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175-015
THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 13-04 Permit to Drill Number: 175-015 Sundry Number: 319-558 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vdv✓w.aogc c. a las ka.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such firrther time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, IQ ere Price r DATED thisa day of December, 2019. RBDMSI" DEC 131019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 5EFD DEC _ 6 2019 *T S Ivfflll AOGCC 1. Type of Request: Abandon Q • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend I] Perforate ❑ Other Stimulate ❑ Pull Tubing Q ` Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑' • Stratigraphic ❑ Service ❑ 175-015 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10115-01-00 ` 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0123B Will planned perforations require a spacing exception? Yes Q No 0 Soldotna Creek Unit (SCU) 13-04 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA 028996 ` Swanson River Field/ Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,843' 10,793' 10,818' 10,768' 1,428 psi 7,947' 10,589' Casing Length Size MD TVD Burst Collapse Structural Conductor 30' 20" 30' 30' Surface 1,990' 11-3/4" 1,990' 1,990' Intermediate 10,310' 7" 10,310' 10,268' Production 2,858' 5" 1 10,843' 10,793' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" & 2-3/8" 6.4# / L-80 & 4.6# L-80 10,253'&10,430'-10,453' Packers and SSSV Type: Baker FH Retrievable Packers Packers and SSSV MD (ft) and TVD (ft): 7,902', 10,430', 10,598', 10,629', 10,658',10, 689', 10,725' 12. Attachments: Proposal Summary r Wellbore schematic a 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch C] 116. Exploratory ❑ Stratigraphic ❑ Development 91 Service 14. Estimated Date for 15. Well Status after proposed work: January 10, 2020 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager Contact Email: ctw0 o dicDhilcorp.com f Contact Phone: 777-8443 Authorized Signature: Date: hQLc Z-oly COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test M Mechanical Integrity Test Q Location Clearance ❑ )54,vy Other: �L Z500 `s' 'Soto Post Initial Injection MIT Req'd? Yes ❑ No ❑ aJ Spacing Exception �f �i - MEC132019 Required? Yes ❑ No Subsequent Form Required: IEIDMS \� BY Approved by: COMMISSIONER THE COMMISSION Date: AHE OMMISS Form 10-403 Revise /2017 1 A1lPpproved ap cation is valid for 12 months from the date of app . O' 6 roval�,1 1h[S b nfj�;A L H Hilwm Alaska. LU Well Prognosis Well: SCU 13-04 Date: 11/22/2019 Well Name: SCU 13-04 API Number: 50-133-10115-01-00 Current Status: Shut -In Oil Well Leg: N/A Estimated Start Date: January 10, 2020 Rig: Rig 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 175-015 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0065 (M) AFE Number: Max. Expected BHP: Max. Potential Surface Pressure: Brief Well Summary —2,500 psi @ 10,720' TVD "'1,428 psi U (Based on offset well data) (Based on expected BHP and 0.1 psi/ft gas gradient to surface) In 1961, SCU 43A-5 was drilled and completed targeting the Hemlock 1-5 sands under PTD #161-016. In 1975, due to sanding issues, the lower section of the well was plugged and SCU 43A-5 was formally abandoned. In 1975, SCU 4313-5 was drilled as a sidetrack out of the original SCU 43A-5 wellbore under PTD #175-015. After the re - drill was complete, the bottomhole location of SCU 4313-5 was reviewed and the well name subsequently changed to U 13-4 for consistency with the Well Numbering System at the Swanson River Field. SCU 13-4 was a Hemlock producer (Bench 8 & 10) from August 1975 to June 2003. The well was offline from 1980 to 1995. The current completion consists of a 2-7/8" gas lift string (9 mandrels) and 7 lower packers with intermittent tubing connections. The well is currently shut-in. The purpose of this work/sundry is to P&A this well. Cement Summa t 20" Conductor cemented from surface to 30' „+ $ J 11-3/4" Surface Casing cemented from surface to 1,990' 7" Production Casing cemented from 7,870'- 10,852'. TOC per CBL. (SCU 43A-5) Milled 11" Window from 8,190' — 8,231', cemented window from 8,170' — 8,330', milled out cement from 8,170'- 8,194' 5" Production Liner cemented from 7,983' (TOL) to 10,843'. Tagged TOL and no cement found, pressure tested to 2,000 psi and failed. Squeezed lap from 7,785'-10,756'. Milled out cement from 7,797'-10,756. Pressure tested lapto 3,000 psi and passed. Ran CBL to 10,816'. Re -tested lap to 2,500 psi and also passed. Notes Regarding Wellbore Condition 0 There is a fish (dropped X Nipple and WLEG) located @ 10,589'. K MCorp Alaska, LL Well Prognosis Well: SCU 13-04 Date: 11/ 22/2019 A plug was set atl/ 9� isolate the perforations in this well on 8/8/2017. A successful MIT test ending with 1,600 psi on the IA was conducted on 8/13/2017. The pressures in this well are constant. Pre - Ops Work 1. Provide 24 hour notice to AOGCC that P&A of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160 G. P�- Slickline Procedure �-I � -131. Jk (T-- (W 14V Z-- 1a.MIRU Slickline Unit and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. RIH and retrieve plug. 07`i7Z- ` n1 D 3. POOH and RD slickline. yr CLei, L-- Workover Rig Procedure (PullTubin¢ ackers){ bLS �T/1 1. MIRU Rig #401. 2. NU BOPE. 3. Test BOPE to 250 psi Low/ 2,500 psi High and Annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC & BLM 24 hrs in advance of BOP test. Q b. Perform Test. c. Test VBR rams on 2-7/8" test joint. d. Email completed 10-424 form to all AOGCC addresses listed on the form within 5 days of BOPE test. s _ 4. L/D BOP test equipment.It.� 11J- 5. Pump kill weight fluid down tubing to ensure wellad. ��� • �F_ 4b ) 6. Pull tubing hanger free and pick up to unseat Baker FH Retrievable Packer (straight pull release mechanism 60,000 pounds over string weight to release). 7. POOH with tubing and packer. 8. PU and RIH with packer retrieval tool to Baker DB Retrievable Production Packer. (straight pull release mechanism). 9. POOH with packer. E -Line Procedure (Set Cement Retainer) 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low/ 2,000 psi High. 2. RIH with gauge ring, tag fish (or fill if present) and POOH. 3. PU and RIH with Cement Retainer and set at approx. 1. 4. POOH and RD E -Line. Workover Rig Procedure (Cement Lower Completion/Abandon Lower and H1 -H5 Perfs) 1. RU Cementers and pressure test lines. 2. RIH with tubing and stab into cementer retainer. n Hilwrp Alaska, LG Well Prognosis Well: SCU 13-04 Date:11/22/2019 3. Using the down squeeze method, Pump cement volume sufficient to cover from 10,430' to 10,818' (PBTD). U's� 4. Sting out and pick up tubing to pump 35' cement on top of retainer. 5. PU and reverse out to clean up pipe. 0 6. POOH with tubing. 1 L ©49 ne Procedure (Abandon G2 perfs) K- /Ud � � � 40Gt cc 1. PU and RIH with CIBP and set at approx. 10,370'. y'a S P7Y 2. Dump bail 35' cement on top of plug. 3. POOH. Set Plug Across Surface Shoe 1. PU RIH with 7" CIBP on E -line to 2,100' and set same. POOH. 2. PU and RIH with casing punches and punch casing from 2,090' to 2,094'. POOH 3. PU RIH W/ Casing punches from 1,888' to 1,892'. POOH. 4. RIH W/ tubing to 2,100 feet and lightly tag CIBP. PU 5' and place balanced cement plug from 2195 to 1700'. 5. PU pipe to 1,600 '. Reverse out to clean up pipe, and pressure up 500 psi to push cement behind ✓ casing. WOC. 6. RIH and tag cement. If cement is lower than 1,890', place second plug on top to makeup difference. E -Line Procedure (Abandon Surface) 1. RU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 2,000 psi High. 2. PU and RIH with 7" CIBP or Mechanical Bridge Plug and set at approx. 160'. POOH. 3. PU RIH with casing punches. Punch 7" casing fro 0TS o 154' OOirxvi�th e -line. C 4. RU Cementers and pressure test lines. Establish cir ion down the 7" X 11-3/4" annulus through the casing punches and up the 7" casing. 5. Pump cement down backside and bring up the 7" to surface. WOC. 6. RDMO Rig 401. Downhole portion complete. Post -Rig Abandonment Procedure 1. Excavate cellar, cut off casing 3' below natural GL. 2. Verify cement level w/ hard tag after cutoff, 3. Notify AOGCC and BLM 48 hrs in advance. 4. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a Hilcorp Alaska, LLC b. PTD 175-015 c. Well Name: SCU 13-4 d. API: 50-133-10115-01 5. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 6. Photo document casing cut off and Welded Plate install. 7. Backfill excavation, close-out location. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. RWO Sundry Revision Change Form Well Prognosis Well: SCU 13-04 Date: 11/22/2019 II 12 � VD Hole in Well was sidetracked •. �✓ �[ from 8,190' in - - art p 7" 29# casing below t( P �' 7/8" x 2-7/8" Butt River r AgL3 2.347 4.631 3 SCHEMATIC 4 �t1 $1 C' WellSSwanson Well SCU 13-4 5 G2 6 6048',6650', Parted 7 H1 -H5 Actual Completion 4/5/99 l[ileonr Alaeka, LLC 11 S (ELM) 7,902' � Packer, Retrievable, Baker Mod. "FH" 2-78" y 10 7,947' 2.313 3.500 Nipple,' X', 2.3131.Div/ PX Plug 09/08/17 io CASING AND TUBING DETAIL 10,253' RKB= 15.30' SIZE WT GRADE CONN to TOP BTM 10,571' 1.995 2.375 1 8 10,579' 2441 3.700 WLEG (Dropped dot" ]role) 20 10,589' 1.995 3.875 Scoophead Guide Assembly 10 30, 1.995 3.937 Overshottvith grapple, (IA' of tubing sndlowed) 10,600' 1.995 2.375 Top of original tubing stub 11 I1-3/4" 47 J-55 - 11.000 Surface 1,990' Otis"S"nippl9 12 2 Seleryloint, Brown "CC", 2-3/8- 12 10,627' 7" 29 N-80 BT 6.184 Surface 126' 14 10,635' - Otis "S" nipple 14 10,653' 7" 26 N-80 BT 6.276 126' 1,206' 10,658' Packer, Retrievable, Baker Mod."PH"2-3/8" 16 10,663' 7" 23 N-80 BT 6.366 1,206' 4,879' 10,687' Otis XA sleeve 17 106g9' 7" 26 N-80 BT 6.276 4,879' 6,681' 10,721' Safety Joint, Brown "CC', 2-3/8" 18 10,722' 7" 29 N-80 BT 6.184 6,681' 190' 10,731' Camco'D"nipple 21 10,733' - - 5" 18 N-80 PERFORATION HISTORY DIL 4.151 7,985' 10,843' Inteval Aecum. Date Zone To Btna Amt s f Comments 726/96 G2 10375' Tubing 4/10/99 Hl 10,43Y 10,441' G' 4 2-1/8" HC 60 de 4/10/99 Hl 10,447' 10,455' 8' 4 2-1/8" HC 60 de 4/10/99 H2 1 468' 10,475' 7' 4 2.1/8" HC 60 de 4/10/99 IDA 2-7/8" 6.4 L-80 Bull (SC) 2.441 15.3' 10,253- 10(504' 10622' 18' 2 1-11/16" FJ Ode . UBS 2-3/8" 4.6 N-80 Butt 1.995 10,430' 10.453' II 12 � VD Hole in Well was sidetracked •. �✓ �[ from 8,190' in - - art p 7" 29# casing below t( P �' 7/8" x 2-7/8" Butt r AgL3 2.347 4.631 3 3506',4237, 4 �t1 $1 C' H8 5 G2 6 6048',6650', Parted 7 H1 -H5 tubing tail at 10564' 9 11 S (ELM) 7,902' � Packer, Retrievable, Baker Mod. "FH" 2-78" y 10 7,947' II 19M LH10 21 12 JEWELRY DETAIL Hole in D Do •. t U118 casing - - M below 7/8" x 2-7/8" Butt 10,691' 2.347 4.631 GLM, Careco, KBMM, 2-7/8" x 1", 05673-000-00001 3506',4237, H8 4841',5445', 14 6048',6650', 7255',7858' //©a 3 7,902' 16 Packer, Retrievable, Baker Mod. "FH" 2-78" y r 4 7,947' 2.313 3.500 Nipple,' X', 2.3131.Div/ PX Plug 09/08/17 io 5 10,253' 17 /�1�►/ 6 10,430' 18 Packer, Baker Retrieve D (646-16-1400) UH10 19M LH10 21 ETD =10,818', TD =10,843' MAX HOLE ANGLE= 2.5deg DRAWN BY: NM Updated by DMA 08-16-17 JEWELRY DETAIL D h D Do Item 20' - - Tubingllanger, 7"x2.7/8", Shaeffer P/N: 421758 Type HBPVP2. 7/8" x 2-7/8" Butt 2 2748', 2.347 4.631 GLM, Careco, KBMM, 2-7/8" x 1", 05673-000-00001 3506',4237, 4841',5445', 6048',6650', 7255',7858' 3 7,902' 2.416 5.968 Packer, Retrievable, Baker Mod. "FH" 2-78" y r 4 7,947' 2.313 3.500 Nipple,' X', 2.3131.Div/ PX Plug 09/08/17 io 5 10,253' 2.441 3.500 WLEG 6 10,430' 2.390 4.125 Packer, Baker Retrieve D (646-16-1400) 7 10,571' 1.995 2.375 Nipple, Baker'X"(Dropped drum hole) 8 10,579' 2441 3.700 WLEG (Dropped dot" ]role) 9 10,589' 1.995 3.875 Scoophead Guide Assembly 10 10,591' 1.995 3.937 Overshottvith grapple, (IA' of tubing sndlowed) 10,600' 1.995 2.375 Top of original tubing stub 11 10,598' - -. Packer, Retrievable, Baker Mad. "FH" 2-3/8" 12 10,603' - - Otis"S"nippl9 12 10,625' Seleryloint, Brown "CC", 2-3/8- 12 10,627' Otis XA sleeve 13 10,629' - - Packer, Retrievable, Baker Mod."FH"2-3/8" 14 10,635' - Otis "S" nipple 14 10,653' Safely Joint, Brown "CC", 2-3/8" I4 10,655' Otis XA sleeve IS 10,658' Packer, Retrievable, Baker Mod."PH"2-3/8" 16 10,663' Otis "S" nipple 16 10,685' Safety Joint, Brom "CC", 2-3/8" 16 10,687' Otis XA sleeve 17 106g9' Packer, Retrievable, Baker Mod. "FIV 2-3/8" 18 10,695' Otis "S" nipple 18 10,721' Safety Joint, Brown "CC', 2-3/8" 18 10,722' Otis XA sleeve 19 10,725' Packer, Retrievable, Baker Mod. PH, 2-38" 2D 10,731' Camco'D"nipple 21 10,733' - - Baker Shear Sub PERFORATION HISTORY DIL Inteval Aecum. Date Zone To Btna Amt s f Comments 726/96 G2 10375' 10418' 43' 6 2-1/8" ET Ode . 4/10/99 Hl 10,43Y 10,441' G' 4 2-1/8" HC 60 de 4/10/99 Hl 10,447' 10,455' 8' 4 2-1/8" HC 60 de 4/10/99 H2 1 468' 10,475' 7' 4 2.1/8" HC 60 de 4/10/99 IDA 10,497' 10.517, 20' 4 2-1/8" HC 60 de 4/10/99 H5 IMM 10,578' 54' 4 2.1/8" HC 60 d 9/11/95 HS(9 10(504' 10622' 18' 2 1-11/16" FJ Ode . UBS 10 608' 10 623' 15' 4 9/6(95 HS 10640' 10654' 14' 2 1-11/16" E1 Ode H8 10,640' 10,654' 14' 2 1-11/16" E1 0 deg. L118 10.665' 10.68U 15' 4 IJH10 10702' 10722' 20' 4 LH10 10734' 1 769' 35' 4 ETD =10,818', TD =10,843' MAX HOLE ANGLE= 2.5deg DRAWN BY: NM Updated by DMA 08-16-17 PROPOSED SCHEMATIC Swanson ell SCU River DilcorPAlnska,LLC Actual Completion 4/5/99 r A SING A Nn Ti I V IN!` nam I n Well was sidetracked from 8,190' in 7" 29# casing 2A 4 RKB = 15.30' V L p IS Punches -1,888- 1,892' �.� ; _ * & Parted " tubing tail at 10564' 5/6 (ELM) 7 10 Hole in 5" casing below 11 10,691' 12 13 14 15 16 2,094' G2 i0450 R� HI -H5 UHS H8 LH8 UH10 LH10 SIZE WT GRADE CONN ID TOP BTM. 20" - -155' Accum. 7" CIBP w/-155' of cement - TOC @. Surface 2A 30' 11-3/4" 47 J-55 - 11.000 Surface 1,990' 7" 29 N-80 BT 6.184 Surface 126' 7" 26 N-80 BT 6.276 126' 1,206' 7" 23 N-80 BT 6.366 1,206' 4,879' 7" 26 N-80 BT 6.276 4,879' 6,681' 7" 29 N-80 BT 6.184 6,681' 8,190' 5 18 N-80 Ons XA sleeve 4.151 7,985' 10,843' Tubing 12 10,635' 2 Otis "S" ni le 13 10,653' 2-7/8" 6.4 J-80 Butt (SC) 2.441 1 15.3' j 10,253' 2-3/8" 4.6 N-80 Butt 1.995 10,430' 10 453' ETD =10,818', TD =10,843' MAX HOLE ANGLE= 2.5deg DRAWN BY: NM Updated by DMA 11-22-19 De th ID OD Item 1 20' - - Tubing Hanger, 7'x2-7/8", Shaeffer P/N: 421758 Type HBPVP 2- 7/8" x 2-7/8" Hutt 2 -155' Accum. 7" CIBP w/-155' of cement - TOC @. Surface 2A `2,100' op 7" CHIP w/ -200' of cement - TOC @ -1,900' 3 -10370' Comments 5"CIBPW/-35'ofcemcnt-111-1-1- 035'-10430' G2 -10 430' 1 10,418' 5"CementRminerw/35'ofcement-1OC r -]0395' 5 10,571' 1.995 2.375 Ni le Baker "X" o ed down hole 6 10 579' 2.441 3.700 WLEG o ed down hole 7 10,589' 1.995 3.875 Scoo head Guide Assembly 10,455' 10,591' 1.995 1937 Overshot with Era p2le, 1.4' of hibing swallowed 4/10/1999 10600' 1.995 2.375 To ofori' al tubing stub 9 10,598' - Packer, Retrievable, Baker Mod."FPf'2-3/8" 10 10,603' 10,517' Otis -S-m2ple 11 10,625' 4/10/1999 Safe Joint, Brown "CC", 2-3/8" 12 10,627' Ons XA sleeve 12 10 629' - Packer, Retrievable, Baker Mod. "FH" 2-3/8" 12 10,635' 2 Otis "S" ni le 13 10,653' 10,608' Safe Joint, Hrown "CC", 2-3/8" 14 10,655' Otis XA sleeve 14 10,658' 10,654' Packer, Retrievable Baker 14 10,663' Otis"S"niDole 15 10 685' 14' Safe Joint Broxm "CC", 2-3/8" 16 10,687' LH8 Otis XA sleeve 16 10,689' 4 Packer Retrievable, Baker Mod. "FPP'2-3/8" 16 10 695' 10,702' Otis "S" nffiole 17 10,721' Saf 7oY- Brown 18 10.722' 10,769' Otis XA sleeve 18 10 725' Packer, Retrievable, Baker Mod. FH, MAI' 18 10,731' Cameo "D" ni le 19 10,733' Baker Shear Sub ETD =10,818', TD =10,843' MAX HOLE ANGLE= 2.5deg DRAWN BY: NM Updated by DMA 11-22-19 PERFORATION HISTORY IL ntema Accum. Date Zone op L51111t s f Comments 7/26/1996 G2 10,375' 1 10,418' 43' 6 2-1/8", EJ, 0 deg. 4/10/1999 Hl 10,435' 10,441' 6' 4 2-1/8" HC 60 deg 4/10/1999 Hl 10,447' 10,455' 8' 4 2-1/8" HC 60 deg 4/10/1999 H2 10,468' 10,475' T 4 2-1/8" HC 60 deg 4/10/1999 H3,4 10,497 10,517' 20' 4 2-1/8" HC 60 deg 4/10/1999 H5 10,524' 10,578'S4' 4 2-1/8" HC 60 deg 9/11/1995 H8/9 10,604' 10,622' 18' 2 1-11/16", EJ, 0 deg. UH8 10,608' 10,623' 15' 4 9/6/1995 H8 10,640' 10,654' 14' 2 1-11/16", EJ, 0 deg. H8 10,640' 10,654' 14' 2 1-11/16", EJ, 0 deg. LH8 10,665' 10,680' 15' 4 UH10 10,702' 10,722' 20' 4 LH10 10,734' 10,769' 35' 4 ETD =10,818', TD =10,843' MAX HOLE ANGLE= 2.5deg DRAWN BY: NM Updated by DMA 11-22-19 U a a F\ U I-� a i U m y N L O m c R L U U C N 2 w E O C U C d a) n E = o 3 a TE v` a) c a) a9 oa o � CL as R N c y R .- c a) N G N R � L c U (6 N L Y U w 0 d 0 R o� a R 3 c U co U dU O c CD E o U N O C a rn O C El w R Y R ❑ rad m Y ❑ U U � U c C7o00 Q Qa a > N S a CO .+ CL 5 Q d a Y R aR 'c CL Cl) C a L Z N Q} Z d rn c R L U 3 a d U 0 a w R ❑ d rn R IL U d El w R Y R ❑ Ln ei O YI IS O M 0 Z Y � 0 « Y J C U0 W Q Q 2 u LU O O > a` Q � > L J Z c O0 0 N Z tv a J H J m N t6 Q. L. 0 U Barrels of Oil per Month or Barrels of Water per Month 0 O O O O O O O O O O O O O O p O N N N N N N N 0 0 o S o o 0 0 0 0 0 o o!iell 110-seE) Jo gjuow jad („j�W„) seE);o;aaj algn:) puesnoyl m N N O N I I I 6 JE —� I m" � ° I � I _ • � I o — v ° Z i jE JE I I I 0 0 o S o o 0 0 0 0 0 o o!iell 110-seE) Jo gjuow jad („j�W„) seE);o;aaj algn:) puesnoyl m August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, \ 'l S G \ S cs Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com UG 2009 ni Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, I� Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Sep -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21 A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 23B-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 32B-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -91 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -Ono known damage no flow Possible shallow gas or gas storage 2011-2014 Mono od A-10 1670760 Apr -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life 1{ p} 1+ Lei ALILSK . 011L AND GS CONSERVATION COloHl~HIISSION June 22, 2009 k—t5 — a"5 SARAH PALIN, GOVERNOR t 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 SCWED Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertCa alaska., Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD _ Union Oil Company of California 179-033 _ Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 _ Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 _ Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 _ Trading Bay Unit K-06RD _ Union Oil Company of California 169-066 _ Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD _ Union Oil Company of California 178-004 Trading Bay Unit K-23 _ Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 _ MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 _ MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 _ Union Oil Company of California 161-033 _ Swanson Riv Unit 212-27 _ Union Oil Company of California 160-041 Swanson Riv Unit 234-15 _ Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 - *- STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union OII Company of California (Unocal) Development: X 168' RKB 153 GL feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, AK 99519 Stratigraphic: Service: Soldotna Creek Unit 4. Location of well at surface 8. Well number 1840' N, 595'W from SE 1/4, Sec. 5, T7N, R9W, SM SCU 13-4 At top of productive interval 9. Permit number/app, r. Qval number (10,435' MD) 571'E & 85'N of Surface Location N/A '~OJ~'- ~ At effective depth 10. APl number 50- 133-10115-01 At total depth 11. Field/Pool 643' E & 90' N of Surface Swanson River Field/Hemlock 12. Present well condition summary Total depth: measured 10,843' feet Plugs (measured) ]. 0,8 1 8 ~ true vertical 10,793' feet Effective depth: measured 10,818' feet Junk (measured) ]. 0,7 2 2 ' - 10,7 7 3 ' true vertical 10,768 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 20" 30' 30' Surface 1,990' 11-3/4" 14,405' 1,990' 1,990' Intermediate 10,310 7" 2,200 sx 10,310' 10,268' Production 2,858' 5" 865 sx 7,985'-10,843' 7,982'-10,793' Liner Perforation depth: measured 10,375-10,418'; 10,606'-10,626'; 10,640'-10,654'; 10,665'-10,680'; 10,702'-10,722'; 10,734'-10,769' true vertical 10,371-10,414'; 10,558'-10,576'; 10,589'-10,603';10,615'-10,630'; 10,672-10,672'; 10,684'-10,719' Tubing (size, grade, and measured depth) 2-7/8", 6.4~,L-80,Butt 10,253' 2-3/8", 4.6~,L-80Butt 10,430'-10,453', 2-3/8", 4.6#.L-80 Packers and SSSV (type and measured depth) Baker FH 7902', Baker retrieved @ Baker FH @ 10,589', Baker FH @ 10,631', Baker @ 10,658; Baker @ 10,691'; Baker FH @ 10, 7' 13. Stimulation or cement squeeze summary IntervNal/~ treated (measured)0 IGJNA L Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7 / 8 / 9 6 16 2 1 420 200 Subsequent to operation 8 / 3 / oj 6 39 2 1 400 200 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: ~ jo:.T/""' !'.' ! ~ ~' i~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge:i'~ '~- ~ L i V L L] Alaska 0ii & G~s Cons. Commission "" AH.~,Oh, ge Signed:"~." ~.,~. Title: Drilling Manager Date: 8/14/1996 Form '~ 0-404 Rev 06/15/88 SUBMIT IN DUPLICATE ATTACHMENT #1 WELL SCU 13-4 PERFORATION INTERVALS New Perforations: Bench G-2 10,375' - 10,418' MD 10,371' - 10,414' TVD ("(~ HPI~ ow RECE!VFD Alaska 0il & Gas Cons. Anchorage ATTACHMENT #1 WELL SCU 13-4 PERFORATION INTERVALS New Perforations: Bench G-2 10,375' - 10,418' MD 10,371' - 10,414' TVD STATE OF ALASKA ALASKA OiL. AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspenoed well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: x Other: 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 5. Type of well: Development: x Exploratory: Stratigraphic: Service: 6. Datum etcwation (DF or KB) 168' R KB feet 7. Unit or Property name Soldotna Creek Unit 4. Location of well at surface 1840' N, 595' W from SE 1/4, Sec. 5, TTN, R9W, SM At top of productive interval 571' E & 85' of Surface Location At effective de~h At total depth 643' E & 90' N of Surface 8. Well number SCU 13-4 9. Perm,~r,_.~ OO 10. APl numl:~r 50- 133-10115-01 11. Field/Pool Swanson River Field/Tyonek 12. Present well condition summary Total depth: measured 10843' true vertical 10793' feet Plugs (measured) 10818' feet Effective depth: measured 10818' true vertical 10768' feet Junk (measured) 10722'-10773' feet Casing Length Structural Conductor 30' Surface 1990' Intermediate 10310° Production 2858' Liner Perforation depth: Size Cemented Measured depth True vertical depth 20" 30' 30' 11-3/4" 1440' sx 1990' 1990' 7" 2200 sx 10310' 10268' 5" 865 sx 7985'-10843' 7982'-10793' measured 10606'-10626'; 10640'-10654'; 10665'_-10680'; 10702'-10722'; 10734'-10769' true vertical 10558'-10576'; 10589'-10603'; 10615'-10630'; 10672'-10692'; 10684'-10719' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 2-7/8', 6.4~, L-80, Butt 10,253' 2-3/8', 4.6~, L-80 Butt 10,430'-10,773' Baker FH 7902'; Baker retrieved @ Baker FH @ 10,589', Baker FH (~ 10,631 Baker @ 10,658', Baker FH @ 10,691' Baker FH @ 10,7251' 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: 15. Status of well classification as: 14. Estimated date for commencing operation July 25, 1996 16. If proposal well verbally approved: . Name of approver Date approved Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Date: ,~ ~',/ Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ? Location clearance Mechanical Integrity Test Subsequent form required 10- JApprova, No. ~)~_ /~ / Approved by order of the Commissioner 0ri !r;al Signed By David W. Johnston Commissioner Date Form 10-403 Rev 06/15/88 Approved Copy Returne~d, SUBMIT IN TRIPLICATE July 18, 1996 Swanson River Field, Well SCU 13-4 Perforating Procedure ,, Run gauge and tag fill Hold safety meeting. 3. Rig up electric line unit. . Pressure test lubricator as directed by Unocal witness for five minutes. Note: A pump-in sub with a valve is required. 5. Shut down all welding and radio transmissions. . Perforate intervals as instruct,ct by Unocal witness. (When gun is 500' below surface, welding and radio transmissions may resume.) . Pull out of hole. (When gun is 500' below surface, shut down all welding and radio transmissions.) 8. Repeat steps 5,6 and 7 as needed to perforate the following intervals: BENCH INTERVAL FEET G2 10,377-10,420 43 TOTAL: 43 -~--STATE OF ALASKA AI~ , OIL AND GAS CONSERVATION COMN ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing _ _ Alter casing__ Plugging Perforate X Repair well Pull tubing X Other X 2. Name of Operator Union Oil Company of California (Unocal) 3. Address P.O. Box 196247 Anchorage, AK 99519 4. Location of well at surface 1840' N, 595' Wfrom SE 1/4, Sec. 5, T7N, R9W, SM At top of productive interval (10,435' MD) 571' E & 85' N of Surface Location At effective depth At total depth (10,843') 643' E & 90' N of Surface 5. Type of Well: Development Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) 168' RKB 153 GL 7. Unit or Property name Soldotna Creek Unit feet 8. Well number SCU 13-4 9. Permit number/approval number 10. APl number 50-133-10115-01 11. Field/Pool Swanson River Field/Hemlock 12. Present Well condition summary Total depth: measured true vertical 10,843' feet Plugs (measured) 10,818' 10,793' feet Effective depth: measured 10,818' feet Junk (measured) 10,722'- 10,773' true vertical 10,768' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 30' 20" 30' 30' Surface 1990' 11-3/4" 14405' 1990' 1990' Intermediate 10,310' 7" 2200 sx 10,310' 10,268' Production 2858' 5" 865 sx 7985'- 10,843' 7982'- 10,793' Liner Perforation depth: measured 10606'-10626'; 10640'-10654'; 10665'-10680'; 10702'-10722'; 10734'-10769' true vertical 10558'- 10576'; 10589'- 10603'; 10615'- 10630'; 10672'- 10672'; 10684'- 10719' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80, Butt 10,253' 2-3/8", 4.6#, L-80 Butt 10,430'-10,453', 2-3/8", 4.6#. L-80 Packers and SSSV (type and measured depth) Baker FH 7902', Baker retrieved @ Baker FH @ 10,589', Baker FH @ 10,631', Baker @ 10,658', Baker FH @ 10,691', Baker FH @ 10, 7 ' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A 14. Treatment description including volumes used and final pressure N/A Alaska 0il & i~',~s Cor]s. Cor~]i.%ion Representative Daily Average Production or Injection Data Anchorage Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Shut-in 16 4 1 440 200 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations _x _ Oil x Gas Suspended _ _ 17., hereby certify that the fo~(~ing~,~ t~t,~nd~t to the best of my knowledge. Signed G. Russell Schmidt~~f..~~ Title Drilling Manager Form 10-404 Rev 06/15/88/" ~ Service Date 10/11/95 SUBMIT IN DUPLICATE SCU 13-4 DAY 1 - 3 (07/21/95 - 07/23/95) ACCEPT RIG AT 07/22/95 @ 06.00 HRS. CONTINUE WITH RIG MOVE TO 13-4. RIG UP ON 13-4. REPAIR AND INSTALL VACUUM DEGASSER. WORK ON EQUIPMENT AND WELDING PROJECTS. CHANGE OUT STANDPIPE HOSE. ACCEPT RIG AT 06.00 HRS 07/22/95. N/D TREE. N/U BOPS. PULL BPV AND INSTALL 2WAY CHECK VALVE. TEST BOPS. PULL 2 WAY CHECK VALVE. BACK OUT TIE DOWN BOLTS AND PREPARE TO L/D TUBING. M/U LANDING JOINT AND RIH. PULL TUBING HANGER TO ROTARY TABLE. CLOSE ANNULAR AND CIRCULATE BOTTOMS UP THRU' THE CHOKE. POOH, L/D 2 718" TUBING CHECKING FOR NORMS. POOH WITH ALL TUBING. (241 JTS TOTAL). PU OVERSHOT ASSEMBLY AND RIH. DAY 4 (07/24/95) RIH W/O SHOT Wi2-718" GRAPPLE TAG FISH @ 7659'. RUN BLIND BACK-OFF. PICKED UP 3K OF WT. CBU. POOH. RECOVERED GLM #6, 2-7~8" TBG, XO, 24 JTS OF 2-3~8" TBG. TOTAL - 1007'. BREAK FISH APART. RECOVERED - ROPE SOCKET, SINKER BAR, SPANG JARS, OIL JARS, KNUCKLE JT, O/SHOT & lB. WIRELINE FISH STUCK IN GLM #6. SCDL. DAY 5 (07/25/95) FINISH CHANGING RAMS TEST. RIH W/O/SHOT. TAG T.O.F. @ 8648' DPM. RU APRSo RIH W/CCL & G.R. TOF @ 8671'. CONT RIH TAG @ 10,620'. JAR OUT. PULL CCL STRING CHART @ 10,610'-10,000'. NO INDICATION OF PACKER FROM CCL. RD APRS. RU SCHLUMBERGER. DAY 6 (07126~95) Rib WITH 1-11/16" CHEMICAL CUTTER ON SCHLUMBERGER WIRELINE WITH CCL/GR. LOG FI 10,550'-8600'. CORRELATION PUTS APRS TAG @ 10,593'. POOH WITH WlRELINE. RU HALLIBURTON SLICKLINE. RIH W/1.75" lB. TAG @ 10,605'. INDICATES FILL. RIH WI 1.5" BAILER 3 TIMES. MADE 2' EACH BAILER RUN. RD HALLIBURTON. SPACE OUT TOOL JOINT. RU ARTIC RECOIL CTU. TEST DOPE. RIH WITH 1.8"3 BLADE BIT, 1- 11/16" MUD MOTOR ON 1-1/2" COILED TUBING. CLEAN OUT FILL 10,614'-10,709'. SET DOWN HARD @ 10,709' CTM. CBU DIRTY WATER FOR RETURNS. NO OIL OR GAS. POOH WITH CT. DISPLACE COIL WITH LEASE WATER. DAY 7 (07~27~95) RIH WITH 1.8"3 BLADE BIT, 1-11/16" MUD MOTOR ON 1-1/2" COILED TUBING. CLEAN OUT FILL 10,614'-10,709'. SET DOWN HARD @ 10,709' CTM. CBU DIRTY WATER FOR RETURNS. NO OIL OR GAS. POOH WITH CT. DISPLACE COIL WITH LEASE WATER. RD ARCTIC RECOIL CTU. PUMPED INTO TUBING WITH WELL CLOSED. . FORMATION TOOK FLUID @ 750 PSI. PRESSURED UP TO 1,000 PSI. BLEED DOWN TO 250 PSI IN 15 MIN. RU APRS AND RIH WITH 1- 7/16" CCL AND SINKER BAR TO 10,709'. LOG COLLARS F 10,702' TO 10,550'. POOH. RIH WITH 1-11/16" CHEMICAL CUTTER AND CUT TBG @ 10,618' = 10,589' DIL. POOH RD APRS. CBU OIL AND GAS @ RETURNS. OBSERVED WELL SLIGHT FLUID LOSS. POOH W/ O/SHOT AND 2-3~8" TBG. DAY 8-10 (07/28-7/30/95) CONTINUE POOH W/O-SHOt AND 2-3/8" TBG FISH. RECORED 61 JTS AND 24' CUT OFF. 1934' TOTAL RECOVERY. TOF @ 10,600'. PU BHA # 3 BAKER DRESSING MILL AND DUAL CASING SCRAPER. RIH W/DRESSING MILL AND DUAL CASING SCRAPER ASSEMBLY. RIH TO 2673'. ATTEMPTED TO BREAK CIRC. WITH NEG RESULTS. POOH W! PLUGGED STRING. PACKED OFF WITH SCALE ABOVE BIT SUB. RIH BREAKING CIRC. EVERY 10 STANDS. DRESSED TOP OF TUBING @ 10,592' (DPM). PUMPED FLO-VlS SWEEP. RETURNS WERE DIRTY WITH FINE SUSPENDED SOLIDS. NO SAND OR SOLIDS SETTLING. POOH W/DRESSING MILL. MU BAKER TIE- BACK OVERSHOT W/SCOOPHEAD GUIDE AND RIH. ENGAGE O/SHOT @ 10,592'. PU 15K OVERPULL AND RELEASED SCOOPHEAD. POOH/LD 3-1/2" DP. MU BAKER RETRIEVE-D PACKER AND TAILPIPE. RIH ON WlRELINE. SET PACKER @ 10,430'. 2-3/8" TBG TAIL @ 10,453. POOH AND RD SCHLUMBERGER WL. RU AND RIH W/2-7/8" GAS LIFT COMPLETION. ,, O Gas 0or~s. Oon~,~nissior~ Anchorage DAY 11 (0731/95) COMPLETED RIH W/2-7/8" GAS LIFT COMPLETION. MADE UP ClW 7" x 2- 7/8' 5M HANGER AND LANDED W/BAKER 7" FH PACKER @ 7905'o TBG TAIL @ 10,256'. TESTED HGR SEALS TO 3000 PSI. DISPLACED WELL WITH CORROSION INHIBITOR. RU SLICKLINE AND INSTALL XX-PLUG IN NIPPLE. SET PACKER. TEST ANNULUS AND TBG TO 2500 PSI. TEST TUBING TO 3000 PSI. RIH WITH SLICKLINE AND RETRIEVE XX PLUG. DAY 12 (08/01/95) PULLED X PLUG FROM NIPPLE AT 7950'. INSTALLED BPV. N/D BOP. INSTALLED XMAS TREE AND ATTEMPTED TO TEST SEALS. LEAKING PAST ANNULUS SEALS. PULLED BPV. AND RAN TWO WAY CHECK VALVE. PRESSURE TESTED TREE BODY TO 5000 PSI. PUMPED PLASTIC TO SEAL TUBING HANGER. SEALED OK TESTED TO 5000 PSI.OK. RELEASED RIG AT 1200 HRS. STARTED RIG MOVE TO WELL 43A-4.. ~ DAY 13 (8/29/95) MIRU ARCTIC RECOIL COILBED TUBING UNIT. TEST BOPE. OK. RIH WITH WASH NO77LE AND WASH THROUGH SCOOPHEAD GUIDE. MAKE SEVERAL PASSES THROUGH SCOOPHEAD. POOH. RD COILED TBG UNIT. DAY 14 (9/1/95) RU SCHLUMBERGER WLU. PU CCL AND GR AND RIH. MAKE TIE IN PASS WITH TOOLS AND POOH. RD WLU. DAY 15 (9/11/95) RU SCHLUMBERGER WLU. RIH WITH 1-11/16' ENERJET STRIP GUN. PERFORATE H-8 @ 10,606'-10,624'. RIH AND PERFORATE H-8 @ 10,640'-10,654'. WHILE POOH GUN BECAME STUCK IN TUBING. PULLED OUT OF ROPE SOCKET. POOH AND RD SCHLUMBERGER. RU SLICKLINE AND RETRIEVE GUN WITH SLICKLINE. Spud: 5 61 Completed: Las[ Workover: 7/51/95 SCU 15-4 Swanson River Field APl No.: 50-155-10115-01 Top o~emtock: 10,608 Ft. MD A,,.~., @ Hem ock: 1,5 Deq$. Hanger: Shafter 0.0- 30.0' 20" OD 94,00t/ft CSG 0.0-1990.0' 11 3/4" OD 40.50t/ft K-55 SURf 6S6 0.0- 255.0' 7" OD 29.00t/ft N-80 Buttress PROD CSG 253.0 - 1206.0' 7" OD 26.00~/ft N-80 Buttress i~ CSG 1206.0 - 4879.0' 7"0t) 25.OO~/ft N-80 Buttress PROD 6SG 4879.0 - 6681.0' 7" OD 26.00t/ft N-80 Bultr~ ~ C% 6681.0- 8471.0' 7" OD 29.00t/ft N-80 Buttress PI~ 6S6 8471.0- 10510.0' 7" OD 29.00t/ft N-80 Butlr~ ~D ~ 7985.0- 10845.0' 5" OD 18.00~/ft N-80 Buttress UNER L_ 15.5-10255.1' 2.875" OD 6.40t/ft L-80 ~G 10450.0- 10452.5' 2.375" OB 4.60t/ft L-80 TBG I0~9.6- 10595.2' 2.575" OD 4.60t/ft L-80 lBO I0600.0- 10706.0' 2.575" OD 4.60t/ft N-80 TBO 10721.0- 10773.5' 2.575"00 4.60t/ft N-80 TBG 7902.9 - 7910.2' RETRV. PACKER Bdker "FH" Pkr. 10430.0 - 10437.2' REIRV. PACKER Baker Retrieva "D" Pkr. 10818.0 - 10845.0' CBI~ RUG KB ELEV: 168' PBTD: 10818' TD: 10680' 10629.6- 10655.i' RE~RV. PACKER Baker FH Pkr 10598.0 - !0605.5' REtRV. PACKER Baker FH 10606.0-10624.0' PERFS H-8, 9/11/95, 2HPF, 18', 1 11/16" [,erjet Guns, 0 10608.0-]0623.0' PERI~ U-8, 4HPF, 15' 1~9.0 - 1065~.0' PERFS M-8, 4HPF, 14' 10640.0-10654.0' P[RFS H-8, 9/11/95, 2HPF, 14', 1 11/16" Erqej Guns, 0 10665.0- 10680.0' PERFS L-8, 4HPF, 15' 10702.0-10722.0' PERFS U-lO, 4HPF, 20' 101,]4.0 - 10769.0' P[RFS L-lO, 4HPF, ,~5' 10658.2 - 1066b.6' RE]RV. PACKER Baker FH Pkr 10689.7 - 10695.1' RL-IRV. P~KER Baker FH Pkr 10722.8 - 10775.5' FI~ 1979, Pkr Fish 10725.7 - 107~1.2' PACKER ~ker FH Pkr Oil WELL Perf'd 9/11/95 · %pud: ~ 61 Completed: Los[ Workover: 7/51/95 SCU 15-4 Swanson River Field APl No.: 50-155-10115-01 top oLH~emlock: 10,608 ft. MD i,.., @ Hemlock: 1,3 Decjs. " H~nger: Shoffer 0.0- 30.0' 20" OD 94.00t/fl CS(;; 0.0-t990.0' 11 3/4" OD 40.50t/fl K-55 SURF CSG 0.0 - 253.0' 7" OD 29.00t/ft N-80 Bullress PRO0 CSG 253.0 - 1206.0' 7" OD 26,~/ft FSO Bu[tress PRO0 CSG 1206.0 - 4879.0' 7" OD 23.00t/ft N-80 Buttress PROD Cgg / ~79.0 - 6681.0' 7" OD 26,~/fl N-80 Buttress PROI) 1989.0 - 1990.0' SHOE t5.3 - 16.3' HANGER Shaffer Tbg Hgt. W/EN 2247.8 - 2254.5' 4.651" OD 2.547" ID GASLIF[ VALVE t9, Camco KBMM GLM ' 3,50E5- }513.0' GASLIF-[ VALVE t8, C(]mco KBMM GLM 4257.0 - 4245.5' GASLIFT VALVE t7, C(]mco KBMM GLM 4841.5- 4848.0' GASLIFT VALVE t6, Camco KBMM GLM 5444,8 - ,5451,,Y GASLIF-I' VALVE t5, Camco MM GLM 6048.0- 6054.5' ~LIFT VALVE t4, C(]mco KBMM GLM 6650.2 - 6656.7' GASLIF[ VALVE t3, Cz]mca KBMM GLM 7255.0 - 7261.5' GASLIF[ VALVE t2, C(]mco KB~ GI.M 7859.0 - 7865.4' GASLIFI' VALVE tl, Cemco KBMM GUM 7902.9 - 7910.2' RETRV. PACKER Beker "FH" ~. ¢ [kq/: 168' B~ 10818' 'I1):' 10680' Oil WELL 9/11/9s Spud: $ 61 Compieted: Lost Workover: 7/51/95 SCU 15-4 Swanson River Field APl No.: 50-155-10115-01 Top o~emlock: 10,608 FL MD /,. , @ Hemlock: 15 Deqs. '" Hanger: $hd[er 10691.0- 10691.0' HOLE Hole In Csg Below 10691 10629,6 - 10655,1' REIRV, PACKER Boker FH Pkr 10635.1 - 10656.7' LANDING NIPPLE Otis S Postion t4 10636.7 - 10653.8' 3.062" OD B~T JOIN]' 10659.0-10653.0' PERFS M-8, 4HPF, 14' 10640.0-10654.0' PERFS H-8, 9/11/95, 2HPF, 14', 111/16" Ener~ Guns, 0 1065:3.8 - 10655.3' JOIN'[ Brown CC .Sefly Jt 10655.3 - 10658.2' SLEEVE Otis XA 10658.2 - 1066~.6' REIRV. PACKER Boker FH Pkr 1066,].6 - 10665.0' LANDING NIPPLE Otis S Position lOroO0.O- 10706.0' 2.375" OD 4.60t/fl N-80 TBG 10665.0- 10685.4' BLAST JOIN]' 10E5.0- 10680.0' P[RFS L-8, ~PF, 15' 10685.4 - 10686.8' JOINT Brown CC Safly 10686.8 - 10689.7' SLEEVE Otis XA 10689.7 - 10695.1' RETRY, PACKER Baker FH Pkr 10695.1 - 10696.6' LANDING NIPPLE Camco O Nipple W/CA plug 10696.6 - 10706.0' BLAST dOINl 10706.0 - 10706.0' PART End Of TJxj. 10702.0 - I0722.0' PERFS U-lO, 4HFT, 20' KB EEEV: 168' PBTD: 1~18' 'ID:. 106g)' Pert'd 9/11/95 ¢Spud: 5 61 Completed: Las[ Workover: 7/51/95 SCU 15-4 Swmnson River Held APl No.: 50-155-1011,5-01 Top of~mlock: 10,608 Ft. MD Ar,,,._ ~ Hemlock: 1.3 Degs. Hanger: Sheller WELL Perf'd 9/11/95 KB ELEV: 168' PBTD: 10818' TD: 10680' 104,30.0- 10452.,5' 2.375" OD 4.60t/ft L-80 IBC 104,30.0 - 10437.2' RETRV, PACKER Bc]ker Retrieve "D" Pkr. 10445.,.} - 10445.,~' 1.875" ID NIPPLE Bc]ker "X" 10452.5 - 10453.0' REENTRY JONT WL Entw Guide 10589.6-10593.2' 10589.1 -10589.6' 10591.$ -1059t8' 10595.1 -10598.0' 10598.0 -10605.5' 10603.5-10605.0' 10605.0 - 10625.3' 2.575" OD 4.60t/It L-80 IBG LOCAfOR JOINT Scoop Guide ON OFF Oversho[ SLEEVE Otis XA RETRV, PACKER Beker FH LANDING NIPPLE Otis S Position t5 3.062" OD BLAST JOINT ]0606.0-10624.0' PERFS H-8, 9/11/95, 2HPF, 18',111/16" E,er~e 10608.0 - 10623.0' PERFS U-8, 4HPF, 15' 10625.3 - 10626.7' JOINI Brown CC S(]fty dt 10626.7 - 10629.6' SLEEVE Otis XA 10629.6 - 10635.1' RETRV. PACKER B(]ker FH Pkr . ~Spud: 5 61 Competed: Last Workover: 7/51/95 10§18.0 - 1084-5.0' Cl]~ PLUG SCU Swanson River Field APl No.: 50-155-10115-01 Top of~mlock: 10,608 Fl. MD Ar,~ g Hemlock: 15 Deqs. Hanger: Shafter 10600,0 - 10706.0' 2.375" OD 4.60t/fl N-80 IBC 10706.0- ]0706.01 PART End Of 10702.0-10722.0' PERFS U-lO, 4HPF, 20' 10722.8 - 10773.3' FISH 1979, Pkr Fish 10721.4 - 10722.8' JOINT Bro~,n CC Safty JL 10722.8 - 10725.7' SIFE~ Otis XA, Top Of Junk Fish 10725.7 - 107~1.2' PACKER Baker FH 107,]1.2 - 10732.1' LANDING NIPPLE Camco D 10732.1 - 10772.7' BLAST JOINT 10721.0-10773.3' 2.375" OD 4,60t/fl N-80 TBG lO7,,u,.O - 10769.0' PERFS L-lO, 4Hff, 3,,5' · _ . _ 10772.7 - 10773.5' SH~SUB Baker Shearsub Bottom Of Junk KB BEV: 168' PI]~ 10818' 11): 10680' Oil WELL Perf'd 9/11/95 Unocal North Oil & Gas Divisior Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region March 31, 1994 Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SRU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 AJaska (Jil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma ~,Dennis L....~~,r~ske Petroleum Engineer Attachment cc: L.R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned ~ 5A5 SCU 13-4 u~--i~ SRU 212-10 b~-q~SCU 34-4 L~t-o5 SRU 23-15 ~-~z, SCU 341-8 ~.-~o SRU 41A-15 L~;~--'/ SRU 34-28 ~z--5~ SRU 14-22 ~-~ SRU 43-28 ~o-t~SRU 23-22 ~o--t~r> SRU 32-33WD ~{-~%SRU 212-27 (.~--t~ SCU 243-8 ~o-~ SRU 331-27 (~7_- Z SRU 21-33WD~O~zLSRU 12-15 bo-~&SCU 14-34 (~o-#q SRU 23-27 SRU 14A-33 GT_-~ SCU 21-8' ~l~b SRU 14-15 B\~E SCU 13-9 (~0-~t SRU 34-15 Io~-u~ff SCU 34-9' SRU 43A- 15 iSq--~DSCU 23B-3' %5-bb SRU 432-15 -eff-~q SCU 43A-4' -~__o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECeIVeD APR - 1 1994 Alaska Oil & Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3' · SRU 33-5: Returned to full time production after workover. Returned to full time production due commencement of Blowdown in field. Returned to full time production after workover, tO RECEIVED aPR - 1 1994 oil & Gas Cons. Commission Anchorage Form 3160- 5 (JUNE 1990) UNITE ~TES DEPARTME~ OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reenlT¥ to a different resavoir. Use 'APPUCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [] Well [] Well r-] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- - 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Exptre~: March 31, 1993 5. Lea~e De~ignation and SePal No. 6. ff Indian, Allottee or Tdbe Name · . · o. 7. ff Unit or CA, Agreement De~ignatlon Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exl~oratoff Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent [] Subsequent Repo~ [] Final Abandonment [~ Abandonment I-1 Recompletion r-] Plugging Back [] Casing Repair ["] Altedng Casing ~ Other Temporarily Abandon r-] Change of Plans ['-] New Construction ['-] Non-Routine Fracturing [-'1 Water Shut-Off r"l Conversion to InJeclJon r-] Dispose Water (Note: Flepo~ reaurm of multiple oonmldel~ on W~ ff wea is ~rmlly drilled, giro ~ubsurface Iocatioas and m~a~urod and true vortical ~ for all ma. ko~ and ~ono As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit .~ J' * SCU 23B-3 SCU 243-8 ~ I SCU 13-4 SCU 341-8 :: '5 i * SCU 21A-4 SCU 13-9 " :31 SCU 34-4 * SCU 34-9 ~ 5' 1 * SCU 43A-4 SCU 14-34 / -o/~.* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit SRU 212-10 .,.'"SRU 14-22 $ / 8RU 43-28 SRU ~F 14-15 ~/-~/,~RU 12-15 ~ I SRU 14A-33 ~/ SRU 23-15 ~ SRU 23-22<;uSpSRU 24-33 ~u~I='SRU 34-15 ~1 SRU 23-27 · SRU 32-33WD %1. SRU 41A-15}r~SRU 212-27 SRU 21-33WD 5~5~ SRU 43A-15G~ SRU 331-27 ~ u~0 SRU 432-15 ~t SRU 34-28 con(~dons of approval, if any: RECEIVED - 1 1994 Tftle 18 U.S.C. Section 1001. makes it a crime fo~ any pemon knowingly and ~l~ffy ~ mako ~o any do~arf~ or agency of ~ United ~a/~f~o~ns. C0mmissi0 r~ fraudulert slatements or representations as to any matter wfthin ils jurbdiction. *See Instruction on Reverse Side Al]ch0rag8 Alaska Region Unocal North AmeHo.~._ ~...\~ Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 C-OMM ' ~ Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ~OMM I-'~ COMM t_i RES ENG ~ ~N-G UNOCAL "" SR ENG _.t 1 ;~ ~, ~'~ ~. ,4. ~¢~v ;~. ENG--AssT-'I~j '~NG ASST I~ ~ r,? (',.-~.-k'~ ~ cc. March 24, 1993 ~ ~/; -~E~OL ASSTI '~-E O L ASSTI ~¥AT TECH[ i~TAm FILE Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue Cf 13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon ('FA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIVED MAR 2 § 199; Alaska Oil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company REEEIVED MAR 2,5 Alaska OJJ & Gas Cons. Commissio~ Anchorage Form 3160-5 (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS FORM APPROVED Budget Bureau No. 100.4-0135 Expires: March31,1993 5. Lease Designation and Serial No. 6. If Indian, Allonec or Tribe Name Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals SUBMIT IN TRIPLICATE I. Tyl~ of Well lOll Gas Well E~] [~ Other Well 2 Name of Operator Union Oil Company of California (dba Unocal) 3 Address and Telephone No. P. O. Box 196247, Anchorage, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit 17 wells Soldotna Creek Unit 14 wells (907) 276-7600 TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA. Agrcemcnl Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or ExpIoralory Area Swanson River Field Il. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA [-~ Notice of linen! [~] Subsequent Report --]Final Abandonment Notice --}Abandonment {~ Recompletion [~ Plugging Back [~ Casing Repair -"]Altering Casing [~] C~her Temporarily Abandon [~ Change of Plans E~New Construction [~ Non-Routine Fracturing [~ Water Shut-Off F-] Conversion to lnjecuon --]Dispose Water (Note: Reporl results of muluple cornpleuon on Well Compleuon or Rccompleuon Report and t.og fo~m ~ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give p~rtinent dates, including estimated date of starting any proposed work. If well is dircctionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)' As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' ,,..¢ ¢ - Swanson River Unit Swanson River Unit / j 0~ SCU 2i-3~ SCU 21-8" SRU 2~2-10 ¢ SRU SCU 23B-3,~~,~ SCU 243-8~ SRU 14-15' SRU ~SCU. 13-4 SCU 341-8'- SRU 23-15f SRU SCU 21A-4 SCU 13-9 × SRU 34-15 SRU SCU 34-4 ~ SCU 24A-9¢ SRU 41A-15~ SRU SCU 43A-4= SCU 34-9'¢ SRU 43A-15 SRU SCU 33-5¢' SCU 14-34L,' SRU 432-15 SRU SRU 14-22¢ SRU SRU * High GOR wells that may be produced intermittently. //.,Yg_.~,4x,, ')~/2V¢ rm~ Petrol eum Engineer ~is s~ for F~ or S~o~) 23-22 23-27 ¢ 212-27~ 331-27 34-28 ~ 43-28 ~ 14A-3f RECEIVED 24-33¢ 32-33WD ~ ~A~ ~ 5 Alaska 0il & Gas Cons. Anchorage Date Approved by Tide l)~te Conditions of approval, if ~my: :-itle lg U.S.C. Section 1001, makes it a crime for ~ny person knowingly ~nd willfully to umke to ~y department or agency of the United States ~y f~se, fictitiotts or fraudulent statements *See Instruction on Ret, er~ SId~ Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: TOtal 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Shut-in Wells until the Field Blowdown Shallow Gas Potential Rate Potential P & A(~) and 'Hemlock Only' P & A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13'4 SRU 212-10 SCU 14-34 SCU 21A-4 SRU 23-15 SRU 23-27 SCU 34-4 SRU 41A-15 SRU 14A-33 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SRU 341-8 SRU 212-27 SRU 34-28 SRU 331-27 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9' SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33121 1 1 Wells 7 Wells 3 Wells 5 Wells 5 Wells (~) Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 12~ Scheduled 'Hemlock Only' P & A in March-April, 1993. · High GOR wells that may be produced intermittently. ~laska Uil & Gas Cous. C0~nmissi0n t~.;choraga Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27', 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: · SCU 21-3: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned StatUs · SRU 21-22: · SRU 12A-4: · SRU 211-15 Returned to production after flowline repair. Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. REC£[V D MAR 2 5 ~995 Alaska 0ii & Gas O0ns. Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 'R%s 'ENG ASST ! i STAT TECH! I Mr. J. A. Dy gas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office Box 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: lo rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC ~ 1 199t Alaska Oil & Gas Cons. ~0mmi~i0n Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye~'s TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J. C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment cc.. L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation R£C£1VED Alaska Oil & raas gons. Anchorage Form 31~,0-5 (November 1983) (Formerly 9.331) UNITED STATES .u...zT m Te.'~C~- (Otl~er laatreetioaa o& ~ D~ARTMENT OF THE INTERIOR ,.~-~ BUREAU OF LAND MANAGEMENT , ,, SUNDRY NOTICES AND REPORTS ON ~LLS not ~ tbll ~orJ for p~l~ to drUI or to d~n or Dlug back to I ~e~nt r~rvolt. U~ "~P~CATION ~R PERMIT~" for such D~L) 2. NAtal Of OPIIATOI ARCO Alaska~ Inc. 3, &DDI~ Of OPH&TOI P.O.Box 100360 Anchorage, AK 99510 ~oc&?~ofe of ~'tr.~, (Relx)rt location clearly end In accordance wtth any Scare requlrementL' See also space 17 b~low.) At su~ace Swanson River Unit Soldotna Creek Unit 14. PIIMI~ NO. 19 wells 13 wells i15. aLAbAmaNs (Show whether oP. WT. Form approved. Budget Bureau No. 1004-0135 Expires August 31. 1985 dali OHIQ.'/&TIOI~ &ID IB~LIL IO. ~. E IIOl&l, ALL,O'TTII OI VIlli NAME '7. UilIT AGIIIMINT NlilI Soldotna Creek/Swanson Rv 8. ILlif OI dali I&tdl WILL IO. 10. IIILO AND POOr.,, 0l WILDCAT 11. mm:** I~.. L, If** OB iLL LiD 12. CO, lit! O! I)illllj 18. fTATB Kenai Alaska Ckec~c. Approtx, ate Box To Indicate Nature oF Notice, Report, or ~ Data NO'riOS Of INTBNTION TO: SHOOT OR ACIDI:~I ABANDONe (Other) Temporary Abandon (N~: RelMrt results of multlUSO eomldeUou Completion or R~completion RelWrt end L~ font) Db'SCRIBe I'ROPOSED aa C'OMPLEYEO OPaIATION~ (Clearly state all i~rtine,t details, and give 12erttuent dst?a, _ln.elud.lnf. eatt.m.&ted .date of.itlrtltf any proposed work. If 'eMI' is dirK~Jouofl7 driUed, give a~ntmLr'(a~-~ Joc&~uns and mall.red and true vertical depum Eof ILl marseru mens m ~hio w~rk.) · As decribed in the attached memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit SCL/ 23B-3 SCU 21-8 * SRU 212-10 SRU SCU 12A-4 SCU 341-8 SRU 14-15 SRU SCU I3-4 SCU 13-9 SRU 23-15 SRU SCL/21A-4 SCU 24A-9 SRU 34-15 SRU SCU 34-4 SCL/ 34-9 SRU 211-15 SRU SCU 43A-4 SCU 14-34 SRU 41A-15 SRU SCU 33-5 SRU 43A-~5 SRU SRU 432-15 SRU SRU 14-22 SRU SRU * -High GaR wells that may be produced intermittently. 21-22 23-22 23-27 212-27 331-27 34-28 43-28 14A-33 RECEIVEE 32-33WD Al~ ,._ '"-s~a 0i/& Gas Cons. Commi~ 18. ! hereby ce~'Ztry-ClZtt-~be fo, refolaf la trap and correct aZC;H'ED .-" / ~"'"-"'--"~ TZTLZ Actinq Reqional Enqineero~.' APPROVED BY CONDITIONS OIP APPROVAL, ~J* ~: TITLE DA~I~ Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for _ Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A SCU 12A-4 SRU 212-10 SCU 13-4 SRU 211-15 SCU 21A-4 SRU 23-15 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 ~- SRU 32-33WD ~, =~ c-~ o c-~ c~ ~ SCU 14-34 SRU 23-27 SRU 14A-33 r'r'l 11 Wells 9 Well~ 3 Wells Shut-in Wells until the Field Blowdown I Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For:. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) DEC ,3 1 99! Alaska Oil & ~as Cons. Commissi Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate fOr shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. I ECEIVFD DEC 5 1 1991 Alaska 0il & Gas Cons. uommissio~, Anchoraoe ARCO Alaska, Inc. Post Office Box ,d0360 Anchorage. Aiaska 995 !.0-0360 Te!ephope 907 275 ~ 2 !5 Engineering December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have planned upcoming work that will enable their return to production is attached. If you have any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment CC: C. V. Chatterton, Chairman AOGCC A. R. Kukla, Marathon Oil Company $.W. Ohnimus, UNOCAL Corporation RECEIVED Dec2 1989 Alaska 0il & lias Cons, Commissioe Anchor,ape < ~.~ -~-~ Form approved. Budget Bureau No. 1004--0135 ~o,= 3~6o-s U, ED STATES ~Nov~b~ 1983) (~ t~~ on ~ ~. ~ o~mn~w ~ ~L nO. (~o=.fl~ ~-33~) D~ARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON ~L~ (~ not m thM form for pm~la to d~l or to d~n or plat ~ek m a ~mnt ~otr. Um "~p~CA~ON ~R PERM,--" ~or su~ ~o I dotna~Creek~ o,~ ~ ~s ~ ~nsa wanson ~ver nits ARCO Alaska, Inc. Post Off fce Box 100360 Anchroage, AK ~951~ 4. ~c&T~o~ or wz~ (Re~rt location clearly and tn accordance wlt~ any S~ ~ul~e~eu~· 10. ffll~ ~D ~, OI WI~IT 8~ also 8pa~ 17 ~low.) At .u~a~ ,Swmnsnn R ~ ~/er F i m I d Soldotna Creek Unit - 11 wel Is Swanson River Unit - 20 wel Is 16. Check Ao~om, ate Box To Indicate Nature o[ Notice, Report, or Odmr Data IqO~ICB OS' INTBNTION TO: PUACTURB TRBA..~ xfULTIPt. I COMPt.RTR SHOOT OS AClDr~B AB&NOONO REPAIR waLL CHANGE PLiN8 (Other) Temporar i I y abandon , SHYINg OR AC~iNO ABAN~MMB~° Other) (No'ti: Repm't results o~ multlsde e~m~etlou on Well Completion or Reeompletlon Reimrt iud I,~ form.) lT. u~;sc~tar- X'ROt'OSCD OR COMPLETED OPERATIOND (Clearly state all ~rtlnent details, and ;lye ~rtinent ht~ lnelud~ ~flmat~ date of I~ ~1 ~ropoecd wor~ If wall b di~tio~y driH~ five a~~ ~uno and meaeur~ and t~e vertl~ dep~ for ~ markers ~d Mas ~ru- sent to ~il wor~) · As described in the attached memo, ARCO Alaska, Inc. requests that the following wells have a temporarily abandoned status: Soldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A-4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 31A-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVED Alaska Oil & Gas Cons. Commissi( Anchorage 18. I hereby certify tJmt the fore,olaf ts t. rae and correct SICS'mD ~ ~'~/~'~""'"'"~ TX?t,E Cook I n let Eng i nerr ing Managn~n (Thio si)nee for Federal or State omee uae) APPROVED BT CONDITIONS OF APPROVAL, I~ ANY: TITLI~ DAT~ *SEE Indn~'tiom on Reveae Side Title tS U.S.C. Section lOOt, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation Rate Potential 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 Wells being evaluated for P&A/Future Utility 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 Wells SI for Inefficient Production 21A-4 33-5 34-10 43-28 24-33 Wells SI until Blowdown 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temporarily Abandoned Status: SCU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU 32-33 W D' Well is temporarily abandoned due to annulus communication problems. Removed from Temnorarilv Abandoned Status: -- _ SCU 243-8,: This shallow sands gas well has been returned production. SCU 13-9: A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10.: This shallow sands gas well has been returned to production. SRU 23-15' This gas-lifted well has been returned to production. SRU 21-34' A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED , 1989 Alaska Oil & fias Cons. Gommissior~ Anchorage For' Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned AOCbOrage For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet / New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 were identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in - inefficient production 4. Shut in - save for blowdown Wells in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, H. F. Blacker Regional Engineer Cook Inlet/New Ventures HFB: JWR: ch: 0006 Attachment cc: C.V. Chatterton, Chairman ' Alaska Oil & Gas Conservation Commission · 6as ?,o~s.G°m~ss'~°~ TABLE Wells under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i ts. 212-10 21-15 31-15 34-15 432-15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 Form 3160--5 (November 1983) (Formerly 9--331) bNITED STATES s~sm? (Other lUltncflong on DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to I different reservoir. Uo~ "APPLICATION FOR PERMIT--" for such propod~a.) or[` ,~ GAn ~ W a~[`[` wE[`L OTHS~[ NAMR OF OPERA'fOB ARCO Alaska, Inc. Soldotn~ 3. ADDIEIa Or OPIIATOI P. O. Box 100360 Anchora~m. AK 9qS]D-D~6D t0CATiOS or WELt. (Report location clearly and 1'~ a~cordance with any State requirements.· Se~ also space 17 below.) At 8qrface Soldotna Creek Unit - 15 Swanson River Unit - 22 wells 14. PgaMIT NO. jIS. EI&YATIONS (Show whether DP, BT, Git, etc.) Form approved. Budget Bureau No. 1004--0135 Expires August 31, 1985 5. LIAII DBIIONATION AND IIlIAL MO. 0. Ir I#DI&M, AL[`Cr~--~IB 01 TIIII Ni¥1t Creek'/Swanson River Unit 8. fAl.# OR [,illt NAMl 0. WILL MO. 10. fflBLD AND POOL) OI WILDCAT Swanson R±ver Yield 11. BB~.. ~. l.. if** OR ILK. Lam mUItVl! on Amm& 12. coow~ si I*A]ltllBI 18. ITATB KenaiJ Alaska 10. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NO'I'ICB Or INTBNTION TO: FRACTURE TRIgAT MULTIPLE COMPI,RTE BI:lOOT nit ACIDIZB ABANDON® REPAIR WELFo CHANGE PLAN~ (Other) Temporarily abandon WATER SHUT,)ri* ~-~ fll'AIBll~O WI~ ~ 8H~TINO OR ACIDlZlNO ABAN~NMBMT° (Other) (NoTs: Report results of multiple completion on Well Completion or Recompletion Report and Ld)g form.) 17. o~sc8;ur, VnOPOSEO oR CO~,IPLETED OPERATION~ (Clearly state all pertlne,t details, and give pertinent dates, Including ~timated date of starting any proposed work. If well is di~ectionaJly drilled, five subsu~ace locations and measured and ~rue vertical depths for nil markers and sones perti- nent to this work.) * As described in the attached memo, ARCO Alaska, Inc. requests the status of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON RIVER UNIT SCU 13-3 SCU243-8 SRU212-10 SCU12A-4 SCU 13-9 SRU 34-10 SCU 13-4 SCU12A-IO SRU 14-15 SCU323-4 SCU343-33 SRU 21-15 SCU43A-4 SCU 14-34 SRU 31-15 SCU 24-5 SCU 14-3 SRU 432-15 SCU 33-5 SCU23B-3 SRU 34-15 SCU341-8 SCU 34-4 SRU41A-15 SCU21A-4 SRU43A-15 SRU312-22 SRU 21-22 SRU 23-22 SRU 22-23WD SRU212-27 SRU314-27 SRU 23-27 SRU331-27 SRU 34-28 SRU14A-33 SRU 24-33 SRU 12-34 SRU 21-34 18. I hereby certl~.at the for.~g~Lng l~v"~'ue and correct · ~_j~' TITLE Pegiona! Engineer (This space for Federal or State ofllee use) APPROVED B! CONDITION8 OF APPEOVAI,, L~ Alq~: TITLE DATa *See IndT~fions on Revere Side T~tI~, 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the .. 'STATE OF ALASKA ~- ALASK~ .~tL AND GAS CONSERVATION C,~ AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A. ]]NC. 75-15 3. Address 8. APl Number P. 0. Box 7-839 Anchorage, AK 99510 5~t33-10115-01 OTHER [] 4. Location of Well 1840' North and 595' West of Southeast corner of Sec. 5; T7N, R9W SB&M 5. Elevation in feet (indicate KB, DF, etc.) 168' KB 12. 6. Lease Designation and Serial No. A-028996 9. Unit or Lease Name Soldotna Creek 10. Well Number SCU 13-4 11. Field and Pool Swanson River Field Hemlock Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). . Commenced work 12'01 p.m.~ Filled well with 74 pcf mud. Install Class III B.O.P.E. and tested okay to 5000 psi. . Pulled and fished out tubing to 10276', leaving 47' of 2-3/8" tubing, packer and jewelry in well from 10726 to 10773'. 4. Ran mul ti spaced and compensated neutron logs. 5. Displaced mud wi th KCL water. . Reperforated 5", liner with four 1/2" jet holes per foot 10608-10626', 10369- 10653' and 10665-106'80' e Ran tubing and packers. Installed x-mas tree and tested of under 5000 psi. e Completed work 7'00 p.m. 10-21-79 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed R.W. Magee /~?~¢~-~'~Title Area Engineer / The space below for Commission use Conditions of Approval, if any: Approved by. COMMISSIONER By Order of the Commission Date ........................ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTF~ ,~ ~ SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen .~ Use "APPLICATION FOR PERMIT--" for such propo~a:lS.)~.~ ~ O~L ~ GAS r-] WELLI~2J WELL 2. NAME OF OPERATOR CHEVRON U.S.A. 3. ADDRESS OF OPERATOR P. O. BOX 7-839 4. LOCATION OF WELL OTHER Alaska 0il & G:::s J,0ns, ~glnmi~ Anchorage Atsurface 1840' North and 595' West of Southeast Corner of Sec. 5; T 7N; R9W SB & M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 168' KB or 15.3' G.L. 14. CheCk Appropriate Box To Indicate Nature of Notice, Re , 5. APl NUMERICAL CODE / . I ] I:N(~) 50-133-10115-01· 6. LEASE DESIGNATION AND SERI AL A-028996 7. IF INDIAN, ALLOTTEE OR TRIB~ :~UNIT, FARMOR LEASE NAME I ~r~ SOLDOTNA CREEK 9, WELL NO. SCU ]3-4 CONFEr: Eli lO, FIELD AND POOL, OR WlLDCAF '~"~ .... SWANSON RIVER - HEMLOCK 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4; T 7N; R9W; SB & M 12. PERMIT NO. ?$-/5 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. · · Pull tubing and packers. Acid circulation wasNperforations. Note: Reperforate if necessary. Run tubing and packers. 16. I hereby certify th~t.~he foregoing is true and correct (This space for State~e use)/~/ /) CONDITIONS'~F APPROVAL, IF~N~: ' AREA ENGINEER DATE 7/31/79 See Instructions On Reverse Side o,,=... TRANSMITTAL A~,~ ACKNOWLEDGEMENT OF RECEIPT OF ,,.£ERIAL - (ALASKA) TO:__ .~.~r. T.R. State of DEPT.:_ Div-[s~on of Oil & Gas 3001 Porcupine D:ivn PLACE:_ Anchorage A .... ~,~a 99504 FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. I I COMPANY WELL HISTORY LOG 2" 5" I00 200 ' 0 .~ ,,.., ./ d ~- ~ .... { ..7'"..~ ' I ...... /,',, ....... , ) RECEIVED BY REMARKS ON OTHER SIDE, THIS SHIZET STIMULATION PROGRAM SCU 13-4 SWANSON RIVER FIELD 1. Prepare surface location and move in a drilling rig. 2. Kill well with 70-72 lb/ft3 low fluid loss drilling mud. NOTES' (a) Stati'c pressure at 10,668 V.D. on 7-05-77 was 4934 PSI'. (b) Programmed mud weight exceeds the formation pressure by 300 PSI. (c) Kill fluid mustlbe completely soluable in Mud Acid. 3. Install a Class III, 5000 PSI B.O.P. See attached B.O.P.E. diagram. 4. Pull tubing and packers. NOTES' (a) Clean and inspect tubing and jewelry. Replace as necessary. (b) Redress packers. 5. Clean out well to top of cement plug at 10,818'. 6. Run Baker 5", 18# tandem casing scrapers from liner top at 7983' to top of cement plug at 10,818'. 7. Circulate and condition well fluid. 8. Rig-up Dresser Atlas and run a Multispaced Neutron Log and a Com- pensated Neutron Log from the top of the cement plug at 10,818' to top of liner at 7983'. (2835') NOTE' These logs should show free gas behind the casing. 9. Change over drilling fluid to KCL water for completion. 10. Run a Baker circulation wash tool for 5" 18# casing with double opposed "GWD" cups spaced two (2) feet apart. Wash tool to be equipped with a circulating port above the top cups and an acid control valve above the circulating port. NOTE' A spare wash tool and additional cups are to be availabe at the well site. l l. Wash the following perforations from bottom'up with 50 gallons of acid per foot using Dowell acid and equipment: Interval Feet Sand 10,769-10,734 35 Lower lO 10,722-10,702 20 Upper lO 10,680-10,665 15 Lower 8 10,653-10,639 14 Middle 8 10,626-10,608 18 Upper 8 TOTAL 102 NOTES: (a) Wash intervals may be modified based on neutron logs. Gas sands will not be washed. (b) All surface lines will be steel. (c) Test surface lines to 5000 PSI. (d) Obtain blank tests at the following locations: 10,775', 10,729', 10,690', 10,650', 10,630', and 10,600'. (e) Mix 5,500 gallons of 12-3 HC[-HF acid with 10% solvent, 1% surfactant and 50#/1000 gallons iron suquestering agent. Acid to he inhibited to 1850 for 48 hours. (f) Keep an accurate wash record. Note intervals that will not wash. (g) Do not exceed 3000 PSI surface pressure while washing. (h) Keep annulus full while washing. 12. Pull wash tool to 10,500'. Open tool by-pass and displace work string and liner wi'th 150 BBLS of lease waste water. Pull wash tool. 13. Check for fill and clean out to top of cement plug at 10,818', if necessary.. NOTE: A perforation program will be provided by Engineering to perforate and acid wash. the intervals that would not wash in Step 11. 14. Rerun tubing and packers. NOTE: (a) Tubing detail to be as close as possible to to prior tubing detail. (b) Before packers are set, run Dresser Atlas Neutron Collar Log to determine exact location of packers. 15. Return well to production with all sleeves open. NOTE: Engineering will provide a wire line program to test each interval at a later date. R. W. MAG EE 7/17/79 KB to TUBING HANGER (ORIGINAL) %5. O0 ' 4879' 1990' .... h125.83~I ~519.9o, TUBING IiANGER W/ COSASCO 3 PU? JTS. 2%'? 6.5// N-80 ( · JTS. 2~'" 6.5# N-80 8rd TUBING CAMCO MM MANDREL 57 JTS. 2~" 6,5# N-SO 8rd TUBING CAMCO ~R~ ~qDm:L 44 JTS. 2~" 6.5# N-80 8rd TUBING C~CO t~,~ ~N])~L . .50 ! 20,20' 2260~40, 13.00' 13.00' 138i. 07 ' 13,00' 6681' -------- 66.1.6.86 ,' 7502.64'~ '7863.27" ?os~~ - 79o8.o5'- -8 ! 90' WINDOW 8131' 10,595.t2' - ~o6o8; - - 10,625,30.- _ IO~,26'- 10,629.58' ' :o,635.:3' .,o.~sa'_ -~g~ / 10680' ~o7~-- lO, 7'22.83' ~ .... 10,725.71' 35 JTS. 2%" 6.5# N-80 8rd TUBING CAHCO MM MANDREL 28 JTS. 2~" 6.5# N-80 8rd TUBING CAMCO MM ~LA~:D~EL ll JTS. 2%" 6.5# N-80 8rd TUBING 1' JT, 2%" 6.5~ N-80 8rd TUBING x-ovm 86.JTS; 2~,, 6.~ff N-80 8rd TUBING , OTIS "~" SLEEVE. ~%'" x 5" ~o;;' ~ o~, :;2~ER Fii FACKER ,~u~.~u,~ RELEASE OTiS "S" ~IPOl'~' Position #5 i BLAST JT. 3,062" OD BRO~:~ "CC" SAFETY JT. OTIS "XA" SLEEVE 2%" x 5" 18# B~ER FH PACKER ROTATIONS., P~;LEASE OTIS "S" NIPPLE~ Posltion #4 3 BLAST JTS, 3.062" OD (I.'5Z',5.60', B1%OkrN "CC" SAFETY OTIS "~" SLEE'~ 2%" x 5" 18# BAKER FH PACKER ROTATIONAl, RELEASE OTIS "S" NIFPLE, Fositlon #3 1 3LAST 3T. 3.062" OD . BROt.~q' "CC" 'SZ~,'ETY 3T. OTIS "~?' SLEEVE ' ' ' 2%" x 5" 18# B~iER FH PAC~jR ROTATIONAL RELEASE OTIS "S" NIFPLE, Position #2 2 BLAST YrS. 3.062" OD (20,32' BRO['IN "CC" SAFETY 3T, OTiS "XA" SLEEVE 2~8" x 5" 18# B:'~tER FH PACF~P. 4.~O[k~TAOt':AL leShaKe" 2 BLAST JTS. 3,062" ()D[~O. 3~ 2[" B~jR SHEAR SUB F F 1 utu · TOP OF PLUG 10,818' T.D. 10,81/3' 1083.96' 13o00' 872.78' 13.00~ 347 ~63' 13.00: 31.75' 1.09' 2685. 1.52' 20.32' 1, th2, 2.86' i.52' '17~20' . l.hS' 2>.~ ~.'f, 1. h.~' 20.31' 1,41i 2.58' 5.h2' 1.52' 24.52' 1.42' 2.86' 0.62' . $ Ipl¥ IZtI~JI'~c ~'~['1I'~~'~'x~' ~-'x.,,- , ,, ~'~ 4--' CASING a TUEqtNG DETAIL SECTION 5 T. 7N.,R. 9W AUG. 2~, 1975 4879' 6681' KB to TUBING ttANGER (ORIGINAL) 1990' TUBING ttANGER W/ COSASCO 3 .PUP JT$. 2~" 6.5# N-80 ( 6.o$~ e.o5~8.,o'1 JTS. 2~" 6.5// N-80 8rd TUBING 2316~70' '" : ' " CAMCO MN MANDREL 57 JTS. 2~" 6.5~'/ N-80 8rd TUBING 4125.83-! CAMCO MM ~4iNDREL ' 44. JTS. 2~" 6.5~ N-80 8rd TUBING 35 JTS. 2~" 6.5f/ N-80 8rd TUBING 6616, 86 ' C~CO ~{ M~D~L 750~.6~,~ 7863.27 798'~' - 790~.05'- WINDOW 28 JTS. 2~" 6.5f~ N-80 8rd TUBING ?-- CAMCO MM MANDREL 1~ JTS. 2Ds'' 6.5f~ N-80 8rd TUBING ~-- C~MCO MM MANDREL ~-~ 2{" x 2%" X-OVER 86,JTS~ 2~" 6.5# N-80 8rd TUBING 8ast__j...__' 595.12 ' .. ' ' ' OTIS "XA" SLEEVE . ~00,598.00' ~ 2~" x 5" 18~~ Bf~R ~i FACKER EGTATiGNAL KELEASE '10608'-!0,603.40~-~-_ OTIS "S" -NIPPLE , Position ~'75 ' :. 1 BLAST JT. 3.062" OD · ~ROWN CC oA~ETY. J~ ~ IO626'-- 10 ~626f 72' ~ j .... zo,6~.5~'~ ozzs "~" s~w - ~ '~ ~O6~9' -- 10,~q,~ ' ~ 3 BLAST JTS. 3.062" 2% x ~ ].8~ BAKER FH PACKER ROIATIONAL ~LEASE OTIS "S" NIPPLE, ~osition ~3 i ,osso' ~o,~sS.S6' ~ z ~Z,tST ~n~. S.062" oD ,' .' ~ ---- [o,68~.~5' ~ o~xs "xA" szzEw - 2~ x 5 18# sAKmR FH PACKER ROTATIONAL RELEAoE ~ ~-~ 10,695.07' ~" , ....... OTIS "S" NIPPLE, Position /t2 ' = .~.10,721.hl, ~- 2 BLAST JTS. 3.062" OD _ ~o722__.i0,722.83, ~ sRO~:~ "CC" SAFETX 10 72~,71'~ OTIS "XA" SLEEVE ~- 10,~1.1~' 2~" x 5" 18# BAKER 'FH PACKER ROTATIONAL ~L~~ .$5.00 ' I .50 ~ 20.20' 2280~40 , 13.00' ~796,13' 13.00' .1381.07' ].3.00' 1083.95 ' 13.00' 872.78' 13.00' 347.63 ' 13.00' 31.78 ' 1,'09' 2685.98' 2j 68 ' 1.52' 20.32' 1,h2' 2.86' .~.~5' 1.52' 17~20, 1,45' 2~b7~ 5.40' 20.31' 1.41~ 2.88' 5.42' 1.52' 24.82' 1.42' ;2.68' 5 · 40.62' TOP OF PLUO 10,818' SUBMIT IN DUPLXCATE* STATE OF ALASKA ',se .... th,,rm. M ructl(~ns (-,11 i'cvel ye side OILAND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* IR, TYPE OF x,V]~LL: OiI'[~ GAg ~,V ELL WELL ~ DRY Other b. TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLCG ~ WEI,I, OVER EN BACK nESVR. Other 2. NAME OF OPERATOR Standard 0il Company of California, 1801 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1840' North and 595' West of Southeast Corner of Sec. 5; T-7N. R-9W, SB&M At top prod. interval reported below 98' North and 562' East of Surface location. At total depth 103' North and 623' East of surface location. ORIGINAt 5. API NU1VI~[LICAL CODE 50-133-10115-01 6, LEASE D~SIGNAT1ON AND SERIAL NO. A-028996 7. IF INDIA-N, ALLOTTEE O1~, TJ%IBE NAl%LE 8. UNiT,FAIL~I OR L~.kSE NAME Soldotna Creek 9. W~L NO. SCU I ~- ~ 10. FIELD ~D POOL. Oi{ ~VILDC&T Swanson River - Hemlock !11. SEC., T., R., M., (BOTTOM HOLE O~E~I'IVE) Sec.~ ; T-7N, R-9W SB&M 12. PE~IIT NO. 75-15 ._~/2S/75 ........ t 6/12/75 ~ 18/10/75 ..... !168 ms _ ..~ , ,, 1d[-TOT~k~-'"D~TPI, NLD & TVD~9. PLUG, B~e~ ....... ~m--~&"~. ~ ~ULTmLE CO~L., 21. INTERVaI,S i,RILI,ED BY . ' I ('ABI,E TOt3IM [ ~ [HO~V ~Y* ROTARY TOOLS 10843' ~ 10792' g~ [ 10828' MD 10778 ~D 0-10843 ' [ 0 ~, PRODUCING IN~VAL(S), OF ~IS CO~P~TIO~--TOP, BOSOM, NAM~ (MD AND ~)- ,23.' WAS D!RECTIONAL ~ SUII VEY MADE Top 10608' ~ 10561tT~ Hemlock ~ yes Bottom 10769' ~ 10720' T~ I 24. TYPE EL&TCTRIC AND OTHER LOGS RUN D1L, Sonic, FDC, CN.L, .C_ement bond ,, 25. CASING RECORD (Report all strings set in well) C/kSI2qG SIZE \VEIGHT, LB, FT. 20" 11 3/4" i 47 7" 23,26r~29 26. .LINER I~EC OIqD I'-GEADE ,~ ~-5s N-80 1:'-110 5" 7985 10843' 865 28. ~EI%FOR,ATJ_OINrS OPW-~q TO P'~ODUCTIOi%I (intcrva], size and number) 10608 - 10623' 10639 - 10653' 10665 - 10680' 10702 - 10722' 10734 - 10769' 30. Four.i/2" jet holes 'per foot i ii PRO DUCT! ON DEPTH SE~.- (MD) f HOLE SiZE!-~0! . CEMLNTiN G IiECOILD 1990' , [ 15 1/2~ 1440 S~g ~m~n~ 10310' ]9 7/8h ] 2200 srs cemeng Window milled 8{ 90[- 8231' for redrill hole 27. ~'UBiNG RECOH3) l SCiiE~ (i~D} SIZE DEPTI-I SEI' (MD ~ See attached , 1 29. ACID, S~:GT, FiiA27[ CH~, C~,IENT SQUJ2!;'ZiL ETC. . /CVlOU NT PULLED , None DATE FIRST PI%ODUCTION I P~ODUCT1ON MEIHOD (Flowiing, !.'a5 lif[, primping--size and type of pump, IV, 1,3Ll., [>'I'ATUS ( Pt'oducing or 8/11/75 ~ [ Flowing I Producin~ ~ 4soj ! ~ 1026 I 2166 ,,1. r~SPOSlTION Or ~aS (80Id, u~ed ~or Jue~, vented, etc.) t TES'I' WI'FNESSED BY Injected back ~nto fkeld 82. f, 18T O~ ATTaCHMeNTS Tubing detail, D1L, Sonic, FDC, CNL cement bond log 33. I hereby certify that . the foregoing and atta~!nfor~ion Is complete and correct as de%ermined fkc, m all-available rv~ilrdl~:' SIGNED R. M. McKinley ITLE lraa Encinoor i [~'t DA'ri' .... , .... ,~....-,.. ~. ., .~-~:/~, . *(See Instructions ~nd Sp~c~s for Additional U~t~ on Revers~ Side) ~ PA£:iiEI~ SET INSTRUCTIONS Genersl: This form is designed for submitting a complete arid correct well completion report end log or'~ all types of lanJs end leases in Alaska. Item: 16: Indicate which elevation is used 8s reference (where mot otherwise shown) for depth n~e,~sure- ments given in c, ther spaces on this form and in amy attach;:~er~ts. Items 20, ~nd 22:: If this well is completed for separ~tc pr<;duction fror~q n~or'e th(-~n one ~nterval zone (multiple completion), so state in item 20, and ir:~ iteq~ 22 show tho prC:tLJCrr~9 intcrv~l, or ~nter'vals, top(s), bottom(s) and name (s) (if any) for only the interv,~! ref)orted ir~ iter'r~ ,gq() Suhr-nit ~ sept]rate report (page) on this form, adectu~]tely identified, for each edditJc)r~l ir~Ic~v¢]l to be seperately produce~, show- ing the ackJitional data pertinent to such interval. Ite, m26: "Sacks Cement": Attached supplement8l records for this well shoul:l show the details of any mul- tiple stage cementir~g ~nd the location of the cementing tool. Item 28: Submit e separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FOI:LMATION TES'I"S iN('L,L]I)IN(; INTEI{VAL TF, STED. PI~E.'%SU¥{E DATA A_N'D J:C~COV['.RIF~~, OF (_)IL GAS. 35 G EX)L, OG I C MARKER WATEH AND MUD _ ,.. NAME . ... , 36. CO~E DATA. Aq'I'ACII ~RIEF D~IPI~ONS OF LITIIOLOGY, POROSITY. FRACWRF~. APP~NT DIPS . AND I)'ETEC~'EI) ~IH)%VS OF OIL. (ihs Oil XVAT~I . GR AT £A D DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STAhrDARD OJL COMPANY COMPANY SCU 45A-5 & SCU ~$B-SJCORRF, CTED ISF, D ~NAME RTVER LOCATION AL57_5-D5 JOB NUMBER SINGLE SHOT 40-22-?5 TYPE SURVEY DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written ~equest. All surveys are kept in a locked file and are held in strictest confidence. Additional c:o,~)ies of your s~Jrvey report can be made from the origin}al by any blue!.~ial Fr'~r"i':'LEl"I¢?~t RFP©RT STA,NDAP. D ()IL CO, WELL A3-A-5 OCTOBER 22,1975 ;']vr'~!'~SCOPIC S~J~VE',' (EAST~",AN) K B ELEV. 168. !Ar~C,F'HT~AL, :~4ETHOD OF CO~,~PL,ITATIONS C(Y"1f':~t)TF;D FOR ORE;AT LAND D~RECT~ONAL DR;LL]NG [NE. BY F. M. LINDSEY AND / ,, RECORD OF SURVEY ALL CALCULATIONS PERFORM. ED BY ! B N ELECTRONIC CONPUTER T R U £ DP. I FT VERTICAL ANGLE DEP'TH D M SUB DRIFT SEA Di~EC DEG, ] O0 0 15 99.99 ?'0<) 0 0 199.99 i:,] ~? r~ 0 30 299,,99 9 (', O 0 0 4 a 9.99 ,~ ~r) Fl 15 599.99 ~'~,'~0 0 30 700,g8 ]090 0 45 999.96 .0,00 -],68,00 S O E -68.00 S 21 E 31.99 $ 0 131.~9 S 9 W 231.99 $ ! E 331.99 $ 0 431.99 S 32 531.99 S 0 F 531,98 N 46 W 7B1.97 N 32 W ~31.96 N 29 W 1100 0 45 1099.95 931.95 N 25 W !200 0 30 110Q.95 1031.95 N ~8 W ]'3nO 0 30 1299.94 1131.94 N 4 W ]./~Or~ 0 ~0 1399.9~ 1231.94 N 5 E tSF)() 0 A5 1~+99.93 1331.93 N 8 E '~",:~ l, ]5 ]599.9~ 1451,91 N 3 W ,," '~" I 0 1609.P9 1531.g9 N 1 W ~;' ~r) 1 15 ].899.8h. ]731.fia N 3 E ;.7;"r'~~O 45 1999.P, 9 1831.83 N 12 W ~2"'(). .,,.~, 30 2199.8~.. 203].fl3 N 6~ E TOTAL COORDINATES 0.00 S 0.00 W 0,40 S 0,15 E 0o~0 $ 0,15 E 1,26 S 0,01 E 2.],~ S 0,0~ E 2,14' S 0,03 E 2.51. S 0.19 W 2.5! $ 0,19 W ].90 5 0.82 W 0.42 S 1,7~ W 0.71 N 2.38 W 1.90 N 2.93 W 2.59 N 3,47 W 3.46 N 3,5~ W 4.33 N 3,45 W 5.62 N ~.27 W 7.80 N 3.39 W 9.55 N 3e42 W 11.70 N 3,76 W 13,fl8 N 3,64 W 15.16 N 3.92 W 15,84 N 3,~7 W 16.22 N 2.58 W CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/1OOFT 0.00 S 0 0 0 W 0.43 S 20 59 59 E 0,43 S 20 59 59 E 1.26 S 0 5~ 46 E 2.14 S 0 56 18 E 2.14 S 0 56 18 E 2,51 S 4 27 53 W 2,51 S 4 27 53 W 2.07 $ 23 22 50 W le79 S 76 19 20 W 2,48 N 7~ 12 22 W 3.50 N 57 1 8 W 4,33 N 53 15 27 W 0,000 . .. 0.250 0.250 0,500 0.087 0,500 0.250 ...... 0.250 0,500 0,529 0.254 0.052 0.286 4,94 N 45 34 47 W. .0,292. 5,54 N 38 35 45 W 0,078 6,51 N 30 12 X W 0,252 8.51N 23 28 22 W 0,533 10.14 N 19 42 11W 0e253 12.29 N 17 48 54 W 0,295 14.35 N 15.66 N ~4 29 ~4 W 0,560 16,19 N ~2 0 40 W 0,~84 ~6,4~ N 9 SECTXON DISTANCE O, O0 0,17 0,17 0.06 0.10 0,10 -0.10 -0.I0 -0,75 -1.73 -2,40 -3.5o -3,65 -3.60 -3,47 -3,75 -4,16 '4e13 -3.92 -~.15 ) ) ) RE¢OR9 OF SURVEY AL.L C^LCULATIONS DERFOR~,ED BY I B ;.4 ELECTRONIC.COMPUTER SUB DR ! FT SEA D ! REC DEG. 2,3r)0 0 45 2299.82 2131.82 S 80 E Jz~!'lO 0 45 2399.81 2231.8! S 8~ E 75,?~C) 0 45 2~99,80 2991.BO S 82 E 2600 ] ]5 2599.78 24~1,78 N 75 E 2700 1 45 2699.7~ 25~1,7~ N 67 E 2'f'~O0 ]. ~5 2799,68 2631~68 N 63 [ 2°90 1 45 2899~64 2731.64 'N 61 E 3q'<')g 2 0 2999,58 28~1,58 N 67 E 310~) 2 0 3099,52 29~1,52 N 75 E 3200 2 ]5 3199.44 3031,~4 N 76 E ~'.73,:.'~0 ? 15 3299,36 31.3t,36 N 76 E "~z~qO 1 45 3399,31 3231,31 N 79 E ~fi<'~<) P 0 3409,25 3331,25 N 70 E ~F~O(~ 1 45 3599,21 ~31.21 N 86 E 3700 2 0 3699,I5 3531,15 N 81 E 3~70 2 15 3799,07 3631,07 N 87 E ~OQ(~ 2 3Q 3898.g7 37~0,97 N 83 E z~O90 2 30 3908,88 3~30,88 N 77 E z;.100 2 15 ~09B,SO 39DO,80 N 76 E 4,20n 2 ]5 ~198,72 4030,72 N 82 E ~409 2 15 &39Be57 4230,57 N ~3 ~ aSC~O 2 15 4498,A9 ~330,49 h,188 ~ 4700 2 30 ~698,32 4530,32 N 89 E ~.nO,'~ 2 30 a798.23 4630,23 S 82 E ",~')0 2 45 4998.02 4830.02 $ 81 E 51nn 2 45 5097.90 4929.90 S 79 E' TOTAL COORDINATES 15,99 N 1,29 W 15,86 N 0,00 E 15,68 N 1.30 E 16.24 N 3,40 E 17.43 N 6.21 E 18.82 N 8e99 20.30 N 11.61E 21,66 N 14.82 22.57 N 1~19 E 23.~2 N 22.00 24.~7 N 25.81 E 25.05 N 28.8~ E 26,24 N 9Z.09 E 26.46 N 35,13 E 27.00 N 38,58 E 27.21 N 42.50 E 27.74 N 46e83 E 28,72 N 51.08 E 29.67 N 54.89 E 30,22 N 58.78 E 30,a2 N 62.70 E 30,90 N 66,59 E 31.0~ N 70,52 E 30.70 N 7~,43 E 30,77 N 78.79 E 30.16 N 83,11 E 29.48 N 87,42 E 28.73 N 92.16 E 27.82 N 96.87 CLOSURES DISTANCE ANGLE D H S . DOG LEG SEVER I TY DEGIIOOFT SECTION DISTANCE 16,05 N 15,86 N 0 O 53 E _. 0,052 15.73 N 4 4~4 25 E 0.026 16.59 N 11 50 46 E ........... 0,6~2 18.51 N 19 37 34 E 20.8~ N 25 24 7 E 0,122 -0.5~ 0.75 2.83 5.60 8,27 23,39.N 29 /+5 38 E ].0,061 10,89 26,25 N 34 22 28 E 28,99 N 38 52 11 E 32.20 N 43 5 21 E 35,56 N 46 31 38 E 38,18 N 48 59 18 E 41e45 N 50 43 5 E 43.98 N 53 0 59 E 47.09 N 55 0 32 E 0,318 0.279 0.253 ...... 0,000 0,511 0,386 0.578 0.299 50.~6 N 97 22 15 E ............... 0.334 54.43 N 59 21 26 E .... 0,300 58.60 N 60 38 59 E 0,262 62,40 N 61 36.14 E .......... 0.253 66.09 N 62 47 25 E .0.235 69.69 N 6~ 6 50 E __ 0,196 73.41N 65. 6 20 E ......... 0.157 77.05 N 66 14 29 £ 0.196 80.51N 67 ~5 8 5 0.275 84,59 N 68_39 52 E .... 0,352 88.41 N 70 2 58 E 0,392 92.26 N 71 21 38 E 0.044 96.53 N 72 ~0 54 E .. 0.250 · 100,78 N 73 58 33 E 0,096 14.05 17.39 21.16 27,91 31,15 34,19 37,61 kl,52 50.0~ 53.82 57.69 61.60 65-47 69,39 73.31 77.67 82.00 86.33 91.10 95.B~ RECORD OF SURVEY ALL CALCULATIONS PERFORatED 8Y ! B N ELECTRONIC COMPUTER TRUE Cr::A.::qo DP!Fi' VERTICAL >FP l't.l A,HGLE ,DEPTH D .N SUB DR ! FT SEA DIRE¢ DEG, TOTAL COORDINATES DOG LEG C_.L 0 $ U R E S SEVERITY SECTION DISTANCE .......... ANGLE . _.DEG/IOOFT ...... DISTANCE . 5j!nO 2 15 5197,82 5029,82 $ 85 E q',.~O<) 2 90 5297,7B 5129,73 $ 81 E 5,'~<')0 2 15 5397,65 5229.65 .5 79 E 5500 2 15 5~97,57 5329.57 S 78 E 560q 1 45 5597.53 5429.53 S 82 E 570<) ~ 0 5697,47 5529,47 S 85 E ~qO 1 45 5797,42 5629.42 S 79 E 5<:~00 2 O 5897,36 5729,36 $ 78 E 6000 ] 30 5997,32 5829,32 5 79 E 6~0(? ]. 30 6097,29 5929,29 S 88 E 6.:?~0 }.. 15 6197.27 6029,27 N 75 E 6'.~nO ] 30 6297,2~ 6129.23 N 71 E 6:~eO : 90 6397,20 6229,20 H 69 E 6500 ! 90 6497,].6 6~29,~6 N 66 E 66~')t) 1 ~5 659'?,1.2 6429,12 N ~ E ~'7~'~r: 1 45 6697.07 6529.07 S 85 E (.~c~ ? 0 6797.0] 6629.01 5 8~ E '7'~'r) 2 0 6996,87 6828.~7 S 54 E :1:)0 I A5 7096,~2 6928,82 S ~0 E 7200 ~ 45 7196.78 7028.78 S ~ E 7~qO 1 45 7296,73 7128,73 S ~9 E 7400 1 a5 7396,68 7228.68 S 47 E 75~)0 1 15 7496,66 7328,66 S 67 E 760~ ] 15 7596,6a 7~28.6~ S 3~ E 7Z('~) 1 ]5 7696.61 7528.61 S 50 W '~'~"'"~ 1. 15 7796.59 7628.59 S 47 E 7~<)0 1 0 7896.57 772~.57 S 70 E ~'~'~ "~ ! 0 7~q&.~6 7828e56 5 67 E 27.47 N 100.78 26,79 N 105,08 26,04 N 108.94 25.23 N 112,78 24.80 N 115.80 24.50 N 119.28 23,91 N 122,28 23,]9 N 125.69 22.69 N 128.26 22,60 N 130.88 23.16 N 132.98 2~,01 N 135,q6 24,95 N 137.90 26,02 N 140.29 26,3~+ N 1~3,33 26,07 N 1~6,37 25.71 N 1~9.8/~ 24.56 N 153.60 22.51 N 156.42 20.54 N 158.76 18,71 N 161,20 16,70 N 163,50 1A.62 N 165,7/+ 13,13 N 167,33 11.34 N 168,59 9,94 N 166,91 8.45 N 168,51 7,86 N 170,15 7,18 N 171,76 10~,46 N 74 ~4 5~ E 108,~5 N 75 41 42 E 112,01 N 76 33 12 E 115,57 N 77 23 23 E 118,~3 N 77 54 35 E 121,77 N 78 23 32 E 0,56~ 0,~00 0,263 0,039 0,519 0,268 124.59 N 78 55 55 E ...... 0,318 127,81N 79 32 42 E 130,25 N 79 57 58 E 132,81 N.80 12 6 E 13~,99 N 80 7 4 E 137.57 N 79 56 42 E 140,14 N 79 44 30 E 142.69 N 79 29 31E 1~5,73 N 79 35 11E 0,252 0,501 0,235 0,~76 0,268 0,052 0,079 0,565 148,68 N 79 53 57 E 0.~35 152.03 N 80 15 50 E 0,252 155,55 N 80 54 52 E 0,~77 158,03 N 81 ~8 38 E .... 0,7~3 160,09 N 82 37 31E _ 0,282 162,28 N 83 22 45 E ..0,092 164.36. N 8~ 9 56 E ....... 0.122 .,. 166,38 N 84 57.26 E .... 0.061 167,85 N.85 30 40 E 168,97 N.86 8 5~ E 167,21N 86"35 21E 168,72 N 87' 7 33 E 170,33 N 87 21 15 E 171,91 N 87 36 21 E 0,500 ...... 0~261. 1,689 1,872 0,511 0,052 99.7 ) 104,0~ 107.96 111,83 114,87 118,35 121.37 12~,80 127,39 130,01 132,09 134,5~ 136.95 139.30 1~2,32 1~5.37 152,6. 155,5~ 157,95 160,45 162,82 165,13 166,77 168,09 166.47 168.11 169.77 171,~0 RECORD OF SURVEY ALL CALCULATIONS PERFOR~ZED BY i B H ELECTRONIC COMPUTER RUE T I C A L SUB DRIFT SEA DIREC F~:;',"~'~], O 8196.52 8028.52 $ 6~ E i:~3<)0 ! 0 ~296,50 8128.50 S 69 E ~/~5)f~ 0 45 8~96,50 8228.50 S 55 E a!'~C~O 0 45 B496,~9 B~28.~9 S 4~ E ~6~FI 0 ~0 8596,a8 8428.48 $ 49 E 8700 () 45 8696.48 8528.48 5 59 E ~800 1 0 8796.46 8628e46 S 61E 8900 1 0 8896,44 8728,~4 $ 58 E !~000 0 45 890&,44 8828.44 S 66 ~ 9)00 1 0 9096.42 8928,4.2 S 63 E 92f~n t 90 9196.B9 9028,39 S 67 E ~'%~'!<) l ~'5 9296,34 9128,B~ $ 76 E 9690 2 0 9396.28 9228,28 S 78 E 950{? 7 1,5 9496,20 0328.20 $ 75 E 9600 ? 30 9596.11 P428,11 S 76 E gTOF) 2 15 0696.0~ 9528,0~ $ 78 E 98©0 2 0 9795.97 9627,97 $ 80 E 9~0 2 O 9845.04 ~677e94 $ 79 E TOTAL COORDINATES 6,25 N 1.7~,73 5,49~ N 175,~0 4,86 N 176,9~ 4.11N 178,00_E 3,19 N 178,9~ 2,$1N 179,59 1,94 N 150e71 1,09 N 182,2~ 0,17 N 183,72 0.~5 S 18~,91 1.15 $ 1.86,47 2.17 $ 188.88 2,91 $ 191,8~ 3,63 $ 195,25 4,65 $ 199,05 5.70 S 203,28 6,52 S 207.12 7.1~ S 210.55 7.~$ S 212.27 CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT 17~,85 N 87 56 12 E 0,253 175,B9 N 88 12 17 E 0,251 177,00 N 88 25 25 E 0,087 178,05 N 88 ~0 29 E .. 0,327 178.96 N 88 58 60 E 0,131 179,61N 89 9 51E 0.254 180,72 N 89 22 59 E _.O,272 182.2~ N 89 39 15 E 183.72 N 89 56 4~ E 186,91S 89 53 20 E 186.~7 S 89 38 67 E 188,89 S 89 20 27 E I91,86 S 89 7 ~9 E 195.29 $ 88 55 58 5 199.10 S 88 39 ~8 5 203,36 S 88 23 29 ~ 207,22 $ 88 11 4~ 5 210,68 S 88 ~ 37 5 212,~0 S 8? 59 ~0 ~ O,252 0,O52 0,278 0.254 0.507 0,357 0,258 0,27~ 0,253 0,263 0,261 0,070 SECTION DISTANCE 173,. ) 175,00 176.65 177.75 178,71 179.39 180.53 182e09 18~.60 18~,81 186.~9 188,8~ 191,82 195,26 199,09 203.~5 207,7 210.6~ 212,~0 HOLE CLOSURE 212,~0 FEET AT S 87 59 10 E ii'!TCRPOLATED TRUE V~'RTIC^L DE,'PTHS, COORDINATES AND CLOSURES FOR GIVEN DEPiHS TRIJE ~!EASURFD VFRT!CAL TO?AL COORDINATES C L 0 S _U R E DE P'i' H DF P TH D ! STANCE ANGLE D M $ SUB SEA r)EPTH AND OTf,,!F'.t:~ PATA EVEN 100 ) FEET OF SUB SEA DEPTH, 368 468 668 768 1168 1568 1768 1~68 2 r~68 2~68 2568 ~ 76 n 2~68 2q68 3169 ~269 9469 TRUE VERTICAL SUB · DEPTH SEA 268, 100. 368~ 200, 488. 300, 568. 400, 668, 500, 768. 600. 86~. 700. 968 * 800 · ]06e · 900, 1],6~. 1000, 126~, 1.100. 1368. 1200, 1468, 1~00. 1568. 1400, 1668, 1768, 1600. 1868, 1700, 1969. 1800, 2068, 1900, 2168, 2000. 2268, 2100, 236~. 2200, 2468. 2300. 2568, 2400, 2668. 2500. 2768. 2600. 2868. 2700, 2968, 2800, 3068, 2900, 9168. 3000, 3268. 3100, 3368. 3200, 3468. 330.0. 3568, 3aOO. 366~, 3500, · MD-TVD O IFF'ERENC~ VERT I CAL CORRECTION 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 TOTAL COORDINATE& 0.99 S 0.06 E 1,86 S 0,03 E ................... 2.14.5 ............. 0,03.,,..E 2.39 S 0.12 W 2,51 $ 0,19 W 2,09 S 0,62 W 0,89 S 1.45 W 0,35 N 2.18 W 1,52 N 2,75 W 2,37 N 3,30 W 3,18 N 3,51W 4,05 N 3.48 W 5,21N 3.33 W 7,11N 3,35 W 8,99 N ~ _.3.41 W 11,02 N 3*65 W 13, 19 N 3.68 W 1~,75 N 3.83 W 15.62 N 3,5~ W 16.10 N 2.83 W !$,07 N. 1,70 W 15,90 N 0,41 W 15,73 N 0,88.E 16.06 N 2,73 E 17.05 N 5,~2 E 18,38 N 8,07 E 19,83 N. 10.76 E 21,23 N 13,80 E 22.28 N 17,13 E 23.22 N 20,80 E 24.17 N 2~.61 E 24,87 N 27,87 E 25,87 N 31,06 E 26.39 N 3~.18 E 26,83 N 37,50 E ) DEPTH AND OTi, tE,P DATA FOR EVER"' EVEN 100 FEET OF SUB SEA DEPTH. r,,~.f: A 5. LJRED VFRTICAL SUB MD-TVD VERTICAL PFF'Tt~ DFPTH SEA DIF'FEREN "'E CORRECTION TOTAL COORDINATE5 3869 3868,, 3700. 4,(')6 9 4068, 3900. a!6~ 4168, 4000, aB69 4~68, 4200, 4.469 4468, 4300, 4670 4668, 4~00, 4770 t+768. 4600, 4870 4~68.~ 4700e 5070 5068, 4900, 5170 516~, 5000, 5270 5268. 5100. ~370 53~,8. 5200. 5a70 5468, 5300. 5~70 556~, 5400. 567 1 5668. 5500. 577 ! 57r,~. 5600, 5n?l 586~( . 5700, 5971 59~-8. 5800, (,07% 6or,~. 5900. 6271 6268, 6100. 6371 6368. 6200, C, 47 1 6468. 6300. F, 57] 65A8, 6400. (.671 6668. 6500. 677 I 6768 . 6600, 597] 6868, (~971 6968, 6800, 70? 1 7068. 6900, 7!71 7168. 7000, 27,1/* N /+l.28 E 27,57 N ~,49 E 28./+2 N . . /+9,76 E 29,38 N 53,71 E 30.05 N 57,58 E 30.36 N 61.49 E 30.75 N 65,40 E 31.00 N 69.32 E 30.80 N 73.26 E 30.75 N 77,47 30.35 N 81.80 E 29,69 N 86.12 E 28.96 N 90.73 E 28.09 N 95.46 E 27,58 N 99.61 E 26.99 N 103.80 E 26.26 N 107.79 E 25,/+7 N 111.64 E 24,93 N 11/+,91 E 24,59 N 118.25 E 2~.09 N 121'39 E 23.40 N 124.69 E 22.84 N 127,51 E 22.62 N '130.11 E 23.00 N 132,37 E 23.77 N 134.73 E 24,68 N 137.19 E 25.71 N 139e60 E 26.24 N 142./+5 E 26,15 N 145,~9 E 2~e81 N ~48.84 E 24,89 N 152.51 23,10 N 155,61 E 21,11N 158,09 E 19,24 N 160,50 E '~F/:~:~ t~F]h· PFPTH A~,]D OTHEP,, [AtA') ~' FOR EVER'~' EVEN 100 FEET OF SUB SEA DEPTH. F"~F'",~ ~EI'~F'D, ..... - ,-,. V['.~,(!'" ' [CAL SUB HD-TVD VE~T !CAL F~r:' P ")' H DEPTH SEA O IFFE~ENCE CORRECTION TOTAL COORD INATE~ 727 1 737' 1 7571 7671 7771. 7871 797 1 8071 8171 8271 ~572 r~572 877 2 8 87 2 ~07 2 9]72 9272 9372 0~7 2 9572 0672 0772 7,68, 7100, 3 0 17.28 N 162.8~ E 7368, 7200, 3 0 15.22 N 165.10 E 746S, 7300~ ~ 0 1~,56 N 1.66,88 E 7568. 7~00, 3 0 11,86 N 168,2~ E 7668. 7500, 3 0 10.3~ N 167,~9 E 7768, 7600, 3 0 ..... BeBS~N .168,05 E 7868. 7700. 3 0 8,0~ N 169.68 E 7q68. 7800. 3 0 7,~7 N 171e~0 E 8068, 7900, 3 0 ..... 6,52 N 173,17 ~ ~168, 8000. 3 0 5,71N 174e85 E 8268~ 8100, ~ 0 5,04 N 176.A7 ~ 836~. 8200. 3 0 ~,33 N 177,70 5 846~, 8300, 4 ! ~,$5 N 178,66 E 8568, 8400, 4 0 2,78 N 179.~0 E ,... 8600. ~ 0 1.35 N 181.80 E $~60, 8700. 4 0 0.~ N 189.29 E 8968. 8800, 4 0 .... 0,20 $ 185e57 E 9068. 8900, 4 0 0.92 $ 186.02 E 9168. 9000. & 0 1.88 $ 188.19 E 9268. 9100, 4 0 ..... 2.70 S 191.00 E 9968, 9200, ~ 0 ~,4~ $ ~94.~9 E 9468, 9300, ~ 0 4.~6 S 197.97 E gS&8. 9400. 4 0 5.41S 20~,09 E 96&8, ~500, ~ 0 6.29 S 206,04 E 9768, g600. 4 0 6.96 S 209.~9 E I' ~I "I' fl PPOLA TED F~,r!!! p TH 1000 2 noO 3000 40OO 5 000 6000 ?000 8000 9000 VALt!F,% F T VE R T EVEN RUE ICAL P TH 1000 FEET OF MEASURED DEPTH, SUB SEA 'TOTAL COORDINATES 999, 831. 0.71 N 2,38 W 999. 1891. 15.16 N 3,92 W 999, 2831, 21.66 N 14,82 E 998. 3830. 28.72 N 51,08 E 998. 4.830, 28,73 N 92,~6 E 997, 5829, 22.69 N 128.26 E 996, 6828, 22.51 N 156.~2 E 996, 7828. 7,18 N 171,76 E nfl '~,,,~'EL.L .¢,C!,~ ~-~ K B ELEV. 16~ FT. SlHGLF-SH~I' SURVEY DECLiHATION 25 DEG. EAST tAL. ~!ETI. i(.')ID OF CO~,~PUTATIONS JOB NO, ALS?D-D5 I~()R GREAT LAND DIRECTI()N~L DR'LLIHG RY F H LINDSEY AND RECORi, OF SttRVEY Ai..L, C:ALCULATIOI'I5 PERF'()R~tTD BY I B 1,4 ELECTRONIC COMPUTER pp.[fiT VE'F~TICAI. ANGLE DEPTH SUB DR I FT SEA DiREC TOTAL. COORDINATES CLOSURES D I STANCE ANGLE D M $ DOG LEG SEVERITY DEG/IOOFT 1 0 819~,,5,? 8028,,52 N 66 W 5,~+9 N 175,]0 E 175,]8 N 88 12 22 E DATA DOWN TO 8200 HD IS FROM AN EASTMAN GYRO SURVEY IN~,l~71 {CORRECTED) 0.000 n;}',)l t,~ 30 ~2J~?,,23 ~119,23 N 62 E 9~,~(', q 0 ~t. Ol.80 ~233.B0 h ~5 E ~'' .... ' 15 8662.11 0494.11 H 73 ~ ~, 'r ::, ,'~ n 0 S 7.1 7 · 5 7 ~ 5 4 g, 5 7 N 7 2 ff 95~r~ lO 65 89~1.1~, ~783,16 N 75 E 9].~3 ]3 15 q188.]0 9000.10 N 77 E 9~P3 ]3 30 9275.07 9107.07 t',l 77 [ 0~,28 ]4, 0 qa~,q-.ll 9236.11 N 77 E 952o 13 0 9495e71, 9327.71 t4 77 E oF, C:2 !3 0 9575.60 9407.60 N 78 E nTnn 12 ~0 9871.2g 9503,28 ~ 78 E 979] 1~ 15 9760.21 959~.2~ N 79 ~ a~f,~, 12 0 ~832.5g 9864.59 N ~0 ~ 8.8t~ N 181,60 12.22 N I86.06 14,82 N 189.63 1~,21 N 196,90 ~ 1.q,9 N 205.~ 25,10 N 217.26 27,91 N 224,67 31,07 N 236.31 35,23 N 250e80 38.51 N 26~,05 42,97 N 282,~9 49.0~ N 908 eT~ 62.07 N 365.11 66.83 N 38~,71 70,66 N 40~,76 7~.07 N q24.51 78e76 N q~)e~$ 81.43 N ~58.61 I81,81N 87 12 ~5 E 186.47 N 86 12 31E 190.21N 85 31 q) E 197,7~ N 8~ ~2 51 E 206,56 N 8~ 1 38 E 218,71N 83 2~ 27 E 226.35 N 83 1 2 E 2~8.35 N 82 30 30 E 253,26 N 82 0 14 E 265.8~ N 81 ~0 1~ E 285.6~ N ~1 20 ~7 E ~12.~1N 80 58 15 E }38.2~ N 60 ~0 10 E ~70.35 N 80 21 3 E ~91.~ N 80 10 12 E 5.688 1.~85 0.523 1.~97 0.776 1.127 1.~60 0.955 1.136 1,~94 0.435 1.907 . 0,227 ) SECTIO,. DISTANCE 17~,08 180.82 185.76 189.67 197.37 206.~1 218.55 226.2~ 25~.2 ) 265,85 Z85,6~ 312.61 338.22 370.31 391.A0 ~0g.81 · ~30.99 465,67 RECOR[;; OF SURVEY ALL CALC'tJL.,a. TiOt,4S PFRFORqED BY ! B ~,~. ELECTRONIC COHPUTER Tr~ SEA D I~EC , DEG. TOTAL COORDINATES 0226 ],2 15 10185,24 ]0017,2~ N ~ E 0305 11 45 10262,58 10094,58 N 8~ E ~)455 I0 30 10410.07 10242,07 N a6 E 0526 if) 0 10479,99 ].O311,g~ ~,~ 86 E ,0BA3 10 0 10792,]8 10624,1B N 86 E 91,~2 N 5~5,12 E 93,10 N 551,12 E ~5.01N 57~.~8 E 95.87 N 590.68 E 99,71N 645.60 E tOTTO!q t~,IOLE CLO~URE 653,25 FEET AT N 8I 1~ 1! E C LO SURE ~ DISTANCE ANGLE D M 491.03 N 79 56 5 E ~E2.09 N 80 1~ 12 E 542.87 N 80 18 15 E 558.9~ N BO 24 $8 E ~86.1~ N 80 ¢0 15 E ~98.~I N 80 46 49 E DOG LEG SEVER I T'Y SEC T I ON DEG/IOOFT DISTANCE O,210 490.~ ) 0.76~ 522.0, 0.704 512.60 0.872 586.11 0,70~ 598,40 OEO00 65~,25 tr~TrF!OOLATEO TRkJF. VFRTICAL D~PTHS, ZOORDINATES AND CLOSURES FOR GIVEN DEPTHS T RUE ~'~A~LjR~D VERTICAL DEP'~'H DEPTH TOT AL COOleD I NATES CLOSURE D I STANCE ANGLE D M SUB SEA 10700 10782 1040~,70 96.10 N 593,97 E 1053.3,17 96953 N 600e04 E 10556,0i 96.82 N 604,19 ~ 1.0633,62 97,76 Fl 617,71. ~ 10651,35 97.98 N 620,82 E lO7B2elO 98.97 N 6~5,03 E t0792,18 99~71N 645,60 E 502,88 N 80 ~ 54 E 10280.~8 597,72. N 60~.?0 N 80 ~8 ~2 E lOD~O,70 607,75. N 80' 51 ~9 E 10965e17 6!1,90 N 80.5~ ~9 E 10~88,8! ' 625,~0 N 81 0 22 E 10~65,62. . 628.51 N 81 I 51 E 6~2,70 "~,:*r:~ T!4 DCPTH 5EA OIFFERENCE CORRECTION 8 ~7 z~ ~6.6,~, 8500, g775 876~, 8600~ ~a76 ~68~ ~700, 8978 8968 · 9020 906~. 8900. glO3 9168, 9000, 9286 9268, 9100, 9~9 9~68. 9200, 9~92 9~68. 95~4 g568, 9400, 96~7 9668, ~00~ t(]~O~ 996f~. 9800. 10106 1006~, 9900, ]92O8 1O168, 10000, 10311 1026~, 10100, I C)4]. 2 10~68. 10200, ],f)B 14 1046~. 10300. 2i,60 IN 29,?8 N 39.2~ N ~9,0~ N 60,04 N 6~,39 N 70,30 N 74,92 N 79.04 N 82.76 N 86,18 N 88,11 N 90.90 N 93,17 N 9%.%7 N ~B.72 N 205,81 218,05 232*10 248.10 266.2~ .285,77 3OB, 71 332,1! 356.34 379,~8 ~02, O~ 423e 79 466,18 487,70 509,78 531,4[ 5~2,12 570.60 588,57 i~'T~:!f~p~L^T~D VALtt[F~ FOI?, EVE?.', lO00 Ft~?ET OF ~,IEASURF, D DEPTH, COORDINATES 8821, 9796, 40,18 N 270.30 86.11 N A86.9~ 2400. VERTICAL SECTION SCALE i"= IOOd STANDARD OIL COMPANY OF CALIFORNIA SCU 43B- 5 ......................... - TANGENTIAL METHOD ............... ,4000- _ . . : · 480C ALL DEPTHS SHOWN ARE TVD. 6400 - 6800- 720O 7600 - 8400 - 8800 - SCU 43A-5 SCU 43B-5 TVD: 9846' ~o, ooo TMD =9850' \ ! Ti,/D = h~ ~c~2' ~ TMD = . ..................................................................... HORIZONTAL VIEW SCALE I"- I00' ........ STANDARD OIL COMPANY OF CALIFORNIA SCU 45 B - 5 ' ' ' ~ ........................................... TANGENTIAL METHOD .... SCU 43B-5 . ...... ]-.-] ......................... ] ........ ] .......... ...-~ ........ -. ............. ]- ....... . .............................. -~o, ooo ~u,'~J~ TVD = - ' : ~, '' ~~~--- ' f ''TMD 10~84S'10'79 2' · ' . SCU 4:3A-'5-' ' . ' - ' 9,~~5.. ~ 655 . _ 2~-B~0~ -' .... : .......... ~ ~ ........... : ...... -: ...... - ........ : ............................................ CLOSURE S87O59'E 212' TVD=9846" TMD = 9850' ALL DEPTHS SHOWN .. ARE TVD GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STARYDARD OIL COMPANY COMPANY s~u ~5~-~ WELL NAME SWANSON RIVER FIELD LOCATION ALS?5-D5 JOB NUMBER 2YNGY,E SHO~ TYPE SURVEY 8-~.75 DATE THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confidence. Additional copies of your survey report can be made from the original by any blueprint company. COMPLETION REPORT AUGUST 14, 1975 STANDARD OIL WELL SRU 438-5 K B ELEV. 168 FT. HAGNETIC SINGLE-SHOT SURVEY DECLINATION 25 DEG. EAST TANGENT[AL METHOD OF COHPUTATIONS JOB NO. AL575-D5 COHPUTED FOR GREAT LAND DIRECTIONAL DRILLING BY F M LINDSEY AND AS$OC, RECORD OF SURVEY ALL CALCULATIONS PERFORHED BY I B N ELECTRONIC COMPUTER TRUE HEAS, DRIFT VERTICAL SUB DEPTH ANGLE DEPTH ........ SEA D M DRIFT DIREC DEG. TOTAL COORDINATES 8200 i 0 8196,74 8028,74 N 66 W 8,37 N 152.36 E ALL ABOVE DATA 'IS EASTMAN GYRO SURVEY 1971 8291 4 30 8287.45 8119.45 N 62 E 8356 5 0 8352.21 8184.21 N 52 E 8406 5 0 8~02,02 8234.02 N 55 E 8486 5 45 8481.61 8313.61 N 65 E 8570 6 15 8565.12 8397.12 N 69 E 8668 7 15 8662.33 8494.33 N 73 E 8724 8 0 8717.79 8549.79 N 72 E 8804 8 45 8796.86 8628.86 N 73 E 8893 9 45 8884,57 ' 8716.57 N 74 E 8961 10 45 8951.38 8783.38 N 75 E 9065 1! 0 9053.47 8885.47 N 77 E 9183 13 15 9168,32 9000,32 N 77 E' " 9293 13 30 9275.29 9107.29 N 77 E 9426 14 0 9404.33 9236.33 N 77 E 9520 13 0 9495.93 9327.93 N 77 9602 13 0 9575,82 9407.82 N 78 E 9700 12 30 9671.50 9503.50 N 78 E 9791 12 15 9760.43 9592.43 N 79 E 9865 12 0 9832.81 9664,81 N 80 11.72 N 15.20 N 17,70 N 21.09 N 24.37 N 27.98 N 30.39 N 33.95 N 38.11 N 41,39 N 45.85 N 51.94 N 57.71 N 64,95 N 69.71' N 73.54 N 77.95 N .. 81.64 N 84.,3! N 158.66 E 163,12 E 166.69 E 173,96 E 182,49 E 194~32 E 201.73 E 213,37 E 227.86 E 240.11E 259.45 E 285.80 E 310,82 E 342.17 E 362.77 E 380.82 E 401.57 E ~20.52 E 435.67 E . . CLOSURES DISTANCE ANGLE D M 5 152.58 N 86 51 20 E 159.09 N 85 46 29 E 163.83 N 84 40 23 E 167,63 N 83 56 9 E 175.23 N 83 5 7 E 184.11N 82 23 34 E 196,33 N 81 48 13 E 20~.01N 81 25 52 E 216.06 N 80 57 28 E 23t,03 N 80 30 18 E 243.65 N 80 13 8 E 263.47 N 79 58 36'E 290.48 N 79 41 58 E 316.13 N 79 28 49 E 348.28 N 79 15 4 E 369.41N 79 7 21E 387,85 N 79 4 B E AOge06 N 79 0 49 E 428.37 N 79 0 47 E 4a3.79 N 79 2 50 E DOG LEG SEVERITY DEG/IOOFT 'SEC] )N D I STANCE 0,0OO 5,688 1,485 0,523 1.497 0,776 1,127 1.360 0.955 1.138 1.494 0.435 1,907 0.227 0.376 1,064 0.274 0,510 0,362 0.441 151.69 . 158,45 163,43 167.35 175.07' 184.03 196,29' 203.99' 216,05 231 243.65 263.45 290.44 316.07 3~8.18 369.28 387.71 408.90 428.20 443.58 RECORD OF ALt., '¢ALCUL'ATIONS PERFORMED BY I B M ELECTRONIC COMPUTER .TRUE MEAS, DRIFT VERT!CAg SUB DRIFT TOTAL COORDINATES DEPTH ANGLE DEPTH SEA D]REC ..... D M DEG, CLOSURES DISTANCE ANGLE. DOG. LEG SEVERITY SECTION DEG/IOOFT DISTANCE . 9984 12 15 9949.10 9781,10 N 80 E . 88,69 N 460,54 E 10128 12 ~0 10089,69_ 9921,69 N 85 E .... 91,~l...N .... 491,58 E 10226 12 15 10185,46 10017.46 N 82 E 9~,30 N 512,18 E 10305 1! 45 10262,80 10094,80 N 84 E 9.5,98 N 528.18 E 10455 10 30 10610~29..10242,29 N 86 E 97,89 N 555.44 E 10526 10 0 10480,21 10312,21 N B6 E .... 9B,75 N 567,74 E 10843 10 0 10792,40 10624.40 N 86 E 102,59 N 622,66 E 469.00 N 79 5 54 E 500,01 N: 79 2? 56 E 520.79 N 79 34~ ! E 536.83 N 79 41 58 E 56~.01 N 80 0 15 E 576,27 N 80 7 56 E 0,210 468 0.76~ 499.~1.. 0,704 520,69 0.823 536,75. 0.872 563.97. 0,70~ 576,25 0,000 631.05 BOTTOM HOLE CL-OSURE 631,05 FEET AT N 80 38 36 E CODE NAME XNTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE .... D M S SUB SEA HEMLOCK 2 10~94 HEMLOCK 3 10522 HEMLOCK 5 10545 H~ POINT 10580 HEMLOCK 8 BASE H8 I0682 HEMLOCK 10 10700 BASE HIO 10782 TD 10843 10448.70 98.36 N 562.20,E 10476.27 98.70 N 567.05 E 10498,92 98.98 N 571.03 E 10533.39 99.41 N 577.10 E 10557.03 99.70 N 581.25 E 10633.8~ 100.6~ N 594.77 E 10651.5? 100.86 N 597.88 E i0732.32 I01.85 N 612.09 E 10792.~0 102.59 N 622.66 E 570,'7~ N,80 4 ,31 E 10280,70 575.58 N 80 7 ~I E 10~08,27.. 579,55 N 80 9 56 E 10330.92 585,60 N,80 13 34 E 10365,39 589.74 N 80 16 -1 E 10389.03 603.22 N 80 23 606.33 N 80 25 27 E 10483,57 620.51 N 80 33 7 E 10564,32 631.05 N 80 38 ~6 E 1062~,40 , MEASURED DEPTH AND OTHER DATA FOR TRUE MEASURED VERTICAL DEPTH DEPTH EVERY EVEN 100 FEET OF SUB SEA DEPTH, SUB HD-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 82T1 8268, 8100, 8372 8368, 8200, 8472 .. 8468, 8300, 8579 .......... 8568, 84,00, 861'4 8668, 8500, 8775 8768, 8600. 8876 8868, 8700, 8978 8968, 8800, 9080 9068, 8900, 9!83 93.68* 9000,. 9286 . 9268. 9100, 9389 9368. 9200, 9~491 9468* 9300, 9594 9568, 9400, 9696 9668, 9500, 9799 ~... 9768... 9600, 9901 . 9868, 9700, 0003 9968, 9800, 0106 10068, 9900, 0208 10168, 10000. 0310 10268. 10100. 0412 10368. 10200. 0514 10468, 10300. 3 4 4 5 6 7 8 10 12 15 . 18 21 23 26 28 31 38 4O 42 46 2 2 3 2 2 2 11.0'0 N 157,31 16.00 N 164,25 20.51 N 172.71 24.48 N 182.84 28.23 N 195,08 32.65 N 209,12 37.32 N ,,' 225,12 42,12 N 243.26 46.62 N 262.78 51.92 N 285.72 57*32 N 309.12 62.91 N 333.34 68.26 N 356.49 .73.17 N 379.05 77.79 N 400.81 81.92 N 422.10 85.63 N /+43,19 89,06 N 464*71 90.99 N 486.79 93.78 N 508-42 96.05 N 529.14 97.3A N 547,62 · 98,60 N 565.59 E E E F. E E E E E E. E E E E E E E E E E E ! INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 900'0 .: 8989. lO000 g964. 1000 FEET OF MEASURED DEPTH, .SUB SEA TOTAL COORD ! NATES 8823., ...... /~3,06 N 247.36 E 9796, 88,99 N 463.99 E HORIZONTAL VIEW SCALE I"=100' STANDARD OIL COMPANY OF CALIFORNIA SRU 4:~ B - 5 · TANGENTIAL METHOD I0,400 9600 ~ __.-.------'"-"~. ~ ALL DEPTHS SHOWN ARE TVD -SO0 2OO · . · 1600 VERTICAL SECTION SCALE I%1000' STANDARD OIL COMPANY OF CALIFORNIA SRU 43B - 5 TANGENTIAl.] METHOD · 2400 . . - 2800 32OO · 3600 -4OOO - 44OO 480O -52OO 56OO ALL DEPTHS SHOWN ARE TVD 6400 68OO ' 72OO 7600 -8400 9200' ~600 (J,O00 -~10, 400 TVD: t0,792' eticc:l Open Flow Pot,'~nt[al with/Damage Removed Ma×. OF~, -- lhf~oretical Open Floc, Portent;al with/Damage Removed Min Ps Q Q, Qo R r,., t to T Z - Cor'npressibiJ fy Factor ~ -- Viscosity Gc~s or L~clu'd Finol Flow Pressure Potentiom:'tric Surfac,' A'ver ag,' Ad~ust~-d Th¢oruticc~l Product~o~ ~ [~')c~n~ag~' Removed Meosured Gas PrOduct~or~ Corrected R(cover~ Rod'us of Well Borax Total Flow T CP Ticket F L U I D S A M P L E D A T A Dote o r_ .u o_ o_-/1:: Number 608024 -Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. Cas of Job HOOK WALL District ANCHORAGE cc. Oil cc. Water Tester L.D. PHILLIPS Witness W.A. DAVIS cc. Mud Drilling Tot. Liquid cc. Contractor KENIA DRILLING COMPANY SM S Gravity ° APl @ °F. EQ U I PM E N T & H O L E DA T A Gas/Oil Ratio cu. ft./bbl. Formation Tested Hamlock RESISTIVITY CHLORIDE Elevation 183' Kelly bushing Ft. CONTENT -- Net Productive lnterval 10665-10680' Perfs 15' Ft. Recovery Water ~ °F. ppm All Depths Measured From Kelly bushing Recovery Mud @ °F. ppm Total Depth10843'Ft. Recovery Mud Filtrate __ @~°F. ppm Main Hole/Casing Size 5" CSg. Mud Pit Sample .~.~. @ °F. ppm Drill Collar Length 2909' I.D. 1.9f~5" Tubing Mud Pit Sample Filt~C~]te~ @ ~°F. ppm Drill Pipe Length 7696' I.D. 2. 764" Packer Depth(s) 10629 ' Ft. LMud Weight 77#/ cu. ft. vis 45 cp Depth Tester Valve 10605.85' Ft. TYPE AMOUNT Depth Bock Surface Bottom Cushion Ft. Pres. Valve Choke 5/8" Choke . 62'" -- Recovered Feetof Reverse circulated well - estimated recovery of · Recovered Feetof 10 bbls. gas cut mud & trace of oil ........ Recovered Feet of Recovered Feet of Recovered Feet of Remarks Tool opened with a weak blow which increased to strong in 3 minutes, gas to the surface in 10 minutes, stabilized on strong blow throughout flow. Closed tool for 722 minute closed in pressure period. (Had 0 surface pressure.) *Read at the end of 348 minutes when chart time expired. **Read at the end -- of 350 minutes when chart time expired. CTE = chart time expired. Gauge No. 3382 Gauge"No. 3381 Gauge No. 2859 TEMPERATURE TIME Depth: 10610.5DFt. Depth: 10615.10. ft., Depth: 10638 Ft. 24 Hour Clock 48 Hour Clock 24Hour Clock TOol A.M. Est. °F. Blanked Off no Blanked Off no Blanked Off _yes ... Opened P.M. 10643' Opened A.M. Actual 185 °F. pressures Pressures Pressures i Bypass P.M. ,, Computed Field Office Field Office Field Office Reported Initial Hydrostatic 5717 5774 .5744 5774 57.%5 5762 Minutes Minutes Ini'tiol I .-3 98 82 9B q6 log 95 ~.~_ Flow---- L~. Final 242 222 245 22q_ _ 25] 218 720 721 Closed in 41 .~q 4201 * 4270 427-g 41 42 41F:2'* 723 722 _ g'o Initial c o Flow __ u©'c Final Closed in -,~ ~=~ Flow Initial .-, ~_~. Final,, " Closed in Final Hydrostatic - C. TF 5842 5703 £TE -- ,, ~ORM 18I.RI--pRIHT~'D IN · Ticket F L U I D S A M P L E D ^ T ^ Date 8-2-75 Number 608024 Sampler Pressure .P.S.I.G. at Surface Kind Halliburton Recovery: Cu. Ft. C-~:~s of Job HOOK WALL D~str~ct ANCHORAGE cc. Oil cc. Water Tester L,D, PHILLIPS Witness W,A, DAVIS cc. Mud Drilling Tot. kiquidcc. Contractor KENIA DRILLING COMPANY SM S Gravity ° APl @ °F. EQ U I PM E N T & H O L E D AT A Gas/Oil Ratio cu. ft./bbl· Formation Tested RESISTIVITY CHLORIDE Elevation Ft. CONTENT Net Productive Interval Ft. Recovery Water @ °F. ppm All Depths Measured From Recovery Mud @__ °F. ppm Total Depth Ft. Recove~ Mud Filtrate __ @ ~°F. ppm Main Hole/Casing Size · Mud Pit Sample @ °F. ppm Drill Collar Length I.D. -- __ Mud Pit Sample Filtrate @~°F. ppm Drill Pipe Length I.D. Packer Depth(s) Ft Mud.. Weight vis cp Depth Tester Valve Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion Ft. Pres. Valve Choke Choke Recovered Feet of O Recovered Feet of Recovered Feet of < Recovered Feet of ~ Recovered Feet of Remarks Fourth gauge Gauge No. Gauge No. Gauge 'No. TEMPER~,TURE 2858 TIME Depth: ]. 0~/], 2 F.t. Depth: Ft. Depth: Ft. 48 Hour Clock Hour Clock Hour Clock Tool A.M. Est. °F. -Blanked Off u~c Blanked Off Blanked Off Opened P.M. '~ ~ ~ Opened A.M. Actual °F. Pressures Pressures Pressures Bypass P.M. Field Office Field Office Field Office Reported Computed -J'nitial Hydrostatic Minutes Minutes --. ,~o Flow Initial NO rea,Jings J i~.~. Final ava lable Closed in ~ ~n~t~a~ Tester failed to c o Flow °~'c Final ~g engage the Closed in S tvl u,.,. - Initial ~o Flow ... ~_~ Final Closed in Final Hydrostatic -- __ Gauge N,o. ,,, 338,2 ...... Depth, 10610..50' .... Clock No. 8739 2~our No. 608024 ..... First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure , ,,, .......... , ,, ,,, , Time Deft. PSIG Time Deft. t -{- ~ PSIG"' Time Deft. PSIG Time Deft. t -Jr- ~ J~SIG Time Dell. PSIG Time Defl. t -{- ~ PSi(3 Temp. Log 'i'emp. Temp. Log Temp. Temp. Log-- Temp. .000" Corr. .000" ~ Corr, .000" Corr. .000" "~ Corr. .000" Corr. .000" ~ Corr. , 0 .0000 R?__ .0000 222 ..... ] '3041~ 123 ,1671"* 3722 2 .6048 l .... .'"9'055 ,~4515q .3274 . 39_33 ... ....... ,,, 8 2,4090 222 (1.1620-*** 4201.) ~ ... 1.2897 " - ...... lo 1.4501 - , , 11 1.6105 - ............... ]: 1.7709 - ]3 1.9312 - ................... 14 · 2.0916 - . ..... ~$ ...... 2, 2520 - .... 2,4124 - GaugeNo. 3381 Depth 10615,10' Clock No. 13861 48 hour o .0000 '96 "' .0000 229 .... ... 1 ~ .1537' 128 0845'1' 3722 2 .3058 "150 1656' 3931 ' ' 3 .4578 162' .2467 4017 4 .6099 177 .'3278 4081 s .7619 192 .4089 4128 a .9140 201 .4900 4162 7 1.066'0 '214 .~'712 4189 I ,' 8 1.218"0 229 .6523 4209 I -7334 4224 9 lo 18145 4236I ]~ .8956 4248 12 .9767 4256 ]3 I 1. 0578 4'263 141 I'l. 1389 4268 15: ! 1.2200 4275] ..... , , , Reading In~e~vol 90 ii 48 ........ Minutes_ RE~^R~S: *FJrs¢ Jnterv~l Js equal ~o 91 mJnutes. ** = 50 m~n~te_~ ***Read ~ the end of 348 m~nutes when chart time expired, ........ , .... , , SPECIAL PRESSURE DATA .... Goucj,e,, No. 2 5 8 9 10 11 12 14 15 2859 Depth 10638 Clock No. 8420 ITicket 24 hour No. 608024 First First Second Second Third Third Flow Period Closed In Pressure Flow Period Closed In Pressure Flow Period Closed In Pressure Time Deft. PSIG Time Deft. - t -J- ~ PSIG PSIG tJr.~ PSIG PSIG PStG Temp. Temp. Temp. LogT Temp. Temp. Temp. Log-- Time Dell. Time Dell. Time Deft, Time Deft. Lo- t ~ ~ ,000" Corr, ,000" ~ Corr. ,000" Corr, ,000" Corr. ,000" Corr, ,000" g~ Corr. .0000 .3042' 120 .6050 143 .9058 158 ;auge N.o.: 2858 170 .6485 1 80 .8089 193 ,9693 '206 1.1298 218 1.171 218 . 3691 3913 .. 4005 4065 ,, 4112 4149 4177 4182) 1. 2902 Depth 1.4507 1.6111 1.7715 1. 9320 2. 0924 10642~. 2,2529 2.4133 ..tester faile( No readings available. 48 Clock No. 7525 to mng~gP the _~ i~ ~q~Ja! to 9! minute. ** = 50 minutes, , Reodin9 Intervol 90 REMARKS: *Fi rst interval Expired 4R hour ty! us. Minutes SPECIAL PRESSURE DATA LITTL£'$ 96673 75C 6/74 TICKET NO. 608024 Drill Pipe or Tubing ................ Reversing Sub ................. .... Water Cushion Valve ................ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Dual CIP Sampler .................. Hydro-Spring Tester ................ Multiple CIP Sampler ' Extension Joint .................... . AP Running Case Hydraulic Jar .................... VR Safety Joint ............... Pressure Equalizing Crossover ......... Packer Assembly ................... Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. Pressure Equalizing Tube ........... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly Anchor Pipe Safety Joint ............ Side Wall Anchor .................. Drill Collars ...................... Flush Joint Anchor .................. Blanked-Off B.T. Running Case ........ Total Depth ....................... O.D. I.D. LENGTH 3.5II !~ 75II ?: 7Ill 3N" 2.76z~'' 7696' 2 3/8" 1,995" 2909' 3 7/8" ,87" 5.45' .. 3 7/8" ,62" 4.65' 3 7/8" 3" 4.60' 3 7/8" 3" 4.60' 3 7/8" .62" 3.20' 3 7/8" . 75" 2' 3.5" · 75" 5.25' 3 3/4" 1.75" 3 3/4" 1o 75" HT-500 Temp recorder 8.15' 4' 1 DEPTH 10605.85' 10610.50' 10615.10' 10629' 10638' 10642' 10643' FORM 187.fll--t:'lllNTIrn IlU Il e · ~ ~ ! · I ~ · I 1---.,I ~ iI.,,I--I ~ i / . TIME != r~ c h Horizontal Line Eaual to 1000 Ticket FLU I D S^'M P L E DAT Sampler Pressure .P.S.I.G. at Surface Kind HOOK WALL Halliburton Recovery: Cu. Ft. Gas of Job PACER District KENAI · cc. Oil cc. Water Tester ~Ro LYONS Witness MRo DAKESSIAN cc. Mud Drilling Tot. Liquid cc. Contractor KE~LA.I DRILLING CO~PA~Z' BJ S Gravity ° APl Gas/Oil Ratio cu. ft./bbl. Formation Tested RESISTIVITY CHLORIDE Elevation ~83' Kelly B~s_bZ~ Ft. CONTENT - -- Net Productive Interval 14' Perforations Ft. Recovery Water ~ @__ °F. ppm All Depths Measured From Kelly Bushin8 Recovery Mud @ °F. ppm Total Depth 10843 t Ft. Recovery Mud Filtrate __ ~__°F. ppm Main Hole/Casing Size 5'l Casing Mud Pit Sample @ °F. ,~ ppm Drill Collar Length 2909t I.D. 1.9~5'~' Mud Pit Sample Filtrate @ °F. ' ppm Drill Pipe Length 7666 t I.D. 2o764" Packer Depth(s) 10598 ! Ft. Mud Weight 76 ~;'S per ...... cu, ::ft,vis 44 cp D, epth Tester Valve 10578~ Ft. TYPE AMOUNT Depth Back Surface Bottom Cushion NONE Ft. Pres. Valve Choke 5~6o_~ Choke 5/8" o~ ± .3/o Recovered Feet of '11 Recovered Feet of Recovered . Feet of ~ -' < Recovered Feet of Recovered Feet of , . Remarks SEE PRODUCTION TEST DATA SHEET .... ,, REVERSED BACK GAS AND OIL. Gauge No. 3382 Gauge No. 2859 Gauge No. 2858 TEMPERATURE TIME Depth: 10583 ' , Ft. Depth: 10613 ' ..... Ft. Depth: 10618 ', Ft. 24 Hour Clock 24 Hour Clock 48 Hour ~lock Tool A.M. Est. °F. '"BJ;3nked CfffNO Blanked Ot~'ES Blanked Off ~E~ Opened 750 P~= - Opened ~;.~. Actual 155 °F. Pressures Pressures Pressures Bypass 1130 p.M. Field Office Field Office Field Office Reported CompL]~ed Initial Hydrostatic 5623 5675 5655 __ 5-687 5664 5679 Minutes Minutes' -- __ · -~o~.c Flow Initial. 1925 181lq I _2346 lllOq 2361 ll18Q bz~ Final.. 1206 1218 1351 1319 1330 1322 460 451 ...... Closed in 3777 3813 3765 3815 480 490 ~o Initial ua.c Flow Final Closed in -- Initial ~ Flow ..... ~.~. ..... Final Closed in -- Final Hydrostatic j - UTR - UTI{ 5664 5659 _ 0J= OUESTION\BLE UTR = UNABLE F'O R~]AD ,, Ir(")l::;) %/IATIC%IXI Ti'CT I-~ATA Casing perfs.10639 t_ 10653 t Bottom choke 5/8" Surf· temp ,'F Ticket No. 849217 Gas graviS. Oil gravity. .C~)R Spec. gravity .Chlorides ppm Res. @ 'F INDICATE TYPE AND SIZE OF GAS MEASURING DEVICE USED ........ Date 8-5-75 Time 750 a.m. Choke Surface Gas Liquid Size Pressure Rate Rate Remarks p.m. psi MCF BPD 750 5/8 Opened tools. 815 " 1800 Gas to surface. 816 20/6~ 1800 · 825 ~ " 2000 Oil t~. surface. ~ 835 " 2000 ' Gas and oil 840 5/8 2000 " " 845 " 1000 " " 900 " 750 1020 " 700 1100 " 65O 1115 1 5/8 650 TOOK choke out of one side and 5/8" on other side- open both sides. 1130 1 5/8 400 Oil and gas 1300 ,, 375 1400 ,, 35O 1500 ,, 325 1530 '" 325 Closed in at tools for final closed in pressure. Reversed tubing at dual closed in pressure tool. _ -- Gauge No. First Flow Period Time Deft. PSIG Temp. .000" Corr. .0000 1811 3043 2701 .2514 1962 .4995 1799 .7477 1567 .9958 1400 1.2439 1304 1.4920 1218 Time Deft. .000" .0000 .0926 3382 .2018 .3110 .4201 .5293 .6385 .7477 .8568 .9660 1.0752 1.1843 I Depth First Closed In Pressure PSIG Temp. Corr. 1218 2798** 3105 3249 3363 3444 3508 3561 3608 3648 3684 3717 L 10583' Second Flow Period Clock No. 8420 Second Closed In Pressure PSIG Temp. Corr. Ticket 84921 7 24 hour No. Third Flow Period PSIG Temp. Corr. Time Deft. .000" 1.2935 3746 1.4027 3770 1.4070 3777 I Time Deft. .000" PSIG Temp. Corr. Time Deft. .000" Time Deft. .000" Third Closed In Pressure PSIG Temp. Corr. e No. 2859 1.5118 1.6210 Depth 1319 10613' Clock No. 8739 24 hour 849217 .0927 2786** 2885 .2019 " 3100 3085 .3112 3249 2236 .4204 3364 2002 .5297 3444 .7482 1748 .6389 3501 1549 .7481 3561 1431 .8564 3608 1319 .9666 3643 1.0759 3681 1.1851 3716 1.2943 3738 .14036 3763 1.5128 3793 1.5710 3813 Reodin9 Intervol 1. 6221 33 . Minutes REMARKS: * INTERVAL = 76 MINUTES ** INTERVAL = 28 MINUTES C = CHOKE CHANGE Q = QUESTIONABLE FORH 183-RI--PRINTED IN U.S.A. SPECIAL PRESSURE DATA LITT~.£'$ g6~73 75C 8/74 TICKET NO. 849217 O. Do Drill Pipe or Tubing ................ Reversing Sub ...................... 3. $" Water Cushion Valve ................ Drill Pipe ........................ 3 1/2~' D~~ Tub.Lng ............... 2 3/8" Handling Sub 8, Choke Assembly ...... Dual CIP Valve ................... 3 7/8" Dual CIP Sampler .................. Hydro-Spring Tester ................ 3 7/8" Multiple ClP Sampler ............... Extension Joint .................... 3 7/8" AP Running':]ase .................. 3 7/8't Hydraulid Jar .................... 3 7/8" VR Safety Joint .............. 3 7/8" Pressure Equalizing Crossover ......... Packer Assembly ... Hook..~&11 ..... 3.5" J. Do I 75" 2. 764" 1.995" .87" .62" 3.00" 3.00" ·62" · 78" .75" LENGTH 2.70' 7666' 2909' 5.45' 4.65' 4.60' 4.60' 3.20' 2.00' 5.25' 10' DEPTH 10573' 10578' 10583' 10588' 10598' Distributor ........................ Packer Assembly ................... Flush Joint Anchor ................. 2 7/8" Pressure Equalizing Tube ......... Blanked-Off B.T. Running Case ....... Drill Collars ...................... Anchor Pipe Safety Joint ............ Packer Assembly ................... Distributor ........................ Packer Assembly ................... Anchor Pipe Safety Joint ............ Side Wall Anchor ................. Drill Collars ...................... Flush Joint Anchor .................. 3 3/4" Blanked-Off B.T. Running Case ........ 3 3/4" HT 500 Recorder Total Depth ....................... 1.75" 1.75" 4.00' _4.00' 1.00' 10621' 10843 ' NOMENCLATURE b __~ Approximate Radius of Investigation ........................ Feet b l - Approximate Radius of Investigation (Net Pay Zone h~) ......... Feet D.R.-- Damage Ratio .......................................... El = Elevation .............................................. Feet GD -- B.T. Gauge Depth (From Surface Reference)~ .................. Feet h -- Interval Tested ......................................... Feet h~ ~_. Net Pay Thickness ....................................... Feet K -- Permeability ........................................... md K~ ~--- Permeability (From Net Pay Zone h~) ........................ md m -- Slope Extrapolated Pressure Plot (Psi2/cycle Gas) .............. psi/cycle OFT m Maximum Indicated Flow Rate ............................ MCF/D OF: m Minimum Indicated Flow Rate ............................ MCF/D OF3 -- Theoretical Open Flow Potential with/Damage Removed Max ..... MCF/D OF:4 ~ Theoretical Open Flow Potential with/Damage Removed Min ..... MCF/D ~ Extrapolated Static Pressure ............................... Psig. ~__. Final Flow Pressure ...................................... Psig. -- Potentiometric Surface (Fresh Water*) ...................... Feet -- Average Adjusted Production Rate During Test ................ bbls/day -- Theoretical Production w/Damage Removed .................. bbls/day --Measured Gas Production Rate ............................ MCF/D -- Corrected Recovery bbls -- Radius of Well Bore ...................................... Feet --- Flow Time ............................................. Minutes -- Total Flow Time ......................................... Minutes ~ Temperature Rankine .................................... °R Z ~ Compressibility Factor ..................................... ~j -- Viscosity Gas or Liquid ................................... CP Loc~ ~ Common Log * Potentiometric Surfece Reference to Rotary Table When Elevation Not C~;ven, Fresh Weter Corrected to 100~- F. Ps Q Q~ Q~ R r~, t to T LOCATED IN THE APPENDIX [21 WFL UI IPR LOG [~ CALIPER SURVEY [21 VOLAN UI CURVE DATA [~ STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER'~ ~~ F~rm 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate . 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL A-028996 8. UNIT, FARM OR LEASE NAME 9. WELL NO. SCO 13-4 ~ 10. FIELD AND POOL, OR WILDCAT~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. ~%g[~'--~WELLGAS 0 OTHER 2. NAME OF OPERATOR Standard Oil Company of California, WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1840' North and 595' West of Southeast corner of Section 5, T-7N, R-9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 168 ' KB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4; T-7N, R-9W 12. PERMIT NO. 75-15 )oft, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L---J PULL OR ALTER CASING I FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ~ ABANDON* REPAIR WELL L___J CHANGE PLANS (Other) ~ Change Wel~i No. SUBSEQUENT REPORT Of: WATER SHUT-OFF ~ REPAIRING WELL fRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) P-4 for SCR 43B-5 (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The bottom hole location of SCU 43B-5 was found to be in Sec. 4; T-7N, R-9W instead of Sec 5; T-7N, R-9W as originally proposed. Therefore to confirm with the Well Numbering System at the Swanson River Field, SCU 43B-5 has been changed to SCU 13-4. ? that the foregoing is true an rr ct SIGNED R.M. McKinley LE Area Engineer (This space for State office use) . DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side State of Alaska Oil & Gas Conservation Committee Well ComPletion or Recompletion Report and Log No. 34 F. T. of perfs, 10,753 - 10,769'. Used 1,100 psi gas cushion. Open 10 hours 30 minutes. Medium steady blow thru-out test. Recovered 620' rise gassy watery mud. Flowing pressure 519 - 1,266'.psi. Shut in pressure 4,617 psi. F. T. of perfs. 10,734 - 10,769'. Open 6 hours. Light steady to medium steady blow with fluid to surface in 45 minutes. Flowed oil of 715 - 1,363 B/D rate. Flowing pressure 167 - 1,512 psi. Shut in pressre 4,506 psi. F. T. of perfs. 10,665 - 10,680'. Open approximately 8 hours. Weak blow increasing to strong blow in 3 minutes and strong blow for balance of test. Gas to surface in 10 minutes. Recovered 10 barrels of gas, cut mud with a trace of oil. Flowing pressure 82-222 psi. Shut in pressure 4201 psi. F. T.~of pelfs. 10,639 - 10,680'.-. Open 7 hours, 30 minutes Flowe~ oil at 310 B/D rate, gas at 4,723 mcf/D rate. Flowing pressure 1,811 psi. Shut in pressure 3,777 psi. ' TRANSI.fLLTTAL Ah~D (, ~, , ~t.,,, .,~ ,, lt_,I',,hOhrLEI, c, EhE,.~l OF ILECEIPT OF HATEI~IAL - (Al,ASK.A) TO: Mr. T. R. Marshall ~tate of Alaska DEPT. :__ DMslon of 011 & Ga~ 3001 Porcupine Drive PLACE:__ Anchorage, Alaska 99504 FD - Folded R - Rolled S -- Sepia F - FiJ.m X - Xerox B - Blt~:~].ine THE FOL].,OWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE C!tECK )J.~D ADV'£SE Ii, fi, II:;DiATEI,Y. WELL HISTORY LOG 2" 5" I .__1__ IO0 20o RECEIVED BY / REMARKS ON OTI4IfR SIDE, THIS SHE'ET COMPLETION REPORT- REDRILL STANDARD OIL CO}~ANY OF CALIFORNIA, WESTERN OPERATIONS..INC., OPERATIONS · ',~ AREA: swanson River Field- - LAND OFFICE: 3mchorage ! Kenai Peninsula : Cook Inlet Area, Alaska P.'ROPERTY: Soldotna Creek Unit LEASE NO: A-028996 WELL NO: 4'3B-5 API NO: 50-133-10115-01 LOCATION AT SURFACE: 1840" North and 595' West of SoUtheast COrner · : of Section 5; T7N, R9W, Seward B & M. LOCATION AT DEPTH: ELEVATION: 168' K.B. (Ground Elevation 15'2.7') · BY: DATE: R. M. McKinley Area Engineer DRILLED BY: Kenai Drilling Co., Rig #2 . . DATE COMMENCED DRILLING: 8:00 A.M. April 25, 1975 DATE COMPLETED: 4:00.P.M. August 10, 1975 DATE OF INITIAL PRODUCTION: August 11, 1975 TOTAL DEPTH: 10,843 ' EFFECTIVE DEPTH: 10,818' SUMMARY cement plug 10,828'-10,843' PLUGS: EZ drill retainer 10,695' EZ drill retainer 10,570' 43-5 20" cemented at 30' 11 3/4" cemented-at 1,990' 7" cemented at 10,582' (top of window) at 10,310' ~- Original shoe at 10,852'. SL~ M b 1975 43A-5 (lst redrill) 7" (window at 10,310') S.-T. 43-5 below 10,310'. ~Jl¥1Sl0N 0~ 0IL AND ~.~ Liner 5" 18#, N-80 cemented at 10,680', top at 10,103'.~,''''''. ..... ~ Plug - 10,680'-10,632'. 43B-5 (2nd redrill) Milled window in 7" casing at 8,190' to sidetrack 43-5 & 43A-5 below this point. Hung 2,860' of 5" liner, top at 7,983'. Perforations: , Four 1/2" holes per foot at: 10,769'-10,753' 10,753'-10,734 ' 10,722 '-10,702 ' Schlumberger: Dual Induction Log Borehole Sonic Formation Density Compensated Neutron Dresser Atlas Neutron Go-International Cement Bond Log 10,680'-10,665 10,653'-10,639' 10,623'~10,608' 8,194'-10,829' (1 run) 8,184'-10,829' (1 run) 8,185'-10,832' (1 run) 8,185'-10,832' (1 run) 10,500'-10,769' (1 run) -10,816' (1 run) Halliburton Formation Tests: ,, HFT ~1 10,769'-10,753 HFT #2 10,769'-10,734 HFT #3 10,665'-10,680 HFT #4 10,639'-10,653 (June 7, 1975) (June 19, 1975) (August 3, 1975) (August 5, 1975) Initial Production: Method: Flowing Oil b/d: 472 Water b/d: 49 Gas mcf/d: 2345 ..~pril 25, 1975 Commenced operations at 8:00 AM. Killed the well with 84 pcf mud. Installed Cosasco plug and removed x-mas tree. .~ 84 pcf mud ~pril'26, 1975 /umstalled 10", 5,000 psi BOPE and tested. 'April '27, ' 1975 Pulled Cosasco .plug. Pulled tubing hanger and loosened packer. Circulated Gas cut mud f~om 62 to 85 pcf. 84-86 pcf mud ~pri1'28,'1975 Pulled out production tubing. Top of fish left at 10,495'. APril 29, 1975 86 pcf mud .En~.aged fish at 10,495' and released packer. Recovered 44' of fish. Top now at 10,539'. Engaged fish at~10,539' rotated packer loose and re~vered 28' of fish. Top of fish at 10,567'. 86 pcf mud April 30, 1975 Worked through tight area 10,552' to 10,562' and circulated. Attempted to run tools ~t could not get below 10,552'. Circulated and went in again but coul~ only get to 10,120'. 'May41, 1975 P~an in with 4 1/8" mill and milled from 10,547'-10,567'. May 2, 19,75 89 pcf mud unable to retrieve packer at 10,567'. Tool parted leaving 20' of fish with top at 10,548'. Tapped fish and recovered all 20'. 94 pcf mud May 3, 1975 To aban~ton well 43A-5 set cement plug with tubing tail at 10,562'. Pumped 30 cu.ft, of Water ahead and equalized 40 cu.ft, of "G" cement with ~419 cu.f.t, mud. Pulled to 10,169' and reversed out trace of cement and 30 cu.ft;. Water. With tubing tail at 10,169', pumped 30 cu.ft, of Water ahead tl~en 54 cu. ft. of "G" cement and displaced with 411 cu. ft. mud. Pulled ~ to 9,604', closed pipe rams and downsqueezed 34 cu. ft. cement to fina~ pressure of 2,300 psi. Pulled to 9,045 and circulated. 94 pcf mud .May 4, 1975 Raised ,-ud weight from 88 to 91 pcf. Located top of cement at 9,260. Tested ~asing to 5,000 psi, ok. With Tri-State section casing mill began to .cut a window at 8,190'. Milled 7" casing from 8,190'-8,231'. Circulated hole clean. Ran mill and reamed window from 8,190'-8,231'. 94 pcf mud ..May 5, 1975 Opened 9 7/8" window to 11" from 8,190'-8,230'. Circulated hole clean and lo~ed viscosity from 182 to 57 sec. with mud weight at 99 pcf. 99 pcf mud May 6, ~975 Ran in lmole with drill pipe to 8,330'. Preceded cement with 40 cu. ft. Water, Ted 93 sacks "G" cement. Equalized cement plug at 7,990' with 331 cu.ft, mud. Pulled up to 7,990' and reversed out a trace of cement and 40 cai. ft. Water. Found cement at 8,170'. Cleaned out cement with 6" bit f~rom 8,170'-8,194'. Circulated hole clean. 89 pcf mud M~y 7, 1975 .Ran and ~rientedDyna-drill at S 45 degrees E. Dyna-drilled 6" hole from 8,194'-8,226'. ~ 98 pcf mud May 8, ,1975 Drilled 6" hole 8,226 '-8, 318 '. (92') 89 pcf mud pnm ~od 96 pnm ~md £6 pnt~ ~od 86 prim ~od 86 ~od 86 pnm ~od 86 pnu~ ~od 86 pnu~ ~od 86 pn~ ~od 86 (, ~£I) 'SL6I '9I X~ (,0Il) ~Ioq .9 SL6I '9T-~4. (, 0ZI) (, ~0I) (, 8II) (,88) , ~8I' 6-, 6~0'6 ~IOq .9 P~II.X~G ,6E0'6-,606'8 ~IOq .9 P~II!~Q ,606'8-.~08'8 ~Ioq .9 P~II!~G ,~08'8-,6A9'8 ,6A9'8-,I9S'8 9A6I 'II A~ , I9S ' 8-, 90~'8 ~I°q .9 P°II.X~(I ~. SL6I '0I ~X~ ,90~'8-,8I£'8'; ~[oq ,,9 P*II~..~I SL6I '-6' K~ Ma~ 18~ 1975 Drilled 6" hole 9,426'-9,520' · Reamed (94') ~ 96 pcf mud May 19, 1975 Drilled 6" h01e 9,520'-9,630' Reamed (110') 96 pcf mud May 20, 1975 Drilled 6" hole 9,630'-9,766' (136') 96-97 pcf mud '.Ma~ 21,'1975 Drilled 6" hole 9,766'-9,878' (112') 96 pcf mud 'May'22~'1975 Drilled 6" hole 9,878'-10,090' (212') 96 pcf mud May 23,'1975 Drilled 6" hole 10,090'-10,135' (45') · Lost 125 bbls. Circulated and added mica and plugging material and regained circulation. Drilled 6" hole 10,135'-10,226' (91') 95 pcf mud May 24, 1975 Drilled 6" hole 10,226 '-10,250 ' (24 ' ) Mud weight dropped from 95 to 92 pcf. Well flowing. Brought weight up to 95 pcf. Drilled 6" hole 10250 '-10,305' (55') Well flowing. Brought weight up to 96 pcf with lost circulation material. Shut in well. Casing pressure up to 18 psi in 15 minutes. 96 pcf mud May 25, 1975 Reamed 10,245'-10,305 ' '~ Drilled 6" hole 10,305' to 10,350' (45') Lost 34 bbls. mud to formation. Built mud volume. Drilled 6" hole 10,350-10,366' (16') Hole is taking fluid when drilling with 96 pcf mud and makes fluid when shut-in. Shut-in pressures are 150 psi on drill pipe and 250 psi on annulus. Circulated and built up mud weight to 101 pcf adding nut plug and mica. Lost 68 bbls. in 2 1/2 hrs. while circulating. .May 26, 1975 Began building mud volume. Added lost circulation material, mud weight is 102 pcf. Ran in hole with open ended drill pipe and attempted circulating. Lost 27 bbls. mud. Mixed up 108 pcf mud pill. Pulled into casing shoe and closed HYdril and choke lineo Well not flowing or losing fluid with heavy pill. 101 pcf mud .M...ay 27, 1975 Ran open ended drill pipe to 10,335' and pumped away 50 bbls. of mixed lost circulation material. Regained circulation at 1,930' with 2,000 psi and 80 pcf mud. Brought mud weight up to 101 pcf. Added lost circulation pill and pumped into lost circulation zone. 101 pcf mud '.May 28; 1975 Pumped 325 bbls. mud into hole, 230 bbls. at 10,242' and equalized with a heavy pill. 'Pulled up to 8,097'. Lost 10 bbls. (400 psi on stand pipe). Built mud volume and circulated and conditioned mud. 95-99 pcf mud ' 'M~y'29, 1975 Lost 12 bbls., then pit started showing a noticeable gain. Raised mud weight to 99 pcf. Mud system balanced.. Ran in hole circulating every 270' from 7,870'. Lowered mud weight to 95 pcf. Had slight flow back on each circulation. 99-90 pcf mud Max, 30, 1975 Increased mud weight to 97.5 pcf. System stabilized. Drilled 6" hole 10,366'-10,374' (8 ' ) May 31, 1975 Drilled 6" hole i0,374 '-10,470' 97-98 pcf mud (96') 96-97 pcf mud June 1, 1975 Reamed 10,435'-10,455' 200psi pressure increase. Circulated and conditioned mud. Mud cut 92 to 95 pcf. .. 'June'2, 1975 Added lost circulation material and got mud to 97.5 pcf. Reamed 10,434'-10,456' June 3, 1975 Reamed 10,456'-10,460' 92-96 pcf mud 97.5 pcf mud 97.5 pcf mud June 4, 1975 Attempted to cut core from 10,459 '-10,461 '. Recovered 1 ' of formation. Drilled 6" hole 1.0,461 '-10,473" (12 ' ) 97.5 pcf June 5, 1975 Drilled 6" hole 10,473'-10,526' (53') 97.5 pcf mud June 6,_ 1975 ..- Drilled 6" hole 10,526'-10,568' (42') '~ 97 pcf mud June 7, 1975 Drilled 6" hole 10,568-10,685 (117') 97.5 pcf mud June 8, 1975 Drilled 6" hole 10,685'-10,759' June 9, 1975 Drilled 6" hole 10,759'-10,780' (74') 97.5 pcf mud : (21-') 97 pcf mud June 10, 1975 Drilled 6" hole 10,780'-10,836' (56') M~de wiper run and circulated and conditioned mud for logging. 97 pcf mud June 11, 1975 Ran Schlumberger Dual Induction Log, Sonic Density and Caliper Log. 97 pcf mud june 12, 1975 Circulated and conditioned mud. Drilled 6" hole 10,836'-10,843' (7') Ran 2,860 of 5", 18# liner with top at 7,983'. Cemented liner with 545 sacks "G" cement. Only partial returns during second half of cement job. Pulled up and reversed, but got no returns. 97 pcf mud June'13, 1975 Tagged top of liner at 7,985, found no cement. Tested formation and it broke down with 2,000 psi. Set Baker squeeze tool at 7,785' to squeeze lap. Used 320 sacks "G" cement and displaced with 350 cu.ft, mud. June 14, 1975 Drilled out cement from 7,797' to 7,983'. Pressure tested lap to 3,000 psi, ok. Cleaned out cement to 8,002'. ~ 97 pcf mud .,June '15, 1~975 Cleaned out cement to 10,756'. Pulled and checked BOPE. 72 pcf mud · 'June '16; ' 1975 Ran in hole and retested lap to 2,500 psi, ok. Rigged up to run Go- International Cement Bond Log to 10,816' : 72 pcf mud 'June '17; '1975 Ran in hole and perforated 10,753'-10,769' with four 1/2" holes per foot. Made up Howco test tools and tested interval 10,769'-10,753'. 'FORMATION TEST: HFT ~1 10,769'-10,753' (June 17, 1975) Ran tester and set packer at 10,678' with tail at 10,700'. Used 1,100 psi Gas cushion. Opened tool at 1:50 PM. Gas bled off 2:55 PM with a medium steady blow for 10 hours and 30 minutes. Closed in at 12:20 AM Reversed out about 620' of Gassy Watery mud. Final shut-in 6 hours. · . ''Recorder '''IH IF FF FSI FH Top Inside 5,861 1,266 519 4,617 5,793 Bottom Inside 5,868 1,479 517 4,615 5,792 Top Outside 5,877 1,417 533 4,631 5,813 Bottom Outside 5,870 1,400 528 4,628 5~801 June 18, 1975 Cleaned out sand and mica from 10,740'-10,828'. Perforated 10,734'- 10,753' with four 1/2" holes per foot and prepared for casing test. 74 pcf mud June 19, 1975 · , HFT $2 10,769'-10,734' (June 19, 1975) Ran tester with packer set at 10,662' and tail to 10,684'. Opened tool at 11:10 AM had a light steady blow increasing to medium steady blow with fluid to surface at 11:55 AM and Oil to surface at 12:05 PM. Flowed well through 5/8" bean at depth and 1/4" and 3/4" bean at surface. Estimated 715 to 1,363 bbls./day flow. Closed tool at 5:10 PM for 3 hour final shut-in. 'Recorder IH IF FF FSI FH Top inside 5,802 167 1,512 4,506 5,802 Bottom inside 5,801 178 1,517 4,505 5,801 Top outside 5,830 194 1,532 4,523 5,830 Bottom outside 5,831 187 1;527 4,525 5,831 Set EZ Drill retainer at 10,695' and tested casing to 3,000 psi, ok~ 'June '20, '1975 Ran in hole and perforated from 10,665'-10,680' with four 1/2" holes per foot. Rig hands walked off job after setting EZ Drill bridge plug at 10,570, turning rig over to supervisors. 75 pcf mud .June '21, - 1975 Pulled 2 3/8" tubing off derrick and laid down 3 1/2" drill pipe. Shut well in at 7:00 PM. June 22 thru July 30, 1975 Shut-in .July 31, 1975 10" 5,000# Started up rig at 12:00 noon. Installed and tested Class III, , BOPE. .Augus.t 1, 1975 Ran in hole with 4 1/8" Econo mill on 3 1/2" drill pipe. Circulated out. ~Ugust 2 & 3, 1975 Ran in hole to bridge plug at 10,570'. Drilled out plug, circulated and conditioned mud for number 3 formation test. .~ HFT #3 10,629'-10,843' (August 3, 1975) Ran tester on 3 1/2" drill pipe and 2 3/8" tubing. Set packer at 10,628' with tail at 10,646'. Opened tool with weak blow which increased to strong in 3 minutes. Gas to surface in 10 minutes. Stabilized on strong blow throughout flow. Closed tool for 12 hours 2 minutes. Had "O" surface pressure. Backscuttled and recovered 10 bbls Gas cut mud with trace of Oil. Recorder ' DEPTH IH IF FF FSI FH Top Inside 10,605 5,774 : 8-~ 2~" 4,201 --- Bottom Inside 10,615 5,774 96 229 4,275 5,703 Top Outside 10,638 5,762 95 218 4,182 ~ Bottom Outside 10,642 .............. .August 4 & 5, 1975 Ran in hole and perforated four 1/2" holes per foot from 10,653'-10,639'. Prepared to test. HFT #4 10,598"-10,843' (August 4, 1975) Ran tool on 3 1/2" drill pipe and:2 3/8" tubing. Set packer at 10,599' with tail at 10,617'. Opened tool for 7 1/2 hours with average Oil flow rate of 310 BOPD and average Gas flow rate of 4,723 MCF/D, with 4.4% cut. Shut tool in for 7 1/2 hour build-up. · 'Recorder ''DEPTH IH IF FF FSI FH Top Inside 1--~,583 5,675 1811 3,777 Bottom Inside 10,613 5,687 1110 3,813 Top Outside 10,618 5,679 1118 3,815 5,659 Bottom Inside (clock was out of order) .A~gUst '6, '1975 Entered hole and milled out retainer at 10,695' and cleaned out to 10,818'. Circulated and prepared to perforate. August 7,'1975 Ran in hole and perforated four 1/2" holes per foot from 10,702'-10,722' and 10,608'-10,626. Ran scrapers to 10,818' and conditioned mud. 75 pcf mud .August 8 ~ '1975 Rigged up and ran 2 7/8" tubing, Hydro tested to 5,000 psi. Ran 50 joints !to 600' '~ · August 9, '1975 Completed running tubing production string as programmed. Ran Dresser Atlas Neutron Collar Log 10,500'-10,769', set packers and landed tubing 15' below derrick floor· Installed and tested production tree to 5,000 psi. Displaced mud with lease crude. August'10, 1975 Completed production string° Clean out mud pits and released rig at 4:00 PM. J. W. Wilson · ~ 6.~ i i i I i i IIll 4679' -up. k ', . Il Il I I Ill Il I I I I nB III II Il l[ I I Il I · - ~ KB to TUBING HANGEk (ORIGINAL) ,]-5.00' .TUBING ILANGER W/ COSASCO .50 3 PUP JTS. 2[" 6.5# N-80 ¢ 6.05: 6~5:8.,o'! 20.20' 7': JTS, 2~" 6.5~ N-80 8rd TUBING 1990' -~ [ . . 57 JTS. 2~" 6.5~ N-80 8rd ~BING ' i796.13' 13.00 ' 2~ N-80 [._. 28 JTS. 2~" ~.5~ N-80 8rd ~BING 872.78' - m _~ ,1 ' 11 JTS. 2~" 6.5~ N-80 8rd TUBING 347.63' C~CO ~ ~L 13.00' '. -- . '~ l'J 2z 6. N-80 8rd ~BING 31'.78' ......._ wiNoow I ~ JTS. ~. 6.5~ N-80 8rd TUBING 2685.98' , BRO~{ CC S~ETY JT, ' . . 107~4 . ~ 2~' C~CO 'D" NIPPLE 10769' - .- ' . ,~ 2 B~ST 3TS-. 3.062" OD (ZO. 51' ZO.3~')') 40.62' .... CASING 8T~BING DETAIL SECTION 5 T. T___~SMITT__~ AND ACKNOWLEDGEMENT OF RECEIPT OF MATERIAL - (ALASKA) TO: DEPT.: PLACE: Mr. T. FL Marshall State of Alaska Division of OI! & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 DATE 3-' ,7~' 7~' FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY WELL HISTORY ! LOG 2" 5" I I i66 .~06 AU~ 2 ? 1975 DIVISION OF OIL AND GAS RECEIVED BY · >:~'~ RE ON OTHER SIDE, THIS Si4E'ET BY TRA~NSMITTAL A~'~ - ,,-' CK~IO~LEDGEMENT OF RECEIPT OF I ERIAL (ALASKA) DEPT.: FD - Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF FLATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. COMPANY H . ,, I I WELL ISTORY LOG 2 5 O .... O0 I O 2 · 4-9 __ REMARRS O~//OTHER SIDE, THIS SHE-ET Form 10-403 REV. 1-10,73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STAT E 0 F A LAS KA OIL AND GAS CONSERVATION COMMITTEE WELL I.--J OTHER SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Standard Oil Company of Californiar WOI 3. ADDRESS OF OPERATOR P. O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1840' North and 595' West of the SE corner Section 5, T7N, R9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 167 K. B. 14. CheCk Appropriate Box To Indicate Nature of Notice, Re i5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. A-028996 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Soldotna 9. WELL NO. 43B-5 10. FIELD AND POOL, OR WILDCAT Swanson River 11. SEC.,T., R.,M.,(BOTTOM HOLEOBJECTIVE) Sec. 5, T7N, R9W 12. PERMIT NO. 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL MULTIPLE COMPLETE ABANDON* CHANGE PLANS FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Suspend (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Drilling operations were suspended on June 20, 1975, as a result of the labor strike. The 5" liner had been cemented at 10483', top at 7985', and the interval 10665 - 680' which had been perforated for testing were isolated with a bridge plug at 10570'. The hole stands full of mud. OiL AND GAS A?',',CHORAGE 16. I hereby certify that J~e foregoing~is t,~ue and correct (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: Area Engineer TITLE DATE June 30, 1975 TITLE DATE See Instructions On Reverse Side FGrTn ~To~ P--4 ]~'V, STATE OF ALASKA SUBMIT I~ DLrF?LICATIg OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS :J. NAME OF OP]RRATOR Standard Oil Company of C~forn~a; WOT 3. ADDRESS OF OP~I{ATOR P. O. Box 7-839, Anchoraqe, Alaska qqq] 0 4 LOCATION OF WF. LL 1840' North and 595' West of Southeast corner of Section 5; T-7N, R-9W. SB&M ~PI NUA. IERICAL CODE 50-133-10115-01 ~ LF. ASE DESiGNA'i'ION AND SERIAL NO. A-028996 IF INT)iA],~ ALO'i'T~E OR TRIBE NAME Soldotna Creek 9 WELL NO SCU 43B-5 10 FIELD A~D POOL, OR %VILDC~Kq' _Swanson River - Hem]oak ~zl SEC. T.. R. M ~O']"I'OM HOI~ Sec. 5; T-7N, R-9W, SB&M 1~ PIeR,MIT NO 75-15 13. REPORT TOTAL DEPTH AT END OF MONTH. C1;-La.~'qGF_.S iN HOLE SIZE, CASING ANT) C]~NIF-2qT!I~G JOBS INCLUDING DEPTH SET AN'I)VOLLrlVIES USED, PEI:CFORATIONS, T'Ie~STS AaN"'D IR/ESULTS FISHING JOB,~ Jt.,CNrK IN HOLEAND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CYH. A. NGF~q IN l~IOI~ CONDITIONS May 1975 Bridged hole with 94 cu. ft. of class "G" cement in two stages from 9620' to 10562'. Pressure tested 7" casing ok to 9620' under 3000 psig. Milled window in 7" casing from 8190' to 8231'. Bridged hole with 93 sacks of class "G" cement from 8170' to 8330'. Drilled out cement from 8170' to 8194'. Directionally redrilled 6" hole from 8194' to 10470'. L~t and regained circulation with lost circulation materials at 10135' and 10350'. ANCHORAGE 14. I hereby ~ertify that the ~oregoing NOTE--Report on this form is required for each eolendar ~nth~ regord!~s o~ th~ ~tus .f o~ratio.~, and mustard I. duplicale wit~ t~ oil Qnd gas Gonlervation commiffee bythe I~ of the suc~Ndiflg mnn~, ~1~ ~therwil~ ~r4Gted. I~ECEIVED' . ~ ,'teE OF THE OIL & GAS SUPERVISOR: ~ ~o. P-~ STATE OF A~KA OIb AND GAS CONSERVATION SUBMIT I~ DUP. LICA'I~ CONSERVATION ' DtVISI~XI~ ...... GEOLOGICAl. SUR~/''~!11'11'1' REPORT OF DRILLING ~O~G~, ^~sr,/~ND WOR'KOVER OPERATIONS API NUAqERICAL CODE 50-133-10115-01 g LF~SE DESiGI~A~ION AND SE.RIAL NO. A-028996 WELL %~I~LL OTHER 2. NAME OF OP~I. ATOR 8 L~IT ~A. rCM OR L~ASE N~ Standard 0il Company of california, WOI Soldotna Creek 3. ADDRESS OF OPhiR 9 WSLL ~O P. O. Box 7-839, ~nchorage, ~laska 99510 8~ 43B-5 4 LOCA~ON OF W~ 10 FIF~D A~D P~I,. OH XVILDCAq' Swanson River - H~lock 1840' North and 595' West of Southeast Corner of Section 5, T7N, R9W, SB&M SEC, T., R. M (I~()TTOM HOI~ OBJEC~ Sec. 5, T7N, R9W, SB&M 1~. PEF,~IT NO 75-15 13. REPORT TOTAL DKPTH AT END OF MON~'I/-I~. CHA.NG,ES IN HOLE SIZE, CASING AND CEMF2qTING JOBS IN'CIA;DING DEPTH SET ~ VOL~ USED P~O~TIONS, ~STS ~ ~SULTS FISHINrG JO~ JUnK IN HOLE AND SIDE-TRACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ CONDITIONS · 'April, 1975 Commenced ..work 8:00 a.m., April 25, 1975. Killed well with 83 pcf mud. Removed xmas tree. Installed Class III BOPE and tested OK under 5000 psi. Recovered all of tubing. While attempting to recover Baker I~odel D packer, found 5" !~ner in bad order at 10,549' Unable to recover packer. 14. I he.by ~ify oil .nd g.s con~erv.tJon commiffiee by t~e 15~ of the ~u~c~ding Febr~aary 13, lg75 ~idotna Creek Unit ~4~-5 Standard Oil C~any of California Permit No. 75-t5 ~. R. ~Kintey Area ~gineer Standard Oil Co. of Calif. P.O. Box 7-.839 ~chorage, Alaska 99510 ~ar Sir: Enctesed is the approved application for permit to drill the above referenced well, on or ab~t February 20, Ig75 at a location in Section 5, Township 7~, ~n~ ~, S.M. Well sables, cort chips, and a ~jd log are not required. A directional survey is ~qui~. ~ny rivers in. Alaska and their drainage systems have been classified as important for the s~ning o~ migration of anadromous fish. Operations in these ar~as are subject to AS 16.50.870 and the regulations promulgated there- under {Title 5, Alaska Administrative Code}. Prior to commencing operations you ~ay ~ contacted by ~ Habitat Coordinator's office, Department of Fish and Game. Pollution of any wa~rs of the State is prohibited by AS 46, Chapter 03, Arti. cle 7 and tP~ regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chap~r 70) and by the Federal Water Pollution Control Act, as amended. ~ior to commencing operations you may be .contacted by a representative of the ~par~t of Environnmntal Conservation. This pemit is approved subject to receipt of final casing weight and grade s~cifications. The re~rds of the Division of Oil and Gas will now reflect that the portion of the original hole down to the .point of side-tracking and the new hole drilled below this point will be identified by the redrill designation. As a result, a Fora 10-407 or a Form. P-7 must be submitted reflecting the abandonment of thru original hole. Very truly )~u~, O. K. Git breth Chai~n Alaska Oil and Gas Conservation. Con~tt~ Mr. R. McKinley- 2- February 13, 1975 OKG:bjm Enclosure cc: Depar~nt of Fish and Game, Habitat Section w/o encl. Depar~t of Enviro~ntal Conservation w/o encl. Department of Labor, SuperVisor, Labor Law Compliance Division w/o enci. lO'-- 401 I--I--71 STATE OF ALASKA OIL AND GAS CONSERVATIO'N ,COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE O~' WORK DRILL [] Redrill WELL WELL OTHER SUBMIT IN TRIPL~ (Other instructions reverse side ) DEEPEN ['-J SINGLE ZONE MU I,TIPI,E ZONE 2. NAME OF OPFARATOR Standard Oil Company of California, WOI 3. ADDRESS C~ OPERATOR P. 0. Box 7-839, Anchorage, Alaska 99510 LOCATION OF V~ELL At surface 1840' N and 595' W of SE corner, Sec. 5, T7N, R9W At proposed prod. zone 1840' N and 180' W of SE corner, Sec 5,T7N, R9W 13, DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approx. 15 miles to KENAI 14. BOND INFORMATION: Statewide - 451636 APl #50-133-10115-01 6. LEASE DI[ESIGNATION A/VD SI/RIAL NO. A-028996 7. IF INDIAN, A_LLXDTTEE OR TR/BE NAME 8. UNIT, FARM OR LEASE NAME .qaldotna creek.,,, unit 'il ~VELL NO. 43n-5 10. FIELD AND POOL, OR WILDCAT Swanson River !1. SEC., 'J'.. R.. M., IBOTTOM HOLE OBJECTIVE~ Section 5, T7N, R9Wt SBM 12. $100,000 TwPENationwide Surety and/or No. SL6205862 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 595 ' 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 105' 21. ELEVATIONS (Show whether DF, RT, CH, etc.) 167 K. B. il0. NO. OF ACRES IN LEASE 480 ~. PRO~OSm 10863 ' 150,000 17. NO. ACRES ASSIGNED TO TltiS WELL 80 20, ROTARY OR CABI.E TOOLS Rotary 22. APPROX. DATE WORK WILL START* Feb. 20, 1975 PROPOSED ?ASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI)E S~I~rlNG DEPTH quantity of cement r, Z~~ d~, ! ; .... , : .... ~', ..... ., u,- ~ ./, ..... . ~ , ,, , ,~, ,, , , , ~ .... * We propose to redrill existing well 43A-5 per attached program; well is to be redesignated 43B-5. DI\,:!31ON C,F OiL AND 0,%5 ~w prddu~ive ~ne. 1~ ArO~'i is m ~rHl or e~n d~ect~onally, glve p~rtment ~' on s~bsu~a~ ~tm~ ~d -ve~icaldept. Giv-e-bi~ prev~0ter-Program. - '- sm~_' ~,~ January 27, 1975 m~ Area anq~eec (This space fo~ S~te office u~) / CONDI~ONS OF ~PROV~, IF A~: DIRECTIONAL SURVEY [] NO MU,D LO'C; [] YES ~NO See Transmittal Letter A.P.I. NUMEI~CAL CODE ~O - i~...-3 -/o 11,5"'- o / February 13, 1975 APPROVAL DAT[: /"~' '*~ I..uctio., On Reverse Side February 13, 1975 ' PROPOSAL FOR WELL OPERATIONS PRO 316-1~ REWORK PROGR/~ Field: Swanson River PROGRAM C. N. Sngr,ar ?rop~r~ty and Well: SCU 43A-5 (to be redesignated 43B-5) ~Existing Surface Location: 1840' north and'595' west of southeast corner · of Section 5, T7N, R9W, SB & M. Existing Bottom tlole Location: 140' north and 115' east of surface loca- · tion at K0P of 8700' for 300' stepout. ~op0sed Bottom Hole Location: 140' south and 300' east of KOP. Total Depth: 10,680' · ~asin~: 20" cemented at 20' Plu~: 10,680 - 10,632, cement · 11 3/4" cemented at 1990' 7" 23#, 26#, and 29t~, N-80 and P-110 cemented at 10,310' (top of w~ndow) 574' - 5" 18#, N-80 cemented at 10,677' (top at 10,103'), squeezed at 10,603'. · . ' ' 7" Casing Detail ' -. ~e Top 6 Joints Next 22 Joints Next 87 Joints Next 42 Joints Next 42 Joints X-Over Next 40 Joints · ~ 0 - 253' 253 - 1206' 1206 - 4879' 4879 - 6681' 6681 - 8471' 8470 - 8478' 8478 - 10310' 29~ Buttress 26# Buttress 23# Buttress 26~ Buttress 29# Buttress Buttress to L8R 29# L8R Perforations: 4 1/2" holes at 10,603' (squeezed) 4 1/2" jet holes/foot as follows: 10,592 - 10,582', 10,578 - 10,572',.10,565 - 10,554', 10,538 - 10,508', ~0,491 - 10,484', and 10,461 - 10,454' Junk: Original completion SCU 43-5: 7", 29# casing cemented at 10,852' (top at 10,350'). $CU 43A-5: Tubing is parted below Model "D" packer at 10,567'. Fish consists of approximately 26' of 2 3/8" N-80 tubing. ~Tubing_ Detail: Per attached'detail. Tubing is parted below Model "D" packer at 10,567' and may be parted between packers at 10,567' and 10,544' Sliding sleeves at 10,497' 10 541' · , 0 , and 10,559' are open. Shoe is open. Proposal for Well Operations PRO 316-1 R~work Program · Blowout Prevention Considerations: Potential Problems Ao Gas PROGRAM C. FI. S :9nar .o Gas may be encountered after packers are released, while fishing ... and cleaning out the 7" casing prior to abandonment, and while redrilling. Care must be exercised at all times not to swab the well during trips or when pulling production equipment. Gas entries will most probably occur within the Hemlock Zone. Hemlock fo~ation pressure could be near 4800 psi. ~.The.programmed mud ' weight of 72 psi prior to redrilling the well will overbalance " .... the potential reservoir pressure of 4800 psig by 425 psi. · B. Water Entries -. · Extreme caution must be exercised while redrilling this well. A mud weight of 96-98 pcf is required to overbalance potential high pressure entries while redrilling the well above the Hemlock. This well was originally drilled with 96-98 pcf mud without .... problems. · C. Lost Circulation 'The Programmed mud weight of 96-98 pcf is the lowest which can be used to maintain an adequate pressure overbalance on the interval above the Hemlock. However, because of lower forma- tion pressure in the Hemlock, lost circulation could occur. While drilling well SCU 42-5 in the Hemlock No. 5 sand with 96-98 pcf mud, lost circulation did in fact occur. As a result, ~t was'necessary to redrill a portion of SCU 42-5. D. PrecaUtions Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods and care should be exercised at all times by every crew member. The hole must be kept full at all times. 2. Maximum Anticipated Formation Pressure: 4800 psi in the Hemlock. 3. Maximum Possib!e Surface Pressure: 4000 psi. 4. Blowout Prevention Equipment As per "Operating Instructions D-17." Class III, 10" - 5000 psi for all work. Proposal for Well Operations PRO 316-1 Rework Program NPPROVED i' P.R.OGRAM Datuz~._____-. Take all measurements from a point 15' above ground level, the original K.B. elevation for SCU 43-5 {167'). o . PROGRAM 1. Prior to rigging up, open "XA" sleeve at 10,412'. Check casing-casing ~"mulus for pressuro.' . · 2. move in rig and mix 72-74 pcf mud. .. · 3. ~11 well by displacing mud down the tubing, out the sleeve at 10,412' and up the tubing-casing annulus. · 4. I~nStall Cosasco back pressure valve and remove the xmas tree. 5. ~ipple up 10" - 5000 psi Class III BOPE including 5000 psi blow and kill lines. Refer to attached BOPE detail. Pressure test all BOPE ~ndmanifolds to 5000 psi per "Operating Instructions D-17." Remove · Cosasco plug. 6. l~elease packers at 10,415', 10,500', and 10,544'. Pull production equipment from above parted tubing. Examine production equipment for damage and note depth of damaged tubing. Pull tubing slowly to sm~nimize any swabbing. .. 7. Recover tubing and mill over and recover Baker Model "D" packer at 10,567'. Clean out and drill out cement to 10,665'. ~lote: If entire tubing string cannot be recovered, supplementary pro- gram will be submitted before further work. 8. Perforate the 5" liner with four 1/2" holes/ft, from 10,650' to 10,625'. 9. ~ake formation test of the interval 10,650 - 10,625'. · · Proposal for Well Operations PRO 316-1 Rework Program ~ PROGRAM ' '" . N. Segnar 4 &. Use'one 24-hour and one 48-hour clock inside and one 24-hour and one 48-hour clock outside. Set packer in blank between 10,625 and 10,603'. Flow period to be long enough to determine fluid content of zone. Shut-in period length to be equal to flow period length. ~{ote: a. If test is clean, then proceed with this program which is · for a 300' easterly stepout for H8 completion. b. If test is 50%+ wet, then directional details as per Step . NO. 7 will be revised for a 500' stepout in lieu of 300'. =. If test is wet, then do not proceed past Step No. 15 until further notice. ~ · · 10. A~ter diagnostic test is made, equalize cement plug in stages, if necessary, from effective depth to 150 ft. above top of liner. Down- squeeze, leaving top of cement at least 50 ft. above top of liner. .11. Run bit and locate the top of the cement plug. If plug is below 10,053' ' · recement. - 12. Pressure test the 7" casing to 3000 psi (rig pumps) for 15 minutes. -o "~1'3. -"~Condition mud '-to '96-98 pcf. 14. Mill a 40' window in the 7", 29# casing from 8700' to 8740'. Casing ~ollars are located at 8635', 8677' and 8719' , - 15. Plug the 40' window and 7" casing with sufficient densified Class "G" cement (126-129 pcf) to leave top of plug +150' above the top of the window. Dow~squeeze, leaving top of plug +50' above top of window. 16. Drill out cement plug to below top of window. 17' Sidetrack original hole and directionally drill 6" hole to 10,819' TVD, estimated 10,863' ~.~. A directional plat will be furnished, but target is the Basal H8 point deviated 331' from the kickoff point along a southeast course. Not.___~_e: Continually moniter mud system for either high pressure fluid entries or lost circulation. Lost circulation is most apt to occur below the top of the Hemlock, estimated at 10,4.59' MD. 18. At TD, condition mud for logs. Obtain a 1/2 gallon sample of drill- ing fluid before pulling out of the hole. 19. Run Schlumberger 'Dual Induction Laterolog with SP, Microlog, BHC Sonic with SP, and Compensated Neutron - Density Log from TD to ~e 9" casing. · · Proposal for Well Operations PRO 316-1 Rework Program -. · I, iROGRAM a. Use linear Scale for 2" DIL and logarithmic scale for 5" DIL. USe +10 MV SP scale and 6-50 ohm-meters for the linear DIL. 20. Cement approximately 2900' of 5" liner at ~otal depth with sufficient Class "G" cement premixed with 3/4% CFR-2 to obtain returns above top of liner. Equip liner with 5" x 7", 29# Burns liner hanger grooved for cementing. Allow for 200' of liner lap. a. Run float collar and float shoe. Float collar is to be two ~oints above shoe. '< .... ~'$. Liner detail to be'Provided, ~ 21. Clean out cement to float collar. · , 22. Run variable density cement bond - neutron - collar log from effective depth to above top of liner hanger. 23. Pressure test 7" casing, 5"'x 7" lap, and 5" liner to 3000 psi for 15minutes. ' '-2~. "Condition mud weight ~o'72'74 pcf. . · . 25. Jet perforate Hemlock 8 sand inter~als for production. 26. Run tandem 5" casing scrapers and scrape the entire 5" liner.. 27. Run and hydrotest to 5000 psi 2 7/8" x 2 3/8" tubing, gas lift mandrels, and completion jewelry. A detailed completion program will be provided after TD logs have been run. 28. Remove BOPE and install xmas tree. Pressure test tree to 5000 psi. Displace drilling fluid down the a~nulus and up the tubing with lease crude oil. · 29. Set production packers and release rig. Place well on production as directed. B. A. Dakessian O/S December 9, 1974 Area Engineer O/S December !0, 1974 Area Supervisor DRILLING FLUID PROGRA/4 REWORK SCU 43B-5 SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Medium treated Lignosulfonate mud. · · DRILLING FLUID PROPERTIES PROPERTY weight - pcf .Viscosity - sec/qti, API .Fluid Loss - cc, API Plastic Viscosity - CPS ~ield Point - Lb/100 ft2 Gel - Lb/100 ft2 - 10 min Calcium - PPM ,~olids Content - %_ Vol Diesel Content - % Vol · IN 7" AND 5" FROGRAM ~C:. N. Segnar --. ~-- WHILE REDRILLING 72 -- 74 96 - 98 43 - 47 :, 43 - 47 4- 7 7 - 10 (See 3) 10 - 14 20 - 30 8 - 12 8 - 12 0 - 5 10 max. 9.5 8.5 - 10 50 max. 50 max. 6- 10 l0 - 18 6-8 6-8 .. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. 2. Maintain adequate supply of barite and LCM on location. 3. }~intain fluid loss between ~ and 7 cc below the top of the Hemlock] o ~ PUB JTS, 4 J~. 2~" .%..~ EUE TUI3iliG OTIS TUDi~IG REI.~¢;J~LS DALL VALVE · ~5 ;;TS. 2~" Etd EUE TUDi~C, ~. C~':CO 1¢,.I Ma'D~L ,. '?~ Srd EUF, TUBING , . 18.07' 129.01' , 1709.'/2' 13.13' 1492.92' · 12.9~ 1130.29' 12.95' 12.99' 529.47' 12o62' 403 o67' 12.88' 222o25~ 12.96~ · 8 ~TS. 2%" Srd EU~ TUBING .... '199' JTS~ 2~" 8rd Eb~E TUBLUG 31~5~29' ~ :~os~o' --"::" ":':'=' > 2~" x 2~" X~~ ..... ''... '.- 1.15' f - . 15 ~S. 2~" 8rd E~ TUS~IG 4~.91' ' ~ ~,~.,. ' ' .'( ":-~'..:....3 P~ ~fS. 2~" (8.0~ 10.05 1.10) 19.20' ~ ~ ~ ~ ~ ~ ~ '- :-?' "J:~ ~'",t:':-' "B~R B~T JT..3,0~" OD ' '-:I~ ~'.~'"- ~o,~.u,J:, ~, ~ r~P~'s._a, (~.~ :.0s,) '~.~, ! ~ i .... ~o,4~.~,~ ~:~:~,,~"~:. ~:", · .....--.. : f~ -,o:3,-- 10 c-O ~,~ . -' " . 3.062 OD 33.Z~ ~ · ' '~ I1~' Il '~ '~ ' ~ II ~ ~ ~ .... 1o,55S.71, ~ I ~;~ ~~ ~i'. 3;0~', ~ ' ' '~ I~ ~' "~ 10,565°59~ I ~H BL~%%' ~. ~.062" ~ ' *-OO, .,. o~ ~ ~,o,,, / ~?s~,m~ FO~ 2.~oo ~o~z..c~. D ~ ~.~, <,, ,, _/~.~K_.~--~ ~ 10 632' ~ T""ur SC · . .. SECTION 5, T. YN.,R.9W. · · · ...... -., : .... :: , _ f..o. ~'w ' ,.9tt,~ FF£/?, .oo . · · .j I · ._I ......... r .~- ~.e/oreor · I ; .! ~, ii . 't ,""(JHECK LtST~::~F. OR- NEW.WELL PERMITS:" .'~-..' .-.. .... -.- ..¥ .... ~ .~.~:,....:.,..-...... ~omp~anY .... ~:,'-.,..:::.''''' I:' ~'''~ Lease · ?:..:~:~.:.~:':"-' ' ' ' .:'..:'~?.,~."....,.i .... ~---::'.:.:.' .'. : .:-.'-:..?~.~'~ .... :.:'~... :'.. ~. '~.. ]~: ~ .?.:.:: ,::.?... ..:.'-..':- :." .? "..: ...... ~~es ~ .No Remarks:_, . ~:-' ..~.,,. .... . . -.., ~. ::~':"~"'~" m ' pe~i.t~ ee at%ach, ed:'~;- ",':;::'.~: ~'~;.. :.~ ,~,. :~:~:''~' ~' ~',- . ....:..~..,. ~.,,.,,...": :-'~'' - -. _'].~:,;~,.~._- "- --~ : ",':,.'~:?~ ......... - .... ...'- - ':L.,:.;.:??..::,.-.~-.:...~; ' . ' .. . . . .'~ . . · . - IS well t'o 'be located in a defined poo-I ........... -. . ...... - ......... ~ . . 3 Is a regi~stered survey plat-attached ..... - ? .......... I, Is well located.proper .distance from property line 5. I.s well located proper distance from other wells . · ....... 6. Is sufficient undedicated'acreage available in thi~ ~ool ...... .~i ~-~Is well to be deviated - . ............. _ . 8. Is operator the only affected party .............. 9. Can permit be appr. oved bef.ore ten-day wait ............. h/~. O. .Does operator have a bond in force I. Is a conservation order needed ................... ~ 2-. Is administrative approval needed ................. 3. Is conductor string provided .................... 4. Is enough cement used to circulate on conductor and surface .... 15/"-Will cement tie in surface and intermediate or production strings . ,, 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequa%e safety in collapse, tension & burst 19, Does BOPE have sufficient pressure rating .............. Approval Recommended' Geology Engi neeri ng' TRM ~ HWK X/~~ ~)KG HHH JAL LCS, ~A--..'~JCM . .................. ~ Revised 1/15/75 f- Well Histo.ry File APPENDIX Information of detailed nature that is not partiCularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically organize this category of information. S A R A ~3 A N D ,,,;'1" A T F; l~w ARHA ~' AT Dtt'p T H ?,,;. 70. 6o, 6o. O. O, : 0,1]0 o.150 0.800 0,25~ 0,000 0,00 10840, io,~g2. I045g, I04,30 O, ' 0 0. 0. 0. O. 0 ,, 0, 10582, 1045R, I0430, 0, 0, 0, DT~,A AHRAY 2.65 2.b5 0.00 0.00 0.00 0,0 ss.s ss.s o.o 6.0 6,o 6' o.ooo o.ooo n.ooo o.ooo o.oo 1 n,l ~r). o. o. o. o o o o 1 o o t o o 2 o o o o o o i o o o o · , INP{.~T F'ARAt~ETI~;I.~S I*Rt)~l 10430, TO u212, 1].:; 0,50 6,00 166, {0~40. ~0. ~,40 65, 0,999 0~996 0 O. O. 2,84 0.~0 108]0, ~J2i2, 0,000 1,00 0,000 3,70 20,00 0,2 ,2oo o,ooo ,~o o,.]o 62soo, 6,o 2,o 34o 0 ~ 0,250 i2], ,0~5 5~, 2~, 16, 8I, 150, i.50, 0,69 0,00 0,4.] 0o.~2 4.~ ~ooo.o o.ov 6.~ O'~o o SP ~TAT1STJCS [)VEI-~ F:.~TIR~ I~Ti£RVhI, BE$ISTIVITY STATISTICS OVE~ E~{TIRE INTERVAL F E E T POLOS % 8278,0 827q,0 8286,,0 8290°0 82~1.0 8292.0 829].0 8296.0 8470.0 8471.0 8473,0 8475,0 8478,0 8479,0 8480°0 8481.0 848~,0 8508,0 8509,0 8510.0 85tl.0 8546.0 8567,0 8588.0 8589,0 8590,0 8591,0 8592.0 8593,0 8594,0 ~644,0 0.~ (). 4 0.0 0.0 O. 1 0.~ 0.0 0.0 0.1 0.0 0.0 0.0 l) ,, 0 0.0 0 o 0 0.0 0.0 0,1 0 ,,,b 0.! 0.0 0.0 0,0 0.7 0,,7 0,4 4.7 4.4 3,,,3 5.3 0.0 0.0 0.1 6.5 7.5 O, 3 2,5 2.0 7.1 lOO ! O0 1 O0 10o IO0 100 1oo 1 oo 95 !oo 1 oo 1o0 I oo 1 oo 1 oo 1 oo 10o 100 100 100 lO0 I00 100 100 100 1 O0 { O0 100 !00 100 !00 I oo ! oo 46 47 41 44 5O 2,91 2.66 2o5i 33 80,64 49 eo. 47 47 44 4 7 7 {~ . 4 7 1 2 , .) 7 _ ' · % 8647, 864~, 8649. 8650, ~686, 8q70, 8972, 8977 , 8978, 8984, 8986, 8992. 8993, 8994, 9027, 9028, 9038, 90~0. 9040, 9041, 9042. 904]. 9044, 9045, 904~, 9047, 9048, g049, 9050. 9051. 9052. 905~. 9054, 9055, 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.~ O.b 0.1 0.0 o 6 0 . 7 0.I O. 0 0..0 O. 0 O. 0 f). 4 0.4 0.1 0.0 0.0 0.0 1 O. 4 {3.0 0.0 0.0 0.0 0.4 0.5 0.2 0.t 2 0.~ 0.~ 0.~ 2,~ 13,0 0 0 8 ,4 .0 ,9 ,4 .4 .0 ,6 ,7 ,9 13,5 8,7 1.3 0,6 6.6 11,9 14,0 12,4 10,2 i4,0 i6,4 12,4 15,5 12,7 10.6 80 lOO 1 o o 1 oo 1 o 0 lOO 1 oo lO0 1oo 1oo 1 oo lOO 10o 100 1oo 1oo 100 I oo 1oo 100 100 100 l oo loo 10o 100 lO0 t00 lO0 loO i o o ! oo loo !oo 4O 44 40 77 76.85 76.77 4.5 4O 49 76 76,01 49 50 47 45 75,77 75 43 75.41 48 45 48 74,§0 74,3~ 12,90 4.23 4 40 37 01 73, ;~{,-34 0 72,78 41 49 01~ p T H 9056,0 9124,0 91.17.0 9119,0 9140,0 9141,0 9142,0 9144,n 9145.0 9146,0 9i4'?,0 9150,0 915!.0 9152.0 9!53o0 9156,0 9157,0 9158,0 9159,0 9161,0 9162,0 g163.0 9164,0 9165,0 9j. 66,0 9167.0 9168,0 9169.0 9170o0 917i.0 9271,0 927~,0 9273,0 9300.0 9]0!,0 9302.0 9303,0 9]04,0 9305,0 0,0 O, ] 0.5 2 1 0,0 0.0 0.0 0.0 2 0.3 0.? I 3 4 0.6 O. b 0.! 0.0 0,0 0,7 ! 0,1 0,0 0.0 0.4 0.? 0.5 0.;{ 0.~. POROS!TY % 11,4 12,5 14.5 14,4 16,0 14,0 14,7 11,6 10.5 14,3 !.4,9 14,B 12,7 II,~ 6,5 12,8 9,3 7.9 12,4 I~.4 % lO0 .I. O0 100 ! O0 1 O0 1 O0 1 O0 ! O0 !O0 lO0 1 O0 I O0 ! O0 100 100 1 O0 100 100 100 100 100 100 1 O0 100 100 100 1 O0 lO0 100 100 t00 100 100 100 100 100 100 VOLU~E % FEET 49 ?l.95 47 4 3~ 11-45 I,!6 O. ?0 70,51 ?0.3~ o.o? 40 69,79 68,02 41 63 4o ss 44 67.4t 5O ,8¸3 66 *~ 65 4~5 65 DEPT~-! FEET SAT. % CLh¥ 9306,0 9308,0 9]09,0 9310,0 9]I1.0 9317o0 93i5.0 9316,0 911~,0 9319,0 9120,0 9121o0 9123.0 q]24,0 944?.0 9448.0 9451,0 9452,0 9454.0 9455,0 9456,0 9457.0 9458.0 9459,0 9460,0 94~2.0 9463.0 9464.0 9465.0 9459.0 9470.0 9471.0 947~,0 9481.0 9482.0 0.4 0,t 0.7 t 0.9 0.7 0.4 0.5 0.5 0.! 0.! 0.2 0.~ 0,4 0.6 0,4 0.7 0.~ 0.0 0.0 O o 0 O, ? 0.4 0.1 0.0 1 tl,6 il,6 It,1 10,~ 1t,6 13.1 12,2 13.0 13.5 13.3 12,9 1!,6 11,6 t2.2 9,9 !0,0 10,6 11,1 11,6 11,0 14.6 16.1 7.5 0o0 5.0 11.1 11.9 11,7 !1,6 7,0 14,~ 1~.7 100 100 1 O0 100 100 1 oO 1 O0 1 O0 100 10O ! O0 1 O0 1 O0 100 1 O0 I00 1 O0 100 100 100 1 O0 100 !00 100 ~7 t00 I00 100 1 O0 I00 100 I00 100 100 100 1 O0 70 10o 42 ~7 4O 41 65,0! 4. 64.54 · 12.89 ' 46 4O 45 47 47 50 64 27 64:t4 64,00 63.51 12, t2. 11~'89 2,B9 a9 61.43 49 61,31 I2,~9 46 60,97 t2.89 4s 46 60,61 12. ~9 42 60,48 12,89 · i! 44 9 84 9,06 58.09 i~.83 DEPTU FERT % VObU~E PO 9484,0 9485,0 9486,0 9487,0 948B,0 9489,0 9490,0 9584,0 9585°0 9586,0 9587,0 9597.0 9598,0 9599,0 9601.0 9620.0 9621,0 9622.0 9626.0 9~43,0 9644,0 9687,0 9691.0 9692,0 9693.0 9694.0 9695.0 9700.0 9701,0 9702,0 9703.0 9704.0 9705,0 972~.0 9723.0 9773.0 9774.0 O, 6 0,4 O. 1 0.0 0,0 0.0 0.2 O, 1 0.2 0,0 0.0 0.0 0.0 (t.4 0.4 0.4 0.~ 0.2 t), 5 0,~ 0.! 0.0 0.0 0.0 O. ,t 0.2 O, () 1 0.5 0.3 0.~ 2.0 2.4 0.1 ~o.~ 3.1 0,0 0,0 1,I 1.1 2.2 0.1 7.3 0.1 1,0 1.4 0,7 0.0 ~,7 3.9 2.2 1.6 I00 100 100 100 iO0 lO0 100 100 IO0 100 100 1 O0 1 O0 100 1 O0 1 O0 ! O0 t 00 !00 I00 1 O0 lO0 100 I00 100 100 100 3¸9 7,69 57.45 57.~2 4-7 56 ~ 4I 56, . 47 55.83 40 55 75 47 55.74 49 55.55 48 55, O0 48 5~,~0 4 9 54.68 5O 54.47 47 2¸7 54,26 · . 03 53.88 43 46 44 47 53.88 53,75 52.7i 52,52 {) E P T H · EE'I N D % 8AT, ~{YCARB CL A Y C .! ~4. 9775.0 0,3 11,4 0776,0 0.~ 11.1 100 9777,0 0,~ IO,H 100 97B1.0 0.! q,9 100 9782,0 0.1 10,3 I00 9783.0 0.~ 9,4 100 9784.0 0.1 q.~ 100 07B6,0 0.0 H,4 100 97B?.0 0.! 8.0 100 97~8,0 0.1 O,H I00 9789,0 O.i 10,0 t00 979~.0 9793.0 9820.0 9821.0 Ol 7,4 7,4 6.,8 2.,I 100 100 100 100 lo0 !.O0 9927.0 0.0 0,9 902~,0 0.0 ~.? 100 9~29.0 0.2 10,? 1.00 qU30,O 0.1 9,1 I00 g831.0 0.0 ~.3 ~00 9~3~.0 0.1 9,5 lO0 9~33.0 o.2 iO.a t00 9834.0 0.1 9,9 I00 9~3~,0 0.1 10,3 1o0 g~3b,O 0.~ 13,2 100 q837.0 O,q 1],4 100 9B3H,O 0.3 il,7 I00 9900.0 0.0 8,2 100 9901.0 0.0 ~,5 100 lO01i.O 0.,~ lO,O 100 100t2.0 0.3 11,4 100 I0013,0 0.3 1i.2 100 100t4,0 0.? i0,4 lO0 i0015.0 0.2 10,5 100 10016,0 0.1 10,1 lO0 10017,0 0.1 9,7 i00 8,9 lO01q 0 5 I00 49 51,67 J~.76 4B ~1.57 1?~,76 50 51,3f{ 12.76 49 46 5-0.60 I~.76 40 50,06 I~.76 39 ~0,02 12.76 40 40,83 I2,76 , 12,76 44 47 49 49 5O 7,66 44 47.0~ .75 12,75 4b,84 I~.75 POt~OS ! T ¥ % % YCR~B DEN5, G~/CC VOL[)~E 10020.0 10024,0 10035,0 10027,0 1002{i,0 10029.0 10030.0 1.003i,0 10032.0 i0033.0 10034,0 10035.0 1003~.0 !00:)7,0 10038.0 10040.0 lO04q.O 10051.0 1005~.0 i005].0 10055,0 10094.0 !0095.0 10096.0 10097.0 10098.0 10121,0 10129,0 10150,0 I013~,o lOlJ],O 10114,0 I0135,o 101{6.0 10137,0 1013~,0 10139,0 10140,0 O. O. O. 0, 0 O. 0 O. O. O. 0 O. O. O. O O. O, O. O, O. O. O, 0. O, 9.6 8.~ 1,0 0,3 1,3 0.4 7.3 9,9 9.7 9,7 4.7 7,5 4,4 1,2 0.1 0.0 4.0 5,4 0,7 9,2 8.6 O,O 9." 12.1 ll,g I00 !00 i00 100 t00 1 oo !00 1 O0 I00 100 100 100 100 I00 I00 100 100 100 1 O0 100 100 100 100 1 O0 100 100 100 100 100 I00 100 1.00 100 100 100 49 45 46.75 46,4! 46,31 45,60 45,25 45.09 49 44. 49 0 44, 4 7 44.2~ 4 7 44,19 49 42.08 s .ot 34 4t,95 49 41 q 9 4 8 40,72 6 4o.$ 42 40,55 4) 40,~ 35 5 40,14 0 40.03 10141°O 10142°O 1014],0 101q4,0 10145,0 ~O14boO 10147.0 I015~o0 10156,0 10~57,0 10197.0 10!98,0 10249,0 10250o0 10251.0 10252.0 10253°O !0254.0 10255.0 I0~56.0 I0257,0 10200,0 10261,0 I0~6~,0 10209,0 10270,0 I0271,0 10274,0 10275.0 10284,0 10285,0 10286,0 10287,0 10288,0 10350,0 10351,0 10375,0 10376.0 0., 0 0.0 0,! 0,1 0,0 0,0 O.i 0oi O. 4 0.4 OeO 0.0 0.0 0,0 0.,.0 O, O O. 1 O. I 0,0 0,I 0.0 0,0 0.0 0.0 0,3 0°2 0,4 0.8 0.? 0,4 0,4 0.0 0,0 0,0 0.0 POROSITY 6.0 6.0 6,0 7,6 9.3 11,7 11.8 0,I 3.2 7,4 7,4 10,1 7,9 5,1. 11,3 10,? 12.0 11,7 t~.3 0,~ 4,6 SAT. % ! O0 t00 100 ~00 100 100 i00 100 100 t00 100 100 1 O0 1 O0 !00 I00 I00 100 ~00 100 100 1 O0 1 O0 100 100 100 100 100 i00 100 qO 100 100 100 100 100 12.75 4~ Iq. ti 42 ]9.0~ I~.75 49 38.28 1-2.75 49 38,i6 12.75 47 46 47 47 44 47 47 44 37.48 .44 37.36 -~7,0:~ 1~.75 12.75 i~.75 2.75 4g ]6.46 42 36,37 172,,:) 7~= 44 34.32 I2.73 I~ 33.94 i2,73 DEPTU P'EET 10177,0 1037a,0 10379,0 103~0.0 !0382o0 10383.0 10384.0 10385.0 10400,0 10401,0 10402,0 !040],0 10405,0 10406,0 10407,0 10408,0 10413,0 10414,0 10415,0 10416,0 10422.0 10423.0 1o424.0 10425.0 0.~ 0.0 0.0 0,0 0,0 0,0 0,0 0.0 0,0 0,0 0.0 0,0 0.! 0.1 0,! 0 .O 0,1 0.0 0,0 0,0 0,0 0,0 POROSITY % 0,4 0,0 1.4 0.3 0.~ 8.0 5.~ 1,7 6.7 7,7 0,~ 9.0 5.4 7.1 09 t O0 Io0 i0o I00 10o i00 10o 100 100 100 lOO 100 1 oo 100 I0O Io0 lO0 t00 :100 49 4 43 9 48 33,87 33.62 ~5 4O 9 46 30. ~o. 30,70 0 0 0 I 0 0 1 0 0 0 0 0 0 0 0 O. t 0 0 0 0 . ~PI. JT PAR ~" ... 13, a O,~O 6,00 0, 0, 2,84 0,20 108]0, b212, 0,000 t,00 0,000 6,60 1.2,60 ~oo o ooo .~o o '.-~o o. ~o RESISTIVITY STATISTIC5 UVFR ENTIR~f INTERVAL GA~NA{~AY NOT USED IN CORRECTION OF OOUBTFDL POROSITY DAT~ AMAbYSi~ BY OU.~8I ~4OOE%., }"ERMEABIbITY BY TI~U~ EOUATIO~ GR Cf.]~:FF, FROt,{ 5TATISTIC~ WASAMp ROUTINE OSED PO~UflT¥ % !0438.0 104]q.O i0468,0 10400.0 I0470.0 10471,0 10472,0 10473,0 I0496,0 1049~,0 10498.0 10499,0 10500.0 10502,0 10503,0 10504,0 10505,0 I0506,0 10507,0 1050~,0 10509,0 10510,0 10~11,0 I051~,0 1051a,O i0514,0 i0515,0 10516,0 i0518,0 lOSlO,O 10523.0 10524,0 10525,0 10526,0 I0527,0 1052a,0 1052q,0 10510,0 I0531,0 I0512.0 I0533,0 10534,0 lOS3~,O 0.0 0,0 0.5 0.6 0,0 0,0 0,0 0,4 1 3 6 0,,7 2O ~0 I0 6 1 0.4 ! 2O 30 2O 20 20 20 3o 2O lO ~,4 7,7 ~,0 8.8 10,3 4.7 6,7 4,4 8,0 10,1 11,7 11,8 t2,2 10,9 11,1 14,? 15,2 15,2 14,2 t~,!. 12,4 t0.2 ~,4 11,7 9.7 10.9 16,4 15.7 15,2 16,! I5,B 14,2 I00 96 5E 57 57 100 1 O0 47 47 43 40 42 3~ 47 45 43 34 34 35 35 34 33 34 0,8~ 0,8~ 0.8~ 0.8+ ~0 3O so 48 44 36 t9 ?9, -28.54 8 06 27.63 6,55 22 16 25,32 2'4,69 DEPT~t % % ~YCA~B C~/CC CLAY % 105j6,O 10537.0 !05~9.0 10540,0 10541,0 10542,0 105~].0 lOb~4.0 10545,0 10546.0 10547.0 I0548,0 I054q,0 10550,0 10551.0 10552°0 10553.0 10554,0 10555,0 10556,0 10557.0 10558,0 10559.0 10500,0 10561.0 1056],0 I0564,0 I0565,0 10567.0 10568.0 ~0569,0 10570.0 10571,0 1057~,0 t0573,0 10574,0 i0575,0 10576,0 I0~77,0 10578.0 1057q,0 10585,0 1058~,0 10587,0 yo 20 10 10 ? 0 10 ~0 0,6 0,0 10 0,1 20 5 1 14,3 16,6 16.7 16.4 !1,9 14,~ 14.2 13,5 7,~ 11.0 12.~ 1~,~ !1,6 !2.0 15,1 11,5 10,1 10,2 ~,4 ]4 30 33 4O I0o 100 100 !4 7 8 I5 14 9 4 I0 !0 9 6 9 5O 48 2,3 75 2~,90 ~2,63 1 , 79 2iI ~I · O~ 20.2-4 20 06 19,6~ o., os DEPT{t FEET Pf}~OSITY % % 10580.0 10590,0 I059t,0 I0592,0 1059],0 10609°0 10610,0 10611,0 10612,0 10613,0 10614,0 10615,0 10616,0 lOei?.O 10618,0 10610,0 10620,0 106~],0 10624,0 10625,0 10676.0 10627.0 I0628,0 10620,O 1.0630,0 1061!,0 10632,0 10633,0 10634,0 106~5,0 10636,0 10637,0 I0638,0 106~g,O I0640.0 10641.0 I0642,0 10643,0 10644,0 10645,0 10646,0 10~47,0 1064~,0 10649,0 0,0 0.6 0.4 0,, 0 0.0 O, 0 0,0 0.0 0.0 0,0 0,0 O.i 0.9 I ! 1 1 ! 1 ! 0o~ 0o0 0o0 0°0 O. 1 0.1 0.2 0,9 '9 4 4 7.2 7.~ 7.5 7.3 ~,0 7,~ 7.8 ~.3 !0,5 ll,t 11.,2 tO,q ll,O ~.6 7.4 6.9 10,2 11,5 9,9 10,5 13,0 13.9 14,9 14,5 13.2 14,2 1~,~ 67 bi 6t 73 74 tO0 lO0 96 99 74 71 68 62 60 64 71 72 99 67 7! {%6 58 5! 47 46 4'; 50 % 0 5O 52 48 49 49 ~0 46 41 ~7 4O 8.06 7,91 17,59 7,02 1.6,70 16,5~ 15,86 15.75 15 4 22 17 20 I? 5 14, 4,41 14,13 DEPTt.~ F E F T !0650.0 10651.0 I065~o0 10653.0 I0654,0 10655°O 10656.0 !0657.O !06~o0 10664,0 10665°0 10606°0 10667.0 10608.0 10669°O 10670,0 10671.0 10672,0 ~067~,0 10674,0 10675.0 !0676,0 t0677,0 I0678,0 ~0679o0 10680,0 10681,0 10682,0 I068~.0 10691.0 10692.0 10693.0 10694.0 10696.0 10697.0 10698,0 !0699.0 10700.0 10701.0 10702,0 1070~.0 10704.0 10705.0 10707.0 3 2 I 0.2 0.1 0.0 0,0 O.n o.0 o. 1 O. 1 o. 1 o. 1 0.2 0.~ 0,~ 1 0.0 O. I O.a 0.3 0,0 0,0 0.0 0.0 0.0 3 0.0 0.0 O.P 0.7 P{{!~f}SIT¥ 11.3 11.4 12o5 11.4 11o4 10.4 4,9 5.4 7.0 9.'~ 10ol IO.8 11.8 10.5 I0.3 7,9 7.5 4,} 4.1 4o~ 4.8 11.4 3,3 6.5 8.4 11o6 ~ATER SAT. % 50 57 55 7~ 100 100 100 !00 1 O0 ~4 8o 7~ 6'/ 6~ 62 62 62 63 62 100 51 55 100 ! O0 100 100 44 41 100 43 44 42 4~ 30 34 34 34 35 37 46 40 4O CU~. 4 4.85 4.79 1.2,41 4,75 t3.18 4.66 i3.0a 4.63 !2.77 . 1~.62 tI~~49 11.92 ii. !,72 ,50 11,06 42 t0.87 4.12 .. 44 10,66 4.03 45 I0,59 44 10,50 io.4s tO 23 9,92 22 % ~TE~ 5~To % 1070~,0 4 It,9 45 10709,0 2 tO,g 10710,0 I q,6 52 I0712,0 ~ 14,{> 45 I0714,0 4 1~o5 10716,0 5 !~.~ 50 10717.0 ~ 12,2 54 1071~.0 ~ 11.4 57 10710°0 0.0 10.3 64 10720.0 O,q 10,4 65 10722,0 0.2 10,3 i072~.0 0.2 10,2 10724.0 1 10,9 ~7 I0725.0 5 14,~ 55 10726,0 1 10.9 61 10727,0 ¢).? 7,5 66 1072g.0 0.4 8.~ t0730.0 0.2 7,4 59 10711.0 0.0 5.5 1073~,0 0,0 ].q 100 10739.0 0.0 5,6 o6 i0734.0 0.1 6.8 66 i0735.0 O.R 9,5 55 10736.0 6 13.6 47 10737.0 ~ 1.3,4 40 t07~8,0 2 10,9 54 10740.0 l 10,2 49 !0711.0 0.5 ",5 10742.0 0.4 8,1 52 I074~,0 0.9 9,1 10744,0 0,7 8,5 48 ~0745,0 0,5 8,~ 10746.0 ~ 10,5 49 1074g,0 5 1],7 10750.0 10 15,8 48 10751,0 7 1~,4 50 10752,0 4 1],4 52 1075],0 ] 1~,5 55 10754.0 6 14,3 51 10755.0 7 15,~ 5~ 0,8~ 22 24 1'9 20 19 1 24 9 9, ,49 .27 ?, 7,i7 6,62 ,41 5, .15 ,06 DEP~,f FE~JT % wATE~ 1.0756,0 7 15,5 10757,0 4 14,0 107ba,O 0,0 11,7 1075q,0 0,~ 10,5 10760,0 0,6 I076i,0 0.5 I1,4 10762,0 4 J076],0 6 14,7 10764,0 5 14,0 10765,0 4 I],4 10766,0 '1 10767.0 2 t2,6 10768,0 4 14,0 10770,0 4 10771,0 O.a 11.0 10772,0 0,2 10,0 10773.0 0.? 10774,0 0.2 I0775,0 0,~ 10.4 10776,0 0,~ 10.1 10777,0 0.2 10.3 10779,0 0.0 7,6 10780,0 0,~ 10781,0 0.2 10818,0 0.0 ~.1 100 10819,0 0,0 l~,~ 71 I0820,0 0,1. a,7 10821,0 0.l ,.4 70 10a22.0 0,0 7,1 10823,0 0.0 7,5 100 10824,0 0.1 0.~ 78 10827,0 0,! 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