT' IN TRIP _ICATE July 22, 1991 RE: G-3RD2 Perforating Procedure 1. RU slick line, run gauge and tag bottom. 2. Hold safety meeting. 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 ma 7. POOH. (When gun is 200' below surface, shut down all welding and r 8. Repeat steps 5, 6 and 7 as needed to perforate the following: BENCH MEASURED HB-1 TRUE VERTICAL 10,307 - 10,337 9,129 - 9,158 TOTAL FT. (MD) 30 TOTAL FOOTAGE: 30 L. £ 5 Gas Oons. Anchorage STATE OF ALASKA Al_AL.., OIL AND GAS CONSERVATION COMMIS~. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate _,x_ Pull tubing X Alter casing __ Repair well __ Pull tubing __ Other __ 2. Name of Opera~NOCA,L ) 5. Type of Well: 6. Datum elevation (DF or KB) Development _..5_ RT 10 3 MSL feet [)n~c)n Oki ComDanv of California Exploratory__ 3. Address Stratigraphic __ 7. Unit or Property name P.O. Box 190247, Anch., AK, 99519 Service__ TRADING BAY UNIT 4. Location of well at surface Leg #4, Conductor #19, Grayling Pla'li1'D:~.]rl~Nellnumber i1833' FNL & 1480' FEL, Sec 29, T9N, R13W, SM G-3RD#2 At top of productive interval 10,3 0 7· MD ( 913 9' TVD ) MB- 1 9. Per~:~ nq. rrkb9rj,apprp, v.~l~umber 1986· FNL & 534· FWL, Sec 33, T9N, R13W, SM --.LU/~- u/o- At effective depth 10,870· MD (9624· TVD) 10. APInumb/e~3_20049_01 2182· FNL & 544· FWL, Sec 33, T9N, R13W, SM 50-- Attotal 11,050· TMD (9780· TVD) 2244' (~ & 606· FWL, Sec 33, T9N, R13W, SM 11.~:~'HUR RIVER/HEMLO 12. Present well condition summary 11,0 5 0 ' Totaldepth: measured 9 780 · feet Plugs(measured) true vertical ' feet Effective depth : measured 10,870 · feet Junk(measured) true vertical 9,6 2 4 ' feet Casing Length · Size Cemented Measured depth True vertical depth Structural 3 7 3 · 2 6" DRIVRN 3 7 3 · 3 ? 3 · ConduCtor Surface 2209' 13-3/8" 2500 SZS 2209' 2179' Intermediate 7670· 9-5/8" 2725 SXS 7670' (WINDOW) 6877· Production 11,045· 7" 975 SXS 11,045· 9780· Liner Perforation depth: measured 10,307'-10,344' DIL; 10,365'-10,422' DIL truevertical 9,139'-9,172' DIL; 9,190'-9,238' DIL Tubing (size. grade, and measured depth)3_'l/2 ,, 9.2# L-80, TDS TUBING @ 10,284' TM Packers and SSSV (type and measured depth) 3-1/2" OTIS SSSV @ 303'; OTIS "BWH" PERM PKR ...... ~,iQ~10' D] 13. Stimulation or cement squeeze summary ~¢.~ '{"~ k.~ '~.; '''~' ~ Intervalstreated(measured) See attached history , .... ~; ~, l ~'~ 0"~ Treatment description including volumes used and final pressure · o,~. ~,/..;qS,, On'r:,';" 14. Representative Daily Average Production or InjeCtion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 274 ..BOPD 294 MCF 5'4 B~PD 1200 PSI (GAS LIFT) 110 595/BOPD 325'MCF 1577 BWPD 1200 PSI (GAS LIFT) 110 Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run - Daily Report of Well Operations __ Oil _..K. Gas ~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gary S~~ ~__..D,.~5~v,' Regional Drilling Manager Signed ¢~ ~, Title Date SI 'SI Form 10-404 Rev 06/1~ I SUBMIT IN DUPLICATE UNOCAL SHEET A WELL RECORD PAGE NO. LEASE Trading Bay WELL NO. G-3RD SPUD DATE 04-10-91 COMP DATE 04-25-91 FIELD McArthur River Field CONTRACTOR P.A.A. RIG NO. 55 LOCATION: Leg #4, Conductor #19, TYPE UNIT National ~3~0 UE Grayling Platform 1833'FNL & 1480'FEL DRILL PIPE DESCRIPTION 3-1/2", 15.5#, E&S Section 29, T9N, R13W, SM ELEVATIONS: WATER DEPTH 125' PERMIT NO. 83-10 SERIAL NO.50-733-20049-02 RT TO OCEAN FLOOR 228' TD ll.050'TMD TVD 9780' RT T~-MLW 103' DEVIATION (BHL) 2244FNL & 606'FWL RT TO DRILL DECK 23.3 " SEC. 33, T9N, R13W, SM COMPANY ENGINEER CHUDANOV GRAHAM HARNESS RT TO PRODUCTION DECK 46.6- CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 26" 373' Driven 13-3/8" 61# BUTTRESS J-55 2209' Cmtd w/2500 sxs "G" CMT 9-5/8" 47, 43.5 BUTTRESS P-110, 7670' Top of Window & 40# N-80 7" 29# BUTTRESS P-il0, 11045' CMTD W/925 SXS "G" CMT & 8RD N-80 PERFORATING RECORD DATE INTERVAL E.T.D. REASON 05/04/83 10652'-10654' 10957' SQUEEZE 05/05/83 10294'-10296' 10622' SQUEEZE 05/09/83 10310'-10311' 10957' DST 05/10/83 10365'-10388' 10957' SQUEEZE 05/11/83 10307'-10337' 10957' SOUEEZE 03/10/84 10368'-10373' 10870' PRODUCTION 03/11/84 10332'-10337' 10870' PRODUCTION 12/21/89 10392'-10422' 10870' PRODUCTION 12/22/89 10317'-10344' 10870' PRODUCTION 04/20/91 10307'-10337' 10627' PRODUCTION 04/20/91 10365'-10422' 10627' PRODUCTION PRESENT CONDITION SQZD BASE OF HB-4 W/100 SXS CMT SQZD Top OF HB-1 W/lO0 SXS CMT TEST FORMATION PRESSURE IN HB-1 SQZD HB-2 W/79 SXS CMT SQZD HB-1 W/79 SXS CMT HB-2 FRAC-OPEN HB-1 FRAC-OPEN HB-2 (OPEN) HB-1 (OPEN) HB-1 (OPEN) HB-2 (OPEN) INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS TYPE: CASING HEAD: CASING SPOOL: TUBING HEAD: WELL HEAD ASSEMBLY CAMERON IRON WORKS/SHAFFER SHAFFER MODEL KD 12" SERIES 900 W/2EA 2" LP OUTLETS X 13-3/8" SOW 12" 3M X 12" 3M W/7" HUNG AT 165,000# TENSION (CIW) 12" 3M X 10" 5M DCB (CIW) TUBING HANGER: ~0" NOMINAL SINGLE TBG HANGER 4-1/2" EU 8RD-DOWN 4-1/2" EU 8RD-UP TUBING HEAD TOP: 10" 5M BASE X 4" 5M TOP (4-1/8" BORE) MASTER VALVES: 2 EA CIW 4" 5M VALVES W/BLOCK BETWEEN FOR 4" 5M WING VALVES CHRISTMAS TREE TOP CONN: 4-1/2" EU 8RD DATE., 04/10/91 04/11/91 04/12/91 MW GRAYLING PLATFORM G-3RD#2 WORKOVER WELL HISTORY ETD 10870' PAGE 1 COMMENTS COMMENCE OPERATIONS AT 0000 HOUR_S oN TBUS G-3RD#2 WORKOVER. RIG UP ELECTRIC LINE FOR TUBING PUNCH PERFORATING RUN. RAN IN AND TAGGED THE BALL VALVE. RIGGED UP SLICK LINE AND PULLED BALL VALVE. RAN IN WITH A TUBING PUNCH TO 10220' WLM. SHOT 4 HOLES IN THE MIDDLE OF THE JOINT BELOW THE "XA SLEEVE". RIGGED DOWN WIRELINE. RIGGED UP TO CIRCULATE DOWN THE TUBING TAKING RETURNS FROM THE ANNULUS TO PRODUCTION. MIXED 1000 BBLS OF 3% KCL/FIW BRINE. CIRCULATED BRINE AROUND THE WELLBORE. FLUID RETURNS WERE CLEAN AFTER PUMPING 566 BBLS. SHUTDOWN AND MONITORED WELL- STATIC. PUMPED AN ADDITIONAL 50 BBLS OF BRINE (14 BBLS TO FILL TUBING). SHUTDOWN AND MONITORED WELL-BOTH SIDES ON A SLIGHT VACUUM. INSTALLED BACK PRESSURE VALVE. HELD A SAFETY MEETING. REMOVE TREE. BEGAN NIPPLING UP BOPE. 10870' FINISH NIPPLE UP OF BOPE. TEST BOPE AS FOLLOWS: RAM TYPE PREVENTERS, CHOKE MANIFOLD VALVES, AND SAFETY VALVES TO 300 PSI (LOW) AND 3000 PSI (HIGH); ANNULAR PREVENTER TO 300 PSI (LOW) AND 2500 PSI (HIGH). PULLED BACKPRESSURE VALVE AND INSTALLED LANDING JOINT. .3ACKED OUT THE LOCK DOWN PINS AND RIGGED TO PULL TUBING. TUBING STARTED MOVING WITH 95K ON-THE HOOK. PULLED HANGER TO THE FLOOR'AND REMOVED SAME. MONITOR WELL-TAKING 18 BPH FLUID. PULLED OUT OF HOLE LAYING DOWN SINGLE 3-1/2" GAS LIFT COMPLETION. FLUID LOSS SLOWED DOWN TO 4 Bp.I!. AT 2400 HOURS. 10870' CONTINUED PULLING OUT WITH 3-1/2" GAS LIFT COMPLETION-RECOVERED ENTIRE STRING. RIGGED DOWN TUBING TOOLS AND CLEAN UP RIG FLOOR. SKID RIG #54 OVER TBUS G-6RD FOR SLICKLINE WORK. PRESSURE TESTED CSO RAMS TO 300 PSI (LOW) AND 3000 PSI (HIGH). SET WEAR BUSHING. MADE UP 6" BIT ON 9 EA 4-3/4" DRILL COLLARS AND RAN IN PICKING UP 3-1/2", 15.5#, S- 135 DRILL PIPE. PULLED OUT STANDING BACK SAME (OFFLOAD FROM BOAT HAD "S" PIPE ON TOP). MADE UP 6" OD MILLSHOE ON 9 EA 4-3/4" DRILL COLLARS AND RAN IN HOLE PICKING UP 96 JOINTS "E" AND 87 JOINTS "G" DRILL PIPE.' GRAYLING PLATFORM G-3RD~2 WORKOVER WELL HISTORY ~' ,. PAGE 2 DATE. MW ETD COMMENTS 04/13/91 10870' 04/14/91 10870' 04/15/91 CONTINUED' RUNNING IN HOLE-WITH BURNOVER SHOE PICKING-UP BALANCE OF 3-1/2', 15.5~ DRILLPIPE. TAGC-~D' BAKER'"-- F-l- PROOUC'rlo~. PACKER AT 10237' DPM~ ANI~B~N.. MILLIN~ OVER-SAME.- NOT GL=T't'ING~'MUCH TORQUE? HAVING A PROI~EM WITH MUD PUMP-PRESSURE= DROPPING TO 500 PS! AND COMING BACK TO 1800 PSI. DECIDED TO TRIP TO CHECK SHOE. CIRCULATED BO'I'rOMS UP AND PULLED OUT OF HOLE. MILL SHOWED VERY LrI"rLE WEAR..-MADE- OF SHOE #2 AND RAN IN HOLE. MILLED ON PACKER FOR 3-1/2' HOURS AND ROTARY TABLE HAD A MECHANICAL FAILURE. FLEX COUPLING=- BETWEEN GEAR BOX AND'DRIVE SHAFF WAS WORN OUT. .. PULLED OUT OF HOLE TO WORK ON THE ROTARY TABLE. MILL SHOE HAD QUITE A BIT MORE WEAR- WORN ON FACE WITH SLIGHT OD- WEAR. REPLACED ROTARY TABLE IN RIG #55 WITH TO ONE FROM RIG #54. RAN IN HOLE WITH MILL SHOE #3 AND TAGGED PACKER AT 10239' DPM. MILLED FOR 1-1/2" HOURS AND PACKER CAME FREE. CHASED PACKER TO 10344' DPM (TOP OF ISOLATION PACKER). CIRCULATED WELL CLEAN AND TRIPPED FOR SPEAR ASSEMBLY TO RECOVER PACKER BODY. -~ 10870' MADE UP SPEAR AND RAN IN TO RECOVER PACKER BODY. SPEAR SET DOWN AT 2911' DPM:; TRIPPED TO CHECKTOOI_$ NO' RECOVERY:~': cu'r~ A BETTER BEVEE ON:THE-STOP SUB-AND-RAISIN = HOLE. TAGC~D PACKER BODY AT 10344' DPM, ATTEMPTED TO ENC_~a, GE FISH: TRIPPED :TO CHECK TOOLS-NO RECOVERY: HAD A FEW MARKS. ON THE BULLNOSE. MADE UP AN OVERSHOT AND RAN IN HOLE. TAGGED FISH AT 10348' DPM. WORKED OVERSHOT OVER PACKER BODY; ISOLATION PACKER: BELOW FISH WAS, MOVING:- DOWNHOLE WHEN-' WEIGHT,' WAS STACKED::'Ot~:~ - - ON TOP OF THE FISH:: TRIPPEDTOCHEOK-T~ .... RECOVERED PACKER-BODY;" ~ RAN IN HOLE.-WITIfl MILL SHOE AND TAGGED THE ISOLATION PACKER AT 10348' DPM.~ PUSHED THE'PAC3<ER.TO 10353' DPM AND PACKER HUNG. UP. MILL ON PACKEI~ ~< ~ ,=- '. - :=- ...................... GRAYLING PLATFORM G-3RD~Ii2 WORKOVER WELL HISTORY PAGE 3 04/16/91 04/17/91 04/18/91 04/19/91 04/20/91 10870' CONTINUED MILLING ON PACKER. PACKER. CAME- FREE AND PUSHED SAME TO' 10621, DPM~. CIRCULATED. POH NOTING SOME JUNI~;~ THE MILL SHOE REQUIRING THE FIRSt:'-2 STANi3S' TO BE PUMPED OUT OF THE HOLF_ RIH Wl3~AN OVERSHOT. 5-7/8" DRESSED WITH A-4-7/8' GRAPPLE AND ATTEMPTED WITHOUT SUCCESSTO ENGAGE THE FISH; POH WITH NO RECOVERY. RIH WITH A PACKER MILLING BHA. WORKEI~.OVER TOP OF FISH NOTING SOME JUNK, CIRCULA3~ED HI-VIS SWEEP. MILLED OVER PACKER: FROM 10621'-10627' DPM. POH FOR OVERSHOT. ' .~ ~-~ .~.~ 10627' CONTINUED POH, RIH WITH OVERSHOT,' 5-7/6- DRESSED WITH 4-7/8" GRAPPLE. ENGAGED FISH AT 10627' DPM. POH WITH HEAVY DRAG TO 10328'. LOST DRAG. POH WITH NO RECOVERY,; BUT SPIRAL GRAPPLE WAS MISSING FROI~THE OVERSHOT. RIH WITH A 3-1/2" SPEAR WITH 4' GRAPPLE. WORKED GRAPPLE TO 10629' DPM. POH. NO RECOVERY. ABANDONED FISH-AT 10627' DPM. RIH WITH 7" 29~ CASING SCRAPER WITH 6" BIT. SLIPPED AND CUT DRILLING LINE~ 10627' RIH WITH 7" SCRAPER TO 10627' DPM. COtJLD NOT PUSH JUNK. CIRCULATED. POH. RIH WITH RTTS AND SET SAME AT 10280' DPM. TEST 7" CSG TO 3000 PSI FOR 15 MINUTES-OK. POH WITH RTTS. TEST BOPE AS REQUIRED-OK. RIH WITH 6' BIT AND 7" SCRAPER TO 10627' ETD DPM; PU .LEED UP TO' 10211'. CIRCULATED~- H(3LE,~rWI~EE- STRINGING IN POLY BFIEAKER'S"; .... "~: -_~_~.~ .:. .- .. ~,~ ,. 10627' COMPLETED CIRCULATION WITH ADDmON (}F POLY BREAKER"S'. PUMPED.. 100 BBL~FiW~WI?H 55 GAL DIRT MAGNET.. CHANGE~~R WELLBORE TO FIW WITH 3% KCL. CLEANED PIT~. CIRCULATED AND FILTERED FLUID TO 38 NTU~. POH. MADE UP HOWCO TEST.TREE... RIH 10627' CoMPLETED RIHW/PEFI~. BHA;, TIED LOGS_ WiTH A -GR/CCL~ LOG RUI~.'~ ~,~' ~; HEMLOCK BENCHES I"AND 2 (10307~!033~L1)IL AND 10365'-10422' DIL)WITH GRAM DP CHARGES, 8 SPF. HAD GOOD BLOW FROM BUBBLE HOSE. REVERSED WELL CLEAN. FORMATION TOOK 40 BBLS/HR. MIXED AND SPOTTED A SIZED SALT PILL REDUCING LOSSES TO ZERO. POH WITH PERF BHA. RIH WITH 6' BIT AND 7' CASING SCRAPER TO 10622'. CIRCULATED DATE 04/21/91 04/22/91 04/23/91 04/24/91 04/25/91 MW GRA-YLING~ PLATFORI~ G-3~WO~~ WELL HISTORY~ PAGE' 4 10627' 10627' 10627' 10627' 10627' HOURS. 4./25./91. POH WITH BIT AND SCRAPER. RIH WITH OTIST.' BWH PERMA DRILL PACKER WITH SEAL BORE. EXTENSION AND SET SAME AT 10210'-?DIL~ RELEASED FROM PACKER AND POH; RIH~WrrH SEAL ASSEMBLY ON 3-1/2' DP AND STABBEE~INTC~ PACKER. TESTED ANNULUS TO 1500 PSI-OK. POH LAYING DOWN 3-1/2" DP. _ CONTINUED LAYING DOWN 3-1/2" Dp. RIGGED_ AND RAN 325 JOINTS OF 3-1/2" 9.2# L-80 TDSTBG PLUS JEWELRY AS PER THE TUBING DETAIL. HYDRO TESTED WHILE RIH. BEGAN SPACING OUT COMPLETION. COMPLETED SPACING OUT TUBING'- STRINg., LANDED 11" 5M X 4-1/2" SINGLE TUBING HANGER IN CIW DCB SPOOL. JEWELRY LOCATED AS FOLLOWS (ALL TBG MEASUREMENTS): TAIL AT 10284'; LOCATOR SUB AT 10210'; XA SLEEVE AT 10174'; AND SSSV AT 303'. NIPPLED DOWN STACK AND REMOVED SAME FROM RIG #55 SUBBASE. INSTALLED AND TESTED CIW 4-1/2' X 11' 5M SINGLE TREE. INSTALLED PRODUCTION FLOWI. INE AND GAS LIFT LINES. RETURNED WELL TO PRODUCTION AT 1200 HOURS. BEGAN TO DEMOBE EQUIPMENT ON RIG #55. · CONTINUED DEMOBE OF RIG #55. MOVED-BOPE HOIST TO RIG #54. INSTALLED ROTARY TABLE. MOVED HANDLING TOOLS TO RIG #54.. ~HOOKED UP SERVICE LINES TO RIG #54. MOVED ~ MANIFOLD TO RIG #54. HUNGOFF BLOCKS AND BEGAN CHANGING OUT THE DRAWWORKS BRAKE FINISH REPAIR ON DRAWWORKS BRAKES. SKID RIG #54 OVER TBUS G-6RD AND HOOKUP SERVICE LINES. RELEASED RIG TO TBUS G-6RD AT 2400 STATE OF ALASKA AL.~$KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ Pull tubing ~ Variance ~ ,', ,,, .... ~ ,", ....... I = ~'~ of Well: ,,~,., .... ~ , , . . Lf'~lon ~)'i~/~bmpany of California ( Oevelopment~ --I- Exploratory __ ~;~r~x 190247, Anch., ~, 99519-~247 StratigraphiC__service__ 4. Location of well at su~ ~4, Conductor ~19, Grayling Platform Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate __ Perforate -.x- Other 1833' FSL & 1480' FEL, SEC. 29, T9N, R13W, SM At top of productive in1~)¢~1307 ' MD/9139 ' TVD ( HB- 1 ) 1986' FNL & 334' FWL, SEC. 33, T9N, R13W, SM At effective depth 10,870 'MD/9624 'ri"VD 2182' FNL & 544' FWL, SEC. 33, T9N, R13W, S.M. At total depth 11,050'TMD/9780' TVD 2244' FNL & 606 FWL, SEC. 33, T9N, 12. Present well condition summary Total depth: measured true vertical 11,050' 9,780 ' feet feet Effective depth: measured 10,8 7 0 ' feet true vertical 9,6 2 4 ' feet 6 Datum elevation f DF or vm 'RT 103' MSL "~ feet 7' Uni~ra%~~y Unit 8. Well number Casing Length Size Structural 3 7 3 ' 2 6" Conductor 2209 ' 13-3/8" 7670' 9-5/8" Surface G-3 RD2 9. Permit number 83-10 10. APl number 50-- 733-20049-01 11. Field/Pool Ri 3W, SM .V[cArtl~ur River/Hemlock Plugs (measured~'% Junk (measured) Cemented Measured depth True veflical depth D=iven 373 ' 373 2500 sxs 2209 2725 sxs 7670' 6877 Intermediate 11,045' 7" 975 sxs Production 11,045' 9780' Liner Pedoration depth: measured 10,307'-10,344' DIL, 10,365'-,10,388' DIL, 10,392'-10,422' DIL 9,139'-9,172' DIL, 9,190'-9,209' DIL, truevertical 9,213'-9,238' DIL Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2", 9.2#, N-80 Buttress Otis Ball Valve @ 322' Baker "F-i" 10,237', Baker "F-i" pkr @ 10,344' pkr @ 13. Attachments Description summary of proposal x__ Detailed operations program __ BOP sketch x__ 14. Estimated date fo..r...comm, e..n.9.in_g operation Marc~ zu, ±~I 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil .~x Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed GA_RY R. RUSH g_.~ ,~. ¢c~.~ Titi~pw.~T~. DRILLING M_ANAGER 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- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH 404 Approved Copy Returned ~ ~ ~~.~.~_J~cemmissioner I Approval No. ? / _. ~ 7 ~ Date :2~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WORKOVER PROCEDURE TBUS G-3RD#2 (MARCH 5, 1991 · · · · · · · · · 10. 11. 12. 13. 14. 15. NOTE: MOVE RIG 55 OVER TBUS G-3RD#2, LEG 4, CONDUCTOR 19. CUT TUBING AT 10,225'. KILL WELL WITH 3% KCL COMPLETION FLUID. INSTALL BPV, NIPPLE DOWN TREE, NIPPLE UP AND TEST BOPE. PULL AND LAY DOWN G/L PRODUCTION STRING. MILL OVER AND RECOVER PERM PACKER AT 10,237'. MILL OVER AND RECOVER PERM PACKER AT 10,344'. CLEAN OUT FILL TO RETAINER AT 10,870' ETD. PRESSURE TEST 7" CASING WITH RTTS PACKER. CHANGE OVER TO CLEAN COMPLETION FLUID. REPERFORATE HEMLOCK BENCHES 1 AND 2 WITH TUBING CONVEYED PERFORATING ASSEMBLY. RUN BIT AND SCRAPER TO 10,870' ETD. SET PERMANENT PACKER AT 10,230' RUN SINGLE G/L COMPLETION. REMOVE BOPE AND INSTALL SINGLE TREE. RETURN WELL TO PRODUCTION AND MOVE OFF. SBHP ANTICIPATED TO BE 4025 PSI AT 9450' TVD. WORKOVER FLUID WILL BE 3% KCL/FIW BRINE WEIGHTED WITH NACL AS REQUIRED FOR WELL CONTROL. 3" KILL LINE WITH TWO 3" 5M VALVES I ' ':b KILL LINE FROM MUD PMP & CEMENT UNIT ,i NIPPLE 13-5/8" 3000 PSI ANNULAR . I PIPE RAMS BLIND RAMS l PIPE RAMS RISER ~ FLOWLINE 13-5//8" 3M FLANGE ADAPTER 3M x 5M 13-5/8" 5M FLANGE DOUBLE GATE 5M 13-5/8" 5M FLANGE 4." CHOKE LINE WITH ONE REMOTE ~: 1 MANUAL 4" §M VALVE ;t) d.~ CONNECTED TO CHOKE MANIFOLD (SEE IvlANIFOLD DRAWING) 13-5/8" 5bi FLANGE SINGLE GATE 5M 13-5/8" 51VI FLANGE 10" 5M x 13-5/8" 5M ADAPTER I I I I ! 13-5/8" BOPE 5M STACK GRAYLING PLATFORM UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 11/26/89 @ 2209' 9-5//8'' WINDOW @ 7670'- 7725' RET @ 1087O' 7" @ 1104-5' / TUBING DETAIL: 3-1//2", 9.2#, N-80 TUBING 1) SUBSURFACE SAFETY VALVE 2) CAS LIFT MANDRELS ,.5) "×A" SLIDING SLEEVE 4.)PERMANENT PKR @ 10230' 5) "X" LANDING NIPPLE 6) RE-ENTRY GUIDE HEMLOCK PERFORATIONS' HR- 1 10507'- 1034.4' HR-2 10365'- 10422' WELL TBUS G-SRD2 PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dbo UNOCAL) DRAWN: DAC SCALE: NONE DATE: 1-3-9 1 C T.B.U.S. G- 3RD WORKOVER, McARTHUR RIVER FIELD i CASING & ABANDONMENT DETAIL II ' ~ ~1 RT-OC~ at 0° ~J SINGLE 4.5' TUBING HANGER at 36.75' ' 20° DRIVE PIPE at 375' ',, I : ! 13318', 61~. J-55 BUTTRESS CASING at 2.209' ! ! 9518°. N-80. 47~,, BUTTRE$~ TO RETAINER at 775~' 4 i~L---; I WINDOW FROM 7670' TO 7725' W/KOP at 7675°. ~"~ E.T.D. CEMENT RETAINER at 10,870' -\ 5 ~.~, ~ 7° P-110, 29-- CASING at 11,045' ii,-- ~ ~I-CL"~; - , r---' ! TUBING DETA IL ? '~t'~M[ 3.5', 9.2., N-e0 BUTRES$ THREAD TUBING ,. a ,~L__~J 1. 4.5' x 3.5' CROSS-OVER at 37.50' i 2. OTIS BALL VALVE NIPPLE at 322.53' ~ 3.-14. McMURRY HUGHES G.L.M. at 3}2397.63', 4)4459.66'. { '.o.~ 5)5767.13'. 6)6613.23'. ?)7275.64', 8)7840. I0'. 9)8300.92'. · ,~l~-~'~ [ 10)8755.50', 11)9204.64', 12')9660.73', 13)9944,47', ~v ] ~ 14) 10,160.86' ~ ~2~ 15. OTIS 'XA' SLEEVE (Min. I.D.:2.75°) at 10,198.63' ,x~ 16. BAKER LOCATOR at 10,233.50' ! 17. BAKER F1 PERM. PACKER W/SEAL ASSY. at 10,237.00' 141~L.M~ 18. OTIS 'X° NIPPLE at 10,255.39' 19. MULE SHOE at 10,278.00' 20. BAKER FB-1 PERM. PACKER at .10,344' ~1~' 21. Ol18 'X' NIPPLE at 10.353' 22. BAKER WIRELINE RE-ENTRY GUIDE at 10,362' ,7 ~ ~ PERFORATION RECORD DATE INTERVAL CONDITION i 10,332' - ~0.337° PROOUGTION HEMLOCK BENCH I ~s~ 10,365 10,388 PRODUCTION. HENLOCK BENCH ~2 HB-1 := ~ -' ~.2/211a9 ].0392' - 10422' Dz~, ,B-2 PROD~C'~O~g 12/22/B! 10307' - 10344' HB-2 :: --. V~e ........ T_B.U.S_ G-3RD WORKOVER I:.-.. ~ UNION 01[. COMPANY OF CALIFORNI& WELL TBUS G-3 FID CASING & CEMENT DETAIL TOP PLUG ~7. 7675' VOLUMES SHOWN ARE (CMT. VOL./HOLE VOL.) TOP CMT, 126' 26°. 1' WALL, DRIVEN TO 373' 13 3/8', 61~'. J-55 CASING AT 2209' 250'0SX$ ('2875ftJ/2083ft;).o · TOP CMT, 3053' 8TM PLU~.?799· TOP ?°LINER, 8975 TOP PLUG *'6, 9144' BTM PLUG. 9293'* TOP 7'.29~.N-80 LINER, 9800' }!i:~.:.,?...~ ~t?O C~ AT ~' - (31341t J;3178~t~ 7',2Oe. N-oO LINER ~?' ~75iXl (43t ft*/teoft)~BND' CMT RETo10870' '7',2'9e; N-eO, 8rcI AT 11045' .' e2S ixl ( tOe31l '11602,lt~;. 6111183 '' ' ,-.,,.,-,o. ,,, -*. ~~-~?~. LINER AT 1 t259' . 40Orca (46011~129211~ '~ ' ' GOM~. 2/~ e/es NOTE: PLUGS 1-5 WERE SET DURING DRILLING OF ORIGINAL 12 1/4' HOLE. (BEFORE 9 5/8' CASING 6ET NOTE : A~L CEMENT TOPS. ARE THOERETICAL GRAYLING PLATFORM CASING & CEMENT DETAIL UNION OIL COMPANY OF CALIFORNIa, :....-..-. :. STATE OF ALASKA ,,,~. AL/-''~, OIL AND GAS CONSERVATION COMMI~ 'N REPOFrl OF SUNDRY WELL OPEI- TION$ 1. Operations performed: Operation shutdown __ stimulate __ Plugging m Perforate Pull tubing __ Alter casing __ Repair well __ pUll tubing __ 2. NarneofOperator Union Oil Co. of Calif. (UNOCAL) 3. Address PCB 190247, Anch, AK., 99519-0247 5. Type of Well: Development L.._/ Exploratory ~ Stratigraphic __ 4. Location of well at surface_ ., . · . 1833' N & 1480'u~ng~c~.rcglr.9,' ~ee~.#~-9, At top of productive interval 2013' S & 273' E of NW C°r., Sec. 33, At effective depth 2~d~pt% 550-' E of NW Cur., Sec. 33, T9N, R13W, T9N, R13W, T9N, R13W, SM SM SM 12. Present well condition summary Total depth: measured 11,050 ' feet true vertical 9,7 6 8 ' feet Effective depth: measured 10,8 7 0 ' feet true vertical - 9,6 0 9 ' feet Plugs (measured) Junk (measured) Other 6. Datum elevation (DF or KB) · RT 99 ' MSL 7, Unit or Property name Trading Bay Unit 8. Well number G-3RD2 feet 9. Permit number/approval number 83-10/7/,,_ F'..~ ~ 10. APl number 50--733-20049-02 11. F~lc~%~hur Rr./Hemlock Casing Length Size Cemented Measured, depth True vertical depth Structural 373 ' 26" DRIVEN 373 ' 373 ' Conductor Sudace" 2,209' 13 3/8" 2,500 sx 2,209' 2,179' Intermediate Production 7,670' 9 5/8" 2,725 SX 7,670' 6,802' Liner 11,045' 7" 925 sx 11,045' 9,765' Perforation depth: measured 10,307'-10,344',-10,368'-10,373', 10,392'-10,422', 10,440'-10,452' true vertical ~ 9,130'-9,161', 9,182'-9,186', 9,202'-9,228', 9,243'-9,253' Tubing (size. grad~ and measured depth) 3 1/2", 09 .2 # , N- 80 @ 10,278 ' : Packers and SSSV (type and measured depth) Baker F-1 @ 10,237' & 10,344' R E~ E~V ED 13. Stimulation or cement sqUeeze summary Intervals treated (measured) Treatment description including .volumes used and final preSSure Iv]AR - 6 t99'i Alaska Oil & Gas Cons. C0m~t-~ ~ch0rage 14. Pdor to well operation Subsequent to oPeration 15. Attachmenls Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 182 116 10 980 Tubing Pressure 100 237 191 2 780 16. Status of well classification as: Oil __/ Gas Suspended -- 17. I hereby certify that,[he foregOing istrue and correct to the best of my knowledge. Signed Gary~ B~XB~h~'/'~ ~ '"'~ T~Re~ional Form 10-404 Rev 06/15/88 Drilling Manager 140 Date ~ - t - c~ \ SUBMIT IN DUPLICATE ~'tOtl STATE OF ALASKA " ALASKA OIL AN D GAS CONSERVATION COM M ISSI ON 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 ~ Pedorate ~ Other ~ 5.Ty ~.¢.,~V~I :,. ,, 6. Datum el~:~{~io r~(~ F~ ore,i_, 2. Name~nO.~[~°roiI Company of Californ:.a t~~~nt~ feet Exploratory ~ . . 911519_O~raphic~ 7. Unit~&~~a~y Unit 3. Addre~.o BOX 190247, Anch , ~, Service 4. Location of well at su~ace COND. 19, LEG 4 8. Wellnum~uS G-3 RD2 1833' N & 1480' W OF SE COR., SEC. 29, T9N, R13~ , SM At top of productive interval 9. Permit number 83-10 2013' S & 273'E OF ~ COR., SEC. 33, T9N, R13W, SM At effective depth 10. APl number 50-- 733-20049-01 11. Field/~lOOK ~'ormatio~ At total de~th 2271' S & 550' E OF NW COR., SEC. 33, T9N, R13W, SM McArthur River 12. Present well condition summary 0 0' 14 [ [ I V t U Total depth: measured 9,768 ' feet Plugs (measured) true ve~ical feet NOV ~ 1 199~ Effective depth: measured 10,870 ' feet Junk(measured) true ve~ical 9,609 ' feet ~ ~il& GaS 80~S. Casing Length Size Cemented Measured depth True ve~ical depth Structural 373' 26" Driven 373' 373 Conductor 2209' 13-3/8" 2500 sxs 2209' 2179' Sudace 7670' 9-5/8" 2725 sxs 7670' 6802' Intermedime 11,045' 7" 925 sxs 11,045' 9765' Production Liner Pedorationdepth: measured 10,037'-10,344' 10 368'- 10 373' 10 392'-10 422' 10,440'-10,452' true ve~ical 9,151'-9,183', 9,298'-9,208', 9,224'-9,298', 9,265'-9,27 Tubing (size. grade, and measured depth) 3-1/2", 9.2~, N-80 8 10,278' MD Packers and SSSV (type and measured depth) Baker F-1 pkr 8 10,237' and 10,344' 13. A~achments Description summary of proposal __ Detailed operations program __ BOP sketch 14. Estimated date.f~rNove~erCOm~encing ~r, ati~n990 15. Status of well classification as: 16. If proposal was verbally approved Oil ~ Gas ~ Suspended ~ Name of approver Date approved Service 17. I hereby oe~i~ ~ fo~?oi~e and correct to the best of my ~~~ DRILLING ~NAGER . Title Date S ned ¢/¢" ¢O. CO .,SS,O. Conditions of a,,rov~,: Not~f~ Co~issio. so r~,re~.tativ. ~ ~it.~ss l*,~rov~, ,o. Plug integri~ __ BOP Test __ Lo~tion clearance __ ~ Mechanical Integri~ Test __ Sub~quent form required 10- Approved 0~¢~ ~IGi~L Sl6N¢D ~* Returned Approved byorderoftheCommi~ion ' ' ' Commissioner Date Form 10-403 Rev 06/15/88 November 21, 1990 RE: G-3RD2 perforating procedure 1. RU slick line, run gauge and tag bottom. 2. RU electric line unit and pressure test lubricator. 3. RIH and perforate the following intervals using 2 118" strip guns loaded at 4 SPF: 10,307' - 10,344' 10,368' - 10,373' 10,392' - 10,422' 10,440' - 10,452' 4. POOH, RD REEEIVED NOV ~ 1 1990 Alaska Oil .& Gas Cons. Gommiss[o~ Nlchorage · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION n REPORT OF'SUNDRY WELL OPERATIONS' 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Perforate __ Pull tubing __ Alter casing __ Repair well __ 2' Nam'~n°[Oo~er~itzO~ Company of California (UNOtA-5~ype°fWoII: Development · Exploratory 3. Addr~s.,~. Box 190247, Anch, Ak., 99519-02~i, 7 Stratigraphic._~_. Service / Other 6. D~t~m:~,,~tio~:~F or KB) 7; U ~D~[~rt~%nit 4. Location of well at sudace 1833' N, 1480' W F/S.E. Cor. of Sec. 29, At top of productive interval 2012' S, 273' E of NW Cor., Sec. 33, T9N, At effective depth At total depth T9N, R13W, $.M. R13W, S.M. 8. Well number G-3RD2 9. Permit number/approval number 83-10/9-892 10. APl number 50-- 733-20049-01 2271' S, 550' E of NW corner, Sec. 33, T9N, R13W, S.M. feet 11. Field/Pool McArthur River/Hemlock 12. Present well condition sUmmary Total depth: measured true vertical 11,050' feet Plugs(measured) 9,768 · feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 10,870 · feet Junk (measured) true vertical 9,609 · feet Length Size Cemented 373 ' 26" Driven 2209' 13-3/8" 2500 sxs 7670' 9-5/8" 2725 sxs Measureddepth 373' 2209' 7670' 11,045' 7" 975 SX 11,045' 10365'-10388' measured 10307'-10344' DIL; ~ueverticaldeCh 373' 2179' 6802' 9765' DIL; 10392'-10422' DIL trueve~ca19139'-9172' DIL; 9190'-9209' DIL; 9213'-9238' DIL Tubing (size. grade, and measured depth) 3-1/2", Packers and SSSV (type and measured depthbtis Ball valve "F-'I" 1¢~,'' fa 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 9.2#, N-80 @ 322', ~0344' Baker "F-i" 14. Representative Daily Average Production or Injection Data pkr @ 10237', Baker RECEIVED , _ancn0rc 3 Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 320 540 2 1064 586 430 CasingPressure ~bingPressure 730 psi (gas lift) 140 psi 1100 psi (gas lift) 200 ps~ 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations~__ 16. Status of well classification as: Oil ._~ Gas ~ Suspended Service 17. I hereby certify that the fgregoing is true and correct to the best of my knowledge. ~2¢;¢,¢ Signed ~' J Roy D. Title Environmental Engineer Form 10-404 Rev 06/15/88 Date//.-~-¢~'~ / SUBMIT IN DUPLICATE ( T.B.U.S. G- 3RD WORKOVER, McARTHUR RIVER FIELD ' CASING & ABANDONMENT DETAIL i:, ~ ~' ~1 i RT-DCB at O' 'iI 2 --~ ~ SINGLE 4.5' TUBING HANGER at 36.75' / ' 20' DRIVE PIPE at 375' i,~ 13 318', 61~, J-55 BUTTRESS CASING at 2,209' 6LM! 9 5/8', N-80, 47~, BUTTRESS TO RETAINER at 7751' ' ~ WINDOW FROM 7670' TO 7725' WIKOP at 7675'_ 4 GLM ' ; ~ ! E.T.D. CEMENT RETAINER at 10,870' -\ i 5 ~L----~ I i 7' P-110, 29~' CASING at 11,045' m-- 6 ~L---~ I i- ~ I TUBING DETA IL 7 GL'--'~ i 3.5', 9.2~, N-80 BUTRESS THREAD TUBING 8 ~L~._~_ ' 1. 4.5' X 3.5' CROSS-OVER at 37.50' 2. OTIS BALL VALVE NIPPLE at 322.53' 9~L~--~-' I 3.-14. McMURRY HUGHES G.L.M. at 3)2397.63', 4)4459.66', ~ ,o ~,~ I 5)5767.13', 6)6613.23', 7)7275.64', 8)7849.10', 9)8300.92'0 . i 1~)8755.50', 11)9204.64', 12')9660.73', 13)9944.47', ~v i ! 14)10,160.86' 1 ;2 ~L--'~ i 15. OTIS 'XA' SLEEVE (Min. I.D.:2.75') at 10,198.63' ~ ~3 GL~ 16. BAKER LOCATOR at 10,233.50' : 17. BAKER F1 PERM. PACKER W/SEAL ASSY. at 10,237.00' 14 18. OTIS 'X° NIPPLE at 10,255.39' I I ' 19. MULE SHOE at 10,278.00' , . 20. BAKER FB--1 PERM. PACKER at .10,344' ~5 X---~- 21. OTIS 'X' NIPPLE at 10,353' 22. BAKER WIRELINE RE-ENTRY GUIDE at 10,362' ~8 ~ DATE INTERVAL CONDITION ~ -10,332' - 10,337' PRODUCTION HEMLOCK BENCH ~,1 :q9 ~ 1 0,365 10,388 PRODUCTION, HEMLOCK BENCH ~2 HR- 1 := i 12/21/89 10392' - 10422' DIL HB-2 PRODUCT/Ot~ 12/22/89 10307' - 10344' DIL l:[6-1 PRODOC~ZON 20 HR-2 _--~ · I ! ! . "' T.B.U.S. -3RD RKOVER = i o~'r[ __3 / 1 5/84 I I .. .. J UNION OIL COMPANY OF CALIFORNIA i &NCHOR&GE:, JtL~=~K& $~4girT$ i LEASE GRAYLING UNOCAL DRILLING RECOR£ ALASKA REGION WELL NO. G-3RD~2 PAGE NO. 1 of FIELD MCARTHUR RIVER DATE 11/02/89 11/03/89 12/21/89 E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS COMMENCE OPERATIONS AT 0001 HRS, 11/02/89. Offload 1-1/2" coiled tubing unit. Rigged up Arctic Recoil on TBUS G-3RD#2, Conductor #19, Leg Room #4. Pressure tested BOPE and riser to 5000 psi. Rigged up 2.55" OD diamond bit and 2-3/8" mud motor on 1-1/2" coiled tubing. Opened well and ran in to 9500' CTM. Placed well on gas lift and broke circulation through coiled tubing at 1-1/4" BPM. Washed down to tubing tail at 10278' TM. Circulated well clean with gas lift assist. Continued in and tagged hard fill at 10326' CTM. Dropped circulation rate to 1 BPM-gaslift could not keep up at higher rate. Drilled scale to 10327' CTM (isolation pkr top). Could not work deeper-stalling mud motor. Trip for 2.5" OD Wavey Bottom mill. Diamond bit worn out on sides and outside bottom. Made up mill on new mud motor. Retest stack to 5000 psi. Open well up and placed on gas lift. Ran in with mill. Continued running in with 2.5" OD mill and tagged up at 10327' CTM. Broke circulation at 1-1/4" BPM. Milled obstruction from 10327' to 10329' CTM. Pulled up to 10200' CTM. Reduced circulation rate to 1/4 BPM and waited for gas lift to unload tubing. Ran in and tagged up at 10329' CTM. Milled obstruction from 10329' to 10345' CTM (end of isolation pkr assy). Made several passes to insure isolation packer assembly is clean to 2.5' ID. Circulated well clean. Shutdown pump and ran in to tag for fill. Tagged fill at 10638' CTM. Decided not to clean out deeper. Broke circulation at 1 BPM and washed up through isolation packer assembly-no restrictions. Continued pulling out, stopping at each GLM to wash out side-pockets. Rigged down coiled tubing unit. RELEASED RIG AT 1500 HOURS, 11/03/89. Rigged up Dresser Atlas for perforating run on G-3RD#2. Pressure tested lubricator to 3000 psi. Ran in with perf gun #1. Tied in and perforated from 10392' to 10422' DIL. Trip for next gun. Retested lubricator to 3000 psi. Ran in with perf gun #2. LEASE GRAYLING UNOCAL DRILLING RECOR! ALASKA REGION WELL NO. G- 3RD~2 PAGE NO. 2 of FIELD MCARTHUR RIVER DATE 12/22/89 E.T.D. DETAILS OF OPERATION, DESCRIPTIONS & RESULTS Continued running in with perf gun #2 to 10530 DIL. Ran gun from 10520' to 10020' DIL for tie in. Dropped down to 10530' DIL for confirmation pass. Logged up to 10020' DIL. Attempt to run back in and guns hung up at top of the isolation packer. Attempt to pull guns free-no good. Flowed well while working stuck guns. Pumped 20 BBL FIW into formation at 8 BPM while working stuck guns. Attempted to pull out of rope socket with 2100# overpull-no good. Fired guns with 2100# overpull and guns came free. Perforated from 10317' to 10344' DIL. Pulled out and recovered all guns. Ran 2.3" OD swage and set down at 10331' DIL. Made up and ran in with perf gun #3. Tied in and perforated from 10307' to 10317' DIL. All perforating was with 2-1/8" silver jet, 32 gram, 4 HPF. Rigged down wireline unit. Released Rig at 1700 hours, 12/22/89. STATE OF ALASKA A. ,KA OIL AND GAS CONSERVATION COME "ON 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 __ O'er x__ Name of Operator ! 5. Typeof Well: 6. Datum elevation (DF or KB) 2. Union Oil Company of California (UNOCAl) Devel0pmentX--- RT 103' MSL / Exploratory __ Address / Stratigraphic__ ~UniliorProD-ertyn-a-m¢-.l. raa~ng ~ay un~ 3. P.O. :Box 190247, Anch, Ak., 99519-0247I Service __ / 4. Locationofwellatsudace Conductor 19, Leg 4 1833' N, 1480' W of SE cor., Sec. 29, T9N, Attopofproductiveinterval R13W, S.M. 2013' S & 273' E of NW Cor., Sec. 33, T9N, R13W, S.M. ~ effectivedepth ~t0taldepth 2271' s, 550 E of NW Cor., Sec. 33, T9N, R13W, S.M. 8. Wellnumber ~-3RD2 9. Permitnumber 83-10 10. APInumber 50-- 733-20049-01 11. Field/Pool McArthur River Field Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,050' feet Plugs (measured) 9,768 · feet Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth 373' 2209' 7670' 11045' 10,870' feet Junk(measured) 9,609 · feet Size Cemen~d 26" Driven 13-3/'8" 2500sxs 9-5/8" 2725sxs 7" 925sxs measured true vertical Uppermost 10,332' Lowermost 10,388' Uppermost 9,147' Lowermost 9,197' Tubing (size, grade, and measured depth) 3 1/2", 9.2#, N-80 Otis Ball Valve @ 322', Baker Packers and SSSV (type and measuringS) "F-i" perm pkr @ 10,344' Measureddepth 373' 2209' 7670' 11045' ~uevedicaldepth 373' 2179' 6802' 9765' "F-l" pkr 13. Attachments Description summary of proposal .-.x.- Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: October 9, 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si ned ("~¢~'"{'~'~/¢"C'~itle t 1 g _ ~ Kft"r~'v ~ Rob~rts ~;k' Environmen a Enqineer - ' - FOR COMMISSION USE ONLY Condition~f/~pproval: Notify Commission so representative may witness Oil ~ Gas__ Suspended __ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGN.=D BY Approved by order of the CommissionerLu,~,'~ ,'--.' r,~., ~.,,.r_ C.. ,~,.,,g~,~lTH. :, Date IApproval No. Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TBUS G-3 RD2 PROCEDURE 1) MIRU SLICKLINE AND PULL BALL VALVE. 2) RUN 2.5" OD GAUGE CUTTER TO TAIL AT 10278' TM. 3) MIRU 1-1/2" COILED TUBING UNIT. 4) TEST BOPE TO 5000 PSI. 5) MIX 3% KCL WORKOVER FLUID. 6) RIH W/ 2-1/4" JET NOZZLE ON COILED TUBING TO TAIL AT 10278' TM. 7) CONT RIH THRU ISOLATION PKR AT 10344'(TAIL AT 10362') AND TAG FILL. 8) CIRCULATE OUT FILL TO 10870'ETD USING 3% KCL FLUID, ADDING NITROGEN AND HIGH VISCOSITY SWEEPS AS REQUIRED. A SMALL MUD MOTOR MAY BE NECESSARY TO ASSIST IN BREAKING UP THE FILL. 9) CIRCULATE UNTIL RETURNS ARE CLEAN. 10) MAKE WIPER TRIP TO TUBING TAIL. CHECK FOR ADDITIONAL FILL. 11) RD COILED TUBING EQUIPMENT. 12) RIG UP ELECTRIC LINE TO REPERFORATE HB-1 & HB-2. HB-1 10307' - 10337' DIL HB-2 10365' - 10388' DIL ' NOTE: ANTICIPATED SBHP IS 4025 PSI AT 9450' TVD. WORKOVER FLUID IS 3% KCL. Arctic Recoil, Inc. (907) 283-1980 P.O. Box 2595 Kenai, Alaska 99611 DATE; FACSIMILE TRANSMISSION COVER SHEET September 1, I989 TO:- Cliff Nave FROM: Jay Albrecht/Arctic Recoil__ Pages to follow including this cover sheet IF YOU DON'T RECEIVE ALL OF THE PAGES, PLEASE CALL AS SOON AS POSSIBLE. ART - KENAI PHONE #907 283-1980 ARI - KENAI FAX #907 283-5137 I hope this drawing and description will be of some help to you. The B~O.P. stack was built by Hydrolex in April of 1989 and is fully certified and documented. Ail Wellhead equipment is in compliance with: A.P.I. 6A and 16A (Specification for Wellhead equipment) N.A.C.E. MR 01-75 (Specification for H2S Service) A.P.I. Specifications for Low Tamp Service MIL-I-45208 (Military standard for Inspection Systems) The Hydraulic Stripper Assembly, Pump in sub, and additional lubricator also meet the above specifications. , "-"-~ STATE OF ALASKA -" ALAS~'....)IL AND GAS CONSERVATION COMN,,_ JlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) RT 99' HSL Feet 3. Add~.sl~ BOX 190247, Anch, AK., 99.519-0247 6. Unit. or Property. name . · ~raoing ~ay unit 4. Location of well at surface Oond. 19, Leg 4, 1833' N, 1480' W of SE Cor., ^t tooN, S.M. 2013' S & 273' E of NW Cor., Sec. 33, T9N R13W SM At effective depth At total depth 2271' S, 550' E of NW Corner Section 33, T9N, R13W, S.M 7. Well number G-3RD2 8. Approval number 633 9. APl number 50-- 733-20049-01 10. Pool Hemlock Formation 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,050' 9,768' 10,870' 9,609' feet Plugs (measured) feet feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Length 373 ' 2209 ' 7670 ' 11,045' Size Cemented 26" Driven 13 3/8" 2500 sxs 9 5/8" 2725 sxs 7" 925 sxs Production Liner Perforation depth: measured true vertical 10,307-10,337 10,365-10,388 9,124 upper most perf. 9,197 lower most perf. Measured depth ~ue Verticaldepth 373' 373' 2209' 2179' 7670' 6802' 11,045' 9765' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) None Treatment description including volumes used and final pressure R;C IVED Zklask~ 0il & Gas Cons, Commission 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 377 0 2 950 110 397 11 11 955 110 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~ _ ~, ~ ~,? ~'~ R)~2ber t s Signed Title Environmental Engineer Dat~03/05/87 Form 10-404 Rev. 12-1-85 Submit in Duplicate DALLY REPORT OF WELL OPERATIONS G-3RD2 February 2, 1987 Rig up on well G-3RD with slickline. Pull ball valve. Rig up electric line unit. Test lubricator to 3,000 psi. February 3, 1987 RIH with 23' of Gearhart 2 1/8" E jet II charges. Perforate Hemlock bench 2 from 10,363' to 10,388' at four shots per foot. POOH. Rig down. STATE OF ALASKA --- ALASK,-, OIL AND GAS CONSERVATION COMM. _.SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) RT 99' HSL 3. Address P.O. Box 190247, Anch, AK., 99519-0247 4. Location of well at surface Cond. 19, Leg 4, 1833' N, 1480' W of SE Cor., Section 29, TgN, R13W, S.M. At top of productive interval 2013' S & 273' E of NW Cor., Sec. 33, TgN R13W SM At effective depth At tot¢~z~_l~ths, 550' E of NW Co:mar Section 33, TgN, R13W, S.I~ 6. Unit qr Prpperty~ame · raozng ~ay Unit 7. Well number G-3RD2 8. Permit number 9. APl number 50-- 733-20049-01 10. Pool · Hemlock Formation 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,050' 9,768' feet Plugs (measured) feet 10,870' 9,609' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Length 373' 2209' 7670' 11,045' Perforation depth: measured true vertical Size Cemented 26" Driven 13 3/8" 2500 sxs 9 5/8" 2725 sxs 7" 925 sxs Upper most 10,332' Lower most 10,388' Upper most 9,147' Lower most 9,197' Tubing (size, grade and measured depth) 3-1/2" 9 2# N-80 Measured depth True Vertical depth 373 ' 373' 2209 ' 2179 ' 7670 ' 6802' 11,045 ' 9765 ' FEB 1 7 1987 Alaska OJJ & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Otis Ball Valve 8 322', Baker "F-i" pkr 8 10,237' Baker FB-1 perm pkr. ~ 10~344' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing opc,.ra, tion reoruary 3, 1987 14. If proposal was verbally approved Name of approver Mike Hinder Date approved 02-02-87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Roy Rober.t;.s Title Environmental Engineer ~9'~~ Co m mission Use Only Date 02/02/87 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance I Approval '~ ,-- /¢,.f,"'- No. Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate PROCEDURE - G-~RD2 1. Rig up slickiine and pull ball valve. 2. Run 2.125" gauge ring to 10,685' (E.T.D.). RD slickiine unit. R.U. Electric line unit and perforate bench 2 from 10,~65' - 10,)88' w/2-1/8" E Oet guns at 4 HPF. Shoot guns under drawdown conditions. 4. R.D. Electric line and rerun ball valve. Return well to production. STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMM._,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other I~ 2. Name of Operator 5. Datum elevation (DF or KB) Union Oil Company of C~lifornia dba UNOCAL RT 99' MSL Feet 3. Address 6. Unit or Property name P.O. BOX 190247, Anchorage, Alaska 99519-0247 Trading Bay Union 7. Well number G-3RD2 4. Location of well at surface Cond. 19, Leg 4, 1833' N & 1480' W of SE ~or., Sec. 29, TgN, R13W, SM At top of productive interval 2013' S & 273' E of NW Cor., Sec. 33, T9N, R13W, SM At effective depth At total depth 2271' S & 550'E of NW Cor., Sec. 33, TgN, R13W, SM 8. Approval number 633 9. APl number 50-- 733-20049-01 10. Pool Hemlock Formation 11. Present well condition summary Total depth: measured true vertical 11,050 ' feet Plugs (measured) 9,768 ' feet Effective depth: measured 10,870 ' true vertical 9,609 ' feet Junk (measured) feet Casing Length Structural Conductor 373 ' Surface 2209' Intermediate 7670 ' Production 11,045 ' Liner Perforation depth: measured Size 26" 13-3/8" 9-5/8" 7" Upper Most Lower Most true vertical UPpe~ Most Lower Most Cemented Driven 2500 sxs 2725 sxs 925 sxs 10,332' 10,388' 9,147' 9,197' Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 Measured depth True Vertical depth 373' 2209' 7670' 11,045' 373' 2179' 6802 ' 9765 ' ECEIVED JAN 0 6 1987 Ala~a 0il & 6~s Cons. Commissiorl Anchorage Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Otis Ball Valve @ 322', Baker "F-i" pkr @ 10,237' Baker FB-1 perm pkr. @ 10,344~ N/A Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 360 155 3 890 140 Subsequent to operation 375 30 5 14. Attachments Daily Report of Well Operations 15. I her~hat the foregoing i., ~e Correct to the best of my knowledge Signed Title Drilling Superindendent Form.~4 Rev. 12-1-/~- "'"" 1000 Copies of Logs and Surveys Run [] 115 Date 12/31/86 Submit in Duplicate DAILY REPORT OF WELL OPERATIONS 12/17/86 CO~ENCED OPERATIONS ON G-3RD2 @ 0500 HOURS 12/17/86. RIGGED UP 1 3/4" JET ON 1 1/4" COILED TUBING. RIH AND TAGGED RESTRICTION AT 9,677'. UNABLE TO JET THROUGH RESTRICTIONS. TRIP FOR 2.57" O.D. DIAMOND BIT AND 1 3/4" DYNA-DRILL. CLEANED OUT INTERMITTENT SCALE FROM 9,600' TO TUBING TAIL AT 10,278'. RIH AND TAGGED FILL AT 10,348'. DRILLED ON FILL AT 10,348 FOR 1 HOUR. DYNA-DRILL LOCKED UP. DID NOT MAKE ANY HOLE. TRIP FOR N~ DYNA-DRILL AND CHANGED TO A 2 1/16" TC ~LL. MILLED THROUGH BRIDGE AT 10,348'. CLEANED OUT TO10,380 AT 2400 HOURS. 12/18/86 Cleaned out soft fill from 10,380' to 10,860' using 6% KCl and high vis HEC sweeps. Wiped hole to 10,278'. Ran in hole to 10,860' and pumped 20 barrels sweep displaced with 110 barrels of 6% KC1. Pulled out of hole to 10,280' and waited 1 hour. Ran in hole and tagged fill at 10,685', 297' rat hole below lower perfs at 10,388' Pulled out of hole and rigged down coiled tubing unit, B-J ~kid and nitrogen. Loaded on MV Monarch for transport to Nikiski. Released at 1500 hours, 12/18/86. STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMrv,,oSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Addr~.s0 Box 190247, Anch, Ak., 99519-0247 4. Locatiion of well at surface UORQ.IY . . , Leg 4, 1833' N & 1480' W of SE cor , Sec 2~ At topTglxfI broR~u~c~/i~e '1%l~erval 2013' S & 273' E of NW Cor., Sec. 33, T9N, R13W, SM At effective depth At total depth 2271' S & 550' E of NW Cor.~ Sec. 33, T9N, R13W, SM 5. Datum elevation (DF or KB) RT 99' MSL feet 6. Unit ~r~~yi~ym~Jnit 7. Well number TBUS G-3 RD 2 8. Permit number 83-10 9. APInumber 50-- 733-20049-01 lO. PO01 Hemlock Formation 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 373' 2209' 7670' 11,045' Perforation depth: measured 11,050 ' feet 9,768' feet i0,870 ' feet 9,609 ' feet Size Plugs (measured) Junk (measured) Cemented 26" Driven 13 3/8" 2500 sxs 9 5/8" 2725 sxs 7" 925 sxs Measured depth True Vertical depth true vertical Upper most perf. 9i29' Lower most perf. 9197' Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 373' 373' 2209' 2179' 7670' 6802' 11,045' 9765' See attached schematic 12.Attachments Description summary of proposal ~ Detailedop~a~c~rr~b BOPsketch~ 13. Estimated date for commencing operation UPON :APPROVAL 14. If proposal was verbally approved i]EC1 5 1986 Alaska 0il & Gas Cons. Commission Name of approver J~~~pproved 15. I herebv~erti~.~tb~ the foregoing is true and correct to the best of my knowledge Signed ,Q.~ Roberts Title Environmental Engineer Date 12/12/86 Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Loo.a..t!On. qlearan...ce Approved by Commissioner IApproval No..~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Unocal proposes to run in the well with coiled tubing and circulate out the fill in G-3RD2 as outlined below: PROCEDURE: 1. RU slickline and pull ball valve. 2. MU 6% KC1 workover fluid. 3. RU skid pump unit to i 1/4" coiled tubing unit. Rressure test surface equipment to 3000 psi. Function test co,led tubing unit BOR system. 5. RIH with Navidrill tool on 1 1/4" coiled tubing to +_500' and break circulation. 6. Continue down hole and drill out any hard fill to cement retainer at 10,870. Estimated top of bridge is +10,344'. (Reciprocate and check pick up weight on coiled tubing after every 20' drilled to insure no bridging. If returns are lost during operation turn on gas lift and reestablish circulation.) 7. ROH with Navidrill and RIH with wash nozzle and tag fill. Kick well on and attempt to circulate fill-out. Use nitrogen to provide additional lift if needed. 8. After clean returns, ROH with coiled tubing and RD. 9. Return well to production and demob. RECEIVED AWska Oil & Gas Cons. Commission Anchor;~¢e T.B.U.S. G- 3RD WORKOVER, McARTHUR RIVER FIELD . . CASING & ABANDONMENT DETAIL RT-DCB at 0' ,~SINGLE 4.5' TUBING HANGER at 36.75' '2Q' DRIVE PIPE at 3,~ 133/8', 61~, J-55 BUTTRESS CASING at 2,209' 9 5/8', N-80, 47*, BUTTRESS TO RETAINER at 7751' WINDOW FROM 7670' TO 7725' W/KOP at 7675.[ E.T.D. CEMENT RETAINER at 10,870' .\ 7' P-110, 29* CASING at 11,045' TUBING DE TA IL " 3.5', 9.2--, N-80 BUTRESS THREAD TUBING 1. 4.5' x 3.5' CROSS-OVER at 37.50' 2. OTIS BALL VALVE NIPPLE at 322.53' 3.-14. McMURRY HUGHES G.L.M. at 3)2397.63', 4)4459.66', 5)5767.13', 6)6613.23', 7)7275.64', 8)7849.10', 9)8300.92', 1b)8755.50', 11)9204.64', 12')9660.73', 13)9944.47', 14)10,160.86' 15. OTIS 'XA' SLEEVE (Min. I.D.:2.75') at 10,198.63' 16. 17. 18. 19. 20. 21. 22. BAKER LOCATOR at 10,233.50' BAKER F1 PERM. PACKER W/SEAL ASSY. at 10,237.00' OTIS 'X' NIPPLE'at 10,255.39' MULE SHOE at 10,27~.00' BAKER FB--1 PERM. PACKER at .10,344' OTIS 'X' NIPPLE at 10,353' BAKER WIRELINE RE-ENTRY GUIDE at 10,362' HB-2 -- -- VI" _~'V. · DATE DATE PERFORATION RECORD %~'~1N T E R V AL CONDITION -lOr&3~' - 10,337' PRODUCTION HEMLOCK BENCH '1 10,365--10,888 PRODUCTION, HEMLOCK BENCH *2 ** 'ESTIMATED TOP OF FILL + 10,344 T.B.U.S. G-3RD WORI(OVER UNION OIL COMPANY OF CALIFORNIA ANCHORAGE , ALASKA RECEIVE o,Aw, B.A.WcKo. A,,,o. Fir,: C ,1 ~ ~,o.~.~ scxL[_ NONE DATE AJ;,s[~a Oit & Gas Cons. Commission Anchorag~ SHEETS SHEET OTIS REELED TUBING UNIT BLOWOUT PREVENTER ASSEMBLY wellhead. It contains four pair~ of rams which are hydraulically-powered for opening and closing. The preventers also contain a manual override to enable the rams to be operated with loss of hydraulic power or to be locked closed. Thc four pairs from thc buttom up are: l-inch OD tubing rems to packoff around the tubing, l-inch OD tubing malfunction. I-inch OD tubing cutler rams to cut the tubing ~hile it is in the wellborc if necessaD', and a pair of blind rams to close when the tubing i~ out of the wellbore. This prexenter a~em~I)- has a 5i0e outlet or inlet to produce or pump through if necessary. ~c assembly is designed for H2S Sec'ice and has a 5000 psi working presiure rating. 991 Alaska Oil & Gas Cons. Commission Anchorage OTIS ENGINEERING CORPORATION i · BLOWOUT PI1EVEHTER AS,~EMBL¥ ? BLIND RA~ ! CUTTER RAN -- SLIP I:AM 1-1]~CIt O.D. PIPE RAM Training UNOCAL Memo from Joyce Duwe )RNIA SHEET D PAGE NO. · ~ELD McArthur River Field [ATIONS, DESCRIPTIONS & RESULTS LENGTH BTM 1.38' 11045.13' 85.08' 11043.75' 1.34' 10958.67' 368.23' 10957.33' 37.72' 10589.10' 634.15' 10551.38' 43.09' 991'7.23' 2534.63' 9874.14' 44.68' 7339.51' 7221.17' 7294.83' 34.51' 73.66' 39.15' 39.15' TOP 11043.75' 10958.67' 10957.33' 10589.10' 10551.23' 9917.23' 9874.14' 7339.51' 7294.83' 73.66' 39.15' 0 STS 7" ISOLATION PACKER DESCRIPTION 3 1/2" Butt Re-entry .Guide 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" "X" Nipple (I.D. = 2.75") 3 1/2" Butt Pup 7" Baker "FB-I" Packer RECEIVED FEB 2 8 1986 Alaska rm ~, (~s Con~. Commi~sion /~eh0rage LENGTH BTM · 50' 10361.80' 8.54' 10361.30' 1.52' 10352.76' 4.14' 10351.34' 3.20' 10347.20' TOP · - 10361.30' 10352.76' 10351.34' 10347~20' 10344.00' ALASKA OIL AND ~AS CONSERYATION.f, OMMISSIO# Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALA~IKA 99 501.1-319 2 TELEPHON~ (907! 279,-1433 RE: We wish to bring to your attention that the Commission has no~* yet received the following required items on the subject well which our records indicated was completed .~--//-./~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. C. V. Chattertfon/ Chairman lc..C. 024 ALASKA OIL A#D GAS CO#SE£¥ATIOf/ CO,~, AfiSSIOY Permit No. Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 '-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C, V, Chatt~rffon Chairman Bill Sheffield Governor ALASKA OIL AHD GAS ~,O#S££VATIOfl ~,OH, i',~ISS/Oft 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501'-3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well %.~hich our records indicated was completed /l Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Co V. Chat~ Chairman ALASKA OIL AHD GAS O,O#S££¥ATIO# Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501;"3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed f~-//-~>~ // /-/ r,y / Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman STATE OF ALASKA ~ ALASK.. OIL AND GAS CONSERVATION ._,.)MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union 0il Company of California 83-10 3. Address 8. APl Number P. 0. Box 6247, Anchorage, Alaska 99502 50-733-20049-01 4. Location of Well Conductor #17, Leg-#4, 1833'N & 1480'W of SE Cor, Sec 29, T9N, R 13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL 6. Lease Designation and Serial No. ADL 18730 9. Unit or Lease Name Trading Bay Unit 10. Well Number TBUS G-3 RD #2 11. Field and Pool McArthur River Field Hemlock Formation 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). PROCEDURE 1. Moved rig over G-3 RD and killed well. 2. Installed BPV, removed tree, installed and tested-BOPE to 3000 psi. 3. Pulled existing 3 1/2" completion assembly. 4. Milled over perm packers@ 10270' and @ 10,420'. 5. Squeezed for isolation in preparation for fracture stimulating Hemlock benches 2 & 1; (f/10365-10388' w/79 sxs cmt & f/10337'-10307' w/61 sxs cmt). , 7. 8. 9. 10. 11. 12. 13. 14. 15. Perf'd f/10368' Set pk.r. @ 10350 Perf'd f/10332' Fractured HB #1 Cleaned out wel Ran GR/CCL logs f/10860'-9800'. Set permanent packers at 10344' &-_10222' DIL. Completed well with 3 1/2" completion assembly. Removed BOPE, installed tree and tested .to 5000 psi. Return well to production. -10373' w/4 HPF. ' & fractured HB #2 w/28 M lbs of bauxite. -10337' w/4 HPF. w/30M lbs. of bauxite. 1 to. 10870' DIL. RECEIVED: ]984 Date 03/23/84 best of my knowledge. Title District Drilling Supt. 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 ~ ~ ~-.~ STATE Or: ALASKA ALASK: )'ILANDGAS CONSERVATION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS./¢, · Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 83-10 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface Conductor #17, Leg #4, 1833' N. & 1480' W. of SE Corner, Sec 29, T9N, R 13 W, S.H. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSL[ ADL 187~o 8. APl Nurnber 50- 733-20049-01 9. Unit or Lease Name Trading Bay UnJ_t I10. Well No. TBUS G-3 RD #2 11. Field and Pool McArthur River Field ~mlock FormatLon For the Month of March ,19 R/z 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced Operations 8 00:01 Hfs, 3/04/84 Released Rig ® 08:00 Hrs, 3/17/84 Fracture Stimulated Hemlock Bench #2 w/ 28,000 lbs bauxite propant Fracture Stimulated Hemlcok Bench #1 w/ 30,000 lbs bauxite propant 13. Casing or liner run and-quantities of cement, results of pressure tests None . ~ 14. Coring resume and brief description None 15. Logs run and depth where run Ran GR log f/ 10860' - 9800' 6. DST data, perforating data, shows of H2S, miscellaneous data Squeezed Hemlock Bench #2 10365'-10388' DIL Squeezed Hemlock Bench #1 10307'-10337' DIL Rerforated Hemlock Bench #2 10368'-10373' DIL Rerforated Hemlock Bench #1 10332'-10337' DIL Completed well with single 3 1/2" completion assembly 17. SIC I hereby/ce~ that the foregoing is true and correct to the best of my knowledge. SUPT 04/13/84 DATE N~_Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska on (~il'and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate ALASKA OIL AND GAS f,O#S££VATiO# Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501~'3192 TELEPHONE(907) 279-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~--//--j~,_~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, 'stipulates that this material shall be filed ~ithin 30 days after completion of a drilled well. Please 'submit the above missing material. Sincerely, C. V. Chat~ Chairman STATE OF ALASKA ~ ALASKA ~,,L AND GAS CONSERVATION CC,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 83-10 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 soZ33-20049-O1 4. Location of Well Conductor #17, Leg #4, 1833'N & 1480'W of SE corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT 99' MSL I 6 . Lease Designation and Serial No. ADL 18730 12. 9. Unit or Lease Name TRADTNC, BAY UNIT lO. Well Number TBUS G-3 RD #2 11. Field and Pool HEMLOCK FORMATION McARTHUR RIVER FIELD Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROCEDURE: 1. Move rig over G-3 RD and kill well. 2. Install BRV, remove tree, install and test BORE to 3000 psi. 3. Pull existing 3 1/2" completion assembly. A. Mill over perm packer ® 10270'. 4. Set RTBR 8 +10420' (on top of iso-packer ® 10420') and sand out to 10400'. A. Rerf H~ #2 f/ 10376' to 10384' w/ 4" casing guns. 5. Set RTTS ® 10350' and frae HB #2 with Dowell vertafrac using bauxite for proppant. 6. Sand out to 10350' and perf HB #1 with 4" casing guns from 10329' to 10337'. 7. Set RTTS ~ 10300' and frae HB #1 with Dowell invertafrac using bauxite as proppant. 8. Retrieve RTBP from 10420,'. 9. Set permanent packer ~ +10290'. 10. Complete well with single 3 1/2" tubing and return well to production. 14.1 he/eby g~rtify that th~o~ng is true and correct to the best of my knowledge.~~ :,!':-.'~:'~ (!ii .' ",2':. {' '.:~.' ~':"-:i!:"',~ ~:.. Signed Title District Drlg Superintendent Date 0/ Th~p.~e below for Commission use ~tions of Approval, if any: Approved Copy Approved by Form 10-403 Rev. 7-1-80 Returned By Order of COMMISSIONER the Commission Submit "Intentions '~in Triplicate and "Subsequent Reports" in Duplicate ~_..~ STATE OF ALASKA ALASKI ILAND GAS CONSERVATION C ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 83-10 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 so- 733-20049-01 4. Location of Well at surface Conductor #19, Leg #4, 1833'N & 1480'W of SE Corner, Section 29, T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSL I ADL 18730 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS G-3 RD #2 11. Field and Pool McArthur River Field Hemlock Fm. F,or the Month of. JUNE 83 ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Recommenced operations ® 00:01 hrs 6/22/83 Completed operations ~ 24:00 hrs 6123183 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None JUL 9 ~eka 0it & Gas Cons. Anchorage ,1 6. DST data, perforating data, shows of H2S, miscellaneous data Reperfed 4 HPF: HB #2 f/ 10388-10365' HB #1 f/ 10337-10307' Stimulated well w/ 3000 gal Naphtha Solvent " 4000 gal Naphtha w/ FFA-1 " 3000 gal Naphtha Solvent 17. her~oy certify foregoing is true and correct to the best my knowledge. I that the of / / SI LE DISTRICT DRLG SUPT DATE 7/11/83 /N~JReport on required month, regardless status operations, and must be in duplicate with this form is for each calendar of the of filed the Alaska L.~ffand Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ./ .~- STATE OF ALASKA '~' ALASKa. ~)IL AND GAS CONSERVATION C.,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER);~ 2. Name of Operator 7. Permit No. UNION 0IL COHPANY OF CALIFORNIA 83-10 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50~33-20049-01 4. Location of Well Conductor #19, Leg #4, 1833'N & 1480'W of SE corner, Section 29, TgN, R13W, SM. 9. Unit or Lease Name TRADING BAY UNIT 10. Well Number TBUS G-3 RD #2 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' MSL I ADL 18730 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Hemlock Formation McArthur River Field NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation J~ 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 completiori.) 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. Perfed Hemlock Bench #2 f/ 10388-10365' and Hemlock Bench #1 f/ 10337-10307' w/ 4 HPF thru tbg. 2. Pumped 3000 gal of Naphtha solvent, followed by 4000 gal of Naptha w/ FFA-1, followed by 3000 gal of Naphtha solvent. 3. Displaced w/ 93 bbls of diesel. 4. Released rig f/ G-3 RD #2. Verbal permitted by Russ Douglas on 6/21/83 REI EIVED JUL 1.9 19113 Anchorage T/~~elow for Commission use (~ions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA/-~'L AND GAS CONSERVATION Ct ",MISSION MONTHLY REPORT OF DRILLING -AND WORKOVER OPERATIO 1. Drilling well J~] Workover operation [] 2. Name of operator 7. Permit No. UNION 0IL COHPANY OF CALIFORNIA 83-10 3. Address PO BOX g247 4. Location of Well at surface ANCHORAGE AK 99502 8. APl Number 50- 733-20049-01 9. Unit or Lease Name TRADING BAY UNIT Conductor #19, Leg #4, 1833'N & 1480'W of SE corner, Section 29, T9N, R13W, SN. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT 99' ~RI] ADL 18730 10. Well No. TBUS G-> RD #2 11. Fie~d and Rooi McArthur River Field F~mlocR Formation For the Month of Iv]BY ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Released rig ~ 24:00 hfs 5/11/83. 11050' TMD 13. Casing Or liner run and quantities of cement, results of pressure tests Ran 7" liner f/ surface to 11045'. gmt'd w/ 925 sxs cl "G", Tested to 2500 psi-ok. 14. Coring resume and brief description None 15. Logs run and depth where run CBL-VDL-GR logs f/ 10957-7000'. :1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed & Sqz'd 10652-10654' 10294-10296' Perfed 10307-10337' 10365-10388' 17. I hereby~/~/that the foregoing is true and correct to the best of my knowledge. SIGNE LE DISTRICT DRLG SUPT DATE 5/20/83 NOTE[R~o~rt on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil an(;ll~as Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate ....... STATE OF ALASKA ':~-' ALASKA]:.. AN D GAS CONSERVATION G~.'-..CllssION ~C~ ,WELL COMPLETION OR RECOMPLETION'REPORT AND LOG ' 1. Status of Well Classification of Service Well , OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA 83-10 3. Address 8. APl Number ~'~ .PO_ R0X 62~.7 ANCHORAGE AK 99502 5°-733-20049-nl 4. Location of well at surface 9. Unit or Lease Name Cond. 19, Leg 4, 1833'N & 1'480'W of' SE cot., Sec. 29, * TRADTNR RAY IlNTT At Top Producing Interval 10. Well Number 2013'S & 273'E of' NW Cci:., Sec. 33, * TBUS 6-3 RD #2 At Total Depth 11. Field and Pool 2271'S & 550'E of NW COZ'., Sec. 33, *T9N, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. McARTHUR RIVER FIELD RT 99' MSL Kg ~oo ADL 18730 HEMLOCK FORMATION 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore i16'N°'ofC°mpleti°ns 4/13/83 4/28/83 5/11/83 ~! ~" feet MSLI 17. Total Depth (MD+TVD) 18. PIug Back Depth (MD+ l-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost ll050'MD & 9768' FVD --- YES~]~ NO [] 318 feet MDI ...... -. 22. Type Electric or Other Logs Run DIL-BHC-Sonic-VDL, FDC-CNL-NGT, CBL-VDL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED _ 7" 29# N-80 & P-110 Surface 11045 8 1/2 925 sxs cl "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD - interval, size and number) -- SIZE DEPTH SET (MD) PACKER SET (MD) HB# MD TVD S±ze HPF 3 1/2" 10290 10250 --1- 1030~-10337 912'~158 ' ~" 8 2 10365-10388 9179-9199' 1/2" 8 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED , 10652-10654 100 sxs cl "G" 10294-10296 100 sxs cl "G" 27. PRoDucTION:TEST Date, Eifst Production . I.Metb. od of Operation (Flowing, gas lift, etc.) 5/12/83J Gas Lif,t Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 5/1-2/83 24 ~rEST PERIOD I1~ 2293 1782 35 192/64] 777 FloW Tubing . Casing Pressure .- CALCULATED I~ OIL-BBL . GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press-, 125 1080 : 24-HOUR RATE -~. ]: '229~_ .1782 35 33.5° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. c ': None ~. : : , . ~ · - : "- - ,,,; ~'; ~as CC:!0 r,~ , : ._ . ,,:,.,~.,;;r~r,,.aS'' ~'":',:~.,~u:~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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. T/"G" Zone 9438 8373_ 519183 Perfed Hemlock Bench #1 T/HemloCk 10304 9127 10310-10311' ® 4 HPF T/N Foreland 10887 9628 Recorded reservoir pressure of 3056 psia. :. 31. LIST OF ATTACHMENTS 32. I hereby cer/t,i~ that the foregoing is true and correct to the best of my knowledge Signed Title DIST DRLG SUPT Date 5/23/83 .// I NSTR UCTtONS General' This form is designed for submitting a complete and correct well completion report and Icg 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 o_nly 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- lng 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". UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. 1 LEASE Trading Bay Unit WELL NO. G-3 RD #2WO FIELD McArthur River Field LOCATION: Conductor #19~ Leg #4, 1833' N and 1480' W of SE cor. of Sec. 29~ TgNr R13W~ SM. SPUD DATE 3/4/84 COMP. DATE 3/17/84 CONTRACTOR Conserv ~rl Co RIG NO' 55 TYPE UNIT National 1320 UE DRILL PIPE DESCRIPTION 5" 19.5# PERMIT NO. 83-10 SERIAL NO. ADL 18730 TD 11050' TMD TVD 9780' TVD DEVIATION (BHL) 4557' $26° 13'E COMPANY ENGINEER McAllister~ Abernathy, Bush ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL 111.60' RT PRT/I~DRILLO~ DECK,, RT TO CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 13 3/8" 61# Buttress 0-55 2209' 9 5/8" 47~43.5~ 40# Buttress P-110 N-80 7670' 7" 29# Buttress~ 8RD N-80 P-110 11045' Cmt'd w/ 2500 sx. Class "G" cmt. Top of window. Cmt'd w/ 925 sx. Class "G" cmt. PERFORATING RECORD ' DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5104/83 10652'-10654' 10957' F.C. B.S. #1 5105/83 10294'-10296' 10622' RET. B.S. #2 5/09/83 5/~0/83 5/11/83 10310'-10311' 10957' F.C. DST #1 10365'-10388' 10957' F.C. Iso S. 10307'-10337' 10957' F.C. Iso S. Sqz'd base of H.B. $;4, w/ 100 sx cmt. Sqz'd top of H B. #1'; w/ 100 sx cmt'. Test formation pressure in Bench #1 Sgzd HB $;2 w/ 79 sx cmt Sqzd HB #2 w/ 79 sx cmt L 3/10/8 _4 10368 ' -10373 ' 10870 ' F.C. Production H.B. #2 Frac/ Open '~.'11/84 10332'-10337' 10870' F.C. Production H.B. #1Frac/ Open INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 5/11/83 10365'-10388' 10307'-10337' 2334' 1% WELL HEAD ASSEMBLY TYPE: CIW CASING HEAD: Shaffer Model KD 12" Series 900 w/ 2-2" L.P. Scr Outl X 13 3/8" SOW CASING SPOOL: 12" 3000 psi X 12" 3000 psi - 7" hung w/ 165~000# TUBING HEAD: CIW 12" 3000 psi X 10" 5000 psi DCB TUBING HANGER: Cameron 10" Nominal x 4 1/2" Buttress Bottom & 4 1/2" Eue 8rd top TUBING HEAD TOP: 10" 5000 psi X 4" 5000 psi adaptor w/ 4 1/8" Bore MASTER VALVES: 2 CIW 4" 5000 psi valves w/ Block between for WKM CHRISTMAS TREE TOP CONN: 4 1/2" Eue 8rd 4" 5000 psi Wing Valves UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. .2 LEASE Trading Bay Unit WELL NO. G-3 RD #2 WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS GRAYLING PLATFORM G-3 RD #2 WO (UOCO) AFE #331413 U.O. 40.95% 10957' ETD FC 1 D 3/04/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 32,888 ACC COST: $ 32,888 AFE AMOUNT: $805,000 COMMENCED OPERATIONS ON G-3 RD #2 ® 00:01 HRS, 3/04/84. KILLED WELL W/ A 30 BBL SAFE SEAL PILL. FILLED ANNULUS. SET BPV. ND X-MAS TREE. NU BOPE. TEST BOPE. CIRC WELL CLEAN THRU "XA" SLEEVE ~ 10233' MD. 10957' ETD FC 2 D 3/05/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 29,632 ACC COST: $ 62,520 AFE AMOUNT: $805,000 CIRC WELL CLEAN. PULL 3 1/2" TBG AND STAND BACK IN DERRICK. PU FISHING ASSY ON 3 1/2" DP AND RIH TO PERM PKR ® 10,262 DPM. CIRC OILY SYSTEM OUT OF WELL AND MIX 6% KCL IN FIW. 10957' ETD FC 3 D 3/06/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 451 PSI/ 1000' DAILY COST: $ 24,153 ACC COST: $ 86,673 AFE AMOUNT: $805,000 BURN OVER BAKER F-1 PERM PKR 8 10,262 DPM (10,270 DIL). POOH W/ DP. PACKER FELL OFF FISHING ASSY ON TRIP OUT OF HOLE. RIH W/ SPEAR & ENGAGE FISH ® 10,427' DPM. POOH W/ FULL RECOVERY OF PKR. RIH W/ BURN OVER SHOE & SPEAR. BURN OVER BAKER FB-1 PERM PKR 8 10,431' DPM (10,420' DIL). POOH W/ FISHING ASSY ON DP. 10870' CMT RET ON TOP OF JUNK 4 D 3/07/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 48,754 ACC COST: $135,427 AFE AMOUNT: $805,000 POOH W/ FISHING ASSY. RECOVER FB-1PKR. LEFT MILLOUT EXT IN HOLE. RIH W/ FISHING SPEAR (4 1/2" CATCH) AND TAG FISH ~ 10890' DPM. ENGAGED FISH AND POOH. NO RECOVERY. LEAVE FISH IN HOLE. RIH W/ 6" BIT & 7" SCRAPER. PUMP HIGH VIS PILL TO CLEAN HOLE. RIH W/ HOWCO TYPE S-V EZ DRILL CMT RET AND SET ~ 10870' DIL ON WL. POOH W/ WL. LEASE Trading Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-3 RD #2 WO SHEET D PAGE NO. FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10870' CMT RET ON TOP OF JUNK 5 D 3/08/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 43,318 ACC COST: $178,745 AFE AMOUNT: $805,000 10870' ETD CMT RET ON TOP OF JUNK 6 D 3/09/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 26,768 ACC COST: $205,513 AFE AMOUNT: $805,000 FIN POOH W/ WL. RIH W/ CMT RET ON WL AND SET ~ 10413' DIL. POOH W/ WL. RIH W/ CMT RET ON DP AND SET ~ 10364' DPM (10353' DIL). SQUEEZED HEMLOCK BENCH #2 (10365'-10388') W/ 79 SXS CMT (.75% CFR-2, .4% HALAD 22A, 5% KCL, CLASS "G") BEHIND THE PERFORATIONS W/ A FINAL PUMPING RATE OF 3 CFM ~ 6000 PSI. SQZ OOB HELD 4800 PSI W/ PUMPS OFF AFTER 3 MIN. CIP ~ 7:30 AM, 3/8/84. POOH W/ DP & STINGER. RIH W/ 6" BIT & 7 CSG SCRAPER. CO CMT F/ 10345'-10364' DPM. CIRC HOLE CLEAN. POOH W/ DP. RIH W/ RTTS & SET TOOL ® 10165' (3 1/2" TBG TAIL ® 10199'). PREP TO SQZ HEMLOCK BENCH #1 (10307'-10337'). SQZ HEMLOCK BENCH #1 (10307-10337' DIL). BROKE DOWN FORMATION W/ 3250 PSI PUMPING 10 CFM. DISPLACED 61SXS (CLASS "G", .75% CFR-2, .4% HALAD 22-A, 5% KCL) BEHIND PERFS W/ FINAL PUMPING RATE OF 4 CFM ~ 5200 PSI. SQZ JOB HELD 4100 PSI W/ PUMPS OFF AFTER 2 HRS. CIP ® 2:00 AM, 3/9/84. POOH W/ RTTS. RIH W/ 6" BIT & WOC FOR 18 HRS. CO CMT F/ 10207-10364' DPM. TEST SQZ JOB TO 2500 PSI, OK. 10870' ETD CMT RET ON TOP OF JUNK 7 D 3/10/84 9 5/81l C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 98,766 ACC COST: $304,279 AFE AMOUNT: $805,000 DRL UP CMT RET 8 10364'. CO CMT TO 10424' DPM. TEST SQZ JOB BENCH #2 to 2500 PSI, OK. CIRC HOLE CLEAN. POOH W/ DP. RIH W/ WL AND PERF F/ 10368-10373' DIL W/ 5" CSG GUN, 4 HPF, 120° PHASING .58" HOLES. TRIP WL & RIH W/ OTIS WDF PERM PKR W/ BALL VALVE BELOW PRK. SET PKR 8 10350' DIL. POOH. RIH W/ OTIS SEAL ASSY ON DP. TAG PKR ~ 10357' DPM. STAB IN & TEST TO 2500 PSI, OK. RIG UP DOWELL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading B~y Unit WELL NO. G-3 RD #2 WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10870' ETD CMT RET ON TOP OF JUNK 8 D 3/11/84 9 5/8" C. 7670' 7" C. 11045' 66 RCF 458 PSI/ 1000' DAILY COST: $ 57,093 ACC COST: $361,372 AFE AMOUNT: $805,000 TST DOWELL PUMPS & LINES TO 6000 PSI, OK. START FRAC PROGRAM. UNSTAB F/ PKR AND START PUMPING FLUID. PUMPED 59 BBLS YF4PSD & 12 BBLS OF WF5 AND STAB INTO PKR. START PUMPING DIVERTIFRAC WFS. PRESS BUILT TO 5000 PSI W/O BREAKDOWN. SHUT DOWN (ll MIN). OPEN BLEEDER VALVE AND RELEASE PRESS. START PUMPING. PRESS BUILT TO 7100 PSI WHEN FORMATION STARTED TO FRACTURE. PRESS FELL TO 4600 PSI PUMPING 5 BBL/MIN. PUMP DIVERTIFRAC STAGES AND WF5 SPACER. PUMP YF4PSD PAD. PRESS BUILT TO 7800 PSI WHILE DISPLACING DIVERTIFRAC INTO FORMATION. SHUT DOWN FRAC SOB DUE TO HIGH .PRESS. PRESS BLED TO ZERO AFTER 20 MIN. RIH W/ 2 1/8" GUNS. GUNS SET DOWN IN WDF PKR ~ 10350'. POOH W/ WL. ATTEMPT TO FRAC BENCH #2 AGAIN. PUMPED AGAINST FORMATION TO 7500 PSI. SHUTDOWN. GOT SLOW BLEED OFF TO 4100 PSI. PRESSURE UP TO 6100 PSI AND GOT BREAKDOWN W/ FIW & 6% KCL (8 BBL/MIN ® 6300 PSI). START PUMPING THE FOLLOWING STAGES: Volume Rate Fluid Press (Gal) BPM Type PSI 3500 5.5 S~acer WF5 6100 looo 7.5 YF4PSD Pad 6100 4000 8.0 YF4RSD Pad 6100 1000 8.0 YF4RSD 6100 1000 8.0 YF4RSD 6100 1000 8.0 YF4PSD 6100 2000 8.0 YF4RSD 6000 2000 8.0 YF4PSD 5400 2500 8.0 YF4RSD 5400 Prop Cone P~op AMT 1.0# 100 Mesh Sand 1.0# 20-40 Mesh Bauxite 2.0# 20-40 Mesh Bauxite 3.0# 20-40 Mesh Bauxite 4.0# 20-40 Mesh Bauxite 4.0# 12-20 Mesh Bauxite 1000 1000 2000 6000 8000 10000 DISPLACE FRAC FLUIDS W/ 6% KCL & FIW. FINAL PUMPING PRESS 5900 PSI ® 9 BPM. PRESS BLED TO 2000 PSI AFTER 25 MIN. UNSTAB & REVERSE OUT EXCESS FRAC FLUIDS (40-50 CF) CIRC HOLE CLEAN. POOH W/ DP. RU & RIH W/ 5" CSG GUN. PERF F/ 10332-10337 DIL W/ 4 HPF, 120° PHASING. 10870' ETD CMT RET ON TOP OF JUNK 9 D 3/12/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $116,931 ACC COST: $478,303 AFE AMOUNT: $805,000 RIH W/ RTTS PKR ASSEMBLY. TAGGED OTIS PKR ® 10360' DPM. PULLED UP 55' AND SET RTTS ~ 10271' OPM, TAIL ~ 10305' DRM. RU DOWELL. TSTD RUMPS & LINES TO 8000 PSI - OK. TSTD ANNULUS TO 2500 PSI - OK. BROKE DOWN BENCH #1RERFS F/ 10332' TO 10337' DIL'W/ 5 BPM ~ 4000 PSI. FRAC STIMULATED HEMLOCK BENCH #1 & DISPLACED FRAC FLUIDS W/ 6% KCL IN FIW. HAD FINAL RATE OF 10 BPM ® 5000 PSI. HELD PRESSURE FOR 1.5 HRS. OPENED TOOL - HAD NO FLOW. PULLED STANDS - DP WAS PLUGGED. CIRC DP CLEAN POOH. RIH W/ BURN-OVER SHOE AND TAGGED FILL 10285'. CO DOWN TO OTIS PKR ® 10362' DPM AND BEGAN MILLING OVER OTIS PERM PKR. LEASE Trading Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-3 RD #2 WO SHEET D PAGE NO. FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10870' DIL ETD CMT RET ON TOP OF JUNK MILL OVER OTIS WDF PERM RKR. POOH W/ FISHING 10 D 3/13/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $ 24,633 ACC COST: $502,936 AFE AMOUNT: $805,000 ASSY. RECOVERED PKR BODY AND BALL VALVE SUB. RIH W/ 6" JUNK MILL & 2 JUNK BASKETS. TAG FILL ® 10382' DRM, (42' OF FILL). CO TO EZ-DRILL CMT RET 8 10424' DRM. MILL CMT RET AND RUSH TO BOTTOM, 10880' DRM (10870' DIL). CIRC WELL CLEAN W/ HIGH VIS RILL. POOH W/ DR & MILL. RIH W/ 6" BIT & 7" CSG SCRAPER TO 10880' DRM. CIRC BTMS UR. POOH W/ DR. 10870' DIL ETD CMT RET ON TOP OF JUNK RIH W/ GR & CCL TOOLS ON DRESSER ATLAS WL. 11D 3/14/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $ 53,577 ACC COST: $556,513 AFE AMOUNT: $805,000 LOG F/ 10860-9800'. POOH W/ WL. RIH W/ 5 7/8" GAUGE RING & JUNK BASKET TO 10400'. POOH. RIH W/ FB-1 BAKER PERM RKR AND SET 8 10344' DIL. POOH. RU TEST SEAL ASSY & RIH. TAG RKR 8 10355' DRM & TESTED RKR TO 400 RSI,~OK. POOH W/ DR. RIH W/ F-1 BAKER PERM RKR AND SET @ 10222' DIL. POOH W/ WL. RIH W/ TEST SEAL ASSY & TAG RKR ® 10233' DRM & TESTED RKR TO 450 PSI -OK. POOH & LD DR. 10870' DIL ETD CMT RET ON TOP OF JUNK LD DP. RU & RUN 3 1/2" TBG. STAB INTO F-1 12 D 3/15/84 9 5/8" C. 7670' 7" C. 11045' DAILY COST: $ 33,662 ACC COST: $590,175 PKR ~ 10237' TBG MEAS. TSTD PKR TO 400 PSI, OK. SPACE OUT & LAND TBG. ND BOPE, NU X-MAS TREE & TEST TO 5000 PSI. RU PRODUCTION LINES. LOAD 3 1/2" DP ONTO BOAT. AFE AMOUNT: $805,000 10870' DIL ETD CMT RET ON TOP OF JUNK DISMANTLED MUD PUMPS AND CLEANED PITS. RIGGED 13 D 3/16/84 DOWN CENTRIFUGAL PUMPS AND LOADED DRILLING 9 5/8" C. 7670' EQUIPMENT INTO BASKETS FOR SHIPMENT. OFFLOADED 7" C. 11045' RIG EQUIPMENT FROM PLATFORM. DAILY COST: $ 27,680 ACC COST: $617,855 AFE AMOUNT: $805,000 10870' ETD CMT RET ON TOP OF JUNK 14 D 3/17/84 " 9 5/8" C. 7670' 7" C. 11045' OFFLOADED ALL DRILLING EQUIPMENT ONTO BOAT. MOVED EQUIPMENT TO MONOPOD. RELEASED RIG ~ 08:00 HRS, 3/17/84. DAILY COST: $ 14,135 ACC COST: $631,900 AFE AMOUNT: $805,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 9 15 15 15 15 19 22 28 43 69 68 9 CIW 3 1/2" TUBING DETAIL DESCRIPTION LENGTH BOTTOM TOP 3 1/2" Baker Wireline Guide 3 1/2" 9.2# N-80 Butt Pup 3 1/2" Otis "X" Nipple 3 1/2" Butt Coupling 3 1/2" 9.2# N-80 Butt Pup Baker Seal Assembly (4" OD) Baker 7" Model F-1 Rkr Baker Locator 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" Otis "XA" Sleeve 3 1/2" Butt Coupling 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" McMurray-Hughes GLM .69' 21.17' .75' .71' 10.18' 10.50 10278.00' 10277.31' 10277.31' 10256.14' 10256.14' 10255.39' 10255.39' 10254.68' 10254.68' 10244.50' 10244.50' 10234.00' Set at 10237' tbg measurement .50' 31.65' 3.22' .72' 29.40' 7.65' 10234.00' 10233.50' 10233.50' 10201.85' 10201.85' 10198.63' 10198.63' 10197.91' 10197.91' 10168.51' 10168.51' 10160.86' 3 1/2" 9.2# N-80 Butt Tubing 208.74' 3 1/2" McMurray-Hughes GLM 7.66' 3 1/2" 9.2# N-80 Butt Tubing 276.09' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 448.44' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 441.49' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 447.03' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 444.07' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 565.81' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 654.76' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 838.45' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 1299.82' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 2054.38' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 2072.84' 3 1/2" Otis Ball Valve 2.26' 3 1/2" 9.2# N-80 Butt Tubing 270.51' 3 1/2" 9.2# N-80 Butt Pup 14.07' 3 1/2" x 4 1/2" X.O. .45' 4 1/2" Butt x 4 1/2" 8RD Hanger .75' Landed Below K.B. 36.75' 10160.86' 9952.12' 9952.12' 9944.47' 9944.47' 9668.38' 9668.38' 9660.73' 9660.73' 9212.29' 9212.29' 9204.64' 9204.64' 8763.15' 8763.15' 8755.50' 8755.50' 8308.47' 8308.47' 8300.82' 8300.82' 7856.75' 7856.75' 7849.10' 7849.10' 7283.29' 7283.29' 8275.64' 7275.64' 6620.88' 6620.88' 6613.23' 6613.23' 5774.78' 5774.78' 5767.13' 5767.13' 4467.31' 4467.31' 4459.66' 4459.66' 2405.28' 2405.28' 2397.63' 2397.63' 324.79' 324.79' 322.53' 322.53' 52.02' 52.02' 37.95' 37.95' 37.50' 37.50' 36.75' 36.75' .00' LEASE Trading B.a¥ Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD · WELL NO. G-3 RD #2 SHEET D PAGE NO. FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 9 61 171 7" CASING DETAIL DESCRIPTION 7" B & W 8 RD Float Shoe 7" 29# P-110 8 RD LT & C 7" B & W 8 RD Float Collar 7" 29# P-110 8 RD LT & C 7" 29# P 110 8 RD LT & C Flag 7" 29# P-110 8 RD LT & C 7" 29# P-110 8 RD LT & C Flag 7" 29# P-il0 8 RD LT & C 7" 29# P-110 x 7" 29# N-80 Butt xo 7" 29# N-80 Butt 7" 29# N-80 Cut-off Landed Below K.B. LENGTH BTM TOP i.38' 1~o45.i3' iio4-'-~.75' 85.08' 11043.75' 10958.67' 1.34' 10958.67' 10957.33' 368.23' 10957.33' 10589.10' 37.72' 10589.10 10551.38' 634.15' 10551.38' 9917.23' 43.09' 9917.23' 9874.14' 2534.63' 9874.14' 7339.51' 44.68' 7339.51' 7294.83' 7221.17' 7294.83' 73.66' 34.51' 73.66' 39.15' 39.15' 39.15' 0 Landed Casing in 12" 3M x 12" 3M Casing Spool w/ 165M#. JTS 7" ISOLATION PACKER DESCRIPTION 3 1/2" Butt Re-entry Guide 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" "x" Nipple (I.D. = 2.75") 3 1/2" Butt Pup X.O. Baker Mill Out Extension 7" Baker "FB-i" Packer LENGTH BTM .67' 29.61' 1.53' 10.28' .70' 5.40' 2.75' 10470.94' 10470.27' 10440.66' 10439.13' 10428.85' 10428.15' 10422.75' TOP 10470.27' 10440.66' 10439.13' 10428.85' 10428.15' 10422.75' 10420.00' Racker Bore = 4" UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE Trading, Bay Unit WELL NO. G-3 RD #2 LO0 SPUD DATE 3/27/83 FIELD McArthur River Field LOCATION: ~Conductor #19~ Leg #4~ t833' N and 1480' W of SE cdr. of Sec. 29~ TgN~ R13W~ SM. SHEET A PAGE NO. 1 COMP. DATE 5/23/83~. CONTRACTOR Conserv'Orl Co RIG NO." '55 TYPE UNIT National 1320 UE '~ DRILL PIPE DESCRIPTION 5" 19.5# t-v~ PERMIT NO. 83-10 SERIAL NO. ADL 18730 TD 11050' TMD TVD 9780' TVD DEVIATION (BH[) 4557' $26° 13'E COMPANY ENGINEER McAllister~ Abernathy~ Bush ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL 111.60' RT TO DRILL DECK RT TO PRO~OJ~DN-~ECK APPROV~O CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 13 3/8" 61# Buttress 9 5/8" 47~43..5~. 40# Buttress 0-55 2209' Cmt'd w/ 2500 sx. Class "G" cmt. P-110 N-80 7670' Top of window. 7" 29# Buttress~ 8RD N-80 P-110 11045' Cmt'd w/ 925 sx. Class "G" cmt. PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5/04/83 10652'-10654' 10957' F.C. B.S. #1 5/05/83 10294'-10296' 10622' RET. B.S. #2 5/09/83 10310'-10311' 10957' F.C. DST #1 5/10/83 10365'-10388' 10957' F.C. Iso S. 5/11/83 10307'-10337' 10957' F.C. Iso S. ~/10/83 10368'-10373' 10870' F.C. Production Sqz'd base of H.B. #4, w/ 100 sx cmt. Sqz'd top of H B. #1, w/ 100 sx cmt. Test formation pressure in Bench #1 Sqzd HB #2 w/ 79 sx cmt Sqzd HB #2 w/ 79 sx cmt H.B. #2 Frac/ Open 9/11/83 10332'-10337' 10870' F.C. Production H.B. #1 Frac/ Open INITIAL PRODUCTION DATE INIEHVAL NET OIL CUT GRAV. C.P. T.P. CHOKE MCF GOR REMARKS 5/11/83 103~5'-10388' 10307'-10337' 2334' 1% WELL HEAD ASSEMBLY TYPE: CIW CASING HEAD: Shaffer Model KD 12" Series 900 w/ 2-2" L.P. Scr Outl X 13 3/8" SOW CASING SPOOL: 12" 3000 psi X 12" 3000 psi - 7" hunq w/ 165~000# TUBING HEAD: CIW 12" 3000 psi X 10" 5000 psi DCB TUBING HANGER: Cameron 10" Nominal x 4 1/2" Buttress Bottom & 4 1/2" Eue 8rd top TUBING HEAD TOP: 10" 5000 psi X 4" 5000 psi adaptor w/ 4 1/8" Bore MASTER VALVES: 2 CIN 4" 5000 psi valves w/ Block between for WKM CHRISTMAS TREE TOP CONN: 4 1/2" Eue 8rd 4" 5000 psi .Wing Valves UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS OTS 9 15 15 15 15 19 22 28 43 69 68 CIW 3 1/2" TUBING DETAIL DESCRIPTION LENGTH BOTTOM TOP 3 1/2" Baker Wireline Guide 3 1/2" 9.2# N-80 Butt Pup 3 1/2" Otis "X" Nipple 3 1/2" Butt Coupling 3 1/2" 9.2# N-80 Butt Rup Baker Seal Assembly (4" OD) Baker 7" Model F-1 Rkr Baker Locator 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" Otis "XA" Sleeve 3 1/2" Butt Coupling 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" MoMurray-Hughes GLM .69' 21.17' .75' .71' 10.18' 10.50 10278.00' 10277.31' 10277.31' 10256.14' 10256.14' 10255.39' 10255.39' 10254.68' 10254.68' 10244.50' 10244.50' 10234.00' Set at 10237' tbg measurement .50' 31.65' 3.22' .72' 29.40' 7.65' 10234.00' 10233.50' 10233.50' 10201.85' 10201.85' 10198.63' 10198.63' 10197.91' 10197.91' 10168.51' 10168.51' 10160.86' 3 1/2" 9.2# N-80 Butt Tubing 208.74' 3 1/2" McMurray-Hughes GLM 7.66' 3 1/2" 9.2# N-80 Butt Tubing 276.09' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 448.44' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 441.49' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 447.03' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 444.07' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 565.81' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 654.76' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 838.45' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 1299.82' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 2054.38' 3 1/2" McMurray-Hughes GLM 7.65' 3 1/2" 9.2# N-80 Butt Tubing 2072.84' 3 1/2" Otis Ball Valve 2.26' 3 1/2" 9.2# N-80 Butt Tubing 270.51' 3 1/2" 9.2# N-80 Butt Pup 14.07' 3 1/2" X 4 1/2" X.O. .45' 4 1/2" Butt x 4 1/2" 8RD Hanger .75' Landed Below K.B. 36.75' 10160.86' 9952.12' 9952.12' 9944.47' 9944.47' 9668.38' 9668.38' 9660.73' 9660.73' 9212.29' 9212.29' 9204.64' 9204.64' 8763.15' 8763.15' 8755.50' 8755.50' 8308.47' 8308.47' 8300.82' 8300.82' 7856.75' 7856.75' 7849.10' 7849.10' 7283.29' 7283.29' 8275.64' 7275.64' 6620.88' 6620.88' 6613.23' 6613.23' 5774.78' 5774.78' 5767.13' 5767.13' 4467.31' 4467.31' 4459.66' 4459.66' 2405.28' 2405.28' 2397.63' 2397.63' 324.79' 324.79' 322.53' 322.53' 52.02' 52.02' 37.95' 37.95' 37.50' 37.50' 36.75' 36.75' .00' LEASE Trading Bay Unit UNION OIL COMPANY OF CALIFORNIA WELL RECORD WELL NO. G-3 RD #2 SHEET D PAGE NO. FIELD McArthur River Field-- DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS , , 2 9 15 61 171 7" CASING DETAIL DESCRIPTION 7" B & W 8 RD Float Shoe 7" 29# P-110 8 RD LT & C 7" B & W 8 RD Float Collar 7" 29# R-110 8 RD LT & C 7" 29# R llO 8 RD LT & C Flag 7" 29# R-110 8 RD LT & C 7" 29# R-110 8 RD LT & C Flag 7" 29# R-110 8 RD LT & C 7" 29# R-110 x 7" 29# N-80 Butt xo 7" 29# N-80 Butt 7" 29# N-80 Cut-off Landed Below K.B. LENGTH BTM TOP 1.38' 110~5.13' 11043.75' 85.08' 11043.75' --10958.67' 1.34' 10958.67' -'10957.33' 368.23' 10957.33' 10589.10' 37.72' 10589.10 ..... 10551.38' 634.15' 10551.38' 9917.23' 43.09' 9917.23' 9874.14' 2534.63' 9874.14' 7339.51' 44.68' 7339.51' 7294.83' 7221.17' 7294.83' 73.66' 34.51' 73.66' 39.15' 39.15' 39.15' 0 JTS Landed Casing in 12" 3M x 12" 3M Casing Spool w/ 165M#. 7" ISOLATION PACKER DESCRIPTION 3 1/2" Butt Re-entry Guide 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" "x" Nipple (I.D. = 2.75") 3 1/2" Butt Pup X.O. Baker Mill Out Extension 7" Baker "FB-i" Packer LENGTH BTM _ _ .67' 29.61 ' 1.53' 10.28' .70' 5.40' 2.75' 10470.94' 10470.27' 10440.66' 10439.13' 10428.85' 10428.15' 10422.75' TOP 10470.27' 10440.66' 10439.13' 10428.85' 10428.15' 10422.75' 10420.00' Packer Bore = 4" UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS GRAYLING PLATFORM G-3 RD #2 WO (UOCO) AFE #331413 U.O. 40.95% 10957' ETD FC 1 D 3/04/84 9 5/8" C. 7570' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 32,888 ACC COST: $ 32,888 AFE AMOUNT: $805,000 COMMENCED OPERATIONS ON G-3 RD #2 ~ 00:01HRS, 3/04/84. KILLED WELL W/ A 30 BBL SAFE SEAL PILL. FILLED ANNULUS. SET BPV. ND X-MAS TREE. NU BOPE. TEST BOPE. CIRC WELL CLEAN THRU "XA" SLEEVE ~ 10233' MD. 10957' ETD FC 2 D 3/05/84 9 5/8" C. 7670' 7" C. 1i045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 29,632 ACC COST: $ 62,520 AFE AMOUNT: $805,000 CIRC WELL CLEAN. PULL 3 1/2" TBG AND STAND BACK IN DERRICK. PU FISHING ASSY ON 3 1/2" DP AND RIH TO PERM PKR ~ 10,262 DPM. CIRC OILY SYSTEM OUT OF WELL AND MIX 6% KCL IN FIW. 10957' ETD FC 3 D 3/06/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 451 PSI/ 1000' DAILY COST: $ 24,153 ACC COST: $ 86,673 AFE AMOUNT: $805,000 BURN OVER BAKER F-1 PERM PKR 8 10,262 DPM (10,270 DIL). POOH W/ DP. PACKER FELL OFF FISHING ASSY ON TRIP OUT OF HOLE. RIH W/ SPEAR & ENGAGE FISH ® 10,427' DPM. POOH W/ FULL RECOVERY OF PKR. RIH W/ BURN OVER SHOE & SPEAR. BURN OVER BAKER FB-1 PERM PKR 8 10,431' DPM (10,420' DIL). POOH W/ FISHING ASSY ON DP. 10870' CMT RET ON TOP OF JUNK 4 D 3/07/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 48,754 ACC COST: $135,427 POOH W/ FISHING ASSY. RECOVER FB-1PKR. LEFT MILLOUT EXT IN HOLE. RIH W/ FISHING SPEAR (4 1/2" CATCH) AND TAG FISH ® 10890' DPM. ENGAGED FISH AND POOH. NO RECOVERY. LEAVE FISH IN HOLE. RIH W/ 6" BIT & 7" SCRAPER. PUMP HIGH VIS PILL TO CLEAN HOLE. RIH W/ HOWCO TYPE S-V EZ DRILL CMT RET AND SET 8 10870' DIL ON WL. POOH W/ WL. AFE AMOUNT: $805,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10870' CMT RET ON TOP OF JUNK 5 D 3/08/84 9 5/8" C. 7670' 7" C. 11045' 66 RCF 458 PSI/ 1000' DALLY COST: $ 43,318 ACC COST: $178,745 AFE AMOUNT: $805,000 10870' ETD CMT RET ON TOP OF JUNK 6 D 3/09/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 26,768 ACC COST: $205,513 AFE AMOUNT: $805,000 FIN POOH W/ WL. RIH W/ CMT RET ON WL AND SET 8 10413' DIL. POOH W/ WL. RIH W/ CMT RET ON DP AND SET ® 10364' DPM (10353' DIL). SQUEEZED HEMLOCK BENCH #2 (10365'-10388') W/ 79 SXS CMT (.75% CFR-2, .4% HALAD 22A, 5% KCL, CLASS "G") BEHIND THE PERFORATIONS W/ A FINAL PUMPING RATE OF 3 CFM 8 6000 PSI. SQZ SOB HELD 4800 PSI W/ PUMPS OFF AFTER 3 MIN. CIP ~ 7:30 AM, 3/8/84. POOH W/ DP & STINGER. RIH W/ 6" BIT & 7 CSG SCRAPER. CO CMT F/ 10345'-10364' DPM. CIRC HOLE CLEAN. POOH W/ DP. RIH W/ RTTS & SET TOOL 8 10165' (3 1/2" TBG TAIL 8 10199'). PREP TO SQZ HEMLOCK BENCH #1 (10307'-10337'). SQZ HEMLOCK BENCH #1 (10307-10337' DIL). BROKE DOWN FORMATION W/ 3250 PSI PUMPING 10 CFM. DISPLACED 61SXS (CLASS "G", .75% CFR-2, .4% HALAD 22-A, 5% KCL) BEHIND PERFS W/ FINAL PUMPING RATE OF 4 CFM ¢ 5200 PSI. SQZ JOB HELD 4100 PSI W/ PUMPS OFF AFTER 2 HRS. CIP @ 2:00 AM, 3/9/84. POOH W/ RTTS. RIH W/ 6" BIT & WOC FOR 18 HRS. CO CMT F/ 10207-10364' DPM. TEST SQZ JOB TO 2500 PSI, OK. 10870' ETD CMT RET ON TOP OF JUNK 7 D 3/10/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 98,766 ACC COST: $304,279 AFE AMOUNT: $805,000 DRL UP CMT RET 8 10364'. CO CMT TO 10424' DPM. TEST SQZ JOB BENCH #2 to 2500 PSI, OK. CIRC HOLE CLEAN. POOH W/ DP. RIH W/ WL AND PEEF F/ 10368-10373' DIL W/ 5" CSG GUN, 4 HPF, 120° PHASING .58" HOLES. TRIP WL & RIH W/ OTIS WDF PERM PKR W/ BALL VALVE BELOW PRK. SET PKR 8 10350' DIL. POOH. RIH W/ OTIS SEAL ASSY ON DP. TAG PKR 8 10357' DPM. STAB IN & TEST TO 2500 PSI,'OK. RIG UP DOWELL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 NO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 10870' ETD CMT RET ON TOP OF JUNK 8 D 3/11/84 9 5/8" C. 7670' 7" C. 11045' 66 PCF 458 PSI/ 1000' DAILY COST: $ 57,093 ACC COST: $361,372 AFE AMOUNT: $805,000 TST DOWELL PUMPS & LINES TO 6000 PSI, OK. START FRAC PROGRAM. UNSTAB F/ PKR AND START PUMPING FLUID. PUMPED 59 8BLS YF4PSD & 12 8BLS OF WF5 AND STAB INTO PKR. START PUMPING DIVERTIFRAC WFS. PRESS BUILT TO 5000 PSI W/O BREAKDOWN. SHUT OOWN (11 MIN). OPEN BLEEDER VALVE ANO RELEASE PRESS. START PUMPING. PRESS BUILT TO 7100 PSI WHEN FORMATION STARTED TO FRACTURE. PRESS FELL TO 4600 PSI PUMPING 5 BBL/MIN. PUMP DIVERTIFRAC STAGES AND WF5 SPACER. PUMP YF4PSD PAD. PRESS BUILT TO 7800 PSI WHILE DISPLACING DIVERTIFRAC INTO FORMATION. SHUT DOWN FRAC JOB DUE TO HIGH-PRESS. PRESS BLED TO ZERO AFTER 20 MIN. RIH W/ 2 1/8" GUNS. GUNS SET DOWN IN WDF PKR ® 10350'. POOH W/ WL. ATTEMPT TO FRAC BENCH #2 AGAIN. PUMPED AGAINST FORMATION TO 7500 PSI. SHUTDOWN. GOT SLOW BLEED OFF TO 4100 PSI. PRESSURE UP TO 6100 PSI AND GOT BREAKDOWN W/ FIW & 6% KCL (8 88L/MIN ~ 6300 PSI). START PUMPING THE FOLLOWING STAGES: Volume Rate Fluid Press (Gal) BRM Type PSI 3500 -5.5 Spacer WF5 6100 1000 7.5 YF4PSD Pad 61oo 4000 8.0 YF4PSD Pad 6100 1000 8.0 YF4RSD 6100 1000 8.0 YF4RSD 6100 1000 8.0 YF4RSD 6100 2000 8.0 YF4RSD 6000 2000 8.0 YF4PSD 5400 2500 8.0 YF4RSD 5400 ~op Cone Prop AMT 1.0# 100 Mesh Sand 1.0# 20-40 Mesh Bauxite 2.0# 20-40 Mesh Bauxite 3.0# 20-40 Mesh Bauxlte 4,0# 20-40 Mesh Bauxite 4,0# 12-20 Mesh Bauxite 1000 1000 2000 6000 8O00 10000 DISPLACE FRAC FLUIDS W/ 6% KCL & FIW. FINAL PUMPING PRESS 5900 PSI ® 9 BPM. PRESS BLED TO 2000 PSI AFTER 25 MIN. UNSTAB & REVERSE OUT EXCESS FRAC FLUIDS (40-50 CF) CIRC HOLE CLEAN. POOH W/ DP. RU & RIH W/ 5" CSG GUN. PERF F/ 10332-10337 DIL W/ 4 HPF, 120° PHASING. NOW: MAKE UP RTTS & RIH. 10870' ETD CMT RET ON TOP OF JUNK 9 D 3/12/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $116,931 ACC COST: $478,303 AFE AMOUNT: $805,000 RIH W/ RTTS PKR ASSEMBLY. TAGGED OTIS PKR 8 10360' DPM. PULLED UP 55' AND SET RTTS 8 10271' DPM, TAIL 8 10305' DPM. RU DOWELL. TSTD PUMPS & LINES TO 8000 PSI - OK. TSTD ANNULUS TO 2500 PSI - OK. BROKE DOWN BENCH #1PERFS F/ 10332' TO 10337' DIL W/ 5 BPM ~ 4000 PSI. FRAC STIMULATED HEMLOCK BENCH #1 & DISPLACED FRAC FLUIDS W/ 6% KCL IN FIW. HAD FINAL RATE OF 10 BPM 8 5000 PSI. HELD PRESSURE FOR 1.5 HRS. OPENED TOOL - HAD NO FLOW. PULLED STANDS - DP WAS PLUGGED. CIRC DP CLEAN POOH. RIH W/ BURN-OVER SHOE AND TAGGED FILL 10285'. CO DOWN TO OTIS PKR 8 10362' DPM AND BEGAN MILLING OVER OTIS PERM PKR. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE Trading Bay Unit WELL NO. G-3 RD #2 WO FIELD McArthur River Field DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS lO87O' DIL ETD CMT RET ON TOP OF JUNK MILL OVER OTIS WDF PERM PKR. POOH W/ FISHING 10 D 3/13/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $ 24,633 ACC COST: $502,936 AFE AMOUNT: $805,000 ASSY. RECOVERED PKR BODY AND BALL VALVE SUB. RIH W/ 6" JUNK MILL & 2 JUNK BASKETS. TAG FILL ® 10382' DRM, (42' OF FILL). CO TO EZ-DRILL CMT RET 8 10424' DPM. MILL CMT RET AND RUSH TO BOTTOM, 10880' DRM (10870' DIL). CIRC WELL CLEAN W/ HIGH VIS RILL. POOH W/ DR & MILL. RIH W/ 6" BIT & 7" CSG SCRAPER TO 10880' DRM. CIRC BTMS UR. POOH W/ DR. 10870' DIL ETD CMT RET ON TOP OF JUNK RIH W/ GR & CCL TOOLS ON DRESSER ATLAS WL. 11D 3/14/84 9 5/8" C. 7670' 7" C. 11045' 65 PCF 28 SEC DAILY COST: $ 53,577 ACC COST: $556,513 AFE AMOUNT: $805,000 LOG F/ 10860-9800'. POOH W/ WL. RIH W/ 5 7/8" GAUGE RING & JUNK BASKET TO 10400'. POOH. RIH W/ FB-1 BAKER PERM PKR AND SET ~ 10344' DIL. POOH. RU TEST SEAL ASSY & RIH. TAG PKR ® 10355' DRM & TESTED RKR TO 400 PSI, OK. POOH W/ DR. RIH W/ F-1 BAKER PERM RKR AND SET ~ 10222' DIL. POOH W/ WL. RIH W/ TEST SEAL ASSY & TAG RKR ® 10233' DRM & TESTED RKR TO 450 PSI -OK. POOH & LD DR. 10870' DIL ETD CMT RET ON TOP OF JUNK LD DP. RU & RUN 3 1/2"'TBG. STAB INTO F-1 12 D 3/15/84 9 5/8" C. 7670' 7" C. 11045' DAILY COST: $ 33,662 ACC COST: $590,175 PKR ~ 10237' TBG MEAS. TSTD PKR TO 400 PSI, OK. SPACE OUT & LAND TBG. ND BORE, NU X-MAS TREE & TEST TO 5000 PSI. RU PRODUCTION LINES. LOAD 3 1/2" DP ONTO BOAT. AFE AMOUNT: $805,000 10870' DIL ETD CMT RET ON TOP OF JUNK DISMANTLED MUD PUMPS AND CLEANED PITS. RIGGED 13 D 3/16/84' DOWN CENTRIFUGAL PUMPS AND LOADED DRILLING 9 5/8" C. 7670' EQUIPMENT INTO BASKETS FOR SHIPMENT. OFFLOADED 7" C. 11045' RIG EQUIPMENT FROM PLATFORM. DAILY COST: $ 27,680 ACC COST: $617,855 AFE AMOUNT: $805,000 10870' ETD CMT RET ON TOP OF JUNK 14 D 3/17/84 9 5/8" C. 7670' 7" C. 11045' OFFLOADED ALL DRILLING EQUIPMENT ONTO BOAT. MOVED EQUIPMENT TO MONOPOD. RELEASED RIG 8 08:00 HRS, 3/17/84. DAILY COST: $ 14,135 ACC COST: $631,900 AFE AMOUNT: $805,000 W? ,j]~a 10 sooo : I ' l~_ ~ooo~ .." T.B.U.S. G- 3RD WORKOVER, McARTHUR RIVER FIELD ~' CASING & ABANDONMENT DETAIL i ~ ~ ~ / RT-DCB at O' SINGLE 4.5" TUBING HANGER at 36.75' I ! 20~ DRIVE PIPE at 375' = I i __ , 133/8", 61-~, J-55 BUTTRESS CASING at 2,209' : 3 GLM , . 95/8', N-80, 47-~, BUTTRESS TO RETAINER at 7751' 4 GLM WINDOW FROM 76'70' TO 7725' W/KOP at 7675' E.T.D. CEMENT RETAINER at 10,870' ! 5 ~ 7" P-110, 29~ CASING at 11,045' I I'11---I 6 ~GLM' -- i TUBING DETAIL 7 'GEM 3.5", 9.2~, N-80 BUTRESS THREAD TUBING I 8 GL..__~.M , 1. 4.5' x 3.5" CROSS-OVER at 37.50' 'i 2. OTIS BALL VALVE NIPPLE at 322.53' 9~LM i ii 3.-14. McMURRY HUGHES G.L.M at 3)2397.63', 4)4459.66', j IOGLM jl 5)5767.13', 6)6613.23' 7)7275.64', 8)7849.10', 9)8300.92', I~ GLMI 10)8755.50', 11)9204.64', 12')9660.73', 13)9944.47', ~V ~ 14) 10,160.86' 12 GLM 15. OTIS 'XA" SLEEVE (Min. I.D.:2.75") at 10,198.63' I I$1GLM 116. BAKER LOCATOR at 10,233.50' 17. BAKER F1 PERM. PACKER W/SEAL A$SY. at 10,237.00' 14 GLM 1'8. OTIS 'X" NIPPLE at 10,255.39' : 19. MULE SHOE at-10,278.00' - 20. BAKER FB-1 PERM. PACKER at 10,344' I ~5 XA 21. OTIS "X" NIPPLE at 10,353' 22. BAKER WIRELINE RE-ENTRY GUIDE at 10,362' ~7 PERFORATION RECORD ~-. i! DATE INTERVAL CONDITION ~! 10,332' - 10,337' PRODUCTION HEMLOCK BENCH-~.I 19 ~ 1 O, 3 6 8' - '10,~37 $' PRODUCTION, HEMLOCK BENCH -~2 . i .' I . I! · RE¥. T B U S G'3RD WOI:IKOVER · · · · SC^L~ NONE DATE3/15/a4 UNION OIL COMPANY OF CALIFORNIA ANCHORAGE, ALASKA SHEETs J SHEET UNION OIL cOMPANY OF CALIFORNIA WELL RECORD LEASE Trading Bay Unit WELL NO. G-3 RD #2 FIELD McArthur River Field LOCATION: Conductor #19~ Leg #4~ 1833' N and 1480' W of SE CDr. of Sec. 29~ TgN~ R13W~ SM. PERMIT NO. 83-10 SERIAL NO. ADL 18730 TD ll050' TMD TVD 9780' TVD DEVIATION (BHL) 4557' S26° 13'E COMPANY ENGINEER McAllister~ Abernath¥~ Bush SHEET A PAGE NO. 1 SPUD DATE 3/27/83 COMP. DATE 6/23/83 CONTRACTOR Conserv Drl Co RIG NO. TYRE UNIT National 1320 UE DRILL RIPE DESCRIPTION 5" ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL lll.60' RT TO DRILL DECK RT TO PRODUCTION DECK APPROVED CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 13 3/8" 61# Buttress 3-55 2209' 9 5/8" 47~$3.5~ 40# ButtrEss P-110 N-80 7670' 7" 29# Buttress~ 8RD N-80 R-110 11045' Cmt'd w/ 2500 sx. Class "G" cmt. Top of window. Cmt'd w/ 925 sx. Class "G" cmt. PERFORATING RECORD DATE INTERVAL E.T.D. REASON PRESENT CONDITION 5/04/83 10652'-10654' 10957' F.C. B.S. #1 5/05/83 10294'-1029~' 10622' RET. B.S. #2 5/09/83 10310'-10311' 10957' F.C. DST #1 5/10/83 10365'-10388' '10957' F.C. Production 5/11/83 10307'-10337' 10957' F.C. Production Sqz'd base of H.B. #4~ w/ 100 sx cmt. Sqz'd top of H.B. #ir w/ 100 sx cmt. Test formation pressure in Bench #1 Open for flow - H.B'~ #2 Open for flow - H.B. #1 INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.R. T.R. CHOKE MCF GOR REMARKS 5/11/83 10365'-10388' 10307'-10337' 2334' 1% WELL HEAD ASSEMBLY TYPE: CIW CASING HEAD: Shaffer Mod. K.D. 12" Series 900 w/ 2-2" L.P. Scr Outl.-bottom Sow 13 3/8"csg. CASING HANGER: Shaffer 12" Nominal 9 5/8" Mod. K.D. -- K.S. CASING SPOOL: TUBING HEAD: 12" 3M x 12" 3M - 7" Hung w/ 165 M# CIW 12" 3M x 10" 5M DC-B TUBING HANGER: Cameron 10" Nominal x 4 1/2" Buttress bottom & 4 1/2" Eue 8rd top TUBING HEAD TOP: 10" 5000# x 4" 5000# adaptor w/ 4 1/8" bore MASTER VALVES: 2 CIW 4" 5000# values w/ block between for WKM 4" 5M Winq Valve CHRISTMAS TREE TOP CONN: 4 1/2" Eue 8rd UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS 6-3 RD #2 FIELD MoArthur River Field__ DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 1 3/27/83 11259' TD 11222' ETD 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW DAILY COST: $ 16,403 ACC COST: $ 16,403 AFE AMT: $2,300,000 2 3/28/83 DAILY COST: ACC COST: AFE AMT: 3 3/29/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 6995' ETD (TOF) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 24,974 $ 41,377 $2,300,000 11259' TD 7020' Est. (TOF) 13 3/8" C. 2209' 9 5/8" C. 9132' 7', L. 8975-11259' FIW $ 34,265 $ 75,642 $2,300,000 Commenced operations ~ 00:01 hrs 3/27/83. Pulled Otis concentric GLVs f/ mandrels ~ 2278', 4648' & 6270' prior to rigging up rig. In- stalled BpV, removed tree, installed & tested BOPE. Attempted to pull tbg. Pkr ~ 10473' would not release w/ 228,000# pull ~ surface. Rigged up Oia-log. RI'H w/ Dia-log 3 3/4" OD jet cutter. Cutter stopped ~ 7028'. Jet cut tbg ~ 6997' w/ 175,000# pull on top of tbg. Tbg would not pull. Ran dia- log freepoint tool. Tbg 10~% free to 7025' where freepoint stopped. Ran 2nd 3 3/4" cutter. Stuck jet cutter ® +6995'. Could not work cutter fr~e. Pulled 250,000# on tbg & fired cutter. Tbg came free. POOH w/ WL. Pulled & layed down 4 1/2" tbg. Had hole thru both sides of tbg ~ 1383' (note: when perfed G-2 last year ~ 1380', established communications with Finished POOH w/ 4 1/2" tbg. RIH w/ fishing tools (8 1/2" OS w/ 4 1/2" grapple) on 5" DR to top of fish @ 6973'. Ciro & milled over top of fish (cut-off retrieved f/ hole was badly flared). Latched onto fish ~ 6973' but grapple would not hold w/ 256M# pull (8OM# on fish). ROOH & added 6' of extension behind OS. RIH & latched onto fish. Rulled up to 40OM# & jarred on fish w/ 320M#. Fish was free to move down but not up. RIH w/ i 5/8" sinker bars and chisel point on WL - tagged obstruction ® 7172' WLM. Spudded down to 7225' WLM. POOH w/ WL. Worked pipe up (gained +._4') w/ 40OM#. Installed kelly & picked up to 205M#. Performed blind back off - had no increase in pick up weight. POOH to check. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 3 LEASE WELL NO...TB~US G-3 RD l~2 _ _ FIELD. ,= _Mc. Ar~_.hu_r R_i?_e=r_. F~i. eld ._ DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4 3/30/83 DAILY COST: ACC COST: AFE AMT: 11259' TD ~ 11218' ETD '(FC) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 31,801 $ 107,443 $2,300,000 POOH & LD 1 jt and 1 cut-off (46.98') of 4 1/2" tbg fish. RIH w/ fishing tools & latched onto fish 8 7043' (23' low). Attempted blind back-off but entire fish was turning. Pulled & worked fish up the hole. Stopped frequently to circ as pkr was swabbing hole. Circ btms up when pkr reached 9 5/8" csg. POOH & laid down remainder of 4 1/2" & 3 1/2" tbg & hyd pkr (tbg was plugged w/ sand and scale). 5 3/31/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 8945'-DPM ETD (Cmt Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 61,369 $ 168,812 $2,300,000 RIH w/ 8 1/2" bit on 9 5/8" csg scraper to top of liner ~ 8979'. Circ& POOH. RU Dialog & set Baker cmt ret ® 8969' WLM. RD Dialog. RIH w/ stinger on 5" DP & stabbed into ret ~ 8945' DPM. Tested surf lines 7000 psi (down 1 hr waiting for Howco to replace 3 defective bleeder valves). Attempted to break down Hemlock perfs f/ 10535' to 11195' DIL w/ 6600 psi. Formation took 1 BPM ~ 6600 psi when began to get returns to' surf & immediate pressure drop. POOH looking for washout in DP - could find none. RIH w/ 9 5/8" RTT5 pkr & tested ~ 1200' - ok. RIH & set ~ 8792'. 411183 DAILY COST: ACC COST: AFE AMT: 11259' TD 11211' ETD (FC) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 21,392 $ 190,204 $2,300,000 Tested surf lines to 7000 psi. Pressured below RTTS to 7000 psi & slowly bled to 6550 psi - probably due to small surf leaks. Could not break down. POOH w/ RTTS. RIH w/ 8 1/2" bit & clean out assy - drld on ret ~ 8944'. Chased ret downhole to 8977'. Orld on ret f/ 8977' to top of liner ~ 8979'. Circ hi-vis pill & POOH. RIH w/ 6" junk mill on 1 4-3/4" OC & milled & pushed ret junk f/ 8979' to 9014'. POOH. RIH w/ 6" bit on 3 1/2" DP w/ 4 4-3/4" DCs. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO% .......... 4 ...... --= LEASE ........ ~AD..L=!~8.7.30. ==== .=~-~:-:-~=--.;. WELL NO._:_ TBUS G._-_3 RD #2 FIELD=__: ........... McArthur_ ........ River= Field ETD · ' DE-T-AILS OF OPERATIONS, DEsCRI'P]~i~NS &-~ESuLTS 7 4/2/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 10400' Est ETD (Cmt)'. 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW 31,698 221,902 $2,300,000 RIH w/ 6" CO assembly to 10508'. · Cleaned out firm fill (sand or CaC03) f/ 10508' to 10649' - plugged bit. Rulled 5 stds & unplugged bit. RIH & cleaned out fill f/ 10649' to ll210'. Circ hi-viS pill & ROOH. RIH w/ OEDR to 11199'. Tested surf lines to 2500 psi. Mixed & spotted 270 sxs ol "G" w/ .75% CFR-2 & .5% Halad 22A across Hemlock perfs for abandonment. CIP ~ 15:00 hrs 4/2/83. Theoretical top ~ 10400' (135'~ above top of perfs). Pulled up to 8970' &circ hole clean. ROOH & laid down 3 1/2" DP. RU Dialog & ran GR to 8200'. Ran csg inspection log f/ 8200' to surface. 8 4/3/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 7753' ETD (Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 54,954 $ 276,856 $2,300,000 Completed running Dialog csg inspec- tion log f/ 8200' to surf. Log showed hole $ 1383', hole $ 6993' (approximate location of tbg jet cut) & several spots of excessive csg wear (70-80% removed). RD Dialog & RU Dresser Atlas. RIH w/ 2' perf gun & perfed for csg stabilization squeeze f/ 7790' to 7792' WLM w/ 4 1/2" HPF. RIH & set Baker cmt ret ~ 7780' WLM. RD Dresser Atlas. RIH w/ stinger on 5" DP & stabbed into ret ~ 7753' DPM (27' high to WLM). Test surf equip to 5000 psi. Broke down perfs ~ 3300 psi. Pumped in w/ 4.3 BPM ~ 3750 psi. Formation held 2800 psi after 3 min. Mixed & sqz'd w/ 250 sxs ol "G" w/ .75% CFR-2 & .1% HR-61. Pumped 100 sxs below tool then hesitation sqz'd remainder. Pumped a total of 230 sxs below ret w/ a final rate of .5 BRM 8 3600 psi. Sqz held 2820 psi after 5 min. CIR ® 17:57 hrs. ROOH w/ DR. RIH w/ RTTS & set 8 6808'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE' ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS · 9 4/4/83 DAILY COST: ACC COST: AFE AMT: I0 4/5/83 11259'~ TD 1371' ETD .(Cmt) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 59,485 $ 338,341 $2,300,000 11259' TO 7751' ETD (Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW DAILY COST: $ 35,960 ACC COST: $ 372,301 AFE AMT: $2,300,000 11 4/6/83 11,259' TD 775i'ETO (ret) 13 3/8" C. 2209 9 5/8' C. 9132' 7"L. 8975' - 11259' FIW Daily Cost: ACC:COST AFE AMT: $ 28,908 $ 401,209 $2,300,000 Pressured below RTTS @ 6808' to test hole (from csg insp log) ~ 6993' tO 3700psi - could not break down. Reset RTTS ~ 1452' & injected into hole ~ 1383' w/ 5.3 BPM ~ 1700 psi. ~Form held 350 psi w/ pumps off 3 min. Tested csg below RTTS to 3000 psi - ok. POOH. RIH & set Baker 9 5/8" cmt ret ~ 1450' DPM. POOH. RIH w/ RTTS & set ~ 1230'. Pumped into hole w/ 3.6 BPM @ 1850 psi. Mixed &-sqz'd w/ 200 sxs cl "G" w/ .75% CFR-2 & 2~ CaCL2. Had final rate of 2.1 BRM ~ 1450 psi. Sqz held 600 psi w/ pumps off l0 min. CIR ~ 07:35 hrs. Held press on sqz for 2 hrs. POOH w/ RTTS. WOC 16 hrs. RIH w/ 8 1/2" CO assy & tagged cmt ~ 1325'. CO firm cmt f/ 1325' to 1371'. Continued to clean out cmt f/ 1371' to 1450'. Drld ret ~ 1450' & RIH to 7711'. Drld junk & cmt f/ 7711' to 7751'. Pumped hi-vis sweep & POOH. RU Dresser Atlas & ran CBL-VDL-GR icg f/ 7750' (30' above ret) to surface. RD Dresser Atlas. Closed blind rams & tested sqz hole to 210 psi (85 RCF equiv) - bled to 160 psi (79 RCF equiv). RIH w/ ret on DR & set ~ 1460'. POOH after setting ret.@ 1460'. DPM . RIH and set RTTS 8 1200'. Broke down hole ® 1383' w/ 1500 psi Pumped in w/ 6.4 BR~iO00 psi Mixed and squeezed w/ 250 sx cl"G" w/ .75% CFR-2 using hesitation method CIR e 04:15 Hrs. Held pressure on squeeze 2 hours. POOH w/ RTTS. RIH w/ 81/2" bit #4 and tagged top of cement ® 1335" Drilled soft cement F/ 1335' to 1342'. W.O.C. 2 Hours. Drilled firm cement F/1342'to to 1360' and hard cement F/1360 to 1371'. RIH and tagged ret.~ 1460' and drilled out ret. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET PAGE NO LEASE ADL _1_87}0 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 12 4/7/83 Daily Cost: ACC:COST AFE AMT: 13 4/8/83 14 DAILY COST: ACC COST: AFE AMT: 419183 DAILY COST: ACC COST: AFE AMT: 15 4110/83 DAILY COST ACC COST: AFE AMT: 11,259' TD 7751'ETD (ret). Window F/7670'-7673' 13 3/8"C. 2209 9 5/8' C. 9132'. 64 RCF 205 Sec 20,134 $ 421,343 ~RIH while picking up. d.p tagged ret ~ 7814 (63'Low) Changed hole over to gel-water, Strapped out of hole- found pipe error. Ret actually ~ 7751'. nIH w/section mill #1 and milled window in 9 5/8" osg. F/ 7670' to 7673'. $2,300,000 11259' TD 7751' ETD (ret.) Window F/7670' - 7695' (25'total). 13 3/8" C.2209' 9 5/8"C. 7670' 64 pcf 205 sec $ 25,768 $ 447,111 $2,300,000 11259' TD 7751' ETD (Ret) Window F/ 7670' - 7707' (37' total) 13 3/8" C. 2209' 9 5/8" C. 7670' 64 pcf 195 sec Continued to mill window F/7673' to 7674'.Circ. and trip for mill #2 nIH and milled window F/ 7674' to 7695'. Continued to mill window F/ 7695'to 7698' Circ. and trip for mill #3. ~IH and milled window F/7698' to 7707'. $ 37,104 $ 484,215 $2,300,000 11259' TD Trip for section mill #4. nIH. 7546 ETD (est TOC) and milled window F/7707' to Window F/7670' - 7725' 7725' Had total window of (55'total) 13 3/8" C. 2209' 9 5/8" C. 7670' FIW $ 17,415 $ 501,630 55'. Circ. clean and POOH. nIH w/ 6 jts. 3 1/2" tbg. On 5" d.p.to 7751'. Circ and displaced hole w/FIW. Mixed and equalized 100 sx. cl. "G" w/.75% CFR-2, .05% HR-6L mixed to 121 pcf. CIP ~ 23:00 HRS 4/10/83. POOH w/ d.p. $2,300,000 UNION OIL COWPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 7 ~_ ~--~ _ - .. LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE 16 4/11/83 ETD ..... · ~ . ? - · . 11259' TD 7620' ETD (Cmt) Window f/ 7670-7725' 13 3/8" C. 2209' 9 5/8" C. 7670' FIW DAILY COST: ACC COST: AFE AMT: 17 4/12/83 $ 20,312 $ 521,942 $2,300,000 7675' TD (KOP) Window f/ 7670-7725' 13 3/8" C. 2209' 9 5/8" C. 7670' 64 PCF 43 SEC DAILY COST' ACC COST: $ 47,105 $ 569,047 AFE AMT: $2,300,000 18 4/13/83 7794'/119' 13 3/8" C. 2209' 9 5/8" C. 7670' 64 PCF 46 SEC 7999'/205' 13 3/8" C. 2209' 9 5/8" C. 7670' 65 PCF 53 SEC DAILY COST: $ 56,394 ACC COST: $ 625,441 AFE AMT: $2,300,000 19 4/14/83 DAILY COST: ACC COST: AFE AMT: 31,038 656,479 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS _ - _.~_~_~_ $2,300,000 POOH w/ DP. WOC. Removed DCB spool.& installed 12" 3M x 12" 3M csg spool & 12" 3M x 10" 5M drlg spool. Reinstalled BOPE. Changed "back brake & fast coupling on rotary. RIH w/ test plug & set in osg spool. Attempted to test BOPE - test plug would not hold. RIH w/ 8 1/2" blt #5 while waiting for pkr to arrive by boat (helicopters weathered in). Tagged cmt ~ 7524'. Drld soft cmt f/ 7524' to 7540' & firm cmt f/ 7540' to 7620' (depth limitation imposed by OGCC inspector until BOP tested). Circ hole clean. Circ & POOH. RIH w/ RBP & set ~ 55'. Tested blind rams & choke manifold. Retrieved RBP. RIH w/ Baker fullbore pkr & set e 53'. Tested hydril to 2100 psi & remaind- er of BOP to 3000 psi. BOP test WAA by AOGCC Inspector. POOH w/ pkr. RIH w/ 8 1/2" cleanout assy & drld hard cmt f/ 7620' to 7675' (5' below top of window). Circ& built mud system. POOH. RIH w/ bit #6 on BHA #1 for Dyne drill run #1. __ Continued to RIH w/ bit #6 on BHA #1 for Dyne drill run #1. Oriented tool face 90° left of high side & dyne drilled 8 1/2" hole f/ 7675' (KOR) to 7794'. Circ & POOH. Laid down 35 jts of "E" DR. RIH w/ bit #7 on BHA #2 (30' belly) for follow run. Picked up 20 jts of HWDP & rubbered the DR. Reamed dyna drill run f/ 7748' to 7794'. Drld & surveyed f/ 7794' to 7997'. Circ & POOH. Repaired cut- tings chute line. RIH w/ bit #7 on BHA #3 for Dyne drill run #2. Cleaned out 18' of fill. RU Eastman steering tool & oriented Dyna drill lO0° left of HS. Dyne drld 8 1/2" hole f/ 7997' to 7999'. Surveys: 7813' 34030, S40 1/2E 7873' 34030' S43E 7969' 35°15' S41 1/2E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD MoArthur River Field DATE 2O 4/15/83 ETD 8185'/186' 13 3/8" C. 2209' 9'5/8" C. 7670' 67 PCF 51 SEC DAILY COST: : $ 34,266 ACC COST: $ 690,745 AFE AMT: 21 4/16/83 DAILY COST: ACC COST: AFE AMT: 22 4/17/83 DAILY COST: ACC COST: AFE AMT: 23 4/18/83 $2,300,000 8396'/211' 13 3/8" C. 2209' 9 5/8" C. 7670' 68 PCF 57 SEC 28,888 719,633 $2,300,000 8758'/362' 13 3/8" C. 2209' 5/8" C. 7670' 69 PCF 56 SEC $ 25,740 $ 745,373 $2,300,000 8945'/187' 13 3/8" C. 2209' 9 5/8" C. 7670' 69 PCF 56 SEC DAILY COST: $ 30,330 ACC COST: $ 775,703 AFE AMT: $2,300,000 24 4/19/83 DAILY COST: ACC COST: AFE AMT: 9050'/105' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 56 SEC $ 30,477 $ 806,180 $2,300,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Dyna drilled 8 1/2" hole f/ 7999' to 8100'. Circ & POOH. RIH w/ bit #9 on BHA #4 (30' belly follow assy) & reamed dyna drill run #2 f/ 7994' to 8100'. ~Directionally drld 8 1/2" hole f/ 8100' to 8185'. Circ & trip for.BHA change. Surveys: 8118' 33°45' S52E 8150' 34° S54E POOH. RIH w/ bit #10 on BHA #5 (locked up 'assy w/ tandem NB stabs). Directionally drld 8 1/2" hole f/ 8185' to 8396'. giro & dropped survey, Trip for bit change. Surveys: .8238' 33°15' S54E 8356' 32° S52E RIH w/ bit #11 on BHA #5. Direc- tionally drld '8 1/2" hole f/ 8396' to 8563'. Circ & dropped survey. Trip for bit change. RIH w/ bit #12 on BHA #5 & directionally drld 8 1/2" hole f/ 8563' to 8758'. Circ & dropped survey. Trip for bit change. Surveys: 8508' 31°30' S52E 8718' 29°30' SSOE RIH w/ bit #13 on BHA #6 (locked up assy). Directionally drld 8 1/2" hole f/ 8758' to 8945'. Cite & dropped survey. POOH & laid down 18 jts of S-135 DP. RIH & set RTTS w/ SSC ~ 69'. Test BOPE - ok. POOH w/ RTTS. RIH w/ bit #14 on BHA #7 for ~yna drill run #3. RIH w/ bit #14 on BHA #7 for d_d~a drill run #% RU Eastman & Dialog & oriented tool face 70° left of high side. Dyna drilled 8 1/2" hole f/ 8945' to 8989'. POOH. RIH w/ bit #15 on BHA #8 (30' belly follow assy) & reamed dyna drill run f/ 8945' to 8989'. Directionally drld 8 1/2" hole f/ 8989' to 9050'. UNION OIL CONPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELd_ Nc6~thur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS . 25 4/20/83 DAILY COST: ACC COST: AFE AMT: 26 4/21/83 DAILY COST: ACC COST: AFE AMT: 27 4/22/83 DALLY COST: ACC COST: AFE AWT: 28 4/23/83 9134'/84' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 56 SEC 28,068 834,248 $2,300,000 9392'/258' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 49 SEC 51,632 885,880 $2,300,000 9636'/244' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 51 SEC $ 25,403 $ 911,283 $2,300,000 10040'/404' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 47 SEC DAILY COST: $ 26,196 ACC COST: $ 937,479 AFE ANT: $2,300,000 29 4/24/83 DAILY COST: ACC COST: AFE ANT: 10283'/243' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 48 SEC $ 28,549 $ 966,028 $2,300,000 continued to directionally drill 8 1/2" hole f/ 9050' to 9087'. Circ & trip out. RIH w/ bit #16 on BHA #9 for pyna drill run #4. CO 13'~of fill. RU Eastman steering tool on Dialog WL & oriented tool face 75° left of high side. Dyna drilled 8 1/2" hole f/ 9087' to 9134'. Circ & POOH. Surveys: 8793' 29° S50E 8905' 28° S48E 8990' 29° S52E 9051' 29° S53E RIH w/ bit #17 on BHA #10 (30' belly) & reamed dyna drill run f/ 9087' to 9134'. Directionally drld 8 1/2" hole f/ 9134' to 9212'. Trip for BHA change. RIH w/ bit #18 on BHA #11 (locked up assy) & direc- ectionally drld 8 1/2" hole f/ 9212' to 9392'. Surveys: 9177' 30° S58E 9320' 29° S58E Directionally drld 8 1/2" hole f/ 9392' to 9636'. Trip for BHA chng. RIH w/ bit #19 on BHA #12 (30' belly w/ tandem NB stabs). Reamed f/ 9610 to 9636'. Surveys: 9445' 29° S58E 9601' 27°45' S56 1/2E Directionally drld 8 1/2" hole f/ 9636' to 10040'. Surveys: 9744' 28° S56E 9869' 28° S56 1/2E Continued to directionally drill 8 1/2" hole f/ 10040' to 10044' Trip for bit change. RIH w/ bi~ #20 on BHA #12. Reamed f/ 10014' to 10044'. Directionally drld 8 1/2" hole f/ 10044' to 10283'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. lO LEASE. .....AD, L 18730 WELL NO, TBUS G-3 RD #2 FIELD McArthur Rive~..Fi. eld__ DATE 30 4125/83' · , DAILY.COST: ACC COST:' AFE AMT: ETD 10485'/202' 13'3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 52 SEC 34,439 $1,000,467 $2,300,000 31 4/26/83. 10709'/224' 13 3/8" C. 2209' 9 5/8" C. 7670' : -70 PCF 50 SEC DAILY COST: $ 30,407 ACC COST: $1,030,874 AFE AMT: ~ $2,300,000 32 .4/27/83 DAILY COST: ACC COST: AFE AMT: 33 4/28/83 DAILY COST: ACC COST: AFE AMT: 10910'/201' 13 3/8" C. 2209' 5/8" C. 7670' 70 PCF 48 SEC $ 32,726 $1,063,600 $2,300,000 11050'/140' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 58 SEC $ 35,666 $1,099,266 $2,300,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Directionally drld 8 1/2" hole f/ 10283' to 10353'.' Circ & POOH. Tested BORE - ok.~' RIH w/ bit #21 on BHA #13 (locked up assy). Tagged ~fill ~ 10328' (25'). Washed to 10353' & directionally~drld 8 1/2" hole f/ 10353' to 10485'. Surveys: 10014' 30° S55E 10157' 31° S55E 10319' 32° S55E 10481' 31°15' S55E Directionally drld 8 1/2" hole f/ 10485' to 10670'. Circ & dropped survey. POOH (bit came out 3/8" un- dergauge). RIH w/ bit #22 (HTC $D4) on BHA #14 (locked up assy - 2 new NB stabs). Worked on electrical control for Hydril $ Koomey remote panel.- RIH & washed & reamed f/ 10572' to 10670' Had i jet in bit plugged. Directionally drld 8 1/2" hole f/ 10670' to 10709'. Could not unplug jet. Survey: 10640' 30° 30' S55E POOH. RIH w/'bit #23 (FP525) on BHA #14 & direCtionally drld 8 1/2" hole f/ 10709' to lO910'. Circ & dropped survey. POOH - had slight tight spot ~ 9805'. Reamed tight spot to clean up. POOH. Survey: 10860' 30° S55E RIH w/ bit #24 on BHA #14. Direc- tionally drld 8 1/2" hole f/ lO910' to ll050'. Circ & cond hole. Made short-trip to window. RIH & circ. Dropped survey & POOH - had slight tight spot $ 8800'. RU Schlum. RIH w/ DIL-BHC-Sonic - tool would not go below lO000'. POOH & rig down Schlumberger. RIH w/ cleanout assembly. Survey: 11005' 28° 30' S55E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE .~ ~:'- '~-] DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4/29/83 DAILY COST: ACC COST: AFE AMT: ll050~' TD 13 3/8" C 2209' 9 5/8"~C~'~7670' 74 PCF 62 SEC - $ 26'832 $1,126,098 $2,300,000 35 4/30/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 13 3/8" C. 2209' 9 5/8" C. 7670' 75 PCF 66 SEC $ 114,683' $1,240,781 $2,300,000 36 5/1/83 DAILY COST: ACC C~OST: AFE. AMT: 37 5/2/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 9 5/8" C. 7670' 7" ® 11045' 75 PCF'64 SEC $ 368,197 $1,608,978 $2,300'000 11050' TD 10957' ETD (Est. FC) 9 5/8" C. 7670' 7" C. 11045' 75 RCF 64 SEC $ 50,579 $1,659,557 $2,300,000 38 5/3/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 23,570 $1,683,127 $2,300,000 RIH-'w/ BHA #15. Had to ream thru tight spots ~ lO000' & 10565' & Washed 20' of fill to ll050' (had 90% Coal returns). Circ & incr MW to 74 RCF. Made short trip to _9 5/8" window - very smooth. RIH & circ btms up. POOH. RU Schlum & ran DIL-BHC-Sonic-VDL log f/ 11024' to 7675' (down 3 hrs to repair SOS power supply). POOH w/ WL. RIH w/ FDC-CNL-NGT log - set down $ 7800', 8200' & 8550'. Began to get sticky $ 8550'. POOH w/ WL. RIH w/ BHA #15 - smooth trip. Circ btms up & POOH. Ran FDC-CNL-NGT log f/ 11024' to 7675' (tool also set down $ 7791', 7822', 7913' & 7980' but was not sticky). Caliper log showed hole out of gauge up high. POOH w/ WL & rigged down Schlum. RIH w/ BHA #15. RIH w/ BHA #15. Circ & cond hole for csg ~ 11050'. POOH & LD BHA. RU to run 7" csg. Ran 260 jts & 2 pups of 7" 29# N-80 butt & P-110 8rd csg fitted w/ float shoe & float collar. Set shoe ~ 11045', FC ® 10957'. Circ & cond mud while reciprocating csg. Circ & lead w/ 200 F3 caustic wtr & 100 F3 fresh wtr. Mixed & pumpd 925 sxs cl "G" w/ .75% CFR-2 & .5% Halad 22A mixed to 15.8 ppg. Used top & btm plugs. Displ w/ 2329 F3 mud to bump plug w/ 2800 psi. Floats held ok. CIR ~ 02:30 hrs. Lifted BOP stack & riser & landed 7" csg on slips w/ 165M#. Cut off excess 7" csg & installed & tested 12" 3M x 10" 5M DCB spool. Relanded BOP stack & laid down 5" DR. Changed pipe rams to 3 1/2". RIH w/ 6" bit & 7" csg scraper while pick- ing up 3 1/2" DR. Tagged FC 10957'. Circ & displ hole w/ FIW. POOH. RU Go WL & RIH w/ CBL tools- tools malfunctioned. POOH & changed tools. RIH w/ new tools & ran CBL-VDL-GR log. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO.__ _-- · _1;2.:__ __ LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS o-F O~=RATIONS, DESCRIPTIONS & RESULTS '5/4/83 ' 11050' TD ' '10622' ETD (Cmt Ret) :: : 9 5/8" C. 7670' 7" C. 11045' ~ FIW DAILY iCOST: ACC COST: $ 27,750 $1,710,877 AFE AMT: '$2,300,000 .Ran CBL-VDL-GR log f/ 10957' to 7000'. Ran gyro surv f/ 10957' to surf. RD Eastman tools. Tested BOPE & csg to 2500 psi. RIH w/ 2' of 4" csg gun & perfed base of Bench #4 f/ 10652' to 10654' DIL for iso- lation Block Squeeze #1. Set cmt ret on WL $ 10622"DIL. RD Go WL. RIH w/ stinger on 3 1/2" DR & stab'd into ret. Tested lines & equip to 6000 psi. Broke down perfs w/ 8 CFM $ 6000 psi (1.08 psi/ft). Formation held 1300 psi w/ pumps off l0 min. Mixed & pumped 100 sxs~ cl "G" w/ .75% CFR-2 & .5% Halad 22A. Displ 23 sxs behind perfs w/ a final rate of 6 CFM ® 6500 psi. Sqz held 5000 psi w/ pumps off 5 min. CIP $ 23:20 hrs. Picked up & rev out 67 sxs cmt. 40 '5/5/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 10254' ETD (Cmt Ret) 9' 5/8" C. 7670' 7" C. 11045' FIW $ 71,982 $1,782,859 $2,300,000 Rev circ clean. POOH. RU Go WL & perfed top of Bench #1 f/ 10294' to 10296' DIL for isolation BS #2. Set cmt ret on WL $ 10254' DIL. RD Go WL. RIH w/ stinger on 3 1/2" DR. Tested surf equip' to 6000 psi. Broke dwn perfs w/ 4800 psi. Pumped in w/ 8 CFM ~ 4700 psi. Form held 2200 psi w/ pumps off l0 min. Mixed & pumped 100 sxs cl "G" w/ .75% CFR-2 & .5% Halad 22A. Displ 80 sxs behind perfs w/ a final rate of 9 CFM e 5400 psi. Sqz held 4500 psi w/ pumps off 5 min. CIR ~ 13:20 hrs 5/5/83. Picked up 20' & rev out 9 sxs cmt. POOH w/ DR. RIH w/ 6" bit & 2 junk subs to lOlO0'. WOC. 41 5/6/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 10957' (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 45,791 $1,828,650 $2,300,000 Tagged cmt ® 10262'. Drld ret ~ 10271'. CO Junk & cmt to 10334'. RIH.Tagged cmt $ 10625'. Drld ret ® 10639'. No cmt below ret. RIH to ETD®lO957'. Circ'd hole. POOH. LD 4 3/4" DCs. RU GO WL. Made gauge ring trip to 10640'. Made up iso (Baker FB-1) pkr assy on WL. RIH & set pkr $ 10420' DIL. POOH w/ WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 13 LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE 42 517183 '~DAILY COST: ACC COST: AFE AMT: ETD ' 11050' TD 105~7' ETD (FC) ~ 5/8" C.'7670' 7" C. 11045' FIW $! 27,876 $1,856,526 $2,300,000 43 5/8/83 DAILY COST: ACC COST: AFE AMT: 44 5/9/83 DAILY COST: ACC COST: AFE AMT: 45 5/10/83 11050' TD 10957' ETD (FC) 9 5/8"-C. 7670' 7" C. 11045' FIW $ 143,907 $2'000,433 $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 43,739 $2,044,172 $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW DAILY COST: $ 30,468 ACC COST: $2,074,640 AFE AMT: $2,300,000 46 5/11/83 ll050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW DAILY COST: ACC COST: AFE AMT: $ 74,526 $2,149,166 $2,300,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS · Made up seal assy on 3 1/2" DP. RIH. 'Tagged pkr w/ locator sub ¢ 10435' DPM. Tested pkr to 1000 psi. Held 10 mins - ok. Bled off pressure & POOH. RU GO Int. Ran 7" Baker F-1 prod pkr. Set ¢ 10250' DIL. POOH w/ WL. RIH w/ seal assy on 3 1/2" DP. Tagged pkr 8 10265' DPM. TEsted pkr to 1000 psi. Held 10 mins. Bled off press & POOH laying down 3 1/2" DP. Rigged up to run 3 1/2" comp tbg string. Completed running 3 1/2" completion string. Landed & tested to 1000 psi - ok. Removed BORE stack. Installed & tested CIW tree. Removed BRV. RU Myers braid line. RIH. Pulled ball valve & removed gas lift valve f/ GLM ~ 4459'. Flanged up flow line. Gas lifted well to 3200' for 500 psi drawdown. Reinstalled GL¥ in mandrel. ~ 4459'. Perfed Hemlock Bench #1 @ 4 HPF f/ 10310-10311'. POOH. RIH & set HR press recorder e lO310'. Opened well i hr, shut well in 2 hrs. Record stabilized HB #1 press of 3055 psi. POOH w/ HR recorder. GL well for drawdown. Completed perfing Hemlock Bench #2 w/ 2 1/2" perf guns ® 8 HPF f/ 10365-10388' DIL w/ gun run #4. Flowed well between perfs to clean up. Completed perfing Hemlock Bench #1. f/ 10307-10337' DIL. Final prod rate from HB#1 & HB#2 2358/2334 BRD 1% cut. Rigged dwn GO & riser. In- stalled cap in xmas tree & turned well over to prod. Released rig ~ 24:00 hrs 5/11/83. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO.~_~_ 14 LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD~-~,.;.McAr.t, hur: , ~: ~River.._-~ Field ~.---~ ~ ± _- · - _ ... ~ _-- .. - .... ~.£ ~ ~_--~ -_- ~ ~ ~ ~ ..... --~- ~ ~ _- ...... ~ ~ = _. DATE ETD DETAILS OF o~ERA?IONS, DESCRIPTIONS & RESULTS 47 6/22/83 11050' TD ~,' ' 10957' ETD (FC) · 9 5/8" C. 7670' ~' 7" C. 11045' DAILY COST: $ 20,010 ACC COST: $2,169,176 Commenced~operations ® 00:01 hfs 6/22/83. RU Myers WL &'pulled ball valve. Ran'2 5/8" gauge cutter thru MS. Offload Dowetl equip & RU same. Spot GO WL unit. AFE AMT:.. 48 6/23/83 DAILY COST: ACC COST: AFE AMT: $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' $ 52,640 $2,221,816 $2,300,000 RU GO WL & tstd lub. Perfed HB#2 f/ 10388' to 10365' DIL (2 runs) & HB#1 f/ 10337-10307' (2 runs). Flowed well between each gun run. RD GO WL. Flowed well into test trap. Well made 1200/996 BRD, 17% cut aftem 2 hrs. Bled press off ann & filled ann w/ 350 bbls of diesel. RU 'Dowell & tstd line to 5000 psi. Rumped 3000 gal of Naphtha solvent (1BRM ~ 2400 psi), followed by 4000 gal of Naphtha w/ FFA-1, followed by 3000 gal of Naphtha solvent. Displ treatment w/ 93 bbls of diesel w/ a final rate of .46 BPM ~ 3600 psi. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE~=,T_~ad. ingBay__~ni_t .-==..WELL NO. ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS DATE ?'_:_CA.S. ING DETAIL 3TS DESCRIPTION :' LENGTH ~'i-B' ~--W '~"RD Float Shoe ' ' 1,38' 11045,13' 11043.75' 2 7" 29# P-110 8 RD LT & C 85.08' 11043,75' 10958,67' 7" B & W 8 RD Float Collar 1,34' 10958,67' 10957,33' 9 7" 29# P-110 8 RD LT & C 368.23' 10957.33' 10589.10' 7" 29# P-110 8 RD LT & C Flag 37.72' 10589.10 10551.38' 15 7" 29# P-110 8 RD LT & C 634.15' 10551.38' 9917.23' 7" 29# P-110 8 RD LT & C Flag 43.09' 9917~23' 9874.14' 61 7" 29# P-ilO 8 RD'LT &. C 2534.63' 9874.14' 7339.51' 7" 29# P-110. x 7" 29# N-80 Butt xo ~ 44.68' 7339.51' 7294.83' 171 7" 29# N-80 BUtt 7221.17' 7294.83' 73.66' 7" 29# N-80 Cut-off 34.51' 73.66' 39.15' Landed Below K.B.~ ' 39.15' 39.15' 0 Landed Casing in 12"'3M x 12" 3M Casin'g'Spool w/ 165M#. 7" ISOLATION PACKER JTS DESCRIPTION - LENGTH BTM TOP 3 1/2" Butt Re-entry Guide 3 1/2" 9,2# N-80 Butt Tubing 3 1/2" "x" Nipple (I,D, = 2,75") 3 1/2" Butt Pup ×o0o Bake~ Mill Out Extension 7" Baker "FB-i" Packer Packer Bore = 4" .67' 10470.94' 10470.27' 29.61' 10470.27' 10440.66' 1.53' 10440.66' 10439.13' 10.28' 10439.13' 10428.85' .70' 10428.85' 10428.15' 5.40' 10428.15' 10422.75' 2.75' 10422.75' 10420.00' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE Trading Bay Unit WELL NO. G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS JTS 1 1 ~ 5 12 13 16 15 16 18 22 29 33 68 69 9 CIW 3 1/2" TUBING DETAIL .DESCRIPTION LENGTH BOTTOM TOP ~.3 1/2" Baker Wireline Guide 3 1/2" 9.2# N-80 Butt Pup 3 1/2" Otis "x" Nipple 3 1.2" 9.2# N.80 Butt Pup Baker Seal Assembly (4" OD) Baker 7" Model F-1 Packer Baker Locator 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" Otis "XA" Sleeve 3 1/2" =9.2# N-80 Butt Tubing 3 1/2" McMurray-Hughes GLM .67' 10309.15' 10308.48' 9.96' 10308.48' 10298.52' 1.53' 10298.52' 10296.99' 18.92' 10296.99' 10278.07' 10.50 10278.07' 10267.57' Set at 10250' DIL .50' 10267.57' 10267.07' 30.50' 10267.07' 10236.57' 3.71' 10236.57' 10232.86' 28.50' 10232.86'~ 10204.36' 7.67' 10204.36' 10196.69' 3~1/2"9.2# N-80 Butt Tubing 151.04' 3'1/2" McMurray-Hughes-GLM 7.67' 3 1/2" 9.2# N.80 Butt Tubing 366.48' 3 1/2" McMurray-Hughes GLM 7.67'~ 3 1/2" 9.'2# N-80 Butt Tubing 388.47' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 472.99' 3 1./2" McMurray-Hughes GLM 7.67' 3 1/2"9.2# N-80 Butt Tubing 446.43' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 474.83' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 534.89' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 656.63'~ 3 1/2" McMurray-Hughes GLM 7.67' 3~1/2" 9.2# N-80 Butt Tubing 866.68' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 1302.78' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 2025.44' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 2105.38' 3 1/2" Otis Ball Valve 2.68' 3 1/2" 9.2# N-80 Butt Tubing 271.40' 3 1/2" Butt Pup 4.00' 3 1/2" Butt Pup 4.00' 3 1/2" x 4 1/2" X.O. .45' 4 1/2" Butt x 4 1/2" 8RD Hanger 1.00' Landed Below K.B. 36.75' 10196.69' 10045.65' 10045.65' 10037.98' 10037.98' 9671.50' 9671.50' 9663.83' 9663.83' 9275.36' 9275.36' 9267.69' 9267.69' 8794.70' 8794.70' 8787.03' 8787.03' 8340.60' 8340.60' 8332.93' 8332.93' 7858.10' 7858.10' 7850.43' 7850.43' 7315.54' 7315.54' 7307.87' 7307.87' 6651.24' 6651.24' 6643.57' 6643.57' 5776.89' 5776.89' 5769.22' 5769.22' 4466.44' 4466.44' 4458.77' 4458.77' 2433.33' 2433.33' 2425.66' 2425.66' 320.28' 320.28' 317.60' 317.60' 46.20' 46.20' 42.20' 42.20' 38.20' 38.20' 37.75' 37.75' 36.75' 36.75' 0 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET A PAGE NO. i LEASE Trading Bay Unit WELL NO. 6-3 RD #2 ~/~ SPUD DATE 3127183 COMP. DATE 6123183 FIELD McArthur River Field CONTRACTOR Conserv Drl Co RIG NO. 55 LOCATION: Condbotor #19, Leg #4, 1833' N and TYPE UNIT National 1320 UE 1480' W of SE ocr. of Se0...29t T~Nt R~3W~ SM. DRILL PIPE DESCRIPTION 5" 19.5# PERMIT NO. 83-10 SERIAL NO. ADL 18730 TD 11050' TMD TVD 9780' TVD DEVIATION (BHL) 4557' S26° 13'E COMPANY ENGINEER McAllisterz Abernathy, BuSh ELEVATIONS: WATER DEPTH RT TO OCEAN FLOOR RT TO GL- i11.60' RT T~d~RILL DECK · RT TO PROD~C~N QEC~~ ,~_ ~ APPROVED ~ ~ ~~_ CASING & TUBING RECORD SIZE WEIGHT THREAD GRADE DEPTH REMARKS 13 3/8" 61# Buttress 0-55 2209' ~ 5./8". 47~43..5, 40# Buttress P-110 N-80' 7670' 7" 29# Buttress~ 8RD N-80 P-110 11045' Cmt'd w/ 2500 sx. Class "G" cmt. To~ of win'dow. Cmt'd w/ 925 sx. Class "G" cmt. PERFORATING RECORD DATE INTERVAL ~.T.D. REASON PRESENT CONDITION 5/04/83 10652'-10654' ~/05/83 10'294'%10296' 10957' F.C. B.S. #1 10~'~2' RET. B.S. #2 5/09/83 10310'-10311' 5110783 10)65'-10388' 10957' F.C. 1'0957' F.C. DST #1 Production 5/11/83 10307'-10337' 10957' F.C. Production Sqz'd base of H.B. #4, w/ 100 sx cmt. S z' ~"of H.B. #1~ w/ 100 sx Cmt. Test fo.rme, t..ion, pre.ssure in Bench #1 'open for flow - H.B. #2 Open for flow - H.B. #1 INITIAL PRODUCTION DATE INTERVAL NET OIL CUT GRAV. C.P. T.R. CHOKE MCF GOR REMARKS 5/11/83 10365'-10388' 10307'-10337' 2334' 1% WELL HEAD ASSEMBLY TYPE: CIW CASING HEAD: Shaffer Mod. K.D. 12" Series 900 w/ 2-2" L.R. Sot Outl.-bottom Sow 13 3/8"csg, CASING HANGER: Shaffer 12" Nominal 9 5/8" Mod. K.D. -- K.S. CASING SPOOL: 12" 3M x 12" 3M - 7" Hung w/ 165 M# TUBING HEAD: CIW 12" 3M x 10" 5M DC-B TUBING HANGER: Cameron 10" Nominal x 4 1/2" Buttress bottom & 4 1/2" Eue 8rd top TUBING HEAD TOP: 10" 5000# x 4" 5000# adaptor w/ 4 1/8" bore MASTER VALVES: 2 CIW 4" 5000# values w/ block between for WKM ~" 5M Wing Valve CHRISTMAS TREE TOP CONN: 4 1/2" Eue 8rd RECEIVED Alaska Oil & Gas Cons, Cor,~mis~.~inr~ AilChorag's UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE DATE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Fie. Id__ ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3/27/83 11259' TD 11222' ETD 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW DAILY COST: $ 16,403 ACC COST: $ 16,403 AFE AMT: $2,300,000 2 3/28/83 DAILY COST: ACC COST: AFE AMT: 3 3/29/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 6995' ETD (TOF) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 24,974 $ 41,377 $2,300,000 11259' TD 7020' Est. (TOF) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 34,265 $ 75,642 $2,300,000 Commenced operations ® 00:01 hrs 3/27/83. Pulled Otis concentric GLVs f/ mandrels ~ 2278', 4648' & 6270' prior to rigging up rig. In- stalled BRV, removed tree, installed & tested BORE. Attempted to pull tbg. Rkr ® 10473' would not release w/ 228,000# pull $ surface. Rigged up Die-log. RIH w/ Die-log 3 3/4" OD jet cutter. Cutter stopped ® 7028'. Jet cut tbg $ 6997' w/ 175,000# pull on top of tbg. Tbg would not pull. Ran dia- log freepoint tool. Tbg 10~% free to 7026' where freepoint stopped. Ran 2nd 3 3/4" cutter. Stuck jet cutter ® +6995'. Could not work cutter fre--e. Pulled 250,000# on tbg & fired cutter. Tbg came free. POOH w/ WL. Pulled & leyed down 4 1/2" tbg. Had hole thru both sides of tbg $ 1383' (note: when perfed G-2 last year $ 1380', established communications with G-3). Finished POOH w/ 4 1/2'' tbg. RIH w/ fishing tools (8 1/2" OS w/ 4 1/2" grapple) on 5" DP to top of fish @ 6973'. Ciro & milled over top of fish (cut-off retrieved f/ hole was badly flared). Latched onto fish e 6973' but grapple would not hold w/ 256M# pull (8OM# on fish). POOH & added 6' of extension behind OS. RIH & latched onto fish. Pulled up to 40OM# & jarred on fish w/ 320M#. Fish was free to move down but not up. RIH w/ 1 5/8" sinker bars end chisel point on WL - tagged obstruction ® 7172' WLM. Spudded down to 7225' WLM. POOH w/ WL. Worked pipe up (gained +~') w/ 40OM#. Installed kelly & picked up to 205M#. Performed blind back off - had no increase in pick up weight. POOH to check. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO LEASE ADL 18730 .~. ~ r ~ ~~ - - ~-~ ~ ~-_ .......... ~. WELL NO.. ~TB.U~S ~_-3~R~ J~. __FIELD.__._; .M_o:A~t~.u:~._.Ri~ve.r.. El. eld DATi~" -: ...... ETD 4 3/30/83 11259' TD 11218' ETD (FC) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW DAILY COST: $ 31,801 ACC COST: $ 107,443 AFE AMT: $~, 300,000 DETAIES-~'O'P~A~-~'~'NS, DESCRIPTIONS & RESULTS ....... ~ --- : ~ ..... ~__~.~-- ~ ~-~-. ~ ............. ~--~-_ .... ~ --- ~-~-~-~- :~ ........ POOH & LD i ~t and i cut-off (46.98') of 4 1/2" tbg fish. RIH w/ fishing tools & latched onto fish ~ 7043' (23' low). Attempted blind back-off but entire fish was turning. Pulled & worked fish up the hole. Stopped frequently to circ as pkr was swabbing hole. Circ btms up when pkr reached 9 5/8" csg. POOH & laid down remainder of 4 1/2" & 3 1/2" tbg & hyd pkr (tbg was plugged w/ sand and scale). 5 3/31/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 8945' DPM ETD (Cmt Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 61,369 $ 168,812 $2,300,000 RIH w/ 8 1/2" bit on 9 5/8" csg scraper to top of liner ® 8979'. Circ & POOH. RU Dialog & set Baker omt ret 8 8969' WLM. RD Dialog. RIH w/ stinger on 5" DP & stabbed into ret 8 8945' DPM. Tested surf lines 7000 psi (down 1 hr waiting for Howco to replace 3 defective bleeder valves). Attempted to break down Hemlock perfs f/ 10535' to 11195' DIL w/ 6600 psi. Formation took 1BPM ® 6600 psi when began to get returns to surf & immediate pressure drop. POOH looking for washout in DP - could find none. RIH w/ 9 5/8" RTTS pkr & tested 8 1200' - ok. RIH & set ® 8792'. 6 411/83 DAILY COST: ACC COST: AFE AMT: 11259' TD ll211' ETD (FC) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 21,392 $ 190,204 $2,300,000 Tested surf lines to 7000 psi. Pressured below RTTS to 7000 psi & slowly bled to 6550 psi - probably due to small surf leaks. Could not break down. POOH w/ RTTS. RIH w/ 8 1/2" bit & clean out assy - drld on ret ® 8944'. Chased ret downhole to 8977'. Drld on ret f/ 8977' to top of liner ® 8979'. Circ hi-vis pill & POOH. RIH w/ 6" junk mill on i 4-3/4" DC & milled & pushed ret junk f/ 8979' to 9014'. POOH. RIH w/ 6" bit on 3 1/2" DR w/ 4 4-3/4" DCs. UNION OIL COMPANY OF CALIFORNIA. WELL RECORD SHEET D RAGE NO ........ 4 .......... LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McAr. thor..._Ri~v:e r. F .ia !~_ -DA:~E :--:-~-:---- - ETD ' ::-D~T'AI'ESOF OPERATIONS, D-E-S'c-RI'PTIONS & RESULTS 11259' TD 10400' Est ETD (Cmt) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW 7 4/2/83 DAILY COST: $ 31,698 ACC COST: $ 221,902 AFE AMT: $2,300,000 RIH w/ 6" CO assembly to 10508'. Cleaned out firm fill (sand or CaC03) f/ 10508' to 10649' - plugged bit. Rulled 5 stds & unplugged bit. RIH & cleaned out fill f/ 10649' to ll210'. Circ hi-vis pill & ROOH. RIH w/ OEDR to 11199'. Tested surf lines to 2500 psi. Mixed & spotted 270 sxs cl "G" w/ .75% CFR-2 & .5% Halad 22A across Hemlock perfs for abandonment. CIP ~ 15:00 hrs 4/2/83. Theoretical top ~ 10400' (135' above top of perfs). Rulled up to 8970' & tire hole clean. ROOH & laid down 3 1/2" DR. RU Dialog & ran GR to 8200'. Ran csg inspection log f/ 8200' to surface. 8 4/3/83 DAILY COST: ACC COST: AFE AMT: 11259' TD 7753' ETD (Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8~75-11259' FIW $ 54,954 $ 276,856 $2,300,000 Completed running Dialog csg inspec- tion log f/ 8200' to surf. Log showed hole e 1383', hole ® 6993' (approximate location of tbg jet cut) & several spots of excessive csg wear (70-80% removed). RD Dialog & RU Dresser Atlas. RIH w/ 2' perf gun & perfed for csg stabilization squeeze f/ 7790' to 7792' WLM w/ 4 1/2" HRF. RIH & set Baker cmt ret ® 7780' WLM. RD Dresser Atlas. RIH w/ stinger on 5" DR & stabbed into ret $ 7753' DPM (27' high to WLM). Test surf equip to 5000 psi. Broke down perfs ~ 3300 psi. Pumped in w/ 4.3 BPM $ 3750 psi. Formation held 2800 psi after 3 min. Mixed & sqz'd w/ 250 sxs cl "G" w/ .75% CFR-2 & .1% HR-61. Pumped 100 sxs below tool ~ then hesitation sqz'd remainder. Pumped a total of 230 sxs below ret w/ a final rate of .5 BPM ® 3600 psi. Sqz held 2820 psi after 5 min. CIP ® 17:57 hrs. POOH w/ DP. RIH w/ RTTS & set $ 6808'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 5 LEASE ADL 187}0 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 4/4/83 DAILY COST: 'ACC COST: AFE AMI: 10 4/5/83 11259' TD 1371' EID (Cmt) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW $ 59,485 $ 336,341 $2,300,000 11259' TD 7751' ETD (Ret) 13 3/8" C. 2209' 9 5/8" C. 9132' 7" L. 8975-11259' FIW DAILY COST: $ 35,960 ACC COST: $ 372,301 AFE AMT: $2,300,000 11 4/6/83 Daily Cost: ACC:COST AFE AMT: 11,259' TD 7751'ETD (ret) 13 3/8" C. 2209 9 5/8' C. 9132' 7"L. 8975' - 11259' FIW 28,908 401,209 $2,300,000 Pressured below PITS $ 6808' to test hole (from csg insp log) ~ 6993' to 3700 psi - could not break down. Reset RTTS ® 1452' & injected into hole ® 1383' w/ 5.3 BRM $ 1700 psi. Form held 350 psi w/ pumps off 3 min. Tested csg below RTTS to 3000 psi - ok. POOH. RIH & set Baker 9 5/8" cmt ret ~ 1450' DPM. POOH. RIH w/ RIIS & set ® 1230'. Pumped into hole w/ 3.6 BPM ~ 1850 psi. Mixed & sqz'd w/ 200 sxs cl "G" w/ .75% CFR-2 & 2% CaCL2. Had final rate of 2.1 BRM ® 1450 psi. Sqz held 600 psi w/ pumps off l0 min. CIR ~ 07:35 hrs. Held press on sqz for 2 hrs. POOH w/ RTTS. WOC la hrs. RIH w/ 8 1/2" CO assy & tagged cmt ~ 1325'. CO firm cmt f/ 1325' to 1371'. Continued to clean out cmt f/ 1371' to 1450' Drld ret $ 1450' & RIH to 7711'. ~rld junk & cmt f/ 7711' to 7751'. Pumped hi-vis sweep & POOH. RU Dresser Atlas & ran CBL-VDL-GR log f/ 7750' (30' above ret) to surface. RD Dresser Atlas. Closed blind rams & tested sqz hole to 210 psi (85 RCF equiv) - bled to 160 psi (79 RCF equiv). RIH w/ ret on DR & set $ 1460'. POOH after setting ret.@ 1460'. DPM . RIH and set PITS ® 1200'. Broke down hole ® 1383' w/ 1500 psi Pumped in w/ 6.4 BRM~iO00 psi Mixed aqd squeezed w/ 250 sx cl"G" w/ .75% CFR-2 using hesitation method CIR ® 04:15 Hrs. Held pressure on squeeze 2 hours. POOH w/ RTTS. RIH w/ 81/2" bit #4 and tagged top of cement ~ 1335" Drilled soft cement F/ 1335' to 1342'. W.O.C. 2 Hours. Drilled firm cement F/1342'to to 1360' and hard cement F/1360 to 1371'. RIH and tagged ret.® 1460' and drilled out ret. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD 12 417183 11,259' TD 7751'ETD (ret) Window F/7670'-7673' 13 3/8"C. 2209 9 5/8' C. 9132' 64 PCF 205 Sec Daily Cost: ACC:COST 20,134 $ 421,343 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS RIH while picking up d.p tagged ret 8 7814 (63'Low) Changed hole over to gel-water, Strapped out of hole- found pipe error. Ret actually $ 7751'. RIH w/section mill #1 and milled window in 9 5/8" csg. F/ 7670' to 7673'. AFE AMT: 13 4/8/83 $2,300,000 11259' TD 7751' ETD (ret.) Window F/7670' - 7695' (25'total). 13 3/8" C.2209' 9 5/8"C. 7670' 64 pcf 205 sec Continued to mill window F/7673' to 7674'.Circ. and trip for mill #2 RIH and milled window F/ 7674' to 7695'. DAILY COST: ACC COST: $ 25,768 $ 447,111 14 AFE AMT: 419183 $2,300,000 11259' TD 7751' ETD (Ret) Window F/ 7670' - 7707' (37' total) 13 3/8" C. 2209' 9 5/8" C. 7670' 64 pcf 195 sec Continued to mill window F/ 7695'to 7698'. Circ. and trip for mill #3. RIH and milled window F/7698' to 7707'. DAILY COST: ACC COST: 37,104 484,215 AFE AMT: 15 4/10/83 DAILY COST ACC COST: $2,300,000 11259' TD Trip fo~ section mill #4. RIH. 7546 ETD (est TOC) and milled window F/7707' to Window F/7670' - 7725' 7725' Had total window of (55'total) 13 3/8" C. 2209' 9 5/8" C. 7670' FIW 17,415 501,630 55'. Circ. clean and POOH. RIH w/ 6 jts. 3 1/2" tbg. On 5" d.p.to 7751'. Circ and displaced hole w/FIW. Mixed and equalized 100 sx. cl. "G" w/.75% CFR-2, .05% HR-6L mixed to 121 pcf. CIP ® 23:00 HRS 4/10/83. POOH w/ d.p. AFE AMT: $2,300,000 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 7 LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur River Field DATE ETD 16 4/11/83 11259' TD 7620' ETD (Cmt) Window f/ 7670-7725' 13 3/8" C. 2209' 9 5/8" C. 7670' FIW DAILY COST: ACC COST: $ 20,312 $ 521,942 AFE AMI: $2,300,000 17 4/12/83 DAILY COST: ACC COST: AFE AMI: 7675' TO (KOP) Window f/ 7670-7725' 13 3/8" C. 2209' 9 5/8" C. 7670' 64 PCF 43 SEC $ 47,105 $ 569,047 $2,300,000 18 4/13/83 DAILY COST: ACC COST: AFE AMT: 19 4/14/83 DAILY COST: ACC COST: AFE AMT: 7794'/119' 13 3/8" C. 2209' 9 5/8" C. 7670' 64 PCF 46 SEC $ 56,394 $ 625,441 $2,300,000 7999'/205' 13 3/8" C. 2209' 9 5/8" C. 7670' 65 PCF 53 SEC $ 31,038 $ 656,479 $2,300,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS POOH w/ DP. WOC. Removed DCB spool & installed 12" 3M x 12" 3M csg spool & 12" 3M x 10" 5M drlg spool. Reinstalled BOPE. Changed back brake & fast coupling on rotary. RIH w/ test plug & set in csg spool. Attempted to test BOPE - test plug would not hold. RIH w/ 8 1/2" blt #5 while waiting for pkr to arrive by boat (helicopters weathered in). Tagged cmt ® 7524'. Drld soft cmt f/ 7524' to 7540' & firm cmt f/ 7540' to 7620' (depth limitation imposed by OGCC inspector until BOP tested). Circ hole clean. Circ & POOH. RIH w/ RBP & set ® 55'. Tested blind rams & choke manifold. Retrieved RBP. RIH w/ Baker fullbore pkr & set $ 53'. Tested hydril to 2100 psi & remaind- er of BOP to 3000 psi. BOP test WAA by AOGCC Inspector. POOH w/ pkr. RIH w/ 8 1/2" cleanout assy& drld hard cmt f/ 7620' to 7675' (5' below top of window). Circ & built mud system. POOH. RIH w/ bit #6 on BHA #1 for pyna drill run #1. Continued to RIH w/ bit #6 on BHA #1 for pyna drill run #1. Oriented tool face 90° left of high side & dyne drilled 8 1/2" hole f/ 7675' (KOR) to 7794'. Ciro & POOH. Laid down 35 jts of "E" DR. RIH w/ bit #7 on BHA #2 (30' belly) for follow run. Picked up 20 jts of HWDR & rubbered the DR. Reamed dyna drill run f/ 7748' to 7794'. Drld & surveyed f/ 7794' to 7997'. Circ & POOH. Repaired cut- tings chute line. RIH w/ bit #7 on BHA #3 for Qyn~r~l~rp, n Cleaned out 18' of fill. RU Eastman steering tool & oriented Dyna drill 100° left of HS. Dyna drld 8 1/2" hole f/ 7997' to 7999'. Surveys: 7813' 34°30' S40 1/2E 7873' 34o30' S43E 7969' 35°15' S41 1/2E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO._ .... ,_ 8 LEASE ADL 18730 WELL NO. TBUS G-3 RD #2 FIELD McArthur Rive~ ~e)~__ : 20 4/15/83 DAILY COST: ACC COST: 8185'/186' 13 3/8" C. 2209' 9 5/8" C. 7670' 67 PCF 51 SEC $ 34,266 $ 690,745 Dyne drilled 8 1/2" hole f/ 7999' to 8100'. Circ & POOH. RIH w/ bit #9 on BHA #4 (30' belly follow assy) & reamed dyne drill run #2 f/ 7994' to 8100'. Directionally drld 8 1/2" hole f/ 8100' to 8185'. Circ & trip for BHA change. AFE AMT: $2,300,000 Surveys: 8118' 33°45' S52E 8150' 34° S54E 21 4/16/83 DAILY COST: ACC COST: 8396'/211' 13 3/8" C. 2209' 9 5/8" C. 7670' 68 PCF 57 SEC 28,888 719,633 POOH. RIH w/ bit #10 on BHA #5 (locked up assy w/ tandem NB stabs). Directionally drld 8 1/2" hole f/ 8185' to 8396'. Cite & dropped survey. Trip for blt change. AFE AMT: $2,300,000 Surveys: 8238' 33°15' S54E 8356' 32° S52E 22 4/17/83 DAILY COST: ACC COST: AFE AMT: 8758'/362' 13 3/8" C. 2209' 9 5/8" C. 7670' 69 PCF 56 SEC $ 25,740 $ 745,373 $2,300,000 RIH w/ bit #11 on BHA #5. Direc- tionally drld 8 1/2" hole f/ 8396' to 8563'. Circ & dropped survey. Trip for bit change. RIH w/ bit #12 on BHA #5 & directionally drld 8 1/2" hole f/ 8563' to 8758'. Circ & dropped survey. Trip for bit change. Surveys: 8508' 31°30' S52E 8718' 29°30' S50E 23 4/18/83 DAILY COST: ACC COST: AFE AMT: 8945'/187' 13 3/8" C. 2209' 9 5/8" C. 7670' 69 PCF 56 SEC 30,330 775,703 $2,300,000 RIH w/ bit #13 on BHA #6 (locked up assy). Directionally drld 8 1/2" hole f/ 8758' to 8945'. Circ & dropped survey. POOH & laid down 18 jts of S-135 DP. RIH & set RTTS w/ SSC $ 69' Test BOPE - ok. POOH w/ RTTS. RI~ w/ blt #14 on BHA #7 for Dyne drill run #3. 24 4/19/83 DAILY COST: ACC COST: AFE AMT: 9050'/105' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 56 SEC $ 30,477 $ 806,180 $2,300,000 RIH w/ bit #14 on BHA #7 for d_d.d.d~ drill run #3. RU Eastman & Dialog & oriented tool face 70° left of high side. Dyne drilled 8 1/2" hole f/ 8945' to 8989'. POOH. RIH w/ bit #15 on BHA #8 (30' belly follow assy) & reamed dyne drill run f/ 8945' to 8989'. Direotionally drld 8 1/2" hole f/ 8989' to 9050'. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE_ .... ADL _!8730 DATE 25 4/20/83 DAILY COST: ACC COST: AFE AMT: ETD 9134'/84' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 56 SEC $ 28,068 $ 834,248 $2,300,000 26 4/21/83 DAILY COST: ACC COST: AFE AMT: 9392'/258' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 49 SEC $ 51,632 $ 885,880 $2,300,000 27 4/22/83 DAILY COST: ACC COST: AFE AMT: 9636'/244' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 51 SEC 25,403 911,283 $2,300,000 28 4/23/83 10040'/404' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 47 SEC DAILY COST: $ 26,196 ACC COST: $ 937,479 AFE AMT: $2,300,000 29 4/24/83 DAILY COST: ACC COST: 10283'/243' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 48 SEC 28,549 966,028 WELL NO. TBUS G-3 RD #2 FIEL~..MqAsthur River Fie~__ DETAILS-OF OPERATIONS, DESCRIPTIONS & RESULTS Continued to directionally drill 8 1/2" hole f/ 9050' to 9087' Circ & trip out. RIH w/ bit ~16 on BHA #9 for Dyne drill run #4. C0 13' of fil~: RU Eastman steering tool on Dialog WL & oriented tool face 75° left of high side. Dyne drilled 8 1/2" hole f/ 9087' to 9134'. Circ& POOH. Surveys: 8793' 29° S50E 8905' 28° S48E 8990' 29° S52E 9051' 29° 553E RIH w/ bit #17 on BHA #10 (30' belly) & reamed dyne drill run f/ 9087' to 9134' Directionelly drld 8 1/2" hole f/'9134' to 9212'. Trip for BHA change. RIH w/ bit #18 on BHA #11 (locked up assy)& direc- ectionally drld 8 1/2" hole f/ 9212' to 9392'. Surveys: 9177' 30° S58E 9320' 29° S58E Directionally drld 8 1/2" hole f/ 9392' to 9636'. Trip for BHA chng. RIH w/ bit #19 on BHA #12 (30' belly w/ tandem NB stabs). Reamed f/ 9610 to 9636'. Surveys: 9445' 29° S58E 9601' 27°45' S56 1/25 Directionelly drld 8 1/2" hole f/ 9636' to 10040'. Surveys: 9744' 28° S56E 9869' 28° S56 1/2E Continued to directionally drill 8 1/2" hole f/ 10040' to 10044'. Trip for bit change. RIH w/ bit #20 on BHA #12. Reamed f/ 10014' to 10044'. Directionally drld 8 1/2" hole f/ 10044' to 10283'. AFE AMT: $2,300,000 SHEET D PAGE NO. 10 UNION OIL COMPANY OF CALIFORNIA WELL RECORD LEASE .... ADL 18730 WELL NO. TBUS G-3 RD #2._._FIELD McArthur River..F_i~e!d__ DATE 30 4/25/83 DAILY COST: ACC COST: AFE AMT: ETD 10485'/202' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 52 SEC $ 34,439 $1,000,467 $2,300,000 DETAILS OF oP'E'R'A~IONS, DESCRIPTIONS & RESULTS Directionally drld 8 1/2" hole f/ 10283' to 10353'. Circ & POOH. Tested BORE - ok. RIH w/ bit #21 on BHA #13 (locked up assy). Tagged fill ® 10328' (25'). Washed to 10353' & directionally drld 8 1/2" hole f/ 10353' to 10485'. Surveys: 10014' 30° S55E 10157' 31° S55E 10319' 32° S55E 10481' 31o15' S55E 31 4/26/83 DAILY COST: ACC COST: AFE AMT: 10709'/224' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 50 SEC $ 30,407 $1,030,874 $2,300,000 Directionally drld 8 1/2" hole f/ 10485' to 10670'. Circ & dropped survey. POOH (bit came out 3/8" un- dergauge). RIH w/ bit #22 (HTC OD4) on BHA #14 (locked up assy - 2 new NB stabs). Worked on electrical control for Hydril ® Koomey remote panel. RIH & washed & reamed f/ 10572' to 10670' Had i jet in bit plugged. Direct~onally drld 8 1/2" hole f/ 10670' to 10709'. Could not unplug jet. Survey: 10640' 30° 30' S55E 32 4/27/83 DAILY COST: ACC COST: 10910'/201' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 48 SEC $ 32,726 $1,063,600 POOH. RIH w/ bit #23 (FP52J) on BHA #14 & directionally drld 8 1/2" hole f/ 10709' to lO910'. Cite & dropped survey. POOH - had slight tight spot $ 9805'. Reamed tight spot to clean up. POOH. AFE AMT: 33 4/28/83 DAILY COST: ACC COST: AFE AMT: $2,300,000 11050'/140' 13 3/8" C. 2209' 9 5/8" C. 7670' 70 PCF 58 SEC $ 35,666 $1,099,266 $2,300,000 Survey: 10860' 30° S55E RIH w/ bit #24 on BHA #14. Direc- tionally drld 8 1/2" hole f/ lO910' to ll050'. Circ & cond hole. Made short trip to window. RIH & circ. Dropped survey & POOH - had slight tight spot ® 8800'. RU Schlum. RIH w/ DIL-BHC-Sonic - tool would not go below lO000'. POOH & rig down Schlumberger. RIH w/ cleanout assembly. Survey: 11005' 28° 30' S55E UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE ADL 18730 WELL NO. TBUS G-3 RD #2_ FIELD McArthur River Field .. - DATE ETD DETAILS OF ORERATIONS, DESCRIRTIONS & RESULTS 34 4129183 DAILY COST: ACC COST: AFE AMT: 11050' TD 13 3/8" C. 2209' 9 5/8" C. 7670' 74 PCF 62 SEC $ 26,832 $1,126,098 $2,300,000 RIH w/ BHA #15. Had to ream thru tight spots $ lO000' & 10565' & washed 20' of fill to ll050' (had 90% coal returns). Circ & incr MW to 74 RCF. Made short trip to 9 5/8" window - very smooth. RIH & circ btms up. ROOH. RU Schlum & ran DIL-BHC-Sonic-VDL log f/ 11024' to 7675' (down 3 hrs to repair SOS power supply). ROOH w/ WL. 35 4/30/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 13 3/8" C. 2209' 9 5/8" C. 7670' 75 PCF 66 SEC $ 114,683 $1,240,781 $2,300,000 RIH w/ FDC-CNL-NGT log - set down ~ 7800', 8200' & 8550'. Began to get sticky ® 8550'. POOH w/ WL. RIH w/ BHA #15 - smooth trip. Circ btms up & POOH. Ran FDC-CNL-NGT log f/ 11024' to 7675' (tool also set down ~ 7791', 7822', 7913' & 7980' but was not sticky). Caliper log showed hole out of gauge up high. POOH w/ WL & rigged down Schlum. RIH w/ BHA #15. 36 5/1/83 DAILY COST: ACC COST: AFE AMT: 37 5/2/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 9 5/8" C. 7670' 7" ® 11045' 75 PCF 64 SEC $ 368,197 $1,608,978 $2,300,000 11050' TD 10957' ETD (Est. FC) 9 5/8" C. 7670' 7" C. 11045' 75 PCF 64 SEC $ 50,579 $1,659,557 $2,300,000 RIH w/ BHA #15. Circ& cond hole for csg e 11050'. POOH & LD BHA. RU to run 7" csg. Ran 260 jts & 2 pups of 7" 29# N-80 butt & R-110 8rd csg fitted w/ float shoe & float collar. Set shoe ® 11045', FC ® 10957'. Circ & cond mud while reciprocating csg. Circ & lead w/ 200 F3 caustic wtr & 100 F3 fresh wtr. Mixed & pumpd 925 sxs ol "G" w/ .75% CFR-2 & .5% Halad 22A mixed to 15.8 ppg. Used top & b~m plugs. Displ w/ 2329 F3 mud to bump plug w/ 2800 psi. Floats held ok. CIR ® 02:30 hrs. Lifted BOR stack & riser & landed 7" csg on slips w/ 165M#. Cut off excess 7" csg & installed & tested 12" 3M x 10" 5M DCB spool. Relanded BOP stack & laid down 5" DP. 38 5/3/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 23,570 $1,683,127 $2,300,000 Changed pipe rams to 3 1/2". RIH w/ 6" bit & 7" csg scraper while pick- ing up 3 1/2" DR. Tagged FC ~ 10957'. Circ & displ hole w/ FIW. ROOH. RU Go WL & RIH w/ CBL tools- tools malfunctioned. ROOH & changed tools. RIH w/ new tools & ran CBL-¥DL-GR log. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO LEASE _-, :ADL.. 18.7~_Q___ .= .... WELL NO. TBUS G-3 RD #2 FIELD McArthur R_iy.e.r._,Eie_ld_¢_ DATE ....... :'E'~D ............. ---'- DETAILS OF OPERA-'T¥ONs-,-'-D~-~RIPTIONS & RESULTS --- -~-~ - ~ '-'~ ...... : - ~-± ":-'-~-'-~ ±-:-" ..... -~:-~ ..... %~--~-: : r ~-~-~ -' ..... : ~-~' - 39 5/4183 DAILY COST: ACC COST: AFE ANT: 11050' TO 10622' ETD (Cmt Ret) 9 5/8" C. 7670' 7" C. 11045' FIW $ 27,750 $1,710,877 $2,300,000 Ran CBL-VDL-GR log f/ 10957' to 7000'. Ran gyro surv f/ 10957' to surf. RD Eastman tools. Tested BOPE & osg to 2500 psi. RIH w/ 2' of 4" osg gun & perfed base of Bench #4 f/ 10652' to 10654' DIL for iso- lation Block Squeeze #1. Set cmt ret on WL ~ 10622' DIL. RD Go WL. RIH w/ stinger on 3 1/2" DR & stab'd into ret. Tested lines & equip to 6000 psi. Broke down perfs w/ 8 CFM ® 6000 psi (1.08 psi/ft). Formation held 1300 psi w/ pumps off l0 min. Mixed & pumped 100 sxs cl "G" w/ .75% CFR-2 & .5% Halad 22A. Displ 23 sxs behind perfs w/ a final rate of 6 CFM ~ 6500 psi. Sqz held 5000 psi w/ pumps off 5 min. CIR ® 23:20 hrs. Ricked up & rev out 67 sxs cmt. 4O 5/5/83 DAILY COST: ACC COST: AFE AMT: 11050' TO 10254' ETD (Cmt Ret) 9 5/8" C. 7670' 7" C. 11045' FIW $ 71,982 $1,782,859 $2,300,000 Rev circ clean. POOH. RU Go WL & perfed top of Bench #1 f/ 10294' to 10296' DIL for isolation BS #2. Set cmt ret on WL ® 10254' DIL. RD Go WL. RIH w/ stinger on 3 1/2" DR. Tested surf equip to 6000 psi. Broke dwn perfs w/ 4800 psi. Pumped in w/ 8 CFM ® 4700 psi. Form held 2200 psi w/ pumps off l0 min. Mixed & pumped 100 sxs cl "G" w/ .75% CFR-2 & .5% Halad 22A. Displ 80 sxs behind perfs w/ a final rate of 9 CFM e 5400 psi. Sqz held 4500 psi w/ pumps off 5 min. CIR ~ 13:20 hrs 5/5/83. Ricked up 20' & rev out 9 sxs cmt. POOH w/ DR. RIH w/ 6" bit & 2 junk subs to lOlO0'. WOC. 41 516183 DAILY COST: ACC COST: AFE AMT: 11050' TO 10957' (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 45,791 $1,828,650 $2,300,000 Tagged dmt 8 10262'. Drld ret @ 10271'. CO Junk & cmt to 10334'. RIH.Tagged cmt ® 10625'. Drld ret ® 10639'. No cmt below ret. RIH to ETD ®10957'. Ciro'd hole. POOH. LD 4 3/4" DCs. RU GO WL. Made gauge ring trip to 10640'. Made up iso (Baker FB-1) pkr assy on WL. RIH & set pkr ~ 10420' DIL. POOH w/ WL. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO._ 13 LEASE__~_: ApL_ !873q ..... --_..---: ._~_.: _- ..: _ WELL NO.j:::TBUS G-3 RD #2 FIELD McArthur River Field__ DATE ETD 42 5/7/83 11050' TD 10597' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW DAILY COST: ACC COST: $ 27,876 $1,856,526 AFE AMT: $2,300,000 DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Made up seal assy on 3 1/2" DP. RIH. Tagged pkr w/ locator sub $ 10435' DPM. Tested pkr to 1000 psi. Held 10 mins - ok. Bled off pressure & POOH. RU GO Int. Ran 7" Baker F-1 prod pkr. Set ® 10250' DIL. POOH w/ WL. RIH w/ seal assy on 3 1/2" DP. Tagged pkr ® 10265' DPM. TEsted pkr to 1000 psi. Held 10 mins. Bled off press & POOH laying down 3 1/2" DP. Rigged up to run 3 1/2" comp tbg string. 43 5/8/83 DAILY COST: ACC COST: AFE AMT: 44 5/9/83 DALLY COST: ACC COST: 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 143,907 $2,000,433 $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 43,739 $2,044,172 Completed running 3 1/2" completion string. Landed & tested to 1000 psi - ok. Removed BOPE stack. Installed & tested CIW tree. Removed BPV. RU Myers braid line. RIH. Pulled ball valve & removed gas lift valve f/ GLM ~ 4459'. Flanged up flow line Gas lifted well to 3200' for 500 p~i drawdown. Reinstalled GLV in mandrel ~ 4459'. Perfed Hemlock Bench #1 ~ 4 HPF f/ 10310-10311'. POOH. RIH & set HP press recorder $ 10310'. Opened well 1 hr, shut well in 2 hrs. Record stabilized HB #1 press of 3055 psi. POOH w/ HP recorder. GL well for drawdown. AFE AMT: 45 5/10/83 $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW Completed perfing Hemlock Bench #2 w/ 2 1/2" perf guns ® 8 HPF f/ 10365-10388' DIL w/ gun run #4. Flowed well between perfs to clean up. DAILY COST: ACC COST: 30,468 $2,074,640 AFE AMT: $2,300,000 46 5/11/83 DAILY COST: ACC COST: AFE AMT: 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' FIW $ 74,526 $2,149,166 $2,300,000 Completed perfing Hemlock Bench #1. f/ 10307-10337' DIL. Final prod rate from HB#1 & HB#2 2358/2334 BPD 1% cut. Rigged dwn GO & riser. In- stalled cap in xmas tree & turned well over to prod. Released rig ~ 24:00 hrs 5/11/83. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO ..... 14 --- LEASE~.=.. ~p.L~l.8.73.0: WELL NO TBUS G-3 RD #2 FIELD NcArthur River F. ie.!d ._ ~_. ..... ._..._ _~ .-:--_- ........... · _~ -. :_-._.~ ~-~ - ~..~ ~._- .... _, -~.: ....... ~-E~ .... '-- ' '~TD DETAILS OF OP~-R'AI-iONS, DESCRIPTIONS & RESULTS - -~' ~- ~ ~ ~ _-:~_-z'-~- ...................... ~-'"--' ~ ...... : ±-"-' : ..... ~--'- ~:~-~"~ - '-~']'~' -- --'-'-~"' :~-' ' -':~' ~ --~ -=-~'~---: ..... ~ -- ' ±-~---~-~-: ~-"'~-~- 47 6/22/83 DALLY COST: ACC COST: ll050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' $ 20,010 $2,169,176 Commenced operations ® O0:O1 hrs 6/22/83. RU Myers WL & pulled ball valve. Ran 2 5/8" gauge cutter thru MS. Offload Dowell equip & RU same. Spot GO WL unit. AFE AMT: 48 6/23/83 DAILY COST: ACC COST: AFE AMT: $2,300,000 11050' TD 10957' ETD (FC) 9 5/8" C. 7670' 7" C. 11045' $ 52,640 $2,221,816 $2,300,000 RU GO WL & tstd lub. Perfed HB#2 f/ 10388' to 10365' DIL (2 runs) & HB#1 f/ 10337-10307' (2 runs). Flowed well between each gun run. RD GO WL. Flowed well into test trap· Well made 1200/996 BRD, 17% cut after 2 hrs. Bled press off ann & filled ann w/ 350 bbls of diesel· RU Dowell & tstd line to 5000 psi. Rumped 3000 gal of Naphtha solvent (1 BRM ® 2400 psi), followed by 4000 gal of Naphtha w/ FFA-1, followed by 3000 gal of Naphtha solvent· Displ treatment w/ 93 bbls of diesel w/ a final rate of .46 BRM ® 3600 psi. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO ........ ....... LEASE_, ,TF.a~d.~n~g .Bay,__U,n!,t . ~..WELL NO..~_~_G.-3.~.D #2 FIELD McArthur River Field ......DATE~--~ '~-~ .... ETD '-- ........ DETAI[S'~ OF' O'PE~-AT~°~S~/DESCRI~'~'~oNs & RESULTS 7" CASING DETAIL OTS DESCRIPTION LENGTH BTM TOP 7" B & W 8 RD Float Shoe 1.38' 11045.13' 11043.75' 2 7" 29# P-110 8 RD LT & C 85.08' 11043.75' 109~8.67' 7" B & W 8 RD Float Collar 1.34' 10958.67' 10957.33' 9 7" 29# P-110 8 RD LT & C 368.23' 10957.33' 10~89.10' ~" 29# P-110 8 RD LT & C Flag 37.72' 10589.10 10551.38' 15 7" 29# P-110 8 RD LT & C 634.15' 10551.38' 9917.23' 7" 29# P-110 8 RD LT & C Flag 43.09' 9917.23' 9874.14' 61 7" 29# P-110 8 RD LT & C 2534.63' ~874.14' 7339.51' 7" 29# P-110 x 7" 29# N-80 Butt xo 44.~8' 7339.51' 7294.83' 171 7" 29# N-80 Butt 7221.i7' 7294.83' 73.66' 7" 29# N-80 Cut-off 34.51' 73.66' 39.15' Landed Below K.B. 39.15' 39.15' 0 Landed Casing in 12" 3M x 12" 3M Casing Spool w/ 165M#. STS DESCRIPTION 7" ISOLATION PACKER 3 1/2" Butt Re-entry Guide 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" "x" Nipple (I.D. = 2.7~") 3 1/2" Butt Pup X.O. Baker Mill Out Extension 7" Baker "FB-i" Packer Packer Bore : 4" LENGTH BTM TOP .67' 10470.~4' 10470~27' 29.61' 10470.27' 10440.66' 1.53' 10440.66' 10439.13' 10.28' 10439.13' 10428.85' .70' 10428.8~' 10428.15' 5.40' 10428.15' 10422.7~' 2.7~' 10422.7~' 10420.00' UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 16 LEASE Trading Bay Unit WELL NO. G-3 RD #2 FIELD McArthur River Field DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3 1/2" TUBING DETAIL OTS DESCRIPTION LENGTH BOTTOM TOP 1 1 5 12 13 16 15 16 18 22 29 33 68 69 9 CIW 3 1/2" Baker Wireline Guide 3 1/2" 9.2# N-80 Butt PUp 3 1/2" Otis "x" Nipple 3 1.2" 9.2# N-80 Butt PUp Baker Seal Assembly (4" OD) Baker 7" Model F-1 Racker Baker Locator 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" Otis "XA" Sleeve 3 1/2" 9.2# N-80 Butt Tubing 3 1/2" McMurray-Hughes GLM · 67' 10309.15' 10308.48' 9.96' 10308.48' 10298.52' 1.53' 10298.52' 10296.99' 18.92' 10296.99' 10278.07' 10.50 10278.07' 10267.57' Set at 10250' DIL .50' 10267.57' 10267.07' 30.50' 10267.07' 10236.57' 3.71' 10236.57' 10232.86' 28.50' 10232.86' 10204.36' 7.67' 10204.36' 10196.69' 3 1/2" 9.2# N-80 Butt Tubing 151.04' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 366.48' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 388.47' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 472.99' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 446.43' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 474.83' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 534.89' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 656.63' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 866.68' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 1302.78' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 2025.44' 3 1/2" McMurray-Hughes GLM 7.67' 3 1/2" 9.2# N-80 Butt Tubing 2105.38' 3 1/2" Otis Ball Valve 2.68' 3 1/2" 9.2# N-80 Butt Tubing 271.40' 3 1/2" Butt Pup 4.00' 3 1/2" Butt Pup 4.00' 3 1/2" x 4 1/2" X.O. .45' 4 1/2" Butt x 4 1/2" 8RD Hanger 1.00' Landed Below K.B. 36.75' 10196.69' 10045.65' 10045.65' 10037.98' 10037.98' 9671.50' 9671.50' 9663.83' 9663.83' 9275.36' 9275.36' 9267.69' 9267.69' 8794.70' 8794.70' 8787.03' 8787.03' 8340.60' 8340.60' 8332.93' 8332.93' 7858.10' 7858.10' 7850.43' 7850.43' 7315.54' 7315.54' 7307.87' 7307.87' 6651.24' 6651.24' 6643.57' 6643.57' 5776.89' 5776.89' 5769.22' 5769.22' 4466.44' 4466.44' 4458.77' 4458.77' 2433.33' 2433.33' 2425.66' 2425.66' 320.28' 320.28' 317.60' 317.60' 46.20' 46.20' 42.20' 42.20' 38.20' 38.20' 37.75' 37.75' 36.75' 36.75' 0 ©pst--- · _ ._._.ex_ / W? II IQ sooo:* 12." dooo -~ G-3 RD¢2 K.B.-0' TUBING HANGER - $6.75~ $~2 ", 9. £ ~, N-SO, BUT TI?ESS, TUBING DETAIl x c oss S.-14. SI/2'' McMURRY HUGHES GAS LIFT MANDRELS AT: 3)2425.66';4)4~58.77' 5)5769. Z2'; 6)6643.57';7)7507.87'; 8) 7850.43'; 9~833Z.93'; 10)8787.03'; 11)9267.7' 12 )9663.~3 ~ 13)]p,037.98'; 14)10,196.69' 15. 31/2'' OTIS' XA SLEEVE AT 10,232.82 16. BAKER LOCATOR SUB AT I0,Z67.07' IZ 10.5' BAKER SEAL ASSY. AT 10,267.57' 18. 3~2" OTIS X NIPPLE AT 10,296.99' 19. "BAKER WlRELINE GUIDE AT10,308.5' 20. XO. (Millouf Ex[ TO 31/~' Burl)AT 10,~28.1~ 21. 3~2" OTIS X NIPPLE AT 10,439.13 ' 22. "BAKER WIRELINE GUIDE AT 10,470.27' 12 15:3/8'' ,61 ~, J-55,BUTTRESS CASING AT 2,209' 9~8", 47~, N - 80, BUTTRESS THREA[ CASING (W/RETAINER AT 7,751') KICK OFF POINT AT 7,675' WINDOW FROM 7,6701 TO 7,725' 14 7" BAKER MODEL FI PKR.'IO,269.57' HEMLOCt¢ BENCHES ~1 8 ~2 itI 7" 29~ P-IlO CASING AT 11,045' T.D. = 11,050' WELL SCHEMATIC .550E of .l'JW Cot Se¢33~T9_N~RI3W S UB.$ URFA CE DIRECTI_ONAL SURVEY ~-I UIDANCE F~ONTINUOUS ~OOl Company Well Name Field/Location MA1A~THON OIL COMPANY D3 REDRILL ~2 RECEIVED Alaska Oil .... Anchorage M~ARTI-I11R RT~R; K~NAT; A1.ARgA Job Reference No. 68711 Lo~ed By: Mc BRI DE Date 2-APR. -84 Computed By: R.SINES SCHLUMBEROER M~RATHON OIL COMPRN¥ O-@ REDRILL'~"~ TRRDINO BRY UNIT KENRI. RL~$K~ OCTOBER 28, ]08@ TVW PLOT FROM OCT DRT~ 88711 WELL: D3 REDRILL #2~ SURFACE' ~l133'FWL ( '57' FSL VERTICAL PROJECTION PROJECTION ON ~RTICt:IL PLANE DF AZIMUTH 0 ~:~:ILE~ IN VF=RTICI:t ~PTI~ HORIZ 6CGII. E = 1/1000 IN/FT WELL' D3 REDRILL #2 SURFACE' l133'FWF"~ 757'FSL ion'ii 4000 ~I~F ~11 -41:100 HORIZONTAL PROJECTION I I i I i i i i ; , J i i i i ! ' I i i ! ! i I J j i i i i i i _'.' i i i i i ~ : ........ - - - , .... ~ - - , Ifil l~! ! J' J !!I! I J I I I ' I i ' J J ! ' i i I I I i I~ ''t- . . , ; .... .' : _:, ' ', :. :. :_ ...... ~ ! ~ ~ i I i i ' ' ' : ~ i: i : ; r-~ ..-~ ~ : .:T-t.: .... illl ::'~ ili! .... · ........... I I : J i llil iiil i_iii ::._.':'. ::il :.:_i: i,i: iii jill j [ i:i '-LJ~'!=4-~LH '" I Ii ! I ! i i Ii i I J ~ i i i ] [ i ii.i[ iii] i i J ! . . . .." :: i i .... I .... -'~'~-:'+' : : . : Iii! l!ll iii! ill-:_. !ili l{!i l!ll J 111 ll [l [ ] [ . J.'__.:l iJL~l!'Ii !il.~.,.i...Li.:.Z.:.::li i-.ii J i I ! ii i i i i i i i i i ~ i ..." i i ] I [ i i i _:.' ~ { Ill jill lJti !iii iill il]i: iiii i~j] ]]iii ili] Jill ill : ilii li!i ii~! iii] iiii iii:.' Ii ii ~-'$--}i i ! i~ { { 4-4-4.'~ { ,:4 b .............................. -~--,* ............... 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J J I ' : m { J J i I I J Ii I J [ i : j i i i J iii! ]]ii iii iii] ] ] i i I i J i i . ~ ; i ! ! ; ; ; : : i ! ; - ': ' - ; - ; :' ! - ~' : I I ; ; ; : :~ I s.-.~.-- ..-e,-*- ;== I 'T--'e--~--e-- -~--'e'--I'"-,--~--~e--e"-*-"~-~' -'"','--',--*-'+'-' --'+'--"'--'--~- l~ J J J! i ' 3 ! i I i i .: i : i I ii ] i i J { 1.' i ! I : '.' i i i i :' i : : ! ! : i ! ! ! .: : I i ! i i [ ~ ii iii'., =-: :. -:. ~ .:=.-'=t t ~ t= i~ ~ :' ~ :: ~ :. ~ i ~ i i ~ '; : :-~ -~l?t--?-?-tm~.."-*---]--t%'-r."'".~'-t"':'"?-"."??'. -t"~-4"'?-???-'-*.'"~--t~-'~'~-~" J J ~ ~ .................. ; ; i ! ~ i i i '.'. ~ _: 'i iii..: I ; I i ':. i i ; ii[[ [!{! !iii: i[]]'f-~ii[ J -_:. ?T .................. ; .... · .......................... :i ........ Iii! i ii i i/ii iii.,; ii{{ {{ i{ ! ,:' '.: i .{i{i :' i i ( ! i i i { i ..; f'~'"' ..' .:"?:'-' i i ~ ~ ~ : L-[' ~.4..-4-i-4---~--,i.-4--F--, ! ! i, ! ! ! ! ! - : : ! : :' ! I I -'. i-.--4.-i,-..,~-;,---'~4-4.-i-.~ : : :-.$ ...... i..~-.4..-i----,~...,:....i...i...,'....i-~-i...$.- i I : ; I ' ' I ; ' ; , : ; i : i : ! i ; : : : I i i i i ~ i ~- ~ i ] ~ ! j i ~ ] i [ i i { : { j i i ~. i i { :: ~ , i { } [ I i ! ~-] { i ~-H....~..14-4.-½~-4.-H.4-H..4--H4--.H~.--,~4...~...Ir--~i-~."-~.- ! !i -: i i I :. .: :l : i . : ; i : : ; , i : ' . : : : : : : ! : ] : : : : i ' i : ; : ~ : ; : : : :-H ! : : i : : ! : , I j~._.,f_~. : ! i : , i , : i i i { i { l: : ..-: :i': ~.:: :.:: : :. :,.. ,: i,, ::-: !!i!~i!il i iii b~.-b 4.4...~.4....-::..$4.-.~-4.4...~...~ ...~...4-b.~-.-4.-.~..H.-,--H-1N .... J i i -" ,: i i ] i i -: { : ; ; i ~ !_J ~ ..' i ~ ii i i { ": i { i~. i { ~'~'"] :7: ': i, ! ! { i' i ~:~:~-]~- }! ! } i~._:.,-.~.-~._.~...~.~....~_ -.: i~:l ~Fr-F.'-m-t.{ 1 '.. ~ :~ ~ ~ ~ :.' I.~: ~: i~~-t-fi:: ii ~=i i ~--b'~f"'l~'%'.%-'y-t'fi'-f--"t...:'-H".'..-~"..'.-±'-f't- i-.-:'--~-7---~--~- -5000 -2000 - 1000 u i GOO 2000 3000 4000ERST I Whipstockl) A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY UNION OIL COMPANY COMPANY Slot No: 19, Well No: G3 rd-2 WELL NAME Grayling Platform MacArthur River Field., Cook Inlet.. LOCATION Alaska JOB NUMBER A0583aG0136 TYPE OF SURVEY Gyro Multi-Shot DATE 04-May-83 SURVEY BY David Miller OFFICE Anchorage, Alaska Eastman Whtpstock A PETF~OLA~JE P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 May 6, 1983 UNION OIL COMPANY P.O. Box 6247 Anchorage, Alaska 99502 Well Number: Slot No: 19, Well No: G3 rd-2 Location: MacArthur River Field, Cook Inlet, Alaska Type of Survey: Gyro Multi-Shot Date: 04-May-83 Method of Calculation: Radius of Curvature/Average Angle/ Tangential Surveyor: D. Miller Job Number: A0583-G0136 ATTN: Mr. Jim Callender Dear Mr. Callender, We are enclosing the original and thirteen copies of the Gyro Multi-Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve yoru needs in the future. Sincere~l~y, Shyan~LL. Talwar Alaska District Operations Manager cc: file enclosure Directional Drillers/Sub-Sudace Surveyors/Instrument & Tool Rentals/Sales/Worldwide UNION OIL COMPANY ".'-];LOT 19., WELL NO: 63 RD-2 GMS ._lOB NO:H"' ¢"= '-' ~ R '"., ._, .=. ..:, ~,., 136 GRAYLING F'LATFORM, MACARTHUR RIVER FIELD, COOK INLET., ALASKA GM'.--;., 0-11005 MD., SLIRVEYOR: D MILLER, DATE RUN: 04-MAY-8:':: CAMERA NO: 1537, GYRO NO: 305, ¢¢0... BEG A/U NO: VERT II:AL '.=;ECT ION CALCULATED IN F'LANE CF F:"ROPOSAL DIRECTION: S 27 DEG. 57 MIN. E .i , RERF~RD OF ;=,JRVEY RADILIS OF CURVATURE METHOD UNION CtlL CnMPANY :::LOT 19, WELL NO: 0:3 RD-2 GM:3 ,_lOB NO: AC)583GC)l:36 GRAYLINO F'LATFORM, MAC:ARTHUR RIVER FIELD, CnOK INLET, ALASKA PAGE NO. TRLIE MEASURED 1:RIFT 13RIFT F:nlIRF;E .... VERTICAL VERTICAL SUBSEA R E C T A N O l i_ L A R P_, L 0 ¢'._, l I_ R E DOGLE DEPTH ANGLE DIRECTIL'IN LENGTH DEPTH SECTION TVD C n 0 R ltl I N A T E S DISTANCE DIREF:TION '._::EVERI FEET 1] M r~ FEET FEET FEET FEET FEET FEET D M DG/100 (.]. C) 0 £) 155. C). O0 0. O0 -99. OC) O. O0 0.00 0.00 C) 0 0.00 100. 0 0 0 1 C) 0. 10C). OC) 0. OC) 1. C) 0 O. 0C) 0. O0 C). C) O 0 0 C). 0 C) 2(.]0. 0 :,:0 S 12 W 100. 200.0(.] 0.3:3 1C)1.00 0.4:3 S 0.07 W 0.44 S 12 0 W 0.50 :3¢)0. C) C) C) 100 3C)C). C)C) C). 67 '-'(' .'.)1 00 0.'-'=' ::; 0 Ic' W C) 87 c; 1c, 0 W C) ~(') . . 4C)C). 0:30 S 2C) E 10C). 4C)C). C)C) 1.1 C) :,:C) 1.0C) 1.26 ::: 0.0:3 W 1.26 S 1 28 W 0.5(:) ( 500. 600. '70C). 800. '.:./00. 1000. 1100. 1200. 1 ::: 00. 14 C) 0. 0 45 S 31 E 0 4.5 .=,~' 4 E 0 0 0 0 15 S 42 E · - ) C) .::( S 7 E 0 30 S :31 E 0 30 S 34 E 0 15 S 15 W C) 30 S iS/ E 1 15 .S 20 E 100. 49$/. 99 2.1 '.=.~ 40C). 99 2.25 S 0.44 E 2.29 S 11 0 E C). 28 100. 5'?'?.98 3.46 500.98 3.48 S 0.83 E :--:.5:3 S 13 21 E 0.35 100. 6$/'F/. S~E: 4.06 /_-,00. fY8 4.14 S 0.87 E 4.23 S 11 54 E 0.75 100. 799.98 4.27 700.98 4.30 S 1.02 E 4.42 S 13 19 E 0.25 100. 899.'.=/8 4.92 800.98 4.88 S 1.27 E 5.05 S 14 44 E 0.33 100. ', 9'.-.-)'~. 97 5.77 900.97 1 O0 ' 1. C)'~Y9.97 6.64 1 C)00 ' 97 100, .? 11 ¢/q ..-.'/7 .... 7, '~ ..... ~.., 110 C). 97 1 O0 1 "'" '- ,:,c~ 1 ~.C)0.96 100.~i!.'i: ' 139~, 95 ' ~ 34 1.=.00 ~ ' . ?.:,= i~ ,-' ' 1 ~(')('). :3 C) c. ~.:p, E 100 1499. ,~o .......... ,_ ,_, 1..,. 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C) 1 E · =;1 '-"~ S '"'=' 45 E · - m ",-, ~ ,_1. = c. 34 51 E 7.-,. 4~:: ..... 106.02 S 42.99 E 140.61 S 50.6,5 E 17'.-}.73 S 59.32 E 222.82 S 69.27 E 26'7.06 S 80.30 E 13.16 S ICY 49 E 1.6:5 21.68 $ 26 :3 E 4.02 36.6:6 L=.; 27 29 E 3.65 57.20 S 26 25 E 2.5'7 ,','-, ,=/0 C' ", -'=,~] ,:,..', ....... -4 ~.... E 4.20 114.41 S '"~-.,~ =' 4 E._.'~..:.'"-.-.~ 149.4.6 S 19 49 E 1.54 1:39.27 S 18 16 E 4.27 · .'.:,.: ..... 4 :E; 17 16 E 1. C)C: 27:3.:37 ~:; 16 44 E 1.1:=: 2500. 28 15 S 15 E 100. 2439.78 319.11 2340.78 2600. 28 30 $ 15 E 100. 2527.77 365.43 2428.77 2700. 29 0 ..E; 15 E 100. 2615.44 412.30 2516.44 2C-:00. 2';-/ 15 S 15 E 100. 2702.80 459.74 260:3.80 2700. 29 45 S 15 E 100. 278SY. 83 507.73 2690.8'.': 312.22 S 92.40 E 358.12 S 104.70 E 404.58 S 117.15 E 451.60 S 129.75 E 499.16 S 142.50 E .... '= 6,1 c; . · :,z.-, .... 16 29 E C) 7.~ :373.12 S 16 18 E 0.25 421.20 S 16 T/ E C).5C: 469.87 S 16 2 E 0.25 51~. 10 S 15 56 E C).5C UNION OIL CFUqPANY '..:3LCIT 1.9. WELL. 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WELL NO: G3'RD-2 GMS dOB NO: A0583G0136 GRAYLING PLATFORM, MAC, ARTHUR RIVER FIELD, COOK INLET~ ALASKA COMPUTATION TIME DATE 11:1.9:16, 20-MAY-83 PAGE NO. 1 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100 0. c) 0 0 155. 0.00 0.00 -9.9.00 0.00 0.00 0.00 0 0 0.00 100. 0 0 0 100. 100.00 0.00 1.00 0.00 0.00 0.00 0 0 0.00 200. 0 30 S 12 W 100. 200.00 0.33 101.00 0.43 S 0.0.9 W 0.44 S 12 0 W 0.50 300. 0 0 0 100. 300.00 0.6,7 201.00 0.85 '.=; 0.18 W 0.87 S 12 0 W 0.50 400. 0 30 S 20 E 100. 400.00 1.10 301.00 1.26 S 0.03 W 1.26 S I 2:3 W 0.5c) ' -:,00 0 45 S 5::1 E 100 49.-'FY 99 2 1.9 400 ¢/¢/ ~.' '--.'.=, ' - . . ~. ._:; 0 44. E 2 2~ S 11 I E 0 ~''-' # . . m ~ '- ' · · m ~ m'-,, ( ,=, C) 0' 0 45 8 4 E 100. ~'-.'~'-]. '.-.-~ 8 :3.48 ~ ~')('). 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E 0.50 12.9.79 E 470.00 S 16, 2 E 0.25 142.54. E 51'F~.24 S 15 56 E 0.50 UNION OIL COMPANY · ~' -i , )~' -' · :,LLT 19 WELL NO: OS RD-2 GMS; dOB NO: A£._,,_,~0136 GRAYLING PLATFORM. MACARTHUR RIVER FIELD, COOK INLET, ALASKA COMPUTATION TIME DATE 11:17:16 20-MAY-83 PAGE NO. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100 3000. 30 15 S 15 E :B100. 31 0 S 15 E 3200· 31 15 S 15 E 3300. 31 0 S 15 E 3400· 31 30 S 15 E 100· 2876·54 100. 2962.59 100· 3048.20 100· 3133.80 100. 3217.29 556.59 2777·54 606.23 2863.5~ 656.61 2747.20 706.~8 3034.80 757·54 3120.27 .54.7. :"- .'q-,F; 4.:3 · -,,:~ '._'-; 1 .... _. E ~_ A_ '-.-~. . ~.'.-":3 ._R 15 ._, ~-- 1 E ('). .-"q,_ ('). 5'.~/_-,.79 S 16::_:.67 E 6,2(1). 17 '.'-; 15 47 E 0·75 6,46 72 S 1'-"-' 04 E 671 '"~ 43 ' · ,:,.~:. . ,_-,._, ~:; 15 E C). 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SLOT 19, WELL NO: 03 RD-2 GMS dOB NO: GRAYLING PLATFORM, MACARTHUR RIVER FIELD, COOK INLET, ALASKA C:OMF'UTAT I ON T I ME [lATE 11: 19: 16 20-MAY-83 PAGE NO. 4 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C: L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI FEET D M D FEET FEET FEET FEET FEET FEET D M DO/lO0 9000. 29 0 S 43 E ~100. 29 45 S 47 E 9200. 30 30 S 50 E ~300. 2~ 15 S 50 E ~400. 29 0 S 50 E 100. 7992.54 3613.96 7893.54 3413.78 S 1276.66 E 3644.69 .S 20 30 E 100. 8079.69 3660.85 7~.~80.69 :_--:448.46 S 1311.34 E 3689.38 .S 20 49 E 100. 8166.18 3707.85 8067.18 3481.72 S 1348.~:B E :}733.9C) S 21 11 E 100. 8252.8.9 3754.01 815.3.8'.--~ .3513.74 S 1.387.0? 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GRAYLING PLATFORM, MACARTHLIR RIVER FIELD, COOK INLET, ALASKA GM'.--:, 0-11005 MD, SURVEYOR: D MILLER, ]]ATE RUN: 04-MAY-8:3 CAMERA NO: 1537, GYRO NO: 305, 90 DEG A/U NO: 1562 VERTICAL SECTION CALCULATED :I N FLANE OF PROPOSAL ' , :~ .'::.DIRECTI:ON:' S.27'DEG. 5'7 ~MIN. E RECORD OF SURVEY TANGENTIAL METHOD I_IN I ON CZ L C:OMF'ANY · SLOT 19, WELL NO: G3 RD-2 GMS JOB NO: AO583AOl:36 GRAYLING F'LATFORM, MAC:ARTHUR RIVER FIELD, COOK INLET, ALASKA C:OMF'UTAT I ON T I ME DATE 11: 12:25 20-MAY-83 PAGE NO. i TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100 0. 0 0 0 155. 0.00 0.00 -99.00 0.00 0.00 0.00 0 0 0.00 100. 0 0 0 100. 100.00 0.00 1.00 0.00 0.00 0.00 0 0 0.00 200. 0 30 S 12 W 100. 200.00 0.67 101.00 0.85 S 0.18 W 0.87 8 12 0 W 0.50 300. 0 0 0 100. 300.00 0.67 201.00 0.85 8 0.18 W 0.87 S 12 0 W 0.50 400. 0 30 8 20 E 10,0. 399.9? 1.53 300.9? 1.67 8 0.12 E 1.68 $ 4 0 E 0.50 -",00. 0 45 S 31 E 100. 499.98 2.84 400.98 2.80 S 0.79 E 2.91 S 15 48 E 0.28 · =,00. 0 45 $ 4 E 100. 599.98 4.04 500.'.-.'8 4.10 $ 0.88 E 4.20 S 12 9 E 0.35 700. 0 0 0 100. 699.$~8 4.04 600.'.98 4.10 S 0.88 E 4.20 S 12 9 E 0.75 800. 0 15 S 42 E 100. 799.97 4.46 700.97 4.43 $ 1.17 E 4.58 8 14 52 E 0.25 700. 0 30 S 7 E 100. 899.S.~7 5.27 800.97 5.29 S 1.28 E 5.44 S 13 36 E 0.33 . 999 97 6 15 900 97 6 04 S 1 7:3 E 10Or). 0 30 $ 31 E 100 ' ..... 1100. 0 30 S o4 E 100.." 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E 2000. 20 0 $ 1:3 E 100. 1984.41 1:30.11 1885.41 122.62 S 46.50 E · 2100. 21 30 $ 12 E 100. 2077.46 165.:35 1978.46 158.47 S 54.12 E 2200. 25 45 S 13 E 100. 216'7.53 207.33 2068.53 200.80 $ 63.89 E 2300. 26 45 8 13 E 100. 2256.82 250.81 2157.82 24,4.66 S 74.02 E .... 2400. 27 30 $ 15 E 100 2345.52 295.81 2246.52 15.54 S 24 9 E 1.85 27.65 .S 28 2 E ,4.02 45.87 S 27 14 E 3.65 68.32 S 25 50 E 2.57 97.37 ~' '"':' . :.-, .--.-, E 4.20 131.14 8 20 46 E 3.39 167.4.6 S 18 51 E 1.54 210.72 S 17 39 E 4.27 ~55 61 S . ~ .... 1 ~1 5 CD E I 00 289.26 S 85.97 E 301.77 $ 16.33 E 1.18 2500. 28 15 S 15 E 100. 2433.61 341.94 2334.61 334.98 S 98.22 E 349.08 S 16 21E 0.75 ...... 2600. · 28.30 $.15 E .............. 100. 2521.50 388.45.~ 2422.50. 381.07 5 110.57 E 396.79 $ 16 11E 0.25 2700. 2~ 0 S 15 E 100. 2608.96 435.69 2509.96 427.90 S 123.12 E 445.26 S 16 3 E 0.50 2800. 29 15 8 15 E 100. 2696.21 483.31 2597.21 475.10 S 135.77 E 494.11 S 15 57 E 0.25 2900. 29 45 S 15. E 100. ..... 2783.03 531.67 2684.03 523.03 S, 148.61E .543.73 S 15 52 E 0.50 UNION OIL COMPANY :E;LOT l'Fx, WELL N~]:_ G3 RD-2 GblS ,JOB NO: AO583G01~'..~6 GRAYLING F'LATFORM, MACARTHUR RIVER FIELD, COOK INLET, ALASKA COMPUTAT I ON T I ME DATE 11.' 12: ,'-~'._, 20-MAY-83 PAGE NO. 2 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C: L 0 S U R E BOGLE( DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI] FEET D M B FEET FEET FEET FEET FEET FEET D M DG/100~ 3000. 30 15 S 15 E 3100. 31 0 S 15 E 3200. 31 15 $ 15 E 3300. 31 0 S 15 E 3400. 31 30 $ 15 E 100. 2869.41 100. 2955.13 100· 3040·62 1(>0. 3126.34 100. 3211·60 580.77 2770.41 630.96 2856.13 681.52 2941.62 731.71 3027.34 782.6B 3112.60 571.69 S 161.65 E 594.10 S 15 47 E 0·50 621.44 S 174.98 E 645.60 S 15 44 E 0.75 671.55 S 188.40 E 697.47 S 15 40 E 0·25 721.2~ S 201.73 E 748.97 S 15 38 E 0·25 771·76 S 215.26 E 801.22 $ 15 35 E 0.50 ( ~0('~ 31 15 $ 15 E 100. 3:297.0? 83:3.19 31'.98.09 821.87 S .... ., 0 ~!) 31 45 S 1.5 E 100 o.-. ~, ~, ~,,-, ..... o .-, .. . ._,..:,,:,-'-. 13 ,=,,:,4.4L'-::--:2:~:-q. 13 ,_,7... 70 .~ :-4700 31:30 '=-' 15 E 100 3467 3¢/ 9":'.~ 40 o.':,/.,=_, ?.9 ¢72::: 17 c. 35:c>c> 31 45 '.::15 E 100. '::~"-' 42 986.68 :'~4.~3 42 974 0c~ S -- . . · ...... ~.. . .. · · ?.:gC~CD. .., 31 45 8; 15 E 100 3637 4/.-, 1037 . '9/-,. ..-:,~,:.,o..,._._,,..,, 46 1024 ,6o c. 228.68 E 853.10 S 15 33 E 242.30 E 905.72 S 15 31E 255.83 E 957.96 S 15 2~ E 26~.45 E 1010.58 $ 15 28 E 283.07 E 1063.20 S 15 26 E 0.25 0·50 0·25 O. 25 0. (>0 4000. 31 30 S 15 E 4100. 31 30 S.16 E 4200· 31 0 S 16 E 4300. 30 30 8 16 E 4400. 30 15 S 16 E 4..=-,_ 0 ¢>.. 30 0 c..., 16 E 100. 3722.72 ' 1C>88. '-"' ' ~ o.- . ,.-,C::T~[--,2:3.72 107._, '" ' ..:,0 S~i~6.=-'- 11 :3 15 25 E 0.25 ..... ,~ E 15.45 '"' ' ~' ~ ~ ~"'"" ":' 9'.:'-" 1 ('~0,:~ :::; 3807.9~ :1140.00 .:,70c,, ? .'.~1125, ,.,.,. $ .,, 1¢'> . E I 167 · 70 15 27 E 0.52 100" :387~..'": ....... 70 I s ~n. ...... ~¢~ 3794.70 1175 0:3..-,':' 325.1'7' E 1219.20 ::315 ."-,5"~"- E 0.50 100 ":~ "'~ "' : .:,;~7 .;.' 87 124-0.04 ",oo,', c .... ~. .... 87 1'-': o..-~ S ~:3¢~ 18 E 1267 ':'-;~ = -..,c~ , : ,:.,.-...,, ~,~ S 1 ,., E 0.5c~ ii , .,,. .. ii · .-- I c>¢~. 4066 ,, 2,5 ::: 1..'-'8¢~,., .......".~'~.., 3967.25 1272.25 .'~: :353.06 E 1320. ..:.~"~'- .S 1.-=,._ 31 E c~,~5- # : : :: ,::,, :.,:.. :: . 1 1 CDC> 41="~ "-'~ .... ~ ~c->='':' c,~ .-, ~. ,:,.., 1 24 320.31 S 366 84 '"':" 8 ' - · -',.-',,~,. -. --.-..-,. E 1370 . ,;: ..... 15 :i::Z E 0.25 4600. 30. 0 S 16 E ..... 100. 4239.46 1387.16 4140.46 1368.37 $ 380.83 E 1420.32 · 8 15 33 E 0.00 4700. 29 45 S 16 E 100. 4326.28 1435.71 4227.28 1416. (>7 S 394.30 E 1469..$74 S 15 34 E 0.25 4800. 3.0 15 $ 16 E 100. 4412.66 1484.99 4313.66 1464.50 S 408.1~ E 1520.32 S 15 34 E 0.50 ~00 30 30 'S 16 E 100. ~o~, ,-,o . ~ ~c,. c,.~ 1534.65 . .....,o~ 151~ ~ '-'~ 422 I E 1571.07 ::, 1~, E 0.~._ 5000. :30 45 S 16 E 100. 4584,76 1584.67 4485.76 1562.43 S 4:36.27 E 1622.20 :B 15 36 E 0.25 5100. 30 45 S.16 E 100. 4670,70 1634,69 4571.70 1611.58 8 450.37 E 1673.33. S~15 37 0.00 5200. :30 30 S 16 E 100, 4756.87 1684.:34 4657.87 1660.:37 S 464,36 E 1724.08 S 15 37 E 0.25 5300. :30 30 8 15 E 100. 4843.03 1733.81 4744.03 1709.39 S 477.49 E 1774.83 S 15 36 E 0.51 5400. 30 45 14 E 100. 4928.97 178:3.43 4829.'~7 1759.01 S 489.86 E 1825.'74 S 15 34 E 0.57 5500. 30 0 E; 14 E 100. 5015.57 1831.95 4916.57 1807.52 S 5600. 30 15 ~: 13 E 100. 5101.96 1880.63 5002.'.~6 1856.61 S 5700. 30 15 S 11 E 100. 5188.34 1928.81 508~.34 1~06.06 8 5800. 30 45 S 11 E 100. 5274.28 1~77.72 5175.28 1956.25 S ~ ~' ~ JO c, 07 ':' 5900 ': 1 4.5 ~ 10 E 100. ~=~' . ~,~60 '~,c ~' . .= ~ ~ .. ~, :,. 322027 78 · oz' . .~, 501.96 E 1875.92 S 15 31E 513 ~'' 926 .~ E 1 .25:S 15 27 E 522.9(> E 1976.48 S 15 20 E 532·66 E 2027.47 S 15 14 E 541.80 E 207~.88 S 15 6 E 0.75 0. '56 1.01 O. 50 1.13 LINI ON OIL ROMPANY · :_::LOT 19 WELL MCi. A.q RD-2 GMS ,_lOB NO: AO._,~._,G0136 GRAYLING PLATFORM, MACARTHUR RIVER FIELD, COOK' INLET, ALASKA CGMPUTAT I ON T I ME 'DATE 11: 12: 25 20-MAY-8:3 PAGE NO.._~ TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C: L 0 8 U R E DOGLE~ DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' FEET D M D FEET FEET FEET FEET FEET FEET D M DG/1001 6000. 28 30 S 15 E 6100. 27 30 S 17 E 6200. 29 45 S 17 E 6300. 31 0 S 17 E 6400. 31 45 S 17 E 100. 5447.20 2074.29 5348.20 2054.16 S 100. 5535.90 2119.62 5436.90 2098.32 S 100. 5622.72 2168.34 5523.72 2145.77 S 100. 5708.44 2218.90 5609.44 2195.02 S 100. 5793.47 2270.57 5694.47 2245.35 S 554.15 E 2127.59 $ 15 6 E 54,7.4,5 E 2173.74 S 15 8 E 582.15 E 2223.34 S 15 11E 597.21E 2274.82 S 15 13 E 612.60 E 2327.41 S 15 16 E 4.10 1..'_-:7 2.25 1.25 0.75 '-',00. ~:'." 1 .=,o 17 E ',~o00. 31 0 L:: 17 E 6700. 30 45 S 15 E 6800. 30 15 S 15 E 6900. 30 45 :E; 15 E 7000. 32 0 S 12 E 7100. 35 0 S14 E 7200. 34 0 S 20 E 7300. 32 45 S 24 E 7400. 35 0 $ 24 E 7500. 34 45 ~' .~, 27 E 100. 5878.04 2322.~6 5779.04 2296.38 S 100. 5963.76 2373.52 5864.76 2345.63 S 100. 4,049.70 2423.35 5950.70 2395.02 S 100. 6136.08 2472.45 6037.08 2443.68 S 100. 6222.02 2522.28 6123.02 2493.06 S 628.20 E 2380.75 S 15 18 E 643.26 E 2432.23 8 15 20 E 656.49 E 2483.36 S 15 20 E 669.53 E 2533.74 8 15 19 E 682.76 E 2584.87 8 15 19 E 100 6..,0 =,. '2573 6207. , . .~._,44. '.S /.,,.o:::. 7,8 EJ_.,._7 77 S 15 15 E 100': ::: o.:-,c.c, 74 ,.-, .'.6289 74 2&O0, · .,,-, 8 707 64, E 12 S 1'=. ~'~,;.,, - . . ~., 13 E ii . ~ ,,,~ .- o~ . 100, 6471 k: .',,,.o~, 28 ,-,/. ::...) e. 4.-, 6372.65 10 726 7:_-': E 2750 84 · ':, .... .~.. .:, $ 15 19 E 6..,..,.-,. 75 2738,25 6454,. 75 . 2702.52 $ 748,78 E z.,.,..,.-,, o.-', S 15 29 E 10G A637, 67':: '-') =- = ':' ..... . , ........ ~7~.,,, 47 6..,3 .... 67~.7...'-" .~4. ?2 ;.:: 772.11 E 2:_::6 1. 07 .S 15 .']-'~ E 797 ¢~c~ E 2916.9o S 1.~ 53 E i , ,- . , ~ .,,,, ~ 0.50 1.25 1.06 0.50 0.50 2. O0 3.20 3.54 2.53 2.25 1.73 7600. :35 30 8 24 E 100. 6801.24 2910.39 6702.24 2858.76 8 821.61 E 2974.48 $ 16 2 E 1.88 7700. :35 0 S 27 E 100. 4,8,5:3.16 2967.74 6784.16 2909.86 S 847.65 E 3030.81 S 16 14 E 1.80 7800. 34 45 S 32 E 100. 6965.32 3024.60 6866.32 2958.20 S 877.86 E 3085.71 8 16 32 E 2.87 '' I '· .... ... o-. E 100 7047 24 I 7:3 6948.24 30OA, ~0 e. 909 0 " · · ~.~:,. ... . o ,1 E o140.75 S 16 50 E 0.62 8000. :34 0 S 34 E 100. 71:30.14 3137.:34 70:31.14 3052.66 :~; 940.37 E 3194.22 :3 17 7 E 1.15 8100. 33 30 ~; 44 E 100. 721:3.53 3190.38 7114.53 8092.37 S 978.71 E 324.3.55 S 17 34 E 5.57 8200. 33 30 S 44 E 100. 7296.92 :324:3.4:3 7197.92 3132.07 S 1017.05 E 329:3.06 S 17 59 E 0.00 8300. ~:2 45 ~; 44 E 100. 7381.02 3295.41 7282.02 3170.98 S 1054.6:3 E 3341.76 S 18 24 E O. 75 8400. :31 45 S 44 E 100. 7466.06 3345.99 7367.06 3208.84 ~; 1091.18 E :3389.29 S 18 47 E 1.00 8500. 31 45 S 43 E 100. 7551.09 3396.80 7452.09 3247.32 S 1127.07 E 3437.35 S 19 8 E 0.53 8600. 31 0 8 43 E 100. 7636.81 3446.54 7537.81 3284.99 S 1162.1~ E 3484.52 S 17 29 E 0.75 8700. 30 15 S 4.2 E 100. 7723.19 34~5.41 7624..19 3322.43 S 1195.90 E 3531.10 S 1~ 48 E 0.~1 8800. 29 15 S 41E 100. 7810.44 3543.01 7711.44 3359.30 S 1227.96 E 3576.70 8 20 5 E 1.12 ...... 8900. 28 30 S 41E 100. 7898.33 3589.49 7799.33 3395.32 S 1259.24, E ~621.31, S 20 21 E. 0.75 UNION OIL COMPANY SLOT 19, WELL NO: G3 RD-2 GMS dOB NO: AO583G0136 GRAYLING PLATFORM, MACARTHUR RIVER FIELD, COOK INLET, ALASKA COMPUTAT I ON T I ME DATE 11: 12:...._,'-'~ 20-MAY-83 F'AGE NO. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SLIBSEA R E C T A N O U L A R C L 0 S U R E DOGLE: DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI' FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100i 7000. 29 0 .'3 43 E 9100. 29 45 S 47 E 9200. 30 30 .S 50 E 9300. 29 15 S 50 E 9400. 29 0 :B 50 E 100. 7~85.77 3636.31 7886.7? 3430.77 S 12~2.33 E 3666.10 S 20 38 E 100. 8072.61 3683.21 7~73.61 3464.61S 1328.62 E 3710.63 S 20 5~ E 100. 8158.77 3730.26 805?.77 34~7.24 S 1367.50 E 3755.0~ S 21 21E 100. 8246.02 3775.54 8147.02 3528.65 S 1404.~3 E 37~8.05 S 21 43 E 100. 8333.48 3820.48 8234.48 3557.81 8 1442.07 E 3840.81 S 22 3 E 1.08 2.10 1.68 1.25 O. 25 ~.o ~ . _. ~_,~, 45 .~ 5¢) E 'x600. 28 0 8 47 E 'i:7700. 28 15 8 47 E ~800. 28 0 S 47 E 9900. 28 45 S 47 E 100. 8421.16 3865.06 8322.16 35~0.73 S 1478.~1E 3883.36 S 22 23 E 100. 850~.45 3~0~.44 8410.45 3622.74 8 1513.25 E 3~26.0~ S 22 40 E 100. 85~7.54 3~54.18 84~8.54 3655.02 S 1547.86 E 3~67.27 S 22 57 E 100. 8685.83 3~8.55 8586.83 3687.04 $ 1582.20 E 4012.1~ S 23 14 E 100. 8773.51 4044.02 8674.51 371~.85 S 1617.38 E 4056.25 S 23 30 E O. 25 1.61 0.25 O. 25 0.75 10000. 29 45 8 47 E 10100. 30 45 S 4.7 E 10200. 32 0 S 47 E 10300. 32 0 S 47 E 10400. 31 30 ::~ 47 E 100 ,' :::.~60. ~ ' ~3 4090.92 8761:33 ~75~. A9 16...3 67 E 4101 80 ~' 2:3 47 E 1 00 100,'j. 8946 27 4139 2~ 8847 27 ~'~'~ 56 c. 1691 06 E 41 ~' °4 . -: ,., ~ 24 3 E 1.00 100.: ~031 07 418~.34: 8932.07 ':' "" ' ~,8~4.70 ~ 172~ '~'~ 97 69 O0. 1 9115 ~'~' ~'"'-' 43 9016 '~"-' '-"-' .o,:, e~o~. .c,o c. o60 84 S 1768.57 E 4246.64 S 24 o7 E 0 00 '~ :,p .... _ . 102.14 8:B~6.47 S 1806 79 E 42~4 99 ~ 24 53 E 0 50 10500 ~' '~' .=.1 0 '=' 47 E 100 ¢~'~- 86 4337 50 5~187 o6 ,60 c; . - .:,; .31 1844 45 E 4342.75 S · ~, . ~ ~,o. , . ._ · ~, 8 E 0. ~,C 10600. 30 45 E; 47 E 100. 9372.80 4385.83 9273.80 3966.47:3 1881.85 10700. :30 30 S 47 E 100. 9458.96 4433.80 9359.96 4001.08 S 1918.97 E 4437.46 S 25 ~7 E 0.25 10800. 30 15 '.3 47 E 100. 9545. :34 4481.42 9446.34 4035.44 S 1955.81 E 4484.41 ~; 25 51 E 0.25 . ~ 5'= ~4':'~ /-5 c~' 49 S 1974 09 E .~ ::50 ~A 0 '.E; 47 E 50. 95po 65 4..0~,,0~ 4 ..... ~. - 4._,07.74 ~ ~,5 ='" .. )U._,. 20 0 c. 47 E 155 9722 ~.o c~/.~,c: c,~, ~= ~.~:A S" .... . . ,: ..... ,,.,...,:,._..:, 1 .... .,:..._.,...,o 41C ..,. 34 c.._, 2¢)30.. 77 E ...,... c... 16 ~8., 19 E 0.00 FINAL ,-' ~ ' '-'/' DEG$ 19 '~ ~LOoURE - DIRECTION: .S -'-=, MING 12 '" "~' · :,EL.._-, E D I STANCE ' =~ '. · 4..,~.U 16 FEET UNION OIL COMPANY SLOT 19, WELL NO: GE: RD-2 GMS dOB NO: AO583G0136 GRAYLING PLATFORM, MACARTHUR RIVER FIELD, COOK INLET, ALASKA GMS, 0-11005 MD, SURVEYOR: D MILLER, DATE RUN: 04-MAY-83 CAMERA NO: 1537, GYRO NO: 305, 90 DEG A/U NO: 1562 ' RECOR:D OF I NTERF'OLATED SURVEY UNIAN OIL COMPANY SLOT 1S7, WELL NO: G3 RD-2 OHS; JOB NO: AO583G0136 GRAYLING PLATFORM, MACARTHLIR RIVER FIELD, CO~]K INLET, ALA'.--;KA PAAE NO. 1 MARKER ....... CODE NAME TRUE SUBSEA MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL DEPTH DEPTH DIFF DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M TOP HEMLOCK 10304.00 '.~ 127 .q-o 1176 6 $.~028 '-'~ ~'"~= .. ...... --,.~._,c,~._,.03 S 1751,62 E 422.~..21 S 24. 30 E · ~ASTllA~N WHIPSTOCK' INC., .............. ~ ........ , .......................................... , ........ .............. : .......... ; ..... i ~ . ' ,! ', ' . ' "' i , , ,I~ i. _.~...i ',,.~'1000' .... i .... i ........ ~ ...... ....."..; ............ 2000 ... . ............................. ~, .,~ ........... .......................... ... .............. , .~ ....... "i .. · ' t ........ UN I ON 0'I L! COMPANY SLOT',19. WELL !NO, 13RAY~ING_'PLATFORM, HACP~RTHUR..RIV.ER FIELD 6ooo VERTiI CALi PROiJECT:I ON SCALE I 'IN. = 2000 FEET ; UNION OIL! COHPAN¥ ! HORI ZONT,AL pRO"j'E'CT"~ON SLOT 19, WELL ;NO, G:3 RD-2" ;" SCALE '1 IN.= 500: FEET,- GR.AY.LI_NG_..BLAT?_ORH_,_i._M_~.CART_HUR_.~RIV. ER FIELD ............. DEPTH. INDICATOR, .,TYD EASTMAN WHIPSTOCK', INO; ' ~ ~ ' ~ ' ' · ~ ' .~ ..... , : .... : , . . ; .... ': , ._ . - ,. , - . i . . ~. : .... : - . . : ~ . · ;_ _ :, .. . : .......... ; _ _ . _ : · j - ~. ._ . : ~ ' . . : : . .3 . . - - ~--- ~ ...... ~ -- ~--' 72~ -: .~.- ~. ..:. ..~ .~ ~ - ~ . . . ~ . _ ~ _. ~ . : . ] . . ~ ~ ~ . ~ ; . :, . . . ~ . ~ J ~ . .- ~ ...... ; .... : ..... ~ -- '' ' ' ~ ~ 7559 ' ' ' ' . ~. ~ .... ~. .~ i .... ~ .... J . .. ~ .... ~ ..... : . ..i .... .......... ~ --~ .... ~ .... ~ ...... ~ .... ~' .~ ..~_.. ~. - .i.- ~CT ~ECTYONAL SU~V~Y SURVEY DATE~ 2R-OC?,~l:13 ~TE~PbLAT~o~ ii,EAR !~ ~E?HUR R.TV~R FIEt~D C~PU?A?~N OATg: :A$!JRgD v~R?ZCAT, VEIm.?T:CAL D£VTA?ION A[iMU?H SEC?ION ~EP?H DFP?H IJEP?H DEG Iq:IN D~G MT, N F~E? Z~ , DEPARTURE AZ~UT~ DEC ~iN 0.00 ~oo.oo ~00. 400 O0 soo:oo OO.O0 00.00 OO O0 ~oo:oo o oo .,~o~.~o ~oo oo '~'I~ 200 O0 93 ~ 0 599 76 49~,S6 698 76 .ooo,oo 993 .lO0 1091 129{ ,.00 I377 il ,.oo ~0~,00 ~?0 .0'0 1561 17~9 0 o o .li i 0 0 $ ' w 0 0 N E 0 0 8 2t: W 54 ~ 3.t ~ 10 984 90 ,¢ 19 59 081 )9 16 ~6 OP 71 1,?~03 25 1364,05 22 44 1B45,~9 7~ 1710,~5 .. 47 O~ s' o ss °i ::8'6 N N N ,'3,.4 ~0 8g ooo ,, 410 49&'5¢ 20 594~48 487,76 ~)O0,O0 2174. 80 206g 60 29 1~ !&O0..O0 ~4)6 9~ 2330. ~e S~ ~ 37 4~ z 60~,)1 603 31 ~ ~900,00 2524 31 241g 11 29 1{ K 37 14 E 64t,g5 ~: 64t 85- 4 : 6so 5~ 4s,,2~ ~SOO.O0 ~611 60 2505 40 29 13 N ]7 26 6so.Ss ~ N 5i8~2~ ~900.00 ~698 6~ 2$97.49 ~9 41 ?1~,54 0 ,~o,.oo ~s.~ ~5, 95 ~o ~ ~7 s, ~ e~m;g? ~ .~$;$? s~o.4~ ~ ~:o~?,2~ ~{00.00 ~044.2! 203~ O1 ~0 2T~ ~82] ~ 878,44 ~ 8?8,44 642,~? 1400.00 3130.2m 3024 09 30 )9 5? 918.17 9l'8,17 ~ 6?3,99 124t,41. 6 ~9 PAGE 2 KEt.~L.Y I~t. iBHTN(~ ~L~VATITON~ T~U~ SUB-S ' 4050,!~ ~8 4 t?O0.O0 2 O0 ~ '598' O0 4.49' ~ i400 O0 4866 90 476( i~O0 00 4957 6~ 4~51 42 4 3~ oo mo 9oo STO0 O0 5140 94 5034 ?4~2 20 i800 O0 ~233 3t 5127 t0 3900.00 53~6 3~ 5~20 15 ~1 46 ~400,00 ~7~2 9~ 5686,78 ~$00 O0 5886 74 5780,54 ~0 3 oo:oo 59~0 4~ 5~74.,22 71 ~700.00 607~ 2n 5961.00 ~2 ~0n.O0 6165 20 6059.09 ~2 55 3900.00 6256 91 6150.?1 24 )00n 00 ~347..7~ 6~41.~5 ~5 46 )t00~00 ~4~7.55 6~31,35 76 )~00..00 0614.0~ 650?.89 3400. 00 6701.6W 659~.46 ?50n'00 67~8o9" 668~.77 )$o oo 676q,63 ~9 54 1100.00 ~04B,07 6q4i.87 ~0 56 7900.00 ?1~4.30 7028.10 ?9 4? NORTH/SOUTH FEE? DEG/~O0 FEET 40 N 1: 1743 1761 1779 1.797 1847 1867 1891 19~0 N 40 6 ~ ~2 2~ ~ i! 40 N 56 26 ~ 9 . 59 35 ~ 1743.62 ~ ~9 33 E 177 ~ 60 21 ~ "~2 1, ~ 1814.42 ~ 62 2? ~ 1830 59 . 59 ~ ~ 1847 07 n 55 o E 196774 M 47 33 F 1991:88 ~ 42 23 e 1920 ~S ~ 37 34 ~ 1951.64 ~ 3 5 ~ 202 .34 ~ 32 ~ ~ 2067, 88 ~ 32 39 Z 210~9 ~ ~3 20 ~ 2191.~3 V 34 44 ~ 223~.05 ~ 35 31 e 2~74.92 106,20 1561,04 E 2340, 59:~ 2 E 2374~ 623,1,~ ~ ~408 1654, 2443 716,36 E 2509 ~747,19 E 2542 t 808~ ~ ~6~7 1836.94 ~ 2657 84 1951,64 N 18~8 1988,32 n 1 202?,34 ~ 1913 2067;88 2108.,59 ~149,7~ ~ 1991, ~2~5,05 ~ 2046 ~274,97 q 20?5. ~]i6,01 ~ 2105 N 38 5"/ E lU 32 ~ FEI ,DEC ~I~ 74 N 36 9 E ~ 2'9 i36 I~4 EE N 39 0 E N 40 13 E 51 N 41 18 E 2305 6~ N 4134 E {1 N 41 50 E N 42 6 E 95 N 42 ~1 E 04 N 42 3~ E 54 N 42 ~3 E 39 N 43 9 ~ N 43 24 E 86 N 43 35 E N 43 42 E 47 h 43 43 E 64 E ~699.2~ N 43 .41 E 92 E ~42,~2 N 4~ 31 E 25 E ~?,59 N 4~ ~0 E 89 E ~834.6~ N 43 9 E B4 E 2a~,14 N 4~ 5~ E O0 t 29)0.,0~ N 4~ 48 E ] E ~976~92 N 42 38 g ~5 F 3028.,8t N 4~ )0 E 76 F ,079,6, N 4~ 22 E /{SURFD V~RTI~,A! IIE'n.T~C~L~ D~VYATIDN' A~I~UTH DEPTH D~PTH DEPTH DEG MXN DEG MTN F S~C'TION ~EVE}ITY NORTH/SOUTH E}$TtWEST F~ET DEC/lO0 FEET FEET FEET DEG PA~E 3 tO~,~o ~T 0o°'"o $00.80 7399 ~00.00 74~0 0.0~90 00.00 ~671 68 779~-48 75 46 O~ 7~8~..88 ~4 57 80 7~74,69 ~4 30 7~ ?.4 3~ 756~ · 56 600.00 7762 8~ 765'6,65 ~4 37 700.00 7853 67 7'~4'7.47 ~4 56 ~oo.oo 7~.~ 7~.~.~ :~ ~ ~,o~.oo ~7 ~oo.oo ~o~ .~00.00 ~398 '400..00 ~4~8 ,~00..00 ~578 ,~0o'00 *667. ,700 O0 m757. ,~00.]00 ~847 1] 801~.g3 }4 3R O0 8110'89 24 ~8 64 8~01..44 ~.5 19 04 8~9~,.84 ~5 36 21 838~.01 ~5 46 0~ 847'1.82 ~6 21 75 8~6t,$5 ~6 ~. 37 865~.17 ~6 2~ 30 874~,~0 75 46 2~ 8m3~.00 ~6 2! }~OO.O0 0202 85 9096,65 ~q 1) ~3oo oo ~2~0]t6 9~.~ ~9 3~ ,400~00 ~376~ 77 9~70.57 30 31 }~00 O0 0462!54 '9~56.~4 31 2R ~600:00 9548 13 944~.g3 30 37 }VOOoOO ~634.5~ 9828.~8 ~9 47 ,~oo.oo n~o~.~ 9,oa.s~ ~7 ao ~ 37 4~ ~ 241~.85 ~ 39 I~ E 2461.50 n)8 27 E 2493.30 ~ 34 38 E 252~,'74 ~ 36 4 F 256~...35 ~ 35 31E 259~.34 ~ ~7 13 E 2629.19 ~ 38 3~ F 26~9'29 ~ 40 41 ~ 2694.32 ~ 46 42 ~ 2945.46 ~ 46 24 E 2075.49 ~ 45 50 ~ N 46 37 ~ ~ 48 ~ ~ 3071.36 ~ 48 4}' E 3~0~,.~9 ~ 47 ~? ~ 3~36.76 N 45 52 E 3171-84 N 45 5~ r 3242.~5 W 44 4t E 3~77..12 N 44 5~ E 3310.~2 O. O: o, 4 ~ 0.. 79 O, ~6 1,10 1.03 0.48 1.5! 0 ,:, 57 1,06 ,, 0.61. 1,21, 1. 14 0:81 0,4~ 1.7 0.00 ~398'32 N ~15:8 ~418.,85 ~ 2181 2461,50 ~ 2215 ~493,30 ~ ~241 ~5:~7:,74 V 2266 ~56't, 35 ~595,34 ~23~4}200 ~6~9, 19 2339 ~789. ~821~ 2853 7915. ~945 ~97'5 56 241.9 2447 39 ~ 2504 2~ N 2535 60 ~ 57 ~ ~5~8 46 N26}9 49 ~ ~661 ~353.03 ~ 41 S7 E N 4~ 52E 3477,64 N 41 43 ~ 351.9.38 N 4, 39 g ,$61'2:, N 4, 37 g 94 E 3602i E 3686 81, ~ 3729 83 F 3772; 09 2:i: ~ 3816 3860 0~, ~ ~905 90 E ..948 54 ~ 3902 0 }o 3101 3136 3i7t 320? 3242 3277 3310 90 N 2727,71 ~ 4083 36 ~ 2762,88 r .4131 59 N 2799,44 E 4i79 76 ~ ?836.8, ~ 42~9 84 N 2874.4,. E 42 {0 84 , 2911 53 ~ 4332 85 N 2947 60 E 4382 t2 ~ ~982 37 z 4431 2~ N 41 si ~ 5~ N 41 54 g 10 N 41 ~8 E 61 ~ 4~ 3 E 28 N 42 .7 E 5! N 4~ 11. E 1~ N 49 13 E 29 N 4~ !6 £ 03 N 42 18 E 47 N 4~ ~9 E 3312,80 N 3017.79 E 4481,26 N 42 lO Z CPHPU?A?t~N DAT~ 2*ApRio4 PA~E 4 EMG~N~R~ M~ ~R~D~ V~TICAL D~VTATIeNAZI'MUTH 6~C?'ION . 090~: O0 98~,.S 9? ,9? 20 ~ O~ O, O, oi,o .o O0 N 0 7, ~ 9 ~ .~0 tol~ ~o t DA~E Or Su.v~Yi ~8,oc~a8~ K~LLY 6USHTNO ~b~Vi?TON: , ? 0 ,so ~"o. 2~,, 0 O. 0 0 0 0 106~20 FT o"o0 N o o £ 0 O0 N 90 0 £ s s? ~ 3~ 40 N 18 E E E N : 29 84 0 E E 8 E 3 E 8 E CbNPU?A?I~H DA?'~J 2,'APR-84 xm~Y ~USHtN¢ TRU~ .'SUB'SEA _ ,.chum$~ V£RTiCAL PO~Lg'O-: R~C?A#GUL.AR CbORDXNATES HbRZZ~ 444J.~4 4,S,6~.S5 St21.02 45 ~8 75i So 25 ,.,0 N ~0 2O ,~ 0 OI 0 O: NN ~o~B, mm PAOE 6 .. N 40 22£ E 3:~r PAGE ? ~ o6,20 IHt~RPO~A?Er) VAbU~8 rbR ~Y~N ~00 r~l Or )U)I~A 1~. g ',o ~, ]. ,, ~ ~%.,,,,. ~,s~,, , ~ ,.,,~.?o , ,, ,?~ O. t6 ;0 25 5~ 1~ 46 ? ]0 N 4 1 2) ~ )9~2 0:~ N 4~ 48 B: E NC N ,4 E £ 26 :N g O0 98 IC ~R?HUR-RTVER FTE~O ~R~KRR ' h '~ ?,T~L O~P?H ~DRZLT, ER) i: o9o6; oo 9~t~. ~ ? · , SUMMARY PA~ 9 ************ Sus,SEA RRC?ANGJbAR COORD~NAT~ : . ********************* SUR. V,~Y DATF,, t ,, Suggested form to be inserted in each "Active" well folder to check for timely compliance with our r'egulations. Operator, Well Name and Number Reports and Materials to be received by: ~- /~ Date Required Date Received Remarks C~letion Report Yes ~-u ~~~ '~.. /..~-,-. ~ ....... ~e ~lgs ~ ~ ~ '- . ~.:.~ ~ .,~ Core ~scription ~ :'" _-. ' Registered S~~- ,~ -4 * Inclination Su~ey . , . ~; ~ "..,. ~r~ s~ ~es~ ~e~s .J~4:~ ~s R~. Yes · - L~ "~ ~.~-'-:: '~ Y~ ~ " / 3-~' ,, Union Oil and Gas D' "~on: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502/ Telephone: (907) 276-7600 unl, n DOCUMENT TRANSMITTAL May 23, 1983 HAND DELIVERED TO: William Van Alen FROM: R.C. Warthen O. P. Brady LOCATION: 3001 Porcupine Drive LOCATION: Alaska District Anchorage, Alaska 99504 ALASKA OIL & GAS CONSERVATION COMMISSION Transmitting: Reference: Union TBU G-3RD-2 One (1) each blueline and sepia of the following: DIL 2" and 5" BHC 2" and 5" NGT 5" Porosity 5" Bulk Density 5" O-H VDL One (1) magnetic tape with verification list One (1) directional survey / KNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. DATED: MAY 2 Anchorage "--., STATE OF ALASKA .---., ALASK,,._..-.~ AND GAS CONSERVATION C~ 41SSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 Drilling well [] Workover operat on [] 2. Name of operator 7. P~f"m~_ V AddresUNION~ 0IL COMPANY OF CALIFORNIA ~ -~3 .... 8. APl Number : PO BOX 6247 ANCHORAGE AK 99502 50- 733-20049 at surface Conductor #19, Leg #4, 1833'N & 1480'W of SE corner, TeN, R13W,.SM. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RT '99' MSL I ADL 18730 TRADING BAY UNIT 10. Well No. TBUS G-3 RD #2 11. Field and Pool Arth,r River Field miocR Formation For the Month of. April ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Milled window f/ 7670-7725' & set cmt plug w/ 100 sxs cl "G". K0P ® 7675'. 11050.'. TMD ®.4130183. 13. Casing or liner run and guantiti.es of cement~ results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run Casing Inspection log f/ 8200' to surface CBL-VDL-GR log f/ 7750' to surface DIL-BHC-Sonio-VDL log f/ 11024-7675' FDC-CNL-NGT log f/ 11024-7675' 16. DST data, perforating data, shows of H2S, miscellaneous, data Abandon Hemlock perfs w/ 250 sxs cl "G". Theoretical top of cmt ~ 10400'. Rerfed & sqz'd f/ 7790-7792' w/ 250 sxs cl "G". Sqz'd f/ 1200-1460' w/ 250 sxs cl "G". 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-- port on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. F,.~n, 'n4.q,'l Submit i~ duplicato MEMORANDUM Stat'e of Alaska C. tte~on ' April 13. Ch~~n/ //' ' FILE NO: TH~U: Lonnie C.. Smith ~ TELEPHONE NO: C~missioner FROM: ~ SUBdSG/: Edgar W. Sipple Petroleum Ins~or 1983 Withness BOPE Test On L%~ion Oil Grayling Platform We 11 No. G3PJD-2 Sec. 29,..T9N RI~$, SM Permit No. 83-10 Conservative Dr il ling Rig 55 Monday, ~April_ll, 1983..: I left Anchorage via AAI to witness a BOPE test on Union Oil Platform Grayling. Conservative Drilling, the contractor was in the pTocess of nippling up when .I arrived. Tuesday, April !2., 1783.: The BOPE test commenced at 2:00 a.m. and was concluded at 11:30 a.m. There were no failures. The reason for the long test, was the test plug leaked. We had to wait for another type of packer to fit in the 9 5/~, casing so we could finish the BOPE test. The state was called out on this job after the initiaI BOPE test had already been performed. The contractor had already cut a window in-the 9 5/8 casing. (See attached. drawing). I filled out the AOCCC BOPE test report ~hich is attached to this report. In summary, I witnessed the BOPE test on Union Oil Crayling Platform, Conservative Drilling Rig 55. 02-001A('Rev. 10/79) o~9 # 4 4/80 '~--~ STATE OF AI,ASKA '~-~' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Omrator. -- Location:. Drilling Co n t r ac to r ~"~;~ v~' Representative ~4;./~ /~ .~ ii ~ ~-~;~ Permit ~ ~3~/~ ~ Casing Set ~ 7~g~ ft. ~ Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack ~ , Annular Pr~oventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve K~i~i~ %qn~e'~ ~a%v e s Check Valve ~. Tea t Pres.sure 00 ~ ACCUMULATOR SYSTEM Full Charge Pressure .~10~ ps.ig Pressure After Closure /~/._.~ psig 200 psig Above Precharge Attained: ~ rain ©~ sec Full, Charge Pressure Atta±ned: ~.- min.~_ sec N2~~,~L~4~ ':-' , ,,~ Cqntrols: Master ~a Remote ~I~. Blinds switch cover f~.3 ___ Kelly and Floor Safety Valves Upper Kelly a& Test Pressure Lower Kelly ~ Test Pressure Ball Type ~ Test Pressure -- ,, I$~~['~a ~F~P~ Test Pressure Choke Manifold No. Valves No. 'flanges ~O -' Adjustable Chokes ~- .~,z i~. llydrauically operated choke ~%~ Test Pressure Test Results: Failures --~o -- - .Test Time '--':h-rs.~O_~4,~ Repair or Replacement of failed equipment to be made within:' A-~days and': Inspector/Commission office notified. · · / Distribution orig.' - AO&GCC cc - Operator cc - Supervisor. DATE FOR~,4 NO. 20-27 (6/76) ~KER PACKERS DIVi~~N , · · ./ ~M ¢ .-~. STATE OF ALASKA ~-.. ¢ (~~...~. ALASK/. % AND GAS CONSERVATION C ~ AISSlON REPORT F DRILLING AND WO OVER OPERAT!ONS . ~NT~LY, lng well Workover operation ~ '2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well at surface Conductor #19, Leg 4, 1833'N & 1480' W of SE corner, Section 29, TgN, R13W, SM. 5. Elevation in feet (indicate KB,~F, etc.) I 6. Lease Designation and Serial No. RT 9~' MSLI ADL 18730 9. Unit or Lease Name TRADING BAY UNIT 10. Well No. TBUS 6-3 RD 11. Field and Pool McArthur River Field Hemlock. Formation For the Month of March ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations 3/27/83 Pulled 4 1/2" tbg to 6973', Fished & removed remaining tbg & hydraulic pkr, Attempting to break down formations to abandon Hemlock perfs. . · .. · 13. Casing or liner run an~ quantities of cement, results of pressur~ tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,ONEO ~,~ ~'7~._ ~ ///~¢..1~ T,TLE DISTRICT DRLG SUPT DATE Z~/ZI'/83 - ' / ~ L~ NOTE]-Re~rt on this form is required f~r ea~ calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate District ~anu r.~anager Union ()il Compgny of C~lifornia P O. Box 6247 Anon er a,'~o Alaska 99~ 5, ion Oil Conpany Permit ~o. 83-i ~,eur. loc. ......... o~ Loc. Dear ~fr. Anderson,.: recov~r~tc~ core ia requ reu. SamDle~ of wall t lo~ are not r~oui~'~r~. A con~u.%~ous directional r~-uired as per 20 AAC 25 050( ~ - . . ~)(5). ~ available, containin~-~ the ~4 ~ o~:,~ for copvinz .... *~ ~'~-~i'~,mta! lo~, and di"~<-~'~e~ clas~fi~d~ as important for the anadrot~ous fish A:, 16 0~ .~ 8.7C and the regulations (Title 5, Ala~:ka Adr;~in~stratlve _ · ..... _ __ o~eration~ 7ou ~,av be contactad ~-,~-,-t Of ~ and Pc, II. ution of =my water~ of '~ State is p~o~~-=d Ch~mter 3, Article 7 and th~ ~-~,,~= ' ('""~.la !g, A!a~ka ~ - . CheDdar 70) and a~m~.n~.¢trativ~ Code, . _. ~ ...... Feder,uI 'G'ater Poi lutzon' (,on~o~~-' ~ ~ Act, a~ ........ a~en~e~ - Prior co~:,;mncing. . o~aration~, yon. __ mav~ be contacted by of~h~e n~,~,.,r-~ .... ~ ~ ~&"~'~<~tal. Conservation. Mr. Robert T. Anderson Trading Bay Unit TBUS G-3 RD -2- January 14, 1983 To aid us in scheduling field work, please notify this office 24 hours prior to con~encing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipn~nt before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~anisston may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C, V. Chatterton ~¥ O~DER OF TM~- ¢O~.,~iS$1ON , Chairman of Alaska Oil and Gas Conservation Commission Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental~ Conservation w/o encl. be Union Oil and Gas F';,,ison: Western Region Union Oil Company~'~ California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager Oanuary 11, 1983 Mr. Chat Chatterton Ak. Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 WEST FORELAND AREA State of Alaska McArthur River Field Trading Bay Unit G-3 Rd. #2 ADL-18730 (8-86-71-5575-601352) Dear Mr. Chatterton: Enclosed for your approval are three (3) fully executed copies of the above captioned Rermit to Drill G-3 Rd. #2. Also enclosed is our Check No. 19222 in the amount of $100.00 to cover the required filing fees. Upon approval of same, we would appreciate a copy so that we may complete our files. sk Enclosures Very truly yours, Robert T. Anderson _ / cc: J. R. Callender A. Lannin-LA Office JAN Z 2 Alaska Oil & 6as Cons, ^nchorage ALASKA OIL AND GAS CONSERVATION COMMISSION Bill Sheffield, Governor 3001 PORCUPINE ;-.:'-RIVE ANCHORAGE,ALA$~;A 99501.--31'92 TELEPHONE (907) 2'79.-1433 January 13, 1983 A D M I N I S T R A T I V E A P P R O V A L NO. 80.44 Re: Application of Union Oil Company of California, operator cf the Trading Bay Unit, to redrill, complete and produce the ~Tradin ay..Unit.G-3 RD~/2 well as part of the pressure mazntaznence pro3ect approved by Conservation Order No. 8~5. Mr. Robert T. Anderson District Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Anderson: The referenced application was received on January 12, 1983 a~:_d stated that the drilling, completion and production of the Trading Bay Unit G-3 RDf/2 well will provide a crestal final withdrawal point in the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No.. 80. Yours very truly, Harry W. Kug Commi s s ioner BY ORDER OF THE COMMISSION HWK: be STATE OF ALASKA ALASKA'rt..-C.L AND GAS CONSERVATION CO~;MISSION I ERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator UNION 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 9950:~ 4. Location of well at surface on Unto 19 eg '. , ~ec~lon ~9, ~T~N, ~W1,8~ N & 1480'W of SE corner At top of proposed producing interval +lgO0'S & +500'E of NW corner, Section 33, * At total depth +2087'S & +800'E of NW corner, Section 33, * 5. E--[evation in feet (i~dicate KB, DF etc.) RT 99' MSL 6. Lease designation and serial no. ADL 18730 9. Unit or lease name TRADING BAY UNIT 10. Well number TBUS G-3 RD #2 11. Field and pool McARTHUR RIVER FIELD HEMLOCK FORMATION 12. Bond information(see 20 AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount $200,000.00 13. Distance and direction from nearest town NW ~morox. 12 16. Proposed'depth (MD & TVD) +ll..200 & +9875 19. If deviated (see 20 AAC 25.050) KICK OFF POINT +77[00 feet. 21 -- 14. Distance to nearest property or lease line miles +800 feet 17. Number of acres in lease feet 3840 20. Anticipated pressures MAXIMUM HOLE ANGLE 38 O l (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed well +500 feet 18. Approximate spud date 3/1/83 2800 psig@W/gaS Surface 3500 psig@ 9750 ft. TD (TVD) SIZE Weight Hole Casing 8 i/? 7" 29# CASING AND LINER Grade Couplingl Length 22. Describe proposed program: (See Attached) SETTING DEPTH MD TOP TVD +7200 1+6500 I MD BOTTOM TVD +110501 +9750 i I QUANTITY OFCEMENT (include stage data) +400 sxs ECE!VED JAN ! 2 983 Oit & Gas Cons, ,-,o . ~ Anchorage ~ ~mm',smon 23. I hereby certi~4~41~~egoing i_,~,ue anti'correct to the best of~ny knowledge SI LE District Land Manager The space below for Commission use i/ii/83 CONDITIONS OF APPROVAL DATE Samples required Mud log required I Directional Survey required APl number FIYES [~O []YES [~NO I ~-YES •NO 50-- ~7,¢~- Permit number _ Approval date ~~ [. ~~ ~ ~ SEECOVER LETT, ER FOROTHER REQUIREMENTS b~ order of the Commission Form 10401 Submit in tri~licato ~ev. 7-~-80 P£RMIT TO DRILL TBUS G-3 RD #2 JANUARY 4, 1982 22. PROCEDURE: 1. Move Rig #55 over G-3 and rig up. 2. Kill well, install BPV, remove tree, install and test BORE. 3. Pull and lay down existing completion equipment. 4. Set cmt ret above perm pkr ® 10358' and sqz Hemlock perfs for abandonment. 5. Isolate and sqz 9 5/8" csg leak as required. 6. Clean out 9 5/8" csg to TOL ~ 9800' & run CBL. 7. Sqz 9 5/8" csg for stabilization and mill window in 9 5/8" csg f/ +7700' to 7770'. 8. Kick off and drill 8 1/2" hole f/ +7700' to +11050' TMD. 9. Run DIL, BHC-Sonic, FDC-CNL-GR logs f/ KOR to TD. 10. Run and cmt 7" liner f/ ±7200' (500' lap) to TD. 11. Run CBL & gyro survey. 12. Sqz as required for isolation. 13. Complete well as required w/ 3 1/2" tbg. 14. Install BPV, remove BORE, install and test tree. 15. Place well on production. .IAN i ,~iaska Oii& Gas Coas, CommissioD Aimhorage ,.,. e · .o · .. .. £L/~'/O P,'A/,,"S ~ o -. · 'IZ' 3,000 .-. JAN ~ 2 ~'~ ' Anchorag~ · J/i'll £~ . FILL lIP LIHS' "- ~ UoTc ' ALt. CHA,',IG£S lvjusr H/kV~ WR~T..TEN APPROVAL BY THE D~STRICT DRILLING SUP[Ri~TE~DENT CASING AND TUBING DESIGN #/g. HYD. GR. II psi/ft. M.S.P. psi. WEIGHT TENSION MINIMUM COLLAPSE COLLAPSE INTERNAL W/ BF -top of STRENGTH PRESS. $ RESIST. BURST MINIMUM INTERVAL DESCRIPTION W/O BF section TENSION bottom tension PRESSURE YIELD ~,E' CASING SIZE Bottom Top LENGTH Wt. Grade Thread lbs~ lbs 1000 lbs TDF psi psi CDF psi psi ~. ~ ~,o~' ~o' ~ego' ~' N:r~ 6~L~. ~:~AZ yY/.~d ~ 6,m~'2P?~ .yo~O $.S~ 8o00 rz~o ~.7,~. UNION lOll COMPANY-"'OF CALI-FOR'NIA: GRAYLING PL.AT FOR'M TRADING BAY UNIT G-3 RD-2(22'- COND. 19 LEG 4' SCALE' I"= I000t DEC. 16,~ 1982 aY ' ' -' -: ........ SURFACE BESSE ~ EPPS-8~ POTTS - -'-.- ---~-;--'--'- O' _~.'.';7_ -~._. FOR ' GREAT LAND DIRECTIONAL DRILLING' 6000 7000 8000 ' 1480', 9O00 · - I0,000 2000 ' ...t_ _.: ._ WELL-- - ....................... :5000 .......... L - - t- '- -; ................ \ ........................ ~ - - : . -' \~i - ' ' ' '- : ..... ;1'- ' .... ' '! --; ;-i .'___'i ~: '-' ;. i ~-:" I- --34° 49' · '- ; ' ' ': 't-' ....... .-:'; ....... i-'-: i ; ! ..... ...... \ 2 o ......................... ', ........... ~ .... DIR. S 5.1 E ! ' . '-I ....... · -:' ..... ~ : ...... : ....... ' \ - ' ..... ' ........_ o ~ooo '' 2000 -" '- ;'. _ DEP=291~ _ ~X KOP TVD=691i, TMD=7700'' ._~ ~__ r: _, .: _: .'. _-~._ -._:' : i_ ' , ! ..... :' ' _. .. __ ........ ' ..... .. DROp 20-. PER I00' eooo~ . . i ; ..: . . -' i' eZS' IS APPROX. 800', BELOW. 6-26' ".'i _ % ...... , ........ :+ . !. !..~_;_.L_; ?URN.LEFT_i26._ . ' .... ~ ...... , ....... '. :-:-, ..... ~--~ .- .... DROP' --:- ' ' ~-" ~. ._ ~ ........ : :. ! ~. ! ...... ~ .: . _ . . ! , ] ......... . ~ : : I '" :'- -: '-q' - ; ' ' :-' :' *" - -I ...... "'·" _ . .: . . . ; ,._: {._' ............'! .; ; ..... Z ....... L ; .' .. ..' ...... ; ' ;_ :..; ...... - .'.iO,O00~'. . ' ._: , . .. ......... ;_: ....~_; ...... ; - ~_, ;_,_~ ............ . .... ~ .... ' ..... ....... ~ ........... !..\ .........._.' .'_! '. '__;_.i..,__~.;_.L_ _i._;_-;._; .: .... ~--'-.-i--"--~-.; ..... ; ....... _:_ __J__!__,_..'_; ...... :_ '._ ' ' ' ' \ _ ' ' ,;_' * ..~_ . ' '_! _:_.L.~ L!.!_;..:: , ~_ :_1 _ . .,h: .i .... '_' · -- '.. ;~-TARGET'_A'(.~OP-HEMLOCK)_.:. :_.~ L__:.!_; i l_Li_ .: .... ;.;.~ i ; ...... ;..: ..... -f ~ ~'-':.~::----~-TVD~9129i-TMD=IO,-334i DEP=4226 ~-i-;-~-g£~-rdA L:--; .... · ' ';'' ' ...... :- \' ~'-,"~'-i ,i'~ ! :--'-J i-;-:--..--i~ - i--'---~--'~-,,~:,~-'~P~_~_ .... : .. . ! i1~000,~,.. ~ i,- j , i ' I :, ' ~ ,. ',,', !~ ~. .... : ; . ! ..... ; - : . i ¢ ¢,"'- i' TD~ TVD=9718 TMD~II,O$$ 'DEP~4,.~7.SJ_~t,i-'~, ~.~.,... ,~ ' ' · . '.._ .: -:._'-.-~:.i__;__', _._i~_-__ ,--;_~ :i'_!.-,.:-~.~-i.-¢.;;-~8~-- ' .-_- :_ ' ': ' ' : ' ' ~ ~ ' ] : ~ : ' . ...... i. } ...... ' I I ' '; : . I ..... ' --" ....... :-'-':--"-i-" '~ .... ~-: ~'~a-0i~-~ r~.,, ,; · ---": .... ."~- :5000 4000' ;; "-' ' ' -; ' 5000' - ........... .... f- i .............. , , . ~i .... ',,,.¢~,.., bUDS-. , '~OI ('- ....... i - ....... : .... ~ .... : -i ~-- :- ~- :-', - -t ....... ; .... .,qp..¢, ': --;- -.- ~rrl,$~fO~ ..... G-4 IO, 164' To 9704, VD TO K-21 6-33 TO 10.790 VD I0t24.1 T( 12,900 VI' 96~9 G-32 TO il,670 VD 10~4-17 G-18 TO 6390 ;D 4'510 G-4 R 6-20 ~ TD 10,642 "~0 9719 6 il 1,072 10,5.1 Gm TO 10,156 I0 VD 10.029 G-6 RD TD 11/300 TO I O~ 4.00 VO 9815 et t ~X~. TD 11,4-50BHL: % VD 10,528 ,o ,o * RD2 G-II o ,o G-2 2 TO ,o, 8.s ,o~ ~ vo ~,o G-2 RD '--- 3 ~ T~ U,CSO' TO 11,335 J2 TO 10,800 ~V39698' VO 9983 G'34 VO 9734 TO / Iz~ VD 9825 ~ ~v :, ~ vD ~ D-7 R D '~o ,~ .~ ~'~ RD - vo eTD I1,1~0 VD 9711 11,025' TMD 97'18' TVD I¢ T/ HEML: ~o 10,370' TMD 9129' TVD 8RD TO 11.750 ~ VD 9857 11,820 ;"23 VD 9257 2,075 984-4 vo'::,,oo ......11 ~ Ufli~Jfl AlaskaOil & ~ ~ ~ ,PROPOSED I ' ~as C~n~ Com~ELL LOCATION I I ] AOL 187~cra:~ ""ss~lo~ OPERATED -- '~ g~ TRAD!~G BAY UNIT ~; McARTHJR RIVER FIELD VD 909~ II TO I ~ ": - ' : ': D-~6 ~, ~.~ G-3RD-2 ~c CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc L .... ~ ..... ~ i ~-~3 (2 thru 8) (3) Admin (9 thru 11) (4) Casg //Z~ I-I~ (12 thru 20) ( 5 ) B 0 P E ?//~/// /-/.~ -fi_? (21 thru 24) 2o 3. 4. 5. 6. 7. 8. 0 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is the permit fee attached ..,~ ....................................... YES NO REMARKS Is well to be located in a defined pool .......... Is well located proper distance from property ii~ ~]~]~[~]~ .... Is well located proper distance from other wells ...~ ................ Is sufficient undedicated acreage available in this pool .......... Is well to be deviated and is well bore plat included ......... ~.1.. Is operator the only affected party ..~ ...................... Can permit be approved before ten-day ~i; 1111 ..... Z ........ .. Does operator have a bond in force ........................ ~ ......... Ts conductor strin§ provided .............. Is enough cement used to circulate on conductor a~d surface ~ill cement tie in surface and i~termediate or production strings Will cement cover all known productive horizons ~i11 sur[ace casing protect fresh water zones ....... , Will all casing §ive adequate safety in collapse~ tension and burst,, Is thls ~ell to be kieked' off from an e×isting wellbore Is adequate ~ell bore separation proposed ................. '° ''' Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~-~ Does BOPE have sufficient pressure rating - Test to ply /API 3 (F 78) Does the choke manifold com w RP-5 eb .................... Additional requirements .............. ............................... Additional Remarks: Geology: Engineeri~ .ng JAL ~__~_~TM / rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. LVP OIO.H02 V'Et,'ilJ?ICATION I.~].ST:'II*i'G PAGE I ** INI-URIvAI, I,C~ R.ECL]R[;S ** 1C)N OIL COt~!Pgl~.'/ tJ G- 3P.P tt 2 a/4 i AS~A A !.,I N I q{" ] YPE O00 000 000 000 000 000 000 O00 000 000 000 O 00 0(30 00~) O00 OC O O03 O18 011 014 0O4 002 002 006 O06 0 04 CODE 065 065 065 065 065 O65 O65 065 0~5 Ir,Vp O~ O. t4(.)'2 'VgR[.F: IC~..1 ]'t}~i i:,I_STi,~ ;. P AG.., 2 RUN ~1, [AlE L~('."fiGE['.:':30:::~:PR :83 IRt!4 : 0.82 ~ tS DF i~l~'~F' = 0.65 ~8 62 DF h~C = 1.15 ~ 62 DF ~:F~. :AT:BHT = 0..335 fa 169: DF L, VP O!til) HO2 VERI]FIC~TI(3~ LIST.I'~,,~:G PAGE · ~ SCHI[.,,UMi}3E'F~(;;E[~, L,(,')3S ] ~CI.;t.~:DE )',': ~]"I"H 'r~.] S M,~[;NETIC tAP ,, '* ~ [)U~I. ].N[)UCT:ION SPHE~ICAI~I..,~ FO.CUSFP LOG :([.)I[.,'] ~' ~ (;ANNA RA.~ ~[CG (0[ :) ~ ,/~ P 1 ~ I L t!7. ,'-; I Z .*,,P R C} (..': Ii': $ S S/t td P L .,', ! ¢ E P P, L E V 'E I.,, C [3 D E 4 0 1 68 4 0 1 68 4. 13 I 68 4 0 1 68 4.: 0 I 68 4 '( i 68 0 0 0 0 0 0 0 0 0 1. 68 1 68 I 68 1, 68 ! 1:68 SP T H, O R NCNb tVRAT D EPT S P T C G.[{ NCNI, N R.A T' SP TtiO ,~ CGF N C N IL, D g P T SP NCNb NRAT SP T ~t 0 R CGi~ NCNb D EPT ,l!051 9~9 999 -999 999 I I. 000 278 52 '24 ~ I U900. 285. 9. 81. 2884. 2. t 0800. 246. 6 . 52. 41.44. 1. 10700. 207. 4. 38. 5,t92. 1. '10600. 0000 5FbU 4.5781 II.,D 7500 GR 64.0000 DT I 318 U R~i~ 1.4292 6328 NPt-4 t 27.9045 DRBO 3750 FCNL 1049.8633 CA[~I 6392 RN~A 2.74.6R 0000 SFLU 61. 9375 I L,D (;000 GR 37. 5000 [ T 2500 URAN 0.9003 Pf'tTA 687,5 ;l~PhI 11,B652 DRIiO 0000 FCNL 2458.0000 CAI, I 592~ RNAA 1 .6855 0000 SFLIJ 60.0625 1750 Ga 39.;';500 24:80 URAi'~ 1.5146 6895 ~h Pti I 8. 3824 7500 F'C ~ I.~ 3907.0000 30'~7 RNRA 1 .4053 0000 SFLU 56.1 B75 I!..,D 7. 2656 ],.b~ 14 5625 'fir 7 : 41'60 0.0942 ~I,,HOE 8 . 351. 6 8GE 4.6367 I l..,~a 77.375O 1 .~554 0.0395 8.9633 S(;14 32.7813 lbl~ 64.5625 0.0527 IF l'i[) B 9.2656 ,5GP, 47.3750 lt.,~ 64.5625 I .2096 .SSA 0.0680 )FHOB 8.5981 SGI~ 52.6875 -999.2)0 ) · 4c.:99. 2500: '999 ~500 -999 :: 500 -999.2500 6.8750 44.0000 53. 0000 2 5039 50.'750o 4.3906 64.0000 94,2871 2.5024 94.2871 26.1562 37.5000 59.7500 2.5840 59.7500 24.3125 39.750O 52.1240 2.6125 52.1.240 2(). 1562 l'-"]~ Jl i ! I i i 1 ii:-] i[~ [:.] i '} LVP 010 t~02 VEFrlFIC~q:Ii3N l,,.;l/,.,qll~;G PAGE 5 T lq t3 P, N C N L N [~ g T C G R I.)EPT SP T lq O 1~ CGR NRAT D ~; P T SP T ["!C !~ C (; R v,,CNL N}~ AT [) E [,: '.I' ~aC at., DEPT SP TIr~E p, C; NCNL DI/:PT S P C 4. 1602 I.i la/~ f,.~ .:. -; ~ 9': :9 4724,0000 F(.Nt 27.12.0:():00 C 4, 2 .: 71.: 88 ] [, D 4Q. 062. gl' 2~09:9'1 :P(')TI~ , 14,0930 DRt,~O 2726' 3750 C.a:bi 1.7855 0300.0000 ~EIU 13 8125 282.000(:) :(,: 7. 845 ? .45:90 2340,6250 [~C,N,L 806.7188 2.78.69 :PN~~:~ : :: '2,9010 I ? D D:'I' -, '][ C A.L, 10200.0000 $'FLU 14.7578 'llJI: 2 8 5 , 2 5 (, 0 G.R. ,~ 9 2 . 8 1 2 5 D T 1. 0 . '1 '121 l,J a.~ I~ 3 . 7483 t[ O'1' h 91.7725 .rg ?~t I 31.4850 Da. HU 2555. 3750 FCNI.., 8'32.5()00 C~LI 2. 9000 RNRh 3. 0693 10100.OO00 SKI U 14,5078 I. LD 244 , 6250 (;k 42 . 2500 DT 5 . {3,:} i ',3 IJ ~gt\~ ,9 . 4,785 PL)TA ]7. 8750 NPHI: 22.6074 DIsH 3954.00((1 ~CNL 1705.0000 CALl'. 2.2744 RN,Rg 2.'3184 10000.0000 SF[,U 99.4375 1. 1,1[ 182.00o0 (;R 41 .53! 3 DT 6.7266 l.l ~/4 r~ 0.280~ 1iOTA 53,3'150 NP~il 19,4336 D~BO 4.244,0000 FCNL 1964~( 000 C ~l,.I 2,0215 Ri~[t h 2,1602 990C. (: 0(() 5FLU 17.5781 l L 21 I. 6250 G.lq 40.0 ] 13 OT 4.6484 L.t ¢g i~ ,1 ,0684 Pttq'g 47,1~75 NPHI 19,0430 DP}tO ,3694,00(0 FCaL 1679.000(} CALl 1 ,9912 ~NF~ ?.lgq2 e5.5625 ,q~ * 1 2:: S 3:2. :78.13: l, .LN 69,0000 g 1'~ . ~ 207 SGI4 . 0235 1:~ i.i 0 B ,2 7 34 S (; R 74:562:5 GR' 2.081 '7 8 G F 0 '0:389 9 o 3125 11 .1094 69.0000 GR 2.3853 t~ 0.066 t~ R H IJ F, 9.33:33 SGR 13.0859 I 1..,~'~ R3.3750 1.4160 SGR 0.0347 ~ .3359 27.9062 :I l.,lV 78.0000 GR I..5137 t~O!' 0.0127 BH(IB 8 2:203 SGR 17.4063 70.3750 GR 1.7578 0.0322 ~.2656 .537' s .ooo i I' I 99 21. 5 ~. 21: ~ '1 ?1.54,69 40 062.. 58: 71:6~ 2.4990 58 ' 71, 6 8: 873 99.6680 2:.6016 99.6680 10.4219 '5 92.812 .... 124,9375 2.6~36 124.9 75 10.9766 42.2500 59.8437 2.41.99 59.8437 17.1562 41.5313 55.8750 2.4336 5." .'~. 750 13.7266 40.031.3 56.6250 2.4004 56.6250 SP 226o6250 GP;, : 89,93"15 D'I "!Fi{~R" 1.3,254.,4: bRAN' :: : :. 0'9"]65 :: POTA ,~Gl~ 105,9609 ~lx Phi }2,3074 D E ~':~ L) NCNL 2539':~/560 'FCNL: r,~ a h T 2.9560 .R N R A 3.0909 : : : ]: : ] : :. DE,''~' "PT~. 10.9922 ,IbN SP :: '76,:t875 I HL R, 10, B1 q5 UBA~ 2,3250 PorA NCN:[~ 3019,2500 FCNL 1. 123,5000 CALl 9. 7500 SGR O00 (,1 $ F tb U 126.4. 375 I L 1 : :'*:" ~ ' ~' ' ..... ) 1128 :'::URhN::' : · ::1']26~ P:OTA 5938 ~ P.H.~ 12. 3535 D[ I]U ~ N m ' ~ NCN[., t62~.0000 [C 1~ 27~4. 0000 GALl C (,,R NRAT DE:PT NCNL N t] A T SP CGR NC[qb NRAT D EPT S P '1' HOE CGR NCNB NRAT D E P T SP C 1,.590B RN~A. 1.6'738 9~500,0000 SFLU 1. 8,6563 ],bD -tr' 7~, 000 ., ; .... ~ ..... ~ "] · 10,1641 UR. AN 2,8965 [ ~,,, TA 86,0625 :{~PH] 45,0195 2'70,0000, GR 6,9531 65,b907. [iXPBI , 2954 · :3750 FC N 1,, 2°8864 9300 0000 255,: 750() 8.2905 69 · 7500 1.590. 0000 3.4961 UBAN l\PHl FCN L RNRA 9200,0000 255.3750 4.9531 53.1875 4048.0000 2.1074 SFLU URAN ~I', F't't I. ~ CNb 91 O0. 0000 244. 7500 9.4.688 '78. 3750 SFL GU U P, A il", PB .[ C A b 1, I1 63.0313 [:I' 2 - 21.02 P 0 '1' A 30 . 1220 942,3750 CALl 3,1348 10. 6563 l I.,D 60.3125 'IT 1., 251.0 P[)TA 4.1 .0156 DRHO 44:9.7500 CALl 3,5439 I 3,1 328 ILD 41.2187 l/qt' 0,7939 POI'A 20.6055 1808.0000 2.2383 7.5~98 66 .'1 875 [ T 2 . 3418 POTA 29.2480 1.6.734:4: :I[.,N 56. ~oo ' t - 157:~: ' 804:7:': 1.4. 3828 lbM : 9 O:. 3750 ~(:R 2.0996 LS,7, F 0.0610 II:::}~OB 9.7031 11.91.41 Ib~, 11.1.0000 '6 Ia 1.9531 0.1.978 111-t0t3 10.1250 SOB I ].4844 IbN 83.7500 'fib I .9043 Sg}~ 0.0269 }} HOB 8.4297 SGR 7.7891 I [,¢,; 7,(..7500 '(-R 2.1 4[.t4 S~lq 0.0391 It, HOB PA GE:: : 6 10.5781, 2,5529 I 1, 4. 2509 2~, 5:9:86 1,11 .8516 1,9.2656 .3438: 2 7852 56 ~ 3438 96~7 S 6 2: s 1,.}::~5oo656 7500 7.3594 63.031,3 85. 281.3 2.5782 85,2813 11.6953 60,3125 80,8281. 2,4786 80,8281 9.9453 41 ,2187 60,21.87 2,394.5 60,2187 6.5156 66.1875 99.1250 2.5313 , "h"' ..... ~'~ ....... PAGE; 7 LVP 0'!O.H02 VERII,' lC I.I,U:, LISI N C N L, D E P T SP THOR C: G }{ N H..A T 0 Ei¢ T SP '1: t~ (".t R N C N L O E P T SP NCI~ I., D 1~,: P T SP T H O t:~ CGR N C N L NRAT D E: P T SP TH 0 R C NCN[, b~ 14 A T [)EP T 8P T H U R C G R a R A T 1) I/.'.:; P T SP THUP !~C.~ L 21,34 . 0000 ,FC t~l 2' -7 383 RNRA tc05 50C0 CALI. .7 ~6 !~ 9.'C 781 8 d i-t. 1~1 .9609 I 1.~[; a. 3., 72 I1, 2461 : 29. 1504 l)~['{[) O. 0664 ~BCIH 907.0000: CA:I.~I 9.9062 :SGR 2. ~ 13 8900.0000 SKtLI 10.?~,422: .81,~2 LIR~ 1~ :2 .4676 F'L, I g 8~. 6641 NPH I 29,2656 DR:HC.] 2466.1250 FCNL 844.6250 CALl 2.'78! 7 RNR~ '2:. 9193 880o.0000 SFLU 1:2.45..:11 :'ILL[ 230.5000 9 84. 6875 NP~'~I 53. 8086 D~HO 1953,000o FQD:L 4~6. 2500:: (~I.,I 4,1992 RNFA 4.5781 8'?00.0000 $1FLU 11.5078 ,l 235.3750 (',; 14 85 ' 7500 IT'> 7~ 11,4609 UH~.N ~7.7 363 ~PHI ~39. 3750 FCNL 838Pz9~2 CALl 3.0197 RNRa 3.1474 860£ .tO0( 0 SFI. U 2(70C .0000 I.I,D 259.7500 GI4 20.0938 D'I' 3.1855 IJRAN ,].0771 POTA 18.8516 .NPH i. 65.0330 DR.F~O 32~. 375 0 FCNL ~54. 3750 CA.bi 4.9640 RNF:A 5,2026 8500.0000 fiE[ U 8.5625 I'Ll) 235.2500 GR 34.2813 DT 4.07(3 URAN 'C.4814 POTA 46.6~75 NPHI 22,'1680 DRHO 3786.00( 0 FCNL 1654.0000 CALl 2.1973 RNRA 2.287! 8400.0000 SFLU 94.8125 It.;[ 245,1250 Git 38.0000 DT ,3.1484 IJH~N ~g' log POTA 27.15b2 NPHi 72.4121 1371.000() F'G}~L 262.0000 CAI, I 5.1797 RN~A 5.23n5 8300.0000 206. 7500 GR 73. I 875 DT 30.1562 127.3750 o .5825 SGP -0.041 3 14HOB t4.0859 8.6563 88. 3750 (;P 1.5625 $ (.; P, 0.0264 RHOB 8.2422 8GP 30 . (.) 1. 56 L.I bl~ 127. 7500 (;F 0.4883 8GR 0.0127 Ri'lOB 9.4141 ',~ 0[, 6.9883 '11.,~,' 82.1875 99J12.~0 7.5703 86.5000 114.8125 i 14~ .5996 .81, 2:5 9922 2, 5234 1. 0 ~5704: 107. 5234 ~,0313 80.312,5 1,05.7500 2.246!. 105'7500 9,2969 85.7500 5:997 1 :~1,". . 5205 26.7969 20.0938 28.3906 1.3622 28.3906 7,2930 34.2813 50.9375 2.3887 50.9375 41.4063 38.0O0O 51.1562 1.5039 51.1562 5.8359 73.1875 [) E'; P T SP CG~ N C N L t,1 ~ A T D E P T T CGR tO C N [, N~AT I,) E P T 8P T H 0 R CGR NC N L BRAT D E P T SP T H O R C (;1~ N C N b 1~ R g T D F P T SP C DEPT SP HOP, CGF C N h I.~ BP1' SP '[ .H 0 R CGR NCNB NEAT C ~ b I 100,0000 SFLLi I 5,8 a28 11.It, 33,5625 K I 249. 375() GR '" 3.1084 U~At',~ 1,0718 P .... !.A 35.531 3 :: tiN:PHi 1:4,6:130 DF, HF~ 457. 0625 FCN,b 246:7.81 25 CA LI, ~ .?059 RN~A I.a056 7900,000 D SFLU 286,250o , GR .10,18113 'I,t R g, N 66,2109 :~P:['~I. 2501.5000 FCNL 3,0205 LF ~[ A (~ 910~ II..D 6 ' 3:12 1: T . , 3247 P 0 T A 3 . 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