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Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb~unocal.com UNOCAL Beverly Harrison Business Ventures Assistant 6/17/2003 To: AOGCC Lisa Weepie 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - ~':W~;~;..,....~, ... .... ,,.,- LOG'i[YPE..,..;,.f...,,,.,-.~.'~,...., .... ,..,.~.,., 'i,!~iCXlt.~f.": . COMPLETION RECORD-2.5" HSD A-15RD POWER JET2506 HMX 5 INCH 5/1/2003 11750-12550 2 1 1 AN-13RD2 RST SIGMA MODE 5INCH 5/22/2003 3400-4650 2 1 1 AN-19 RST SIGMA MODE 5INCH 5/22/2003 3400-4650 2 1 1 AN-37 RST SIGMA MODE 5INCH 5/22/2003 3100-4250 2 1 1 COMPLETION RECORD- 2.5" HSD G-12RD3 POWERJETGSPF 5 INCH 5/10/2003 12400-13610 2 1 1 2 1/2" HSD PWER JET 2506, HMX 3 1/2" '"GRINER-1 HALLIBURTON PLUG 5 INCH 4/19/2003 250-1780 1 1 1 "GRINER-1 CEMENT MAP 4/8/2002 0 0 1 TEMPERATURE SURVEY- CEMENT TOP KGSF-3 IDENTIFICATION PBMS 2 INCH 6/4/2003 3500-7020 1 1 1 COMPLETION REPORT- 2.5" HSD M-5 POWER JET, 6 SPF 5 INCH 4/16/2003 3600-3900 2 ;~ \ 1 1.56"1606 HMX, TUBING PUNCHER ~,~ CX /SRU 223-28 COMPJETION RECORD 5 INCH 5/25/2003 1580-5606 1~,.~- 1\ ~ 3.5 HALLIBURTON CAST IRON PLUG / SRU223-28 CEMENT DUMP BAILER 5INCH 5/24/2003 .1662-5665 1 1 1 18\ 0 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907/ 263-7828. ..... . ......... ,~ I, ' v, ...... Received B ~ o ~ ~ ~ .~ Date: Finol Abctndonment of 5wonson River Gos Well 5P, U 223-28 June 04, 2003 RECEIVED Winton Auber't A06¢¢ 333 West 7th Avenue, Suite 100 Anchor'(~ge, AK 99501 JUN 0 9 2003 Alaska 0il & Gas Cons. Commission Anchorage bear/~r. Aubert, We completed the processes involved with the abandonment of SRU 223-28 on June 04, 2003 and would like to submit the attached Form 10-407 (and other attachments) for your information and/or approval. Please feel free to contact the undersigned if you have any questions. ta-Darkwah ' Petroleum Engineer Unocal Alaska 263-7864 phone 2~6, ~ -/bOo 263-7884 fax darkwahs@unocal.com attachments AOGCC Form 10-407 Well Completion or Recompletion Report and Log Post-Abandonment Wellbore Schematic Summary of Daily Field Operations During Abandonment Period Directional Survey Record SRU 223-28_Final Aban Cover w Form 10407_060403 Page I of 1 6/4/2003/4:08 PM STATE OF ALASKA 'i' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company of California (UNOCAL) 97-88 3. Address 8. APl Number P. O. Box 196247 Anchorage, AK 99519 50- 133-20478-00 4. Location of well at surface 9. Unit or Lease Name 1229' FNL, 1488' FWL, Sec. 28, T8N, R9W, SM Swanson River Unit At Top Producing Interval 10. Well Number 2258' FSL, 1596' FWL, Sec.28, T8N, R9W, SM SRU 223-28 At Total Depth 11. Field and Pool 1775' FSL, 2023' FWL, Sec. 28, T8N, R9W, SM Swanson River Field/Tyonek 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 237' RKB above MSL A-028399 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 8/5/1997 8/14/97I 9/15/97 NA feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 7,360'/6,664' 6,274'/5,720'I Yes: x No: NA feet MDI NA 22. Type Electric or Other Logs Run DITE/CNT/LDT/GR, TDT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68# K-55 0 84' Driven 0 7" 29# L-80 0 2,125' 8-1/2" 400 sx-lead, 20 sx-tail 0 3-1/2" 9.3# L-80 1,953 6,745' 6" 721 sx of 15.8 ppg 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 1,953' 1,953' None. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED l 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 9/21/1997I Flowed to flare for test. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/21/1997 2 TEST PERIOD => 0 173 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 2,060 0 24-HOUR RATE--> 0 2,078 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None.RECEIVED JUN 0 9 2003 ~,~DI~4S, BF!'.,, JU~ 1 0 ~'J Alaska Oi~ & Gas Cons. Commission (.,~- Anchorage NPlP IKtAi Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. U. Tyonek 6,065' - 6,079' 5,542' - 5,554' Flowed dry gas. RECEIVED JUN 0 9 2003 Alaska Oil & Gas Cons, Commission Anchorage 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'"~ ~'~-~ Tit .e /~ ~'/*/,'l, ~'F) ~"'~,~/;A~--¢'~' D a t e 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 than 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 this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: FlOwing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Form 10-407 Item 28: If no cores taken, indicate "none". ORIGINAL Date: Subject: June 4, 2003 Daily Summary of Operations for SR U 223-28 Well Abandonment Date 05/22/03 O5/23/03 05/24/03 05/25/03 05/26-27/03 05/28/03 06/04/03 Event Unsuccessfully attempted to establish injection into existing perfs. Tagged on obstruction at 5,694' RKB using a 2.8" GR with 2.65" centralizer. Submitted modified procedure to set bridge plug and dump bail cement to BLM and AOGCC. Both agencies approved revised procedure. J Set Haliburton's EZ-Drill bridge plug ~ 5,665' RKB and dump bail approximately 18 gallons cement on top in 3 bailer runs. f Tag Top of Cement (TOC) at 5,606' RKB with gun, pulled uphole and shot 1955 - 1966 RKB ~ 4 SPF and 0 degree phasing (40 holes w/0.19" diameter). Circulated tubing/casing annulus with 71 bbl of 12.8 #/gal Pumped 1 gallon of same cement into 3/8" methanol injection line. ~~ Allowed cement to set- no field activity. / Cut wellhead and weld abandonment plate on wellbore. Clean, cut and fill cellar with approximately 200 cubic feet of pad material. End of abandonment processes. COCOCO 00~ OI~-IO0001.~O-,ICO010COcO0 Swan.son River Field Abandoned Well SRU #223-28 Actual Completion, 8/19/97: Abandoned (m 5/28/03 RKB to top of TBG Head = 26.75' Tree connection: 3-1/8" 5K Cameron Flange SIZE WT /[~ ---- }x 13-3:8' 68 I 7" 29 CASING AND T[JBING DETAIL Gl;La, DE CONN TOP BOTTOM I<2-55 Weld SurC 52' Driven L-80 Butt Surf 2125' Liner: 3-t'2" 9.3 L-80 Hydri1533 1953' 6745' Tubing: 3-1,,2" 9.3 L-80 Hydril 533 Surf with 3,8" ss methanol injection line Surf Note: 3-12" 9.3~ ttydrit 533 tubing 9 3 8 4 10 5 Per[~s 9/15/97 6 6065'-6079' 7 7 8 Sand on top to 6263' Bridge Plug (~} 6274' 9 NO~ 0 TOP 6065 Nominal ID-- 2.992" (pipe body) Drtf_t f~. 867" (pipe body) Coli~¢ctio~ 1D 2.942" (pin and box bored ID) ~EV~ ELRY DETAIL Depth Item 6247wlm 5665 1953' 1894' 3-1/2" Tbg hgr w/Cameron "H" BPV profile 3-1/2' 8rd pin x 3-1/2' Hydril 533 pin xover 1894 Macco 3-1/2" SFO-1CI Chem Inj Mdrl w/900 ps/chem i~i valve, Drift ID- 2.867" Baker ZXP Liner top packer 19~3 Flex-lock Hydraulic set rotating liner hgr RS nipple 1972 Seat Bore Extension 1983 3-1/2" seal assembly bottom 6679 3-1/2" Landing collar (6066' TVD) 6711 3-1/2" Float Collar 6745 Bottom of 3-1/2" float shoe 6745 Top of fish lefl in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) Fish, 12.3' perf head and 14' spent perfgons. Cast Iron EZ-Dri/t Permanent Bridge Plug 56' Cement Plug fi'om 5662 - 5606 ~ 5694 Last tag (5/22/03) w/2.8" GR & 2.65" centralizer PERFORATION DATA BTM ZONE SPF DATE COMMENTS 6()79 G 6 9/'15,'97 TD = 7360' MD, PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33<, KOP (a 500' 223-28 Post Abdmentschm 5-28-03 RE\/ISED: 6,4.2003 DRAWN BY: SAM RE: SRU 223-28 Abandonment Subject: RE: SRU 223-28 Aband ent ) at 7 - c9 -$ ~ Date: Thu, 22 May 2003 21:57: ~ -0800 From: "Darkwah, Samuel A" <darkwahs~unocal.com> To: "Winton Aubert" <Winton_Aubert~admin.state.ak.us> CC: "Harness, Evan" <ehamess~unocal.com> Winton, We attempted to begin the abandonment of the subject well today but encountered some difficulties as detailed below: We unsuccessfully attempted to establish injection into the existing perforations at 6065 - 6079 MD by pumping 19.5 bbl of freshwater @4500 psi surface injection pressure. Subsequently, we conducted a wireline tag using 2.8" gauge ring with a 2.65" centralizer and tagged on an obstruction at 5,694'MD. As a result of the foregoing, we would like to propose the following procedure for the abandonment of SRU 223-28: ABANDON PERFS AS FOLLOWS: · Rig up E-line. · Set bridge plug at 5,670' MD. · Dump bail 35'of cement. · RIH with 2'x 2.5" perf gun. · Punch circulation holes in tubing (1,900'- 1,902' MD). · POOH. · Rig down E-line. SURFACE ABANDONMENT · Pump 65 bbl cement down tubing taking returns from annulus. Once cement returns on annulus side, shut down pump. Pump water into annulus to push cement down 5-10' below grade to facilitate wellhead removal. Rig down cement equipment. Cut off wellhead, weld on abandonment plate. We believe that our current procedure will provide an effective means of plugging the well and will prevent fluid movement into sources of hydrocarbons or freshwater. Please notify us by e-mail with your approval of the newly modified procedure. Thank you. Samuel Atta-Darkwah Unocal Corporation 907-776-6614 (field) 907-301-0811 (cell) ..... Original Message From: Winton Aubert [mailto:Winton_Aubert@admin.state.ak. us] Sent: Tuesday, April 29, 2003 3:41 plVl To: Darkwah, Samuel A Subject: Re: SRU 223-28 Abandonment Samuel, AOGCC hereby approves proposed changes to your SRU 223-28 abandonment as detailed below (App. No. 302-318). Please give AOGCC Inspectors an opportunity to witness the plug tag. Winton Aubert AOGCC 793-1231 "Darkwah, Samuel A" wrote: RE: SRU 223-28 Abandonment <<SRO 223-28_current schmi' Winton, 'loc>> <<223-28 Revised Abandonment Sche:i. ;.doc>> On October 08, 2002, Unocal's sundry to abandon the subject well was approved by AOGCC. In the approved sundry, we proposed to conduct the abandonment using the following procedure: · Use E-Line to set plug @ 6,035' MD · Dump bail 35' of cement on top of the plug · Use 2'x2.5" perf gun to punch holes in tubing @ 1,920' - 1,922' MD · Pump 50 bbl cement down tubing taking returns from annulus. · Once cement returns on annulus side, shut down pump. · Pump water into annulus to push cement down 5-10' below grade to facilitate wellhead removal. · Cut off wellhead, weld on abandonment plate. We have slightly modifed the abandonment procedure above with the following: · MIRU cementer. · Establish injection rate into perforations at 6,065' - 6,079' MD · Bullhead - 35 bbls of cement ito 3-1/2" tubing from bottom of perforations at 6,079' to 2,100' MD. · Allow plug to set up and test to 1,500 psi and verify top with wireline tag. · R/U E-Line and punch hole in 3-1/2" tubing at +/-1,900' MD. · Establish circulation rate through hole and up 3-1/2" x 7" annulus. · Circulate cement down tubing and up 3-1/2" x 7" annulus to surface (approximately 65 bbls). · Rig down cementer. · Cut off wellhead and weld plate on. Mark as per AOGCC regulations. The attached "revised" schematic shows the well after the modified abandonment procedure. The other "current" schematic show the well as it is now. The intended start date for this abandonment project is 05~04~03. Please notify us by e-mail with your approval of the modified abandonment procedure. Do not hesitate to cantact the undersigned if you have any questions about this request. Thanks. Samuel A tta-Darkwah Petroleum Engineer Unocal Alaska darkwahs@unocal.com 907-263-7864 office 907-301-0811 cell 907-263-7874 fax SRU 223-28 Abandonment [ t~ 7- 0~ Subject: SRU 223-28 Abandonmei' Date: Tue, 29 Apr 2003 15:08:5I'-~800 From: "Darkwah, Samuel A" <darkwahs~unocal.com> To: <winton_aubert~admin.state.ak.us> <<SRU 223-28 current schmatic.doc>> <<223-28 Revised Abandonment Schematic.doc>> Winton, On October 08, 2002, Unocal's sundry to abandon the subject well was approved by AOGCC. In the approved sundry, we proposed to conduct the abandonment using the following procedure: · Use E-Line to set plug @ 6,035' MD · Dump bail 35' of cement on top of the plug · Use 2'x2.5" perf gun to punch holes in tubing @ 1,920' - 1,922' MD · Pump 50 bbl cement down tubing taking returns from annulus. · Once cement returns on annulus side, shut down pump. · Pump water into annulus to push cement down 5-10' below grade to facilitate wellhead removal. · Cut off wellhead, weld on abandonment plate. We have slightly modifed the abandonment procedure above with the following' · MIRU cementer. · Establish injection rate into perforations at 6,065' - 6,079' MD · Bullhead ~ 35 bbls of cement ito 3-1/2" tubing from bottom of perforations at 6,079' to 2,100' MD. · Allow plug to set up and test to 1,500 psi and verify top with wireline tag. · R/U E-Line and punch hole in 3-1/2" tubing at +/-1,900' MD. · Establish circulation rate through hole and up 3-1/2" x 7" annulus. · Circulate cement doWn tubing and up 3-1/2" x 7" annulus to surface (approximately 65 bbls). · Rig down cementer. · Cut off wellhead and weld plate on. Mark as per AOGCC regulations. The attached "revised" schematic shows the well after the modified abandonment procedure. The other "current" schematic show the well as it is now. The intended start date for this abandonment project is 05/04/03. Please notify us by e-mail with your approval of the modified abandonment procedure. Do not hesitate to cantact the undersigned if you have any questions about this request. Thanks. Samuel Atta-Darkwah Petroleum Engineer Unocal Alaska darkwahs@unocal.com 907-263-7864 office 907-301-0811 cell 907-263-7874 fax UNOCAL ) RKB to top of TBG Head = 26.75' Tree connection: 3-1/8" 5K Cameron Flange Perfs 9/15/97 6065'-6079' 7 Sand on top to 6263' Bridge Plug @ 6274' 4 5 TD = 7360' MD, PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33°, KOP ~ 500' SCHLAST1 SIZE WT Swanso( iver Field Well SRU #223-28 Actual Completion, 8/19/97 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 68 K-55 Weld Surf' 52' Driven 7" 29 L-80 Butt Surf 2125' Liner: 3-1/2" 9.3 L-80 Hydri1533 1953' 6745' Tubing: 3-1/2" 9.3 L-80 Hydril 533 Surf with 3/8" ss methanol injection line Surf 1953' 1894' Note: 3-1/2" 9.3# Hydril 533 tubing ID= Nominal ID= 2.992" (pipe body) Drift ID= 2.867" (pipe body) Connection ID = 2.942" (pin and box bored ID) JEWELRY DETAIL NO. Depth Item 1 2 1894 3 1953 1972 1983 4 6679 6711 5 6745 6 6745 3-1/2" Tbg hgr w/Cameron "H" BPV profile 3-1/2" 8rd pin x 3-1/2" Hydril 533 pin xover Macco 3-1/2" SFO- 1CI Chem Inj Mdrl w/900 psi chem inj valve, Drift ID= 2.867" Baker ZXP Liner top packer Flex-lock Hydraulic set rotating liner hgr RS nipple Seal Bore Extension 3-1/2" seal assembly bottom 3-1/2" Landing collar (6066' TVD) 3-1/2" Float Collar Bottom of 3-1/2" float shoe Top of fish left in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) 7 6247wlm Fish, 12.3' perfhead and 14' spent perfguns. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6065 6079 G 6 9/15/97 Revised: 10/7/02 DRAWN BY: TAB UNOCAL ) RKB to top of TBG Head = 26.75' Tree connection: 3-1/8" 5K Cameron Flange Cement Plug f/1,900' to Surface Cement Plug f/6,079' to 2,100' Perfs 9/15/97 6065'-6079' Sand on top to 6263' Bridge Plug ~ 6274' 6 TD = 7360' MD, PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33°, KOP ~ 500'. 223-28 Revised Abandonment Schematic.doc SIZE WT Swansoi. iver Field Well # SRU #223-28 Revised P&A Schematic CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 68 K-55 Weld Surf' 7" 29 L-80 Butt Surf 52' Driven 2125' Liner: 3-1/2" 9.3 L-80 Hydril 533 1953' 6745' Tubing: 3-1/2" 9.3 L-80 Hydril 533 Surf with 3/8" ss methanol injection line Surf 1953' 1894' Note: 3-1/2" 9.3# Hydril 533 tubing ID= Nominal ID= 2.992" (pipe body) Drift ID= 2.867" (pipe body) Connection ID -- 2.942" (pin and box bored ID) JEWELRY DETAIL NO. Depth Item 1 2 1894 3 1953 1972 1983 4 6679 6711 5 6745 6 6745 3-1/2" Tbg hgr w/Cameron "H" BPV profile 3-1/2" 8rd pin x 3-1/2" Hydril 533 pin xover Macco 3-1/2" SFO- 1CI Chem Inj Mdrl w/900 psi chem inj valve, Drift ID= 2.867" Baker ZXP Liner top packer Flex-lock Hydraulic set rotating liner hgr RS nipple Seal Bore Extension 3-1/2" seal assembly bottom 3-1/2" Landing collar (6066' TVD) 3-1/2" Float Collar Bottom of 3-1/2" float shoe Top of fish left in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) 7 6247wlm Fish, 12.3' perfhead and 14' spent perfguns. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6065 6079 G 6 9/15797 REVISED: 4/29/2003 DRAWN BY: ADS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: X Suspend: ' Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 237' RKB above MS[ 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Swanson River 4. Location of well at surface .v/ ,~- 8. Well number 1229' FNL, 1488' FWL, Sec. 28, T8N, R9W, SM SR 223-28 At top of productive interval 9. Permit numbgr 2258' FSL, 1596' FWL, Sec. 28, T8N, R9W, SM 97-88 At effective depth 10. APl number // 50- 133-20478-00 :.~ At total depth 11. Field/Pool 1775' FSL, 2023' FWL, Sec. 28, T8N, R9W, SM Swanson River Field / Tyonek 12. Present well condition summary Total depth: measured 7360' ?/ feet Plugs (measured) 6274' true vertical 6664'~ feet 5720' Effective depth: measured 6274' feet Junk (measured) true vertical 5720' feet Casing Length Size Cemented Measured depth True vertical depth Structural 84' 13-3/8" Driven 84' 84' Conductor Surface 2125' 7" 420 sx 2125' 2058' Intermediate Production Liner 4792' 3-1/2" 721 sx 1953'-6745' 1895'-6123' Perforation depth: measured 6065'-6079' true vertical 5542'-5554' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 @ 1953' Packers and SSSV (type and measured depth) Baker, ZXP Liner Top Packer @ 1953' 13. Attachements Description summary of proposal: Detailed operations program: X BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: 10/15/2002 16. If proposal well verbally approved: Oil: Gas: X Suspended: Name of approver Date approved Service: 17. I hereby certify that the forego~g is true and correct to the best of my knowledge. Signed: ,,,, Title: ~_L.~,~...~,,/[, f_~,/,~,.,,Zj~-" Date: //(~7_~ · ,,,,,,¥'~,,] FOR COMMISSION USE ONLY r~-e~sentative I. Conditions of approval: Notify Commission so may witness [Approval No. Plug integrity ~ BOp Test Location clearance ~) ~ ~1~ ~' ~'~ ~ ~ Mechanical Integrity Test Subsequent form required 10- ~-~""'~li~ L ~,, ~ ! V g ~,~ OCT 0 7 2002 ORIGINAL SIGNED t~ y D Taylor Seamoun~ Alaska0tt&6a~ ~.C0 Approved by order of the Commissioner Com miss,oner /~ nt, hn~l~t~ ~/~"/(~ Form 10-403 Rev 06/15/88 '' '~ ~" SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Swanson River Well No. SR 223-28 Prepared by: Tim Brandenburg Date: 10/7/02 Final Abandonment UNOCAL No. Preliminary Procedure Abandon Perfs 1 RU E-Line. 2 Set Plug at 6035' 3 Dump Bail 35 Feet of cement 4 PU 2'x 2.5" perfgun. RIH. 5 Punch circ holes in tubing 1920'- 1922'. POOH. 6 RD E-Line. Surface Abandonment 7 MIRU Cement Equipment. 8 Pump 50 bbls cement down tubing taking returns from annulus. Once cement returns on annulus side, shut down pump. Pump water into annulus to push cement down 5-10' below grade to facilitate wellhead removal. 9 RD Cement Equipment. 10 Cut off wellhead, weld on abandonment plate. UNOCAL ) RKB to top of TBG Head = 26.75' Tree connection: 3-1/8" 5K Cameron Flange SIZE WT Swanson River Field Well # SR #223-28 Actual Completion, 8/19/97 CASING AND TUBING DETAIL GRADE CONN TOP 13-3/8" 68 K-55 Weld Surf' 7" 29 L-80 Butt Surf Liner: 3-1/2" 9.3 L-80 Hydri1533 1953' BOTTOM 52' Driven 2125 'MD/ 2017" TVD 6745' Tubing: 3-1/2" 9.3 L-80 Hydril 533 Surf with 3/8" ss methanol injection line Surf 1953' 1894' Per~ 9/15/97 6065'-6079' Note: 3-1/2" 9.3# Hydril 533 tubing ID= Nominal ID= 2.992" (pipe body) Drift ID= 2.867" (pipe body) Connection ID = 2.942" (pin and box bored ID) JEWELRY DETAII, Depth Item 1894 NO. 1953 1972 1983 6679 6711 6745 6745 3-1/2" Tbg hgr w/Cameron "H" BPV profile 3-1/2" 8rd pin x 3-1/2" Hydril 533 pin xover Macco 3-1/2" SFO-1CI Chem Inj Mdrl w/900 psi chem inj valve, Drift ID= 2.867" Baker ZXP Liner top packer Flex-lock Hydraulic set rotating liner hgr RS nipple Seal Bore Extension 3-1/2" seal assembly bottom 3-1/2" Landing collar (6066' TVD) 3-1/2" Float Collar Bottom of 3-1/2" float shoe Top of fish left in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) 7 Sand on top to 6263' Bridge Plug ~ 6274' 4 5 TD = 7360' MD/6664' TVD PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33°2 KOP ~ 500' TOP 6O65 6247wlm Fish, 12.3' perfhead and 14' spent perf guns. PERFORATION DATA BTM ZONE SPF DATE COMMENTS 6079 G 6 9/15/97 SCHLAST1 REVISED: 10/7/02 DRAWN BY: TAB UNOCAL ) Tubing and tubing x Annulus Cemented from 1920' Bridge plug at 6035' w/35' cement dump bailed Pcrfs 9/15/97 6065 '-6079' 7 Sand on top to 6263' Bridge Plug @ 6274' 4 5 TD = 7360' MD/6664' TVD PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33°, KOP ~ 500' SR 223-28 ABDN Draw SIZE WT Swanson River Field Well SR No. 223-28 Proposed Abandonment CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 68 K-55 Weld Surf' 7" 29 L-80 Butt Surf Liner: 3-1/2" 9.3 L-80 Hydri1533 1953' 52' Driven 2125'MD/ 2017"TVD 6745' Tubing: 3-1/2" 9.3 L-80 Hydril 533 Surf with 3/8" ss methanol injection line Surf 1953' 1894' Note: 3-1/2" 9.3# Hydril 533 tubing ID= Nominal ID= 2.992" (pipe body) Drift ID= 2.867" (pipe body) Connection ID = 2.942" (pin and box bored ID) JEWELRY DETAIL NO. Depth Item 1 Surface 2 1894 1953 1972 1983 6679 6711 6745 6745 Abandonment Plate welded on 7" Surface Macco 3-1/2" SFO-1CI Chem Inj Mdrl w/900 psi chem inj valve, Drift ID= 2.867" Baker ZXP Liner top packer Flex-lock Hydraulic set rotating liner hgr RS nipple Seal Bore Extension 3-1/2" seal assembly bottom 3-1/2" Landing collar (6066' TVD) 3-1/2" Float Collar Bottom of 3-1/2" float shoe Top of fish left in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) 7 6247wlm Fish, 12.3' perf head and 14' spent perf guns. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6065 6079 G 6 9/15/97 REVISED: 10/7/02 DRAWN BY: TAB AOGCC Geological Materials Inventory PERMIT 97-088 UNOCAL Log Data Sent Recieved Box BRIDGE PLUG ~I'(ELAR 5800-6679 3/9/98 3/11/98 CBT ~AR 1800-6250 3/9/98 3/11/98 CN/LDT ./..~M'~ EAR 2125-6359 9/9/97 9/16/97 COMP RED ~'~fLAR 5800-6160 3/9/98 3/11/98 PIL-SFL ~]~AR 2125-6390 9/9/97 9/16/97 SERVERING TOOL ~YLAR 6570-6760 9/9/97 9/16/97 SRVY CALC ,~0-7360. 9/22/97 9/26/97 TDTP ~LAR 5800-6670 3/9/98 3/11/98 L1~'407 Completion Date 5 :/.'? Daily ~vell ops Are dry ditch samples required? yes jno And received? Was the well cored? Are tests required? Well is in compliance yes ~"~no yes ~- no Analysis _description recieved? Received? ~.~y~~-~n o Initial Comments Thursday, September 23, 1999 Page 1 of 1 Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd @.unocal. corn UNOCAL Debra Childers Geotech Assistant DATA TRANSMITTAL March 9, 1998 To: Laurie 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: ' -'7(0- · f'5 .coS- . '~'5' I'"-.,o --- , '=1~,' , b,O,o~q DILLON 2rd - 1/25/98 Packer Set'tin( Record DILLON 4 Packer Tie in Record 1/30/98 GP 18742-38 . Record with Gamma-Ra~ 11/17/97 GP 53 Cement Evaluation with GPJCollars 8/28/98 GP AN-26 · Record with Gamma 11/19/97 GP AN-52 . Thermal Decay Time 1/31/98 MGS 17595-11 · Record 10/30/97 MGS 17595-13. Record with Gamma 12/10/97 MGS B-30 · Determination 11/12/97 MGS Baker 32 · Record 11/24/97 MGS Baker 32--. Record 12/10/97 SRU 212-27 . Record 9/11/97 SRU 223-28 . Cement Bond Log 9/8/97 SRU 223-28 · Record 9/15/97 SRU 223-28 · Record 9/8/97 SRU 223-28 · Thermal Decay Time Log 9/8/97 SRU 23-22 : Record 9/12/97 TBU D-11 Record 2.5 HSD. 31J UJ HMX 1/16/98 TBU D-25rd . Perforation Record 2 Y2" Ultra ets 1/09/98 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received I Date: STATE OF ALASKA r~a~- , ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL [] lb. TYPE TEST STABILIZED f"] NON STABILIZED [] ANNUAL [] MULTIPOINT [] CONSTANT TIME [] SPECIAL [] OTHER J~O~IjCI~-p ~[)CI'~'I2~I'~t~L'- ISOCHRONAL 2. Name of Operator 7. Permit No. 3. Address 8. APl Number ,. 4, Location of Well ~ ~Ac~: 9, Unit or Lease Name ~ ~12 O~ J)~oP~t~l~{~ i~)~V~: 10. Well Number ~'T To'T~L ~gflY-~f 11.'FieldandPool 5~ Elevation i~ feet (indicate KB, DF etc.) J 6. Lease Designation and Serial No. 12. Completion Date 113. T0talpepth~V~ 14. Plugbac~ T.D.~/TV~ 115. Type Completion (Describe) . 13 ~/~" Weight per foot lb. I.D. in inches Setup25'tat ft/ Perforations: ~)~,~ tFr°m To 'r ~'I~ ~ t~" 4c~5,~ (m~) 17. mbg. Size Weight per foot, lb. I.D. in inches , Set at ft. ~.~.~ t 18. Packer set at ft. [19. GOR cf/bbl. [20. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) , ,, .... 22. Producing thru: ~eservoir Temp. o F. Mean Annual Temp, o F. Barometric Pressure (~a), psia 23. Length of flow channel IL') Vertical Dep"th IH) J Ga. J % CO2 J "( N2 % H2S' Prover 'Meter run Taps 24. Flow Data Tubing Data Casing Data Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Line X Orifice Flow No. Size (in.) Size (in.) psig hw ,o F. psig o F. psig o F. Hr. I ....... ,,. ~.¢.. . ..,.. ,, Flow Temp. Gravity Super Comp. Basic Coefficient ~ Pressure Factor Factor Factor Rate of Flow (24-Hour) hwPm Pm Q, Mcfd No. Fb or Fp Ft Fg Fpv 2. 17.~3 6'i · 15- 8'1~ ,, ~. oo 5. ........ ...... ~ for Separator for Flowing Temperature Pr T(~g) Tr Z ;>~:":" :':* ';997 6., Fluid No. Gg G 5. , ............................ Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate Dry,. -7 1 0¢/ No... Pt Pt2 Pc2 - Pt2 Pw Pw2 Pc2 - Pw2 Ps ps2 (,/v]~ pf2 . ps2 ~Nf) , 5. ........ 25. AOF (Ucfd) ~I ~OO n O, ~-D~- Remarks: I hereby certify that the foregoing is true and correct to the best of my knowl~ge , . Signed. '~'1, ,' .Title 7~./,~,,IC'1~,~ Date. iC' ~ ~'~ /~ ~ ...................... , , AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/-X/hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=-x/-1-~-~'--dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TV D) Length of flow channel, feet (MD) Exponent (slope) o~ beck-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-42 Dear Mr. Hartz: Unocal Alaska Resour¢ Unocal Corporation ..... 909 West 9th Avenue, P.O~.-~ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL October 7, 1997 Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Conservation Attn: Jack Hartz Swanson River Well SRU 223-28 API# 50-133-20478 Form 10-421, Gas Wel1 Open Flow Potential Test Report Attached is Form 10-421 for the modified isochronal flow test on Swanson River Well SRU 223-28 conducted on September 21, 1997. Please direct any questions to Sam Darkwah at 263-7864. Sincerely, Sam A. Darkwah Reservoir Engineering Technician STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT 1 a. TEST: INITIAL [] ANNUAL [] SPECIAL [] lb. TYPE TEST STABILIZED [] MULTIPOINT [] NON STABILIZED CONSTANT TIME ISOCHRONAL 2. Name of Operator 3. Address 4. Location of Well ~ ~Y~'~c~ r ~'T Tc'T~L PEP/-H ' 5. Elevation in feet (indicate KB, DF etc.) [ 6. Lease Designation and Serial No. 12. Completion Date 13. Total Depth MI)iTv,~ 14. Plugbacl¢ T.D./~I)/TV¢ 16. Csg. Size . Weight per foot, lb. I.D. in inches Set at ft. 17. TbS. Size Weight per foot, lb. I.D. in inches Set at ft. 7. Permit No. 8. APl Number 9. Unit or Lease Name 10. Well Number 11. Field and Pool 15. Type Completion (Describe) Perforations: From To 18. Packersetatft.~,~_~, {19. GORcf/bbl.~i.~ I20'APl LiquidHydrOcarbOns~l/~ 21.SpecificGravityFlowingfluid(G)~)~ 22. Producing thru' Tbg. 1~ Csg. [] 23. Length of flow channel (L) 24. FI~ No, 1. 2. 3. 4. 5. Prover Choke Line X Orifice Size (in.) Size (in.) Reservoir Temp. o F. Vertical Depth IH) I G~. ! % CO2 ,w Data Pressure psig Diff. hw Temp. o F. Mean Annual Temp. o F. Barometric Pressure (Pa), psia 5%, ~J~"/ -' ~e. 6ff ~: N2 1%H2S 1 Pr°ver ] Meterrun I Taps Tubing Data Pressure psig Temp. OF. Casing Data Pressure psig Temp. °F. Duration of Flow Hr. ;ti ?o I Basic Coefficient I Flow Temp. Gravity Super Comp. __~ Pressure Factor Factor Factor Rate of Flow (24-Hour) hwPm Pm Q, Mcfd No. Fb or Fp Ft Fg Fpv 2. 1.7.73 6') . Iff, ~/~ t. eo~. ~ i-2~5- I,c~K t, oco '5. II ~ f for Separator for Flowing Temperature Pr T ( ~'t2,) Tr Z Gas Fluid No. Gg G 1. ~-io '.-~b9 i" C-,a~ o~ Sbt¢ ,ui~ o, ~, 5. .] Form 10-421 CONTINUED ON REVERSE SIDE Submit in duplicate STATE OF ALASKA ALASKA C, -AND GAS CONSERVATION L, MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classificatior~ of Service Well ' OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Oil Company of California (UNOCAL) 97-88 3. Address 8. APl Number P. O. Box 196247, Anchorage, Ak 99519 50- 133-20478 4. Location of well at surface ¢ . ::;.' '" ', ':'; ; ~'~ll~i 9. Unit or Lease Name 1229' FNL, 1488' FWL, Sec. 28, T8N, Raw, SM i ~/~_i~.~ } ~ Swanson River AtTop Producing Interval i- ~¢~/Z?~_~ ~i r- 10. Well Number 2258' FSL, 1596' FWL, Sec. 28, T8N, R9W, SM YE.a!F!rq; ~ SR ¢¢223-28 At Total Depth ,__.-.i..~.. _' ~.7~.. r?.~ 11. Field and Pool 1775' FSL, 2023' FWL, Sec. 28, T8N, R9W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/Tyonek 237' KBI A-028399 22. Type Electric or Other Logs Run DITE/CNT/LDT/GR, TDT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68# K-55 0 84' Driven 0 7" 29# L-80 0 2125' 8-1/2" 400sx-lead, 20 sx-tail 0 3-1/2" 9.3# L-80 1953 6745' 6" 721 sx Of 15.8 ppg 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 1953' 1953' 6065'-6079' MD 6 spf, 0.31" dia hole 5542'-5554' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) 9/21/97 Iflowing to flare for test Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/21/97 2 TEST PERIOD => 0 173MCF 0 NAI NA Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 2060 0 24-HOUR RATE => 0 2078MCF 0 NA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ORIGINAL Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. · .r~--_, 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. U. Tyonek 6065'-6079' 5542'-5554' Flowed dry gas. 31. LIST OF A~ACHMENTS Wellbore schematic, Daily Summa~ of Rig Operations, Directional Su~ey Record 32. I hereby cedi~ that the foregoing is tree and coffect to the best of my knowledge Signed _2~') ('--~' & ";~ ~ Title Drilling Manager Date 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 than 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 this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 UNOCAL ) RKB to top of TBG Head = 26.75' Tree connection: 3-1/8" 5K Cameron Flange Perfs 9/15/97 6065 '-6079' 7 Sand on top to 6263' Bridge Plug @ 6274' 4 5 TD = 7360' MD, PBTD = 6679' MD/6066' TVD MAX HOLE ANGLE = 33°, KOP ~ 500' SCHLAST.DOC SIZE WT Swans~_~River Field Well # SR #223-28 Actual Completion, 8/19/97 CASING AND TUBING DETAIL GRADE CONN TOP BOTTOM 13-3/8" 68 K-55 Weld Surf' 52' Driven 7" 29 L-80 Butt Surf 2125' Liner: 3-1/2" 9.3 L-80 Hydri1533 1953' 6745' Tubing: 3-1/2" 9.3 L-80 Hydril 533 Surf with 3/8" ss methanol injection line Surf Note: 3-1/2" 9.3# Hydril 533 tubing ID= Nominal ID= 2.992" (pipe body) Drift ID= 2.867" (pipe body) Connection ID = 2.942" (pin and box bored ID) JEWELRY DETAIL NO. Depth Item 1953' 1894' 1 2 .. 1894 1953 1972 1983 6679 6711 6745 6745 6247wlm 3-1/2" Tbg hgr w/Cameron "H" BPV profile 3-1/2" 8rd pin x 3-1/2" Hydril 533 pin xover Macco 3-1/2" SFO-1CI Chem Inj Mdrl w/900 psi chem inj valve, Drift ID= 2.867" Baker ZXP Liner top packer Flex-lock Hydraulic set rotating liner hgr RS nipple Seal Bore Extension 3-1/2" seal assembly bottom 3-1/2" Landing collar (6066' TVD) 3-1/2" Float Collar Bottom of 3-1/2" float shoe Top of fish left in open hole from drilling (Stab, 4-3/4" drill collar, NB stab, 6" bit) Fish, 12.3' perfhead and 14' spent perf guns. PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 6065 6079 G 6 9/15/97 REVISED: 9/22/97 DRAWN BY: TAB SWANSON RIVER #223-28 DAY 1 8/04/97 RU POOL ARCTIC RIG #123. ACCEPT RIG @ 16:00HRS, 8/4/97. (FUNCTION TESTED DIVERTER 8/3/97). CLEAN OUT 13-3/8" CONDUCTOR WITH 12-1/4" BIT TO 86' RKB. .,~ ~ ~ ~] ~ ~ DAY 2 8/5/97 ¢~i? 2 ~; 1997 .Aa.~ib~ ,,.',~C~_ ~mm~S~l~ .... ,'- ~ ' ti,. GRAVEL. CLEAN OUT AND MODIFY FLOWLINE.'' '~"~'""~"'~'D~~-r¢~~O' 162', KELLY HOSE FAILED, REPLACE SAME. DRILL FROM 162' TO 283'. LARGE AMOUNTS OF GRAVEL CAUSING HOLE PACK-OFF PROBLEMS AND FLOWLINE PLUGGING. DAY 3 8/6/97 DRILL WITH 8.5" BIT FROM 283' TO 2074' (KICK-OFF POINT AT 500'). DAY 4 8/7/97 DRILL FROM 2074' TO CASING POINT AT 2125'. POOH, TIGHT HOLE FROM 1331'-600'. RIH WITH CLEAN OUT ASSY. REAM THROUGH BRIDGE AT 642'-685', WASH DOWN FROM 685' TO 750'. REAM TIGHT SPOTS AT 1425'-1455', 1600'-1640' AND 1877'-1925'. TAG BOTTOM AT 2125' WITH NO FILL. PUMP HI VIS SWEEP WITH NO SIGNIFICANT CUTTINGS RETURN. POOH WITH NO PROBLEMS. DAY 5 8/8/97 RAN 7" CASING TO 2125'. CEMENT CASING WITH LEAD CEMENT OF 400 SX (140 EELS) CLASS G WITH 4% BENTONITE, 2% CACL, AND .266% CELLOFLAKES AT 12.9 PPG, AND TAIL CEMENT OF 4 BBLS CLASS G WITH 2% CACL, .1GAL/SK D-145, .75 GAL/SK D-300. PROBLEMS PUMPING TAIL SLURRY DUE TO LOSING PRIME. DISPLACE CEMENT AND BUMP PLUG. FULL CIRCULATION THROUGHOUT JOB, CEMENT CONTAMINATED MUD TO SURFACE. ND DIVERTER AND RAN 1" TUBING TO 96', PUMPED TOP JOB WITH 74 SX CLASS G 15.8 PPG CEMENT. SET SLIPS, CUT CASING AND INSTALL TUBING SPOOL. NU ROPE. DAY 6 8/9/97 PRESSURE TESTED BOPE TO 5000 PSI, WITNESSED BY LOU GRIMALDI-AOGCC. RIH WITH 6" BIT, TEST 7" CASING TO 3000 PSI. DRILL FLOAT EQUIPMENT. DAY 7 8/10/97 DRILL 10' OF NEW FORMATION TO 2135'. PERFORM LEAK-OFF TEST WITH 9.0 PPG MUD AT 2058' TVD. BROKE FORMATION AT 1300 PSI = 21.1 PPG EMW. DRILL 6" HOLE TO 3923'. DAY 8 8/11/97 DRILL FROM 3923' TO 5023'. DAY 9 8/12/97 DRILL FROM 5023' to 5867'. DAY 10 8/13/97 DRILL FROM 5867' to 6731' DAY 11 8/14/97 DRILL FROM 6731' TO A TOTAL DEPTH OF 7360'. POOH FOR LOGS. DAY 12 8/15/97 POOH. RU SCHLUMBERGER, RIH WITH DITE/CNT/LDT/GR TOOL STRING, UNABLE TO GO BELOW 6398'.LOG FROM 6398' TO SURFACE. RD SCHLUMBERGER. RIH WITH CLEAN OUT ASSY, WORK THRU TIGHT HOLE AT 2820', 3536', 4096', 4296', 6400' AND 6792'. STUCK PIPE AT 6792'. DAY 13 8/16/97 WORKING STUCK PIPE, NO PROGRESS. RU APRS SEVERING TOOL ON SCHLUMBERGER WIRELINE UNIT. RIH W/SEVERING TOOL, CUT DRILL STRING AT 6746'. POOH. TEST BOP'S. DAY 14 8/17/97 RIH WITH CLEAN OUT ASSY. TIGHT HOLE AT 6600', WASH AND REAM TO TOP OF FISH AT 6746'. PUMP HI VIS SWEEP, POOH W/NO PROBLEMS. RU TO RUN LINER. DAY 15 8/18/97 RIH W-3-1/2" HYDRIL LINER. RUN LINER HANGER ASSY ON DRILL PIPE. ClRC HOLE CLEAN WHILE ROTATING IN SLIPS. SET HANGER AT 1300 PSI, CEMENT LINER WITH 721 SX CLASS G CMT WITH 0.1 GAL/SK D-145A, 0.75 GAL/SK D-300, 0.5 % S-002. ROTATE PIPE THROUGHOUT JOB, GOOD RETURNS. OVERDISPLACED CEMENT BY 3.5 BBLS, DID NOT BUMP PLUG DUE TO WIPER PLUG FAILING TO LEAVE CEMENT HEAD. UNSTING FROM HANGER, ClRC HOLE CLEAN, POOH WITH DRILL PIPE AND LINER RUNNING TOOL. RIH W/ BAKER LINER TOP PACKER W/6' SEAL NIPPLE. DROP BALL AND SET PACKER IN TIE-BACK RECEPTACLE AT 1953'. SHEAR BALL AND TEST ANNULUS TO 3000 PSI. ROTATE 10 TURNS TO RELEASE FROM PACKER. ClRC HOLE TO FRESH WATER, POOH. DAY 16 8/19/97 LAY DOWN 3-1/2" DP. PICK UP SEAL ASSBY. RIH W-3-1/2" HYDRIL 533 TUBING COMPLETION, SPACE OUT AND LAND COMPLETION. TEST 3-1/2" X 7" ANNULUS TO 1500 PSI FOR 30MINS, OK. ATTEMPT TO TEST LINER, 2500 PSI LEAKED AT 200 PSI IN 5 MIN (WET SHOE), TEST PRESSURE STABILIZED AT 1900 PSI. N/D BOPS. DAY 17 8/2O/97 TEST TREE TO 5000 PSI. PULL 2-WAY CHECK VALVE, ND BOPS. CLEAN MUD PITS. RELEASED POOL RIG #123 AT 12:00 HRS 8/20/97. DAY 18 9/5/97 RU DOWELL COILED TUBING UNIT. DAY 19 9/6/97 RIH WITH 2.80" MILL ON 1-3/4" COILED TUBING. ClRC WITH MOTOR AT 1.3 BPM FROM 1900' TO LANDING COLLAR AT 6679' WITH NO RESISTANCE. POOH WITH MILL WHILE ClRC AT 1.3 BPM. DAY 20 9/7/97 RIH WITH HYDRABLAST NOZZLE ON COILED TUBING. ClRC AT 1.7 BPM FOR 4 PASSES FROM 1900'-6679' INDEXING TOOL BETWEEN EACH PASS. LOAD HOLE WITH 6% KCL WATER. POOH WITH COILED TUBING. RU SLICKLINE AND RUN 2.80" GAUGE RING TO 6679' WITH NO PROBLEM. RD COILED TUBING AND SLICKLINE. DAY 21 9/8/97 RU SCHLUMBERGER WIRELINE UNIT. RIH WITH TDT/GR/CCL AND LOG FROM 6678' LANDING COLLAR TO 5800'. POOH WITH TDT LOG. RIH WITH 2.75" BRIDGE PLUG. UNABLE TO GO BELOW 6367'. PU FOR CCL CORRELATION AND UNABLE TO GO DOWN. SET BRIDGE PLUG AT 6274'. POOH WITH E-LINE. PRESSURE TEST TUBING/LINER TO 3000 PSI, AFTER 30 MINUTES PRESSURE WAS 2975 PSI, GOOD TEST. RIH WITH SLT-J CEMENT BOND TOOL. LOG FROM 6274' TO 1800'. POOH AND RD SCHLUMBERGER. Day 22 9/14/97 RU POLLARD WIRELINE UNIT. RIH WITH SAND IN DUMP BAILER. DROP TWO BAILER LOADS OF SAND ON TOP OF BRIDGE PLUG AT 6274', TOP OF SAND AT 6263'. SWAB WELL DOWN TO 1600'. DAY 23 9/15/97 RU SCHLUMBERGER WIRELINE UNIT. RIH WITH 2-1/8" ENERJET GUN. PERFORATE 6065'-6079' AT 6 SPF 0 DEGREE PHASING WITH 0.31" DIA HOLES. TUBING PRESSURE INCREASED TO 500 PSI. ATTEMPT TO POOH, GUNS STUCK AT 6042'. PUMPED METHANOL DURING AND AFTER FIRING GUNS. ATTEMPT TO PULL OUT OF ROPE SOCKET, TOOL MOVED UP TO 5944' BUT STUCK AGAIN. COULD NOT PULL OUT OF ROPE SOCKET WITH MAX PULL OF 4200 LB (ROPE SOCKET SHOULD FAIL AT 2000 LB). FLOW WELL AND WORK LINE, UNABLE TO MOVE TOOL. FINAL TUBING PRESSURE = 2100 PSI. DAY 24 9/16/97 LOAD HOLE WITH 20 BBL OF 6% KCL AND 24 BBL DIESEL. TUBING PRESSURE = 800 PSI. WORKED LINE, STILL STUCK. DROPPED HALLIBURTON-KINLEY CUTTER BAR WITH 60 MINUTE TIMED EXPLOSIVE CUT. WORKED WIRE TO ENSURE CUTTER SLIDE TO BOTTOM. HEARD CUTTER FIRE. PULLED 2000 LB AND LINE CAME FREE. RECOVERED ALL EmLINE. FLOW WELL TO UNLOAD FLUID. DAY 25 9/17/97 RU POLLARD WIRELINE. RIH WITH 1" JDC TO 5956' WLM AND LATCH CUTTER. POOH WITH CUTTER. RIH WITH 2.25" IMP BLOCK, SHOWED WIRE ON TOP OF FISH. RIH WITH 2.375" BLIND BOX AND BEAT DOWN FISH TO BRIDGE PLUG AT 6269' WLM. POOH AND RD POLLARD. BEGIN FLOW TEST. UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax September 23, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501-3192 Attn' Commissioner David Johnston Subject: Swanson River Well #223-28 APl #50-133-20478 Form 10-407, Well Completion Report Dear Commissioner Johnston: RECEIVED · ~taska 0il & Gas Cons, Anchorage Attached is the Form 10-407 for the ddlling and completion of Swanson River Well #223- 28 including a Daily Summary of Rig Operations, current wellbore schematic and directional survey record. Please direct any questions to Tim Billingsley at 263-7659. Sincerely, Dale A. Haines Drilling Manager Unocal-Alaska ORIGINAL b AOGCCCOV.DOC 1 9~22/97 SUHVE¥ L;ALL;ULA-I IUN ANU FII:.LI3 WUHK$1"II:LET .~obNo. 0450-67256 Sidetrack No. Page 1 of 4 Company LJN©CAI. RiO Contractor& No. Pool Arctic Alaska- #123 Field SWANSON RIVER FIELD Well Name& No. SRLJ223-281223-28 Survey Section Name Definitive Survey BHIRep. MI[[F_R, ltAMBI, JRG WF//DAIA ................ 'arget'fVD ¢:I) TargetCoord. N/S SlotCoord. N/S . :!_2_2_.8_..76 Grid Correction 0...0_.0..0. Depths Measured From' RKB[i MSLII SS[ 'arget Description Target Coord. E/W Slot Coord. E/W 1489.87 Magn Declination 22.2!_0. Calculation Method MINIMUM CLJRVATI. JRE :'alger Direction (t)~ [~udd\Walk\DLper' 100ltl)~ 30mI I I°ml I Vcrt Sec. Azim. .2.33 82 M~,gn to MapCor,. 22.210 M,,pNo,II~ .................... SURVEy DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical ..... Build (+1 Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N(t) / S(~) .... ~'(-i') / w(-) DI 'l'ype ¢:~) [[)~)) (nD) ¢' r) (FI) ifil If q ¢',.., ~o~)l 1~' Drop (-) l.ett (-) ............ 0.00 000 0.00 0.00 000 0.00 0 00 'fie IN POIN1 ................................ 05-AUG-97 MW[.} 116.00 0.20 33.82 116.00 116.00 -0.1g 0.17 0.11 01'/' 0.17 ........................ 05 ALJG t)/ MWI) ;;'()ii 00 () 1() 3:39 bG 92 O0 2.08.00 0 Lit'> 0.38 0 1 / 0 II~, 0 11 ..................... 06-AUG-97 MWD 299.00 020 33.38 91.00 299.00 -0.53 0.58 0.23 0.18 0.11 ................................................................ 06-AUG-97 MWD 390.00 0.30 51.47 91.00 390.00 -0.92 0.86 0.51 0.14 0.11 ORIGINAL 06-AUG-97 MWD 511.00 0,90 237.21 121.00 510,99 -0,29 0.55 -0.04 0.99 0.50 06-AUG-97 MWD 571.00 2,10 239.92 60,00 570.97 1.28 -0.26 -1.39 2.00 2,00 ..................... 06-AU G-97 MWD 693.00 4.60 224.18 122.00 692.76 8,32 -4.89 -6.74 2.16 2,05 .................................................................................. 06-AU G-97 MWD 783.00 7.30 235.40 90.00 782.27 17.60 -10.72 -13.96 3,25 3.00 12.47 06-AUG-97 MWD 875.00 10.00 240.09 92.00 873.21 31.38 -18.03 -25,70 3,03 2,93 5.10 06-AUG-97 MWD 965.00 11.60 242.07 90.00 961.62 48.11 -26.16 -40,47 1.82 1,78 2.20 ............................................................................................ 06-AUG-97 MWD 1057.00 13.40 240.09 92,00 1051.43 67.86 -35.81 -57.88 2 01 1.96 -2.15 06-AUG-97 MWD 1148.00 17.50 238,42 91.00 1139.13 91,99 -48,24 -78,68 4.53 4.51 -1.84 .................................................... 06-AUG-97 MWD 1238.00 20.60 234.10 90.00 1224.19 121,32 -64.62 -103,04 3,78 3,44 -4.80 06-AUG-97 MWD 1333,00 20.60 234,05 95.00 1313.12 154,74 -84.23 -130.11 0,02 0.00 -0.05 06-AUG-~7 ~W[-) 1429.00 20.00 232.11 ¢6.00 1403.15 18804 -104.23 -156.74 0.94 -0.152 -2.02 ~'"~-- ~,.~ cj> ~,~ -~ ~'~' ...... ....................................................................................... ~ ; ............ 06-AUG-97 'MWDI 16;ii;0 19.40' 231.~'~ i~1~3; ' 1;11.66 .... 264,21 -151,21 -216.74 ~i;~ ........... ;;;';; .............. ~.~3~) ~ *' ~'~ .........................................._.._____ ........... ___ 06-AUG-9? MWD 1746.00 19.50 232.07 95.00 1701.24 295.83 -170,69 -241.66 0.12 0.1-1 0,19 .................................................................................................................. ~' 06-^UG-97 ~WD 1838.00 18.70 231.63 92.00 1788.17 325.91 -18920 -265.34 0.88 -0.67 -0.48 ;~> .<.1:~ ~., .................................. O~-AtlG-O7 MWD 1 ~33.00 ,.0~0 23080 ~500 1877.75 357.51 -20911 -289¢~ 1.61 1.58 -087 ..................... 07.-AUG-g7 MWD 2028,00 19.70 230.62 95,00 1967.05 38988 -229,63 -315,07 0,53 -0.53 -0,19 ,.. 07-AUG-97 MWD 2080.00 19.50 230.26 52.00 2016,04 407.29 -240.74 -328.52 0.45 -0.38 -0.69 ........................................................................................................... 0-AUG--97 MWD 2214.00 19.50 230.48 134,00 2142.35 451.94 -269.27 -362.97 0.05 0.00 O. 16 ........ . ,, ,., .. . ,. . ~ ~ ~ .~ ~ , ,, SuHVE'Y L;ALL;ULA-i IuN ANU FIb. LO WUHK$1'lb.E-i- Jo~,~o. o450._8."_/2,~6' SidutrackNo P~,ge 2 el 4 Company UNOCAL Rig Contractor & No. Pool Arc!it _A!as~,a- #!2.3. Field SWA.N..S.O.N .R!vER F!E.LD Well Name & No. SRLJ223-28/223-28 Survey Section Name Definitive Survey Bill Rep. MILLER. PIAMBtJRG ~ll~"r~-~ , ' ' WELL DATA ..... arget Description Target Coord. E/W Slot Coord. E/W . _ !!.8_9.87 Magn. Declination _22..2.!.0., Calculation Method MINIMUM CURVATURE arget Direction (o[~) Build\Walk\DL per: 100ftlXj 30mI I 10mi I Verl. Sec. Azim. .2.33.82 Magn. to Map Corr. 22.210 Map North to' OTi ............ stiav[¥ .................... ............ St,l~ey ~urvey Incl. Hole Course Vertical Total Coordinate BLlild Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(t ) / S(~) .... ~'(]1-) '/W(-) DL Build (+) Right (4-) Comment Type (F'r) ([~o) (oD) (FT) 1~ (Fl1 IF ri P~, ~0o ¢ q Drop (-) Left (-) ...................................................... 0-AUG-97 MWD 2341.00 2030 230.14 127.00 2261.77 495 08 -296 88 -396 24 064 063 -027 ................................... I 0-AUG-97 MWD 2435.00 20.60 229.01 94.00 2349.84 527.84 -318.18 -421.23 0.53 0.32 -1.20 ................................................................................ I 0-AUG-97 MWD 2563.00 21.20 228.08 128.00 2469.42 57330 -348.41 -455.45 054 0.47 -0.73 ................................ 10-AUG-97 MWD 2658.00 18.90 226.16 95.00 2558.66 605.65 -370.55 -479.34 252 -2.42 -2.02 ........................................................................ ~ lO-AUG-97 MWD 2753.00 19.40 216.38 95.00 2648.42 635.96 -393,91 -499.80 3.41 0.53 -10.29 ..................................................................................................... 10-AUG-97 MWD 2846.00 19.50 214.91 93.00 2736.12 665.38 -419.08 -517.84 0.54 0.11 -1.58 ............................................................................................................... 10.AtIG.97 MWD 2941.00 18 60 206.59 95.00 2825.93 693 85 -445.63 -533.70 3 01 -0.95 -8 76 ......... 10-AtIG-97 MW[]) 3036.00 18.00 197.85 95.00 2916.14 719.21 -473.16 -544.98 2 95 -0.63 -9 20 10 At Jf, J ti/ MW[) ;J130.OO IU.50 Il. Il.ti/ 940(.) 30£)5.1 / /41 UO -b02.53 -b',~1.61 313 1.60 -10bl 10-AUG-97 MWD 3226.00 19.60 179.52 96.00 3095,66 762.46 -534.51 -553.70 2.94 0.10 -8.80 ...................................................................................................................... 10-AUG-97 MWD 3322.00 20.30 169.33 96.00 3185.92 779.03 -566.98 -550.48 3.69 0.73 -10.61 lO..AUG-97 MWD 3417.00 22.10 164.31 95.00 3274.50 792.39 -600.39 -542.60 2.69 1.89 -5.28 .................................................................................................................. 10-AUG-97 MWD 3513.00 22.20 163.35 96.00 3363.41 804.77 -635.15 -532.51 0.39 0.10 -1.00 .......................................................................................................................................................... , 10-AUG-97 MWD 3610.00 25.00 158.48 97.00 3452.30 816.09 -671.79 -519.74 3.52 2.89 -5.02 ............................................................................................................... 10-AU G-97 MWD 3703.00 28.10 157.90 93.00 3535.48 826.39 -710.37 -504.29 3.34 3.33 -0.62 ........................................................................................................................................... 10-AUG-97 MWD 3799.00 31.40 155.56 96.00 3618.82 836.99 -754.10 -485.43 3.64 3.44 -2.44 .......................................................................................................... 10-AUG-97 MWD 3894.00 31.50 155.13 95.00 3699.86 846.89 -799.15 -464.75 0.26 0.11 -0.45 ......................................................................................................... 10-AUG-97 MWD 3991,00 30.90 154.83 97.00 3782.83 856.62 -844.68 -443.50 0.64 -0.62 -0.31 11-AUG-97 MWD 4086.00 30.80 153.00 95.00 3864.39 865.15 -888.43 -422.09 0.99 -0.11 -1.93 .................... 11 -AUG-97 MW[) 4180.00 30.80 152.08 94.00 3945.14 872.45 -931.14 -399.89 0.50 0.00 -0.98 ....................................................................................... 11-AUG-97 MWD 4276.00 30.80 151.87 96.00 4027.60 879.42 -974.53 -376.79 0.11 0.00 -0.22 ........................ 11 At lC, ,07 MWI') ,1:I72 0(} ;tO 80 1 '1,ri ,01l `0G.00 ,lt 10 OG Illl!i [;,0 -1 O1/'.4(.) :1!~;' ~.)1 1 I) l 0 0() 1 ~,)! 11-AUG-97 MWD 4499.00 30.30 148.57 127.00 4219.43 891.65 -1072.98 -319.94 0.69 -0.39 -1.11 ........................................................................................................................................................ 11 -AUG-97 MWD 4592.00 32.00 152.58 93.00 4299.03 897.34 -1114.88 -296.35 2.88 1.83 4.31 . , .. , , . ... , .,, · .~ ..m ~ ., . ,. . ! ! ~ ~ i ~ ~ , ¢ " SURVEY CALCULA'I-ION AND FIELD WORKSHEET J,~,r~o 0,~o.8'72~6 si..t.,,:kNo ~,,,,o 3 o, . ,I Field SWANSON ttlVt I1 [ lEI () I:~lr-].l:t:l c,,,,,~,,,,,y tIN(.)~.:AI Iii(.] Contractor 8, N,) I'ool A,,.t,c Al~,t, ka · 11123 /I Well Name & No. Stit. J 223-28/223-28 Survey Section Name Definitive Survc.'.y [:lift Rep. Mil t ER. IIAMBtJ['IG I~~='~ .... "; "': ' ;' ' WELL DATA ........ ;' ' ....... arOet IVt) ¢ ~) la,get Cooed. N/5 '.;lot Coord. N/S -!22~./b (A~ct (;or,cotton 0 000 Depths, Mcast,ed ~rom: RKbl [X1 M~SI..I [ SSI 'arget Description Target Coord. EAN Slot Coord. E/W . !489.87 Magn. Declination 22.2.!.0. Calculation Method MINIMLJM CLJF~VAI-IJRE Target Direction (r~l,i Build\Walk\DE per: ~0ott[>~ 30mil ~o,-t I yon. soo. Azim. _23.3.82 Magn. to Map Corr. 22.~!..0. Map North to: OTttdR ............. sUhvEY DATA ............ Survey Survey Incl. 14ole Course Vertical Total .......... Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(.t ) / S(-) E(+) / W(-) DL Build (-t-) Right (+) Comment Type (FT~ (DD) (DB) (F'r) (FI) (Fi') (Fr) I(U~, ~00 Fl) Drop (-) Left (-) 11 -ALJG-97 MWD 4688.00 31.80 151.31 96.00 4380.53 904.51 -1159.64 -272.49 0.73 -0.21 -1.32 ! 1-AUG-97 MWD 4782.00 32.40 151.74 94.00 4460,16 911.21 -1203.55 -248.68 0.68 0.64 0.46 11-AUG-97 MWD 4876.00 32.40 152.80 94.00 4539.53 918.61 -1248.13 -225.24 0.60 0.00 1.13 12-AUG-97 MWD 4972.00 32.70 151.20 96.00 4620.45 925.96 -1293.73 -200.99 0.95 0.31 -1.67 12-AUG-97 MWD 5068.00 32.70 150.97 96.00 4701.23 932.52 -1339.13 -175.92 O. 13 000 -0.24 12.At 1(.1 97 MWI) !)1 t;O.O0 3;.: t;O 150.40 92.00 4778.70 (.)38.45 -1382.41 -lbl.62 0.35 -0.11 -OG2 12-AUG-97 MWD 5256.00 32.30 150.31 96.00 4859.71 944.31 -1427.18 -126.14 0.32 -0.31 -0.09 12-AUG-97 MWD 5352.00 32.60 149.37 96.00 4940.72 949.71 -1471.71 -100.26 0.61 0.31 -0.98 12-AUG-97 MWD 5445.00 32.50 148.59 93.00 5019.11 954.21 -1514.59 -74.47 0.46 -0.11 -0.84 12-AUG-97 MWD 5541.00 32.20 147.69 96.00 5100.21 958.08 -155B.22 -47.36 0.59 -0.31 -0.94 12-AtIG.97 MWD 5635.00 32.40 148.21 94.00 5179.6'7 961.70 -1600.80 -20.71 0.36 0.21 0.55 12-AUG-97 MWD 5730.00 32.90 146.86 95.00 5259.65 965.02 -1644.03 6.81 0.93 0.53 -1.42 13-AU G-97 MWD 5825.00 32.70 146.20 95.00 5339.51 967.45 -1686.96 35.19 0.43 -0.21 -0.69 13-AUG-97 MWD 5921.00 32.60 145.70 96.00 5420.34 969.38 -1729.88 64.19 0.30 -0.10 -0.52 ~ 13-AUG-97 MWD 6016.00 32.20 144.91 95.00 5500.55 970.70 -1771.73 93.16 0.61 -0.42 -0.83 13-AUG-97 MWD 6112.00 31.80 143.19 96.00 5581.96 970.91 -1812.91 ] 23.02 1.04 -0.42 -1.79 13-AUG-97 MWD 6168.00 31.70 142.27 56.00 5629.59 970.35 -1836.36 140.86 0.88 -0.18 -1.64 13-AUG-97 MWD 6260.00 31.30 141.15 92.00 5708.03 968.58 -1874.09 17065 0.77 -0.43 -1.22 13-AUG-97 MWD 6325.00 31.50 140.72 65.00 5763.51 966.88 ~1900.38 191.99 0.46 0.31 -0.66 · 13-AUG-97 MWD 6388.00 31.30 140.30 63.00Ii. 5817.28 964.98 -1925.71 212.86 0.47 -0.32 -0.67 13-AUG-97 MWD 6481.00 31.70 140.38 93.00 589658 962.03 -1963.12 243.87 0.43 0.43 0.09 13-AUG-97 MWD 6576.00 30.80 139.35 95.00 5977.79 958.64 -2000.80 275.64 1 . 10 -0.95 - 1.08 14-AUG-97 MWD 6702.00 30.60 139.40 126.00 6086.14 953.65 -2049.63 317.52 0.16 -0.16 0.04 14-AUG-97 MWD 6766.00 3020 138.61 64.00 6141.34 950.94 -2074.07 338.76 0.88 -0.62 -1.23 ~---JIJ~l~.~} SUHVEY L;ALL;ULA'I ILIN AND FII:.LI3 WUI-IKSI-IEE'i' ,~o,)No o,~.0.-~.7~ S~dotrackNo, Rag° 4 et ,~ i II ' - ' LJNOCA[. Ri9 Contractor & No, Pool Arctic Alaska - #123 Field SWANSON RIVER FIELD Well Name& No. SP, tJ223-28/223.28 Survey Section Name Definitive Survey BPIIRep. Mlit. ER, itAMBI, JRG WEll DAI'~ ....... target 'IVD ¢ ,) Target Coord. N/S [..;lot Coord. N/S -}228.'_/6 Grid Correction O.O00 Depths Measured From' RKB ~Xi MSt.1 J SSI target Descriphon ]'argot Coord. E/W Slot Coord. EAN 1489.87 Magn. Declination 22.2~0 Calculation Method MINIMLJM C(JRVAT(JRE .... fa,ge~ Direction ¢)[)) Build~Walk~DL per' lO0ff[~ 30mI I 1Omi ~ Vert. Sec. Azim. ~33.82 Magn. to Map Corr. 22.2!~ Map Nodh lo: OTi tER ................ suav v'bXi, ...................... . . lotal Coo[dinate ~uilO ~ate Walk Bate Survey Sumey Incl. Hole Course Vedical .......... Build (+) Right (+) Comment Date Tool Depth Angle Direction Length ~D Section N(t) / S(~)- E(+) / W(-) DL Type Drop (-) Left (-) (Fq (OD) (DD) (F'O (~ (FI~ (Fq (P~r 100 F1)I ...........................................................................................-'1 14-ALJG-g7 MWD 6862.00 2940 13769 g6.00 6224.64 94623 -210961 3705g 0,96 -0.83 -0,96 . . 14..ALJG-97 MWD 6988.00 2880 136.35 12600 6334 74 93898 -2154.44 412.36 O, 70 0.48 - 1.06 ............................................ 14-AJIG.g7 MWD 7116,00 2790 135.42 128 00 6447.39 g30,60 -2198,09 454 66 078 -0,70 .0 73 14-At K~ 97 MWD /211.00 2/. 10 13,1.47 95.00 6531.65 923.83 -2229.08 485./1 096 -0.84 -1.00 ............................................................................... 14-AUG-97 MWD 7281.00 27.10 133.69 70.00 6593.97 918.44 -2251.26 508.61 0.51 0.00 -1.11 ............................................... 14-AUG-97 MWD 7360.00 27.10 133.69 79.00 6664.29 912.11 -2276.12 534.64 0.00 0.00 0.00 Projected Data - NO SURVEY ...................................................................................................................................................... ......................................................................................................................................................................................................... ...... ,/ .. ........................................................... ....... .............................................................................................................................................................................................................................. ........................................ ~ ...................... MEMORANDUM TO: DavidJ .(~~~on, Chairmac¢" State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 9, 1997 THRU' Blair Wondzell, '~ FILE NO: P. I. Supervisor FROM: Lou Grimald~, ¢.¢¢~ SUBJECT: Petroleum Inspector A999JHIEE.DOC BOPE Test, Pool rig #123 UNOCAL well #SRU 223-28 Swanson River Field PTD #97-88 Saturday, August 9, 1997: I traveled to UNOCAL's Swanson River field to witness the initial BOPE test on Pool rig #123, which is drilling well #SRU 223-28. I arrived at 0530 this morning, the test got underway at 1130 and ended at approximately 1630. This rig has been idle since it drilled the Corea Creek well for Marathon last year. All equipment that I observed seemed to have taken the inactivity well. The pad although small provided good access to the rig and was kept orderly and clean. All BOPE equipment was tested with one failure observed, this being the floor safety valve. Although it was apparent that it had just been rebuilt there was a slight leak at both the Iow and high test pressures. A spare valve was picked up and tested successfully. It was apparent to me that the BOPE equipment was well taken care of. Gary Goerlich (POOL toolpusher) provided a good check of the equipment and seemed dedicated to operating a safe rig. Summary: I witnessed the initial BOPE test on Pool rig #123 drilling well #SRU 223-28 in the Swanson River field. The test lasted 5 hours with one failure, the floor safety valve. Attachment: A99JHIEE.XLS cc; Dan Williamson (UNOCAL Drilling Supt.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 8OPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Pool Rig No. Unocal SRU 223-28 Set @ X' Weekly Other 123 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 8/9/97 97-88 Rig Ph.# 283-2539 Mike McAfl Gary Goerlich 28 T. 8N R. 9W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 250/3500 P N/A 250/5, O00 P 250/5, 000 P 250/5, 000 P 250/5,000 P 250/5,000 P 250/5, 000 P N/A 250/5, 000 MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test O. uan. Pressure P/F 1 250/5, 000 P 250/5,000 P 250/5,000 F 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 250/5,000 P 34 250/5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: Six Bottles 2,900 P 600 P minutes 22 sec. minutes 15 sec. P Remote: P 2200 Average Psig. TEST RESULTS Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 2'/ Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Floor safety valve leaked, picked up spare valve and tested "OK" Good test procedure, Good results for initial test on newly activated rig. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X' NO Waived By: Witnessed By: Lou Grirnaldi FI-021L (Rev.12/94) A99JHIEE.XLS UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax July 28, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Swanson River #223-28 ~'~ ''~ ~' (~ ~ APl#50-133-20478 As-Built Conductor Surface Location Commissioner Johnston' Enclosed is the surveyed as-built conductor location for Swanson River Well #223-28. If there are any questions, please contact Tim Billingsley at 263-7659. Dale Haines Drilling Manager Unocal Alaska bJ bJ NE CORNER SEC. 28 PROTRACTED N 2471790.608 E !42472.~25 1487.6' FWL S89'14'39"E NORTH LINE SEC. 28 Pad Surface Location Well 223-28 Top Center 8' Dia. CMP N 2470541.98' E 545946.04' 60'45'53.909" N 150'52'21.251" W Surface Elev. 209' MSL 1) Location of well site was accomplished using static GPS techniques. 2) All dimensions are in U.b. ~urvey feet end bearings are grid unless noted otherwise, ,3) Surface location coordinates ore referenced to NAD27 NGS Sra. "Audry" recovered. 4) Cartesian coordinate values are in Alaska State Plane Zone 4. 5) Surface elevation is referenced to MSL based on SRU 43-28 Well Elev. 159.0' according to Completion Report. SECTION 28 TSN, RgW, SEWARD MERIDIAN, ALASKA GRID 97-17-~5 FIELD I~OC~< NO, 1":500' SCALE 7/~3/97 OATE \./.E-II VV L__L_L_ SWANSON RIVER FIELD, ALASKA Surveyed by: McLAN Consulting Group Box 468 Soldotna, AK 99669 UNOCALd DRAWING NO. 973018WS TONY KNOWLES, GOVERNOR ALASI~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 16, 1997 Dale Haines Drilling Manager UNOCAL P O Box 196247 Anchorage, AK 99519-6247 Re' Swanson River Unit 223-28 UNOCAL Permit No: 97-88 Sur. Loc: 1275'FNL, 1500'FWL, Sec. 28, T8N, R9W. SM Btmhole Loc. 1241'FSL, 1719'FWL, Sec. 28, T8N, R9W, SM Dear Mr. Haines: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BO?E test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notic .~g the Commission at 279-1433. David W. ~,ohnsto~-- ~ '~'- ~ Chairman ~.~ '~ BY ORDER OF THE COMMISSION dlffEnclosures CC; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA .. _. ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill X Redrill E Re-entry [3 Deepen E 2. Name of Operator Unocal lb. Type of well Exploratory ~ Stratigraphic Test 13 Development Oil FI Service ,Fi., Development Gas X Sin. glo Zone 13 Multiple Zone D 5. Datum Elevation (DF or KB) 10. Field and Pool 230' RKB est 6. Property Designation A-028399 7. Unit or Property Name Swanson River 8. Well Number 223-28 9. Approximate spud date 7/1/97 3. Address P.O. BOX 196247 Anchorage. Ak 99519-6247 4. Location of well at surface 1275' FNL and 1500' FWL Sec. 28, T8N, R9W, SM At top of productive interval U. Tyonek 1835' FSL and 1489' FWL Sec. 28, T8N, R9W, SM At total depth 1241' FSL and 1719' FWL Sec. 28, T8N, R9W, SM Swanson River Field Tyonek Pool 11. Type Bond (see 20AAC2S.0253 AK Statewide Oil & Gas Bond Number U 62-9269 Amount $200,000 12. Distance to nearest property line 1968'@ Surf, 2120'@ BHL 13. Distance to nearest well 3498'@ surf(SRU#41-28) 2112' (~ TD (SRU#34-28) 16. To be completed for deviated wells Kickoff depth 500 feet Maximum hole angle 36° 18. Casing program size Hole I Casin.~ I 9-5/8 .8.5" I 7" , 6" I 3-1/2 Specifications WeightI Grade t Coupling ' 53.5 I L-80 I Buttress 29 I L-80 I ABButt 9.2 I'L-80 [ ABButt Length 8O 2300' 5386' 14. Number of acres in property Lease 1760 acres 15 Proposed depth (MD ar~ 'rVD) 7486' MD 6600' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2) Maximum Surface 496 psig. Attotal depth (TVD) 3432 psig Setting Depth Top Bottom 2100' 2031' 19. To be completed for Redrill, Re-entry and Deepen Operations Present well condition summary Total depth: measured feet true verical feet TVD Quantity of cement 80 Drive 2219' 600 cur Class G blend 7486' 6600' 1040 cuff Class G blend Plugs (measured) Effective Depth measured feet true vertical feet Junk(measured) Casing Length Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Size Cement~-' ~, C{. E ~ V ~.e~ured Depth APR 1997 True Vertical Depth 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'~ ~_~, (,., ..011¢--~ Title: Drilling Manager '---- Commission Use Only Date Permit Number APl Number I Approval date ¢'¢' Conditions of approval Samples required E] Yes ~¢'No Mud log required E] Yes ~ No Hydrogen Sulfide measures [] Yes ,,~No Directional Survey required '~Yes FI No Required working pressure for BOPE Q 2M FI 3M 'J~5M ~ 10M FI 15M Other: by order of Approved.by 0rlgJna; $i,j~!ec, d',... Commissioner the commission Form 10-401 Rev. 12-1-85 David W. Johr~s~o~:, ISee cover letter for other requirements Submit in triplicate DRILL PAD LOCATION MAP SWANSON RIVER UNIT Swc~nson River Field RE~E~V Swanson River Field 34 -9 0 :i ~ 31-5 x i7 !6 14-t5 29 T8N-R9W ~"~ 3 ! 7----.2__.~, / / -~7 T.2'. 41-33 -, -. 13-34 ~{ i Swanson River 223-28 Property Plat Surface Location: 1275' FNL & 1500' FWL Sec. 28, T8N, R9W, SM proposed Target Locations (Section 28) Target #1 = 1655' FNL & 981' FWL @ 2610' TVD Target #2 = 1816' FNL & 899' FWL @ 3170' TVD Target #3 -- 1835' FSL & 1489' FWL @ 5720' TVD Target Sterling A-9 Beluga B-6 U. Tyonek TD = 1241' FSL 1719' FWL, 6600' TVD C-061447 i A-028077 CIRI Section 20 Section 21 Section 22 ' A-028406 SR 223-28 Surface Location Section 29 Section 28 Section 27 A-0283 I A-028396 Section 33 Section 34 Section 32 i la i A-028990 I I 1" = 0.5 mile UNOCAL SwansOn River #223-28 Offset Section Ownership Section Lease # Owner 28 A-028399 100% Unocal 2O C-061447 100% Cook Inlet Region, inc. 21 A-028077 100% Unocal 22 A-028077 100% Unocal 27 A-028406 100% Unocal 29 A-028399 100% Unocal 32 A-028396 100% Unocai 33 N/2 and SW/4 A-028399 100% Unocal 33 SE/4 A-028990 100% Unocal 34 N/2 A-028406 100% Unocal 34 S/2 A-028990 100% Unocal U PRPPLNOW. DOC /~.vh', £ 2 1997 Alaska 0it & Gas Cons. uommiss~"' Anchorage 1 4/7197 Swanson River 223-28 Proposed Directional Plan 5' Surface Localion: 12T FNL & 1500' FV, rI.. Sec. 28, T8N, R9W, SM RKB = 230' estimate Target Location Target #1 = 1655' FNL & 98l' FWL @ 2610' TVD Target #2 = 1816' FNL & 899' FWL @ 3170' TVD Target #3 = 1835' FSL & 1489' FWL @ 5720' TVD 1241' FSL 1719'F~,6600'TVD T~ Sterling A-9 Beluga B-6 U. Tyonek SR 223-28 Proposed Surface Location SRU 41-2~ Targets #1 and 02 Target #3 SRU 43-28 } TD, 7486' MD =6600' TVD SRU 34-28 Section 28 Section 27 SRU 12-27 SRU 212-27 SRU 221-33 Section 33 ~I~SRU 31-33 WD Water Disposal BRKER HUGHES INTEQ ID:907-267-6621 HKK U~'~K i~:DU HO.UU1K.uz ~000,00 2~oo.oo 2716.27 2800,00 2900,00 3000.00 3100.00 3200.00 3300.00 33or.17 3400.00 3500,00 3600,00 3700,00 )800.00 3900.00 3926.38 4000.00 &500.O0 5000.00 5500.00 6000,00 63~.4s 6500.00 ?000,oo UNOCAL SRU 223-28,223-28 Swanson River Untt,Kenet Penir~ute, ALaska Neasured Inciin. AzJ~th True Vert Depth Degrees Oegree~ Depth 0,00 0,00 233.82 0.00 500.00 0,00 233,82 500,00 600.00 3.00 233.82 ~99.9~ ?O0,O0 6.00 233.82 699.63 800,00 9.00 233.82 798.77 900.00 ' 12.00 2~3.82 897.08 1000.00 15.00 233.B2 1100,00 18.00 2~].BZ 1090,18 1166.36 19.93 2~3.82 1151.0~ 1500.00 19.93 233.82 1A66,58 19,93 233.82 1936.63 19.93 233.82 2~06,69 19.93 233.B2 2610.00 18.98 226.82 268~.96 18,22 217.70 2783.76 17.92 208.05 2878.85 18,11 198.35 297"5.97 18.76 189.07 306S.86 19,86 180,57 3163.25 19.93 180.00 3170.00 22.08 175.07 3256.66 2~,~ 170.71 33~8.50 27,10 167.11 3~38.51 29.7~ 16~.10 3526.46 32,~3 161,5~ 3612.10 35.17 159.3& ?~69~.19 35.90 158.81 3716.66 35.90 158,81 3776.29 35,90 158.81 G181.33 35.90 158.81 ~586.36 35.90 t58,81 4991.39 35.90 158.81 5396.42 35.~:~ 158.81 35.90 158,81 5801.,6 35,90 158,81 6206.~ 7~8~,78 35.90 158,81 6600,00 PROPOSAL LISTING Page 1 Your ref : ~-~8 Vere{on~ Last revised E C T A N G U L A R Dogleg Vert 0 0 R 0 ! N A ? £ ~ Oeg/lOOft Sect 0.00 N 0.00 E 0,00 0.00 0.00 # 0.00 E 0.00 0.00 KOP 1.$S $ 2.11 ~ 3.00 2.62 6.18 $ 8,&~ ~ 3,00 10.46 13.88 S 18,98 N 3,00 23,~1 24.64 s 33.69 u 3.00 ~1.7~ 38,~Z S 52,53 ~ 3,00 65.08 55.18 S 7~.~5 ~ 3.00 93.48 67.53 ~ 92.33 U 3.00 116.39 EOC 135.07 ~ 184.68 ~ 0.00 228.80 ~35.68 s 32~.26 w 0,00 399.25 336.30 8 459.83g 0.00 569.69 379.82 $ 519.3& ~ 0,00 6~3.41 397.56 S 540.79~ 3,00 671.20 421.06 $ 56Z,21 ~ 3,00 702,36 447.02 $ 579.ol u 3.oo 7~1.2G 475.35 5 591.14 W 3.00 757.76 505.98 S 598.57 ~ 3,00 781,84 538.~ $ 601.28 ~ 3.00 803.42 5~1.28 $ 601.29 ~ 3.00 80~,8~ 57a.69 $ 599.r9 ~ 3,00 87.3.~? 613.72 $ 59~.82 ~ 3.00 8~2.41 656.~3 S 586.38 U 3.00 860.81 70~.49 S 57&.50 U 3,00 8r8.42 r51.79 S 559,22 ~ 3.00 895.18 80~.~8 s 5&0.56 w 3,00 911.05 818.~1 $ 53~,0~ w 3.00 915.08 858,75 s ~1~,48 w 0.00 9~6.~ 1132,09 $ ~13,$0 ~ 0.00 100~.07 1~0~.~4 s 307.S2 ~ 0.00 10rr.88 1678.76 S 201,~4 w 0,00 115~.?0 195~,13 $ 95,~6 W 0,00 1229.52 2170.~0 $ 10,89 Q 0,00 1290.09 2225.67 $ lO,&Z E 0.00 1305,34 2498.82 S 116.&0 E O,OD 1381.15 2764.39 S 219.37 E O.O0 1454.81 TO 9-Apr-97' Begin Turn to Target #2 Begin Finat Build ! Continue lurnJ~aal/aJG Fina( EOC Coordinates from slot #1 and TV~ from RKB (230.00 Ft above ~ean sea [eve[). Bottom hots distance is 2773.08 on azi~dth 175.~6 degrees from ~e[[head. Total Dogleg for ue[Lpath 15 ~6.~6 degrees. vertical ~e¢tion fa from uel[head on a~lmuth ~33.8~ degrees. Calculation uses the mintn~ncurvature method. Pre'anted bY Baker Hug~sel~N' ~1 ~ -i ~/~DK~~ . PP, 2 1997 Gas Cons. Anchorage UNOCAL Surface- Pleistocene Gravel (Fresh Water) Sterling Beluga Upper Tyonek (D-1 Coal Marker) Swan~bn River #223-28 Geological Information 4110197 Geological Marker Tops MD 60'-500' TVD (RKB:230' above sea level) 60'-500' 2716' 2610' 3307' 3170' 6399' 5720' TD 7486' 6600' The Pleistocene fresh water zones down to 500' will be protected behind the surface casing which will be cemented from 2219' TVD/2300' MD to surface. The gas sands listed above will be protected by the production liner which will have cement from TD to the base of the surface casing at 2219' TVD/2300' MD. TAB Geolform.doc 1 4/10/97 UNOCAL 10) 11) 12) 13) Swan~'On River #223-28 General Procedure 4/10/97 1) Build appx 1 mile of road and a 250' x 200' ddlling pad west of SRU 41-28. The surface location of the Swanson River #223-28 will be approximately 1275' FNL & 1500' FWL, Sec. 28, T8N, R9W 2) Install 9-5/8" conductor to at least 80' by ddving or with auger. If auger is used, cement conductor to surface. Install starting head on conductor. 3) Move in Pool Rig #123 or equivalent. RU mudlogging unit. 4) Rig up diverter and lines. Function test divert valves. 5) Directionally drill 8-1/2" hole from surface to 2300' MD/2219' TVD. 6) Run 2300' of 7" 29# AB Modified Buttress casing. 7) Cement 7" casing with 600 cuft cement (100% excess). 8) ND diverter, install wellhead, NU and test 5000 psi BOP stack. 9) Drill float equipment, cement and 10' of new formation and perform LOT. Directionaily drill 6" hole from 2300' to 7486' MD/6600' 'I'VD. Log from 7486' TD to surface casing at 2300' with tdple combo density/neutron/induction log. Run 3-1/2" 9.2# L-80, AB Modified Buttress liner from 7486' to 2100' with 3-1/2" x 7" liner hanger and 3-1/2' tie-back receptacle. The 3-1/2" liner stdng will include a diverting tool at approximately 5000' MD to ensure cement coverage over upper interval of liner. Pump staged cement job through bottom of liner and through diverting tool. Total cement for both stages will be 1040 cuff based on 50% excess. 14) Set hanger, release from same and circulate through stinger to avoid having cement fall back into top of 3-1/2' liner. Set liner top packer. POOH. 15) Run 3-1/2' completion tubing. Stab into tie back receptacle at liner top packer. 16) ND BOP stack, NU seal flange and tree. Test tree to 5000 psi. 17) Demob rig. 18) Run cement evaluation log from PBTD at 7400' to top of liner at 2100'. 19) Perforate and flow test well. /f TAB Proc.doc 1 4/10/97 Swanson River 223-28 Proposed Casing Program Appx RKB = 230' 3-1/2 x7 liner hanger/pac er [x><~ with tieback receptacle ~ "~ 9-5/8" L-80 47# Buttress conductor @ 80' Max hole angle - 36 degrees KOP = 500' Methanol Injection Line ~ appx 2000' Surface Casing 7" 29# L-80, AB modified buttress ~ 2300' MD/2219' TVD Divert Tool 5000' MD appx Production Liner 3-1/2" L-80, 9.2# AB mod buttress 7486' MD/6600' TVD Note: All tubulars for this well will be new. Swanson River #223-28 Offset Mud Weight vs Depth 7.0 o Mud Weight, ppg 8.0 9.0 10.0 11,0 12,0 13.0 1000 2O0O 3000 4OO0 5OOO 6000 70OO 8000 2/97 12-27 i~I 212.27 10/59 9000 -.-,~#34-28,1963 ] -~#41-28,1961 ] --~-#43-28,1961 ] ~#242-16,19891 [] Initial Reservoir Pressures Swanson River Well #223-28 Bottomhole Pressure Information The following presents data used for calculation of anticipated surface presures (ASP) during drilling of the Swanson River No. 223-28. The pore pressure gradient was estimated from the following information: BHP Depth Well psi TVD EMW, pp.q Comment SRU 242-16 1292 3161 7.9 SRU212-27 3250 6532 9.57 9/89, initial BHP before production 2/97, initial BHP after recompletion SRU 212-27 4730 7620 11.9 SRU 12-27 4300 7650 10.8 10/61, initial BHP before production 10/59, DST The fracture gradient at surface casing point was conservatively estimated at .80 psi/ft or 15.4 ppg. Casing Pore Casing Setting Fracture Pressure Mud Pore ASP Size Depth Gradient Gradient Weight Pressure Drilling (in.) (.'I'VD ft) (Ibs/~al) (Ibs/¢lal} ('lb/_clal} (psi) (psi) 7 2219 15.4 8.4 9.0 970 391 3-1/2 6600 NA 9.57 10.6 3284 Procedure for Calculatinq Anticipated Surface Pressure While Drillinq 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 1/4 gas gradient and 3/4 mud gradient to the surface as follows: 1) ASP = (FGx.052xD) - (MWx.052xD) = (15.4x.052x2219) - (10.6x.052x2219) = 554 psi OR 2) ASP FPP- (0.1gas gradient xDx.25) - (MWx. 052xDx. 75) 3284 - (. 1x6600x.25) - (10.6x.052x6600x,,7-.5.~.~. _ 3284- 165- 2728 391 psi Alaska Oil & *'Gas Cons, 6omrnlss~o, Anchorage Kick Tolerance With 10.6 ppg mud in the hole and a gas bubble in the well and a shoe frac gradient of 15.4 ppg, the shoe will fail at 554 psi of surface pressure ((15.4- 10.6)x.052x2219'). At the most vulnerable point for shoe failure when the gas bubble is just below the 7" casing shoe, the hydrostatic pressure situation will be as follows: + 554 psi surface pressure + 2219' x .052 x 10.6 ppg mud in the surface casing - 1223 psi + Gas height (Ht) x 0.1 psi/ft gas bubble just below surface casing + (6620'-2219'-Ht) x .052 x 10.6 mud below the gas bubble -- 9.57 x .052 x 6600' TBD - 3284 psi formation pressure Solving the above equation for Ht: 554 + 1223 + 0.1Ht + (6620'-2219'-Ht).5512 = 3284 Ht = 2012' (TVD height of gas bubble just below shoe which will cause shoe fracture failure) The hole angle is 35.9° so the MD height of the gas bubble is 2483' MD and the gas volume is 2483' x (.023 bbl/ft for a 3.5" x 6" annulus) = 57 bbl If the gas volume at the shoe is 57 bbl, then the original gas kick volume when it first entered the wellbore at 6600' TVD would be: P1 x V~ = P2 xV2 P~ = 10.6 x 6600' x .052 -- 3638 psi hydrostatic pressure at TD V~ = X, unknown gas volume at TD P2 : (554 psi surf pressure w/o fracturing shoe) + (10.6 ppg x .052 x 2219') = 1777 psi pressure at shoe V2 = 57 bbl gas bubble below 7" shoe V~ = 57 bbl x 1777 psi/3638 psi: 28 bbls kick tolerance at 6600' TVD. This size of kick should be able to be detected with close monitoring of the trip tank and with the help of a mudlogging unit which will be operating during the drilling of this well. Swanson River #223-28 Casing Design 7" Surface Casinq, 29# L-80, Buttress Worst case for burst is tubing leak near the surface after the well is completed. Burst = 6600'TVD x((9.57 formation x .052) - 0.1 gas grad)) 29# rated @ 8160 psi for burst = 2624 psi fl drlg to TD Safety Factor = 3.1 OK Worst case for collapse is if lost returns occur while drilling below the 7" surface casing. Collapse = (8.4x.052x22197 -(2219' x .1) = 747 psi for full evacuation Tension = 29 x 2300' = 66,700 29# rated @ 7020 psi for clpse Safety Factor = 9.4 OK 29# rated for 676K Safety Factor = 10.1 OK 3-1/2" 9.2#, L-801 AB mod buttress liner ¢. 8836' MD, 8112' TVD Tension = (7486'-2100') x 9.2#= 50K Rated = 207K for joint Safety Factor = 4.1 OK Worst case for collapse of the liner would be when the completion interval depletes and a formation with virgin pressure is behind pipe. Collapse = (9.57 x .052 x 6600') - 0 psi inside Rated = 10,530 psi for collapse = 3284 psi (Unrealistic but worst case) Safety Factor 3.2 OK 3-1/2" will be tied back to surface as completion tubing so worst burst case is: Burst= 6600'TVD x((9.57 formation x .052) - 0.1 gas grad)) Rated = 10,160 psi for burst = 2624 psi Safety Factor = 3.9 OK Swanson River #223-28 Casing Specifications Proposed Casing Surface Liner 7" 29#, L-80, AB mod Butt Joint Strength, K lbs i 676 Bocly Strength, K lbs 3-1/2" 9.2#, L-80, AB moa Butt 207 2O7 ! 746 {. Burst Rating, psi ~ 8160 ! 10,160 Collapse Rating, psi i 7020 ' 10,530 CSGSPEC.XLS Swanson River #223-28 Drilling Fluid Program Surface Hole Section 0'-2300' MD/2219' TVD Hole size = 8-1/2" Casing Size = 7" Mud type "- Fresh Water Spud Mud Mud Parameters: Weight: 8.4-9.0 ppg pH: 8.0-9.0 PV: 15-30 YP: 20-40 Fluid Loss: 20 cc/30 min % Solids: 10+ Production Hole Section 2300'-7486' MD or 2219'-6600' TVD Hole size = 6" Casing Size -- 3-1/2" Mud type- Polymer, Iow solids, non-dispersed Mud Parameters: Weight: pH: PV: YP: Fluid Loss: % Solids: 9.0-9.5 ppg from 2300' MD to 6750' MD/6000' TVD, increase to 10.6 ppg from 6750' MD to 7486' MD TD. 8.0-9.0 8-15 10-15 5-12 cc/30 min 6-10 Drill out the 7" shoe with a Iow solids non-dispersed polymer mud. Maximize efforts to keep drilled solids in mud to a minimum. Control excessive rheological conditions with light dispersant treatments as needed. Be cautious of sloughing coals. Circulate out drilling breaks to reduce possibility of sticking the drill string in a coal bed. At 6750'MD/6000' -I'VD, increase mud weight to 10.5 ppg to drill through Upper Tyonek intervals. Exercise caution on trips out of the hole to prevent swabbing in gas from Tyonek intervals. Observe hole closely for lost returns after mud weight increase. Drilling Fluid System Description Nabors Rig #154 or Equivalent Mud Pumps 2 ea Gardner Denver PZK10 (7'x10'') 1350 hp tdplex with one Hydril pulsation dampener, Model K20-5000. Pump charged by a 5" x 6" Mission 60 HP. Mud Tank System (1000 bbl Total Volume) Tank #1- 280 bbl, 4 compartments Tank #2- 440 bbl, one compartment Tank #3- 280 bbl, two compartments one of which is a 70 bbl pill pit Trip Tank - 100 bbl Mud System Eauipment 2 ea Derdck Plus Flow-line Cleaners (shale shakers) 1 ea Ddlco MOD degasser (deep pit) 1 ea Picenco mud cleaner 1 ea Picenco desilter, 16 cones 1 ea Picenco desander with two cones Iea Pioneer sidewinder mud mixer 4 ea Brandt 7.5 HP Brandt mud agitators 1 ea Pioneer Mark II Centrifuge 1 ea Pit level indicator with audio and visuaio alarms 1 ea Fluid flow sensor 1 ea Gas monitoring for H2S and LEL with sensors at dg floor, sub and sl~akers. UNOCALI ) SW~son River #223-28 Diverter Fill-up 4 Annular BOP 13-5/8" 5000 psi Flow 10" divert line with 10" ball valve The divert line will be situated as straight as possible with vent being 100' or more from any ignition source. 9-5/8" Conductor The valve automatically opens when the diverter closes. This is a vadance from 20AAC25.035. Diverter. doc REVISED: 4/14/97 DRAWN BY: TAB UNOCAL 13-5/8" BOP Stack 5000 psi Fill-up Double Gate 3" 5000 psi ith one manual and one hydraulic valve Annular BOP 13-5/8" 5000 psi I I Pipe Rams 13-5/8' 5000 psi Blind Rams 13-5/8" 5000 psi Flow Choke Line 3" 5000 psi with one manual and one hydraulk valve Single Gate Pipe Rams 13-5/8' 5000 psi BOPSM.DOC REVISED: 3/28/97 DRAWN BY: TAB Blowout Prevention Equipment Nabors #154 or Equivalent 13-5/8" BOP Equipment 1 ea 13-5/8" x 5000 psi wp ram type preventer (Hyddi) 1 ea 13-5/8" x 5000 psi wp double ram type preventer (Hyddl) 1 ea 13-5/8" x 5000 psi wp annular preventer (Hyddl) 1 ea 13-5/8" 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 kiill line. 1 ea Koomey BOP accumulator control unit with 285 gallon volume tank, w/twenty 11-gallon accumulator bottles. 1 ea 6 station, remote control panel 1 ea Thornhill Craver, automatic choke 3" - 10,000 psi with control choke panel 1 lot Hydraulic pipe and fittings from manifold to BOP stack. 2 2 199i' ~Jas.~ .0il .& Gas Cons. ~nch0.rage Swanson River Well No. 223-28 Cementing Program 7" Surface Casinq 8-1/2" hole @ 2300' MD Cement volume for surface casing: Lead cement Class G with additives at 12.9 ppg: 2050' x 0.127 cuft/ft (8-1/2" x 7~) x2.0 (100% excess) = 520 cuff Tail Cement Class G with additives at 15.8 ppg: 250' (2300'-2050') x 0.127 cuft/ft x 2.0 (100% excess) = 64 cuff 80' float joints = 80' x .2085 cuft/ft = 16 cuft Total Tail = 80 cuft Total cement = 520+80 = 600 cuff 3-1/2" Liner 6" hole @ 7486' MD, top of liner at 2100' MD Cement volume for liner based on open hole volume plus 50%, liner lap, and shoe joints. Estimated volume is: 5186' (7486'- 2300') x 0.1296 cuft/ft (6"x 3-1/2") x 1.50 = 1008 cuft 200' liner lap @ 0.1418 cuft/ft = 28 cuff 80' shoe jts x 0.04883 cuft/ft (3-1/2' liner capacity) = 4 cuft Total Cement = 1008 + 28 +4 = 1040 cuff Class G cement (~ 15.8 ppg with additives. The above volume will be pumped in two stages through a divert tool. The depth placement of the divert tool will be contingent on the formation log evaluation with the tool being placed at approximately 5000' MD near the bottom of the lowest productive Beluga interval. The first and second cement stage volumes will proportioned according to the actual divert tool depth. UNOCAL ) SR #223-28 Depth vs. Time Summary I I ' AFE ' ' Actual ~un 7" surf ca~ing ...... -jK.~ ................................................................................. - . . Oi)timum .... I Log, Run 3-1/2" liner a._nd complete as monobore I - ?/ ........ 1,000 2,000 3,000 4,000-, 5,000= 6,00~ 7,000 8,000 9,000 10,000 0 5 10 15 20 25 30 35 40 45 50 Time (Days) 3 monlnr.xls 4/10/97/9:30 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM/~ISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF UNION OIL COMPANY OF CALIFORNIA for an order granting an exception to spacing requirements of Title 20 AAC 25.055 to provide for the drilling of the Swanson River Field 223-28 development gas well ) Conservation Order No. 394 ) ) ) Union Oil Company of California ) Swanson River Field 223-28 ) ) ) ) May 12, 1997 IT APPEARING THAT: 1. Union Oil Company of California (Unocal) submitted an application dated April 18, 1997 requesting exception to 20 AAC 25.055(a) (4) to allow drilling the Swanson River Field 223-28 development gas well to a producing location that is closer than 1500 feet to a drilling unit boundary. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on April 25, 1997 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1. The Unocal Swanson River Field 223-28 well as proposed will be a deviated hole drilled from a surface location 1275' from the north line and 1500' from the west line (FWL) of Section 28, T8N, R9W, Seward Meridian (SM), the proposed top of the productive interval is 1835' from the south line (FSL) and 1489' FWL of Section 28, T8N, R9W, SM and the proposed bottom-hole location is 1241' FSL and 1719' FWL of Section 28, T8N, R9W SM. 2 Offset owners Cook Inlet Region Inc. and Union Texas Petroleum have been duly notified. 3. An exception to 20 AAC 25.055(a) (4) is necessary to allow drilling of this well. Conservation Order No. 3. April 2, 1997 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Swanson River Field 223-28 well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to 20 AAC 25.055 for the purpose of drilling the Swanson River Field 223-28 well is approved as proposed. DONE at Anchorage, Alaska and dated May 12, 1997. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission , Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entD7 of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). UNOCAL ) P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax Apdl 14, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Application for Permit to Drill (Form 10-401) Swanson River #223-28 Commissioner Johnston: Enclosed is the Application for Permit to Drill the Swanson River #223-28 including two copies. This well will be a gas well drilled into the Upper Tyonek Formation. The proposed BHL is approximately 1 mile west of current Tyonek gas production at SRU 212-27. The Beluga and Sterling formations will also be evaluated by this proposed well. There is no history in the Swanson River Field of hydrogen sulfide gas being present in any of the formations that this well will encounter. A road and drill pad will need to be constructed for this well. '; ne proposed surface location will be approximately 3/4 mile west of an existing pad at SRU #41-28. The well will need to be directionally drilled from the surface location which is situated on relatively high ground to a bottom hole location which is underneath land unsuitable for road or pad construction. The proposed directional wellbore at certain depths will be closer than 1500' to a section line but not closer than 1500' to a property line. A spacing exception request will be forthcoming. An exact survey of the surface location will be provided when road and pad construction is completed and a conductor is installed. If there are any questions, please contact Dan Williamson at 263-7677. Dale Haines Drilling Manager Unocal Alaska UNOCAL P. O. Box 196247 Anchorage, Ak 99519-6247 907-276-7600 907-263-7884 fax APR 17 1997' April 14, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Re: Commissioner David Johnston Application for Permit to Drill (Form 10-401) Swanson River #223-28 Commissioner Johnston: Enclosed is the Application for Permit to Drill the Swanson River #223-28 including two copies. This well will be a gas well drilled into the Upper Tyonek Formation. The proposed BHL is approximately I mile west of current Tyonek gas production at SRU 212-27. The Beluga and Sterling formations will also be evaluated by this proposed well. There is no history in the Swanson River Field of hydrogen sulfide gas being present in any of the formations that this well will encounter. A road and drill pad will need to be constructed for this well. '; ne proposed surface location will be approximately 3/4 mile west of an existing pad at SRU #41-28. The well will need to be directionally drilled from the surface location which is situated on relatively high ground to a bottom hole location which is underneath land unsuitable for road or pad construction. The proposed directional wellbore at certain depths will be closer than 1500' to a section line but not closer than 1500' to a property line. A spacing exception request will be forthcoming. An exact survey of the surface location will be provided when road and pad construction is completed and a conductor is installed. If there are any questions, please contact Dan Williamson at 263-7677. Dale Haines Drilling Manager Unocal Alaska Alask~ 0ii & Gas Cons. 'Anchorage WELL PERMIT CHEcCKLISToo yC.r _,,._. ,7/ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool .............. Y N 5. Well located proper distance from drlg unit boundary.. . N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............... '~ 'Y IY N 10. Operator has appropriate bond in force ........ t .Yv/ 11. Permit can be issued without conservation order ..... ; I~~ 12. Permit can be issued without administrative approval.~ N 13. Can permit be approved before 15-day wait ....... Nv REMARKS APPR ~TE 14. Conductor string provided ............... ~Y~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ....... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate. .'.'.'.'.'.'.'.'.' 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... m-%-y~ N 26. BOPE press rating adequate; test to ~~ psig. Y~/~rT~ N 27. Choke manifold complies w/A~I RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis of shallow gas zones .......... Y N 33. Seabed condition survey (if off-shore) ......... Y N 34. Contact name/phone for weekly progress reports ..... Y N [explorator~ only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions:
