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167-014
Wallace, Chris D (DOA) From: Larry Greenstein [Igreenstein@hilcorp.com] Sent: Monday, June 03, 2013 10:00 AM To: Wallace, Chris D (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: Glen Payment; Tim Cowan; Dan Moultrie; Robert Baker; Chet Starkel Subject: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey (PTD# 1670140) Attachments: AN -5 Temp Survey 5-30-13 vs 5-19-11.xls Hi Chris, A compliance temp survey was conducted on Granite Point State 18742 #5 (a.k.a. Anna Well No. 5), AIO 6.003 (PTD 1670140) water injector on 5/30/13. The attached temp plots (MD and TVD) overlaying the two most recent An -5 temp surveys indicate downhole containment of the injection fluids within the approved injection interval as no significant temperature anomalies were detected. An effort was made to run the temp survey to the top perforation depth of 9072' MD, but the tools were only able to reach 9009' MD (-200' below the tubing tail) before tagging up. This is similar to the depths reached on previous temp surveys and still demonstrates downhole containment of the injection fluids. Based on the pressure plot, the fluid level in the tubing appears to be 2500' MD. The slight difference in thermal gradient between the two surveys is most likely due to a shorter shut-in time for the newest temp survey. Please call if you have any questions. Thank you Larry OC I 03 2014 1 Hilcorp Well: jAnna # 5 Field: Anna 05/30/2013 0 0 1000 2000 3000 4000 5000 t Q G 6000 7000 8000 9000 Pressure (psia) Pressure -Temperature Profile 1. RIH to 9009' RKB 2. Shut -In i I I 10000 40 Temperature (Deg. F) 5-30-13 Pressure — Perfs 13 3/8" 9 5/8" 7" TBG 5-30-13 Temp 5-19-11 Temp Report date: 6/3/2013 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMI; )N • REPORT OF SUNDRY WELL OPERATIONS MAY 2 3 2014 1.Operations Abandon❑ Repair Well❑ Plug Perforations ❑ Perforate p Other a Performed: Alter Casing❑ Pull Tubing❑ Stimulate-Frac 0 Waiver❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Wella 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory 0 167-014 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑✓ 6.API Number: Anchorage,AK 99503 50-733-20010-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018742 Granite Pt St 18742 05(AN-05) 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Granite Pt/Middle Kenai Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,803 feet Plugs measured None feet true vertical 9,507 feet Junk measured 9,348 feet Effective Depth measured 10,749 feet Packer measured None feet true vertical 9,455 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 603' 20" 603' 603' 2,110 psi 520 psi Surface 2,050' 13-3/8" 2,050' 1,948' 2,730 psi 1,130 psi Intermediate Production 8,965' 9-5/8" 8,965' 7,808' 5,750 psi 3,090 psi Liner 2,043' 7" 10,797' 9,501' 8,600 psi 5,875 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS 3-1/2" 9.2#/N-80 8,796'(MD) 7,665'(TVD) Tubing(size,grade,measured and true vertical depth) SS 3-1/2" 9.2#/N-80 8,608'(MD) 7,505'(TVD) Packers and SSSV(type,measured and true vertical depth) Packer: N/A SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): JUL /► diA Treatment descriptions including volumes used and final pressure: uAHNED u 0 201Y 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service 2 Stratigraphic a Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 WDSPLO GSTOR ❑ WINJ Q WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 3i `/ - za3 Contact Dan Taylor Email dtaylorhilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature „_ Phone (907)777-8319 Date 5/23/2014 j./`( Form 10-404 Revised 10/2012 Submit Original Only Gl �v RBCMS MAY 2 3 2 4 Granite SCHEMATIC Anna PlatforPointmField Well: AN-05 Completion Date:09/15/1997 Ililcorp Alaska,LLC CASING AND TUBING DETAIL RKB to TBG Head = 30' SIZE WT GRADE CONN ID TOP BTM. 20" 85-94 CSA Surface 603' 13-3/8" 54.5 J-55 ST&C 12.165 Surface 2,050' 9-5/8" 40,43.5 S-95/N-80 ST&C/BUTT. 8.755 Surface 8,965' 1 A 7"Liner 26 S-95 ST&C 6.276 8,754' 10,797' Tubing Long String Z , 3-1/2" 9.2 L-80 BTC SC 2.992 8,796' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' JEWELRY DETAIL NO. Depth ID OD Item Long String 9-5/8"Csg Breakdown: 1 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half 0'-4466' : 40#N-80 2 8,618' 3.00 3.86 Crossover,3-1/2"Buttress Box x 3-1/2"EUE 8 rd Pin 4466'-6452': 40#, S-95 6452'-8965': 43.5#, S-95 3 8,619' 2.68 6.5 Kobe,3",Type"B",Pump Cavity 4 8,642' 3.00 4.5 Xover,3-1/2"EUE Buttress Pin x 3-1/2"8 RD Box 5 8,797' 3.00 5.25 Wireline re-entry guide 0 Short String A 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover,3-1/2"Buttress Box x 2-3/8"EUE 8 rd Pin L , C 8,609' 2.00 2.37 Pup,2-3/8",4.6#,L-80,EUE 8 rd Fish/Fill: Depth Date B I 1,198'Tail Pipe,2-7/8",6.4#,N-80,Buttress (Unverified) 9,348'DPM 9/10/97 II Slickline Fish(1-1/2"Si,1-1/2"01,2.13"GR) Below EOT 8/6/00 Mt 2 Jam! I` III Ran 1.50"GR and tagged up 9,043'MD 1/7/10 m =mum IV Ran 1-3/4"GR and tagged up 9,078'SLM 3/30/14 -:_.I. Min ID(JP BHA): 3 2.25" IC AM Perforation Detail Mit M=1111! Top Btm Top Btm Present Mr Zone (MD) (MD) (TVD) (ND) Amt SPF _ Condition X���' \\\\ Perforations: C-2 9,072' 9,087' 7,829' 7,841' 15' 13' Open 580,7360 8,849 C-5 9,323' 9,400' 8,028' 8,089' 77' 6' Open G Btm TB 8,797' J C-5 9,410' 9,440' 8,097' - 8,121' 30' - 6' Open C-6 9,523' 9,540' 8,187' 8,201' 17' 9' Open L , C-6 9,567' 9,580' 8,222' 8,232' 13' 9' Open izO 9-5/8"Csg Btm: C-7 9,755' 9,790' _ 8,371' _ 8,399' 35' 6' Open 8,965' C-7 9,805' 9,830' 8,411' 8,431' 25' 6' Open T C-7 _9,845' 9,895' 8,443' 8,482' 50' 6' Open /11111 III - C-7 9,905' 9,985' 8,490' 8,554' 80' 9' Open C-8 10,170' 10,183' 8,700' 8,711' 13' 9' Open II C-8 10,230' 10,294' 8,748' 8,799' 64' 9' Open C-8 10,374' 10,411' 8,862' 8,892' 37' 9' Open - C-9 10,583' 10,613' 9,028' 9,052' 30' 6' Open I V . ''N PBTD= 10,749' TD= 10,803' MAX HOLE ANGLE=33.8°@ 4,071' Updated by: JLL 05/22/14 Hilcorp Alaska, LLC Ilikcorp Alaska,LU Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GRANITE PT ST 18742#5 50-733-20010-00 167-014 4/23/2014 4/23/2014 Daily Operations: 04/23/14-Wednesday Hold safety meeting.Rig up wireline and pack off. RIH with 1-11/16"dummy gun and tag at 9,078'. POOH.Turn off cathodic protection.Stop all welding operations.MU run#2,1-11/16",13',6 spf,0 deg phasing strip gun. RIH,correlate on depth and shoot interval 8,836'to 8,849'.POOH,all shots fired. MU run#3,1-11/16",30',6 spf,0 deg phasing strip gun. RIH,correlate on depth and shoot interval 8,806'to 8,836'. POOH,all shots fired. MU run#4,1-11/16",20',6 spf,0 deg phasing strip gun. RIH,correlate on depth and shoot interval 8,786'to 8,806'.POOH,all shots fired. MU run#5,1-11/16",10',6 spf,0 deg phasing strip gun. RIH, correlate on depth and shoot interval 8,776'to 8,786'. POOH,mis-run. Detonator cord was soaked and detonator wires were severed.MU run#6,1-11/16",10',6 spf,0 deg phasing strip gun. Well pressured up,1.5 gal of fluid out of packoff bled well down through production choke to<100psi and stabilized. POOH with perf gun. Rig down pack off and e-line.Turned well over to production. P. THE STATE )F�; ✓ A f j '� ly.r5f'rs .:7 T r7 rrq_ st '- r.. 333 West Seventh Avenue GOVERNOR SEAN PARNLLI_ Anchorage, Alaska 99501-3572 Main: 907 279 1433 Fax 907.275.7542 SCANNED JUL 2 2 2014, Dan Taylor J Operations Engineer 1 — 01 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 05 (AN-05) Sundry Number: 314-223 Dear Mr. Taylor: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this day of April, 2014. Encl. E • STATE OF ALASKA /APR 0 7 Hit ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool 0 Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate Q Pull Tubing❑ Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 167-014 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic CIService 0 . 6.API Number 7 Anchorage,AK 99503 50-733-20040-@4 6'0-t33-o2O0/0'6o'co 7.If perforating: ?Itb 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? VA- Cd .(Q Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Pt St 18742 05(AN-05) ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 • Granite Pt/Middle Kenai Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,803 9,507 10,749 ' 9,455 None 9,348 Casing Length Size MD TVD Burst Collapse Structural Conductor 603' 20" 603' 603' 2,110 psi 520 psi Surface 2,050' 13-3/8" 2,050' 1,948' 2,730 psi 1,130 psi Intermediate Production 8,965' 9-5/8" 8,965' 7,808' 5,750 psi 3,090 psi Liner 2,043' 7" 10,797' 9,501' 8,600 psi 5,875 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2'dual 9.2#/N-80 LS 8,796'&SS 8,608' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): None None 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 Service 0 14.Estimated Date for 15.Well Status after proposed work: 4/9/2014 Commencing Operations: Oil ❑ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtavlort hilcorp.com Printed Name Dan T3yIol `_,,�-' Title Operations Engineer Signature / :.- .. Phone 907)777-8319 Date 4/7/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3V-l- 223 Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS ' MAY 10 2014 Spacing Exception Required? Yes ❑ No 7 Subsequent Form Required: /o —I/Q l �1 APPROVED BY Approved by: (;)_4iv,J COMMISSIONER THE �COMMISSION,i,' .75,4, � ` 5Date: (/�.-/y �Ts�" " �/ 4i-g -? `'S" ' �`' " Submit Form and Form 10-403(Revised 10/2012) Appr p li.aG t 4' 1Lonths from the date of approval. Attachments in Duplicate Well Prognosis Well: An-5 Hilcorp Alaska,LL) Date:4/7/2014 Well Name: AN-5 API Number: 50-733-2000-01 Current Status: Injector Leg: 4 Estimated Start Date: April 9, 2014 Rig: Anna Platform Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 167-014 First Call Engineer: Dan Taylor (907)777-8319(0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907)777-8421 (0) AFE Number: Current Bottom Hole Pressure: 2,500psi @ 7,680ft TVD/8,810ft MD Based on surrounding reservoir pressure data. Maximum Expected BHP: 2,500psi @ 7,680ft TVD/8,810ft MD Based on surrounding reservoir pressure data. Max.Allowable Surface Pressure: 890 psi 0.1 psi/ft(gas)*2/3*TVD+ 0.435psi/ft(water)* 1/3*TVD Well Summary An-5 was drilled and completed as a Tyonek oil well in September 1967. It was originally brought on as a dual string jet pump completion with perforations shot from the C2-C9 sands(Total Perforated Interval-MD: 9,072ft to 10,613ft). The well was converted to an injector in October of 2004 and began injecting with 150psi-200psi. In February 2014 the well pressured up while injecting and would not take any fluid at an injection pressure of 2,000psi. We will perforate the Cl sands over the interval of+/-8,776ft to+/-8,849ft MD(+/-7,650ft to+/-7,709ft TVD). Procedure: 1. Identify and record fluid level. 2. Hold pre-job safety meeting. 3. Prepare well for e-line perforating. a. Check well head pressure. b. Ensure crown and wing valves are closed. c. Bleed pressure from well head. d. Ensure there is no trapped pressure. e. Ensure there is proper lighting for operations. f. Keep excess personnel away from operations. g. Ensure perforating unit is grounded. 4. Rig up lubricator and slick line: a. Test lubricator to+/-3,000psi. b. Run in hole with GR to tag at+/-9,078ft(last tag 3-30-14). i. -1-3/4in GR 5. Rig up lubricator and run in hole with wireline: +/-10ft strip gun, GR and CCL. a. Tie in to correlation log. b. Well will perforate while well is+/-balanced. c. Perforate interval: +/-8,776ft to+/-8,849ft MD(+/-7,650ft to+/-7,709ft TVD). d. Total number of runs to cover interval 7.3(-8). 6. Pull out of hole with perforating guns. 7. Rig down lubricator 8. Turn well over to production. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic v ii Anna ALASKA •FILLING WellNo. 5 UNOCAL 76 Actual Completion 9/15/97 CASING AND TUBING DETAIL RKB to TBG Head =30' SIZE WT GRADE CONN ID TOP BTM. 20" 85-94 CSA Surface 603' 13-3/8" 54.5 J-55 ST&C 12.165 Surface 2,050' 1 - ' A 9-5/8" 40,43.5 S-95/N-80 ST&CBUTT. 8.755 Surface 8,965' 7"Liner 26 S-95 ST&C 6.276 8,754' 10,797' Tubing Long String 3-1/2" 9.2 L-80 BTC SC 2.992 8,796' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' JEWELRY DETAIL NO. Depth ID OD Item Long String 9-5/8" Csg Breakdown: 1 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half 0'-4466' : 40#N-80 2 8,618' 3.00 3.86 Crossover,3-1/2"Buttress Box x 3-1/2"EUE 8 rd 4466'-6452': 40#, S-95 Pin 6452' -8965': 43.5#,S-95 3 8,619' 2.68 6.5 Kobe,3",Type"B",Pump Cavity 4 8,642' 3.00 4.5 Xover,3-1/2"EUE Buttress Pin x 3-1/2"8 RD Box 5 8,797' 3.00 5.25 Wireline re-entry guide 0 Short String A 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half R 8,608' 2.00 3.86 Crossover,3-1/2"Buttress Box x 2-3/8"EUE 8 rd Pin Z C 8,609' 2.00 2.37 Pup,2-3/8",4.6#,L-80,EUE 8 rd Fish/Fill: Depth Date I 1,198'Tail Pipe,2-7/8",6.4#,N-80,Buttress (Unverified) 9,348'DPM 9/10/97 II Slickline Fish(1-1/2"SJ, 1-1/2"OJ,2.13"GR) Below EOT 8/6/00 III Ran 1.50"GR and tagged up 9,043'MD 1/7/10 B 2 I.IE- C PERFORATION HISTORY 1=1It 1• _ ■IlI Interval Accum. 3 WMuM Date Zone Top Btn Ant spf Present Condition l mem NM C-2 9,072' 9,087' 15' 13' Open tni Ell C-5 9,323' 9,400' 77' 6' Open 4 - C-5 9,410' 9,440' 30' 6' Open C-6 9,523' 9,540' 17' 9' Open X 5 ` , C-6 9,567' 9,580' 13' 9' Open X C-7 9,755' 9,790' 35' 6' Open L III , C-7 9,805' 9,830' 25' 6' Open II _ C-7 9,845' 9,895' 50' 6' Open C-7 9,905' 9,985' 80' 9' Open - C-8 10,170' 10,183' 13' 9' _Open C-8 10,230' 10,294' 64' 9' Open I - C-8 10,374' 10,411' 37' 9' Open C-9 10,583' 10,613' 30' 6' Open 14 / `-' PBTD= 10,749' TD=10,803' MAX HOLE ANGLE=33.8°@ 4,071' O:\NAU\MCBU\Alaska\Depts\CI_Oil_Ops\Fields\GPF\Anna\Wells\Injectors\An-05\Schematics\An-05 Schematic 4-23-08.doc REVISED: 1/7/10 by JHM Granite Point Field • . n Proposed Anna Platform Well: AN-05 ' Completion Date:09/15/1997 Hilcorp Alaska,LLC CASING AND TUBING DETAIL RKB to TBG Head = 30' SIZE WT GRADE CONN ID TOP BTM. 20" 85-94 CSA Surface 603' - 13-3/8" 54.5 J-SS ST&C 12.165 Surface 2,050' 1 I / 9-5/8" 40,43.5 S-95/N-80 ST&C/BUTT. 8.755 Surface 8,965' A 7"Liner 26 5-95 ST&C 6.276 8,754' 10,797' Tubing Long String L , 3-1/2" 9.2 L-80 BTC SC 2.992 8,796' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' JEWELRY DETAIL NO. Depth ID OD Item Long String 9-5/8"Csg Breakdown: 1 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half 0'-4466' : 40#N-80 4466'-6452': 40#, S-95 2 8,618' 3.00 3.86 Crossover,3-1/2"Buttress Box x 3-1/2"EUE 8 rd Pin 6452'-8965': 43.5#, S-95 3 8,619' 2.68 6.5 Kobe,3",Type"B",Pump Cavity 4 8,642' 3.00 4.5 Xover,3-1/2"EUE Buttress Pin x 3-1/2"8 RD Box 5 8,797' 3.00 5.25 Wireline re-entry guide 0 Short String A 30' 2.99 11 CIW 3-1/2"DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover,3-1/2"Buttress Box x 2-3/8"EUE 8 rd Pin L , C 8,609' 2.00 2.37 Pup,2-3/8",4.6#,L-80,EUE 8 rd Fish/Fill: Depth Date I 1,198'Tail Pipe,2-7/8",6.4#,N-80,Buttress (Unverified) 9,348'DPM 9/10/97 II Slickline Fish(1-1/2"SJ,1-1/2"OJ,2.13"GR) Below EOT 8/6/00 III Ran 1.50"GR and tagged up 9,043'MD 1/7/10 B 2 im IM. INC Perforation Detail Top Btm Top Btm Present JIM [III Zone (MD) (MD) (TVD) (ND) Amt SPF Condition 3imamX C-1 ±8,776' ±8,849' ±7,650' ±7,709' 73' Future C-2 9,072' 9,087' 7,829' 7,841' 15' 13' Open MEL Miff lit C-5 9,323' 9,400' 8,028' 8,089' 77' 6' Open fffff■•III C-5 9,410' 9,440' 8,097' 8,121' 30' 6' Open 4 _ C-6 9,523' 9,540' 8,187' , 8,201' 17' 9' Open C-6 9,567' 9,580' 8,222' 8,232' _ 13' 9' Open C-7 9,755' 9,790' 8,371' 8,399' 35' 6' _ Open X XC-7 9,805' 9,830' 8,411' , 8,431' 25' 6' Open 5 C-7 9,845' 9,895' 8,443' 8,482' 50' 6' Open / III , C-7 9,905' 9,985' 8,490' 8,554' 80' 9' Open C-8 10,170' 10,183' 8,700' 8,711' 13' 9' Open II aft - C-8 10,230' 10,294' 8,748' 8,799' 64' 9' Open - C-8 10,374' 10,411' 8,862' 8,892' 37' 9' Open C-9 10,583' 10,613' 9,028' 9,052' 30' 6' Open I 1 _ r - PBTD= 10,749' TD=10,803' MAX HOLE ANGLE=33.8°@ 4,071' Updated by: JLL 04/07/14 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 23, 2011 4:47 PM To: 'Martin, J. Hal'; Regg, James B (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Payment, Glen A; Lee, John R Subject: RE: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey Thanks Hal. I concur that downhole containment is indicated. Tom Maunder, PE AOGCC From: Martin, J. Hal [mailto:Hal.Martin @chevron.com] Sent: Thursday, May 19, 2011 6:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Payment, Glen A; Lee, John R Subject: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey Jim and Tom, A compliance temp survey was conducted on Granite Point State 18742 #5 (a.k.a. Anna Well No. 5), AIO 6.003 (PTD 167 -014) produced water injector on 5/19/11. The previous compliance temp survey was conducted on 1/7/10. The attached temp survey data and plots include a tab with a MD plot overlaying Anna Well No. 5 temp surveys on 5/19/11 and 1/7/10. The plot indicates downhole containment of the injection fluids within the approved injection interval with no significant temperature anomalies. Other MD and TVD plots of the 5/19/11 survey are also included in the attached file and show the same temperature trend. Anna Well No. 5 continues to inject produced water at daily rates of about 175 BWPD. An effort was made to run the temp survey below the top perforation depth (9072'). The gauges reached 9000' (72' from top perf) before tagging up. Nothing definite exists at that point, but we were unable to work the tools deeper. For reference, the 1/7/10 temp survey gauges reached 9039' before tagging up. Please call me if you have any questions. Thanx, F40444EDMAY 2 3 2O Hal Martin Optimization Engineer MidContinent /Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 ha I. martin©chevron.com 5/23/2011 0 0 IC I WeII:1Anna # 5 I Field: 'Anna 105 -19 -2011 Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 Pressure - Temperature Profile 1. RIH Overlay 05', 07', 10', 11 loon 2. Shut -in 2000 t 3000 \lh" 1 4000 X \ CD 5000 - ., \\\\\' ' \ "\ .. Q C) 6000 7000 1 8000 — l 9000 _ - Imo 10000 40 50 60 70 80 90 100 110 120 130 140 150 160 TAwfNAM7 +..lA In. C\ — Perfs 13 3/8" 9 5/8" 7" TBG — — Pressl0 —Press 11 — — — Temp 10 Temp 11 Report date: 5/23/2011 • • Page 1 of 4 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) ~s~~~-~~ JrfS ~~~~iy~t 'C-~~~~C~~~ Sent: Friday, January 15, 2010 1:03 PM ~\~~~ «~~ `~~ ~,~~ ~PC~'_~.3.~'~tJ~S To: Martin, J. Hal; 'Greenstein, Larry P' , W ~ ~~ i.... ;,~C, C~.c3.t~ ~"~`1 ~ C ~ c~~ ~E. Cc: Regg, James B (DOA) Subject: RE: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey -.~ ~ t~l~- (~,; Hal and Larry, , b`1-~l `~` I concur that the temperature survey comparison indicates that fluid is confined to the intended interval. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Friday, January 15, 2010 8:39 AM To: Maunder, Thomas E (DOA) Subject: FW: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~~~~~ JAN ~ ~ 2Q1D From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, January 14, 2010 5:53 PM To: Regg, James B (DOA) Cc: Greenstein, Larry P Subject: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey .7im, A compliance temp survey was conducted on Granite Point State 18742 #5 (a.k.a. Anna Well No. 5), AIO 6.003 (PTD 167-014) produced water injector on 1/7/10. The previous compliance temp survey was conducted on 4/7/07. The attached temp plots (MD and TVD) overlaying Anna Well No. 5 temp surveys on 1/7/10 and 4/7/07 indicate downhole containment of the injection fluids with no significant temperature anomalies. As you can see on the plots, an effort was made to run the 1/7/10 temp survey below the top perforation depth (9072'). The tools reached 9039' (33' from top perf) before tagging up. Nothing definite exists at that point (possibly slickline tools lost in 8/00), but we were unable to work the tools deeper. For reference, the temp survey in 4/07 was run to 8796' (end of the tubing). A compliance temp survey was due for this well by 5/20/09. As mentioned below in our correspondence, access to Anna Well No. 5 was prevented until mid-December 2009 because of a rig-use building set on the deck covering the slot. Please call me if you have any questions. Thanx, Hal 1/15/2010 • Page 2 of 4 Thanx, Hal From: Martin, J. Hal Sent: Friday, December 18, 2009 2:56 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 ]im, Status Update. The rig-use building was removed from the Anna this week. It was delayed alittle -- most recently due to the fog which essentially shut down travel for a week or two. We still have a Utility Module and a Rig to skid in to a position that would allow access to most, if not all of the wells on the Anna. Because of the holidays, the skidding of this equipment is currently planned for sometime in ]anuary. An-5 and An-19 were under the building that was removed and we'll work toward getting an MIT on those wells after the holidays as well. An-38 needs the rig to be skidded before it becomes accessible. Thanx, Hal From: Martin, J. Hal Sent: Thursday, October 01, 2009 2:42 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim, I spoke with Wayne Rust about moving the buildings on the Anna. The current plan is to remove one of the buildings and skid the other sometime before December. Once this is done, then we should be able to access and work toward getting the temp surveys on the An-5, An-19, and An-38 wells. Thanx, Hal From: Martin, J. Hal Sent: Tuesday, September 22, 2009 1:45 PM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Rust, Wayne; Brandenburg, Tim C Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Jim, The person responsible for figuring out the removal of the Anna rig-use buildings is currently out of the office. I made the comment below to respond to you now before I knew that he was out. I should be able to get an idea next week some time after he returns. 1/15/2010 '� R E °\ II� FE z SEAN PARNELL, GOVERNOR L=, �� U L' -Ll L �TAYASKA 011L AND GAS� 333 W. 7th AVENUE, SUITE 100 CONST'�{ RMONT CO-MUSS101V E ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 December 16, 2009 Dale Pittman Alaska Production Manager ExxonMobil Production Company PO Box 196601 Anchorage, AK 99519 Re: Acquisition of XTO Energy, Inc. Dear Mr. Pittman: SSR, OCT 03 20W Congratulations on your acquisition of XTO Energy, Inc. Attached please find information on three XTO-operated wells in Alaska. The Alaska Oil and Gas Conservation Commission requests that you confirm or update the wells' status and plans. Sincerely, 1 114CC4� Cathy. . Foerster Commissioner (2) Enclosures ENERGY July 27, 2009 Ms. Cathy P. Foerster, Commissioner State of Alaska Oil & Gas Conservation Commission 333 W. 7t" Ave, Suite 100 Anchorage, AK 99501 Re: Request for Information — Status of Oil and Gas Wells Dear Ms. Foerster: JUL u 1. 2009 ,rxEizS:.:`c OF7i r Si(•CI XTO Energy Inc. (XTO) has received a request dated June 22, 2009, pursuant to 20 AAC 25.300, requesting information about the status of three wells located in the Middle Ground Shoal field of Cook Inlet, which is operated by XTO. Commission records indicating that these wells (A42-14, C24-26RD, C34-26) have been inactive for five years or longer are correct. The A42-14 (167-014) has been inactive since September 1998 when it produced 6 bopd & 294 bwpd. The well was shut-in in October 1998 because it was no longer economic to produce. Since that time it has remained shut-in with production tubing and packers installed in the well. XTO has plans to utilize this wellbore for an east flank sidetrack when economic and budget conditions are sufficient to justify re -activating the drilling rig on Platform A. The C24-26RD (179-062) has been inactive since May 1992 when it produced 24 bopd & 660 bwpd. The well had been active intermittently from 1988 until it was shut-in in May 1992 due to the high water cut. Since that time the well has remained shut-in with production tubing and packers installed in the well. XTO is evaluating this wellbore for its use in drilling a sidetrack well targeting additional reserves in the west flank. The timing of future work will be determined by economic and budget conditions. The C34-26 (168-019) has been inactive since November 1988 when it produced 10 bopd & 80 bwpd. The well was shut-in due to uneconomic production. The production tubing and packers remain installed in the well. XTO is currently evaluating the potential of returning this well to production in the current configuration. In the event that this attempt is not feasible or is uneconomic, the well will likely be suspended during a future drilling program when the rig is available. Should you have any further questions or need additional information you can contact me at 432-620- 6742 or jeff gasch@xtoenergy.com. SWce Jh Operations Engineer XTO Energy Inc. XTO Energy Inc. • 200 North Loraine, Suite 800 • Midland, Texas 79701 • (432) 682-8873 • Fax (432) 687-0862 17 f l f SARAH PALIN, GOVERNOR 77 �y_ �,� � / 333 W. 7th AVENUE. SUITE 100 C�,�g2LJ.\7 �Q��� ��-�? PHONANCHE � 907)279-14339501.3539 FAX (907)276-7542 June 22, 2009 Kyle Hammond Vice President XTO Energy Inc. 200 North Loraine, Suite 800 Midland, Texas 79701 Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Mr. Hammond: 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 XTO Energy Inc. have been inactive for five years or longer. If, for any listed well, XTO Energy Inc. 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, XTO Energy Inc. 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 XTO Energy Inc. of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert(ralaska.,(�. Enclosure Sincerely, Cathy . Foerster Commissioner • • Page 3 of 4 Thanx, Hal _ _ _ _. From: Martin, J. Hal Sent: Wednesday, September 16, 2009 11:07 AM To: 'Regg, James B (DOA)' Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA); Freeman, Justin T Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim, The short answer is: 1. Drilling is supposed to be working the plan to remove the rig-use buildings that covering the An-5 and An-19 slots and the rig is on the leg that An-38 is on, but out of position to get over it. Once the building and utility module are removed, access to all the wells will be available on An-5 and An-19 and my understanding is that then skidding the rig can be planned. 2. The waterflood will be down for a while and it is not a given that it will be restored at this point. The sand filters were recently inspected internally and uncovered a failure of the grating that kept the various sizes of sand media stable and properly layered. As you recall, we were hoping it was a butterfly control valve issue, which would have been an easier fix. We are in the process of evaluating whether to proceed with repairs given the significant cost impact coupled with budget constraints. I am guessing that we should be close to an answer on this by mid November. I'll get back to you on this either tomorrow or Monday afternoon with more info on the current timing guesstimate from our drilling guys on the rig-use building removal. Let me know if you have any other questions. Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 16, 2009 9:00 AM To: Martin, ). Hal Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Would appreciate an update on schedule for completing temp survey in Anna 5. Same for Anna wells 19 and 38 if they are back on injection; otherwise, we would appreciate an update on status of water flood on Anna platform. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 1/15/2010 ;EfNTEGY July 27, 2009 Ms. Cathy P. Foerster, Commissioner State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Re: Request for Information — Status of Oil and Gas Wells Dear Ms. Foerster: lc-4-1- o k4_(�' iUL 3 u 2009 AissL,P: oil & Rs Gens. Cer�misskin �cllil �c�e S.WED 0C i 0 3 2014 XTO Energy Inc. (XTO) has received a request dated June 22, 2009, pursuant to 20 AAC 25.300, requesting information about the status of three wells located in the Middle Ground Shoal field of Cook Inlet, which is operated by XTO. Commission records indicating that these wells (A42-14, C24-26RD, C34-26) have been inactive for five years or longer are correct. The A42-14 (167-014) has been inactive since September 1998 when it produced 6 bopd & 294 bwpd. The well was shut-in in October 1998 because it was no longer economic to produce. Since that time it has remained shut-in with production tubing and packers installed in the well. XTO has plans to utilize this wellbore for an east flank sidetrack when economic and budget conditions are sufficient to justify re -activating the drilling rig on Platform A. The C24-26RD (179-062) has been inactive since May 1992 when it produced 24 bopd & 660 bwpd. The well had been active intermittently from 1988 until it was shut-in in May 1992 due to the high water cut. Since that time the well has remained shut-in with production tubing and packers installed in the well. XTO is evaluating this wellbore for its use in drilling a sidetrack well targeting additional reserves in the west flank. The timing of future work will be determined by economic and budget conditions. The C34-26 (168-019) has been inactive since November 1988 when it produced 10 bopd & 80 bwpd. The well was shut-in due to uneconomic production. The production tubing and packers remain installed in the well. XTO is currently evaluating the potential of returning this well to production in the current configuration. In the event that this attempt is not feasible or is uneconomic, the well will likely be suspended during a future drilling program when the rig is available. Should you have any further questions or need additional information you can contact me at 432-620- 6742 or Jeff gasch@xtoenergy.com. SWce Jh Operations Engineer XTO Energy Inc. XTO Energy Inc. • 200 North Loraine, Suite 800 • Midland, Texas 79701 • (432) 682-8873 • Fax (432) 687-0862 e tt \j E L. \(-,L-1-0\ 4-r� E ` SARAH PALIN, GOVERNOR /Y ATA SKA 011L AND G 333W 7th AVENUE, SUITE 100 CONSERVATYLO F COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 22, 2009 Kyle Hammond Vice President SCMW OCT 0 3 2014 XTO Energy Inc. 200 North Loraine, Suite 800 Midland, Texas 79701 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Hammond: 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 XTO Energy Inc. have been inactive for five years or longer. If, for any listed well, XTO Energy Inc. 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, XTO Energy Inc. 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 XTO Energy Inc. 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.aubertr@alask a.g_ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Permit No. Well Name XTO Energy Inc. 167-014 MGS A42-14 XTO Energy Inc. 179-062 MGS XTO Energy Ince 168-019 _C24-26RD MGS C34-26 • • Page 4 of 4 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G Subject: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim and Tom, FYI and reminder. I just sent you the compliance temp surveys for An-21 and An-25. We were able to access those wells. We have yet to do the compliance temp surveys for An-5, An-19, and An-38, which were also due on May 20th as well. The reason, as we've discussed before, is that the wells are currently not accessible with slickline due to rig equipment covering the wells and supply boat support issues. We will run temp surveys on the three wells above when we regain access to the well bores. All of the Anna waterflood injectors have been shut in since January 2008 due to ongoing surface facility issues compounded with heavy drilling rig activity during much of 2008. An-5, a produced water injector, is still on injection, averaging about 60 BWPD. As we've discussed, as a result of the unusual shut-in circumstances brought on by the Redoubt volcano, this is because we are still producing some wells on the platform, separating out the produced fluids, and injecting the produced water down An-5. The oil is being injected in to four producers. This is a temporary situation that we are monitoring during this period of downtime for oil shipments. Let me know if you have any questions. Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal. martin@chevron.com 1/15/2010 • • 'Chevron I Well: 'Anna # 5 I Field:lAnna 101 -07 -2010 Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 0 Pressure - Temperature Profile 1. RIH Hole TVD — 2. Shut -In 1000 I 2000 3000 — 4000 — t Q 5000 — — 6000 7000 8000 9000 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) - 1 - - 10 Pressure — Perfs 13 3/8" 9 5/8" - T' TBG 1 - - 10 Temp 4 -7 -07 Temp • 'Chevron I WeII:lAnna # 5 I Field:lAnna 101 -07 -2010 I Pressure (psia) 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 0 Pressure - Temperature Profile 1. Going in hole to 9039' RKB 2. Shut -In 1000 2000 3000 — 4000 G1 y.• L 5000 sZ 6000 7000 8000 - 9000 ` 10000 40 50 60 70 80 90 100 110 120 130 140 150 160 Temperature (Deg. F) —1-7-10 Pressure — Perfs —13 3/8" 9 5/8" 7" —TBG —1-7-10 Temp —4-7-07 Temp Report date: 1/15/2010 • • Page 1 of 2 Regg, James B (DOA) ----_. .~ P~ t~ ~t~ CA~-~ta s From: Martin, J. Hal [Hal.Martin@chevron.com] Sent: Wednesday, September 16, 2009 11:07 AM To: Regg, James B (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA); Freeman, Justin T Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim, The short answer is: 1. Drilling is supposed to be working the plan to remove the rig-use buildings that covering the An-5 and An-19 slots and the rig is on the leg that An-38 is on, but .out of position to get over it. Once the building and utility module are removed, access to all the wells will be available on An-5 and An-19 and my understanding is that then skidding the rig can be planned. 2. The waterflood will be down for a while and it is not a given that it will be restored at this point. The sand filters were recently inspected internally and uncovered a failure of the grating that kept the various sizes of sand media stable and properly layered. As you recall, we were hoping it was a butterfly control valve issue, which would have been an easier fix. We are in the process of evaluating whether to proceed with repairs given the significant cost impact coupled with budget constraints. I am guessing that we should be close to an answer on this by mid November. I'll get back to you on this either tomorrow or Monday afternoon with more info on the current timing guesstimate from our drilling guys on the rig-use building removal. Let me know if you have any other questions. {~ ~ ~ ~ ~~~~ ,iA~~ Thanx, Hal From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, September 16, 2009 9:00 AM To: Martin, J. Hal Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G; Schwartz, Guy L (DOA); Aubert, Winton G (DOA) Subject: RE: Anna Platform Remaining Waterflood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Would appreciate an update on schedule for completing temp survey in Anna 5. Same for Anna wells 19 and 38 if they are back on injection; otherwise, we would appreciate an update on status of water flood on Anna platform. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 9/16/2009 Page 2 of 2 From: Martin, J. Hal [mailto:Hal.Martin@chevron.com] Sent: Thursday, May 21, 2009 5:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Greenstein, Larry P; Moultrie, Dan R; Baker, Robert R; Dorman, Allen; Moultrie, Dan R; Agler, Brit G Subject: Anna Platform Remaining WaterFlood Injector Compliance Temp Surveys -- An-5, An-19, and An-38 Tim and Tom, FYI and reminder. I just sent you the compliance temp surveys for An-21 and An-25. We were able to access those wells. We have yet to do the compliance temp surveys for An-5, An-19, and An-38, which were also due on May 20th as well. The reason, as we've discussed before, is that the wells are currently not accessible with slickline due to rig equipment covering the wells and supply boat support issues. We will run temp surveys on the three wells above when we regain access to the well bores. All of the Anna waterflood injectors have been shut in since .7anuary 2008 due to ongoing surface facility issues compounded with heavy drilling rig activity during much of 2008. An-5, a produced water injector, is still on injection, averaging about 60 BWPD. As we've discussed, as a result of the unusual shut-in circumstances brought on by the Redoubt volcano, this is because we are still producing some wells on the platform, separating out the produced fluids, and injecting the produced water down An-5. The oil is being injected in to four producers. This is a temporary situation that we are monitoring during this period of downtime for oil shipments. Let me know if you have any questions. Hal Martin Optimization Engineer MidContinent/Alaska Business Unit Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7675 Fax 907 263 7847 hal. martin@chevron.com 9/16/2009 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp@chevron.com] Sent: Monday, May 05, 2008 2:09 PM To: Maunder, Thomas E (DOA) Subject: RE: TBU D-22 (169-108) and GP St. 18742 05 (167-014) Attachments: TBU D-22 Packer Depth; RE: TBU D-22 Packer Depth; RE: Anna 5 Discrepancies You're right again Tom, I tend to use the common well name so that people here know which well t'm talking about. But the official forms should be using the official name of the well. In talking with Jim about these two wells, he gave me direction as to how to fill in the 404. To address this, when you change these forms (403 & 404) to include the TVD of the packer, there needs to be a box for a short verbal description of the purpose of the form, not just a check box up top. It would have been easy to add a comment to the form to make it mean more to whoever picked it up Sorry for the confusion...thought these might go to Jim to process as he knew all about them. Larry ~~~~~ MAY ' ~OQ~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, May 05, 2008 1:54 PM To: Greenstein, Larry P Subject: TBU D-22 (169-108) and GP St. 18742 05 (167-014) Larry, You just submitted some 404s for these wells other and "revised" noted in block 1 Could you provide a little information as to what was revised? Atso, please note An-05 is not the official name for 18742 05. Thanks, Tom Maunder, PE AOGCC 5/6/2008 Page 1 of 1 • Maunder, Thomas E (DOAj • From: Regg, James B (DOA) Sent: Tuesday, April 22, 2008 2:00 PM To: Greenstein, Larry P Cc: Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA) Subject: RE: Anna 5 Discrepancies Attachments: Anna 5 schematic.pdf; Anna 5 10-404.pdf This time with attachments Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Regg, James B (DOA) Sent: Tuesday, April 22, 2008 1:41 PM To: 'Greenstein, Larry P' Cc: Fleckenstein, Robert J (DOA); Foerster, Catherine P (DOA) Subject: Anna 5 Discrepancies The Commission has been doing some QA work on all injection well records in Alaska. Included in that effort is verifying the TVD of the packer since that is a key number in determining the MIT pressure for injection wells. Currently, the TVD pf the packer is not required to be reported (only required to report MD) on the applications and subsequent reports (10-403s, 10-404s, and 10-407s) so we are calculating TVD from reported MD and the directional survey. We'll be sharing our results with operators in the near future. Anna 5 (PTD 167-014) is a packerless completion; during our review of the well record, the following discrepancies were identified: - well schematic received with admin approval request (Unocal letter dated 1/14/05; AIO 6.003) shows well TD is 13,821 ft; the 10-404 recd 4/22/05 indicates TD of well is 10803 ft - perforations on well schematic range from 9072 ft to 10613 ft; 10-404 shows perforated interval (MD) as "various 10471-11575 ft'; in other words, the perforations are deeper than the TD of the well according to the 10-404 - well schematic shows TD of SS tubing @ 8608 ft, LS @ 8618 ft; 10-404 shows SS tubing @ 8608 ft and LS @ 8796 ft. I've attached the 10-404 (4/22/05) and well schematic (9/19/97; provided with AIO 6.3 application). Please review and provide us with corrected paperwork that accurately reflects the well configuration. Give me a call if you have any questions. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 5/6/2008 STATE OF ALASKA ~'~-.~'=0~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ Revised Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Union Oil Company of California (UNOCAL) Development ^ Exploratory^ 1670140 3. Address: P. O. Box 196247 Stratigraphic^ Service0 6. API Number: Anchorage, AK 99519-6247 50-733-20010-00 7. KB Elevation (ft): 9. Well Name and Number: 100' RT above MSL An-05 Q ._ 8. Property Designation: 10. Field/Pool(s): -~ Granite Point 18742 Middle Kenai 'C' Sands ~ ~ 11. Present Well Condition Summary: O Total Depth measured 10803 ~ feet Plugs (measured) none tG~ ~ ~ true vertical 9507 feet Junk (measured) 9348 { ~ Cs c Effective Depth measured 10749 feet ~~ true vertical 9455 feet Q' Casing Length Size MD TVD Burst Collapse Structural Conductor 563 20 603 603 2110 520 Surface 2020 13 3/8 2050 1948 2730 1130 Intermediate Production 8935 9 5/8 8965 7808 5750 3090 Liner 2043 7 10797 9501 8600 5870 Perforation depth: Measured depth: V2rI0US 9072 - 106 13 True Vertical depth: various 7900 - 932 4 Tubing: (size, grade, and measured depth) LS & SS 3 1/2" 9.2# N-80 LS to 8796 & SS to 8608 Packers and SSSV (type and measured depth) none 12. Stimulation or cement squeeze summary: Intervals treated (measured): y 6 ~ ~ tv ~.~~, ~~,, M~~ ~ 2Q08 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Press ure Prior to well operation: 0 0 0 0 80 Subsequent to operation: 0 0 0 0 80 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Larry Greenstein @ 263-7661 Printed Name Larry Greenstein .~- Title Production Technician Signature Phone 263-7661 Date 4/29/2008 Form 10-404 Revised 04/2006 ~ ~ ~ ~ A ~ ~ ~~ b Submit Original Only ~~VJJ Anna Well No 5 V N ~~A~. 76 . Actual Completion 9/ 1 5/97 CASING AND TUBING DETAIL RKB to TBG Head = 30' sizl: wT GRADE CONN ID TOP BTM. 20" 85-94 CSA Surface 603' 13-3/8" 54.5 J-55 ST & C 12.165 Surface 2,050' ~ A 9-5/8" 4Q 43.5 5-95/N-80 ST & C/BUTT. 8.755 Surface 8,965' 7" Liner 26 5-95 ST & C 6.276 8,754' 10,797' Tubing Long String 3-1/2" 9.2 Lr80 BTC SC 2.992 8,796' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' NO. Death ID JEWELRY DETAIL OD Item Long String 1 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half 2 8,618' 3.00 3.86 Crossover, 3-1/2" Buttress Box x 3-I/2" EUE 8 rd Pin 3 8,619' 2.68 6.5 Kobe, 3", Type "B", Pump Cavity 4 8,642' 3.00 4.5 Xover, 3-1/2" EUE Buttress Pin x 3-1/2" 8 RD Box 5 8,797' 3.00 5.25 Wireline re-entry guide 0 Short String A 30' 2.99 11 C[W 3-1/2" DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover, 3-1/2" Buttress Box x 2-3/8" EUE 8 rd Pin C 8,609' 2.00 2.37 Pup, 2-3/8", 4.6#, L-8Q EUE 8 rd Fish/Fill: Depth Date I 1,198' Tail Pipe, 2-7/8", 6.4#, N-80, Buttress (Unverified) 9,348' DPM II Ran 1.75" GR to 8,796' MD 8,796' MD 4/7/07 PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf PresentCondition G2 9,072' 9,087' 15' 13' Open G5 9,323' 9,400' 7T 6' Open G5 9,410' 9,440' 30' 6' Open G6 9,523' 9,540' 17' 9' Open G6 9,567' 9,580' 13' 9' Open G7 9,755' 9,790' 35' 6' Open G7 9,805' 9,830' 25' 6' Open G7 9,845' 9,895' S0' 6' Open G7 9,905' 9,985' 80' 9' Open G8 10,170' 10,183' 13' 9' Open G8 10, 230' 10,294' 64' 9' Open G8 10, 374' 10,411' 3T 9' Open G9 10, 583' 10,613' 30' 6' Open U .. ~ PBTD = 10,749' TD = 10,803' C:\Documents and Settings\greenlp.CT\Desktop\Att-OS Schematic 4-23-08.doc MAX HOLE ANGLE = 33.8° @ 4,071' REVISED: 4/23/08 by LPG Re: Granite Point State 18742 #5 (aka Anna ¡AlO 6.003 Complia... . I agree with your assessment; you're call on going past C-2 perfs on next survey. I would be satisfied with survey to same depth as baseline. Thank you for respondin . Jim Regg AOGCC Martin, J. Hal wrote: Jim, There is an element of being aware of the fish, but I can't say that it is the reason we stopped at 8796'. I think the reason we stopped at 8796' is because it was the depth of the baseline survey back in 10/04 and actually deeper than the follow-up survey in 1/05 -- and I don't recall at the moment why we stopped at that depth back then, but it must have been acceptable to both of us at the time. In any event, the temp tools do not see a cooling kick -- and I don't think they would see much of one anyway (unless it was leaking somewhere up shallow) because I believe the fish would prevent us from wanting to go as deep as the C-5 where I think most of the fluid is probably going. The temp survey does show that down to past the EOT the temp gradient has no significant anomaly which, to me, means that the point where fluid is exiting the casing is deeper -- which is good. .. If it is acceptable to you, I will make a note to attempt to get to 9100' (past C-2 perfs) on the next compliance temp survey. Thanx, Hal g~ MAY 0. '1 2007 From: James Regg [mailto:iim reqq@admin.state.ak.us] Sent: Monday, April 30, 2007 1:40 PM To: Martin, J. Hal . ..,.,,,..., ,._~.._..._~.__"4-,,,,~,">..,~ Subject: Re: Granite Point State 18742 #5 (aka Anna #5) AIO 6.003 Compliance Temp Survey iJt After reviewing temp survey, I was curious why the temp survey does not extend into the perfed interval; is it because of the fish in hole at ~9300 ft? Jim Regg AOGCC lof2 5/1/200710:26 AM Re: Granite Point State 18742 #5 (aka Anna ¡AlO 6.003 Complia... Martin, J. Hal wrote: . Jim & Tom, Granite Point State 18742 #5 (aka Anna #5), AIO 6.003 (PTD 167-014) was approved on 3/29/05. In e-mail correspondence with Jim in March, permission was granted to delay running the compliance temp survey until May 2007. The compliance temp survey for Anna #5 was completed on 4/7/07. The attached temp plots (MD and TVD) overlaying Anna #5 temp surveys on 1/9/05 and 4/7/07 indicate downhole containment of the injection fluids. The shape of the temp surveys are similar and the cooler temperature trend recorded on the 4/7/07 survey probably reflect the two years of additional cooling along the well bore since injection was first established. Please call me if you have any questions. «An-5 Temp Survey 4-7-07 & 1-9-05.zip» Thanx, HaC :Martin Optimization Engr Chevron 909 W. 9th Avenue Anchorage, AK 99501 Tel 9072637675 Fax 9072637847 hal.martin@chevron.com 20f2 5/1/2007 10:26 AM Granite Point State 18742 #5 (aka Anna #5) A~6.003 Compliance... ~ a • Subject: Granite Point State 18742 #5 (aka Ant1a #5) AIO 6.003 Compliance Temp Survey From: "Martin, J. Hal" <Ha1.Martin c~chevron.com> Date: Mon, 30 Apr 2007 13:20:51 -0500 T~-: ",fii~l Re~,~~(-~0(~~'C)~~ "jim ic~~~~~~rradmin.5tate.ak.us.>, "To~ii 1i~iur~~ler(,~~0000)~~ ` 101T1 ]Tl~lll[1c~Cr([1'111I1111i1.5~81t'.a~.US.' CC~: "Grc~nstcin, Larry P" ~ -Crccnstcinlp~~~'che~~ron.coin- ~, ~~Dorri~an.:~,llcr~" <-.llornlan,=1!~i'che~°r~~n.com> The attached temp plots (MD and TVd) overlaying Anna #5 temp surveys on iJ J and J?J07 indicate ownhol c ntainent of the injection fluids. The s a f the to p surveys are similar a t e cooler to Brat re trend recorded on the J7Jo7 survey r a l reflect the two years of additional cooling along ,/~ t e ell ore since injection was first establis . lease call me if you ave ny uestions, «An-5 Temp Survey 4-7-07 & 1-9-05.zip» Thanx, t ~t~ Chevron 909 W. 9th Avenue Anchorage, AK 99501 Tel 907 263 7675 Fax 907 263 7847 hal.martin@chevron.com An-5 Temp Survey 4-7-07 & 1-9-OS.zip ~~7 MAY ~ 2 2007 Content-Description: An-5 Temp Survey 4-7-07 & 1-9-OS.zip Content-Type: application/x-zip-compressed '! Content-Encoding: base64 1 of 1 4/30/2007 12:20 PM 10000 40 o o 400 800 1800 1000 2000 3000 4000 5000 6000 7000 8000 9000 100 10 120 Pressure Perfs 3 3/8" -4-7-07 5/8" ~7!t An-5 & -9-05.xls 3000 4000 5000 6000 1000 8000 9000 10000 40 5 60 70 80 Perfs TBG _711 u 90 100 140 13 9 5/8" - -9-05 & Re: Anna Well No.5 MIT . ? ~....),<:I. ~... Based on a review of TIO pressure data for Anna 5 provided monthly, and the findings noted in Administrative Approval 6.003 dated March 29,2005, the well continues to demonstrate acceptable mechanical integrity. We agree that delaying the temperature survey as requested does not represent an increased risk of loss of mechanical integrity nor does it introduce an increased risk of fluid movement. Your request to delay the temp survey (required every 2 years) on' Añ.ña 5 until May 2007 is acceptable. 0\4- \toî/ Jim Regg AOGCC SCANNED MAR 2 7 2007 Martin, J. Hal wrote: Jim, Larry informed me that you and he noted that Anna Well No.5 is due for it's biennial MIT (temp survey) this month (March). In an effort to consolidate our annual MIT work requirements on the Anna Platform, I'd like to request that Chevron be allowed to move the temp survey date required for Anna Well No.5 this year to May to coincide with all the other MITs to be done on Anna this year. Chevron currently has plans to begin moving a rig on to the Anna beginning sometime in June for drilling work scheduled late this year. Therefore, our plan is to move the MITs up to May. We would like to do Anna Well No.5 at the same time. Anna Well No.5 will continued to be monitored and does not indicate any anomalous behavior. Chevron does not believe that delaying this temp survey approximately 2 months introduces significant risk in our expectation that the well bore is containing fluids as required. I will be out of office until 3/26. Please contact Larry Greenstein if you have any questions or let him know if this is acceptable to the AOGCC. Thanx, Hal :Martin Optimization Chevron 909 w. 9th Avenue Anchorage, AK 99501 Tel 907 263 7675 ~~ Z- Io~k.- ~ 3/20/2007 1 :32 PM ~. ) ) UNOCALe April 25, 2005 RECEIVED APR 2 7 2005 Ala'ka Oil & Gas C ons. Commission Anchorage Hal Martin Optimization Engineer Dir 907 263-7675 Fax 907 263-7847 Mr. Steve McMains Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 SCANNED APR 2 7 2005 Form 10-404 Submittal Anna Platform Well No. An-5 Permit No. 167-014 Granite Point Field Dear Steve: Enclosed is Form 10-404 for the Anna Platform Well No. An-5, Granite Point Field. This sundry report is a follow up of the well operation to convert the well from an idle producer to waterflood injector, a multi-step temperature survey and injection process with first injection recorded in October, 2004 and Administrative Approval, AIO 6.003, granted by AOGCC for Well An-5 on March 29, 2005. Please call me at (907)263-7675 if you have any questions. Sincerely. _ / J1¿/}¡~, Hal Martin CI Oil Optimization Engineer Unocal Alaska / Union Oil Company of California 909 W. 9th Ave. P.O. Box 196247 Anchorage, AK 99519-6247 STATE OF ALASKA ALP -} all AND GAS CONSERVATION COMI\110N REPO~T OF SUNDRY WELL OPERATIONS 1':"oþeràtions Abandon U Repair Well U Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California (UNOCAL) Name: 3. Address: 909 W. 9th Anchorage, Alaska 99501 7. KB Elevation (ft): 100' RT above MSL 8. Property Designation: Granite Point 18742 11. Present Well Condition Summary: Total Depth measured 10803 true vertical 9507 Effective Depth measured 10784 true vertical 9488 Casing Length Structural Conductor 563' Surface 2020' Intermediate Production 8935' Liner 2043' Size 20" 13 3/8" 95/8" 7" Plug Perforations U Perforate New Pool D Perforate D 4. Current Well Class: Development 0 Stratigraphic D Stimulate U Other ~ Convert to In. j ( WaiverD Time ExtensionD ()tT )/)D Re-enter Suspended Well D 5. Permit to Drill Number: ExploratoryD 167-014 Service D 6. API Number: 50-733-20010-00 9. Well Name and Number: Anna - 5 10. Field/Pool(s): Middle Kenai 'C' Sands feet feet Plugs (measured) none Junk (measured) none feet feet MD TVD Burst Collapse 603' 2110 psi 520 psi 2047' 2730 psi 1130 psi 7810' 5750 psi 3090 psi 9498' 8600 psi 5870 psi 603' 2050' 8965' 8754' - 10797' Perforation depth: Measured depth: various 10471' - 11575' True Vertical depth: various 8874' - 9876' Tubing: (size. grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): LS & SS 3 1/2" LS to 8796' & SS to 8608' 9.2# N-80 none Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 90 o 200 90 15. Well Class after proposed work: Exploratory D Development D 16. Well Status after proposed work: oilD Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Contact Hal Martin Printed Name J-/11 L /1111 ({ T /1'/ . Signature 4ÞJ¿ /J¡~Vr--- Form 10-404 Revised 04/2004 Tubing Pressure 90 90 Service 0 GINJ D WINJ 0 WDSPL D Sundry Number or N/A if C.O. Exempt: Title Optimization Engineer Phone (907)263-7675 Date 4/22/2005 ~ ßD1Vl5 L~f~71 ð~ Submit Original Only ~' .' ~ r'fÆ' s-? æ ' I " '.. ¡ 1 ¡! r' ., .', r' l ~ ¡ I I, '/ L¡ j ~ L\ l . ) ~ f~ (Æ., q '¡-~ (ñ" rl~'c' ~ ¡ I ~ ¡U:,' ! : lð"" d ~ß\, ~:~<~U ~ if ~. /.i~\', ~i [I Ln":~ I ~_\ 'u"D1J\ \~ l,J}:j! " I, ! iL..... ;u,-"u\ i U ' ¡, ' ,; ," .~ . 'i.-.=J~ ' \1. ,r ,\ ) A.TfA.~1iA. OIL AND GAS CONSERVATION COMMISSION /./' .. / I .I .1 FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 6.003 Mr. Hal Martin Reservoir Engineer U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 SCANNEJ) APR 2 0 2005 RE: Granite Point State 18742 #5 [aka Anna #5] (PTD 167-014) Request for Administrative Approval Ala 6 Dear Mr. Martin: Per Rule 9 of Area Injection Order ("Ala") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by U nocal and approved by the Commission. 3. In support of this application, Unocal has submitted the results of temperature logs obtained prior to initiating injection and approximately 10 weeks later. These operations were conducted according to Sundry permit 04-318. They have also submitted a graphical maximum operating pressure determination. 4. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. 5. Unocal has also begun reporting injection rate and pressure information on the well. The pressure information indicates that the reservoir pressure in Anna 5 is low and insufficient to support a fluid column to surface. The successive pressure information gathered with the temperature surveys indicates that the bottomhole pressure in the vicinity of the well is increasing. 6. Examination of the well file and production history indicates that as best can be determined the well structure is sound and that 2 competent casing barriers exist to prevent the release of pressure or fluids. Mr. Hal Martin March 29, 2005 Page 2 of2 ) ) 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #5 [aka Anna #5] is conditioned upon the following: 1. The effect date for conversion from producer to injector is the date injection commenced according to Sundry permit 304-318, October 24, 2004, Unocal shall file form 10-404 noting the changed status of the well. 2. Injection is limited to WATER ONLY; 3. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rates daily; 4. Unocal shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 5. U nocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 6. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 7. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person may not appeal a Comm' si n decision to Superior Court unless rehearing has been requested. ge, Alaska and dated March 29, 2005. ) Unocal AlaSka') Union Oil Company of Ca, 'a 909 West 9th Avenue, P.O. I:jOX 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL'" Hal Martin Reservoir Engineer January 14, 2005 ~ i\ "' ' :'1,1 .C& '7 n 0 h) .J /,r:-?\ ~' 'þ ,,~~hir L.~)·" ~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 REQUEST FOR ADMINISTRATIVE APPROVAL UNDER AREA INJECTION ORDER 6 CONVERSION TO INJECTOR ANNA PLATFORM WELL NO.5 GRANITE POINT FIELD Dear Tom: Unocal requests administrative approval under Area Injection Order 6, Rule 9 for the conversion to an injector of non-hazardous Class II fluids for Anna Platform Well NO.5 (Permit # 1670140) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. MD and TVD plot of pre-injection/baseline and post-injection period temperature surveys (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below). The Anna Well NO.5 was drilled and completed as a producer in 9/67 in the Tyonek Formation with C-2, 5,6,7,8, and 9 Sand perforations spread out between 9074' and 10613'. A cement bond log run in the 9-5/8" casing on 7/3/67 indicated that bond exists from the shoe at 8965' to approximately 8620'. ../ Indications are that the 9-5/8" casing was tested to 2000 psi on 8/14/67. No information was found for a test on the 7" liner.+"Converted to a hydraulic lift completion in 6/74, the Anna Well No. 5 produced until 2/96 when it developed tubing integrity issues. A coiled tubing jet pump completion was run in 7/96 and production continued until problems developed in 4/97. A hydraulic workover in 9/97 repaired the well with dual strings of 3-1/2" tubing and hydraulic pump completion. The well developed holes in the short string in 12/02 and was shut-in. Efforts to remedially repair in 3/03 were unsuccessful. In 10/04, Unocal received permission to begin the process of converting the well to a Tyonek C-2, 5, 6, 7, 8, and 9 injector of non-hazardous Class II fluids. A baseline temperature survey was run on 10/6/04, then beginning on 10/24/04 waterflood water was injected into the well under conditions averaging about 150-200 BWPD with 100 psi. On 1/9/05, a follow up temperature survey was run and confirmed that -- water was not moving upl1ole. C:\Documents and Settings\ambrudm\Local Settings\Temporary Internet Files\OLK7\An-5 Admin Relief Request Jan05.doc ,Tom Maunder January 14, 2005 Page 2 ) ) As an injector, Anna Well NO.5 will support AN- 23Rd and 33 which currently produce at combined test rates of about 180 SOPO and 90 SWPO (33.3% WC). Anna Well No.5 is not the first completion without a packer to be converted to an injector on the Anna Platform. Anna Well Nos. 21, 25, 32RO, and 38 have also been converted to injection and are currently operating as injectors. Unocal will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Please note also that Granite Point Field has an aquifer exemption per EPA40CFR147.102b2i. Please call me at (907)263-7675 if you have any questions. ;¡;,~~ - Hal Martin JHM:dma Attachments UNOCALe RKB to TBG Head = 30' L f.·.· ifI' iii Ì 11 ~ ~ ¡ It ~ 1 ¡ A . ~ 9-5/8" CSg Breakdown: 0' - 4466' : 40# N-80 4466' - 6452': 40#, 8-95 6452' - 8965': 43.5#,8-95 L ) ) Anna Well No.5 Actual Completion 9/15/97 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20" 85-94 CSA Surface 603' 13-3/8" 54.5 J-55 8 RD ST & C 12.165 Surface 2,050' 9-5/8" 43.5 S-95/N-80 8 RD/BUTT. 8.755 Surface 8,965' 7" 26 S-95 8 RD ST & C 6.276 8,754' 10,797' Tubing ~ Long String 3-1/2" 9.2 L-80 BTC SC 2.992 8,618' Short String 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' JEWELRY DETAIL NO. Depth ID OD Item Long String 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half 2 8,618' 3.00 3.86 Crossover, 3-1/2" Buttress Box x 3-1/2" EUE 8 rd Pin 3 8,619' 2.68 6.5 Kobe, 3", Type "B", Pump Cavity 4 8,642' 3.00 4.5 Crossover, 3-1/2" EUE 8 rd Pin x 3-1/2" Buttress Box 5 8,796' 3.00 5.25 Wireline re-entry guide, 3-1/2" Buttress Box 0 Short String A 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover, 3-1/2" Buttress Box x 2-3/8" EUE 8 rd ~ Pin C 8,609' 2.00 2.37 Pup, 2-3/8", 4.6#, L-80, EUE 8 rd Fish: 1,198' Tail Pipe, 2-7/8",6.4#, N-80, Buttress @ 9,348' DPM B ---., 2 '- "......, C PERFORATION mSTORY _.. .- I' . . 3 Interval Accum. -- I .1 I Date Zone Top Btm Amt spf Present Condition -, - I . 11 C-2 9,072' 9,087' 15' Initial then re perfed - . I ·11 I C-5 9,323' 9,440' 117' 4 ':'- C-6 9,523' 9,580' 57' C-7 9,755' 9,995' 240' Z Z C-8 10,170' 10,411' 241' - 5 C-9 10,583' 10,613' 30' Partially coverd by fill L ~ See Perforation Data Sheet for more Detail rT I I I [ ¡ ¡, , , ~ : ¡ ! PBTD = 10,784' TD = 13,821' l MAX HOLE ANGLE = 33° @ 1,850' L ~ O:\OOE\OOEFields\GPF\Anna\ Wells\An-05\Schematics\A-5Schm9-19-97.doc DRAWN BY: tcb REVISED: 9/19/97 AQ-5 MD Temperature survey. s ) 10-6-04 vs 1-9-05 ) o o :<fL~'~~~.'~:~::: 200 400 Pressure (psia) 600 800 1 000 1200 1400 ..m_~ I I 1600 I 1800 I 2000 I 2200 2400 . ......-........................-. . ._...-....~._...".....-_...-..,,-,,-._.--... ......-....., ...,...,_......_....~.,..__.._... .........- .. ... ~.._.._....__.. .., ........... .---..... Pressure-Temperature Profile ...--- 1. Going in hole 2. Shut-In ............-...-... .,.,..-..... . "'_"'"'''_.u.__.__.,.''''' ,.... --.".,..." ""~''''.''~''''''''~ ,"". 1 000 -. --.. . _.,...._..,._..-..~ ..... ....·......ø.._'...n.'......._ , .--..-....-."....,.,.,.....,......." .........."......~.__...,.. "'h'.' .......,.,............-...,...,......."..."...., "...--....,. ....,...".....--..... _.... .... ..m,. "".......~.._...,__. .............._................... ..___.."....... ". ..... .'. .... '.n._..·....··"......".. .... ........,'".......~...,...,_ .. ..."....."~.."'~.....~~......_,,. _._ . ........... ........ ._.... ".._...".."._...... ..~_ \ :~~~c.: ~ 2000 - -- -~~~~:~~~;=-=~·~~:==:::·=::::~:-:;0~;~-;~;~:=~~~~~i~~~~:~~==~~ : c \ -\ \J'/\. ~ ~ 3000 . -. . -. --- ---- ..----==:::. ::=:.=..::~::-: ::::::.::::::. ---- --. -- - .. ..... -,.. ........ '"~~~~\)\~oo ~~~~~~.-:- - . CD of S~"1 ~\ ~ 7000 .........--....-....---..-..-....... .-.- ..- ..... -...-.-......-..,-.--... .-.. .. . ...........-........-...'''.... ....-.._.._-......-................. ........,-_...._~....".......,.._." ..."....,.........,..............-,.. ......."'.-".-,....- ."- .- .. ..~. "....., ...~" .",..-................~ ".... .... .................. ,,"....--....-..--....---.-. ....-,............--. .-- ,-, ~ \ 5000 I .c .... 0- CD C 6000 ....._____.._ .._._,___ ..._. .__._.. ~.._.,...._~_. .__M" ... .,.... ....."...._.._...._....... .. ..... ....."... ._. ..__.. ....._" ,_ ..__......_..." .....__.._..þ. .._~........"._ __................ ,___..~.... 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F) -10-6-04 Pressure - Perfs -95/8" -7" -1-9-05 Pressure -10-6-04 Temp 13 3/8" -TBG -1-9-05 Temp O:\OOE\OOEFields\GPF\Anna\Wells\An-05\Surveys\Temp\An-5 Temp Survey 10-6-04 & 1-9-05.xls ~ 4000 CI) ~ - c" >. 5000 I- ,. I l .c ..... c. CI) C 6000 10000 40 An::,S TVD Temperature SurVl'~rs ) 10-6-04 vs 1-9-05 o 200 o :<"-I::.:.:::::::':.':: Pressure (psia) 600 800 1000 1200 1400 1600 I 1800 2000 2200 I I 2400 400 ......~,_.. . .......... ....w. ..... ....,.. ~.,_~...". , _......w......_.'.....M_ _....M.... .. ...m,."...'.......,._......",. . .... .........................-p. -"..".......,.,..,.,."...--.........,.....-..,.......-........ Pressure-Temperature Profile 1. Going in hole 2. Shut-In ................... ,.,.",..-.", ..,_..~. 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"n'_"_~.~_._'"'_''___''' ._....._....~____._ ....._. __..____....._...._......__ _..__.__.._...._..______._ ....... _....u......_......_....._. ...._.__...._.__........._____ ___........__............___. ,.,.....__........._........._.. ............~ ....._._.......__~. ..".,."__..,,._,,_.___._ _...._~__"..__~.____. ..._~"~_...._._.__".~ ._._.___......__......___. uu_._.._...._._.. ___ ___._m______..___._.._~__n.____..___ __..____. ..__n__..__.._ ____~_______.._.... ....._............__........_. ......... ...._~..._._~____ ........_..._....._....._.._. ..._....._..._..,._..__~...... ...._._._.."..._........_.. _.~....__....n....._...._... ....n__.·._"~,,__. _~_.. __.__......._~_..... __. ~._...___...~_~....___.... ___.._.__...._...n~____ _.._.________~__. ._u.._~n.n_____._. ,_..._~., __.,___.._.._.._. _.."__ '__..,,~_n_....'" .n....____...~___~~_.." _____~_....._._.~..... ....__~..__.___._..__. ___.~_~_.~~__...__..._. _n.._____...___._.. .,,_~____~.._.._... .._.~ 9000 _._..~......__...._____... ....__~_~_..______... ........____.___,_._... ..__.._.___.__..._ .._~____......__.."....... ~._.....~~ ._,,~...._ _ n__.__ ..._ '_'.~.~~.u. .._.,__......_~_.......,........_ """_._.___"__"_._" .____._.__...,._'"_ .._..._....w_.....__.w._. ____~._......... ..~_. ~._....._.....__...._.___. .__.......___.._..... _..___ .__._..___.,___.....~. .______._._n_u_._._ _4...._____.._...._.." ......~............_.....__..... _.__~" ....___. ....._..._._. ...._...._..........._. ..._... ,._. _n..~......·__._..·.__. W""_...._..____U_...__. ._n...n__~"........U.. __n,,__' _ ___"... _ _____~__ ._.__.~_ _ _ ~ _~_ ...__ _. __ _ _ _ _._ . ._. ... ~ _ _. n~._ __ _ .. u. ._~ _ W ~_. __ _ ____ ..__ ____ _._. .~_ _._ ._._._ ___ _ __._ _ ____ __. ._. .... ~ ____ . _ __._ ... _~..____.._.__~......,_,_ ....... _,_,,_... .._..W....._..,. "'.._... _._........, "". _.... _...__..__.____.._._. ._, ..._.._......_.. .~_W"_· _nn.._"..__..__..__," ..__. ._. ..n_ ...._ ___..n_..._..._"_ . ..._nh. _._'U.__n'__ .._ .___...._._.,,_ '.U __..______......._."._~ _._....."."~...... .____....." ._ ...._.._ .~_~.__,_..._.. _ '.."4" .__h.."~_ _. '''___'' ._.,,____,,_._. . __.....~._. _ '_" . ... .n."_~_~____' __.._ .__ ___.._...~.._,,_.. "._.' ..........n.~ '..n____ ,.~._ ..___U....._.u___. ... ·_~..U.._."_.... .____ ".".___u._~._ "_.. __ .....~~._ .~... ..._........ .._.~"_.__.,... _W"'_".U_' . .__......~_._._._~.......... __..._....._.. ..... .~.... _ _.. _ _~_.n.._n..... ~........._ . ... __. _...___.... _.__n. __ ,,__ ....__nn__~___ ...........n_ .u.... ...h.. ".._ ..__.._n_n. ._. __"..~.....~. n"_.__' ._____.__.._......__ _~..__~..___ ..____ _,__.. ___~..__. .._.._m__ _.___" ..._. ~___....n ... _ ___..n~___._.._._ __... ._..... .. .n. ___., ___..··..____..n_._~__.. ."._ ..,_ . _. _.. ._. ..nn'.... ___._..~..~_,._~~_ __. ,__. .~__... ..._._.._.. ___..______U.._. ._._____.__. __._......__._._.__._ ___~. ...,__..,________ _..._.. .~... .._..._......._ U.. __..___...._....._. ..."_.. .._.. __..n.... _. . _~. ..".__.. ....__.. ..."n__. _.._ .... ,_.__ _....n.._..____..~ ...._n... n....~_.__ .__........n _..__._..._.._..__. ,_"n_.._d~._.__n_ _ ._._.....__U_n _"_._,,. ...~_._.._ .___. .___...~__.._....__._..... ._.~___n_.~' .~._... ...___..~__~__. ._ ...._ ....__.._..._.._... _n..._.u_._,,_....~... ......_._.__.._.......n ___._._~"_...~...._._.. .~".....~.__.__.._~.. ·_.U,_....._......~__ .~____.. ...'__.__. ...__........_,___. 50 120 130 160 140 150 80 90 100 110 60 70 Temperature (Deg. F) -10-6-04 Pressure - Perfs -95/8" -7" -1-9-05 Pressure -10-6-04 Temp 13 3/8" -TBG -1-9-05 Temp O:\OOE\OOEFields\GPF\Anna\Wells\An-05\Surveys\Temp\An-5 Temp Survey 10-6-04 & 1-9-05.xls An-5 Maximum Allowable Operating Pressure Graph 0,000 9,000 8,000 Run date: 1/14/200510:15:59 AM Safe operating pressures (surface gauge) Production ~ 4021 psi. @ 70% nominal ca.ing yield Inlerme< iate ~ 517 psi. limited by fraclUre pressure al.hoe Surface ~ 153 psi. rllnited by fracture pressure at .hoe Current Pr~c;lIrP fÞ::.rling!=i TBGPRESS ~ 84 CSGPRESS2 ~ 84 CSGPRESS3 ~ 380 ~GPRESS5 ~ ° sing Details U r Casing = r 26#. $-95 internal yield = 8597 psi from 8755' to 10797 MO' Lin r Shoe ~ 7" II. internal yield ~ NJA psi from 10796' 10 10797' MIY PrOOüCtion 5e<¡ment ~ 9,625·~. N-80 internal vield ~ 5745 osi from 4499' to 8965' MD' P,-.:tion 5e<¡ment ~ 9.625" 4()j , 5-95 internal yield = 6822 psi from 6979' to 8965' MD' P,odldion Segmenl ~ 9.625" 43.~. 5-95 inlemal yield = 7510 psi from 6452' to 8965' MIY ProduWon Shoe ~ 9.625"., internal yield = NlA psi from 8964' 10 8965' MD' ,nteæE iate Casing = 13.375'" 54.5#. J-55 internal yield = 2734 psi from 31' to 2050' MOO Inle . Shoe = 13375" II, internal yield = NJA psi from 2049' 10 2050' MIY Surface 'a.ing ~ 20· 94#, H40 inlemal yield = 1530 psi from 31' to 603' MD' Surface S<>oe = 20' II, internal yield = NJA psi from 575' to 603' MD' Casing P,;Irameters I Assumptions Produdion œ.ing yield @ 70'4 of nominal with fluid weight 01 0.4331J1ft Intennediate ....ing yield @ 45% 01 nominal with fluid weighl 01 0.4331J1ft Surface eosin yield @ 45% 01 nominal with fluid weight of 0.4331J1ft Fracture grad;' (,O.71J1ft WorKbook: An-,Sing Pressure Analysis@70 percenl 20050114.xIs 7,000 6,000 Pressure (PSI 5,000 4,000 3,000 2,000 . o 0·' ,000 2,000 100 ~ 4,000 5,000 ê È .c Q. GI C 6,000 nul Variable Definitions ~ FP = Formation Pressure Cyp ~ Casing Yoeld Pressure SF = Safety ~actor (70% for working annulus; 45 for outer an FHP = Intemal Fluid HydrauHc Pressure MASP = Maximum allowable surface worI<ing pressu\ Grahical calculation method 0. uts.:t: press. - ure conta.imnent = inside pressure poten. I. Therefore FP + (CYP . SF) = FHP + MASP Rearranging MASP = FP + (CYP' SF)· FHP \ .-lt0oo f . 8,000 I I -Inlemal Fluid Hydraulic Pressure .- -.- Formation facture pressure @ D.7 #Ift -Production CYP @ 70% -Outside Pressure Conlainment -MASP (production ca.ing) ........Inlermediate CYP @ 45% -Outside Containment for Intermediale casing -MASP (Inlermediate casing) . Current Pressure Readings 9,000 10;000 Graphical Casing Pressure Analysis ver 21x.xls g~~I~~;;;~~~;" ~~br~hed sources where .pecifications are known. If specifications are unknown then values are the lowest value of probable mateñals TVD interpolaled from Openwork. directional.urveys. Values .hould be +/. 25 ft@ 10,000 ft. MD 11,000 ~' '. iU'. -~:å'1T rE' , . t ' \ I ~ ¡ \ ,; t,· W ~ ) ;.,-;::;:"\1 r? fA, ~' n'" ~7"'(';ñ'~ 1'1(. ¡ ~" \ f t ¡ ¡ ¡ ~--~ ¡'i~ \ ,¡"ill': \ ~':~.'~ ¡ : ~. ,1','fA '\ i r t I 'U? U 'lb' iJ\ j¿)'<,\, : ¡ r.1J" r Ii r [ , I" ,_, 'j':'" I \~ \ ! ,:' I ,U Ü ru d '1 gj 'I' ) AIßA~IiA. OIL AND GAS CONSERVATION COltDlISSION / J I f J FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRA TIVE APPROVAL AIO 6.003 Mr. Hal Martin Reservoir Engineer U nocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 S(~.f~N~\jE[) J\PR: ~? 0 2005 RE: Granite Point State 18742 #5 [aka Anna #5] (PTD 167-014) Request for Administrative Approval AIO 6 Dear Mr. Martin: Per Rule 9 of Area Injection Order ("AIO") 006, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. The subject well is not completed with a packer and there is no plan to workover the well to install a packer. 2. Several similarly equipped wells on Anna Platform were previously converted to service wells beginning in 2000 according to a procedure developed by Unocal and approved by the Commission. 3. In support of this application, Unocal has submitted the results of temperature logs obtained prior to initiating injection and approximately 10 weeks later. These operations were conducted according to Sundry permit 04-318. They have also submitted a graphical maximum operating pressure determination. 4. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. 5. Unocal has also begun reporting injection rate and pressure information on the well. The pressure information indicates that the reservoir pressure in Anna 5 is low and insufficient to support a fluid column to surface. The successive pressure information gathered with the temperature surveys indicates that the bottomhole pressure in the vicinity of the well is increasing. 6. Examination of the well file and production history indicates that as best can be determined the well structure is sound and that 2 competent casing barriers exist to prevent the release of pressure or fluids. Mr. Hal Martin March 29,2005 Page 2 of2 ) ) 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point State 18742 #5 [aka Anna #5] is conditioned upon the following: 1. The effect date for conversion from producer to injector is the date injection commenced according to Sundry permit 304-318, October 24, 2004. Unocal shall file form 10-404 noting the changed status of the well. 2. Injection is limited to WATER ONLY; 3. U nocal shall monitor and record wellhead pressures [T /I/O ] (tubing/inner annu- lus/outer annulus) and injection rates daily; 4. Unocal shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 5. U nocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 6. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 7. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person may not appeal a Com . si n decision to Superior Court unless rehearing has been requested. o a: ch ~e, Alaska and dated March 29, 200S. J Chairman ) ) ~ (fù I Ff\ \\ I lu\ æJl \lr\J FRANK H. MURKOWSK/. GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 16,2004 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Larry Greenstein Production Technician UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Granite Point State 18742 #32RD (Anna-32RD) Granite Point State 18742 #5 (Anna-5) PTD: 187-063 Sundry Application: 304-305 PTD: 168-036 Sundry Application: 304-306 PTD: 188-034 Sundry Application: 304-307 PTD: 167-014 Sundry Application: 304-318 PTD: 187-109 Sundry Application: 304-327 Granite Point State 18742 #25 (Anna-25) Granite Point State 18742 #38 (Anna-38) Granite Point State 18742 #37 (Anna-37) Dear Mr. Greenstein: We are returning, without approval, the Applications for Sundry Approval (Form 403) relating to the above-referenced wells, because the relief you request needs to be sought through a different procedure. AIO 6 regulates injection activities on Anna and Bruce Platforms in the Northern Portion of Granite Point Field. When an injection well exhibits an integrity loss, the injection order requires that the Commission be notified and that the Operator submit a plan for corrective action. Corrective action for purposes of an integrity loss means proposing to accomplish the physical well work necessary to repair the integrity loss. A corrective action plan should be submitted as an attachment to Form 403 per usual practice. If it is proposed to keep a well in operation without accomplishing a repair that would restore complete integrity, a request for Administrative Relief ("AR") in accord with Rule 9 of AIO 6 should be submitted. If you desire to request AR, your application should be similar to the attachment submitted with the sundry, however it should also include an evaluation/verification of the remaining barrier(s) that serve to confine injection fluids to the wellbore, SCANNED NO\! 2~ (1 2004 ) ) consideration of trapped pressures and the consequence thereof in any wellbore "space" and an explanation of the management decision not to repair the well. For these particular wells, it is acknowledged that none of the wells are equipped with packers, ordinarily a standard piece of completion equipment for injection wells. Injection was previously authorized for 4 of these wells (Anna-5 is a new application) after a review of the wells' construction and demonstration of integrity via temperature logs and step rate injection tests according to a procedure entitled, "Procedures to Obtain Variances on Packerless Wells (version 4) dated February 9, 2000". This procedure was cooperatively developed by Unocal and the Commission in accord with 20 AAC 25.450 (a), that allows the Commission to authorize less stringent well operating and construction requirements where injection does not occur into, through or above fresh water. All aquifers within 'l4 mile of Granite Point Field are exempt according to 40 CFR 147.102 (b)(2). Should you have any questions on this process, please contact Jim Regg at 793-1236 or Tom Maunder at 793-1250. Ute., U~tan "-- BY ORDER OF THE COMMISSION DATED this LZday of November, 2004 Encl. ~. ~ y z Hal Martin Reservoir Engineer ~,~„ JUG ~ 2008 Unocal Alaska Union Oil Company of Cal is 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL ~~~~~~ August 12, 2004 au G ~ ~ 2ooa~ Tom Maunder Alaska Oil b Gas Cons• Cumrrussron Anchorage Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 CONVERSION TO INJECTOR ANNA PLATFORM WELL NO. 5 GRANITE POINT FIELD Dear Tom: Unocal is proposing to convert Anna Platform Well No. 5 (Permit # 1670140) in Granite Point Field from a shut-in producer to an injector. Enclosed is Form 10-403. ~~~~'---' The Anna Well No. 5, a hydraulic lift producer, developed holes in the short string in December 2002 and was shut-in. Efforts to remedially repair in March 2003 were unsuccessful. Unocal proposes to make the well a Tyonek C-2, 5, 6, 7, 8, and 9 injector using produced water to support AN- 23Rd and 33 which currently produce at combined test rates of 210 BOPD and 50 BWPD (19.2% WC). The plan is to make no downhole modifications, but to use a similar procedure as performed on other conversion projects on the Anna Platform. The procedure is: 1) Baseline temperature survey. 2) Obtain permission to inject. 3) Inject until the well has stabilized (approximately 1 month). 4) Follow-up temperature survey. 5) Obtain variance to inject. 6) Monitor well daily and repeat temperature surveys every two years. Please review the enclosed Form 10-403 and let me know if you have any questions. Sincer ly, J~ ~~ Hal Martin JHM:dma Enclosure 04!GINAL C:\Documents and Settings\ambrudm\Local Settings\Temporary Internet Files\OLK71 Wn-5 Conversion Cover Letter Aug04.doc . ~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25zso / 1. Type of Request: Abandon Suspend ^ Operational shutdown Perforate Waiv Annular Dispos. Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Exten on ^ Other Change approved program^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspend WeII ^ Conversion to Injector 2. Operator Name: UNION OIL COMPANY OF CALIFORNIA 4. Current Well Class: 5. P it to Drill Number: (UNOCAL) Development ~ Exploratory ^ 1 0140 3. Address: P.O. BOX 196247 ANCHORAGE, AK 99519 Stratigraphic ^ Service ^ 6. API Number: 50-733-20010-00 7. KB Elevation (ft): 9. Well Name and Number: 105' Anna - 5 {, 8. Property Designation: Granite Point 18742 10. Field/Pools(s): Middle Kenai 'C' San 11. PRESENT WELL CONDITION SUMM Y Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth VD (ft): PI gs ( asu ): J asured): 10803' 9507' 10784' 9488' none n Casing Length Size D TVD Burst 3` Collapse Structural Conductor 563' 20" 85# / 94# H-40 603' 2110 psi .. 520 psi Surface 2020' 13 3/8" 54.5# J-55 20 47' 2730 1130 psi Intermediate Production 8935' 9 5/S' 40ft/43.5# S-95/N-80 g 5' 810' 57 0 psi 3090 psi Liner 2043' 7" 26# S-95 7 10 ,, 7 9498' 0 psi 5870 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): ng ize: u i Grade. Tubing MD (ft): 10471'-10488', 10860'-10978', 8874'-8883', 9232'-9332', 96 tying - ~ '^E" # N-80 ~ 8796' 11315'-11350', 11435'-11480', 9677', 9749'-9795', 98 98 Sho String - 3 1/2" .2# L-80 8608' 11505'-11575' Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Pr posal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP ketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/1/2004 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is ue and correct to the best of my knowledge. Contact Larry P. Greenstein C~3 263-7661 Printed Name a~~ Larry P. Green, ern Title Production Technician ...,_ Signature ~ 1 P.hD~ie 263-7661 Date 8/13/2004 '~C COMMISSION USE ONLY Conditions of approval: Not' Commission so that a representative may witness Sundry Number: ~O~-~ 3/~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: RBgMS BFL~ Gov 2 2 20~ Subseque Form Required: "' - BY ORDER OF Ap oved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate .' ',:' • Anna • -~~~~ Well No. 5 UNOCAL 76 Actual Completion 9/15/97 CASING AND TUBING DETAIL RKB to TBG Head = 3O' SILE ~~'T GRADE C'ONN ID "TOP BTM. 20" 85-94 CSA Surface 603' 13-3/8" 54.5 J-55 8 RD ST & C 12.165 Surface 2,050' ,~ ~ A 9-5/8" " 43.5 5-95/N-80 8 RD/BUTT. 8.755 Surface 8,965' 7 26 5-95 8 RD ST & C 6.276 8,754' 10,797' Tubing Long String 3-1/2" 9.2 L-80 BTC SC 2.992 8,618' Short S[ring 3-1/2" 9.2 L-80 BTC SC 2.992 8,608' 9-5/8" Csg Breakdown: 0' - 4466' : 40# N-80 4466' - 6452': 40#, S-95 6452' - 8965': 43.5#, S-95 2 3 4 5 ~~ B C JEWELRY DETAIL NO. Depth ID OD Item Long String 1 30' 2.99 11 CIW 3-1/2" DCB Tubing Hanger Half 2 8,618' 3.00 3.86 Crossover, 3-1/2" Buttress Box x 3-1/2" EUE 8 rd Pin 3 8,619' 2.68 6.5 Kobe, 3", Type "B", Pump Cavity 4 8,642' 3.00 4.5 Crossover, 3-I/2" EUE 8 rd Pin x 3-1/2" Buttress Box 5 8,796' 3.00 5.25 Wireline re-entry guide, 3-1/2" Buttress Box 0 Short String A 30' 2.99 l 1 CIW 3-1/2" DCB Tubing Hanger Half B 8,608' 2.00 3.86 Crossover, 3-I/2" Buttress Box x 2-3/8" EUE 8 rd Pin C 8,609' 2.00 2.37 Pup, 2-3/8", 4.6#, L-80, EUE 8 rd Fish: I 1,198' Tail Pipe, 2-7/8", 6.4#, N-80, Buttress @ 9,348' DPM PERFORATION HISTORY Interval Accum. Date Zone To Btm Amt s f Present Condition C-2 9,072' 9,087' 15' Initial then re erfed C-5 9,323' 9,440' 117' C-6 9,523' 9,580' 57' C-7 9,755' 9,995' 240' C-8 10,170' 10,411' 241' C-9 10,583' 10,613' 30' Partial) coverd b fill See Perforation Data Sheet for more Detail PBTD = 10,784' TD = 13,821' MAX HOLE ANGLE = 33° @ 1,850' O:\OOE\OOEFields\GPF\Anna\Wells\An-OS\Schematics\A-SSchm9-19-97.doc DRAWN BY: tcb REVISED: 9/19/97 Procedures to Obtain Variances on Packerless Wells (version 4) February 9, 2000 It is preferred that wells have been shut-in for an extended period of time. Injection fluid will normally be filtered Cook Inlet water at --55 deg F. 1. Do a base line temperature profile from surface to top of perfs. 2. Start injection -after 14 days, run a standard step-rate-test per SPE recommended procedure. Run test to maximum allowable pressure. Repeat step-rate-test after injection pressures have stabilized. 3. After 30 days of injection, run a temperature profile making stops as in the baseline survey (if appropriate) and hang recorder in well. Note: if the stops used in the baseline profile are not appropriate, make appropriate stops in this pro#le and use in all subsequent surveys in this well. 4. After 48 hours, retrieve recorder and run a temperature profile from the perfs to the surface using the appropriate stops. 5. After retrieving the recorder, run in hole with high speed recorder which was used for Step #1. 6. Compare the series of profiles to the baseline. 7. Evaluate all data from the temperature profiles and the step-rate-test to determine if the there are indications of leaking casing and or upward flow behind the casing. 8. If the conclusion is that there are no casing leaks above the zone and no upward flow behind the pipe, the well can be put back on injection. 9. Daily injection rates and tubing and surface casing pressures will be recorded daily and reported to the AOGCC monthly. 10. If injection rates or pressures or surface casing pressure indicate the possibility of a casing leak, the well will be immediately shut-in and the AOGCC notified; future operations will then be as agreed. 11. The well will be tested every two years for mechanical integrity as in the above steps or by another procedure acceptable to the AOGCC. ,~. ~ • Hal, This note confirms our conversation this morning regarding the conversion of Anna 5 from producer to injector. A review of the specific requirements of our injection orders has determined that in order to comply with those requirements, a "process" change is needed. The process change will apply to service wells lacking regulatorily required completion equipment (in this case a packer) or service wells that have less than complete mechanical integrity (tubing, casing or packer leaks) where the operator does not propose to make repairs. For Anna 5, you will need to make an application for an administrative approval (AA) under rule 9 of the Area Injection Order 6 (AIO 6). AIO 6 applies to Anna and Bruce. We are fortunate in that a "process" was developed in early 2000 that addressed the demonstration of mechanical integrity on wells lacking packers. According to the sundry you have submitted, you plan to perform the work outlined in procedure developed in 2000. With regard to the sundry you submitted, it has been approved to allow you the opportunity to begin the work to demonstrate that the well has the integrity necessary to operate as a service well. 1 of 1 9/10/2004 3:42 PM MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Jo~ Chairman ~ Blair Wondzell, P. I. Supervisor FROM: Lou Grimaldi,~'~'~-/~.~- SUBJECT: Petroleum InslSector DATE: September 9, 1997 FILE NO: AOAJIIEE.PIR Not Confidential BOP test HWC #123 UNOCAL Anna platform Well #A-5 Granite Point field PTD #67-014 Tuesday, September 9, 1997; I witnessed the initial BOP test on the Hydraulic Well Control's unit HWC #123 , owned by Hydraulic Well Control of Houma, Louisiana. They were preparing to change tubing and cavity in UNOCAL's Granite Point, Anna well # A-5. The BOPE for this rig was for the most part, second party owned. The stack, a 5000 pound Schaffer double gate shorty and Hydril annular preventer are owned by UNOCAL. The Accumulator and Choke manifold assemblies were provided by DSR of Anchorage. The rest of the equipment was owned by Hydraulic Well Control. I found all necessary ancillary equipment including PVT, gas detection and remote choke panel to be in place and in good operating condition. The BOP test went fairly well with two failures observed. The single pipe rams had a small leak at the high test of 5000 psi, these were changed requiring a special flight from the beach for replacement elements. The IBOP also failed and the replacement that was onboard was brought up and tested "OK". There were two floor safety valves that tested good, these and the good IBOP all had the proper connections for the tubing they were preparing to pull (3 1/2 buttress). AOAJIIEE.DOC (PAGE 2 OF 2) I worked with both the Day and Night pusher's (Lenny Goin/Gene Buquet) and found them to be highly competent and a pleasure to work with. Both pushers held MMS certification for well control. The test spanned nine hours which included approximately three hours of downtime waiting on and installing the pipe ram elements. SUMMARY: I witnessed the initial BOP test on the Hydraulic Well Control unit HWC #123. Two failures observed, parts replaced, and retested ok. Test time 6 hour's - 2 failures. Attachments: AOAJIIEE.XLS cc; Dan Williamson (UNOCAL drilling supt.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Hydraulic Weft Control Rig No. 123 PTD # UNOCAL Rep.: A #5 Rig Rep.: Set @ Location: Sec. X Weekly Other 67-014 DATE: Rig Ph.# Larry McAIlister 9/9/97 776-6626 Lenny Goin/Gene Buquet T. R. Meridian TEST DATA MISC. INSPECTIONS: Location Gen.: Fair Housekeeping: Fair (Gen) PTD On Location N/A Standing Order Posted n/a* Well siCn P Drl. Rig N/A Hazard Sec. N/A BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 250/2500 P I 250/5, 000 F N/A 250/5, 000 N/A I 250/5, 000 P 1 250/5,000 P 1 250/5,000 P 2 250/5, 000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F N/A 250/5,000 N/A N/A 250/5, 000 N/A 2 250/5, 000 P 1 250/5,000 F CHOKE MANIFOLD: No. Valves 10 No. Flanges 27 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5, 000 I P 250/5,000 ] P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure 3,050 P Pressure After Closure 1,950 P 200 psi Attained After Closure minutes 42 System Pressure Attained 2 minutes 43 Blind Switch Covers: Master: P Remote: Nitgn. Btl's: Four Bottles 2150 Average Psig. sec. sec. P TEST RESULTS Number of Failures: 2 ,Test Time: 6.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659.3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Pipe rams failed, replaced elements and retested "OK"./BOP failed, brought up spare and tested "OK" No place for standing order's in basket, Explained meaning with workover crew and Drilling foreman. Gas detectors tested after test "OK". Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi FI-021L (Rev. 12/94) AOAJIIEE.XLS To: Mr. Jack Hartz - AOGCC, Fro: Dan Williamson Re: Hydraulic WO Unit Well Control Piping · IIIIII . IBiiii II .._ II I On August 28, 1997, Unocal Alaska will mobilize Hydraulic Well Control's hydraulic workover unit to Baker Platform to perform a pump and tubing change on Baker Well 13. Upon completion of this work the unit will be sent to Anna Platform to perform the same task on Anna Wells.~5, 2~6, and 38. These wells are all no flow wells, having no packer or safety valve tn them.'7'Our data shows that the Anna wells are extremely subnormal pressured (1,840 psi at 8,200 ft 'I'VD), have a high water cuts and produce very little gas. The Baker well is higher pressured but will be readily killed with filtered inlet water; it also has a high water cut and produces very little gas. The hydraulic unit will be on each well for a brief time. The wells are not considered by Unocal Alaska to be a high welt control risk. We respectfully request the following variances be granted: 1, To employ the use of 2", 5M, Steel Molded Lines and Fittings with 1502 Weco Unions for service as a Kill Line and Downstream Choke Line. 2. To use the production Iow pressure separator system as opposed to the use of a "Poor Boy Degasser". _Sincerely, 'Note 7671 Page I of 1 Calculation UNOCAL~) Recoro .f FORM 1,2C.50 (REV, 2-67) PRINTED IN U,S,A, CHOKE I/AN, UNE ~; 5~ ;LAN~E 2', 5M 150e IlNION TO PROI)IJC~ON 5M STEEL UNION CIRCULATING PLATFORMS SYSTEM FOR HWC ANNA AND BAKER tlANU~ CHOKE '3 :-.: 3 ~/8', 5M kRMORE1) HOSE .4.', 5M HYD FLOW UNE . 2". 5~ ~502 ::~ 3., 5M UNION KELLY UNE . ,,--- 2', 5M LOTORC ['9 2' 15~ 2', 5M SlEEt ,,/,5o~, UNION FRO~ PU~P %\ TO PRODUCTION OVERHEAD VIEW FROM WELL P,~IC UNE 1t3" PRODUCTIO~ SIDE VEW PANIC UNE GAUGE VALVE 81" AT gO DEGREES _1 1/8" , 5M CHOKE MANIFOLD PLATFORMS BAKER/ANNA IUNOCAL )I UNOCAL Alaska Drilling Department To: Mr. Jack Hartz AOGCC From: Dan Williamson Re: Hydraulic WO Unit Well Control Piping Pages including cover sheet: 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: Alter casing: Repair well: x Other: x 2. Name of operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X RKB 105' above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Point State 18742 4. Location of well at surface Leg 4, Slot 4, Anna Platform 8. Well number 774' FNL, 709' FEL, Sec. 12, T10N, R12VV, SM Anna #5 At top of productive interval 9. Permit number/approval number 1346' FSL, 1847' FWL, Sec. 12, T10N, R12W, SM N/A At effective depth 10. APl number ~r 50- 133-20010 At total depth 11. Field/Pool 840' FSL, 1567' FWL, Sec. 12, T10N, R12W, SM Granite Point 12. Present well condition summary Total depth: measured 10803' feet Plugs (measured) N/A true vertical 9507' feet Effective depth: measured 10784' feet Junk (measured) N/A true vertical 9488' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 173' 20" 1085 sx 203' 203' Surface 2020' 13-3/8" 1233 sx 2050' 2047' Intermediate Production 8935' 9-5/8" 650 sx 8965' 7810' Liner 2043' 7'' 500 sx 10797' 9498' Perforation depth: measured See attachment true vertical Tubing (size, grade, and measured depth) LS: 3-1/2.', 9.2#, N80 8686'; 2-7/8", 6.5#, N80 8710'-10546'; 1-3/4" coil (1.53" ID) 35'-8538' SS:: 3-1/2'', 9.28, N80 8679'; 1-3/4" coil (1.53" ID) 35'-8518' Packers and SSSV (type and measured depth) Kobe 3" Type B BHA {~ 8709', 1-3/4" Jet pump cavity ~ 8540' and 852~i~, ~ ~ I" ! ~ I !" I~, 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/AAUG 1 2 1996 Treatment description including volumes used and final pressure Alaska 0t! ,~. ~s Cons p, nmmi~sion t4. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut in due to hole in Kobe Cavity Subsequent to operation 231 21 541 105 110 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: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale Haines .~~.. 4;2) i ¢;4,,.~ Title: Drilling Manager Date: August 1, 1996 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ANNA #5 PERFORATION SUMMARY Perforating Performed on 7/9 and 7/10/96 9072'-9087' 9323'-9333' 9523'-9540' 9567'-9577' 9905'-9985' 10170'-10180' 10234'-10294' 10376'-10411' Perforation Depth: Measured: True Vertical: 9072'-9084' 9323'-9440' 9523'-9580' 9755'-9995' 10170'-10411' 10583'-10613' 7899'-7910' 8116'-8216' 8288'-8341' 8503'-8726' 8894'-9128' 9295'-9323' ANNA 5 Coiled Tubing DAY (3) (7/12/96) RIH AND RETRIEVE PACKER PLUG IN LS. RU ON SS. RIH WITH PACKER TEST PLUG AND INSTALL IN PBR. SHEAR OFF PLUG. FILL SS WITH 39 BBLS OF POWER OIL. TEST PLUG TO 500 PSI. LOST 110 PSI IN 10 MIN. RIH AND LATCH PLUG AND EQUALIZE. POOH AND RD. WAIT FOR CTU. DAY (4-5) (7/17-18/96) HOLD PRE-JOB SAFETY MEETING. RD SWAB VAVLES. UNLOAD BOAT AND SPOT CTU AND EQUIP. RU 1-3/4" CTU ON LS. PUMP BALL THROUGH COIL. TEST COIL AND BOPE. MU CTC AND TEST. MU BHA #3. STAB RISER AND PERFORM SHELL TEST OF LUB. RIH WITH BHA#3. STAB SEAL ASSY. INTO PACKER. SPACE OUT. CUT COIL. MU CT HANGER. MU GS RUNNING TOOL AND RIH AND LAND HANGER. TEST HANGER. RD INJECTOR HEAD. RU SLICLINE AND DROP 1-1/4" JET PUMP WITH BLANK DIFFUSER. TEST PACKER AND SEALS. RIH AND ATTMEPT TO RETRIEVE JET PUMP. MAKE THREE ATTMEPTS--NO RECOVERY. SDFN. DAY (6-8) (7/19-21/96) RIH WITH SLICKLINE AND ATTMEPT TO RETRIEVE JET PUMP WITH BLANK DIFFUSER. PUMP DOWN ANNULUS AND RETRIEVE. INSTALL JET PUMP AND ATTEMPT TO PRODUCE. NOT OPERATING. PULL JET PUMP AND RUN JET PUMP #2. WELL WOULD NOT PRODUCE. RIH WITH BLANKED JET PUMP. PRESSURE TEST COIL. OK. PRESSURE TEST ANNULUS. ANNULUS ON VACCUUM. RU CTU AND PULL LONG STRING COMPLETION. DIFFUSER IN PUMP CAVITY OFF SEAT. CHANGE OUT SAME. RIH WITH CT AND INSTALL NEW CONPLETION. TURN WELL OVER TO PRODUCTION. WELL PRODUCTION 814 BFPD. FLUID LEVEL DROPPED FROM 3,500' TO 4,300' IN 2 HOURS. Anchorage DAY (9) (7/22/96) CONTINUE TO TEST LS. FLUSH SS WITH 76 BBLS OF POWER OIL. C/OUT CT SPOOLS AND RU BOPE ON SS. PUMP 1-3/8" BALL NAD NERF BALL. TEST BOPE. OK. MU CTC AND BHA WITH LIVE JET PUMP INSTALLED IN CAVITY. RIH TO 8,500' (CTM). STAB SEALS INTO PBR. SPACEOUT. LAND COIL AND RD CTU. NU SWAB VALVE AND PRODUCTION LINES. TURN WELL OVER TO PRODUCTION. SDFN. DAY (10) (7/23/96) RU DOWELL PUMP ON 3-1/2" X CT ANNULUS. ESTABLISH FLOW PATH AND REVERSE CIRUCLATE. RD PRODUCITON LINES AND RU SLICKLINE. RIH AND RETRIEVE JET PUMP. BREAK DOWN PUMP. FULL OF SCALE IN PORTS. PRESSURE UP ON CT. DIRECT COMMUNICATION TO ANNULUS. RD SLU AND BLOW DOWN CT. CHANGE REELS. STAB PIPE. SECURE WELL. SDFN. DAY (11 ) (7/24/96) TEST BOPE. FLANGE CONNECTION FAILED. CHANE OUT APl RING. PULL SEALS LOOSE AND REMOVE SEAL BODY UNIT. POOH WITH 1-3/4" CT. LD BHA. SEAL ASSEMBLY FULL OF SCALE. CHANE OUT SEAL ASSY. AND MU BHA. RIH WITH BHA #2 ON 1-3/4" CT. PUMP 10 BBLS OF FIW DOWN ANNULUS OT FLUSH PACKER. WELL ON GOOD VACCUUM. RIH AND STAB INTO PBR. SAPCE OUT AND LAND HANGER. PUMP 23 BBLS OF FIW DOWN CT WITH ANNULUS COLSED. SHEAR OUT PLUG. TEST WELL WITH DOWELL. RD CTU AND PREP FOR LOAD OUT. INSTALL SWAB VALVE. RU SLICKLINER ON SS AND LS TO CONFIRM DRIFT TO PULL PUMP. DAY (12) (7~25/96) TURN WELL OVER TO PRODUCTION. MONITOR WELL. LOAD OUT EQUIPMENT. WELL TEST: 231 BOPD, 541 BWPD. LAST REPORT RECF VF.D Anchorage UNOCAL ) ANNA PLA. FORM WELL # 5 ACTUAL COMPLETION: 7/25/96 KB = 105' MSL; CSG HEAD ELEVATION = 75' D Cut Fish Tagged Fill ~ 10,462' (7/26/96) 10,645' (8/17/87) PBTD = 10,784' TD = 13,821' MAX HOLE ANGLE = 33° ~ 1850' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 2O 85-94 CSA 13-3/8 54.5 CSA 9-5/8 40-43.5 N-80 7" 26 S-95 Tubing Long String 3-1/2 9.2 N-80 2-7/8 6.5 N-80 Used Coil in Long String 1-3/4 1.91 Short String 3-1/2" 9.2 N-80 Used Coil in Short String 1-3/4 1.91 30 203 30 2,050 30 8,965 8,754 10,797 BTC 30 8,686 8rd EUE 8,710 10,546 BTC 30 8,527 30 8,679 30 8,507 JEWELRY DETAIL NO. DEPTH ITEM Long String 1 8,687 2 8,709 3 8,710 4 10,547 5 8,532 6 8,538 7 8,541 Sho~ String A 8,688 Cut 8,546 Fish 8,639 B 8,512 C 8,518 D 8,521 TOP BTM 3-1/2" Buttress Crossover KOBE 3" Type B OPF BHA (Pump Cavity) 3-1/2" 8rd X 2-7/8" EUE XO Guide Shoe X-Landing Nipple Trico 1-3/4" Jet .Pump Cavity 3-1/2" HES RCP Packer 3-1/2" X 2-3/8" Crossover Chemical Cut TBG 2-3/8" W Circ plug X-nipple Trico 1-3/4" Jet Pump Cavity 3-1/2" HES RCP Packer PERFORATION DATA ZONE SPF DATE COMMENTS 9,072 9,087 C-2 9,323 9,440 C-5 9,523 9,580 C-6 9,755 9,995 C-7 10,170 10,411 C-8 10,583 10,613 C-9 4/2/3 67/74/96 4/2/3 67/74/96 4/2/3 67/74/96 4/2 67/74 4/2/3 67/74/96 4/2 67/74 Initial then Re-perfs O:~DRILLING\SCHEMATIC\GP\GPPLA5C2.DOC REVISED: 6/12/96 DRAWN BY: MWD Form ~o. STATE O, ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT ]~ DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL ~ GAll WKLL w~LL ~~TOR Amoco Production Company ~ DRESSOFOPERATOR P. O. Box 779, Anchorage, Alaska 99510 4 LOCATION OF WEI~L Leg 4, Slot 4, Granite Point Platform "A," 774' FNL, 709' FEL, Sec. 12, T10N, R12W, S.M. ~ APZ NU~EmCAL COD~. 50--133--20010 LEASE DESIGI~ATION AND SERIAL NO. ADL-18742 ~' IF INDIA~ ALOTT'EE OR TRIBE NAME 8. L,~IT F.~%M OR LEASE NAME Granite Point Stage 18742 9 W~.LL 5 ~ AND POOL. OH WILDCAT Granite Point om,T~ Sec. 12, T10N, R12W, S.M. 12. PE~t,MIT NO 13. REPORT TOTAL DEPTH AT END OF MONTH. CI-La..NGES IN HOLE SIZE, CASING AND CEIVIENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED. pE.H,FOF,_ATIONS, TESTS A.N-D RESULTS FISHING JOB~ JIL'NK IN HOLE AND SIDE-TI~ACKED HOLE A~D ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS The Subject well was worked over to convert from a flowing to a Kobe lift producer and to reperforate the production interval. June 16 June 17- June 18 June 19 June 20 June 21- June 23 Rig OC 1200 hours, 6-16-74. Prepared to pull tubing and pulled 3-1/2" Buttress tubing. Cut 2-7/8" tubing at 8605' and prepared to pull tubing. Attempted to latch on to fish at 8605' with overshot. Jarred fish loose with overshot and recovered packer and 2-7/8" tailpipe. Cleaned out to 10,647' with bit and scraper. following intervals with 2 SPF: 9074-9084' 9330-9400' 9410-9440' 9528-9538' 9570-9580' 9755-9790' 9805-9830' 9845-9895' Perforated the 9910-9985' 10,173-10,183' 10,230-10:;290' 10,370-10,410' 10,583-10,613' Installed 2-7/8" EUE tailpipe, Type B OPF Kobe BHA and dual 3-1/2" Buttress tubing. Landed 2-7/8" tatlpipe at 10,573' and BHA at 8696'. June 24 June 25- June 30 Run Kobe 3" x 2-1/2" Pumping N.G. x 1-7/8" pump and put ,IIIL DIVISION OF OIL._ O_ S ~ th. {orego,~i~?'''ue andTl're~ ........ ndent NOTE --Report on th s form is required for ea~ oalendar ~nth% regardless of fha status of operations, and must ~ filed 'In duplicate with the oil and got conoervot~n commiflee bythe 15~ of the suoc~ding ~n~. ~le~ otherwise directed. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 May 6, 1974 File: GJR-286-WF Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage,'Alaska 99501 Dear Sir: I~ c-~o~. J I ? O~:aL I '.---- '-'1 2; GEoL I'-- ...... I ...... i~v 'l- '--j DRAFT I I SEC J CONFER: 'FILE: Re: Sundry Notice and Reports on Wells Granite Point 18742 Well No. 5 Attached for your authorization are necessary copies of State of Alaska Form 10-403 forC~e~~of the subject well. Verbal approval for this Workover wa~-~e~-iv~from Mr. Lonnie Smith by Mr. L. R. Chism on May 3 1974. George J. Ross Area Superintendent Attachments OiL ~D GI~S Form 10 - 403 REV. I - ~0 ~brnit "Intentions" in 'triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO.N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APP-I.ICATION 'FOR ~EIt~I'/'-L-'' 'for such . °' 2] WELL WELL OTHmR 2,NAME OF OPERATOR Amoco P. roduction .Company ADDRESS OF OPERATOR P. O. Box 77.9.; An. chorage~ Alaska 99510 4.LOCATION OF WF~LL ^tsurface Leg 4, Slot 4, Granite Point Platform "A," 774' FNL, 709' FEL, Section 12, T10N, R12W, S.M. 13, ELEVATIONS (Show whether DF, RT, GR, e~c. RKB 105' above MSL AP1 NUiVIEP. ICAL~ CODE 50-133-20010 I.~,A~I~ DES4GNATION AND SERIAL NO. ADL-18742 ~. IF I1N-OIA.N, A.I.~O'z-l'.e~ 01~. TRIBE NA2VI~ Granite Point State 18742 9. WEL~ NO, 5 1~. FLEI~D AaN'D POOL, OR WILDCAT Granite Point n. SEC,, T.. ~., ~.. (morrom OBJECTIVE) BHL: Sec. 1.2: T10N, R12W,'S.M. 12. PEI~.JV~T BIO. NOTIC~ OF INTENTION TO: 8UBIEQUENT ItIFOBTOF: FRACTURE TREAT MULTIPLE COMPI,ETE FRACTL'RJ TJJAJJJ~T J ALTIRING CABING 8HOOT OR ACIDIZ~ ABANDON~ BHOOTING OR ACIDIZINO , ABANDONMEnt* nEPAIE W~LL CHAN0[ PLANB pump (Other) (No~: Report results of multiple completion on Well ,Other)convert from flow~n~ to Kobe i ,, Completion or Reeompletion Report and Lol form.) 15. v~:scR~ag PnoPosE9 o~ COMPLETED OP~RATION~ (Clearly stat~ all pertin~nt d~talls, and gtv~ vertln~nt dates, lneludln~ estimated dat~ of starting any ~roposed work. To da~e, we have been unable to bring the subject well back to a flowing status s~nce ~he Gran~e Poing pipeline has been repaired and ~he platform put back on production. If we are unable to geg the well ~o flow, we plan Co change ~o Kobe 1ii~ and will perforate the following intervals during ~his operation .at. 2SPF: 9074-9084~; 9330-9400'; 94~0-9tt0~; 9528-9538'; 9570-9580'; 975549790'; 9805-983D'; 98~5-9895'; 99~0-9985'.~. ~0,~73-~0,~83'; ~0~230-~0,290', ~0,370-~0,~O:; and ~0,583-~,6~3~. (~o~a1 of~455' or 9~0 sho~.) Per verbal approval received from Mr. Lonnie Smith by Mr. L. R. Chism on May 3, 1974, the well will be pumped for at least a 30-day period and then the pump will be shut down for a 24-hour period to determine if the well is capable of flowing. MAY ? 1974 DII/ISlOI OF OiL (This space for StYe offi_c'~) ....... CONDITIONS OF aPP~a~,' Z~ i~: / / - - May 6, 1974 See Instructions On Reverse Side Approved Copy Returned November 15, 1972 File: ASH-237-WF Mr. Leland Franz Skelly Oil Company 1088 Lincoln Tower Building 1860 Lincoln Street Denver, Colorado 80203 Dear Mr. Franz: Re: Middle Ground Shoal Field 17595 Well No. 11 Amoco Production Corn P. O. Box 779 Anchorage, Alaska Regarding your inquiry dated 11'7-72,, a review of our records indicates that our M~jiddle Gr..o~md. S.hoal Wel.1. No._l~l is being reported in error as a gas lift well on' State of-Aiaska Forms 10-405. Middle Ground Shoal Well No. ll's conversion to Kobe was finalized March 13~ 1972, and our records have been corrected to indicate hjfdraulic p~Lnp as current method of lift for this well. · A further review of our records indicates that due to a transposition error, Granite Point State_lB742, Well No_. 5, has been carried as hydrauli~ pumping well on F~m 10-~05 since October~ 197_1. Please cor- rect your records to reflect this well as a ~l.o.win_g well. Very truly yours, ms. A. S. Haley Area Administrative Supervisor AND FGrM P-~7 SUBMIT IN DUPLI~ .E* STATE OF ALASKA (See 6£her ih: structions on OIL AND GAS CONSERVATION COMMISSION reverse side) WELL COMPLETION OR RECOMPLETIC}N REd'PORT AND LOG * la. TYPE OF WELL: b. TYPE OF COMPLETION: NeW [] WORKU] WELL OVER OIL [] GAS ['~ ~-~ Other %VELL WEI~L L__I DRY ! EN BACK R~SVR. g~ Other 2. NAME OF OPERATOR ( Pan American Petroleum Corporation:" ADDRESS. OF. OPERATOR . P. O. Box 779 - Anchorage, Alaska 99501 4. LOCATION OF WELL (Report locatioa e]early aad ia accor~aace wtt~ aay State reeuiremeata)* At surface Leg 4, Slot 4, Granite Point ~latform A; 774' FNL, 709' FEL, Sec. 12, T10N, ttl2W, S.M. At top prod. interval reported below r~ 1346' FST,, 1847' FWL,- Sec.~;12, T10N, R12W, S.M. At total depth ~ '- ~ 840' FSL, 1567' FWL, Sec. 12 ! 14. PERMIT NO. T!0N, R12W, S.S.[ 67-14 5/6/67 9/5/67 ; i 9/.20/67 API #50-133-20010 ~ Effective: July 1, 1964 · 5. ,LEASE' DESIGNATION 'AND SERIAL' NO. ADL- 18742 7. UNIT AOREEMENT NAMe $. FARM OR-LEASE NAME Granite Point State 18742 9. 'WELL NO, 5 10. FIELD AND I~00L, OR WILDCAT Granite Point 11. SEC., T., R., M;, OR BLOCK AND SURVEY OR. AREA BHL: Sec. 12, T10N, R1ZW, SoMo I2. BOROUGH , [ 113. SiTATE Kenai [ Alaska DATE ISSUED ] 4/20/67 18. ELEVATIONS (DF, RE;B, aT, GR, ETC.) 19. eLeV. CASiNGHeAD 15. DATE SPUDDED RKB 105' above MSL ] '~ 75' 20. ~rrAL DeFrH, ~D ~ ~ 1:~21, PLUO, EACh:. LO., MD ~ ~WO ] 22: IF MULTIPL~ COMPL.', : 10,803' MD'l'.. ~10,78~4':MD -{~_ :'~°w 24. PRODUCING IN~ERVAL(S), OF THIS COM~E~ION TOP, 'BOTTOM, NAME (MD AND 23. INTERVALS ROTARY TOOLS DRILLED BYI 0 -. TD 9074-10,608' - '?C'?'Unit,- Middle Kenj~i Formation 26. TYPe eLECTRIC AND OTHER LO~-G8 RUN CASING SIZE ] WEIGHT. LB./F~ 20,' I 85~& 13- 3 / 8" 54.~5# '~ 9-5/8" 40~ & 43.5# CABLE TOOLS 25. WAS DIRECTIONAL SURVEY' MADE 28. lES, GR-So~nic, Dipmeter) GR cbllar, lo~ator (.,, CASING RECORD (,~ep~r~t alt striags set ia well) yes 27. WAS WELL CORED No ..~IOLE SIZE CEMENTING RECORD AMOUNT PULLED DEPTH SE~,.j_(MD)., ["> ~ 603' 'f ~ ~050' _ ~ 8965' , :1 7-1J 2" 1085 sx 1233 sx :12-1/4" 650 sx 30. TUBING RECORD . I~INEt RECORD '-- size TOP (MD) ~ [ BOT~bM.~;(MD) ~SACKS CeMEN~~ 10,598-608',~~, 10, SCREEN (MD) 1.0, 230-4-0', 10,173.~83', 9975-95', 9910- 60', 9850-80', 9810-30', 9760-80', 9570- 80' 9523 38' 9410-40' 9330-90' 9074- - 84' all with 4 j spf. 33.* PRODUCTION' DATe FIRST PRODUCTION I I;RODUCTION METHOD (.Floto'iag~ ga8 ltft~ pumpiag--si~6 aa~l type of pump) 9/15/67 [ Flowing SIZE [ DEPTH SET (MD) PACKER SET (MO) 10, 611' 8645. (dual) 8, 657' 82. ACID, SHOT FRACTURE, CEMENT SQUEEZE, ETC. DEPTH-INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED WELL STATUS (Produciag or a~u~-~a) Producing DATe OF TeST HOURS TeSTeD [ CHOKe SiZe ~ PROD'N. FOR ] OlL--~BBr.._. TEST P~RIOD _ [ GAS MCF. 9/19/6'/ 6 I124:5/64~ ~ > 2301 1392 F~W. T~ING P~8. CASING PRESSURE [ CALCULATED OI~BBL. GAS--MCF. 24-~0'ua a~ : 300L, 375S ~-: > [ 9204 5568 WATER--BBL. J GAS-OIL RATIO 23 [ 605 WATER--BBL. OIL GRA¥ITY-APZ '(CORR.) 41.2° 34. DISPOSITION OF GAS (~old, used ~orfuel, veated, etc.) [ TEST WITNESSED BY I Flowed ~. LIST OP ATTACHMENTS Electric Log, Well History ce the foreg~ng and tt&.~.~ed information is complete and correct as determined from all available records .10NED ' TITLE A..S'$1. t. Area A.dmln. Supvr. Jnstructi-(~n~an ' d Spaces [or Additional Data on, Reverse Side) 0C~' *(See INSTRUCTIONS C~nerai.~This form is designed for s~bmitting a complete and correct well completion rePort and log on all-types of lands and leases' to either' a Federal agency or a State agency," J~r bo ~t~h,-,"pursuant to applicablo Federal and/or 8tare laws 'and. regfilations. Any necessary special instruction~ concerning_ the use of this J~orm and the number of copies to be : ghbmi~t~d, particularly with regard t~ local, area, or regional procedures and practices, either are shown below or ~ill be issued by, or may be obtained from~ the ~oeal Federal and/or~tate office. See instructions.~on items 22 and 24, and 33, below regarding separate reports for separate{ eomp-letions. .~II 'notr.~!.ed prior to the riCe this sammary record is submi~ed, copies of all currently available log~ (drillers, geologists, sample and core analysis, all types electric, etc.) ,~brma- tfon and"pressure tests, and directional surveys, should be attached hereto, to th~ extent required by applicable Federal and/or State laws an(1 regulations.' All attachments -should _b~ listed on this form, see item 35. . . · 'Ifcm 47 If there are no applicable State requirements, locstions on Federal or Indian land should be described in accordance with Federal requirements. Consult local State 'Ji' Fedm~l office for specific instructions. II,~m tll.-~.Indicate which elevation is used. as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments.' I~ems '2~a~d 24: If this well is completed for separate produetio{~ f~om more than one interval zone (multiple completion), so state in item 22, and in item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any)~ for only the interval report.~l tn item 88. 8ubmit.a ~parate repo~ (page) on thia form, adequately identified, for each additional interval to be separately produced, shOwing the additional data pertinent to such interval I~m 1~: "~gacl~s Cement": Attached supplemental records for this~well should show the details of any multiple stage cementing and'the location of the cementing tool. ifem 33: Submit a separate completion report on this form for 'each interval to be separately produced. (See instruction for items 22 and 24 above.) . . _ . ~7. SU.~I~IAR¥ OF POROUS ZONES: · . 'Y SHOW ALL IMPORTAI~T ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND AL~ DRILL-STE~ ~ESTS, INCLUDING 38. ~EOLOGIC ~ARKERS DE~H INTERVAL TESTED~ CUSHION USED, TIME TOOL OPEN, FLOWINO AND SHU~-IN PRESSURES, AND RECOVERIES FOR3IATION TOP BOTTOH DESCR!PTION~ CONTEHTS, ETC. ' TOP ' . .. . - NAME _ MEAS. DEPTH TRUE VER~. DEPT~ 'M~S Sand 9320' 9'450' SS, white,med-coarse-g.,vry. cong., ~. 'Member ......... poorly sorted, _.quartZose, sOme jasper, Beluga' " ~ 4240' ~3'791' : .' . ,~ fair poro. , oil bearing . _.~ '. : ~ .~.. 9510' 9580' ~- '-'~S, brn-white, fine,med-g.,sli, cOng', 'M~S sand '6670'- ~858' . - ~_ ~ ,argi}l. , poor- fair poro. ,_ oil~bearing, r~" Membe~ ~; .:'~. . . .. ~ TD.... "~ ~.~ ~-. 9750' "~9990' ~ ~,white, me g.,sli.'cong.,looSe qtz ~--."' ~ . " ' ' grains, fair ~poro., oi~bear!ng . . ~ .. : ~- --.I017f0' 10290' - SS, brn-white, fine-med-g.,sli, cong., ' - ' ~ ..-. . ' .. "~ -- _ . pood-fair sor~,~ sub ang. , argill. ~ silty, ": ~ .. . ~ .' <}- [~- . ' .... ,fair poro., ~il ~e-aring - ..... ,: ~ , :~-- ,~' ~. 10370' ' 10~10' SS;white,-fine-~ed-g., sli. cong., pgor ~ . . " 'fn~i - ...... .~' ~ :.~ s0rt~.- subrd.~_~ 7/ r poro., oil~ bearing ,~ . '.:- Chronological Well History Granite Point State 18742 #5 5/06/67 5/09/67 Spud with drilling rig from Leg 4, Slot 4, Granite Point PlatformA; 774'FNL, 709'FEL, Sec. 12, T10N, R12W, S.M. Drilled to 650' and set 20'r casing at 603' with 1085 sx. 5/16/67 Drilled to 2088' and set 13-3/8" casing at 2050' with 1Z33 sx. 6/20/67 Drilled to 8948' and stuck while drilling off whip- stock No. 6. 6/30/67 7/o3/67 Completed fishing and drilled to 8972'. Set 9-5/8" casing at 8965' with 650 sx and tempo- rarily suspended. 8/14/67 9/06/67 Move on workover rig. Drilled to 10, 803', logged and set 7" liner 8754- 10,797' with 500 sx. 9/11/67 Perforated 10598-608', 10308-400', 10270-90', 10230-40', 10173-83', 9975-95', 9910-60', 9850- 80', 9810-30', 9760-80', 9570-80', 9523-38', 9410- 40' 9330-90', 9074-84' all with 4 jspf. 9/12-19/67 - Run tubing and complete and flow test. 9/Z0/67 Completed as flowing oil well. RECEIVED OC' 20 1967 DIVISION OF MINES ~ MINERAL~ .1: t', ^ ~ C"O" II '17 0 }:: ^ . . 1' T [} N ... DIP, I~C'£io};AI. COiqTROI. ,. · __ E .. ...~.~ 2'et' ,!. D C. ourse Eactor 'TVD ' FaCtOr . . __[_.~'_?~._z7 - N S · W Dogleg · _.~_.~.~_':_o~ .... 4_1.77 ,, P A N A H E 1~"[ C ,~." 'C 0 R P 0 R A T I O'N " DIRF. CTIOi'fAL CO;iTftOl,..:', ) Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 orr,=- Anchorage State 18742 LESSEE'S MONTHLY REPORT OF OPERATIONS State .............. _A__.]-__a__s__B_a__ ............. Borouffh ......... _~_e_.n___a_! ..................... Field ...... _G_.~_a..n.i..t__e____.~o..!_n_.t_. ...................................... Tke followir~ff is a eorreot report of operations and prod,zetior, (ir~eludir~ drillinff and prod~oir~ for t~e mo,~t~ of ............... _S.._e~_t_~m_b__e_.r_ ...... 19_6_7__ .............................................................................. ,/l g e r~ t' s address .................. __P_:___O__,___._B___o__x____7__7__9_ .................... Company __P__a__n____A___m_e__r_ia~a_P_e.tr_ole.um..C_o_rp. ............................................ .......... ..... ....................... P Y~one ................................. _Z._7__Z__:_8_.4_.7__l_ ................................ .4 ~ ent' s title __A__s._s_J_t_,__A x_e_a_~dmLu.,..~q_up.v.r, SEC. AND GtSOLINE WITER (If (If th'filing, depth; If shu$ down, ~ o~ ~ Tw~. R~G~ W~L~ D~rs Cu. F~. o~ O~s GX~ONS o~ B~ o~ RE~ARKS No. Pao~c~ BARRE~ OF O~ GRAVY (~' thom~) RECOVERED none, so s~te) ~ ~d r~ult ot ~t for -~ e~t of e~) L: I0N lgW 5 ( 11 lll, 70g 4Z+ 67,580 0 0 AP1 50-133-Z001C ~ Produced from C 9/20 - PBTD 10 784' Com.plete,2 as flowir.g well Middle Kenai 9/1 - TD 10:, 472'. ~ ~YDbS/p'x~7~.. _ 9/5 9~t7 - TD 1~),800', Lc and set 7" liner ~ 9/~ 9t14 - ~.TD 10,784.~ per~orate an~i run tu~ing. 9/15 - ~'/19 - ~TD 10,784.', flow test. 9/20 - PBTD 10,784', well comi)leted. NW SW 6 {10N 12W 7 0 615 42~ NA 0 0 API 50-133-20012 10/1 - PBTD 10, 260', Flov~ test .9/1 - TD 0,~['. Fishings. 9/8 PB%'D 10,~2',Pusl.ed fi~:h to~tt~n {top ot fish at .0,341') and Set_ 7"~~t~, 10, 312'.~ ~~ ~. 9/~ - 9 ~lS PE TD lu~C', 1~~, perf,,rated a~d ran t~ bing. ~ v 9/~ - PBTD 10, Zt~0',~mo~qfffd{'illing rig, move oa worko,'er rig. 9/17 - ~'/30 - PBTD10,~~;queeze, perforate~ and te . ...... . _. .. Unit, NOTE.~There were ................................................ 157, 845 runs or sales of oil; .................... ..N....o. ..................... M cu. ft. of gas sold; ......................... ..N...o.. ............................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Min~aE ~ ~ ~ [~e succeeding month, unless otherwise directed. OCT 9 1901 Page 1 of Z F'6Fm No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 c~o ar~,=£ Aritho rage ~ ~ ADL - 18742 ~ ~ ~'~ ~ Granite ~oint State 18742 LESSEE'S MONTHLY REPORT OF OPERATIONS State ........... __A__l___a__s__.~_._ ................. Borough ............. _.K__.e_n_a~ ................. Field ......... _G._ r. a__.n..i._t._e_..?_.o_.!_n_.t__ ................................... Tl~e followir~ is a correct repot* of operatior~s and prod~etior~ (ir~el~dir~ drillir~ and prod~eir~ wells) for tke mor~tk of ................ .-A---u-g-U--S-~ ........... , 19--6--7- .............................................................................. .4Cent's address ................ __P__.____O__.____~__o__x____7__7__9__ ..................... Company ___P_~p____A.___m___e._r_ i _c_.a. n_...~ '-'7~- '-'7~--~-'P-'e"t'r-'-°']:'e'"u'--m'""C"9' rp. SEC. AND ~4or ~4 BHL: Sec. 12 SE of SW ~rwP. R~ iOTNpllll dril] BARRELS OF OIL lng ahead skidded ri on 81 cu. F~. o~ OAS (In thousands) /67. 16, TD 91 (~ALLON$ OF OASOLINE i~ECOVERED )3', drill BARRELS Og WX~gR (If none, so state) .ng ahea, REMARKS (If drilling, depth: if shut do~n, pause; date and result of t~t for ga~oUne oo~tent of RECEIVED SEP 1 11967 I$1ON OF MINES & MINERALS · ~ Nr~gAOE NOTE.--There were ............. .N....©. ............................ runs or sales of oil; ..................... .N....©. .................... M cu. ft. of gas sold; No runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAN° or~,=~ Anchorage L~A~E NUMBER ADL - 18742 -~AsE n~ uN,, ~ Granite Point State 18742 LESSEE'S MONTHLY REPORT OF OPERATIONS API 50-133-20010 State ................ A_l_g_.s_ka ........... Borough ...........Kex~ai ................... Field ........ _G___r_a._n._i..t._e__~.o._i_n_.t._ .................................... Th, e follow~r~g is a correct report of operatior~s and prod~ctior~ (ir~eggdir~ drigHr~ an.d prodgoin~ weirs) [or tt~e month o/ ................ _J.__u_l__y_ ................. , ~a_6_7__ ............................................................................... ./lger~t' s address ................;_~'____O__-_____B___o__x____7_7__? .................... Company _P___a_n____A____.m___e_xi~an.P.e.troleum..C. arp. PI, one .................................. _2__7_.2_.-__8___4__7__1_ ............................... ~er~t's titte ___A__r_e_a___S___u_~._e~n~eadem~~~ ........... SEC. AND ~o~ 5/ BHL: Sec. 12 SE of SW 3, ~rD el972,I, se, .onSterfaPo r~rily BABRELS OF OIL 0 >perations 9- 5 / 8" ca R-2; prep; suspended (~RAVIT~ 0 tern' ~ing ring Cu. F~. o~* GAS (In thousands) orarily s~ ~t 8965' ar to skid ri, OALLONS OF O~ASOLINE RECOVERED spended d cemen · 7/5, BARRELS oF W~?,~R (If none, so state) ~ed with TD 8972 REMARKS (If drlllinf, depth: if shut down, oau~e; date and result of teet for ~asolhle content o! 650 sx , oper- NOTE--There were .................... ..N..©. ...................... runs or sales of oil; ................ N.o .......................... M cu. ft. of gas sold; ........................ .N....©. ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month,[~r~s~o~e[v~i~e directed. 1967 DIVISION OF MINES & MINERAI~ ANCHORA~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 LAN° =r~,=~ Anchorage L~^sE NuMBERADL - 18742 L~AS~ =R UN,~ ~^~ Granite Point State 18742 API 50-133- 20010 LE$SEE'S MONTHLY REPORT OF OPERATIONS Tl~e followir~ is a correot report of operations and prod~e~io~ (inel~dir~ drillir~ and prod~einff wells) for ~he month of .................. _J__u___n_.e_ ................ 19__6__7__ ............................................................................. .4 ~ e ~ ~ ' s address .... _~_,____0_,___~~_o__x___7_7__9_ .................................... Company ~P.~an-~A~9~e~r~i~-c~a~n~P~-e~-t~i;~-~-e~u~m-~r~ V .................... _2_ 7___2_::_8_?__3_ .............................................. Uae ?_ t._ ............. SE0. AND BARRELS OF OIL (~RA~ITY (~A$OLINE WATgR (If (It ~ll~e. depth: If ehut down, ~ OF ~ TWP. RANGE WELL DArS CU. FT. OF GAS OALLONS O~ BARR~ O~ RE~ARKS NO. PRO~C.D (~ tho~) date ~d r~ult Of t~t for g~ol~e RECOVgR~ none, so s~te) con~ of ]: :. 12 of ~ 10N 12W ~ 0 0 0 0 0 0 TD 8967i'. Dril],ing ahead on 6-~0-67. 6-1-67,~ TD ~463' drilling ahead. 6-12-6' , TD 8648', trip])ing in with wh[pst~)ck arid drilled off at 8583 - 9]'. 6-13-67, TD 8661', set whi~sto~:k No. 2 at 8648' and drilled oJ~f to 8661' and t::i~ped in with hoL~ oper.er. 6-15-67, [D~ 873~' s~t whipst~ock No. ~ at 8712' a~d d:~ille~ off to 8734'.. 6-16-67, TD 8823'~, .set wh:[pstock No. 4 at 88~)9' a~.d drilled off t.~ 8823'~. 6-19-67, TD 8935 , set whipstock N~). 5 ~.t 8871-85'. 6-20-67, TD 8948',drilled of~ whipstock No. 6 a~ 89~5-48 and stuck whip3tock. 6. 21-67, %D 8948', and fishing. 6-28-67, TD 8950', recovered fis~ and dril].ing on junk. BHL Sec SE NOTE.--There were ............... N...©. ............................ runs or sales of oil; ................. N...o. .......................... M cu. ft. of gas sold; ........................ ..N..©. .............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding mor~, [~n/l~s~h~r~e r~t directed. JUL 11.19 .7 DIVISION OF MINES & MINEI~. ~J~ICHDi~GE FORM 470 2-57 PANAMERICAN PETROLEUM COI PO ION P. O. Box 779 Anchorage, Alaska 99501 June 15, 1967 File: FKK- 838-WF Re: Application to Drill Granite Point State 18742 #5 Mr. Thomas R. Marshall, Jr. State of Alaska Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Our application for permit to drill Granite Point State 18742 #5, assigned No. 50-133-20010, stated the location at the surface to be slot 6 of leg 3, which is 834' FNL and 676' FEL. The surface location has subsequently been changed to slot 4, leg 4, which is 774' FNL and 709' FEL. Please adjust your records accordingly. Yours very truly, F. K. Krebill Area Superintendent RECEIVED JUN 1 ~, 1~7 DIVISION OF ~INES & MtNEP..AI~ ANCHORAGE t Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 k'~ · ~o ~r~,~.~ Anchorage LEA,, NUM,,, ADL - 18742 ~ ~ ~'* ~ Granite Point State 18742 LESSEE'S MONTHLY REPORT OF OPERATIONS State ......... _A___l__a__s_k_a__ .................. Borough .......... ..K__e_._n_.a..~ .................... Field .......... _G_ ?_.a__n._i_.t_.e____P_o__i__.n_.t_ ................................... Ti*e followir~ is a correct report of operations and prod~etio~ (inelz, di~ drillir~ and prod~ein~ wells) for ti*e month of ...................... .M__._a_~[_ ............ 19_6__7___, ............................................................................ ./l ~ e r~ t ' s address ............... ?_._ _ _ _ _O__ _.. _ _ .B_ _ _o_ _ _x. _ _7_ 7_ ~ ....................... Company _~__a__n____A____m___e_.r__i_.c_.a.._n__~_e..t.T__o_.l._e_._u.__m_.._~.p._rp. ......................................... A__n__c__h__o__r_~ ge:.___ _A__l__a__s_Ka_ .............. Si ~r~ed, ..... ~~ ........... PI,one .............................. ~_7__Z__-__8___4_7__! ................................... Z~ent s titZe ___A__r_e_~_i_.n.t.ez~d__e._n__t ........... ~[EC. AND BARRELS OF OIL ORAVIT¥ (~ASOLINE WATER (If (If drilling, dopth; if shut down, oau~e; ~ or ~ TwP. RANOR WELL Dars CU. F~. or (]AS GALLONS or BARRELS or REMARKS NO. Pao~uc~. (In thous~) date ~d r~ult of ~t for g~ol~e RECOVERED DOHO~ so state) con~t of ~) L: . 12 of SW 10N 12W 5 0 0 0 0 0 0 TD [46~' Drilling on 6/[/67. Spuc at 0:.30 on 5/7 67. 5/10/67, 2?D 650', set 20" casing at 6~)~', cemented~zithl~5 sx Clas ~ G plus 3~ Dia(:el D per ~sx and 900 sx Class ~ plus 4% CaC12. ./11/67, TD 686' and drilling ahead. 5/16/67, TD 2088', setl3-~/8" casing at 2~)50', cemented with 500 sx Class G plus ~3~ pe:c sx of Diacel D and 600 s~ class G plus 2~0 CaC12. 5/18/67, TD 278~' and drilling a. aead. BHL Sec SE NOTE.--There were .................. N....°.. ....................... runs or sales of oil; ................ N....°.. ......................... M cu. ft. of gas sold; ........................ N....©. .............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the Division of Mines& Minerals by the 6th of the succeeding month, un_less_otherwise directed, gEC E [ V E D DIVISION OF MINES 470 2-57 Pm:ao , v CORPO ION P. O. Box 779 Anchorage, Alaska 99501 May 8, 1967 Director Division of Lands State of Alaska Department Of Natural R~sources 344 Sixth Avenue Ancho rage, ~'Ala s ka Dear Sir: File: FKK- 668-WF Spud New Well - Granite Point State This is to notify you that the subject well was spudded on State Lease ADL - 18742 at 1:30 a.m. on May .7, 1967. The surface location of this well is at NE/4 NE/4, Section 1Z, T10N, R1ZW, S.M. ' We plan to drill this well directionally to a bottom hole location of SE/4, SW/4, Section 1Z, T10N, R1ZW, S.M. Yours very truly, ! F. K. Krebill i Area Superintendent RECEIVED I:[ '~,,¥ 15.1967 · O1¥151ON' OF MINES & MIN ANCHOi~GE FORM SA - I B 50M 1/67 ~ MEMORAN M TO: J'- FROM: State of Alaska DATE : SU BJ,,~"CT ~ April, :20, 1t67 ~ {ir. ireblll: 1~~ f~ etm~ tho q~~d eppl~ for pmit to drill tb.rtfereuad gill. Ibll m~b fid eon ddpB ore FORM SA- lB 50M 1/67 ??::"i~i~'i~""i~"'~'Mr-~ORAN~60M state."of Alaska TO: I-' FROM: DATE FOR.M~ 4?0 2-5? PAN AMERICAN PETROLEUM CORPORATION P. O. Box 779 Anchorage, Alaska 99501 April 10, 1967 File: FKK- 524-WF Re: Application to Drill, Granite Point State 18742 #5 Mr. Thomas R. Marshall, Jr. State of Alaska Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Enclosed please find three copies of our application P-1 to drill Granite Point State 18742 Well No. 5, three location plats, and our draft for $50.00. This well will be spudded after receipt of your approval. Yours very truly, F. K. Krebill A rea Superintendent Enclosures APR 1 3.1967 DIVISION OF MINES & MINERALS ANCHORAGE '~' .~'-~ :~oitc,~ ;;:.,.~ ~"~I $b 50- ~3~-20010 * ~ Fox~--I~..:. -r- '~.~ .... "~:~.'; ~i . .' i'.'~:..'.-:r~;x':''~:. ..... ~-?',.- ~ .. ;--.~ ~:-/: ~ ' .(Other-instruCtionS. on. ' . : .-- .~ ~-_..F,' *' ?' ', . :'-~ : - -~'"'; F::.~-~9'; '.3 _z,¢:~ L-~'.-:-'s. ' ~--'- ~'~ '-~'-'~ Y"~F . ' OIL AND GAS ~ONSERVATION iO~l~lON:: -.: .-~ ' .... ~; ~is~' ~m~iO'~ ~s~'~o. APP'LIC, TI :FOR 'PERMIT"TO Dffl- l: DEEPEN;?OR'"PI UG ;B'A'CK ii (' wE~ .~..~ ?, ~- ._ F~, ~ ......... 0~, .~,-. ,-~,, ?~ ...... ~: ....~,- ..... ~,,.z°~., ,. ,~ ........... ' Pan American P. O.' Box ?79 - Ancho;~age;" ~tas'ka"~'9'9501: ....... ~ ..... - ~ ' ......"' ~tsurface Slot 6, Le~ ~}, .~,: /.~.f - ~ ~_~_ ~ ~( i~ :' ~:~i-; ;'~k~at ~::- c.~ :-,.-,~,-~;.,m ~(, -~.~- --~, ..... , ..... · .... · - tt proposed ~gliI.FNL, 676' FEL, Sec. 12, T10N, ~lZW. S.M. 660' ESL, 1640' FWL, Sec. 12, T10N, ~lZW. S.M. 14. DISTANCE IN MILE8 AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs 9 miles SW of Tyonek iG~ahi[e P°in6.$tate 18742 NO. .... -Grahft~ POint 11. S~C.~ ' '" 'AI~V'~UaVE~ Oa iaEA Sec. 12, T10N, RlZW, S.M.' 12. B. OROUGH SH] la. STATE Kenai [ Alaska 1§.. DISTANCE FROM PROPOSED$ LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drlg. unit line~ if any) 1640' FWL DISTANCE FROM PROPOSED LOCATIONs TO NEIREST WELL, DRILLING, COMPLETED, 19 9 9' E, OR APPI~.~D FOR, ON THIS L~,~E, Fr. 3901'N to Well #3 16. NO. OF ACRES IN LEASE 5060 19. PROPOSED DEPTH 12, 500' 21. ~.I~VA~0NS (Show whether DF, RT, GE, etc.) Estimated RKB 117' above MLLW (72') 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE26I~°F HOLE [ SIZE2011OF CASING S[ - ~- '"~-', ~---WEIGHT PER FOOT 17-1/2" t 13-3/8" ,{ 54.5~ 1Z-l/4" J 9-5/8" 53.5, 47, 43.5# 17. NO. OF ACIL2S ASSIGNED TO THIS W~LL 160 20. ROTARY ~)R 'CABLE TOOL8 Rotary 22: APPROX, DATE WORK WII~L STARTs 4-20-67 SETTING DEPTH QUANTITY OF CleMENT 600' Circulate to surface 8-5/8" 7" 26, 29, 32# 2000' Circulate to surface , ,, 11,500' Min. of 500' above shoe; addi- tional cement may be used de- pending upon electric log inter- pretation. 11,200-12,500' Complete fill-up from shoe to hanger. Reason for Deviation: To reach BHL from permanent platform. There are no affected operators. BOP specifications attached. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: I~ proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. · Give blowout preventer progr-m: if any. 24. I hereb~ertif~iah~t the' ~o~ is True and Correct. Area Superintendent DATE 4-10-67 (This space for Federal or State office use) PERMIT NO. ~ 7 -- /(~ CONDITIONS OF APPROVAL, IF ANY: TITLE APPROVAL DATE THOMAS R. MARSHALL, JR. Executive Secretary Alaska Oil 8, Gas ConserVation Committee *See Inductions On Reverse$icJe DATE RECEIV[f) APR 1 3 1967 DIVISION Of MINES & MINERAL~ DM- 12 A,.P~J. CODE. ~, 0_._133.20010 _ Release Date 10-20-69_ State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD OperatorPan .iaaer._ Pet. Corp. Location (Surface) Lease No ;' UADL-- : 18742 .......... -= o r Owner,, Loc. R. 12 I~ __ ..~_ Meridian Permit No. ,_. 67~'!~. Issued 4-20-67 Slot 6- Leg 3 Plat£oza "A" 774' lq~ &: 709' FEL Sec. 12 .__~ra._~!Ce _Pp!nt_ State =__ (Bottom) 839 FSI, &' 1577 la~ Sec. 12 We 1 i No. 5 Area Granite · Point Spud Date .... _~.7~67 Dr l I 1 lng Ceased Suspended =; Abandoned Completed (F-GL-P),~ ..... ~..2,0.,67,, IP 9204 B/D, Gray ........ - P.B. 10.784 := Total Depth,_ !OsgO0 Elevation 75' 6SO. hd, _ , ..... L_ t L J,,~. ,- ,,. i APl Cut .i1L, O.. ~ .4!. '(s) ........... Gas 5568 MCF/D, Bean 124.5/6/4 CP P.O- psi, TP _ ~' ~_jjll cJ. _ L = ¥~=-= ~: -: '- ..... I. Cas ing: S i ze ~ SxCmt :: ~ _-. 6o ' 13 3/8" ' 2050 m 1233 Parr: 10,598, ",6Q8'; _. _}00,_(~_) _ psi 10,230-40: -10.173-83' I 9.975-957~I ....... . :_, , 9 5/8" 8965' . 650 9.810-30'~ 9.760-8Q~.,I 2 tbs strings ~n~ ~as' 9~AlO~'~_ __ 9,330-90'1 ....... - _= .=. ..... - .... - & 10~611 9~074-84 GEOLOGI C FORHATI ONS PRODUCTI VE HORi ZONS Surface Lo. st Tested Nam~ Depth Contents WELL STATUS Year Jan Feb, Mar .APr ..... May June July Aug Sept ,Oct Nov ~ec ~'~ = LEG. NO.I LAT. 60058, 37.56" LONG. 151° 18' 4 6.00" Y = 2,551, 413 X = 266,816 , FROM N.E. COR. 729' SOUTH 8~ 636' WEST 1 TmON 12 6 SEWARD MERIDIAN ALASKA LEG. NO. ;> LEG. NO. 3 LAT. 6g°58';56.96'' LAT. 60°58'36.53'' LONG. 151° 18'4 5.28" LONGo151°I$'46.82'' Y= 7,551,~55Z Y = 2,551,~510 X = 266,850 X = 266,774 FROM N.E. COR. FROM N.E. COR. 790' SOUTH ~ 8~4' SOUTH (~ 600' WEST 676' WEST SCALE= I" = 1,000' LEG. NO. 4 LAT. 60°58' ~7. 12'' LONG. 151° 18'47.48" Y= 2,551,157 I X : 266,742 FROM N.E. COR 774' SOUTH 8~ 709' WEST 13 18 CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land-surveying in the State of Alaska and that this plat represents a location survey mede by me or under my supervision end that all dimensions (]nd otherw details are correct. Date Surveyor APR NOTE The location of platform legs was accomplished b~,N~(~E triangulation stations Dud, Trinity, and Tyonek Offset. FINAL PLAT OF TYONEK PLATFORM "A" lOCATED I N N ir I/4, NE I/4, PROTRACTED SEC. 12,TION, R 12W, S.M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. i~,.1~. BOX 779 ANCHORAGE, ALASKA SURVEYED BY F M. LINDSEY 8~ ASSOC. LAND SURVEYORS 8~ CIVIL ENGINEERS 3201 ARCTIC BLVD. ANCHORAGE, ALASKA Ccc-C"t' Z ~ APR 1 3.1967 PI.VI.SION OF MINES & Mhk,!ERAL,S ANCHORAGE ~L_ 1 L_ _ _-yz'-_-zx-~_ ~d' -- I b. i'7, '
