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200-087
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. (~YD_ - ~ ;Z Well History File Identifier RESCAN D Color items: ~'~ .... - ~,.~,,~ysca~e items: Poor Quality Originals: [] Other: DIGITAL DATA ~ Diskettes, No./ [] Other, No/Type TOTAL PAGES: ~(~ ORGANIZED BY: NOTES: BEVERLY BREN~SHERYL MARIA LOWELL OVERSIZED (Scannable) [3 Maps: D Other items scannable by large scanner OVERSIZED (Non-Scannable) [] [] DATE;/~,,.-/ Logs of various kinds Other Isl ~ Project Proofing PROOFED BY: BEVERLY BREN~HERYI. MARIA LOWELL [] Staff Proof By: Date: IS~ ~ PAGES: ,~ (at the time of scanning) SCANNED BY.' BEVERLY~ VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) RevlNOTScanned.v4xl OF 77.4, • • 6 0. *\ y /,s THE STATE Alaska Oil and Gas �'�V �_� ✓Aim 9� O T . f�LA�� Conservation Commission OF T P GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 �Q� 1 8 ]���I SCANNED M G Chad Helgeson Operations Engineer p — Hilcorp Alaska, LLC •*., d 0 O 7 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 42 -04 Sundry Number: 313 -096 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ca by P oerster 1/14 Chair DATED this /(-1- a y of March, 2013. Encl. ar � R � I STATE OF ALASKA 3� f- EB 2 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION ( P 7 5 3 (- APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill 0 . Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development 0 . Exploratory ❑ 200 -087 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50- 133 - 10109 -01-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership cianges: ❑ Soldotna Creek Unit (SCU) 42 -04 • Spacing Exception Required? Yes 9. Property Designation (Lease Number): 10. Field / Pool(s): Soldotna Creek Unit (FEDA028997) • Swanson River Field / Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,901 10,379 • 10,901 10,379 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13 -3/8" 3,000' 3,000' 2730 psi 1,130 psi Intermediate Production 10,168' 7" 10,168' 10,168' 6340 psi 3,830 psi Liner 831' 3 -1/2" 10,898' 10,379' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Surface to See Attached Schematic See Attached Schematic 4 -1/2 ", 3 -1/2" L -80 10,070'; 10, 070' to 10,095' Packers and SSSV Type: ZXP Liner top packer w /6' x .25" tieback Packers and SSSV MD (ft) and TVD (ft): p p 10,095' MD / 10,095' TVD sleeves 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development 0 • Service ❑ 14. Estimated Date for March 23rd, 2013 15. Well Status after proposed work: Commencing Operations: Oil , ? Gas ❑ WDSPL ❑ Suspended [���9 ii 16. Verbal Approval: Date: WINJ ❑ �4 G INJ ❑ WAG ❑ Abandoned ❑ �` Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson 777 -8300 Printed Name Chad Helgeson 777 -8300 Title Operations Engineer Signature i9 . / /.. //� Phone Date /' Vi 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 515 -09 C 7 Plug Integrity ❑ BOP Test 4/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4. 3 D p s wTG l e rG . r / a l eo ?PAY` Z 0 CV"i , Lam- (f C- C. ) 300 dos.. CQ.s,. -3 -f-4.4.-- RBDMS MAR 15 2O1 Subsequent Form Required: 1 p — y o - 7 - - APPROVED BY Approved by: G , ! f COMMISSIONER THE COMMISSION Date: 3 , ci.,' y_5 O i\11V .NA 3 (z�3 . Submit in Duplicate �� • • Well Prognosis Well: SCU 42 -04 Hilcorp Alaska, LL Date: 2/21/13 Well Name: SCU 42 -04 API Number: 50- 133 - 10109 -01 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: March 23rd, 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 200 -087 . First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: Pending Current Bottom Hole Pressure: - 2,500 psi © 10,379' TVD Maximum Expected BHP: - 2,500 psi @ 10,379' TVD (Based on offset well pressure surveys) Max. Allowable Surface Pressure: -1463 psi (Based on pressure gradient of 0.1 . psi /ft of TVD) Brief Well Summary SCU 42 -04 has been identified as a candidate for re- drilling. The new wellbore will utilize the existing casing program down to 9600' MD/TVD. The well will be sidetracked at 9600', and target the Hemlock formation to the South. The new well will be called SCU 41A -04. The purpose of this work /sundry is to abandon the current productive interval and prepare the wellbore for redrilling operations. A 10 -401 PTD application is also attached for the drilling & completion of SCU 41A -04. Notes Regarding Wellbore Condition BwF • Current well status is a producing oil well on gas lift (564 water, 24 bopd oil). Brief Procedure: 1. RU slickline, RIH and pull orifice on bottom gas lift mandrel at 9,950'. 2. Set PX plug in X- nipple at 10,101'. 3. MIRU Williams Rig on SCU 42 -04. 4. Notify AOGCC 24hr in advance of BOP testing. 5. Fill productionannulus with produced water, circulate through gas lift mandrels and up tubing to kill well. 6. Install & test BPV. ✓ �' °"� hc- 7. N/D tree. 8. N/U and test BOP test same to 250psi low /3,000psi high, annular to 250psi low /1,500psi high. 9. Pull tubing hanger & seal assy (do not exceed 75% of the tubing string weight). L/D hanger, 4 -1/2" tubing, and 4 -1/2" seal assy. 10. Make GR + CCL logging pass. 11. RIH with cement dump bailer and dump bail 2 bbls of cement, on plug (61' from 10,101' to 10,040'). (Waiver required from 20AAC25.112(c)(1) &(2)... for the distance from hydrocarbon bearing strata because of the 3 -1/2" slotted liner.) Wait on cement, RIH and tag top of cement in 7 ", should be at 10,040'. 2 pit- Cic c� 3 12. Pressure test plug and casing tosi for 30 min with ppg PW. 13. RIH and set CIBP at - 9625' MD. (depending on gamma /ccl log). CvoG1f �5 was 6 po0, ✓ we `l (ro- Ike S'ti'r w, i ®a "'r c ,)• L T «"d P o ctC e q f4-p f ' /7 a 007- S lyG iva . kir grfe,,1(T ar` ro ,,,et✓�l Zo 9 � � l / w'al�� Qvj. (fie � � 4 /00/, 429/e. ' ffc'e 'nj / 4,5" we'd Shay � r , i /V -e C O . Ai �, % /�j • • Well Prognosis Well: SCU 42 -04 Hilcorp Alaska, LL Date: 2/21/13 14. N/U dry hole tree. RDMO Williams rig Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics 1. • • Swanson River •---n _. SCHEMATIC Well SCU 42 -4 Hilcorp Alaska, LLC _ .. Plugged and Abandoned - CASING DETAIL ]I1 -'T -I L.- SIZE WT GRADE CONN ID TOP BTM. 22" 22' 1t- 13 -3/8" 54.5 J -55 8rd /ST &C 12.615 Surface 3,000' 29 N -80 Buttress 6.184 Surface 304' :Im , 1•11 26 N -80 Buttress 6.276 304' 1,235' IP - 23 N -80 Buttress 6.366 1,235' 4,229' t.:, ` >ti 7" 26 N -80 Buttress 6.276 4,229' 4,527' RKB = 17. - � - 29 N -80 8rd LT &C 6.184 4,527' 6,489' 26 P -110 8rd LT &C 6.276 6,489' 9,346' 29 P -110 8rd LT &C 6.184 9,344' 10,992' 3 -1/2" liner 9.2 K -55 Hydril 511 2.992 10,067' 10,898' slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row TUBING DETAIL 1 ciBP 9l,2S , Jewelry Detail 2 NO. Depth ID OD Item 1 9,625' - - CIBP 2 10,040' - - 2 bbl cmt plug from 10,040' to 10,101' 3 3 10,095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 3a 10,044' 4.44 5.88 Baker HMC liner hanger 3b 10,051' 4 5.63 Seal Bore Extension 3c 10,067' 3.44 5.5 KOIV flapper, 3.437" ID after flapper knocked out 4 10,101' 2.81 4 X nipple, with plug set. 4 5 10,181' Baker Bottom Trip Whipstock 6 10,192' 7" cement retainer 7 10,898' 2.99 3.5 3 -1/2" liner shoe i G2 8 10,202' 3.88 5.97 Baker SABL -3 7" x 4" ,, \� 9 10,485' Baker Model "F" ,, N Fish Chemical gun /CCL 13' long , ss 5 s, Kick off Point @ 10,168'- 10,181' 6 Hl H2 MD 10,901' ss H3 - -_ • H5 8 I C TD = 10,901' MD/10,379' TVD . ° " 1 `i 2 ' MAX HOLE ANGLE = 91.34 deg 7 DO - PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G -2 10,147' 10,167' 10,147' 10,167' 20' 6 Behind 3 -1/2" liner 5/30/1996 9 1 C Window cut through G -2 10,177' 10,184' 10,177' 10,184' 7' 6 perfs 5/30/1996 H -1 10,226' 10,227' 10,226' 10,227' 1' 5 Squeezed WSO 3/11/1960 H -1 10,230' 10,265' 10,230' 10,262' 35' 8 Squeezed 7 -25 -00 11/13/1977 H -2 10,275' 10,285' 10,272' 10,280' 10' 8 Squeezed 7 -25 -00 11/13/1977 H -3/4/5 10,310' 10,394' 10,301' 10,352' 84' 4/8 Squeezed 7 -25 -00 11/13/1977 - 10,402' 10,403' 10,356' 10,356' 1' 5 Squeezed 3/11/1960 wall+" H -8 10,409' 10,478' 10,358' 10,369' 69' 4 Squeezed 7 -25 -00 3/17/1960 10,992' ` H -10 10,508' 10,585' 10,369' 10,368' 77' 4 Squeezed 7 -25 -00 3/17/1960 10,598' 10,599' 10,367' 10,367' 1' 5 Squeezed WSO 3/11/1960 - 10,600' 10,601' 10,367' 10,367' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' N/A N/A 1' 5 Squeezed Old 3/11/1960 Wellbore 11,315' Drawn by: LDD Edit by: LEK 2/21/2013 • • Swanson River ..., n __:_.. SCHEMATIC Well SCU 42 -4 Existing Welibore ✓ Hilcorp Alaska, LLC ... . . ` CASING DETAIL J _ Im 10•I SIZE WT GRADE CONN ID TOP BTM. 22" 22' CIF-. --' 13 -3/8" 54.5 1 -55 8rd /ST &C 12.615 Surface 3,000' 29 N -80 Buttress 6.184 Surface 304' ( 1� , -I 26 N -80 Buttress 6.276 304' 1,235' - - 23 N -80 Buttress 6.366 1,235' 4,229' `�.,`, i 7" 26 N -80 Buttress 6.276 4,229' 4,527' RKB = 17. ' 29 N -80 8rd LT &C 6.184 4,527' 6,489' 26 P -110 8rd LT &C 6.276 6,489' 9,346' i 1 1 29 P -110 8rd LT &C 6.184 9,344' 10,992' 3 -1/2" liner 9.2 K -55 Hydril 511 2.992 10,067' 10,898' slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row TUBING DETAIL 2 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 10,070' 3-1/2" 9.2 L -80 Buttress 2.992 10,070' 10,095' Jewelry Detail 3 NO Depth ID OD Item 1 15' - - Tubing Hanger, 7- 1/16" x 4 -1/2" 8rd., Type" H" BPV profile. CL prep. 2 2,250' 3.813 5.591 4 -1/2 Camco BP -61 LANDING NIPPLE for methanol inj. with 3/8" control line strapped w/168 x1 -1/4" SS bands in 4 -1/2" GLM Camco KBG -2 with 1" KB2 top lock valves 4700' 4 1 Gas Lift Mandrel .. 3 6800' 3.866 5.984 4 2 Gas Lift Mandrel 4 --m-• 8700' 4 3 Gas Lift Mandrel 5 9950' 4 4 Gas Lift Mandrel 4 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 4a 10044' 4.438 5.875 Baker HMC liner hanger 6 ] 5a 10,051' 4 5.625 Seal Bore Extension IN 5b 10,067' 3.437 5.5 KOIV flapper, 3.437" ID after flapper knocked out 6 10,101' 2.813 4 X nipple, 2.813" ID i 7 10,181' Baker Bottom Trip Whipstock ' , �� G2 8 10,192' 7" cement retainer % 9 10,898' 2.992 3.5 3 -1/2" liner shoe � �% 10 10,202' 3.875 5.97 Baker SABL -3 7" x 4" %% ‘ 11 10,485' Baker Model "F" \ . s Fish Chemical gun /CCL 13' long s s . 7 H1 Kick off Point @ 10,168'- 10 MD 10,901' 8 H2 H3 • H5 10 I TD = 10,901' MD/10,379' TVD L IZ- ° L ' t MAX HOLE ANGLE = 91.34 deg 9 1 D' - J PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G -2 10,147' 10,167' 10,147' 10,167' 20' 6 Behind 3 -1/2" liner 5/30/1996 11 I 1 Window cut through G -2 10,177' 10,184' 10,177' 10,184' 7' 6 perfs 5/30/1996 H -1 10,226' 10,227' 10,226' 10,227' 1' 5 Squeezed WSO 3/11/1960 H -1 10,230' 10,265' 10,230' 10,262' 35' 8 Squeezed 7 -25 -00 11/13/1977 H -2 10,275' 10,285' 10,272' 10,280' 10' 8 Squeezed 7 -25 -00 11/13/1977 H -3/4/5 10,310' 10,394' 10,301' 10,352' 84' 4/8 Squeezed 7 -25 -00 11/13/1977 10,402' 10,403' 10,356' 10,356' 1' 5 Squeezed 3/11/1960 4 - * H -8 10,409' 10,478' 10,358' 10,369' 69' 4 Squeezed 7 -25 -00 3/17/1960 10,992' H -10 10,508' 10,585' 10,369' 10,368' 77' 4 Squeezed 7 -25 -00 3/17/1960 - 10,598' 10,599' 10,367' 10,367' 1' 5 Squeezed WSO 3/11/1960 - 10,600' 10,601' 10,367' 10,367' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' N/A N/A 1' 5 Squeezed Old 3/11/1960 . Wellbore 11,315' Drawn by: LDD Edit by: TDF 8/22/2012 A ' ... • • Swanson River SCU 42 -04 02/21/2013 Hilrnrp \lu•la. i.1.(. Swanson River SCU 42 -04 Williams BOP 2013 ,ate • . • I I I III h u h I III III III III I 3.46' Shaffer 1 11" 5M 11i1 Ill iii iii ill a , e. , Shaffer LWS ®® ; • ® - v • - 2.75' _ 11 5M _ _� 2 1/16 10M Choke and Kill �� ��" Valves ; III III 111 III III • *� . �. . �. 200 r.. . i i I I CJ 7 !1 ' .C4� 7 i Ii �� Ili I 111 I l u l ' 41 f11 111111111 1!f X 2.00 7 5M g , Ilir ......„ . 111 ii 1I,- li i i .1111A", 0 ::: I _ 1 II. I iO,:: pell e FI] 1 1Q1 I III ir N O I !_i ' III i -L. M me' • • Page l of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 / form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, March 07, 2013 1:45 PM To: 'Chad Helgeson' Subject: Sundry Application: SCU 42 -04 Chad, I noticed on the Sundry Application for SCU 42 -04 that you used an obsolete form. In the future please use revised Form 10 -403, which is available online at: http: / /doa.alaska.gov /ogc /forms /forms.html. Please make other Hilcorp engineers aware of this form revision. Thanks, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907 - 793 -1224 Fax: 907 - 276 -7542 1 Davies, Stephen F (DOA) From: Luke Keller[Ikeller @hilcorp.com] Sent: Tuesday, February 26, 2013 4:19 PM To: Davies, Stephen F (DOA) Subject: RE: SCU 41A-04 Surface Location Attachments: SCU 42-4 (NAD27).pdf Steve, We had McLane Consulting, Inc resurvey the well recently and this is the new survey data that was given to us: 961' FNL, 1127' FEL, S. 4, 7N, 9W,SM. It is different from what we had on file as well. Attached is the survey from McLane. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 SCANNED JUL 2 9 2013 From: Davies, Stephen F (DOA) [mailto:steve.daviesCalalaska.gov] Sent: Tuesday, February 26, 2013 3:05 PM To: Luke Keller Subject: SCU 41A-04 Surface Location Luke, Could you please check the surface location of 41A-04 for me? Hilcorp's permit to drill lists the location of the parent wellbore SCU 42-04 as being 961' FNL, 1127' FEL, S.4, 7N, 9W,SM. AOGCC's database and the well completion report for SCU 42-04 list this same surface location as 1000' FNL, 1170' FEL,S. 4, 7N, 9W, SM. Thanks, Steve Davies AOGCC 907-793-1224 1 2- 7 • • 0 100 r I 200 I ' SCALE I SECTION CORNER COMPUTED NORTH FROM CYQ S5&WCMC S33/S4) 33 34 4 3 N 2461154.123 I E 347629.593 / AS-BUILT LOCATION WELL SCU 42-4 N:2460223.814 E:346506.271 ♦ ���N\1 LAT:60°43'52.634"N ♦ Q F.q J\ LONG:150°51'27.010"W � '.......�qs �I \ -J ASP ZONE 4 NAD27 (0P. )' •'�y�/ \ z FEL=1127' *:'49� /\ */0 FNL=961' I� A % \\ ELEV=173.7'(NAVD88) / '•,STAN A. McLANE i SECTION 4, \ — T7N,R9W,SM,AK /I 4637-S \ /la .. elY-.9. FEL 112 ih / // ® I V \/ , I \ _ \ \\_ ��� 1 \ \ \ \ \ \ \ - \ \ \ \ \ \ \ \ \ \ \ \ NOTES 1)BASIS OF COORDINATES:NGS OPUS SOLUTION FROM CORS "ZAN1","TBON"AND"TSEA"ALASKA STATE PLANE ZONE 4 NAD83 EPOCH 2003. 2)BASIS OF ELEVATION:NGS BM 079 RESET 1991 NAVD88. 3)SECTION LINE OFFSETS COMPUTED FROM BLM CORNERS FOUND ALONG NORTH BOUNDARY OF S4 USED TO COMPUTE `EAST BOUNDARY OF S4 SHOWN. SCU 42-4 AS-BUILT SURFACE LOCATION (NAD27) SWANSON RIVER FIELD LOCATION: SECTION 4, TOWNSHIP 7 NORTH, / ENGINEERING-TESTING RANGE 9 WEST, SEWARD MERIDIAN ALASKA // SURVEYING-MAPPING llilc�e>rl►Alaska,1.1,C P.O.BOX 468 M . SOLDOTNA,AK.99669 JOB NO. 133008 VOICE:(907)283-4218 FAX:(907)283-3265 DWG. CannulbirgInc WWW.MCLANECG.COM 133008 I Date: 2/11/2013 FIGURE: 2 ALI" OIL AND GAS CONSERVATION COMMISSION R E C E' V E D REPORT OF SUNDRY WELL OPERATIONS SEP 0 7 2012 1. Operations Abandon U Repair Well U Plug Perforations ❑ Perforate 11 Oth -1 6 Gee ci ty String Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension Ill �..��ttv�Vs► Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development El Exploratory ❑ 200 -087 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service ❑ 6. API Number: Alaska 99503 - 50- 133 - 10109 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 Soldotna Creek Unit (SCU) 42 -04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,901 feet Plugs measured N/A feet true vertical 10,379 feet Junk measured N/A feet Effective Depth measured 10,901 feet Packer measured 10,095 feet true vertical 10,379 feet true vertical 10,095 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13 -3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 10,168' 7" 10,168' 10,168' 6,340 psi 3,830 psi Liner 831' 3 -1/2" 10,898' 10,379' Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic MD TVD 4-1/2" L -80 10,070' 10,070' Tubing (size, grade, measured and true vertical depth) 3 -1/2" L -80 10,070'- 10,095' 10,070'- 10,095' ZXP Liner top packer w/6'x.25" Packers and SSSV (type, measured and true vertical depth) tieback sleeves N/A 10,095' MD 10,095' TVD 12. Stimulation or cement squeeze summary: N/A SCANNED MAR 0 4 2013 Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 650 Subsequent to operation: 0 0 0 20 1000 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. la 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 -269 Contact Chad Helgeson Phone: 907 - 777 -8405 Printed Name Chad Helgeson Title Operations Engineer Signature � � Phone 907 - 777 -8405 Date 9/7/2012 RI SEP 102012c0. V1F 'Z Ard °7M Form 10 -404 Revised 11/2011 g l V1 ( Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 42 -04 50- 133 - 10109 -01 200 -087 7/27/12 8/8/12 Daily Operations: 7/27/2012 - Friday RU slickline lubricator. PT to 250 psi low and 2,500 psi high. RIH with 1.30" GR and set down in XN nipple at 10,439' RKB SLM. POOH. RIH with braided line brush and brushed XN nipple at 10,439' RKB SLM. POOH. RIH with XN plug and set plug in profile nipple at 10,439' RKB SLM. POOH. RIH with plug prong and set in plug at 10,439' RKB SLM. POOH. RD lubricator and secure well. 7/30/2012 - Monday Put pit liner down for containment for tanks. Spot coil equipment from SCU 22 -4. Finish RU Wed morning. 08/01/2012 - Wednesday Mobe to location. Finish RU. Pull test coil connector to 25k. Test BOP to 250 psi low and_3 500 psi hghjWitnessed by,kou GrimaIdi witness waived by Jim Regg, AOGCC). Plan on latching velocity string in the morning. Pick hanger up far enough to close rams on coil tubing and bleed off coil to make sure plug is holding. Well has 650 psi on it. Once we verify plug is holding, plan on pumping down the back side and kill well. 08/02/2012 - Thursday Mobe to location. Put GS tool on coil. Latch velocity string profile and pick up to 20K. Work way up to 40K and wt dropped down to 36 -38K. Picked coil up approx 3' and wt went to 40K and parted just above the dimple coil connection. Waiting for overshot and crossovers. RIH and tagged fish at 65.4'. POOH. Overshot assy was shipped from the slope today that will be here tomorrow. 08/03/2012 - Friday Mobe to location. PT lubricator to 250 psi low and 3,000 psi high. RIH with 1 -3/4" overshot and catch fish at 66.4'. POOH with GS tool assy. GS tool had 7 of the 10 dogs broke off. Waiting on magnets and a 3 -1/2" GS tool. RIH and latch into velocity string profile with a 3 -1/2" GS tool. Pick wt up to 15K. Pump 137 bbls of produced water down back side. Annulus had 655 psi on it. After 55 bbls annulus pressure was at 0 psi. Continue to pump at 3 bbls per min. Pick up to 20k and pull velocity hanger assy into lubricator. Monitor well for 30 min. Shut in pipe rams and pipe slips. WHP was at 0 psi. Unscrew bowen connection and started to strip off assy and had some fluid coming out of lubricator. Sat lubricator back down and tighten connection. Ran 1/2" hose from kill port on bop to choke manifold and monitored stream of fluid coming out. Closed blind shear rams. Confirmed we had a positive seal from the well bore and bled off lubricator and unstab lubricator. Found that we had cut the oring on the bowen connection. Put night cap on and secured well. After 3 hrs WHP climbed up to 800 psi. • 08/04/2012 - Saturday Mobe to location. RU lubricator and PT to 250 psi and 3,000 psi high. Put coil connector on and test pull to 15k. Velocity string pressure was 1,045 psi and annulus was 50 psi. Bled velocity string down to 0 psi in 30 min and monitored well for 2 hrs. Put overshot assy on coil. Pumped 5 bbls of produce fluid down velocity string to give approx 1,000 psi hydrostaic. Latched onto fish and picked up to 25k to move velocity string. Pulled fish into lubricator and monitored well for 45 min. Cut overshot assy off coil and put cold roll on. Cleaned gripper blocks and pull coil from 10,323' tp 10,058'. Pumped 60 bbls down back side to try and help pull string. Pulled up to 32k trying to get thru. Worked coil up and down and pulled it thru bridge. Pulled velocity string from well_. Coil tubing counter read 9,829' but got all the string out including BHA. Had depth counter slipping due to heavy paraffin. Secured well. Cut velocity string off BHA. 08/05/2012 - Sunday Mobe to location. Late start. Stab injector head on well. Air liquid arrived with nitrogen. Filled 3 SLB N2 tanks. Cool down N2 and blow down reel. Recovered approx 12 -15 bbls of fluid. Unstab from well and coil from injector head. Changed packoffs and RD pumping iron from reel and hyd lines. Pulled velocity string reel from unit. Unloaded work reel and backed up to unit to Toad on and gin pole truck broke down. Will double check the load limit and certificates of the rigging equipment of gin pole truck in the morning. 08/06/2012 - Monday Inspected gin pole truck per Hilcorp safety man instructions. All checked good. Picked work string reel and set on SLB coil tubing truck. Pin reel and hook up hoses. Finished RU and pull tested connector to 15K. 08/07/2012 - Tuesday Cut coil connector off and put motor and mill assy on coil. Pull tested to 15K. Fill coil tubing work string with produced water and pressure test lubricator to 250 psi low and 3,000 high. It was 2 -1/8" motor and 2.78" 5 bladed mill. RIH w/ 1 -3/4" coil and at 2,200' noticed steel shaving falling out of injector head. SD and checked coil. Shaving was .025" thick and about .25" wide. RIH to 10,000'. Tried to break circulation with 400 scf N2 at 3/4 bpm. Couldn't get returns so started coming up hole pumping with cir psi at 1,556 psi. Got to 3,690' and got returns of mainly N2 with 600 scf and 1/2 bpm fluid. Circ pressure was 2,232 psi and WHP was 200 psi. Went back down pumping and at 10,011' lost fluid returns and was getting very little N2 back. Went down and tagged at 10,393'. Pumped a 50 bbl gel sweep. Had to pull up to 30k and work thru tight spot by moving coil at 65 fpm. Started back up hole slowly trying to get returns but hadn't got them by 8,800'. POOH. Strapped tank and had got only about 5 bbls back in return tank. Pumped approx 165 bbls & 3,500 gal N2. Rig lubricator off well. Break Weatherford tools off line. Secured well and clean up area. 08/08/2012- Wednesday RU coil lubricator and pressure test to 250 low and 3,000 psi high. Put 1 -3/4" jet nozzle on coil. RIH down to 10,000'. Started pumping n2 at 400 scfpm and tried it from 400 to 1,100 scfpm. Ran coil from 10,000' to 9500'. WHP was 52 psi with circ rate going from 600 up to 100 psi and then drop back down again. It would rise and fall. Never got any fluid back. POOH, at 5900' started getting wet paraffin. Back to the rain for rent tank. Rig lubricator off well and secured well. .. 11 • Swanson River SCHEMATIC Well SCU 42 -4 Hilcorp Alaska, LLC .. CT Velocity String Completion mial � CASING DETAIL ]rlim 'r _ ■I SIZE WT GRADE CONN ID TOP BTM. 1 . 1 22" 22' OW- '- ' 13 -3/8" 54.5 J -55 8rd /ST &C 12.615 Surface 3,000' 61*111011 29 N -80 Buttress 6.184 Surface 304' 26 N -80 Buttress 6.276 304' 1,235' 23 N -80 Buttress 6.366 1,235' 4,229' 7" 26 N -80 Buttress 6.276 4,229' 4,527' RKB = 17. - - 29 N -80 8rd LT &C 6.184 4,527' 6,489' i 1 1 26 P -110 8rd LT &C 6.276 6,489' 9,346' 29 8rd LT &C 6.184 9,344' 10,992' 3 -1/2" liner 9.2 P -110 K -55 Hydril 511 2.992 10,067' 10,898' slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row TUBING DETAIL 2 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 10,070' III 3 -1/2" 9.2 L -80 Buttress 2.992 10,070' 10,095' J ewelry Detail 3 NO. Depth ID OD Item 1 15' - Tubing Hanger, 7- 1/16" x 4 -1/2" 8rd., Type" H" BPV profile. CL prep. IMI 2 2,250' 3.813 5.591 4 -1/2 Camco BP -61 LANDING NIPPLE for methanol inj. with 3/8" control line strapped w/168 xl -1/4" SS bands M I 4 -1/2" GLM Camco KBG -2 with 1" KB2 top lock valves 4700' # 1 Gas Lift Mandrel 3 6800' 3.866 5.984 # 2 Gas Lift Mandrel 4 _ MI _ 8700' # 3 Gas Lift Mandrel 5' 9950' # 4 Gas Lift Mandrel 4 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 4a 10044' 4.438 5.875 Baker HMC liner hanger 6 5a 10,051' 4 5.625 Seal Bore Extension 5b 10,067' 3.437 5.5 KOIV flapper, 3.437" ID after flapper knocked out 6 10,101' 2.813 4 X nipple, 2.813" ID 7 10,181' Baker Bottom Trip Whipstock ' 1 1 G2 8 10,192' 7" cement retainer %, \ 9 10,898' 2.992 3.5 3 -1/2" liner shoe 10 10,202' 3.875 5.97 Baker SABL -3 7" x 4" r `% `, 11 10,485' Baker Model "F" ` `, Fish Chemical gun /CCL 13' long 7 Kick off Point @ 10,168'- 10,181' 8s`` H1 H2 MD 10,901' -- H3 ` • H5 10 r- TD = 10,901' MD/10,379' TVD MAX HOLE ANGLE = 91.34 deg 9 DO PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G -2 10,147' 10,167' 10,147' 10,167' 20' 6 Behind 3 -1/2" liner 5/30/1996 11 I C Window cut through G -2 10,177' 10,184' 10,177' 10,184' 7' 6 perfs 5/30/1996 H -1 10,226' 10,227' 10,226' 10,227' 1' 5 Squeezed WSO 3/11/1960 H -1 10,230' 10,265' 10,230' 10,262' 35' 8 Squeezed 7 -25 -00 11/13/1977 H -2 10,275' 10,285' 10,272' 10,280' 10' 8 Squeezed 7 -25 -00 11/13/1977 H -3/4/5 10,310' 10,394' 10,301' 10,352' 84' 4/8 Squeezed 7 -25 -00 11/13/1977 10,402' 10,403' 10,356' 10,356' 1' 5 Squeezed 3/11/1960 4r .` Z,A, H -8 10409' 10,478' 10,358' 10,369' 69' 4 Squeezed 7 -25 -00 3/17/1960 10,992' 7r•+ H -10 10,508' 10,585' 10,369' 10,368' 77' 4 Squeezed 7 -25 -00 3/17/1960 10,598' 10,599' 10,367' 10,367' 1' 5 Squeezed WSO 3/11/1960 - 10,600' 10,601' 10,367' 10,367' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' N/A N/A 1' S Squeezed Old 3/11/1960 Wellbore 11,315' Drawn by: LDD Edit by: TDF 8/22/2012 • Sat 4-z -1- PJ) z©o 057 Regg, James B (DOA) From: Chad Helgeson [chelgeson @hilcorp.com] Friday, August 10 Sent: y, g 10, 2012 4:34 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Chet Starkel Cc: Billy Applewhite - (C); Stan Golis; Carl Kemp; Cole Bartlewski; raviles @slb.com Subject: RE: BOP use 42 -4 Attachments: SCU 42 -4 Schematic Revised 8- 7- 12.doc; SLB BOP Kenai equipment.pdf; SCU 42 -4 Schematic 01 Aug 2004.doc; SKMBT_C45212081013341.pdf Jim, Attached is the new wellbore schematic and the previous wellbore schematic (with the velocity string) and the BOP's on the well for the Swanson 42 -4. Below is the info that I think you needed on this issue last Friday. I am sorry this information took so long to get together this week. I wanted to pull as much together for you in one email. 1. The XN plug set in the profile was not tested, because it was set after the stinger /seal assembly was removed from the coil and the coil was in communication with the formation and could not be tested until it was pulled into the lubricator. The installation of the plug was determined to be a better way to have well control when the tubing was pulled into the lubricator. 2. Update after shearing coil on Friday. a. Ensure the pressure was bled off the lubricator to ensure that the blind rams were holding and repaired the o -ring on the lubricator. b. Pressure tested the Lubricator to 250psi and 3000 psi. Velocity string pressure was 1045 psi and annulus was 50 psi. c. Bled velocity string down to 0 psi. Pumped into velocity string, ensure plug was set. Latched onto string and picked up to move string. Pulled string into lubricator, monitored well for 45 min to ensure the well was dead & plug was holding. Cut overshot assembly off and put cold roll on. Pulled velocity string out of the well. It was determined that the plug was set in the XN Nipple and was holding. The gas pressure was not from the formation, but the void in the velocity string when fluid was pumped into the string and then was displaced. The hydrostatic from trying to kill the well from surface went into the velocity string and when the BOP rams were closed the fluid in the velocity string wasn't able to bleed back into the annulus and was starting to flow. Once the fluid /gas swapped in the velocity string the pressure was from the increased fluid volume in the closed system. The fluid that was coming from r the well and caused the shear rams to close was not directly from the formation, but trapped pressure that was created during the well work. Please let me know if you need any additional information on this situation. Chad SCP1HNED 'APR Q 8 613 From: Billy Applewhite - (C) Sent: Monday, August 06, 2012 6:32 PM To: Chad Helgeson Subject: FW: BOP use From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, August 06, 2012 2:30 PM To: Billy Applewhite - (C) 1 • • Cc,: Schwartz, Guy L (DOA) Subject: RE: BOP use Date on your report (August 8) should be August 3? Please provide the following info: - Was XN plug set in profile at 10439 ft tested before pulling BOPE? If not , why not? - Current well schematic; - Schematic of CT equipment, including BOPE, involved in this event; Update o f event. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Billy Applewhite - (C) f mailto:bapplewhite@ hilcorp.coml Sent: Saturday, August 04, 2012 7:18 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: emuniz(aslb.com; eburreIk slb.com; Chad Helgeson; Billy Applewhite - (C) Subject: FW: BOP use BOP closure incident Date: August 8 2012 1600hrs SCU 42 -04 /Swanson River/ PTD 2000870 ' Rig Name: Schlumberger Coil Unit 2 Operator Contact: Cole Bartlewski 907 - 690 -3406 , cbartlewskiPsIb.com Summary below BOPE equip: 4 1/16 10M Quad EU TOT BOPE. Dressed from top to bottom 1.75in blind /shear, blind /shear, Pipe slip, Pipe rams. Reason for use: control well fluid due to cut lubricator o -ring. Details in email below. Date BOPs tested: August 2" d 2012. Additional information: with the plug set and not sure if the plug and prong set in the xn nipple at the bottom the velocity string is holding. We will pump another tubing volume down the back side and try to bleed off any pressure inside the coiled tubing hanging in the well. If we get this pressure down to zero we will close in at the choke and monitor pressure build up inside the coiled tubing. This will let us determine if the plug and prong is actually holding pressure. If we get build up inside the coil we can assume that the plug and prong is not holding pressure and then determine the best way to pump down the coil. We will most likely have to use the lubricate and bleed method to kill the coil string due to not being able to flow fluid down the coil at a greater rate because of the restriction caused by the plug and prong. This report was written by Cole Bartlewski and sent from Billy Applewhites computer. From: Cole Bartlewski [mailto:CBartlewski(sIb.com] Sent: Saturday, August 04, 2012 5:32 AM To: Billy Applewhite - (C) Cc: Chad Helgeson Subject: BOP use 2 8 -3 -2012 we were rigged up on 42- 0 well work was done by slick line. They had pulled the CT seal nipple (tree saver) from the well and ran a Plug and prong to the xn nipple in the bottom of the coiled tubing velocity string. Previously we had attempted to retrieve the string and the GS tool failed causing the coil velocity string to fall 68 feet bellowing its original position in the tubing hanger. We fished the gs and made up new connections at surface. Ran in hole and stabbed in to fish. At this time we pumped down the back side at 3 bbls a minute. Attempting to kill the well before we pull the v string to surface. Initial whp was about 600 psi at this time. After we pumped 50 or so barrels our hydrostatic was overcoming the column of gas and everything started going south. WHP dropped to zero as we continued to pump at 3bbls a min down the back side for a total of 137 bbls pumped. Coil x Tubing Annulus is 122 bbls. After we killed the well we shut down an monitored the whp for 30 minutes. Everything looked stable so I pulled the v string to surface over pull was 25k and then broke back to a consistent 20k . Pulled pu Fish and Hanger assembly into lubricator. Closed my pipe rams and slips and manually locked them in. At this time we got ready to strip pipe and lift off the injector head assembly from the bop stack to expose the coil and make our cut. Whitey bleed on lubricator showed no pressure so we began to unstabbed from the bops. As we lifted up some water came out so we quickly set back down into the BOPS. (possibly cut the o -ring at this time) Determined there was some fluid left so we hooked up a half inch hose into the kill port on the bops and the other end to the choke. This is the only way to bleed down the stack above the pipes and slips. We monitored the flow coming from the hose and determined there was still gas migrating up the coil. When we killed the well down the back side we were aware that there was communication with the coil and coil tubng annulus . WE made the decision to let the coil unload itself to see if we could bleed down the gas that was coming up to surface. We watched the coil unload for 20 -30 minutes controlling it at the choke. As the flow rate increased we noticed a leak coming from the bowen connection above the bops. We went up and made sure it was seated and tightened. Operator had me swing the crane a bit to one side to see if he could tighten the bowen. This is about the same time the gas hit and the leak was more prevalent. Discussed that the only way to control this leak was to cut coil with the blind /shear rams. WE cut coil and gained well control . Pressure below had built up to about 850 lbs. I believe the back side was still dead and we gained pressure from the coil . We confirmed that the stack was holding for at least an hour and decided to pull injector and put Night cap on the bops. Cole Bartlewski Field Specialist II Coiled Tubing Services 49420 Kenai Spur Hwy Kenai, AK 99611 cell (907)- 690 -3406 Office (907) 776 -8155 Fax (907) 776 -8154 cbartlewski(a�slb.com . 4. 4 eraii COIL TUBING' SERVICES A Schlurberget Company 3 mum C Ltat�� Kenai Well Control Equipment 5K Conventional stripper Crossover 4 1/16" 10K BX- dressed for 1.75" Coil 155 to 7" 5K Bowen Lubricator Thread • 1.75 blind sheafillsealing rams 4 1/16" 10K Quad '� tested min of BOP 1 blind she 9r -4 5 X MPWHP Dressed for 1.75" Slip Ram or 1000 psi over max treating Pipe Seal Rarressure. 4 1/16" 10K Flowcross with flanged 2 1/16" 10K Kill Line ports rigged to pump • Returns Outlet to 10K rated Variable choke Crossover from wellhead Dual 2 1/16" 10K fully open flange to 4 1/16"" 10K BX -155 valves per side 1 S ch iurnbe rger d�d '4' • �wanson River DRILLING' � fi Well SCU 42 -4 U N O CA _ ." Revised 8/7/12 +/ "�' _ CASING AND TUBING DETAIL ir 7 .1.1 SIZE WT GRADE CONN ID TOP BTM. "_.° 22 " 22' Off=: t_; 13 -3/8" 54.5 J -55 8rd/ST &C 12.615 Surface 3,000' . 7" 29 N -80 Buttress 6.184 Surface 304' --: ry 26 N -80 Buttress 6.276 304' 1,235' m T •I 23 N -80 Buttress 6.366 1,235' 4,229' 26 N -80 Buttress 6.276 4,229' 4,527' t ,,oi • 29 N -80 8rd LT &C 6.184 4,527' 6,489' RKB = 17. 2 - 26 P -110 8rd LT &C 6.276 6,489' 9,346' 29 P -110 8rd LT &C 6.184 9,344' 10,992' 1 3 -1/2" liner 9.2 K -55 Hydril 511 2.992 10,067' 10,898' slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row Ai j ''' 2 [ Tubing 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 10,070' 3 -1/2" 9.2 L -80 Buttress 2.992 10,070' 10,095' • 'ff 4 JEWELRY DETAIL MI NO. Depth ID OD Item 1 15' - - Tubing Hanger, 7 -1/16" x 4 -1/2" 8rd., Type" H" BPV profile. CL prep. 3 2,250' 3.813 5.591 4 -1/2 Camco BP -6I LANDING NIPPLE for methanol inj. ZINE2 with 3/8" control line strapped w /168 xl -114" SS bands 4 3.866 5. 4 -1/2" GLM Camco KBG -2 with 1 "KB2 top lock valves 4700' # 1 Gas Lift Mandrel 5 0 6800' # 2 Gas Lift Mandrel 6 8700' # 3 Gas Lift Mandrel 9950' # 4 Gas Lift Mandrel 5 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 5a 10044' 4.438 5.875 Baker HMC liner hanger 6a 10051' 4.000 5.625 Seal Bore Extension 6b 10067' 3.437 5.50 KOIV flapper, 3.437" ID after flapper knocked out 7 7 10101' 2.813 4.00 X nipple, 2.813" ID 8 10181 Baker Bottom Trip Whipstock ' 9 10192' 7" cement retainer G2 10 10,898' 2.992 3.5 3 -1/2" liner shoe 11 10202' 3.875 5.97 Baker SABL -3 7" x 4" 12 10485' Baker Model "F" %�, �' Fish Chemical gun /CCL 13' long 8 4 Kick off Point @ 10168- 10181' H1 MD 10901' 9 -- H2 H3 __ • H5 10 11 1 1 - TD = 10,901' MD/10,379' TVD MAX HOLE ANGLE = 91.34 deg PERFORATION HISTORY Interval Accum. i D Zone Top Btm Amt spf Comments 12 5/30/1996 G -2 10,147' 10,167' 20' 6 Behind 3 -I/2" liner 5/30/1996 G -2 10,177' 10,184' 7' 6 Window cut through perfs 3/11/1960 H -1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/1977 H -1 10,230' 10,265' 35' 8 Squeezed? -25.00 11/13/1977 H -2 10,275' 10,285' 10' 8 Squeezed 7 -25 -00 11/13/1977 H -3/4/5 10,310' 10,394' 84' 4/8 Squeezed? -25.00 3/11/1960 - 10,402' 10,403' 1' 5 Squeezed °., .. \ 3/17/1960 H -8 10,409' 10,478' 69' 4 Squeezed 7.25 -00 10992' 3/17/1960 H -10 10,508' 10,585' 77' 4 Squeezed? -25 -00 3/11/1960 - 10,598' 10,599' 1' 5 SqueezedWSO 3/11/1960 - 10,600' 10,601' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' 1' 5 Squeezed ■ 11315' SCU 42 -4 Schematic Kevlsea a- / -12 Drawn by: LDD Edit by: BCA 10/03/12 . •wanson River Well SCU 42 -4 CT Velocity String Completion 1 . OA CASING AND TUBING DETAIL L -1=' .-:1=7.11.1 SIZE WT GRADE CONN ID TOP BTM. 22" 22' tom: ti 13 -3/8" 54.5 J -55 8rd/ST &C 12.615 Surface 3,000' 7" 29 N -80 Buttress 6.184 Surface 304' l TrT 26 N -80 Buttress 6.276 304' 1,235' Lr �� t �� 23 N -80 Buttress 6.366 1,235' 4,229' 26 N -80 Buttress 6.276 4,229' 4,527' tom' : y; . ' ' 29 N -80 8rd LT &C 6,184 4,527' 6,489' _. RKB = 17. _ - i . -. 26 P -110 8rd LT &C 6.276 6,489' 9,346' 29 P -110 8rd LT &C 6.184 9,344' 10,992' 1 I 3 -1/2" liner 9.2 K -55 Hydnl511 2.992 10,067' 10,898' (Y Jl slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row tV ' t /, E Tubing 2 1^l� 'll 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 10,070' 3 9.2 L -80 Buttress 2.992 10,070' 10,095' , r 1 -3/4" Coil 1l' 80 20' 10,323' 3 4 JEWELRY DETAIL NO. Depth ID OD Item 1 15' - - Tubing Hanger, 7- 1/16" x 4 -1/2" 8rd., Type" H" BPV profile. CL prep. 1 1 2 20' TIVV Auto `:P' CT Hanger w/ Tie -Back Reciprocal. 3 2,250' 3.813 5.591 4 -1/2 Camco BP -6I LANDING NIPPLE for methanol inj. a 11 with 3/8" control line strapped w/168 x1 -1/4" SS bands 4 3. 5.984 4 -1/2" GLM Camco KBG -2 with 1" KB2 top lock valves 4700' # 1 Gas Lift Mandrel 5 6800' # 2 Gas Lift Mandrel 8700' # 3 Gas Lift Mandrel 6 i 9950' # 4 Gas Lift Mandrel 5 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 5a 10044' 4.438 5.875 Baker HMC liner hanger 6a 10051' 4.000 5.625 Seal Bore Extension 6b 10067' 3.437 5.50 KOIV flapper, 3.437" ID after flapper knocked out 7 7 10101' 2.813 4.00 X nipple, 2.813" ID 8 _ 10181 Baker Bottom Trip Whipstock ' 9 10192' 7" cement retainer 1 1 1 ' G2 10 10,898' 2.992 3.5 3 - 1/2" liner shoe 1 11 10202' 3.875 5.97 Baker SABL -3 7" x 4" / , 12 10485' Baker Model "F" k 13 10,323' CTC. Pup joint, Profile Nipple & Shear Sub � Chemical gun /CCL 13' long 8 Hl Kick off Point @ 10168 - 10181' MD 10901 9 --- _- --- .: H2 H3 ___ • H5 10 11 TD = 10,901' MD/10,379' TVD MAX HOLE ANGLE = 91.34 deg .J PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf omments 12 I 1 5/30/1996 G -2 10,147' 10,167' 20' 6 Behind 3-112" liner 5/30/1996 G -2 10,177' 10,184' 7' 6 Window cut through perfs 3/11/1960 H -1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/1977 H -1 10,230' 10,265' 35' 8 Squeezed ? -25 -00 11/13/1977 H -2 10,275' 10,285' 10' 8 Squeezed 7-25-00 11/13/1977 H -3/4/5 10,310' 10,394' 84' 4/8 Squeezed 7-25-00 3/11/1960 - 10,402' 10,403' 1' 5 Squeezed 3/17/1960 H -8 10,409' 10,478' 69' 4 Squeezed? -25 -00 3/17/1960 H -10 10,508' 10,585' 77' 4 Squeezed 7.25.00 10992' 3/11/1960 - 10,598' 10,599' 1' 5 Squeezed WS0 3/11/1960 - 10,600' 10,601' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' 1' 5 Squeezed 11315' SCU 42 -4 Schematic 01 Aug 2004 Drawn by: LDD Edit by: CRW 10/03/12 c ■■••••n■ori* **./ ''. V • ,....N I CD c. j ''*'' 0 00,8 )N i ) . 1 rkedi . ---____-- --- ' -.. --- 1 , L 0 i ‘..2 - 2rS "1/49 <1 1') 4, frva o ..i <-----_' ) t 0 1 C\A ., ,9r\A ., yzrvo 0 0 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm_ Marker. doc ~ t .,.', '. . , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 17.1' KB 8. Property Designation: Soldatna Creek Unit 11. Present Well Condition Summary: Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D 7?¿~ s¡:JlB 1 81Wt)~ Stimulate U cit~e:¡;¡t~J~3iVéI~S~~;$(!f.lng \ Waiver D Time Extension D t;;,mJìÜ!;G~~ Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 200-087 Service D 6. API Number: 50-133-10109-01 9. Well Name and Number: SCU 42-04 10. Field/Pool(s): Swanson River Field/Hemlock Total Depth measured 10,901 feet Plugs (measured) true vertical 10,379 feet Junk (measured) Effective Depth measured 10,901 feet true vertical 10,379 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 853 (1000Ib) 1 ,130 psi Intermediate Production 10168' 7" 10168' 10168' 532 (1000Ib) 3,830 psi Liner 831' 3-1/2" 1 0,898' 1 0,379' . ..~ "' K) 2005 Perforation depth: Measured depth: 10,168-10,898 slotted Imer open to reservOSCANNED FE B 2. (.J ." Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 2,680 360 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 Gas D WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. True Vertical depth: 10,168 - 10,379 Tubing: (size, grade, and measured depth) Velocity string (1-3/4" CT) Surface - 10,323 md Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 29 17 attached Contact Steve Tyler 907-263-7649 Printed Name Timothy C. Brandenburg '/(;9 ~-~ Signature' (- ~._-- .~ Form 10-404 Revise 04/2004 4-1/2" , 3-1/2" L-80 Surface to 10,070'; 10,070' to 10,095' ZXP Liner top packer w/ 6' x 5.25" tieback sleeves 10,095' Tubing Pressure Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: RBDMS BFL FEB 222m S 304-149 Titlè Drilling Manager Phone 9¡J7 -276-7600 Date '2... -/I-ê)S Submit Original Only 07/19/2004 MIRV Pollard wireline. Pressure tested to 1000#. Made up tool string with anti blowup tool, roller stem and tungsten carbide stem with 2.80" gauge ring. RIH while flowing well. Tools set down at 10442' RKB in deviation. POOH rig down. 07/24/2004 SIMOP's with Production & Construction. PTSM with Peak & daily instructions. PTSM with Schlumberger. Launch NerfBall and Hippo Turbine down coil. Get returns and pull ball catcher with nerf and hippo turbine. Load 1.32 ball and pump Got ball pull catcher and change over whip end to valve for pressure test. Stab injector and test TIW connectors during pressure test. Cut whip on coil. Stab injector head with coil. M/U Baker Coil connector. Pull test 15K, Pressure test 4500# (OK). Have good 30 minute pressure test at 4500# on 21950' of 1 3/4" coil for 42-4 and 22-4 velocity strings. Stand injection head back on trailer. Rig up BOP's. SDFN. 07/27/2004 Sim-Ops Mtg. with Production and Well services crew Nippled up BOP's Pressure tested to Unocal specification, 250-low & 4,OOO-high. Made up Baker bottom Coil Tubing Connector, BHA TIW Blow out plug wlBullet Nose wlo catcher, Haliburton XN Nipple, TIW 6' pup joint 1-112" NUE 10 Rd Pin X Box and pressure tested to 4,500-psi pulled test Bottom Connector 15-K good test. Made up Lubricator. Connection pressure tested to 2,500-psi and Started in hole. Continued in hole to 10,360' CTM 10,377' RKB and set down 10K weight Picked up worked tubing set down 5-K. 07/28/2004 Slacked offset down at 10,360' CTM picked up, weight 36-K at 10,358' CTM. Picked up 35' 10,323' CTM allowed 35' off bottom to ensure setting of Coil Tubing hanger assembly. Held Safety meeting set Coil tubing slips and closed pipe rams, bled off tubing and stack above rams. Cut coil tubing dressed coil tubing installed GS running tool pulled tested same to 25- K. Dressed Coil tubing top above stack. Installed lubricator on tree, and secured well. M/U lower tree 4-1116" Cross, 3-118" Cameron hanger spool, and 3-1116" 5-M Crown Valve. Picked up Injector Head installed CTC Pulled tested 12-K with Crane. Connected GS Running Tool into PBR made connection on lubricator. P/U 38-K opened slips and rams. Coil Tubing weight 36-K WIH 7' picked up to l' slacked off set Top ofPBR 2' below tubing hanger. pressure up to 750-psi disconnected GS RT POOH. Rigged down Schlumberger BOPE nippled up lower tree pressure tested 4,000-psi. Rigged up Slickline picked up tree extension, cameron 3.05" O.D. hanger RIH stung into PBR landed hanger. Run in locked down screws, sheared JR pulling tool bled off above hanger seal. Perform negative test. Tested OK rigged down slickline. Installed top of tree made up same, rigged up pump unit pressure up to blow plug. Pressure Tested top of tree 4,000-psi. pressure up to 750-psi on 1.750" CT blew plug well went on vacuum. Secured well. 07/29/2004 Production hooked flow line from the well 42-4. SCU 42-04 (162277) morning report summary, CONFIDENTIAL: last revised 2/9/2005, Page 1. t i Owanson River letetlikaiktill 111 Well SCU 42 -4 V NOCA - 3 CT Velocity String Completion I-- \_ CASING AND TUBING DETAIL L ' " r - ' SIZE WT GRADE CONN ID TOP BTM. - 22" 22' IP -'.' . - 13 -3/8" 54.5 J -55 _ 8rd/ST &C 12.615 Surface 3,000' 7" 29 N -80 Buttress 6.184 Surface 304' , � T` 26 N -80 Buttress 6.276 304' 1,235' 1 r� l -7- ' ' ') 23 N -80 Buttress 6.366 1,235' 4,229' -11 - 26 N -80 Buttress 6.276 4,229' 4,527' t ~' t 29 N -80 8rd LT &C 6.184 4,527' 6,489' RKB = 17. A I - 26 P -110 8rd LT &C 6.276 6,489' 9,346' 29 P -I10 8rd LT &C 6.184 9,344' 10,992' -r 3 - liner 9.2 K -55 H dril 511 2.992 10,067' 10,898' I - Y I` J slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row t.' f, Tubing --• 2 Tubing 12.6 L -80 Buttress 3.958 Surf 10,070' 3 -1/2" 9.2 L -80 Buttress 2.992 10,070' 10,095' ig 1 -3/4" Coil HS-80 20' 10,323' 3 1 1 am JEWELRY DETAIL I I ■ NO. Depth ID OD Item II , I ..1.5:. p - - Tubing Hanger, 7- 1/16" x 4 -1/2" 8rd., Type" H" BPV profile. Cl. prep. 2 20' TIW Auto "J" CT Hanger w/ Tie -Back Reciprocal. 3 2,250' 3.813 5.591 4 -1/2 Camco BP -6I LANDING NIPPLE for methanol inj. II II with 3/8" control line strapped w/168 x1 -1/4" SS bands 4 3.866 5.984 4 -1/2" GLM Camco KBG -2 with 1" KB2 top lock valves 4700' # 1 Gas Lift Mandrel _ 6800' # 2 Gas Lift Mandrel - j - 8700' # 3 Gas Lift Mandrel ( ' m ...: 9950' # 4 Gas Lift Mandrel 5 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 5a 10044' 4.438 5.875 Baker HMC liner hanger 6a 10051' 4.000 5.625 Seal Bore Extension • • 6b 10067' 3.437 5.50 KOIV flapper, 3.437" 11) after flapper knocked out 7 10101' 2.813 4.00 X nipple, 2.813" ID 8 10181 Baker Bottom Trip Whipstock ' - 9 10192' 7" cement retainer t 1 ' t (; 10 10,898' 2.992 3.5 3 -1/2" liner shoe A 11 10202' 3.875 5.97 Baker SABL -3 7" x 4" A A 12 10485' Baker Model "F' r ` 13 10,323' . 'Y'. Pup joint, Profile Nipple & Shear Sub Fish Chemical gun /CCL 13' long 8 Kick off Point @ 10168 - 10181' 9 �• MD 10901' �% 113 ■ HS 10 11 TD = 10,901' MD/10,379' TVD MAX HOLE ANGLE = 91.34 deg PERFORATION HISTORY Interval Accum. NNE ■ Zone Top Btm Amt spf Comments = 5/30/1996 G -2 10,147' 10,167' 20' 6 Behind 3 -I/2" liner 5/30/1996 G -2 10,177' 10,184' 7' 6 Window cut through per 3/11/1960 H -1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/1977 H -1 10,230' 10,265' 35' 8 Squeezed? -25 -00 11/13/1977 H -2 10,275' 10,285' 10' 8 Squeezed? -25 -00 11/13/1977 H -3/4/5 10,310' 10,394' 84' 4/8 Squeezed? -25 -00 3/11/1960 - 10,402' 10,403' 1' 5 Squeezed *;R \ 3/17/1960 H -8 10,409' 10,478' 69' 4 Squeezed? -25-00 10992' 3/17/1960 H -10 10,508' 10,585' 77' 4 Squeezed ? - 25 - 00 3/11/1960 - 10,598' 10,599' 1' 5 Squeezed WSO 3/11/1960 - 10,600' 10,601' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' 1' 5 Squeezed 11315' SCU 42 -4 Current Scnemanc up Drawn by: LDD Edit by: CRW 02/09/05 ) STATE OF ALASKA, ALASKA OIL AND GAS CONSERVATION COMM. - JION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 17.1' KB 8. Property Designation: Soldatna Creek Unit 11. Present Well Condition Summary: Total Depth measu red 10,901 feet true vertical 10,379 feet Effective Depth measured 10,901 feet true vertical 10,379 feet Casing Length Size MD Structu ral Conductor 22' 22" 22' Surface 3,000' 13-3/8" 3,000' Intermediate Production 10168' 7" 10168' Liner 831' 3-1/2" 1 0,898' Perforation depth: Measured depth: 1 0, 168-1 0,898 slotted liner open to reservoir. True Vertical depth: 10,168 - 10,379 Tubing: (size, grade, and measured depth) 4-1/2" , 3-1/2" Packers and SSSV (type and measured depth) Stimulate U Other LJ Velocity String Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 200-087 Service D 6. API Number: 50-133-10109-01 9. Well Name and Number: SCU 42-04 10. Field/Pool(s): Swanson River Field/Hemlock Plugs (measured) Junk (measured) FEB 1 . 2005 0 TVD Burst 22' 3,000' 853 (1 OOOlb) 1 ,130 psi 10168' 532 (1 OOOlb) 3,830 psi 10,379' L-80 Surface to 10,070' ; 10,070' to 10,095' ZXP Liner top packer w/ 6' x 5.25" tieback sleeves 10,095' 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED FEB 1 5 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 2,680 360 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oil0 Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 29 17 attached Tubing Pressure Service D GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 304-149 Contact Steve Tyler 907-263-7649 RBDMS 8Ft ~ËB ) 4 2005 Title Drilling Manager Printed Name Timothy C. Brandenburg Signature ~ ¿c~- Form 10-404 Revised 04/2004 :7 c;¡; --3:7 Phone 907-276-7600 Submit Original Only Date 2-If-DS ) ) 07/19/2004 MIRV Pollard wire1ine. Pressure tested to 1000#. Made up tool string with anti blowup tool, roller stem and tungsten carbide stem with 2.80" gauge ring. RIH while flowing well. Tools set down at 10442' RKB in deviation. POOH rig down. 07/24/2004 SIMOP's with Production & Construction. PTSM with Peak & daily instructions. PTSM with Schlumberger. Launch Nerf Ball and Hippo Turbine down coil. Get returns and pull ball catcher with nerf and hippo turbine. Load 1.32 ball and pump Got ball pull catcher and change over whip end to valve for pressure test. Stab injector and test TIW connectors during pressure test. Cut whip on coil. Stab injector head with coil. M/U Baker Coil connector. Pull test 15K, Pressure test 4500# (OK). Have good 30 minute pressure test at 4500# on 21950' of 1 3/4" coil for 42-4 and 22-4 velocity strings. Stand injection head back on trailer. Rig up BOP's. SDFN. 07/27/2004 Sim-Ops Mtg. with Production and Well services crew Nippled up BOP's Pressure tested to Unocal specification, 250-10w & 4,000-high. Made up Baker bottom Coil Tubing Connector, BHA TIW Blow out plug wlBullet Nose wlo catcher, Haliburton XN Nipple, TIW 6' pup joint 1-,1/2" NUE lORd Pin X Box and pressure tested to 4,500-psi pulled test Bottom Connector 15-K good test. Made up Lubricator. Connection pressure tested to 2,500-psi and Started in hole. Continued in hole to 10,360' CTM 10,377' RKBand set down 10K weight Picked up worked tubing set down 5-K. 07/28/2004 Slacked off set down at 10,360' CTM picked up, weight 36-K at 10,358' CTM. Picked up 35' 10,323' CTM allowed 35' off bottom to ensure setting of Coil Tubing hanger assembly. Held Safety meeting set Coil tubing slips and closed pipe rams, bled off tubing and stack above rams. Cut coil tubing dressed coil tubing installed GS running tool pulled tested same to 25-K. Dressed Coil tubing top above stack. Installed lubricator on tree, and secured well. M/U lower tree 4-1/16" Cross, 3-1/8" Cameron hanger spool, and 3-1/16" 5-M Crown Valve. Picked up Injector Head installed CTC Pulled tested 12-K with Crane. Connected GS Running Tool into PBR made connection on lubricator. P/U 38-K opened slips and rams. Coil Tubing weight 36- K WIH 7' picked up to l' slacked off set Top of PBR 2' below tubing hanger. pressure up to 750-psi disconnected GS RT POOH. Rigged down Schlumberger BOPE nippled up lower tree pressure tested 4,000-psi. Rigged up Slickline picked up tree extension, cameron 3.05" O.D. hanger RIH stung into PBR landed hanger. Run in locked down screws, sheared JR pulling tool bled off above hanger seal. Perform negative test. Tested OK rigged down slickline. Installed top of tree made up same, rigged up pump unit pressure up to blow plug. Pressure Tested top of tree 4,000-psi. pressure up to 750-psi on 1.750" CT blew plug well went on vacuum. Secured well. 07/29/2004 Production hooked flow line from the well 42-4. SCU 42-04 (162277) morning report summary, CONFIDENTIAL: last revised 1/25/2005, Page 1. a r 1 Ildlettliallatil Ovanson River Well SCU 42 -4 UNOCA -73 CT Velocity String Completion ' � i r- r _ CASING AND TUBING DETAIL i l l �t�' 1 SIZE WT GRADE CONN ID TOP BTM. L' . _ 22" 22' ". : _ - 13 -3/8" 54.5 3 -55 8rd/ST &C 12.615 Surface 3,000' 7 " 29 N -80 Buttress 6.184 Surface 304' 7 ■Tt..�.r _ - _ 26 N -80 Buttress 6.276 304' 1,235' 1 L_. I I 23 N -80 Buttress 6.366 1,235' 4,229' -' it I - 26 N -80 Buttress 6.276 4,229' 4,527' ` 29 N -80 8rd LT &C 6.184 4,527' 6,489' RKB = 17. Al_1.- 26 P -110 8rd LT &C 6.276 6,489' 9,346' � 29 P -110 8rd LT &C 6.184 9,344' 10,992' i - 3 -1/2" liner 9.2 K -55 Hydril 511 2.992 10,067' 10,898' slotted 24 slots / ft 1/8" wide 2.5" long with 12 slots /row �, %. Tubing 1 I. 4 -1/2" 12.6 L -80 Buttress 3.958 Surf 10,070' 3 -1/2" 9.2 L -80 Buttress 2.992 10,070' 10,095' 1 -3/4" Coil HS -80 20' 10,323' 3 N • 4 I Om. JEWELRY DETAIL \O. Depth ID OD Item O 1 15' - - Tubing Hanger, 7- 1/16" x 4 -1/2" 8rd., Type" H" BPV profile. CL prep. 1 11 20' TIW Auto "J" CT Hanger w/ Tie -Back Reciprocal. 111 N 3 2,250' 3.813 5.591 4 -1/2 Camco BP -6I LANDING NIPPLE for methanol inj. , with 3/8" control line strapped w/168 x1-1/4" SS bands MN 4 3.866 5.984 4 -1/2" GLM Camco KBG -2 with I" KB2 top lock valves 4700' # 1 Gas Lift Mandrel 5- ► 6800' # 2 Gas Lift Mandrel - 8700' # 3 Gas Lift Mandrel - , . 9950' # 4 Gas Lift Mandrel 5 10095' 5.25 5.75 ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve 5a 10044' 4.438 5.875 Baker HMC liner hanger 6a 10051' 4.000 5.625 Seal Bore Extension a 6b 10067' 3.437 5.50 KOIV flapper, 3.437" ID after flapper knocked out 7 10101' 2.813 4.00 X nipple, 2.813" ID 8 10181 Baker Bottom Trip Whipstock 9 10192' 7" cement retainer ' t ; 2 10 10,898' 2.992 3.5 3 -1/2" liner shoe ■ 11 10202' 3.875 5.97 Baker SABL -3 7" x 4" Ili t 12 10485' Baker Model "F' 13 10,323' CTC, Pup joint, Profile Nipple & Shear Sub Fish Chemical gun /CCL 13' long s ‘44- 's 8 • Kick off Point @ 10168-10181' 9 H2 G '/ H1 MD 10901' H3 ___ ■ H5 10 11 I I TD = 10,901' MD/10,379' TVD MAX HOLE ANGLE = 91.34 deg PERFORATION HISTORY Interval Accum. I Date Zone Top Btm Amt spf Comments 5/30/1996 G -2 10,147' 10,167' 20' 6 Behind 3-1/2" liner 5/30/1996 G -2 10,177' 10,184' 7' 6 window cut through perfs 3/11/1960 H -1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/1977 H -1 10,230' 10,265' 35' 8 Squeezed 7 11/13/1977 H -2 10,275' 10,285' 10' 8 Squeezed7 - 25 - 00 11/13/1977 H -3/4/5 10,310' 10,394' 84' 4/8 Squeezed 7 3/11/1960 - 10,402' 10,403' 1' 5 Squeezed * '' 3/17/1960 H -8 10,409' 10,478' 69' 4 Squeezed? - 25 - 00 10992' / * 3/17/1960 H - 10,508' 10,585' 77' 4 Squeezed 7 3/11/1960 - 10,598' 10,599' 1' 5 Squeezed WSO 3/11/1960 - 10,600' 10,601' 1' 5 Squeezed 3/11/1960 WF 10,965' 10,966' 1' 5 Squeezed 11315' SCU 42 -4 Current Scnematic uD Drawn by: LDD Edit by: CRW 01/25/05 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10,901 10,379 10.901 10,379 Length Size MD TVD ~ Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 17.1' 1. Type of Request: 8. Property Designation: Swanson River Unit Casing Structural Conductor 22' 3,000' Surface Intermediate Production Liner 10992 831 - I I -- ~ STATE OF ALASKA 1"'""\ ALAt . OIL AND GAS CONSERVATION COMIV.. JION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: 1) } I.S' ~/f¿Ó !~ Suspend U Repairwell 0 Pull Tubing 0 Perforate U W4k Waiver U Annular DiSPOS~U Stimulata.W Time Extension n - 1 I Ot 1er. IAiW1- ~ST~ 1/ l{O Re-enter Suspended Well 0 ~ f-y.' 5. Permit to Drill Number: I Exploratory 0 200-087 / Service D 6. API Number: /' 50-133-10109-01 Development Stratigraphic 0 0 9. Well Name and Number: SCU 42-04 / 10. Field/Pools(s): Swanson River/Hemlock Junk (measured): Burst Collapse 22" 22' 3,000' 22' 3,000' 13-3/8" 853 psi 1,130 psi 7" 10,168 10898 ITUbing Size: 4-1/2",3-1/2" ZXP Liner top packer w/6' x 5.25" tieback Packers and SSSV MD (ft): sleeves Perforation Depth MD (ft): 10,181 10,379 Tubing Grade: L-80 10,095' TUbing MD (ft): 10,070',10,095' 532 psi 3,830 psi 3-1/2" Perforation Depth TVD (ft): Packers and SSSV Type: 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Philip J. Krueger Title Drilling Manager S~"at".. ~/~- 9O:"::;:'ONUSEONLY Oote Commencing Operations: 16. Verbal Approval: 5/25/2004 Date: 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas [2] Plugged WAG 0 GINJ 0 WINJ Abandoned WDSPL 0 0 [2] Service 0 D 0 Contact Steve Tyler 907-263-7649 4/16/2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: dt/4-/1-f ¥'" Plug Integrity 0 BOP Test D Other: Form 10-403 Revised 12/2003 Mechanical Integrity Test 0 Location Clearance D RECEIVED APR 2 3 2004 .. 8FL #itI8'.' BY ORDER OF COMMISSIONER THE COMMISSION 16~'le~~A~~_E RKB = 17.1' 4 5 6 7 11 12 iY ::J c 10992' SCU 42-4 CurrentScnemanc 11315' NO. I G2 -Date 5/30/96 5/30/96 3/11/60 11/13/77 11/13/77 11/13/77 3/11/60 3/17/60 3/17/60 3/11/60 3/11/60 3/11/60 Drawn by: T' 3-1/2" liner slotted Tubing 4-1/2" 3-1/2" Depth 15' 2 3 2,250 2,250' I I I \ I \ \ \ \ \ \ \ \ \ , , , "'" HI . -......1. Kick offPoint @ 10168-10.181' l ", ", H2 MD 10901' " "" H3 ',----- . H5 ........... - - - - - - ---~-- -- --- - ~ --- ~ - -- --- ~~--- ~ ~~~~~~~~~ ~~~~~:~~~;~~~~--] PERFORATION HISTORY Interval Accum. Top Btm Amt spf 10,147' 10,167' 20' 6 10,177' 10,184' 7' 6 10,226' 10,227' 5 10,230' 10,265' 35' 8 10,275' 10,285' 10' 8 10,310' 10,394' 84' 4/8 10,402' 10,403' I' 5 10,409' 10,478' 69' 4 10,508' 10,585' 77' 4 10,598' 10,599' I' 5 10,600' 10,601' l' 5 10.965' 10.966' I' 5 4 4700' 6800' 8700' 9950' 10095' 10044' 10051' 10067' 10101' 10181 10192' 10,898' 10202' 10485' Fish Zone G-2 H-l H-I H-2 H-3/4/5 H-8 H-IO WF 29 26 23 26 29 26 29 9.2 24 slots I tì 12.6 9.2 3.958 3.813 3.866 5.25 4.438 4.000 3.437 2.813 2.992 3.875 N-SO N-SO N-SO N-SO P-IIO P-110 K-55 1/8" wide m Srd/ST&C Buttress 304' Buttress 6.276 1,235' Buttress 6.366 1,235' 4,229' Buttress 6.276 4,229' 4,527' Srd LT&C 6.1S4 4,527' 6,4S9' Srd LT&C 6.276 6,4S9' 9,346' Srd LT&C 6.1S4 9,344' 10,992' Hydril 511 2.992 10,067' 10,898' 2.5" long with 12 slotslrow Buttress 3.958 Surf 10,070' Buttress Box x 8rd pin 2.992 10,070 10,095 L-80 L-80 m JEWELRY DETAIL OD Hem Tubing Hanger, 7-1116" x 4-1/2" 8rd., Type"H"BPV profile. CL prep. 5.954 4-1/2" L-80 12.6 ftIlb Butt. tubing 5.591 4-1/2 Cameo BP-6I LANDING NIPPLE for methanol inj. with 3/8" eontrolline strapped wll68 xl-1/4" SS bands 5.984 4-1/2" GLM Camco KBG-2 with I" KB2 top lock valves # I Gas Lift Mandrel # 2 Gas Lift Mandrel # 3 Gas Lift Mandrel # 4 Gas Lift Mandrel ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper knocked out X nipple, 2.813" ID Baker Bottom Trip Whipstock T' cement retainer 3.5 3-1/2" liner shoe 5.97 Baker SABL-3 T' x 4" Baker Model "F" Chemical gun ICCL 13' long 5.75 5.875 5.625 5.50 4.00 10 Comments Behind 3.112" liner Window cut through perts squeezed WSO Squeezed 7.25.0() Squeezed 7.25.00 Squeezed 7.25.00 Squeezed Squeezed 7.25.00 Squeezed 7.25.00 Squeezed WSO Squeezed Squeezed 04/15/04 - 5 6 7 ::J c 8 9 II 12 10992 ' 11315' SCU 42-4_Proposed ~cnemanc 13-3/8" 7" 3-1/2" liner slotted Tubing 4-1/2" 3-1/2" G2 Date 5/30/1996 5/30/1996 3/11/1960 11/13/1977 11/13/1977 11/13/1977 3/11/1960 3/17/1960 3/17/1960 3/1l/1960 3/11/1960 3/11/1960 Drawn by: LDD CASINGAND TUBING DETAIL m 22' 54.5 8rd/ST &C ]2.615 Surface 3.000' 29 Buttress 6.184 Surface 304' 26 N-80 Buttress 6.276 304' 1,235' 23 N-80 Buttress 6.366 1,235' 4,229' 26 N-80 Buttress 6.276 4,229' 4,527' 29 N-80 8rd LT&C 6,184 4,527' 6,489' 26 P-II0 8rd LT&C 6.276 6,489' 9,346' 29 P-IIO 8rd LT&C 6.184 9,344' 10,992' 9.2 K-55 Hydril511 2.992 10,067' 10,898' 24 slots ft 1/8" wide 2.5" long with 12 slots/row 12.6 L-80 Buttress 3.958 Surf 10,070' 9.2 L-80 Buttress 2.992 10,070' 10.095' 5 5a 6a 6b 7 8 9 10 II 12 4700' 6800' 8700' 9950' 10095' 10044' 10051 ' 10067' 10101' 10181 10192' 10,898' 10202' 10485' - NO, Depth m I 15' 2,250' 3.813 4 3.866 I I \ I \ \ \ \ \ \ \ \ \ , , , , "'" HI I KickoffPoint@ 10168-10.181' I ", ", H2 MD 10901' " "'- H3 ',------ . H5 ..,"'""""" ,,'- -,. ~ ~ -..' - ~ -- -,. ~ ~ -, - -, ~~~-:~~~:~'~~~~~ ~-~~~~ ~;, -] Fish Zone G-2 G-2 H-l H-l H-2 H-3/4/5 H-8 H-IO WF JEWELRY DETAIL OD Hem Tubing Hanger, 7-11l6" x 4-1/2" 8rd., Type" H" BPV 5.591 4-1/2 Cameo BP-61 LANDING NIPPLE for methanol inj. with 3/8" control line strapped wll68 x 1-1 /4" SS bands 4-1/2" GLM Cameo KBG-2 with I" KH2 top lock valves # I Gas Lift Mandrel # 2 Gas Lift Mandrel # 3 Gas Lift Mandrel # 4 Gas Lift Mandrel ZXP Liner Top Pkr with 6' x 5.25" 10 tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper kno~ked out X nipple, 2.813" 10 Baker Bottom Trip Whipstock 7" cement retainer 3-1/2" liner shoe Baker SABL-3 7" x 4" Baker Model "F" 5.984 5.25 4.438 4.000 3.437 2.813 5.75 5.875 5.625 5.50 4.00 2.992 3.875 3.5 5.97 Chemical gun /CCL 13' long 10 PERFORATION HISTORY Interval Accum. I Top Btm Amt spf Comments 10,147' 10,167' 20' 6 Behind J-1/1" liner 10,177' 10,184' 7' 6 Window cut through 10,226' 10,227' l' 5 Squeezed WSO 10,230' 10,265' 35' 8 Squeezed 7-25-00 10,275' 10,285' 10' 8 Squeezed 7-25-00 10,310' 10,394' 84' 4/8 Squeezed 7-25-00 10,402' 10.403' I' 5 Squeezed 10,409' 10,478' 69' 4 Squeezed 7-25-00 10,508' 10,585' 77' 4 Squ<ezed 7-25-00 10,598' 10,599' I' 5 Squeezed WSO 10,600' 10,601' l' 5 Squeezed 1O,96? 10,966' l' 5 Squeezed 04/15/04 " - L- UNOCAL8 Swanson River Well seu 42-4 Proposed eT Velocity String Completion /' su~ Procedure . MIRU Slickline. RIH wi OR to 10,450'. POOH. RD. . MIRU 1-314" CTU. NU BOPE, MU CTc. Pressure test same. . PUMU Lwr BHA. RIH wi 1-3/4" CT to 10,430'. . Cut CT MU CTC & TIW Hanger. RIH on OS PT. hang CT below tbg hngr. . Release from CT Hngr. POOH. Secure well. RD Demobe CTU. . ND tree and flowlines above bottom master valve. . NU 2-1116" flow tee, CT hngr, master valve, flow tee and swab valve. . RU Slickline. PUMU Tie-Back assy. RIH stab seal assy into hngr tie-back re~le. Land in CT hangr. . Turn well over to production. seD 42-4_Proposed Schematic ~ ùrawn by: LDD """-""', 04/15/04'" ' DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Permit to Drill 2000870 Well Name/No. SOLDOTNA CK UNIT 42-4 MD TVD 10379 Completion Oat 8/6/2000 ...------ Completion Statu 1-01L 10901 REQUIRED INFORMATION Mud Log No Sample No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type / Fmt Name L L L L L L L L R R C e-/ Well Cores/Samples Information: Log Log Run Scale Media No 2 vliUCCL ~~ETT RCD -š'RVY RPT '-~. 2/5 1-5 2/5 1-5 5 1 5 1 1 Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? . Y / t~ Analysis Rp.C'.p.ivp.rI? ~..Lr~L, Comments: Compliance Reviewed By: v~ Operator UNION OIL CO OF CALIFORNIA API No. 50-133-10109-01-00 Current Status 1-01L UIC N Directional Survey ~iJ~. (data taken from Logs Portion of Master Well Data Maínt) Interval OHI Dataset Start Stop CH Received Number Comments 10186 10846 Open 8/30/2000 09704 ~186-10846 10165 10845 OH 8/30/2000 10165-10845 7/27/00 THRU 10165 10370 OH 8/30/2000 10165-10370 7/27/00 THRU 8000 10190 CH 8/30/2000 8000-10190 8000 10190 CH 8/30/2000 8000-10190 10161 10901 OH 8/30/2000 1HULM 10161-10901 OH 8/30/2000 9704 SCHLUM GR-MD Sent Dataset Number Comments Received Daily History Received? ~ ð)N Formation Tops Date: ¡f- \ \' v , t, dJ-r'f- )d's~ )': STATE OF ALASKA ........ ALASKA OIL AND GAS CONSERVATION C JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Alaska 200-087 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 150- 133-10109-01 4. Location of well at surface i'~ !i.''~,;':;- .......... - ~ i~:',.i'~'~ii ~ ~ ! 9. Unit or Lease Name 1000' FNL & 1170' FEL of Sec. 4, T7N, R9W, SM ;i i'.~-,,.,~,,,~.,~ i Soldotna Creek Unit ' :!":": ~ At Top Producing Interval i ~'..X~.~.~..'~ i~ [ 10. Well Number 1052' FNL & 1165' FEL of sec. 4, T7N, R9W, SM i ~'-":i~ i::;'; ~ SCU 42-4 At Total Depth '~~ Swanson River/Hemlock 1605' FNL & 1198' FEL of Sec 4, T7N, R9W, SM i.::: ~C'~ i' 11. Field and Pool 5. Elevation in feet (indi~te KB, DF, etc.) ~ 6. Lea~ Designation and Serial No. 180' RKB at MSL~ A-28997 12. Date Spudded 13. Date T.D. Reached ~ 14. ~ate Comp. Susp. or Aband. J 15. Water Depth, if offshore 16. No. of Completions 27 July 2000 4 August 2000~ ,~Abg~st 2000~ WA feet MSL 1 17. Total Depth (MD+TVD)10,901, MD/10,379' 18. Plug Back Depth (MD+TVD)10,901, MD/10,379' ~ 19' Directi°nal Su~ey I 20' Depth where SSSV Setyes: X No: ~A feet MD ~ 21. Thickne~ of PermafrostN/A 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 22" Sudace 22' Driven 0' 13-3/8" 55 J-55 Sudace 3000' 17.5" 2200 sx 0' 7" 29-23 N-80 & P-110 Suda~ 10,992 9-7/8 1692 sx Window cut 10168-10182' 24. Pedomtions open to Production (M~TVD of Top and BoEom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) 10161' - 10864' MD SIoEed liner. 3-1/2" 10063' 10018' 24 slot~ff, 1/8" wide, 2.5" long, 12 slotCmw 26. ACID, FRACTURE, CEMENT SQUEEZE, ~C. 10161' - 10377' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 24 slot~ff, 1/8" wide, 2.5" long, 12 slot~mw 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) 14 August 2000~ Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 22 Aug 2000 24 TEST PERIOD => 17 8934 2 95/64~525000 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 1080 1150 psi 24-HOUR ~TE => 8934 2 37 28. CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock 10320' 10308' Hemlock HB-1 10320' 10308' Hemlock HB-5 10355' 10331' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe ........ . , '" Form 10-407 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more lhan one interval (multiple completion), so state in item 16, and in item 24 show the productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for His well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~.~-~,~,. ~' Item 28: If no cores taken, indicate "none". ANADRILL SCHLUMBERGER Survey report Client ................... : UNOCAL Field .................... : Swanson River Well ..................... : SCU 42-4 API number ............... : 50-133-10109-01 Engineer ................. : Leafstedt COUNTY: .................. : CC #1 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : GROUND LEVEL Depth reference .......... : GL above permanent ....... : 168.00 ft KB above permanent ....... : 187.00 ft DF above permanent ....... : 187.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 185.00 degrees 5-Aug-2000 05:48:57 Page ORIGINAL Spud date ................ : 1960 Last survey date ......... : 05-Aug-00 Total accepted surveys...: 31 MD of first survey ....... : 10161.00 ft MD of last survey ........ : 10901.00 ft 1 of 3 Geomagnetic data ..... Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 00-Y- 0 Magnetic field strength..: 1105.96 HCNT Magnetic dec (+E/W-) ..... : 21.44 degrees Magnetic dip ............. : 73.56 degrees MWD survey Reference Criteria Reference G .............. : 1002.02 mGal Reference H .............. : 1105.96 HCNT Reference Dip ............ : 73.56 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 21.44 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 21.44 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2000 Anadrill IDEAL ID6_iA_21] ANADRILL SCHLUMBERGER Survey Report 5-Aug-2000 05:48:57 Page 2 of 3 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 10161.00 0.00 0.00 2 10168.00 0.00 0.00 3 10175.00 1.90 217.40 4 10181.23 2.50 184.30 5 10195.00 2.50 184.30 0.00 7.00 7.00 6.23 13.77 TVD depth (ft) Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 10161.00 0.00 0.00 0.00 10168.00 0.00 0.00 0.00 10175.00 0.10 -0.09 -0.07 10181.23 0.32 -0.31 -0.14 10194.98 0.92 -0.91 -0.19 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) {deg) i00f) type type 0.00 0.00 0.12 0.34 0.93 0.00 0.00 TIP 0.00 0.00 MWD 217.40 27.14 GYR 204.84 22.13 MWD 191.72 0.00 MWD 6 10206.00 5.40 184.30 7 10217.11 9.86 180.00 8 10237.00 15.30 175.00 9 10245.67 18.49 176.13 10 10276.61 27.23 172.00 11.00 11.11 19.89 8.67 30.94 10205.96 1.68 -1.66 -0.25 10216.96 3.15 -3.14 -0.28 10236.37 7.43 -7.46 -0.06 10244.67 9.92 -9.97 0.14 10273.15 21.69 -21.90 1.46 1.68 3.15 7.46 9.97 21.95 188.38 26.36 185.18 40.44 180.43 27.87 179.21 36.99 176.20 28.70 GYR MWD GYR MWD SP 6-axis 11 10304.60 36.38 171.21 12 10338.26 47.91 171.29 13 10369.64 57.01 171.94 14 10401.28 67.15 174.82 15 10433.05 78.01 175.51 27.99 33.66 31.38 31.64 31.77 10296.91 36.02 -36.47 3.62 10321.83 57.92 -58.76 7.05 10340.93 82.10 -83.35 10.66 10355.73 109.46 -111.09 13.85 10365.22 139.28 -141.25 16.40 36.65 59.18 84.03 111.95 142.19 174.33 32.72 173.16 34.25 172.71 29.05 172.89 33.04 173.38 34.25 SP SP SP SP SP 6-axis 6-axis 6-axis 6-axis 6-axis 16 10448.45 83.44 177.20 17 10454.61 84.99 176.85 18 10478.08 90.41 179.47 19 10518.77 90.62 184.99 20 10549.42 91.34 185.78 15.40 6.16 23.47 40.69 30.65 10367.70 154.30 -156.41 17.36 10368.33 160.37 -162.53 17.68 10369.27 183.64 -185.96 18.43 10368.90 224.27 -226.60 16.85 10368.38 254.91 -257.11 13.97 157.37 163.49 186.87 227.22 257.49 173.67 36.88 173.79 25.79 174.34 25.64 175.75 13.58 176.89 3.49 SP SP SP MWD MWD 6-axis 6-axis 6-axis 21 10581.14 91.37 185.32 22 10613.50 91.37 185.57 23 10643.03 90.41 186.12 24 10676.51 88.04 187.00 25 10702.59 87.91 187.24 31.72 32.36 29.53 33.48 26.08 10367.63 286.62 -288.67 10.90 10366.85 318.97 -320.87 7.83 10366.39 348.49 -350.25 4.83 10366.85 381.96 -383.50 1.00 10367.77 408.00 -409.36 -2.23 288.88 320.97 350.28 383.50 409.37 177.84 1.45 178.60 0.77 179.21 3.75 179.85 7.55 180.31 1.05 SP SP SP SP SP 6-axis 6-axis 6-axis 6-axis 6-axis 26 10734.46 87.81 186.96 27 10768.99 87.60 187.48 28 10801.38 85.36 188.39 29 10835.27 85.92 187.55 30 10842.41 85.99 187.61 31.87 34.53 32.39 33.89 7.14 [(c)2000 Anadrill IDEAL ID6_iA_21] 10368.96 10370.34 10372.33 10374.91 10375.41 439.83 -440.97 -6.16 474.30 -475.20 -10.50 506.59 -507.21 -14.96 540.33 -540.68 -19.65 547.45 -547.74 -20.59 441.01 475.31 507.43 541.04 548.13 180.80 0.93 SP 181.27 1.62 MWD 181.69 7.46 SP 182.08 2.97 SP 182.15 1.29 SP 6-axis -- 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 5-Aug-2000 05:48:57 Page 3 of 3 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) Projected to TD 31 10901.00 85.99 187.61 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 58.59 10379.51 605.83 -605.67 -28.33 606.33 182.68 0.00 Srvy tool type MWD Tool qual type [(c)2000 Anadrill IDEAL ID6_iA_21] UNOCAL RKB = 17.1' 5 6 10992' 11 12 11315' CASING AND TUBING DETAIL SIZE WT GRADE · vanson River ,Cell SCU 42-4 Sidetrack Completion CONN !I) TOP BTM, 22" 13-3/8" 7" 3-1/2" liner slotted Tubing 4-1/2" 3-1/2" 54.5 J-55 29 N-80 26 N-80 23 N-80 26 N-80 29 N-80 26 P-110 29 P-110 9.2 K-55 24slots/~ 1/8"wide 12.6 L-80 9.2 L-80 22' 8rd/ST&C 12.615 Surface 3,000' Buttress 6.184 Surface 304' Buttress 6.276 304' 1,235' Buttress 6.366 1,235' 4,229' Buttress 6.276 4,229' 4,527' 8rd LT&C 6.184 4,527' 6,489' 8rd LT&C 6.276 6,489' 9,346' 8rd LT&C 6.184 9,344' 10,992' Hydril 511 2.992 10,067' 10,898' 2.5" long with 12 slots/row Buttress 3.958 Surf 10,070' Buttress Box x 8rd pin 2.992 10,070 10,095 %% % NO. Depth 1 15' ID JEWELRY DETAIL OD Item 2 2,250 3.958 5.954 3 2,250' 3.813 5.591 3.866 5.984 5.25 5.75 4.438 5.875 4.000 5.625 3.437 5.50 2.813 4.00 2.992 3.5 3.875 5.97 4700' 6800' 8700' 9950' 5 10095' 5a 10044' 6a 10051' 6b 10067' 7 10101' 8 10181 9 10192' 10 10,898' 11 10202' 12 10485' Fish '1 '", Kick offPoint @ 10168-10.181' ,, ,. HI MD10901' ",,. '" H3 · - It5 -, TD = 10,901' MD/10,379' TVD · ! "--. MAX HOLE ANGLE = 91.34 deg Tubing Hanger, 7-1/16" x 4-1/2" 8rd., Type" H" BPV profile. CL prep. 4-1/2" L-80 12.6 ft/lb Butt. tubing 4-1/2 Camco BP-6I LANDING NIPPLE for methanol inj. with 3/8" control line strapped w/168 x 1-1/4" SS bands 4-1/2" GLM Camco KBG-2 with 1" KB2 top lock valves # 1 Gas Lift Mandrel # 2 Gas Lift Mandrel # 3 Gas Lift Mandrel # 4 Gas Lift Mandrel ZXP Liner Top Pkr with 6' x 5.25" ID tieback sleeve Baker HMC liner hanger Seal Bore Extension KOIV flapper, 3.437" ID after flapper knocked out X nipple, 2.813" ID Baker Bottom Trip Whipstock 7" cement retainer 3-1/2" liner shoe Baker SABL-3 7" x 4" Baker Model "F" Chemical gun/CCL 16' long PERFORATION HISTORY Interval Accum. Date Zone Top Btm ~t S~f COmments 5/30/96 G-2 10,147' 10,167' 20' 6 Behind 3-1/2" liner 5/30/96 G-2 10,177' 10,184' - 7-~ ......... 6- Window cut th~ough .......... 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed wso 11/13/77 H-1 10,230' 10,265' ~--~5'- .... 8 ' sqa**zed7.25-0o 11/13/77 H-2 10,275' 10,285' 10' 8 Squeezed 7-25-00 11/1~/77 H-3/4/5 10,310' 10,394' -~4'-- -- 4~8- ' squ .... d 7-25-00 3/11/60 10,402' 10,403' 1' 5 Squeezed 3/~7/60 -- H-8 10,409' 10,4787- 6~~- ' 4 ' Squeezed 7-25-00 3/1-7/60 H-10 1~,,508' 10,585' 77' 4 Squeezed 7-25-00 3lTl/60 10,~-98' 10,5995 ---iV ...... ~ '' Sq~u .... d wso . . 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed SCU 42-4 Schematic Drawn by: LDD 08/30/00 Unocal Alaska Drilling Weekly Drilling Summary Report Abandonment of SCU 341-4 & SCU #42-4 Re Drill 7/13/00 to 7/16/00 7/13/00 7/14/00 7/15/00 7/16/00 Rig up lubricator and APRS wireline and test to 2800 psi-Ok. Make up 3.625" chemical cutter and run in hole. Tie in and locate packer. Make chemical cut at 10,195'. Pull out of hole. Chemical cutter slips start hitting tubing collars at 6800' to 6600' then every other collar to 3800'. Worked free to 3345'. Stuck cutter and failed to work free. Pull out of rope socket. Left 15.91' of wireline tools in the hole. Move in Pollard Wireline. Make up lubricator and test to 2800 psi. Make up Pollard Wireline tools and run in hole to fish. Latch onto fish and hit jars with 800#. Broke overshot and left part of over shot and guide ring in hole. Make up new overshot and run in hole. Engaged fish and sheared off tool. Pull out of hole and left overshot in the hole. Make up new Bowen overshot and run in the hole. Engage fish and jar on fish w/1000g. Jar on fish five times, sheared pins and left Bowen overshot in the hole. Rig down Pollard Wireline and install back pressure valve. Move in and rig up Inland Drilling Rig CC 91. Continue to move in and rig up Inland Drilling Rig CC #1. Unocal Alaska Drilling Weekly Drilling Summary Report Abandonment of SCU 341-4 & SCU #42-4 Re Drill 7/17/00 to 7/23/00 7/17/00 7/18/00 7/19/00 7/20/00 7/21/00 7/22/00 7/23/00 Continue to move in and rig up Inland Drilling CC gl. Nipple up BOPE, weld koll line and picture nipple to fit well head height. Hook up BOPE control lines. Change out 3-1/2" pipe rams to 4-1/2" rams. R/U test chart recorder, pull back pressure valve and set TWC. Rig up to test top drive, both kelly valves leaked. Service top drive valVes and test choke manifold. Finished testing choke manifold, outside check valve, full opening safety valve, pipe rams, blind rams, HCR, dart valve to 250 psi low and 5000 psi high. Re- tested top drive kelly valves-OK. Tested annular to 250/3500 psi-OK. Make up landing joint and engage tubing hanger. Pick up tubing string. Worked string to 160 Klbs. Make blind back off. Backed off after 22 turns. Pull out of hole looking for wireline fish. Finish pulling out of hole with 4-1/2" tubing (314 jts). Top of fish at 9883'. Did not see wireline fish. Rig up Pollard Wireline and run in hole making a feeler run to 10202'. No sign of wireline fish. Lay down wireline tools and lubricator. Run in the hole drifting 4-1/2" tubing to 3.75". Continue to run 4-1/2" tubing. Screw into fish at 9883'. Rig up APRS. Run in hole with 3.625" chemical cutter. Make chemical cut at 9950'. R/D APRS. Pull out of hole laying down 4-1/2" tubing. Finish laying down 316 jts of 4-1/2" tubing + 4.45' cut off. Change out 4-1/2" rams t o 3-1/2"rams. Test to 250 psi/5000 psi-OK. Make up milling assembly. Pick up 3-1/2" drill pipe and drift while running in the hole. Finish picking up 3-1/2" drill pipe. Slip and cut drilling line. Tag 4-1/2" stub at 9949'. Mill over packer at 9954 to 9957'. Pull out of hole and lay down mill. Make up 5-7/8" overshot with 4-1/2" grapple. Finish making up fishing bottom hole assembly. Run in hole and work over the top of the fish at 9949'. Work fish and pull out of hole with the fish. Lay down tubing fish and found that K-22 anchor seal released from lower packer. Make up junk mill and string mill. Run into hole to 10199'. Pull out of hole. Unocal Alaska Drilling Weekly Drilling Summary Report Abandonment of SCU 341-4 & SCU #42-4 Re Drill 7/24/00 7/25/00 7/26/00 7/27/00 7/28/O0 7/29/00 7/30/00 Finish pulling out of hole and lay down string mill and junk mill. Nipple down flow line and rig up lubricator. R/U Schlumberger and run CBL/GR/CCL from 10,190 to 8,000'. Lay down logging tools. Make up Baker mocel K-1 Cement retainer. Run in the hole and set at 10,195'. Rig down Schlumberger. Nipple up flow nipple and flow line. Finish nippling up flow line and flow nipple. Make up Baker Model B snap latch stinger and run in hole on 3-1/2" drill pipe. Make up cement line and test to 4000 psi. Stab into packer and establish injection at 1690 psi w/5 bpm. Batch mix 15.8 ppg cement. Pump 50 bbls of cement and squeeze 49 bbls of cement below cement retainer. Final pump pressure 2000 psi @ 5 bpm. Static surface pressure holding at 1500 psi prior to stinging out of retainer. Reverse out 1 bbl of cement. Pull out of hole and lay down cement stinger. Test BOP and related equipment to 250 psi low and 5000 psi high (annular 250/3500). Kill line check valve failed. Pressure test top drive valves 250 psi low/5000 psi high. Pick up widow milling assembly. Run in hole with whipstock to 10150'. Rig up APRS and Gyro Data. Run in and orientated whipstock to 185 degrs. Set down on cement retainer and set whipstock anchors. Mill window 10,168 to 10,172. Clean pits and drain pumps. Fill pits with oil base drilling fluid. Continue to fill pits with oil base drilling fluid. Circulate and change over oil base drilling fluid. Resume milling window and formation from 10,172 to 10,195'. Circulate hole clean. Pull out of hole. Make up and run in the hole with mud motor and directional drilling assembly. Continue to run in hole with directional drilling assembly. Rig up APRS and Gyro Data. Run in hole and stab into UBHO with gyro. Run in the hole and clean out. Directional drill from 10,195 to 10247. Lost gyro signal. Pull to shoe and pull out hole with wireline. Found damage wireline 245' from bottom of tool string. Cut and re-head wireline. Run gyro back into hole. Continue to directional drill from 10,247 to 10,308'. Pull out of hole with gyro. Rig down side entry sub. Run into hole to 10~308'. Directional drilling from 10,308 to 10,348'. Started losing mud at 30 bbls/hr. Pull to window at 10,182'. Mix loss circulation material. Spot 12 bbl pill in open hole. Continue drilling with losses from 10,348' to 10,438'. Pull out of hole to change bits. Losing .75 bbls/hr. Make bit g2 and run in hole. Repair top drive rail and lost 2 bbls in two hours. Continue to run in hole to 10,438'. Break circulation. Directional drill from 10,438 to 10,478' with 30 bbls of losses in first 2 hours of drilling. Spot 10 bbl LCM pill on bottom. Pull out of hole. ~,~ ~.. ~, ~.. .... Unocal Alaska Drilling Weekly Drilling Summary Report SCU #42-4 Re Drill 7/31/00 to 8/6/00 7/31/00 8/1/00 8/2/00 8/3/00 8/4/00 8/5/00 8/6/00 Pull out of hole and lay down motor. Make up new BHA and run in hole to 1005'. Test MWD. Continue to run in hole slowly to 10,444' filling drill pipe every 3000'. Bring up pumps slowly watching for losses. Directional drill by sliding from 10,478 to 10,508'. Lost 8 bbls in first 1.5 hrs of drilling with pump rate at 172 gpm, increased pump rate to 203 gpm and increased loss rate to 6 bph). Directional drill from 10,508 to 10,632'. Circulate bottoms up and spot a 20 bbl loss circulation pill on bottom. Pull out of hole and change bits. Make up bit no. 4 and orientated MWD. Run in hole with new bit. Lost 12 bbls of mud for the day. Run in hole slowly ~ling drill pipe every 3000'. Break circulation at 10,632'. Directional drill from 10,632 to 10,750'. Tight spot at 10, 676' required jarring w/40klbs and rotating free with 5k ft/lbs. Continue to drill from 10,750 to 10,759'. Pull out of hole for bit change. Mud losses 3-4 bph. Circulate bottoms up and spot 20 bbl loss circulation pill. Pull out of hole monitoring losses. Worked through tight spots at 10,612 and 10,470'. Test BOP and related equipment to 250 / 3000 psi. Make up bit no. 5 and run in hole slowly f'dling drill pipe every 3000'. Continue to run in the hole. Hit and worked through tight spots at 10,590 and 10,645'. Break circulation at 10,759 and bring up pumps slowly to 175 gpm. Directional drill from 10,759 to 10,901'. Circulate a hi-vis pill around. Finish circulating hi-vis pill. Pull out of hole with tight spots at 10,710, 10,680 and 10,620'. Slip and cut drilling line. Losing .5 bph. Rig up to run 3-1/2" liner. P/U 3-1/2" liner and drift liner. Make up and stab and run inner 2-1/16 tubing string inside 3-1/2" liner. Make up liner hanger and isolation valve. Establish circulation though liner with 450 psi at 90 gpm. Continue running liner in on 3-1/2" drill pipe, filling drill pipe every 5 stands. Continue running 3-1/2" liner to 10,898'. Set liner hanger at 10,050'. Displace oil base drilling'fr0m 'slotted liner with base oil. Test liner pa~ei; to 1500 psi for 15 min, lost 25 psi to 1475 psi. Pull out of hole to 10,000'. Clean pits and displace well from oil base drilling fluid to base oil. Unocal Alaska Drilling Weekly Drilling Summary Report SCU 942-4 Re Drill 8/7/00 to 8/11/00 8/7/OO 8/8/00 8/9/00 8/10/00 8/11/00 Finish displacing well to base oil. Clean shakers, shaker tank, possum belly. Pull out of hole cleaning drill pipe. Lay down liner hanger setting tool and 2- 1/16" inner string. Pull wear bushing and install test plug and 4-1/2" top rams. Finish changing 4-1/2" top rams. Test to 250/3000 psi-ok. Rig up and run 4- 1/2" tubing string drifting to tubing and gas lift mandrels to 3.75". Make up ported chemical injection mandrel and test. Continue to run 4-1/2" tubing with 3/8" chemical line. Continue running the 4-1/2" gas Completion. Space out completion and make up tubing hanger. Test chemical injection line to 5000 psi-ok. Clean pits and prepare floor to rig down. Make up landing joint and land tubing. Test tie-back seals to 500 psi. Set back pressure valve. Continue to clean pits. Flush pumps, choke manifold, lines and BOP stack. Nipple down choke line valves, HCR, gas buster and degasser. Continue to nipple down BOPE. Nipple up adapter flange and production tree and test to 5000 psi, OK. Rig up Pollard Slickline unit. Make up lubricator and test to 3000 psi. Run in the hole and pull blanking sleeve. Pump through chemical line. Rig down Pollard Slickline. Set back pressure valve and secure well. Remove Tesco Top Drive from derrick. Continue to rig down and load out equipment. Inland Drilling CC gl released at 1200 hrs on 8/10/00. Move rig off well. Clean up pad and remove liner. Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 265-7889 Fax: (907) 263-7828 E-maih childersd @ unocal, corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL August 29, 2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: i-i~i-Well-:'~' ~":~:/:i; ~ ~' LOG~PE ~:t-:SCALE LOG DATE INTERVAL COPIE Medium SCU~14-3 Thermal Decay Tool/Sigma Logs 2/5 INCH 7/22/00 3400-8200 1B-Line SCU:~4-3 Thermal Decay Tool/Sigma Logs 2/5 INCH 7/22/00 3400-8200 1 Film SCU 23A-9 MWD GR Measured Depth Log 2/5 INCH 7/1/0010180-10910 1B-Line SCU 23A-9 MWD GR Measured Depth Log 2/5 INCH 7/1/0010180-10910 1Film SCU 23A-9 MWD GR True Vertical Depth Log2/5 INCH 7/1/0010180-10910 1B-Line SCU 23A-9 MWD GR True Vertical Depth Log2/5 INCH 7/1/0010180-10910 1Film SCU 323-9 Plug Setting Record 5 INCH 6/24/00 !9900-10240 1B-Line SCU 323-9 Plug Setting Record 5 INCH 6/24/00 9900-10240 1Film SCU 42-4 Cement Bond Log / Gamma Ray-CCL 5 INCH 7/24/00 8000-10190 1B-Line SCU 42-4 Cement Bond Log / Gamma Ray-CCL 5 INCH 7/24/00 8000-10190 1Film SCU 42-4 MWD GR Measured Depth Log 2/5 INCH 7/27/00 10165-10845 1B-Line SCU 42-4 MWD GR Measured Depth Log 2/5 INCH 7/27/00 10165-10845 1Film SCU 42-4 MWD GR True Vertical Depth Log2/5 INCH 7/27/00 10165-10845 1B-Line SCU 42-4 MWD GR True Vertical Depth Log2/5 INCH 7/27/00 10165-10845 1Film SCU 42-4 Plug Setting Record 5 INCH 7/24/00 8000-10190 1B-Line SCU 42-4 Plug Setting Record i5 INCH 7/24/00 8000-10190 1Film Please acknowl~~rec/~ipt by sigp~ng and 'returning one copy of this transmittal or F~ ~ ¢0~) [2~-~-82~.~ I Received ~-~/(,~~ I Date: AU(} B0 '000 J Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COPlMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Donald S. Byrne Acting Drilling Superintendent Unocal P O Box 196247 Anchorage, AK 99519-6247 Re~ Soldotna Creek Unit SCU 42-4 Unocal Permit No: 200-087 Sur Loc: 1000'FNL, 1170'FEL, Sec. 4, T7N, R9W, SM Btmhole Loc. 1670'FNL, 1229'FEL, Sec. 4, T7N, R9W, SM Dear Mr. Byrne: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission at 279-1433. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this --;7 /~'~ day of July, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la: Type of work Drill [] Redrill X I lb. Type of well Exploratory [] Stratigraphic Test [] Development Oil Re-entry [] Deepen []I Service [] Development Gas ~_ Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Unocal 180' RKB Swanson River Field 3. Address P.O. Box 196247 6. Property Designation Hemlock Anchorage. Ak 99519-6247 A-28997 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (see 1,000' FNL, 1,170' FEL, Sec. 4, T7N, R9W, SM Soldotna Creek Unit 20AAC25.025) AK Statewide Oil & Gas Bond At top of productive interval Hemlock H-4 @ 10,317' TVD 8. Well Number Number 1,073' FNL, 1,176' FEL, Sec. 4, T7N, R9W, SM SCU 42-4 U 62-9269 At total depth 9. Approximate spud date Amount 1,670' FNL, 1,229' FEL, Sec. 4, T7N, R9W, SM 6/20/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15 Proposed depth (MD and property line TVD) 1,000' 1,008' (SCU 332-4) Lease 2560 acres 10,948' MD @ T.D. 10,360' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Kickoff depth 10170 feet Maximum hole angle 90° Maximum Surface 1030 psig. At total depth (TVD) 2000 psig 18. Casing Setting Depth program size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6" 3-1/2" 9.2 J-55 Flush Jt 881' 10,067' 10,067' 10,948' 10,360' None, slotted liner 0RIG'NAL 19. To be completed for Redrill, Re-entry and Deepen Operations I 9 ~.... ~' ~' !i,:~,~ ' ;~. Present well condition summary Total depth: measured 11,315 feet Plugs (measured) True vertical 11,315 feet r ..... Effective Depth measured 10,580 feet Junk (measured) .... ~",,!~1~.* ~'~' ~;~'~':"~:~:~ L~,:-~S ....... L-..~'!~.;' .... True vertical 10,580 feet .;.,~. Casing Length Size Cemented Measured Depth True Vertical Depth Structural Conductor 22' 22" Yes 22' 22' Surface 3,000' 13-3/8" 2,200 sx 3,000' 3,000' Intermediate Production 10,992' 7" 1,692 sx 10,992' 10,992' Liner Perforation Depth: Measured 10,147'-10,167'; 10,177-10,184'; 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394'; 10,409'-10,478'; 10,508'-10,585' True Vertical 10,147'-10,167'; 10,177-10,184'; 10,230'-10,265'; 10,275'-10,285'; 10,310'-10,394'; 10,409'-10,478'; 10,508'-10,585' 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~ '~ ~ /~-Title: Drilling Manager Date Commission Use Only Permit Number APlNumber ~__~ ~-.. I Approval date I See cover letter ~--~:~:)~'~ 50- / ~"~ '"/ /~ ~" ~-----)/ for other requirements Conditions of approval Samples required [] Yes ~No Mud log required [] Yes ~'No Hydrogen Sulfide measures El Yes ~No Directional Survey required ,,~Yes [] No Required working pressure for DOPE [] 2M [] 3M ]~i~5M [] 10M [] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 AFE# Submit in triplicate 0RI$1NAL Hazard Section Application for Permit to Drill SCU 42-4 There are no known over-pressured intervals in the proposed drilling interval of SCU 42-4. The deep kick-off point of 10,170' MD/TVD is in the G-2 interval. However, in the drilling of the original production hole, abnormal pressure was experienced in an in~_e~!~.~(~.,~75-~,9301).~!~at.required a 13.1 ppg mud weight to drill. After setting 7" production casing Standard performed block squeezes due to a poor primary cement job. A cement bond log was not run in the well. A 1996 test of the G-Zone in this well indicated that it is isolated and not in communication with over pressured strata from above and that the G-zone is not abnormally pressured. The remainder of the drilling to TD of 10,948'MD/10,360'TVD will be in the Hemlock. Data from the Hemlock indicates a depleted pore pressure of 0.20 psi/ft for an equivalent mud weight of 3.8 ppg. The proposed oil based mud program of 8.4 ppg mud density will be sufficient to control the reservoir pressure down to 10,948' TD. Lost circulation is possible while drilling the well so attention will be directed towards good drilling practices including slow trips in/out of the hole, accurate monitoring of trips with a trip sheet and keeping the hole full by circulating over the top of it. Lost circulation will be treated initiallywith Ventrol 401. If losses still occur, 100 ppb liquid casing and CaCO3 will be added to the oil based mud system. Mud and Cuttings Disposal The oil based mud from SCU 42-4 will be disposed in the mud disposal well, SCU ¢f-43-4MD. The cuttings generated by drilling 42-4 will be disposed in the solid waste facility at Swanson River Field. Abandon SCU 341-4 General Sidetrack Procedure SCU 42-4 (Formerly SCU 341-4) 1) RU coil tubing, RIH and tag fill at 10,580'. 2) Mix and cement volume to cover from PBTD to tubing tail· Appx cmt volume = (10,580'-10,225') x .0371 bbl ft for 7" 29# = 13.17 bbl Total cmt volume = 13.17 bbl. 3) Once cement has reached end of Coiled Tubing, extract coil at a 1:1 ratio pulling one foot for every one foot of displacement. Once cement volume has been pumped, displace with water. While pumping water, continue extraction of CT to 9,000'. Circulate coil clean. Shut in well and squeeze away 5 bbls. RIH to tubing tail and circulate· 8) POOH and rig down coil tubing unit. 9) Set plug in XN Nipple at 10,217' 10) Cut tubing at 10,195'· Punch tubing at 9,980'. Redrill SCU 42-4 1) Move in Inlet Drilling Rig #CC-1. 2) NU and Test BOPE to 3,~u~p~. Pull completion tubing. Mill packer at 9,956' and retrieve. 3) 4) 5) RU e-line. Run Cement Evaluation Log. 6) RIH and set 7" bridge plug at approximately 10,170'. 7) RIH with 7" whipstock on drill pipe and set whipstock on top of bridge plug at 8) Mill window at 10,170' and commence horizontal redrill of SCU No. 42-4. 9) Directionally drill 6" hole from 10,170'MD/TVD to 10,948'MD 10,360'TVD. 10) Run 3-1/2" Hydrill 511 Slotted Liner with 2-1/16" inner string from TD to 10,948'. 11) Set hanger, release from hanger and flush out mud outside and inside slotted liner via 2-1/16" inner string. 12) RIH with top packer on drill pipe. Set 3-1/2" x 7" Liner top packer, pressure test liner top packer to 1,500 psi. POOH with drill pipe and packer setting tool. 13) Run 3-1/2" tubing completion with seal assembly stabbed into liner top packer tie back sleeve. Completion includes methanol injection mandrel with chemical injection line down to approx. 2,500' and approx. 5 ea. Gas lift mandrels for kick off/unloading purposes. 14) Install and test tree. Move drilling rig. Install flowline and methanol injection pump at surface. 16) Gas lift well if necessary to initiate gas production. UNOCAL Schlumberger Proposed Well Profile - Geodetic Report Client: Unocal Field: Swanson River Unit Structure: Soldotna Creek Unit 323-09 Well: 341-04 Borehole: 341-04A (P3) UWlIAPI#: 501331010901 Date: May 05, 2000 Grid Convergence: -0.74846083= Scale Factor: 0.99992684 Location: : Coordinate System: N 60 43 52.172, W 150 51 28.733 N 2460178.000 flUS, E 346420.000 ftUS NAD27 Alaska State Planes, Zone 4, US Feet Survey Computation Method: Minimum Curvature DLS Computation Method: Lubinski Vertical Section Azimuth:~ 185.000° Vertical Section Origin: N 0.000 fl, E 0.000 ft TVD Reference: KB 180.0 fl above MSL Magnetic Declination: 21.492° Total Field Strength: 55296.922 nT Dip: 73.563° Declination Date: April 27, 2000 Magnetic Declination Model: BGGM 1999 North Reference: True North Coordinate Reference To: Well Head Grid CoOrdinates Geograph!c Coordinates I Station ID I' MD IIncl(ft) (°) I Azim I (°) TVD (ft} I VSec I (fi) N/'S I E/'W I (ft) (fl) (°/lOOft) DLS N°rthing I Easting (flus) (flUS} Latitude Longitude Top Whipstock 10155.00 0.00 185.00 10155.00 0.00 0.00 0.00 0.00 2460178.00 346420.00 N 60 43 52.1 Base Whipstock 10167.00 2.00 185.00 10167.00 0.21 -0.21 -0.02 16.67 2460177.79 346419.98 N 60 43 52.170 W 150 51 28.733 Build 29.5/100 10172.00 2.00 185.00 10171.99 0.38 -0.38 -0.03 0.00 2460177.62 346419.97 N 60 43 52.168 W 150 51 28.733 Base G2 10185.04 5.83 185.00 10185.00 1.27 -1.27 -0.11 29.41 2460176.73 346419.87 N 60 43 52.159 W 150 51 28.735 10200.00 10.24 185.00 10199.81 3.37 -3.35 -0.29 29.41 2460174.65 346419.67 N 6043 52.139 W 150 51 28.739 Top H1 10231.26 19.43 185.00 10230.00 11.36 -11.32 -0.99 29.41 2460166.70 346418.86 Top H2 10274.68 32.20 185.00 10269.00 30.23 -30.11 -2.63 29.41 2460147.93 346416.98 10300.00 39.65 185.00 10289.49 45.07 -44.90 -3.93 29.41 2460133.16 346415.48 Top H3 10324.02 46.71 185.00 10307.00 61.50 -61.27 -5.36 29.41 2460116.81 346413.84 Top H4 10339.26 51.19 185.00 10317.00 72.99 -72.71 -6.36. 29.41 2460105.39 346412.69 Top H5 10377.72 62.51 185.00 10338.00 105.14 -104.74 -9.16 29.41 2460073.40 346409.47 10400.b0 69.06 185.00 10347.13 125.45 -124.97 -10.93 29.41 2460053.19 346407.44 End Build 10471.20 90.00 185.00 10360.00 195.07 -194.33 -17.00 29.41 2459983.92 346400.46 TD 109,48.20 90.00 185.00 10360.00 672.07 -669.51 -58.57 0.00 2459509.36 346352.69 N 60 43 52.060 W 150 51 28.753 N 60 43 51.875 W 150 51 28.786 N 60 43 51.730 W 150 51 28.812 N 60 43 51.568 W 150 51 28.841 N 60 43 51.456 W 150 51 28.861 N 60 43 51.140 W 150 51 28.917 N 60 43 50.941 W 150 51 28.953 N 60 43 50.258 W 150 51 29.075 N 60 43 45.579 W 150 51 29.911 341-04A (P3) report Page 1 of 1 5/5/00-4:24 PM UNOCAL VERTIC2tL SECTION VIEW Client: Unocal Well: 341-04A (P3) Field: Swanson River Unit Structure: Soldotna Creek Unit Section At: 185.00 deg Date: May 05, 2000 Schlumberger 10000- 10200 10500 Top Whipstock 10155MD 10155TVD 0 de~re ~ ~e ~ipstock ~ 10167MD 10167~ ~ 2'00~ 185.00~ = ~ o d,~e ........... ~Z ~2~S2 ~ Dj0?~Z .......... ~ ...... - - ~ Build 29.5/101 ~0L72~ 1J ~17~ ~ ...... ~ H~ 1~2] 1 ~D~0~30~ ......... 2.00~ t85.00~ ~ 0 de~um T~H2 1(~75 MD 10269~ 'EWd Bu~ ....................... /171 MD 10~0~D -.-~ / 90.00" !85.00~ "~ T~ I',3 ;0324 MD 10307 -~ / _19~ure _T~t ~9M~l~ll~D_ _ _ .... / ~ Hi 10~7~ U~ J03~8~ ............. o TD 10~; MD 10~0~ Hold Angle 90.00~ 90.o0 185.oo 672 c ..... 8u~ .... 0 200 400 600 Vertical Section Departure at 185.00 deg from (0.0, 0.0). (1 in = 100 feet) UNOCAL PI~VI~ Client: Unocal Well: 341-04A (P3) Field: Swanson River Unit Structure: Soldotna Creek Unit Scale: 1 in = 100 ft Schlumberger A A A 0 z v v v -200 -100 0 100 200 -2( .400 -700 .Top I/hipstock ~ / Bas~ Whipstock 10151 MD 10155TVD~ ./ 1016 MD 10167'rVD 0.00° 185.00° az 2.00' 185.00° az ON E OS )W Build 29.5/1110 True North 2.00° 185.0 D° az Mag Dec ( E 21.49° ) 0f OW /~---------_ ;nm R,,ilH -200 10471 MD 0360 TVD 90.00° 185. )0° az 194S 17V~ - - - -400 _ --- _ i'D 10948 MD 10360 TV[ ;)0,00° 185.00° az 370 $ 59 w .. -_ -- <<< WEST EAST >>> Swanson River Well SCU 42-4 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface pressures (ASP) during drilling of the sidetrack SCU 42-4. The pore pressure gradient was estimated from the following information: BHP Depth Well psi TVD EMW, ppg Comment 42-4 2000 10,145' 3.8 ppg or .20 psi/ft Depleted Hemlock and G-zone The fracture gradient at sidetrack window at 10,170' is estimated at .70 psi/ft or 13.5 ppg. Casing Pore Casing Setting Fracture Pressure Mud Size Depth Gradient Gradient Weight (in....) (TVD ft) (lbs/gal) (lbs/gal) (lb/gal) Pore ASP Pressure Drilling (psi) (psi) 7" 10,170 13.5 3.8 8.4 2034 1030 3-1/2" Inr 10,360 NA 3.8 8.4 2072 Procedure for' Calculating Anticipated Surface Pressure While Drilling ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat (with gas bubble just below shoe and mud gradient above shoe) or 2) formation pore pressure at the next casing point less gas gradient to the surface as follows: 1) ASP = (FGx.052xD) - (MWx.052xD) -- (13.5 x .052 x 10170) - (8.4 x .052 x 10170) =2697 psi OR 2) ASP : FPP - (0.1gas gradient xD) : 2072 - (.lx10,360') - 2072 - 1042 = 1030 psi Production Casing SIZE WT SCU 42-4 Casing Design GRADE CONN ID TOP ,, 29 N-80 Buttress 6.184 Surface 26 N-80 Buttress 6.276 304' 23 N-80 Buttress 6.366 1,235' 26 N-80 Buttress 6.276 4,229' 29 N-80 8rd LT&C 6.184 4,527' 26 P-110 8rd LT&C 6.276 6,489' 29 P-110 8rd LT&C 6.184 9,344' Worst case for burst is tubing leak near the surface after the well Burst = 10,170' x ((3.85 formation x .052) - 0.1 gas grad)) = 1,019 psi Worst case for collapse is if lost returns occur while drilling below Collapse = (12.6 x.052 x10,170') -(10,170' x .1) = 5646 psi for full evacuation Collapse = (12.6 x .052 x 9,346')-(9,346' x .1) = 5,188 psi for full evacuation Collapse = (12.6 x .052 x 6,489')-(6,489' x .1) = 1,571 psi for full evacuation Tension = NA (casing already in place and cemented) 3-1/2" 9.2#, J-55, Slotted Liner @ 10,984' MD/10,360' TVD Tension - (10,948'-10,067') x 9.2#= 8.1K Collapse = Not applicable for slotted liner Burst = Not applicable for slotted liner BTM. 304' 1,235' 4,229' 4,527' 6,489' 9,346' 10,992' is completed. 7" 23# rated @ 6,340 psi for burst Safety Factor - 6.2 OK the 7" casing. 29# P-110 rated @ 8,510 psi Safety Factor - 1.5 OK 26# P-110 Rated @ 6,230 psi Safety Factor- 1.2 OK 29# N-80 Rated @ 7,020 psi Safety Factor - 1.95 OK Rated = 118K for connection yield Safety Factor = 14 OK SCU No. 42-4 Casing Specifications Proposed Casing Liner 3-1/2" 9.2#, J-55, Flush Joint Tubinq, slotted Joint Strength, K lbs 118 Body Strength, K lbs 142 Burst Rating, psi NA, slotted liner Collapse Rating, psi NA, slotted Cplg OD, in (flush jt) 3.5 CSGSPEC 42-4 SCU 42-4 Cementing Program 3-1/2" Slotted Liner The deep kick-off point of 10,170' results in the proposed sidetrack penetrating only the G-2 and Hemlock intervals. It is not necessary to isolate the G-2 from the Hemlock productive intervals so a slotted liner will be run instead of cementing a solid liner. UNOCAL .... RKB to Tbg. Spool = 17.10' A B G-2 SCU 341-4 Draw 8-1~ C SIZE WT Swan.~n River Soldo .a Creek Unit Well No. 341-4 Actual Completion 8/12/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 13-3/8" 7" 54.5 29 26 23 26 29 26 29 Tubing 4-1/2" 12.6 22' J-55 8rd/ST&C 12.615 Surface 3,000' N-80 Buttress 6.184 Surface 304' N-80 Buttress 6.276 304' 1,235' N-80 Buttress 6.366 1,235' 4,229' N-80 Buttress 6.276 4,229' 4,527' N-80 8rd LT&C 6.184 4,527' 6,489' P-110 8rd LT&C 6.276 6,489' 9,346' P-110 8rd LT&C 6.184 9,344' 10,992' L-80 Mod. Butt. 3.958 17.10' 10,190' NO. Depth I__D_D 1 17.10' JEWELRY DETAIL OD Item Tubing Hanger, 4-1/2" EUE 8rd Lift Thread x 4-1/2" Buttress Suspension Thread, Type 'H' BPVP 2 9,956' 3.875 5.970 3 9,969' 3.958 5.20 4 10,199' 3.875 5.850 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.725 5.20 8 10218' 3.958 5.20 9 10,225' 3.958 5.20 Scab Liner/Tubing Assembly Packer, Permanent 7" x 4" Baker SB-3 7 jts. Tubing, 4-1/2", 12.6#, L-80, Modified Buttress Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab __ 3/11/60 H-1 10,226' 10,227' 1' 5 Squeezed WSO 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' 84' 4/8 3/11/60 10,402' 10,403' 1' 5 Squeezed 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 3/11/60 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 10,600' 10,601' 1' 5 Squeezed 3/11/60 WF 10,965' 10,966' 1' 5 Squeezed PBTD = 10,850' TD = 11,315' MAX HOLE ANGLE = Vertical CORRECTED BY: sit ~S~iS'~!i~ 3/15/00 UNOCAL RKB to Tbg. Spool = 17.10' A TOC approx. 10,3 50' SCU 341-4 Draw SIZE Swanson River :~ Soldotna Creek Urn. Nell No. 41A-4 (Formerly 341-4) Proposed Sidetrack, June 2000 CASING AND TUBING DETAIL WT GRADE CONN 1D TOP BTM. 22" 13-3/8" 7" ,, Tubing 54.5 29 26 23 26 29 26 29 22' J-55 8rd/ST&C 12.615 Surface 3,000' N-80 Buttress 6.184 Surface 304' N-80 Buttress 6.184 304' 1,235' N-80 Buttress 6.184 1,235' 4,229' N-80 Buttress 6.184 4,229' 4,527' N-80 8rd LT&C 6.184 4,527' 6,489' P- 110 8rd LT&C 6.184 6,489' 9,346' P-110 8rd LT&C 6.184 9,344' 10,992' NO. Depth ID JEWELRY DETAIL OD Item 2 10,166' 3 10,166' 4 10,199' 3.875 5.850 5 10,202' 3.875 5.970 6 10,207' 3.958 5.20 7 10,217' 3.725 5.20 8 10218' 3.958 5.20 9 10,225' 3.958 5.20 7", 29#, Whipstock 7" Bridge Plug Traveling Anchor Seal Assembly, Baker Packer, Permanent, 7" x 4" Baker SABL-3 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress 'XN' Nipple, 4-1/2" Buttress (3.725" I.D.) 1 ea. Pup, 4-1/2", 12.6#, L-80 Modified Buttress WLEG NO. Depth Item Notes A 2,002' 13-3/8" Stage Collar B 6,944' 7" Stage Collar C 10,485' Packer, 7" x 4", Baker Model 'F' PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf C0~-ments 5/30/96 G-2 10,147' 10,167' 20' 6 Isolated By Scab 5/30/96 G-2 10,177' 10,184' 7' 6 Isolated By Scab _ 3/11/60 H- 1 10,226' 10,227' 1'- 5 Squeezed WSO 11/13/77 H-1 10,230' 10,265' 35' 8 11/13/77 H-2 10,275' 10,285' 10' 8 11/13/77 H-3/4/5 10,310' 10,394' 84' 4/8 3/11/60 - 10,402' 10,403' 1' 5 Squeezed __ 3/17/60 H-8 10,409' 10,478' 69' 4 3/17/60 H-10 10,508' 10,585' 77' 4 3/11/60 - 10,598' 10,599' 1' 5 Squeezed WSO 3/11/60 - 10,600' 10,601' 1' 5 Squeezed __ __ 3/11/60 WF 10,965' 10,966' 1' 5 :Squeezed PBTD = 10,850' TD = 11,315' i.' ~,'/ i.:'~ ]~..S~'r' ~,:j¥ MAX HOLE ANGLE = Vertical CO~CTED BY: slt REVISED: 3/15/00 UNOCAL ,~q;wanson River Nell SCU 42-4 Proposed Sidetrack Completion RKB= 17.1' ~ G2 CASING AND TUBING DETAIL SIZE WT GRADE 22" 13-3/8" 7" CONN ID TOP BTM. 54.5 J-55 29 N-80 26 N-80 23 N-80 26 N-80 29 N-80 26 P-110 29 P-110 9.2 K-55 22' 8rd/ST&C 12.615 Surface 3,000' Buttress 6.184 Surface 304' Buttress 6.276 304' 1,235' Buttress 6.366 1,235' 4,229' Buttress 6.276 4,229' 4,527' 8rd LT&C 6.184 4,527' 6,489' 8rd LT&C 6.276 6,489' 9,346' 8rd LT&C 6.184 9,344' 10,992' Hydril 511 2.992 10,067' 10,948' 3-1/2" liner slotted Tubing 3-1/2" 9.2 L-80 Buttress 2.992 Surf 10,067' JEWELRY DETAIL NO. Depth ID OD Item 1 15' - Tubing Hanger, 7-1/16" x 3-1/2" Butt., Type" H" BPV profile. CL prep. 2 2.992 3.500 3-1/2" L-80 9.3 ft/lb Butt. tubing 3 2000' 2.867 5.313 Gas Lift Mandrels Macco SFO-I, appx five total 4 2,500' 5 10040' 6 10067' 7 10067' 8 1O17O' 9 10170' 10 10,948' 2.867 5.500 2.813 Methanol Injection Mandrel Macco SFO-1CI Baker 3-1/2" 'CMU' Sliding Sleeve Baker Locator type seal assembly (5.25" OD) Baker "ZXP" Liner Hanger with 10' tieback extension Baker Bottom Trip Whipstock 7" bridge plug 3-1/2" liner shoe Kick off Point ~ 10170' ~ H5 TD = 10,948' MD/10,360' TVD MAX HOLE ANGLE = 90 deg SCU 42-4 Proposed Schematic Drawn by: TCB 05/23/00 Drilling Fluid Program Unocal Swanson River Unit SCU 341-4 May 12, 2000 MUd Type: Oil base invert oil mud (Versadrill) 6" hole Vendor: M I Formulation: Mapco 200 (200 degree flash point) Calcium chloride brine (10.2 PPG) V G-69 - organophlic clay Versacoat Versawet Lime Barite Calcium carbonate Properties: Mud Weight = 8.4 lb/gal Funnel Viscosity = 80 sec/qt Plastic Viscosity = 15 to 20 cps Yield Point = 12 to 20 lb/100 ft2 Gels = 12/20 lb/100 ft2 Oil Water ratio = 85/15 HPHT < 10 cc This well will be drilled using high flash point base oil - invert emulsion mud system. This system is recommended because of improved bore hole stability, reduced torque and drag and reduced chances of differential sticking. Displacement to oil base mud will take place after milling the window. Properties will be adjusted as indicated from well conditions. All cuttings will be collected in cutting boxes and properly disposed. No fluids will be discharged. All fluids will be stored in contained areas. Lost circulation material will be available on location. After the well is drilled and the slotted liner is run. The slotted liner will be displaced to diesel. The oil mud system will be stored for use on a future project. %1/16", 5M, Shaffer Annular 7-1/16", 5M, Shaffer Double Gate 7-1/16", 5M, Mud Cross w/Y', 5K, Outlets 7-1/16", 5M, Shaffer Single Gate 7-1/16", 5M, Spacer Spool ,9 ].2,, Concrete ~r 15" Approx. 15" 15-1/8" , Welded 13-3/8" 799 7-1/16" 5M X 13-5/8" 3M Superior Tbg. Spool Mod. SM- TCM 13-5/8" 3M KD Head ]2" Concrete UNOCALe/ BOP Hookup Well SCU 341-4 Swanson River, Alaska Drawn by: TCB Date: 5-10-00 Blowout Prevention Equipment Inlet Drilling Rig #CC-1 or Equivalent 7-1/16" BOP Equipment Iea .1 ea 7-1/16" x 5000 psi wp single ram type preventer 7-1/16" x 5000 psi wp dOuble ram type preventer Iea 7-1/16" x 5000 psi wp annular preventer 1 ea 7-1/16" x 5000 psi wp drilling spool with 2 ea 4" side outlets (choke and kill), HCR and manual valves on choke line and two manual valves on kill line. Kill line also has a check valve. Iea Koomey BOP control unit with 120 gallon volume tank, w/twelve lO-gallon accumulator bottles and nitrogen back-upsystem. Valve at annular preventer on Koomey line, . . Iea 5 station, remote control panel Iea 5,000 psi choke manifold with Cameron automatic hydraulic choke 3" - 10,000 psi with control choke panel. I lot Hydraulic pipe and fittings from manifold to BOP stack. Drilling Fluid System Description Inlet Drilling Rig #CC-1 Mud Pumps Iea PZ9 Gardner Denver, 3"x 5000 psi shear release valve and a 4" x 4000 psi gates bumper hose powered by a 398 TA Cat. 1' ea 214P Oilwell powered by twin 671 Detroit diesel engines. Mud Tank System (466 bbl Total Volume). Tank A- 88 bbl suction tank Tank B- 150 bbl middle tank Tank C- 172 bbl shaker tank Tank D- 27 bbl pill tank Tank E- 17 bbl centrifuge tank Tank F- 12 bbl sand trap Trip Tank- 35 bbl 501 bbl total Mud System Equipment 1 ea Brandt dual tandem 800 gpm shale shakers 1 ea Drilco See-FIo degasser Iea 36" x 6' Poor Boy gas buster Iea Pioneer eight cone desilter Iea Pioneer Model S-800 mud hopper 3 ea Medearis 3" revolving mud agitator guns 1 ea Pit level indicator with audio and visual alarms Iea Fluid flow sensor Iea Gas monitoring for H2S and LEL with sensors at rig floor, sub and shakers. MUD TANKS ATTACHMENT E · 8bD BbP/-/'~ Bbl~ , Drilling Fluid System Description Inlet Drilling Rig #CC-1 Mud Pumps 1 ea Iea PZ9 Gardner Denver, 3"x 5000 psi shear release valve and a 4" x 4000 psi gates bumper hose powered by a 398 TA Cat. 214P Oilwell powered by twin 671 Detroit diesel engines. Mud Tank System (466 bbl Total Volume) Tank A- 88 bbl suction tank Tank B- 150 bbl middle tank Tank C- 172 bbl shaker tank Tank D- 27 bbl pill tank Tank E- 17 bbl centrifuge tank Tank F- 12 bbl sand trap Trip Tank- 35 bbl 501 bbl total Mud System Equipment 1 ea 1 ea 1 ea 1 ea 1 ea 3 ea Brandt dual tandem 800 gpm shale shakers Drilco See-FIo degasser 36" x 6' Poor Boy gas buster Pioneer eight cone desilter Pioneer Model S-800 mud hopper Medearis 3" revolving mud agitator guns 1 ea 1 ea Iea Pit level indicator with audio and visual alarms Fluid flow sensor Gas monitoring for H2S and LEL with sensors at rig floor, sub and shakers. 17 Swanson River Field Kenai Peninsula, Alaska 8N-9W ~0 t SWANSON RIVER -UNIT !8 43-28 .1LAJ~F.,HOUSE AND 14A-33 23-33 13. 34 24-33 '1-4 21A-4 OWE 42A-f5 ,42B-fi 314-4 DISPOSAl, 34 -8 243-8 3t2-g 32A-I 412-22 331 0.-2? 27 ~PILL EQUIPMENT 23-22 4-34 21_3° 43-9 10 34-8 1 I $OLDOTNA . I CREEK i UMT I J. 44~.~.8 ! :?o 1, -16 t j / / ! I I I t 22-23 I I l I 23 26 LANDZNG STRIP I I / / I I I I I \ I t 11 Actual SCU 42-4 Pad Drawing 5/16/00 Proposed SCU 42-4 Equipment lay out Drawing RD to 1-4 TS & north trees 5000 gal methanol tanks helipad cat walk parts house Tool shed Rd to LPG loading carrier 2-14 mud pits gen boiler h20 & acc PZ-9 Trailers H20 wells heater & house 8' culverts lite water linef/ hydrants Plant fence dumpster Ambulance & fire trk Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager May 31, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Commissioner Christenson: Attn: Re: Commissioner Robed N. Christenson Application for Abandonment (Form 10-403) Swanson River Field Soldotna Creek Unit No. 341-4 Enclosed is the Sundry Notice (Form 10-403) relating to the abandonment of Soldotna Creek Unit Well No. 341-4. It is proposed to abandon the current SCU No. 341-4 wellbore in order to sidetrack the well and drill a horizontal gas producer in the Hemlock Bench 5 interval which will be named SCU No. 42-4. This well is currently a vertical well producing from Hemlock Benches 1 through 10 as shown on the attached schematic. The G-zone Bench 2 is perforated but is isolated by the current completion. It is proposed to lay a cement plug from 10,580' (top of fill) to the tubing tail at 10,225'. perforations). After spotting the cement, approximatly 5 bbls will be squeezed away placing the top of cement at +/- 10,350'. The objective is to isolate the HB-8 through HB-10 intervals in the old wellbore because of possible future water production. The new sidetrack well will be relatively close to the old wellbore and will be drawing down the HB-5 reservoir pressure. If sufficient isolation in the old SCU 341-4 wellbore is not present, water production from HB- 8 through HB-10 may be drawn up through the old wellbore and crossflow through the HB-5 reservoir into the new horizontal wellbore. After the coil tubing cement placement is completed, the drilling rig will move in and pull the 4-1/2" tubing and top packer. A bridge plug will be set in the G-2 perforations and a whipstock will be set on top of the bridge plug to sidetrack the well. The expected start date for this well is June 21, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Brandenburg at 263-7657. ~:)~..L.c- -~ Dan~'amson Drilling Manager AOGCC cover letter 341-4 abdn Tim Brandenburg Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager May 31, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner Robert N. Christenson Application for Permit to Drill (Form 10-401) Swanson River Field Soldotna Creek Unit 42-4 (Formerly SCU 341-4) Commissioner Christenson: Enclosed is the Application to Drill (Form 10-401) Soldotna Creek Unit Well 42-4. This proposed well will be a Hemlock sand gas producer sidetracked from an existing vertical wellbore, SCU 341-4. The proposed sidetrack has a total course length of 778' of which approximately 571' will be "horizontal" through Hemlock Bench 5. A 3-1/2" slotted liner will be run in the 6" hole to provide hole stability in the production mode. The proposed sidetrack point in the 7" casing will be at 10,170' in the G-2 zone so overpressure problems while drilling will not be a problem. The new well will be drilled to a TD of 10,948' MD/10,360' TVD. An MWD/GR will provide directional and lithological control for the wellpath. There is no history of hydrogen sulfide in the Swanson River Field in any of the formations that this proposed sidetrack will encounter. The expected start date for this well is June 25, 2000 so your timely consideration for approval is appreciated. If there are any questions, please contact Dan Williamson at 263- 7677 or Tim Brandenburg at 263-7657. Dan Williamson Drilling Manager AOGCC cover letter 42-4 redrill Unocal Alaska Resources Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ) May30,2000 Commissioner Robert N. Christenson Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Soldotna Creek Unit #42-4 ADMINISTRATIVE APPLICATION FOR VARIANCE: RULE 5, CONSERVATION ORDER 123-A Dear Chairman Christenson: Enclosed and submitted in triplicate is our application for Permit to Drill Soldotna Creek Unit A-28997 Well 42-4 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2003594 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Verification of Application by the undersigned stating that applicant is acquainted with the facts, pursuant to 20 AAC 25.055 (d)(3), is attached as part of this application. It is requested that the Commission approve' an administrative variance to Rule 5, Conservation Order 123-A for the drilling of well SRU #42-4, A-28997, as the addition of #42-4 will cause more than two completed wells to be within the northeast governmental quarter-section of Section 4, T7N, R9W, SM. Soldotna Creek Unit Well 42-4' The specific location, interval, and depth are as follows: Surface Location: 1,000' FNL, 1,170 FEL, Sec. 4, T7N, R9W, SM Top of Productive interval: 1,073' FNL, 1,176' FEL, Sec. 4, T7N, R9W, SM Total Depth: 1,670' FNL, 1,229' FEL, Sec. 4, T7N, R9W, SM The lease is currently beyond its primary term and is being held by the Soldotna Creek Unit. All applicable provisions of 20 AAC 25.050 (Deviation) have been met for each owner and all operators of governmental sections directly or diagonally offsetting the section where the gas wells are located. Unocal is the owner and operator of all directly or diagonally offsetting sections; therefore, notices by registered mail pursuant to 20 AAC 25.055 (d) are not necessary. If you require additional information, please contact Shannon Martin at 907-263-7882, or Tim Billingsley, Drilling Department at 907-263-7657. Sincerely, Enclosures VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA Lease # 28997 Well: Soldotna Creek Unit #42-4 I, SHANNON W. MARTIN, Legal Analyst, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the Soldotna Creek Unit #42-4 Well. I have reviewed the application submitted for the exception to 20 AAC 25.055 (a)(4) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and r._e~.ired data. DATED at Anchorage, Alaska this j,0t~day~~~.~ -Shannon W. Marti Legal Analyst STATE OF ALASKA ) ) ss THIRD JUDICIAL DISTRICT ) _I.- SUBSCRIBED TO AND SWORN before me this/tOth'-day of May 2000. THE STATE OF ALASKA My Commission expires: : .... :, ,.> )0 "-". + + ~14 E'/ /! + A-28396 A-28399 ~-'"-" ~ 28406 UOC UO~_~ , UOC ~ 2 . ~ 2~' ~'~ / ....... · ~-~ .... // ~ ,,~. A-28990 ~ a-=~ ..... : -v ~ -/:~ ~ uoc + ~ .... ~ ~ ~ · .+ ..... ' I ~ooo' ,,_, ~ .~ ~ ~o~0'~ A-28396 ~ A-28996 ~ - ~ ~""~~~ A-28997 uoc ~ " uoc--E:~ ~ ~'.4,~"~~ uoc ~ ~- ~-3 ~-5 ' ~ , A-28997 "-'~,~ ~ ~.. ~_, "~_. // .... ~1-~ ~ A-28996 ~)~ A-28997 ,~ A~2~,997 21B-16{ b,{~ r ~-5810 .% A-28993 oMo~~ + UOC UOC ~ Soldotna Creek Unit 17 - ' ! PROPOSED PROPERTY 1,~ ~ ~ ~ ~ ~ PLAT SCALE IN ~ET FOR INQUIRIES CONTACT LOCATION WHERE INVOICES WERE SUBMITTED 31-MAY-00 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. DRILLPERMITSCU4 05003000509 DETACH STUB BEFORE DEPOSITING CHECK 100.00 100.00 100.00 100.00 ---- CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCALe Pay One Hundred Dollars And O0 *********************************** 2003594 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 Date CheckAmount V 31-MAY-00 *******100.00 · Void after six months from above date. "'aD0559~1,' ':OS&;~O0i]Oql: 3q~;&~;~57,' COMPANY ~/'~:~42.,,~4~.._ WELL NAME ... ~/~-~.,, PROGRAM: exp~ , WELL PERMIT CHECKLIST dev ~ redrll v/serv wellbore seg ann. disposal para req FIELD&POOL '7'~ ~-/~.~ INIT CLASS '~'-' '- -- - --"'"~-- .-,,,- ADMINISTRATION 1. Permit fee attached ............ ~.~. -~'~/~/~ '~ N 2. Lease number appropriate.. ~ ............... ~N 3. Unique well name and number.4N ............... N 4. Well located in a defined pool .................. ~' N ~'~ ~ ~/- ~'~ 5. Well located proper distance from drilling unit bounda~ .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without consewation order ........ ~P~ DATE 12. Permit can be issued without administrative approval~... ~ ,~. O~) 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Sudace casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & sud csg ..... 17. CMT vol adequate to tie-in long string to sud csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or resewe pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ ~Y) N DATE 26. BOPE press rating appropriate; test to ~~ psig. ~/~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ -" [ ~' ' 28. Work will occur without operation shutdown ........... ~ N ~~~ ~~%~~~%~ ~~~ ~ ~~~_ 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ~~N 31. Data presented on potential overpressure zones ....... N 32 Seismic analysis of shallow gas zones ............. A~ DATE 33. Seabed condition suwey (if off-shore) ............. ~ Y N ~ ~' [, ~ 34. Contact name/phone for weekly progress repods [exploratory] Y U ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ,, ENGINEERING: UIC/Annular COMMISSION: GEOLO~: Comments/Instructions: Z -.-I '1' c:\msoffice\wordian\diana\checklist (rev. 02/17/00)
