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167-049
1 Christianson, Grace K (OGC) From:McLellan, Bryan J (OGC) Sent:Monday, June 9, 2025 5:10 PM To:Casey Morse; Wyatt Rivard Cc:Christianson, Grace K (OGC) Subject:MGS St 17595-13 (PTD 167-049) Sundry is not approved Casey & Wyatt, The plan in the sundry application we received on 5/12/25 for this well is rejected because it does not isolate the West Foreland perforations from MGS E,F,G perforations with a plug that is compliant with 20 AAC 25.112. I’m happy to discuss options going forward. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: Middle Ground Shoal 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,691 N/A Casing Collapse Structural Conductor Surface 1,130psi Intermediate Production 3,090psi Liner 11,390psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Coiled Tubing 6/1/2025 10,6901,884 3-1/2" (LS) & (SS) & 2-3/8" (SS) 10,360 N/A & N/A N/A & N/A 8,920 Perforation Depth MD (ft): 7,195 - 8,755 8,920 7" 6,947 - 8,480 8,6369-5/8" 450 26" 20" 13-3/8" 595 2,011 MD 2,730psi 595 1,977 595 2,011 Length Size Proposed Pools: 450 450 9.2#/L-80 (LS) & (SS) & 4.6#/N-80 (SS) TVD Burst 7,150 (LS) / 7,054 (SS) / 7,065 (SS) 5,750psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017595 167-049 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20039-00-00 Hilcorp Alaska, LLC MGS ST 17595 13 AOGCC USE ONLY 8,460psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Middle Ground Shoal Oil N/A 10,361 8,850 8,570 2462 8,850 & 9,400 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:56 am, May 12, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.05.08 15:49:12 - 08'00' Dan Marlowe (1267) 325-295 West Foreland perfs are open across a ~1500' interval below the MGS Oil pool. The Proposed plugging operation in this sundry is not adequate to abandon the West Foreland. The sundry is denied. XX RBDMS JSB 061025 Abandon MGS Oil Pool Program Well: Ba-13 Well Name:Ba-13 API Number:50-733-20039-00-00 Current Status:Shut-In Producer Rig:SL, CT, cement Regulatory Contact:Juanita Lovett First Call Engineer:Casey Morse 907-777-8322 603-205-3780 (M) Second Call Engineer:Eric Dickerman 907-564-4061 Current Bottom Hole Pressure (est):3273 psi @ 8113’ TVD (2008 SBHPS, EMW: 7.8 ppg) Max. Potential Surface Pressure:2462 psi Gas Column Gradient (0.1 psi/ft) Current Pressures (LS/SS/IA/OA/OOA):260/300/170/95/50 psi History Drilled and completed in 1967 and put on production as an oil producer. Several workovers were performed including acidizing, plug-backs, perf adds, squeezes, and recompletes. The well has open perforations from 7195 – 8755’. The perforations from 5790 – 6935’ were squeeze cemented, and the deep perforations were isolated with a bridge plug at 8850’. The well was SI in 2003. It was then circulated with 9.8 ppg brine and a 60 bbl pill of LCM was pumped to plug off the perforations. 20” Casing set @ 595’ MD. Cement: 185 sxs class G / 33# / sk Diacel “D” + 4 % Co 112 + ¼ #/Sk Cellophane Followed by 1100 Sks “G” + 4% CaCl2 + 1#/Sk Cellophane. Cement to surface, full returns. 13-3/8” Casing set @ 2012’ MD. Cement: 1900 Sacks Class G. Cement to surface. 9-5/8” Casing set @ 8920’ MD. Cement: First stage 875 sacks Class G. Second stage collar @ 6902’ MD w/ 825 sx Class G. CBL shows good cement bond through the top of logged interval @ 5500’ MD. Current Status Shut-in. The LS, SS, and IA were loaded with 8.6 ppg FIW. Pre-P&A Diagnostics Performed 1. Circulate FIW: a. Pump down LS up IA @ 300psi/2 BPM b. Pump down IA up LS @ 300psi/2 BPM c. Pump down SS up IA @ 300psi/2 BPM d. Pump down IA up SS @ 300psi/2 BPM e. Pump down LS up SS @ 300psi/2 BPM f. Pump down SS up LS @ 300psi/2 BPM 2. Attempt to inject down LS at 1 bpm, pressure climbed to 2100psi after 7bbls, held at 2100psi for 12bbls. Increase rate to 1.25bpm, pressure increased to 2350psi and broke over to 1900psi, pressure rose to 2400psi in 4bbls, held at this pressure for 5bbls. Drop down to 1bpm, pressure dropped to 2250psi and held for 5 bbls. pumped a total of 35bbls FIW. Limited injectivity into perfs. 3. RIH w/ 3.5” D&D Holefinder to 7050’. Pressure up to 1500 psi with 0.15 bbls. Held for 5 minutes – good test. Did not log to TOC. Abandon MGS Oil Pool Program Well: Ba-13 Objective Plug the MGS Oil Pool in the Ba-13. Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (E). Hilcorp requests the existing mechanical plug set at 8,850’ be considered sufficient for abandonment of the perforated intervals beneath the plug. The bridge plug was set in 1991, and since that time, approximately 1,000 ft of debris and scale has accumulated in the wellbore above the plug. Performing an intervention to clean out the wellbore and place cement directly on top of the bridge plug would be a high-risk operation (requiring rig intervention) or would have limited chance of success utilizing coil tubing given the large diameter of the casing relative to the tubing size. Hilcorp requests the proposed P&A plug be placed with coil tubing via the displacement method on top of the accumulated debris. The proposed cement plug will be placed across open perforations in the E and F zones up to the tubing tail. From that point, cement can be circulated through the tubing to cover the remaining benches of the MGS Oil Pool. Procedural steps Coil Tubing 1. MIRU Coiled Tubing and pressure control equipment 2. PT lubricator to 250 psi low / 3000 psi high 3. MU cement nozzle BHA 4. RIH through end of tubing and into perforations to tag. PU off bottom ~10’ and confirm circulation. 5. Pump reservoir abandonment plug as follows: a.60 bbl 14 ppg cement, monitoring return volumes b. Displace cement out coil c. Pull up into the tubing above cement top and ensure cement is circulated out of coil d. Adjust cement volume based on tag depth to place estimated TOC ~7150’ 6. POH and RD coil Fullbore 1. Circulate the LS/SS/IA with 9.8 ppg brine. 2. Establish circulation down LS up IA, and down LS up SS. 3. Pump upper cement plug as follows: ¾ 20 bbls FIW (Filtered Inlet Water) w/ Surfactant Wash (down LS and out IA) ¾117 bbls 14 ppg Class G cement i. Take 63 bbls returns up IA to fill LS w/ cement. ii. Swap to taking returns up the SS. Take returns out the SS until 14 bbls are recovered. iii. Open up IA and return a total of 88 bbls cement into IA (40 bbls cement, Foam wiper ball, 48 bbls displacement) ¾ Foam Wiper Ball ¾ 48 bbls of 9.8 ppg brine displacement of cement i. This places TOC in LS / SS / IA ~5500’ ¾ LS volume from tubing tail to 5500’: 0.0087 bpf * (7150’-5500’) =15 bbls Bring cement volume inside LS to maximize plug length below tubing tail. Then reverse out cement by pumping down IA, up LS & SS to maintain circulation path for next cement plug. -bjm The West Foreland is a separate oil pool open below this bridge plug. There will not be cement below the MGS Oil Pool. Plugs must be drilled out to place cement across West Foreland perfs. -bjm Pump excess cement volume to allow for losses to open perfs. Circ out excess from Tbg tail. -bjm Verify TOC per 20 AAC 25.112(g)(1). Set down max safe weight with CT, minimum 5000 lbs on TOC. Alternative is to verify by tag w/ wireline and pressure test to 2200 psi per 20 AAC 25.112(g)(2). -bjm Ensure depth is corrected and known relative to tubing tail. -bjm Variance request is denied. -bjm Abandon MGS Oil Pool Program Well: Ba-13 ¾ IA volume from tubing tail to Kobe: 0.0639 bpf * (7150’-7065’) = 6 bbls ¾ IA volume from Kobe to 5500: 0.0520 bpf * (7065’-5500’) =82 bbls (9-5/8” 40#) ¾ SS volume from Kobe to 5500: 0.0087 bpf * (7065’-5500’) =14 bbls ¾ Casing volume from WREG to 7941: 0.0758 bpf * (7941’-7150’) =60 bbls ¾ LS volume from 5500’ to surface: 0.0087 bpf * 5500’ =48 bbls ¾ IA volume from 5500’ to surface:101 bbls o 5500 to 1163: 0.0520 bpf * 4337’ =226 bbls (9-5/8” 40#) o 1163 to surface: 0.0494 bpf * 1163’ =58 bbls (9-5/8” 47#) ¾ SS volume from 5500’ to surface: 0.0087 * 5500’ =48 bbls Fullbore / Slickline 1. CMIT LSxSSxIA to 1500 psi (AOGCC Witnessed). 2. Tag TOC in LS and SS (AOGCC Witnessed). Cement Tops x 9-5/8” Casing (CBL on file with T# 34810): o First stage cement: 875 sx @ 8920’ assuming ~1.2 cuft/sk = 187 bbl Annular volume 0.0558 ft/bbl Assuming 50% washout, cement top is 6685’ vs. stage collar @ 6905’ o Second stage cement: 825 sx @ 6905’ assuming ~1.2 cuft/sk = 176 bbl Annular volume 0.0558 ft/bbl Assuming 50% washout and no carry-over from 1st stage of cement, TOC ~ 4795’ Bottomhole Pressures x Frac pressure: estimated at 0.9 – 1.1 psi/ft as per AIO 7 o TVD of top perf is 6947’. Estimate frac pressure of ~6250 psi at perfs x Full column of 9.8 ppg brine: 3540 psi o Frac pressure > 2500 psi with 9.8 ppg brine in well x Full column of 14 ppg cement: 5100 psi o Frac pressure > 1000 psi surface pressure with full column of cement. Attachments: Current Schematic Proposed Schematic Coil BOP Diagram (Fox Energy) CBL shows good cement to top of log interval at 5500' MD. -bjm Updated by: JLL 3/30/16 SCHEMATIC Middle Ground Shoal Well: Ba-13 (MGS ST 17595 #13) Last Completed: 12-10-1997 PTD: 167-049 API: 50-733-20039-00 Jewelry Detail #Depth ID OD Item Long String 1 31 2.992 Split 11” DCB Hanger Cameron Type “H” BPV profile, 3-1/2” Butt Dwn 2 7,064 2.992 3.865 Crossover, 3-1/2” Butt x 3-1/2” EUE 3 7,065 2.687 7.25 TRICO 3” Parallel DBL B cavity 4 7,088 2.992 4.5 Crossover, 3-1/2” EUE x 3-1/2” Butt 5 7,150 2.992 3.5 WREG Short String A 31 2.992 Split 11” DCB Hanger Cameron Type “H” BPV profile, 3-1/2” Butt Dwn B 7,054 2.992 3.865 Crossover, 3-1/2” x 2-3/8” EUE 7,065 2.687 7.25 TRICO 3” Parallel DBL B cavity PBTD = 8850’ TD = 10691’ MAX HOLE ANGLE = 33O @ 1850’; 28O @ 5420’ 5 26” 450’ TOC CBL 5500’ Top of Fill 7941’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 8,920’’ Open Perfs 7195’ – 8755’ Oil Top G&G 5700’ 2 3 4 1 Stage Collar 6902’ 20” 595’ 13-3/8” 2,012’ 7” 10,691’ Drillable BP 9400’ Drillable BP 8850’ TOL @ 8806’ A B Perfs Squz 5790’ – 6935’ BHT = 145 @ 7000’ TVD Pore Press = 3200 psi @ 7000 TVD (8.8 ppg EMW) 5 2 3 4 1 A B Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments 5,790' 6,935' 5,557' 6,693' 1,145' Sqz'd E,F,G 7,195' 8,755' 6,947' 8,480' Open Top of Fill @7,941' (2005) 8,985' 10,535' 8,697' 10,205' Isolated Below Bridge Plugs Mean Sea Level Mud Line Notes 6/30/2024 Set Holefinder @ 7050’ in LS and pressure test @ 500 psi for 5 mins - good 7/22/2005 Attempt Inj test down LS 7/22/05 – Tbg X Csg Annulus pressure to 1500 psi with no formation breakdown. 7/5/2005 Fill: 7,941' - Tagged w/2.65” GR 3/20/1991 Top 1163’ of 9-5/8 csg changed during 1991 WO due to corrosion/holes. Backed off at collar and screwed back into collar with new casing. Pressure tested to 2000 psi and held. History shows potential casing wear and/or deformed casing from 2114’ – 2122’. 7/20/1981 Identified leaks in 9-5/8” casing 5750’-5190’, 6829’-6935’. Squeezed w/ cement Casing Details Size Type Wt/ Grade/ Conn ID Top Btm 26” Structural .5” Wall 25 Surf 450 20” Conductor 85# 19.124 Surf 595 13-3/8” Surface 54.5, J55, STC8rd 12.615 Surf 2,011 20.5º 9-5/8” Intermediate 47, N80, Butt 8.681 Surf 1,163 40, N80, LTC 1,163 5,457 40, S95, LTC 8.835 5,457 7,966 43.5, P110, LTC 8.755 7,966 8,501 43.5,S95,STC8rd 8.755 8,501 8,920 7” Scab Liner 38, N80, 8rd 5.92 8,806 10,690 Tubing Details Long String 3-1/2" Prod Tubing 9.2, L80, BTC 2.992 32 7,150 Short String 3-1/2" Prod Tubing 9.2, L80, BTC 2.992 32 7,054 2-3/8" Prod Tubing 4.6, N80, EUE 8rd 7,054 7,065 DOGLEGS 3636 3.37 7578 3 8574 3.48 Updated by: JLL 3/30/16 PROPOSED SCHEMATIC Middle Ground Shoal Well: Ba-13 (MGS ST 17595 #13) Last Completed: 12-10-1997 PTD: 167-049 API: 50-733-20039-00 PBTD = 8850’ TD = 10691’ MAX HOLE ANGLE = 33O @ 1850’; 28O @ 5420’ 5 26” 450’ TOC CBL 5500’ Top of Fill 7941’ RKB: MSL = 101’ Mudline= 203’ Water Depth= 102’ 9-5/8” 8,920’’ Open Perfs 7195’ – 8755’ Oil Top G&G 5700’ 2 3 4 1 Stage Collar 6902’ 20” 595’ 13-3/8” 2,012’ 7” 10,691’ Drillable BP 9400’ Drillable BP 8850’ TOL @ 8806’ 5555555555555 2222222222222222 3333333333333 4444444444444 A B Perfs Squz 5790’ – 6935’ BHT = 145 @ 7000’ TVD Pore Press = 3200 psi @ 7000 TVD (8.8 ppg EMW) A1 177 bbl cement: 60 bbls layed in with CT in perfs and 117 circ thru tubing Est TOC ~5500’ i LS/SS/IA Mean Sea Level Mud Line Casing Details Size Type Wt/ Grade/ Conn ID Top Btm 26” Structural .5” Wall 25 Surf 450 20” Conductor 85# 19.124 Surf 595 13-3/8” Surface 54.5, J55, STC8rd 12.615 Surf 2,011 20.5º 9-5/8” Intermediate 47, N80, Butt 8.681 Surf 1,163 40, N80, LTC 1,163 5,457 40, S95, LTC 8.835 5,457 7,966 43.5, P110, LTC 8.755 7,966 8,501 43.5,S95,STC8rd 8.755 8,501 8,920 7” Scab Liner 38, N80, 8rd 5.92 8,806 10,690 Tubing Details Long String 3-1/2" Prod Tubing 9.2, L80, BTC 2.992 32 7,150 Short String 3-1/2" Prod Tubing 9.2, L80, BTC 2.992 32 7,054 2-3/8" Prod Tubing 4.6, N80, EUE 8rd 7,054 7,065 Jewelry Detail #DepthID OD Item Long String 1 31 2.992 Split 11” DCB Hanger Cameron Type “H” BPV profile, 3-1/2” Butt Dwn 2 7,064 2.992 3.865 Crossover, 3-1/2” Butt x 3-1/2” EUE 3 7,065 2.687 7.25 TRICO 3” Parallel DBL B cavity 4 7,088 2.992 4.5 Crossover, 3-1/2” EUE x 3-1/2” Butt 5 7,150 2.992 3.5 WREG Short String A 31 2.992 Split 11” DCB Hanger Cameron Type “H” BPV profile, 3-1/2” Butt Dwn B 7,054 2.992 3.865 Crossover, 3-1/2” x 2-3/8” EUE 7,065 2.687 7.25 TRICO 3” Parallel DBL B cavity Perforation Detail Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status Comments 5,790' 6,935' 5,557' 6,693' 1,145' Sqz'd E,F,G 7,195' 8,755' 6,947' 8,480' Open Top of Fill @7,941' (2005) 8,985' 10,535' 8,697' 10,205' Isolated Below Bridge Plugs DOGLEGS 3636 3.37 7578 3 8574 3.48 Notes 6/30/2024 Set Holefinder @ 7050’ in LS and pressure test @ 500 psi for 5 mins - good 7/22/2005 Attempt Inj test down LS 7/22/05 – Tbg X Csg Annulus pressure to 1500 psi with no formation breakdown. 7/5/2005 Fill: 7,941' - Tagged w/2.65” GR 3/20/1991 Top 1163’ of 9-5/8 csg changed during 1991 WO due to corrosion/holes. Backed off at collar and screwed back into collar with new casing. Pressure tested to 2000 psi and held. History shows potential casing wear and/or deformed casing from 2114’ – 2122’. 7/20/1981 Identified leaks in 9-5/8” casing 5750’-5190’, 6829’-6935’. Squeezed w/ cement KLU A-1 Well Head Rig Up 1 1 1 1 4 1/16" 15K Lubricator - 10 ft 100" Gooseneck HR680 Injector Head 4 1/16" 10K Flow Cross, 2" 1502 10k Flanged Valves 4 1/16" 15K Lubricator - 10 ft API Flange Adapter 10K to 5K for riser/wellhead Hydraulic Stripper 4 1/6" 15K API Bowen CB56 15K 4 1/16" 10K Combi BOPs Blind/Shear Ram Pipe/Slip Ram 4 1/16" 10K bottom flange 4 1/16" 5K flanged Riser - 10 ft if necessary 45_COAL A-1 C E1_ST 44_COAL E -4_MKR_R G-2_ST F-1 G-3B_ST B-3 D-2 46_COAL G-2_MKR G-3_MKR A-2X F 42_COAL C-2 D-1 F-2 D-3 E_ST B-1 G-5_ST A-2 F2_ST A A-3 WF_MKR A-1X WF_MKR_2 E-1 F-3 F2_BASE B G-4_MKR G-4A_ST A-4 e 18746-1) F-4 G-5_MKR B-2 G-1A_ST E-2 47_COAL G-1B_ST C-3 43_COAL B-4 D G-3A_ST SAND_TOP C-4 HEMLOCK AND_BASE E1_BASE C-1 Cement Inactive Inactive Inactive Inactive Inactive Active Active Active Active Active Fill Fill Fill Fill Fill Active Fill Fill Fill Fill Fill Fill Fill Active Fill Fill Fill Inactive Inactive Inactive Inactive Inactive Inactive Inactive Inactive Inactive 10691 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 9200 9225 9250 9275 9300 9325 9350 9375 9400 9425 9450 9475 9500 9525 9550 9575 9600 9625 9650 9675 9700 9725 9750 9775 9800 9825 9850 9875 9900 9925 9950 9975 10000 10025 10050 10075 10100 10125 10150 10175 10200 10225 10250 10275 10300 10325 10350 10375 10400 10425 10450 10475 10500 10525 10550 10575 10600 10625 10650 10360.6 4700 4725 4750 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 9200 9225 9250 9275 9300 9325 9350 9375 9400 9425 9450 9475 9500 9525 9550 9575 9600 9625 9650 9675 9700 9725 9750 9775 9800 9825 9850 9875 9900 9925 9950 9975 10000 10025 10050 10075 10100 10125 10150 10175 10200 10225 10250 10275 10300 10325 10281.6 4600 4625 4650 4675 4700 4725 4750 4775 4800 4825 4850 4875 4900 4925 4950 4975 5000 5025 5050 5075 5100 5125 5150 5175 5200 5225 5250 5275 5300 5325 5350 5375 5400 5425 5450 5475 5500 5525 5550 5575 5600 5625 5650 5675 5700 5725 5750 5775 5800 5825 5850 5875 5900 5925 5950 5975 6000 6025 6050 6075 6100 6125 6150 6175 6200 6225 6250 6275 6300 6325 6350 6375 6400 6425 6450 6475 6500 6525 6550 6575 6600 6625 6650 6675 6700 6725 6750 6775 6800 6825 6850 6875 6900 6925 6950 6975 7000 7025 7050 7075 7100 7125 7150 7175 7200 7225 7250 7275 7300 7325 7350 7375 7400 7425 7450 7475 7500 7525 7550 7575 7600 7625 7650 7675 7700 7725 7750 7775 7800 7825 7850 7875 7900 7925 7950 7975 8000 8025 8050 8075 8100 8125 8150 8175 8200 8225 8250 8275 8300 8325 8350 8375 8400 8425 8450 8475 8500 8525 8550 8575 8600 8625 8650 8675 8700 8725 8750 8775 8800 8825 8850 8875 8900 8925 8950 8975 9000 9025 9050 9075 9100 9125 9150 9175 9200 9225 9250 9275 9300 9325 9350 9375 9400 9425 9450 9475 9500 9525 9550 9575 9600 9625 9650 9675 9700 9725 9750 9775 9800 9825 9850 9875 9900 9925 9950 9975 10000 10025 10050 10075 10100 10125 10150 10175 10200 10225 10250 45_COAL A-1 C E1_ST 44_COAL E G-4_MKR_R G-2_ST F-1 G-3B_ST B-3 D-2 46_COAL G-2_MKR G-3_MKR A-2X F 42_COAL C-2 D-1 F-2 D-3 E_ST B-1 G-5_ST A-2 F2_ST A A-3 WF_MKR A-1X WF_MKR_2 E-1 F-3 F2_BASE B G-4_MKR G-4A_ST A-4 Top MGS Oil Pool (MGS State 18746-1) F-4 G-5_MKR B-2 G-1A_ST E-2 47_COAL G-1B_ST C-3 43_COAL B-4 D G-3A_ST F_SAND_TOP C-4 HEMLOCK F_SAND_BASE E1_BASE C-1 BA-13 [SSTVD] Spud date: 09/11/1967 UWI:507332003900 Completion Date: 01/01/1968Gas Rate - 10.03.23: Oil Rate - 01.03.23: Water Rate - 01.03.23: Cum. Gas - 10.03.23: Cum. Oil - 01.03.23: Cum. Water - 10.03.23: Max inc: 23.25 deg Petra WSN #: 75 TD (MD): 10691.0 ftMD19.51 145.48mVSP -11.94 137.80gAPI GR -0.300 0.300ft3/ft3NPHI_DPHI_265 0.00 1.00CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 NPHI-DPHI_2.65 CoalLogRHOB <= 1.95 RHOB TVD Perforation_LogPerforation_Log_ShortStringSSTVD1:1000 1.00 100.00ohm.mRESS 1.0000 100.0000ohm.mRESD 1.00 100.00CoalLog_GR_RESD_DTC 0.00 1.00CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB > 14 ohms < 14 ohms 0.600 0.000ft3/ft3DPHI_265 0.600 0.000ft3/ft3SPHI_MJP 1.65 2.65g/cm3RHOB 150.00 50.00us/ftDTC 0.00 1.00CoalLog_GR_RESD_DTC 0.00 1.00 CoalLogRHOB CoalLog_GR_RESD_DTC - GR < 50 & RESD > 45 CoalLogRHOB <= 1.95 RHOB SPHI_MJP DPHI_265 >= 0.12 Proposed Cement Dale A. Haines Union Oil Company of California Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 _ Operations Anchorage, AK 99503 Tel 907 263 7951 ` Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 AUG 0 h 2009 Cathy Foerster Commissioner AlpskI Oil & Gas Nns, CommibfiioF4 Alaska Oil & Gas Conservation Commission Anrhai,Fq: 333 W. 7th Avenue Anchorage, Alaska 99501 n�T ?0 soma, Dear Commissioner Foerster, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, ()'e, 1 � Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 1642 1670770 Feb -87 Abandoned Phase 1 Abandon abandon at end of platform life Br 1842 1680120 Apr -89 Colla sed Casing 100% water production Phase 1 Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 21B-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/1-Iemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 444 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -Ono known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of pl form life F, F ' t ' I U'1\ L' 1_11 AIASKA 011L AND GALS CONSERVATION E OMUSSION June 22, 2009 Dale Haines k -4--i - c3 4- 0�, SARAH PALIN, GOVERNOR i f 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 UNOCAL crAiMM OCT 0 3 Z014, 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the welli.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska.,)ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 _ Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 _ Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 Union Oil Company of California 182-083 Trading Bay Unit D40RD _ Union Oil Company of California 178-045 _ Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 Trading Bay Unit G-24 Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD _ Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California _ 168-038 Trading Bay Unit K-06RD Union Oil Company of California 169-066 Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 _ MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 _ Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 _ Union Oil Company of California 100-269 Soldotna Ck Unit 41B-09 _ Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 _ Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 _ Union Oil Company of California 160-018 Swanson Riv Unit 212-10 _ Union Oil Company of California 161-033 Swanson Riv Unit 212-27 _ Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 Trading Bay St A-30 ) ) Chevron .. Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October 10, 2005 S(;ANNED NO'~ ~ [) 2.005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 ~/ " ~q \ ~..\Q ~\\.., Re: Baker Platform Pilot Pre-Abandonment Work Summary Dear Commissioner Norman, This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BHP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BHP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. \"""',. ~. Jf1~. 1\'r' ~J E · . .~-' t .~. l ~,... '~J Union Oil Company of California I A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker SOland in the gas well Baker 32. In light of the Chevron Corporation acquisition of Unocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, ~ --ac', .2 ~ L-.g- '/~~ð Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California I A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27-Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-J ul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7 -J ul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned -' Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Injector 6.;J uH05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 ~Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba-17 Injector No survey Ba -1 8 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 ~ Ba-31 Producer 29-Jul-05 11 433 10636 3795 0.357 6.9 Ba-32 Producer No survey '~~!Æ~! ) :} !Æ ~fÆ ~ ~«fÆ ) A I¡ASIiA. OIL AlVD GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. .,-rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 l,.",.,L"..',.'. """'" ,"","';'...-K"""",,'ifG::~4ii' ,"t1;;;""'" ,j, ~':;"fF'Y r i Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiVÍlÍg your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be llbmitted forthwith. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 SCANNEf~~ NO\! -¿ 4 2004, Enel. 1", STATE OF ALASKA ) ALAb" ,,' OIL AND GAS CONSERVATION COMMISSiON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Perforate U WaiverU Annular Dispos. U Plug Perforations D Stimulate D Time Extension D Other 0 Perforate New Pool D Re-enter Suspended W,,;tl D Monitor Frequency 4. Current Well Class: 5. Permi~rill Number: Development 0 Exploratory D 167~ Stratigraphic D Service D ~PI Number: / 50-733-20039-00 .I 9. Well Name and Number:/ Ba-13 / 10. Field/Pools(s): / Middle Ground yt<oal PRESENT WELL CONDITION SyMMARY Effective Depth MD (ft): Effective DéPth TVD (ft): 266' 30" 595' 20" 2,012' 13-3/8" 8,920' 9-5/8" 1,884' 7" Perforation Depth TVD (ft): 5,518 to 8,479 12. Attachments: Description Summary of Pr posal ~ Detailed Operations Program D etch D 14. Estimated Date for Commencing Operations: Commission Representative: 17. I hereby certify that the foregoing is tr e and correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY ,{ ,) Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 79' 8. Property Designation: BAKER 11. Total Depth MD (ft): 10,691' Casing Structural Conductor Total Depth TVD (ft): 10,375' Length Surface Intermediate Production Liner Perforation Depth MD (ft): 5,750 to 8,755 Packers and SSSV Type: 16. Verbal Approval: Printed Name /J,,' D.», ol,e ~ Signature Mv¥/lJd Suspend U Repair well D Pull Tubing D 8,850' Plugs (measured): Junk (measured): Drillable B.P.@ 8,850' & @ 9,400' Burst 8,559' Size TVD Collapse 266' 595' / 2,012' 8,920' 1,978' 8,635' 2,330 psi 1,130 psi 6,870 psi 4,760 psi 8,697 psi 5,885 psi Tubing MD (ft): LS: 7,150' SS: 7,065' 8,806'-10,690' ubing Size: 8,528'-10,356' Tubing Grade: L.S.3-1/2" S.S.3-1/2" Both 9.2# L-80 Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D WDSPL 0 Service D D D Abandoned D D Plugged WINJ Phone 27-Sep-2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3CJi-L(Lf.~ Plug Integrity D BOP Test D Other: Mechanical Integrity Test D D Location Clearance RBDMS BFL NOV 222004 APPLlCATlONRETURNED 11/17104 NOT APPROVED BY COMMISSION Subsequent Form Required: Approved by: ~D3 Form 10-4Q4.Revised 12/2003 RECEIVED OCT 1 2 2004 Q R I ~ , \j A I BY ORDE~~ka Oil & Gas emu;:" Commission OFv1MIAs~NER LrHE COMMISSION AnGbwage Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Suspend Lj Operation Shutdown Lj PerforateLj WaiverLj Other d Performed: Alter Casing ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Time Extension F] Change Approved Program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re-enter Suspended Well[-] Shut in & secure 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development Q Exploratory❑ Stratigraphic❑ Service❑ 1670490 3. Address: 909 West 9th Ave. 6. API Number: Anchorage AK 99501 50-733-20039-00 , j 7. KB Elevation (ft): 9. Well Name and Number: 79' Ba -13 8. Property Designation 4 10. Field/Pool(s): i BAKER L+r Middle Ground Shoal �''" �1 e 11. Present Well Condition Summary: ` Total Depth measured 10,691' feet Plugs (measured) Drillable B.P. @ 8,850' true vertical 10,375' feet Junk (measured) Drillable B.P. @ 9,400' Effective Depth measured 8,850' feet; SCANNED true vertical 8,559' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 266' 30" 266' 266' Surface 595' 20" 595' 595' Intermediate 2,012' 13-3/8" 2,012' 1,978' 2,330 psi 1,130 psi Production 8,920' 9-5/8" 8,920' 8,635' 6,870 psi 4,760 psi Liner 1,884' 7" 8,806'-10,690' 8,528'-10,356' 8,697 psi 5,885 psi Perforation depth: Measured depth: See attached sheet True Vertical depth: See attached sheet Tubing: (size, grade, and measured depth) L.S. 3-1/2", 9.2#, L-80, 7,150' S.S. 3-1/2", 9.2#, L-80, 7,065' Packers and SSSV (type and measured depth) RECEN None 12. Stimulation or cement squeeze summary: 1 `n 7 4 L' Intervals treated (measured): , i*a N 9, GA -s Cons. GOIm*of6 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water Bbl Casing Pressure Tubing Pressure Prior to well operation: 55 269 55 60 Subsequent to operation: 0 0 220 on 10/05/03 440 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory[] Development Service ❑ 16. Well Gtatus after proposed work: Daily Report of Well Operations Oil Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ 17. 1 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 Printed Name P. M. Ayer Title Petroleum Engineer Signature Phone 263-7620 Date 10 Jun 2004 • HBDMS MAY 2 9 2012 'F2 Form 10-404 Revised 12/2003 Wellview database / Baker 13 COM DTTM DEPTHTOP DEPTHBTM TYP SHOTDENSITY SQZD 1985❑1j; 5,750 5,770 SQZD 1985; 5,795 5,805 SQZD 1985; 5,865 5,875 SQZD 1985; 6,215 6,370 SQZD 1985; 6,535 6,935 12/10/1997 0:00 7,195 7,210 2-1/8" Hollow carrier 4.0 E, 1985❑❑; hide 7,195 7,210 12/10/1997 0:00 7,206 7,221 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,240 7,250 2-1/8" Hollow carrier 4.0 E, 1985❑❑; hide 7,240 7,250 12/10/1997 0:00 7,251 7,261 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,265 7,275 2-1/8" Hollow carrier 4.0 E, 1985❑❑; hide 7,265 7,275 12/10/1997 0:00 7,275 7,285 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,280 7,290 2-1/8" Hollow carrier 4.0 E, 1985❑❑; hide 7,280 7,290 12/10/1997 0:00 7,290 7,300 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,525 7,540 2-1/8" Hollow carrier 4.0 F, 198511D; hide 7,525 7,540 12/10/1997 0:00 7,536 7,551 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,555 7,565 2-1/8" Hollow carrier 4.0 F, 1985❑❑; hide 7,555 7,565 12/10/1997 0:00 7,566 7,576 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,715 7,730 2-1/8" Hollow carrier 4.0 F, 1985'❑ ❑; hide 7,715 7,730 12/10/1997 0:00 7,725 7,740 2 1/8" H. CARRIER GUNS 4.0 12/10/1997 0:00 7,870 7,890 2-1/8" Hollow carrier 4.0 G, 1985❑ ❑ 7,870 8,010 12/10/1997 0:00 7,878 7,898 2 1/8" H. CARRIER GUNS 4.0 G, 1985; 8,030 8,080 G, 1985; 8,150 8,170 G, 1985; 8,200 8,380 G, 1985; 8,425 8,616 G, 1985; 8,645 8,755 ISOLATED BY BRIDGE PLUG; 8,985 9,010 ISOLATED BY BRIDGE PLUG; 9,035 9,100 ISOLATED BY BRIDGE PLUG; 9,235 9,260 ISOLATED BY BRIDGE PLUG; 9,270 9,340 ISOLATED BY BRIDGE PLUG; 9,470 9,480 ISOLATED BY BRIDGE PLUG; 9,580 9,590 ISOLATED BY BRIDGE PLUG; 9,760 9,770 ISOLATED BY BRIDGE PLUG; 10,035 10,050 ISOLATED BY BRIDGE PLUG; 10,075 10,090 ISOLATED BY BRIDGE PLUG; 10,100 10,110 ISOLATED BY BRIDGE PLUG; 10,260 10,275 ISOLATED BY BRIDGE PLUG; 10,480 10,495 ISOLATED BY BRIDGE PLUG; 10,520 10,535 Printed on 6/10/2004 at 2:20 PM Jeff Dolan Ba -13 10-404 20040610.x1s Platform: Baker Well: #13 Revised: 12-10-97 Completion Casing and TubinE Detail Casing: 13-3/8" 54.5# CSA 30' 2,012' 9-5/8" 40-43.5#N-80 30' 8,920' 7" 26# 5-95 8,806' 10,690 Short String: Split 11" DCB Hanger, 3-1/2" EUE Top, Cameron Type "H" BPV profile, 3-1/2" Butt Dwn @ 31' 3-1/2" 9.2# L-80 Butt 31' 7054' X/0 3-1/2" Butt x 2-3/8" EUE 7054' 7055' 13-3/8" @ 2,012' 2-3/8" 4.6# L-80 EUE 7055' 7065' TRICO 3" Parallel DBL B cav 7065' Long String: Split 11" DCB Hanger, 3-1/2" EUE Top, Cameron Type "H" BPV profile, 3-1/2" Butt Dwn @ 31' 3-1/2" 9.2# L-80 Butt 31' 7052' 3-1/2" PUP L-80 Butt 7058' 7064' X/0 3-1/2" Butt x 3-1/2" EUE 7064' 7065' TRICO 3" Parallel DBL B cav 7065' 7088' X/0 3-1/2" EUE x 3-1/2" Butt 7088' 7088' 3-1/2" 9.2# L-80 Butt 7088' 7149' WLEG 7149' 7150' Perforations: A, B, C, & D Perforations: Squeezed 5750'— 5770' 5795'— 5805' 5865' — 5875' 6215'— 6370' 6535'— 6935' E -Zone Perforations: 7195' — 7210' 7206'— 7221' 7240' — 7250' 7251'— 7261' 7265'— 7285' 7280'— 7290' F -Zone Perforations: 7525'— 7551' 7555'— 7576' 7715'— 7740' GZone Perforations: ., ..` 7870'— 8010' 8030'— 8080' 8150' — 8170' 8200' — 8380' 8425' — 8616' 8645'— 8755' 9-5/8" @ 8,920' Bridge Plug Isolated Perforations: 8985'— 9010' 9035'— 9100' 9235'— 9260' 9270' — 9340' 9470'— 9480' 9580' — 9590' 9760'— 9770' 10035'— 10050' 10075'— 10090' 10100'— 10110' 10260'— 10275' 10480'— 10495' 10520'— 10535' Bridge Plugs; Drillable BP set at 8,850' Drillable BP set at 9,400' PBTD: 8,850' TD: 13,821' Max Hole Angle: 33 @ 1850' 7" @ 10,690'zpl� E BAKER PLATFORM API # 50-733-20039-00 M G S ST. 17595 # 13 WELL HISTORY LAST WORK: 5/8/99 Date Finaled Work Performed 1968 1/1/68 COMPLETED AS AN OIL WELL. 6-68 Killed well with mud. Squeezed 8675-9095' with cement. Did not drill out. Squeezed 5865-75' and 5900-5910' in A zone. Reperf 5750-5805'. Treated with 5500 gallons mud acid. Swb water x sand. Re-acd with 2200 gallons 6% MCA. Swb 85 BF in 14.5 hours. (28% BS&W). Ran gas lift equipment. Closed sleeves to A zone. Prod. EFG only. After: 522 BFPD, 7.3% BS&W, 253 MCFD 12-68: Perf. add'1 EFG zone. 1971 10-71 Killed well with oil base mud. Squeezed A zone with 150 sx Class G cement. Squeeze did not hold. Squeezed with 400 sx, squeeze held at 950 psi. Put EFG on Kobe. Prior: 1280 BOPD, 34 BWPD, 708 MCFD After: 1630 BOPD, 56 BWPD, 388 MCFD 1973 3-73 Killed well with oil base mud. Pulled BHA. CO scale to 8658' Prior: 1255 BOPD, 92 BWPD, 276 MCFD After: 1744 BOPD, 5 BWPD, 583 MCFD 10-73 Killed well with 7-8 PPG mud. Pulled BHA (found scale on pump. CO to PBTD. Prior: 1124 BOPD, 50 BWPD, 292 MCFD After: 1328 BOPD, 47 BWPD, 481 MCFD 1974 10-74 Killed well with oil based mud. Pulled BHA (stuck pump). CO to 8620'. Prior: 1245 BOPD, 99 BWPD, 534 MCFD After: 1203 BOPD, 55 BWPD, 466 MCFD 4-74 Killed well with oil base mud. Pulled BHA (stuck pump). CO to 8860'(30' of fill). DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) 4-74.1 Prior: 1200 BOPD, 118 BWPD, 412 MCFD After: 1269 BOPD, 77 BWPD, NG on gas 1977 8-18-77 Killed well with salt water containing Dowell's F-75. Pulled BHA (scaled in). Used 15% HCI to free BHA. CO to 8650'. Test BCD, A, squeezed perfs at 3886-4270', x casing bowl at 10,741'. A zone broken down. Acd G zone with 3500 gallons 15% HCI with additives. Squeeze A zone with 450 sx Class G cement with fluid loss x viscosity additives - Held OK. Set packer at 7050'. Run Type `B' BHA. Prior: 410 BOPD, 13 BWPD, 74 MCFD After: 294 BOPD, 45 BWPD, 86 MCFD with smaller pump Estimated cost - $303,313 1978 10-78 Reverse circulated well to retrieve pump. Pressured up to 3200 psi. Appeared as though pump would not unseat. Ran in with wireline and found pump at 3000'. Pulled out of hole. Circ in 3" Type 'B' Kobe Acidizing Dummy. Circ PO at a 360 BPD rate at 1500 psi. Pump 24 bbls 7% HC1 x 10 gal. A200 Inhibitor at 1/4 bbl/min. at 1500 psi. Displace with PO at 360 rate (120 bbls). Pressure dropped from 1500 psi to 1100 psi. Unseat acidizing tool with 150 psi. Circ well x PO for 1/2 hour at 500 BPD rate at 0 psi differential. Re -ran Kobe pump. Before: 266 BOPD, 24 BWPD, 103 MCFD After: 311 BOPD, 48 BWPD, 143 MCFD 1979 1-79 Circ well x PO. Rigged up Schlumberger and reperforated the following intervals with 2-1/8".Ener-Jet gun with 2 JSPF and zero - degree phasing: 8425-8510' 8040-70' 8200-8380' 7880-8000' (415' total) Well was put on production by operating conditions of pump indicated cavity and production string was scaled up.DRILLING AND Rigged up Dowell x acidizing bottomhole assembly with 3" Kobe acidizing dummy pump. Circulate 1000 gallons of 7 percent of HCL inhibited with A200. Followed with PO at 1/4 BPM. Circulate acidizing dummy out of hole. Before: 275 BOPD, 31 BWPD, 132 MCFD After: 690 BOPD, 280 BWPD, 260 MCFD 1981 7-20-81 Tubing leak. Killed well with 9.5 PPG NaCl. Retrieved packer at 7050'. Tested BCD zone perforations. Leaks found at 5750-5190', 6825-6935'. Cement squeezed leaks. Ran new BHA and tailpipe to 7850'. No packer. WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) Date Finaled Work Performed 7-20-81 (cont.) Before: 34 BOPD, 7 BWPD, 55 MCFD After: 112 BOPD, 260 BWPD, 33 MCFD 9-22-81 Acidized BHA. Sclae problems since packer removal. 1982 1-1-82 Killed well with 9.4 PPG CaCI. Set packer at 7150' to separate BCD zone perforations from G zone, due to severe scale problems. Annulus is full of inhibited fluid. Before: 364 BOPD, 206 BWPD, 95 MCFD After: 216 BOPD, 226 BWPD, 23 MCFD 1-10-82 Tagged fill at 8611' KB. 1985 10-11-85 Killed well with 9.2 ppg NaCl water with 3 percent KCI and 2 ppb EDTA. Cement squeezed 6215-70', 6825+45', 6920-35' and placed 50 sx class G behind pipe. Cleaned out to 9900, ran GR log and set bridge plug at 9400. Perforated 8510-8615' 9035-9100' 8645-8755' 9235-60' 8985-9010' 9270-9340' Placed well on hydraulic lift and it sanded up immediately. Before: 100 BOPD, 140 BWPD, 40 MCFD After: Sanded up and shut-in 10-23-85 Killed well with 9.2 ppg NaCl water with 3 percent KCI and 2 ppg EDTA. Pulled tubing, washed sand from 9310-9400'. Returned well to production. Before: Shut-in After: 112 BOPD, 789 BWPD, 51 MCFD 1991 3-23-91 Replace failed tubing and 1163 ft of 9-5/8" production casing. Casing corroded by continuous annular injection of undiluted scale inhibitor. Set BP @ 8850' 7-91 SOC scale inhibitor treatment. 12-14-91 6000 gal 7-1/2% HCl acid wash and squeeze with 1.5" swirl nozzle on 1.25" coiled tubing followed by SOC scale inhibitor treatment. Tagged fill @ 7901' WLM. Production increased from 100 BOPD to 150 BOPD. 1992 1-7-92 Scale inhibitor squeeze. DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) Date Finaled Work Performed 2-8-92 Lost pump pulling tools. Circulated fish and pump out of hole. Fish recovered. Tagged btm @ 7892' SLM. 3-9-92 Lost pump pulling tool. Unable to fish. 3-25-92 Pull tubing and remove pump and pulling tool fish lost 3/9/92. Squeezed leaking `B' zone perfs w/cmt from 5865'- 5875'. Drilled out to 8806' DPM. Ran dual 3-1/2" Kobe pump completion. 1995 1-28-95 Pulled pump. Wireline noted tight spot in L string. 1996 8-30-96 Unable to pass bundle test. SI S string while continuing to pump the well @ 1500 power oil psi and 700 BOPD power oil rate with pump pressure normal and fluid level rising. Suspect hole in S string. Pulled STV, tagged fill w/1-7/8" tool string @ 7963' SLM. 12-30-96 AFE 125494 Circ pump out of well. R/U slickline on S string. RIH w/2.31" gauge ring to 7154' WLM/RKB. RIH w/1-1/4" nylon flag tool to 7154' WLM/RKB while injecting power oil down S string @ 540 BOPD rate with L string master valve shut and annulus open. Unable to find leak. Saw slight bobble at 3880' WLM/RKB. Increased power oil injection rate to 1000 BOPD and ran past 3880' WLM/RKB again, no indication of leak. RIH w/2.8" gauge ring, cut scale to 381 1'WLM/RKB, POOH and circ scale out w/power oil. RIH w/2.72" gauge ring, cut scale to 7030' WLM/RKB, POOH and circ scale out w/power oil. RIH w/2.65" gauge ring, cut scale from 7031' to 7154' WLM/RKB tag 2-3/8" XO at top of cavity, POOH and circ scale out w/power oil. RIH w/2.72" gauge ring, cut scale from 7032' to 7154' WLM/RKB, POOH and circ scale out w/power oil. RIH w/2.65" swedge tool tag top of cavity @ 7154' WLM/RKB. P/U swedge, stuck, unable to POOH. Closed annulus, opened S string, pressured up on L string with power oil. S string pressure zero, annulus and L string pressure equal. Slickline tools freed when L string pressure reached 600 psi, POOH. RIH w/2.5" swedge to 7139' WLM/RKB. Pumped power oil down S string with L string SI at 1600 BPD rate. Tools gained wt from 530# to 600#, indicating flow past tools. R/D slickline from S string. R/U slickline on L string. Pull STV. RIH with 1-3/4" tool string, tag btm @ 7952' WLM/RKB. Rerun STV. R/D slickline. NOTE: Confirmed leak in S string side of cavity below 7154' WLM/RKB. 1997 8/20 TAG — Tag fill @ 8,573' Long String. 8/21 WL — Cut Long String tbg @ 7,100' DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) Date Finaled Work Performed 1997 (cont.) 8/27-9/4 WO - 27 -Aug Bled well to production. Offload HWC equipment to Baker Platform and spot for RU 28 -Aug RU HWC and pumping equipment. Pressure test mud pump hardlines. Turned well over to 3% KCI taking returns back to production. 29 -Aug Completed killing well and monitor for pressure buildup. Stable. ND Injection manifold. Set BPV's. ND tree & NU BOP's and koomey lines. Function test. NU work window and basket. Pull BPV's and Set 2 -Way checks. Ptest annular 250-3500. Test blind and pipe to 250-5000. Test surface lines 250-5000 psi. Pull 2 -Way Checks. Finish RU on Jack equipment. 30 -Aug Continue RU ops. Circulated well to production taking returns from annulus. Cleared residual oil. PU long string and work pipe. POOH with long string 31 -Aug POOH with Long string. MU landing joint in short string. POOH with short string. 1 -Sept Continue POOH with short string. Recovered KOB cavity. Set test plug and test DCB spool. OK. Pull test plug. Changed out and tested dual rams for 3-1/2". PU KOB cavity and tail pipe. Start running 3-1/2" dual completion. 2 -Sept Continue running dual completion 3 -Sept Continue running 3-1/2" dual. Stop with LWEG @ 7149'. PU and space out strings. MU hangers. Land hangers. Engage hold down pins . RIH with 2.85" GR and verify no obstructions in tubings. Drop standing valve and allow to fall. Circ dwn LS with returns from short. Pressure test tubulars to 4000 psi. Record on chart. Test good. Set BPV's. Start RD HWO unit 4 -Sept Continue RD HWO unit and risers. NU tree. Test hanger and voids to 5k. Good. Pull BPV's and set 2 -Way checks. Test tree to 5k. Test good. Pull 2 -way checks. Install production lines. Released well at 06:00 12/10 PF - Perforate W/2-1/8" Hollow Carrier Guns, 4 HPF, 0 Phase Zone Interval Feet E 7,206' - 221' 15' E 7,251' - 261' 10' E 7,275' - 285' 10' E 7,290' - 300' 10' F 7,536'- 551' 15' F 7,566'- 576' 10' G 7,725' - 740' 15' G 7,878' - 898' 20' TOTAL 105' DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) Date Finaled Work Performed 1997 (cont.) Production Tests: Date Oil Bbls Gas MCF Water(BbIs) TP Psi CP Psi 12/3/97 77 102 368 70 70 12/16/97 111 32 336 70 70 1998 6/30 WL — (Pulled pump, circulate well ) RIH with 2.5" SB baited on over shot to 7050, 7089 KB jar for 30 -min., pump came free, POOH with pump, rubber off packer cups in hole. 7/1 WL — (Equalize, standing valve, pull same, run new standing valve ) RIH with equalizing prong to 7,084', work tool well went on vacuum POOH. RIH with KOBE pulling prong to 7,084', work tool, POOH, got standing valve rubber in SV had friction. RIH with new standing valve, fluid level 1,400', shake Off POOH. 1999 5/7-8 TAG - Pulled SV & RIH w/ 2" gauge ring to fill @ 8,041' KB, reran SV to fluid level. POOH. 06/30/03 Shut in well B-13 and reverse circulate pump to surface. Kill well and pull pump as usual. Line up well B-13 to circulate 125 bbls of water down long string and up short string. Once flushed, pull standing valve with wireline. All casing and tubing valves closed; pipe connections removed and blind flanges installed. Gauges installed to monitor pressures. DRILLING AND WORKOVER HISTORY MIDDLE GROUND SHOAL 17595 WELL NO. 13 (continued) MIDDLE GROUND SHOAL ADL 17595 WELL NO. 13 Pertinent Data: Spud Date: Completion Data: 1/1/68 Surface Location: Slot 6, Leg 2, - 1983' FNL, 589' FWL, Section 31, T9N, R12W, S.M. Subsurface Location: 542' FNL, 805' FWL, Sec. 31, T9N, R12W, S.M. Elevation: 78.75' RKB from MSL Total Depth: 10,691' Plug Back Depth: 8660' Casing: 20", 85# @ 595'w/1285 sx 13-3/8", 54.5# @ 2012'w/1900 sx 9-5/8", 40 and 43.5# @ 8920'w/1700 sx (1st stage - 875', 2nd 6902' - 825 sx) 7", 38# @ 8806-10,690'w/420 sx Initial Potential: A zone 642 BOPD, 428 BWPD, 841 GOR, 125 TPF EFG zone 1485 BOPD, 6 BWPD, 402 GOR, 100 TPF Initial Stimulation: None MIDDLE GROUND SHOAL ADL 17595 WELL NO. 13 Perforation Record: Date Zone Interval 11-67 EFG 10035-50', 10075-90', 10100-110' x csg gun in oil base mud. 11-67 BCD 6215-25', 6245-70', 6330-70'x csg gun in oil base mud. 12-67 BCD 6535-45', 6570-80', 6825-45', 6920-35' x csg gun in oil base mud. 12-67 BCD 6245-70', 6215-25 ' x csg gun in oil base mud. 12-67 A 5900-10', 5865-75', 5795-5805', 5760-70'x csg gun in oil base mud. 12-67 EFG 7195-7210', 7240-50', 7265-75', 7280-90', 7525-40', 7555-65', 7715-30', 7885-95', 7910-20', 7950-60', 7990-8000', 8050-60', 8215-20', 8230-35', 8280-90', 8320-25', 8345-50', 8370-80', 8425-35', 8480-8500', 8600-10', 8675-80', 8690-8700', 8995-9005', 9035-45', 9060-70', 9085-95', 9245-55', 9275-90', 9320-35', 9470-80', 9580-90', 9760-70', 10260-75', 10480-95', 10520-35'x csg gun in oil base mud. 6-68 A 5750-5805'x csg gun in water base mud. 12-68 EEG 8425-8510', 8200-8380', 8150-70', 8030-80', 7870-8010' x tbg gun in well fluid. 1-79 EFG 8425-8510', 8200-8380', 8040-8070', 7880-8000' 2-1/8" Ener -Jet at 2 JSPF. MIDDLE GROUND SHOAL ADL 17595 WELL NO. 13 (Continued) Reservoir Data: Zone Depths: A zone - 5612-6058' BCD zones- 6058-7165' EEG zones- 7165-10,691' Cored Intervals: BCD zones - 6240-65', 6447-65' EFG zones - 7710-35' DST Intervals and Results: Open hole 8904-9579', GTS 4 hours 25 minutes. OTS 12 hr. 25 min. Tool open total 36 hr x prod. 110 BO x 2 BM at max. TPF 150 psi. Rev. out 37 bbls clean oil, 50 bbls 0 x GCM, 2 bbls clean oil x 3 bbls water FFP 2520 psi. Perf interval 10,035-110'. No fluid to surface. Rev. out 35 BO x 5 BW x 10 bbls GCM, FFP 1350 x FSIP 3640. Perf interval 6215-6370' . GTS 2 hrs. x no fluid to surface. Reverse out full column water. Perf interval 6535-6935' . No fluid to surface. Rev. out 29 bbls SGCM x 30 BW in 26-1/2 hrs. FFP 2407 x FSIP 2455. Perf interval 5760-5910', GTS 12 min., GCMTS 32 min. x FLW 72.7 BFPH at 45% BS&W (2% water x 43% mud emulsion) x 853 MCFD at GOR 474 x TPF 220psi. Perf interval 7130-8660'. GTS 1-1/4 min. x fluid to surface but would not flow. Rec. 123 BF x top sample 14%mud, 86% oil x trace water, middle x btm sample 100%emulsified oil x mud x trace water. Perf interval 5865-5910' . GTS 50 min. x no fluid to surface. Rec. 5 bbls G x OCM x 47 bbl fresh water. Perf interval 5750-- 5805', GTS in 40 min. x no fluid to surface. Rec. 1 bbl W x MCO, 47 bbl MCW x wtr. Selective Tests: As given in DST's x workovers above. Log Inventory: IES, GRS x Dipmeter. BAKER CLEANING TASK LOCI Task Completed Confirmed BY Date By Tom McCaughey 6/28/2003 Rick Lewis Shutdown Wells and Pull Pumps Note: Pull Kobe pumps now, before source water is circulated. If they are circulated out with water, the wells will be very difficult to put on vacuum. Pull pumps one at a time so oil will be replaced with produced water. Tom McCaughey 6/28/2003 Rick Lewis Shut in well B-13 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 61`29/2003 Rick Lewis Shut in well B-6 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-5 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-11 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-30 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/29/2003 Rick Lewis Shut in well B-29 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Shut in well B-28 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Shut in well B-25 and reverse circulate pump to surface. Kill well and pull pump as usual. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-13 to circulate 125 bbis of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Line up well B-6 to circulate 125 bbis of water down long string and up short string. Once flushed, pull standing valve with wireline. Tom McCaughey 6/30/2003 Rick Lewis Circulate B-20 by operating the pump with power water for 50+ bbis. Pull CT Jet pump in Well B-20. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-5 one tubing volume of 102 bbis. Pull standing valve in B-5. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-11 one tubing volume of 71 bbis. Check for clean returns. Pull standing valve in B-11. Tom McCaughey 1 7/1/2003 Rick Lewis Circulate Well B-28 one tubing volume of 146 bbis. Pull standing valve in B-28. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-30 one tubing volume of 65 bbis. Unable to pull standing valve in B-30. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-29 one tubing volume of 140 bbis. Pull B-29 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Circulate Well B-25 one tubing volume of 134 bbls. Check for clean returns. Pull B-25 standing valve. Tom McCaughey 7/1/2003 Rick Lewis Operate Well #31 while metering power fluid for one complete tubing/casing volume of 480 bbis. There is no standing valve so operating the pump will circulate out any power oil remaining in the well. Tum well over to Wireline to pull pump. Tom McCaughey 7/6/2003 Brett Aldridge Blind Well # 14 gas in Leg Room 1 to isolate it from the LP Dehy. Rick Lewis 8/24/2003 Rick Lewis Blinded Injection Well B-16 after completing final injection and flush. Note that this information was extracted from the overall Baker Cleaning Task Log by Rich Novcaski 6/10/04. STATE OF ALASKA ALASKA OIL GAS CONSERVATION cOMMISSION REPORT OF-SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: X 101' RKB above MLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. BOX 196247 ANCHORAGE, AK 99519 Service: MGS State 17595 4. Location of well at surface Baker Platform Leg # 2, Slot # 6 8. Well number 1983' FNL, 589' FWL, Sec. 31, T9N, R12W, SM Well No. 13 At top of productive interval 5,612' MD 9. Permit number/approval number 764' FNL, 1427' FWL, Sec. 31, T9N, R12W, SM 67-49 At effective depth 8,850' MD 10. APl number 536' FNL, 1228' FWL, Sec. 31, T9N, R12W, SM 50- 133-20039-00 At total depth 10,691' MD 11. Field/Pool '542' FNL, 805' FWL, Sec. 31, TgN, R12W, SM Middle Ground Shoal 12. Present well condition summary Total depth: measured 10,691' Plugs (measured) Drillable B.P. @ 8,850' true vertical 10,375' Drillable B.P. @ 9,400' Effective depth: measured 8,850' Junk (measured) true vertical 8,559' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 595' 20" 1,285 sxs 595' 595' Surface 2,012' 13-3/8" 1,900 sxs 2,012' 1,978' Intermediate Production 8,920' 9-5/8" 1,700 sxs 8,920' 8,635' Liner 1,884' 7" 420 sxs 8,806'- 10,690' 8,528'- 10,356' Perforation depth: measured See attachments. ORIGINAL true vertical Tubing (size, grade, and measured depth) L.S. 3-1/2", 9.2#, L-80, 7,150' MD On 9/3/97 Tbg. was pulled and replaced. S.S. 3-1/2", 9.2#, L-80, 7,087' MD Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary RECE.%'"[~, V EL,/ Intervals treated (measured) On 12/10/97 the 40 sand was perforated 4 HPF, see attachments for details.MAR 2 5 1998 Treatment description including volumes used and final pressure Alaska Oil & Gas Cons, ~~ 14. Representative Daily Average Production or Iniection Data ~-a~i'&l~ OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/3/97 77 102 368 70 70 Subsequent to operation 12/16/97 111 32 336 70 70 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 A. Haines ~,~'~_. r.. ~L.-,._ Title: Drilling Manager Date: February 5, 1998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE PERFORATION DATA SHEET BAKER # 13 Perforated W/2-1/8" Hollow Carrier Guns, 4HPF, 0 Phase. DaM zone Interval N[D Interval TVD 12/10/97 E Zone 7,206' - 7,221' 6,958' 12/10/97 E Zone 7,251' - 7,261' 7,002' 12/10/97 E Zone 7,275' - 7,285' 7,025' 12/10/97 E Zone 7,290' - 7,300' 7,040' 12/10/97 F Zone 7,536' - 7,551' 7,283' 12/10/97 F Zone 7,566' - 7,576' 7,313' 12/10/97 G Zone 7,725' - 7,740' 7,471' 12/10/97 G Zone 7,878' - 7,898' 7,623' - 6,973' - 7,012' - 7,035' - 7,050' - 7,298' - 7,323' - 7,486' - 7,643' Perforations open to wellbore. Measured Depth 7,195' - 7,221'; 7240' - 7,551'; 7,555' - 7,576'; 8,030'- 8,080'; 8,150' - 8,616'; 8,645' - 8,755' 7,261'; 7,265' - 7,300'; 7,525' - 7,715' - 7,740'; 7,870' - 8,010'; 8,170'; 8,200' - 8,380'; 8,425' - True Vertical Depth 6,947' - 6,973'; 6,991' - 7,012'; - 7,298'; 7,302' - 7,322'; 7,461' 7,754'; 7,774'- 7,824'; 7,893' - 8,164' - 8,347'; 8,375' - 8,479' 7,030' - 7,050'; 7,272' - 7,.486'; 7,615' - 7,913'; 7,942' - 8,120'; RECEIVED ~ £~ 1998 Alaska Oil & Gas Cons. Commission Anchorage UNOCAL Baker 13 HWO Daily Summary Well Baker 13 27-Aug Bled well to production. Offload HWC equipment to Baker Platform and spot for RU 28-Aug RU HWC and pumping equipment. Pressure test mud pump hardlines. Turned well over to 3% KCI taking returns back to production. 29-Aug Completed killing well and monitor for pressure buildup. Stable. ND Injection manifold. Set BPV's. ND tree & NU BOP's and koomey lines. Function test. NU work window and basket. Pull BPV's and Set 2-Way checks. Ptest annular 250-3500. Test blind and pipe to 250-5000. Test surface lines 250-5000 psi. Pull 2-Way Checks. Finish RU on Jack equipment. 30'-Aug Continue RU ops. Circulated well to production taking returns from annulus. Cleared residual oil. PU long string and work pipe. POOH with long string 31 -Aug POOH with Long string. MU landing joint in short string. POOH with short string. 1 -Sept Continue POOH with short string. Recovered KOB cavity. Set test plug and test DCB spool. OK. Pull test plug. Changed out and tested dual rams for 3-1/2". PU KOB cavity and tail pipe. Start running 3-1/2" dual completion. 2-Sept Continue running dual completion 3-Sept Continue running 3-1/2" dual. Stop with LWEG @ 7149'. PU and space out strings. MU hangers. Land hangers. Engage hold down pins. RIH with 2.85" GR and verify no obstructions in tubings. Drop standing valve and allow to fall. Circ dwn LS with returns from short. Pressure test tubulars to 4000 psi. Record on chart. Test good. Set BPV's. Start RD HWO unit 4-Sept Continue RD HWO unit and risers. NU tree. Test hanger and voids to 5k. Good. Pull BPV's and set 2-Way checks. Test tree to 5k. Test good. Pull 2-way checks. Install production lines. Released well at 06:00 summ.doc 12118/97 UNOCAL Baker 13 HWO Daily Summary 10-Dec Perforate W/2-1/8" Hollow Carrier Guns, 4 HPF, 0 Phase Zone E E E E F F G G TOTAL Inte~al 7,206'-221' 7,251'-261' 7,275'-285' 7,290'-300' 7,536'-551' 7,566'-576' 7,725'-740' 7,878'-898' Feet 15' 10' 10' 10' 15' 10' 15' 20' 105' summ.doc 12/18/97 Platform: Baker Well: #13 Revised: 12-10-97 Completion 13-3/8" @ 2,012' 9-5/8" @ 8,920' 7" @ 10,690' Casi and Tubi Detail Casing: 13-3/8" 54.5# CSA 30' 2,012' 9-5/8" 40-43.5#N-80 30' 8,920' 7" 2Or S-95 8,806' 10,690 Short String: Split 11" DCB Hanger, 3-1/2" EUE Top, Cameron Type "H" BPV profile, 3-1/2" Butt Dwn @ 31' 3-1/2" 9.2# L-80 Butt 31' 7054' X/0 3-1/2" Butt x 2-3/8" EUE 7054' 7055' 2-3/8" 4.6g L-80 EUE 7055' 7065' TRICO 3" Parallel DBL B cav 7065' Long String: Split 11" DCB Hanger, 3-1/2" EUE "Il" BPV profile, 3-1/2" Butt Dwn @ 31' Top, Cameron Type 3-1/2" 9.2# L-80 Butt 31' 7052' 3-1/2" PUP L-80 Butt 7058' 7064' X/0 3-1/2" Butt x 3-1/2" EUE 7064' 7065' TRICO 3" Parallel DBL B cav 7065' 7088' X/0 3-1/2" EUE x 3-1/2" Butt 7088' 7088' 3-1/2" 9.2# L-80 Butt 7088' 7149' WLEG 7149' 7150' Perforations: A, B,C,&D Perforations: Squeezed 5750'-5770' 5795'-5805' 5865'-5875' 6215'-6370' 6535'- 6935' E-ZonePerforafions: 7195'- 7210' 7206'- 7221' 7240'- 7250' 7251'- 7261' 7265'- 7285' 7280'- 7290' F-ZonePerforafions: 7525'- 7551' 7555'- 7576' 7715'- 7740' G-Zone Perforations: 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8616' 8645'- 8755' Bridge PlugIsolated Perforations: 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' Bridge Plugs; Drillable BP set at 8,850' Drillable BP set at 9,400' R E C E ~ V [ D PBTD: 8,850' TD: 13,821' Max Hole Angle: 33 @ 1850' Alaska 0il & Gas Cons. Anchoraoe / 0 RIG IN,IfiL ALA~ .OILAND GAS CONSERVATION COMM, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown w Stimulate __ PlUgging m Perforate __ Pull tubing __ Alter casing w Repair well X Pull tubing __ Other__ 2. Name of Operator 15. TyPe of Well: J Development UNION OIL COMPANY OF CALIFORNIA (UNqCAL) E~p,°rato./-- 3. AddreSs ...... l Stratigraphic P.O. BOX 196247 ANCHORAGE, AK 99519/ 4. Location of We, at surface Leg #2,' COnductOr '~-6, 'Baker"Platf0r~ 1983' FNL & 589' FWL, Sec. 31, T9N, R12W, SM At top of productive interval Top of "E" Zone at 7195' MD (6948' TVD) 764' FNL & 1427' FWL, Sec. 31, T9N, R12W, SM At effective depth 8850' MD (8559' TVD) 614' FNL & 1165' FWL, Sec. 31, T9N, R12W, SM At tolal depth 10691' MD (10357' TVD) 542' FNL & 805' FWL, Sec. 31, T9N, R12W, SM 6. Datum elevation (DF or KB) 101' RKB above MLW feet 7. Unit or Property name MGS State 17595 8. Well number Well No. 13 9, Permit number/approval number 67-49/91-080 10, APl number 50-133- 20039 11, Field/Pool Middle Ground Shoal 12. Present well condition summary Total depth: measured true vertical 10,691' feet Plugs (measured) 10,357' feet Effective depth: measured true vertical 8,850' feet Junk (measured) 8,559' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth 595' 20" 1285 sxs 595' 595' 2012' 13-3/8" 1900 sxs 2012' 1978' 8920' 9- 5/8" 1700 sxs 8920' 8635' 1884' 7" 420 sxs See attached perforation record 8806'- 10690' 8528'- 10356' true vertical Tubing (size, grade, and measured depth) Long string: 3-1/2" 9.2# N-80 Buttress at 7176' TM Short string: 3-1/2" 9.2# N-80 Buttri~'~'/~4~4~ Packersand SSSV (type and measured depth) None I\L~.,L/ v I..I.,' 13. Stimulation or cement squeeze summary Intervals treated (measured) 5865'--5875' Treatment description including volumes used and final pressure APR 2 2 199?- Alaska 0il & Gas Cons. C0mmissio~ Anchora.ae 250 sxs, 2000 psi @ 2-1/2 BPM 14, Prior to well operation Subsequent to operation Representative Daily. Average Production or Injection Data OiI-Bbl Gas-Mcr Water- Bbl Casing Pressure 0 0 0 100 ./.~t-- 80 800 0 Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil z~ Gas ~ Suspended Service 7. I hereby certify tl~at~the foregoing is true and correct to the best of my knowledge. ISigned Gary S. ~jlS~ ' . . Title Regional Drilling Manager Form 10-404 Rev 06/'t'5/88 Date SUBMIT IN DUPLICATE DATE BAKER #13 WORKOVER JOB HISTORY ETD COMMENTS 03/15/92 03/16/92 03/17/92 03/18/92 03/19/92 03/20/92 03/21/92 8850' 8850' 8850' 8850' 5900' 6450' 8806' SKIDDED RIG TO WELL#13. RIH WITH A 2.7" OD JET CUTTER AND CUT THE SHORT STRING AT 6870'. CIRCULATED 8.45 PPG BRINE. SIDPP 300PSI, SICP 350 PSI. INCREASED THE MW FROM 8.45 TO 9.6 PPG. INSTALLED BPV'S. REMOVED TREE. INSTALLED 13-5/8" 5M BOPE. TESTED THE BOPE TO 300 LOW AND 3000 HIGH. INCREASED MW TO 9.8 PPG. WELL STABLE. POOH WITH THE SHORT STRING TO 5420'. WELL STARTED FLOWING. RIH TO 6865' AND INCREASED MW TO 10.0 PPG. POOH WITH THE SHORT STRING. POOH WITH THE LONG STRING. TESTED THE BLIND RAMS TO 300 LOW AND 3000 HIGH, OK. RAN AN 8.5" GAUGE RING AND JUNK BASKET TO 7100'. RAN A 64 ARM CALIPER LOG FROM 7080' TO SURFACE, OK. BEGAN RIH WITH A RETRIEVABLE PACKER ON TUBING. CONT'D RIH WITH A RETRIEVABLE PACKER . SET THE PACKER AT 7083', 6450', AND 5950' AND ATTEMPTED TO TEST THE ANNULUS AT EACH SETTING, NEG. SET THE RETRIEVABLE PACKER AT 5850' AND TESTED THE ANNULUS TO 2000 PSI, OK. POOH LAYING DOWN TUBING. MADE UP CEMENT RETAINER ON 3-1/2" DP AND SET AT 5900'. POOH. CONT'D POOH. RIH AND SET A DRILLABLE RETAINER AT 5840' AND TESTED THE ANNULUS TO 2000 PSI, OK. SQUEEZED THE B ZONE PERFS FROM 5865' - 5875' WITH 250 SACK OF CLASS G CEMENT. REVERSE CIRCULATED. POOH. RIH AND DRILLED THE CEMENT AND RETAINER AT 5842' TO THE RETAINER AT 5900'. TESTED THE SQUEEZE TO 1000 PSI, OK. DRILLED THE RETAINER AT 5900'. CHASED RETAINER JUNK TO 6450'. CONT'D TO CHASE RETAINER JUNK TO 7892' SET DOWN, UNABLE TO CIRC. POOH. RIH AND TAGGED FILL AT 7882' CLEANED OUT TO 7898'. THERE IS A TIGHT SPOT IN THE CASING AT 7898', CAN ROTATE AN 8-1/2" BIT THROUGH BUT WITHOUT ROTATING THE BIT WILL SIT DOWN. CONTINUED CLEANING TO 8806'. CIRC. DATE BAKER #13 WORKOVER JOB HISTORY ETD COMMENTS 03/22/92 03/23/92 03/24/92 03/25/92 8806' 8806' 8806' 8806' CONT'D TO CIRC. POOH LAYING DOWN 3- 1/2" DP. PICKED UP AND DRIFTED 76 STANDS OF 3-1/2" TUBING FOR THE SHORT STRING. COMPLETED POOH WITH THE SHORT STRING. RAN A DUAL KOBE HYDRAULIC COMPLETION HYDROTESTING TO LONG STRING TO 4000 PSI AND DRIFTING THE LONG STRING. LANDED THE CIW 11" 5000 PSI DCB SPOOL, RAN THE TIE DOWNS AND PACKED OFF THE HANGER. INSTALLED BPV'S. REMOVED THE BOPE. INSTALLED AND TESTED THE 3-1/2" CIW TREE TO 5000 PSI. REMOVED THE BPV'S. HAD SOME DIFFICULTY GETTING THE PUMP THROUGH THE TREE. INSTALLED THE BPV'S. REMOVED THE TREE. INSTALLED THE TREE AFTER TURNING IT 180 DEG. REMOVED THE BPV'S AND RAN THE PUMP THROUGH THE TREE WITH NO PROBLEM. BEGAN DEACTIVATING THE DRILLING RIG. APR ~ 2 l°J~J~ Alaska Oil & Gas Cons. comm%SS'~ot~ Anchorage MGS 17595 #13 PERFORATION RECORD (3-23-91) ZONE "A" "B,C,D" t! E If CONDITION SQUEEZED SQUEEZED SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED MEASURED DEPTH 5750'- 5770' 5795'- 5805' 5865' 6215' 6535' - 5875' - 6370' - 6935' 7195' 7240' 7265' 7280' - 7210' - 7250' - 7275' - 7290' 7525' 7555' 7715' - 7540' - 7565' - 7730' 7870,- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' TRUE VERTICAL DEPTH 5518'- 5538' 5563'- 5573' 5632' 5979' 6297' - 5642' - 6034' - 6693' 947' 992' 007' 022' - 6962' - 7002' - 7017' - 7032' 7272' 7302' 7461' - 7287' - 7312' - 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377'- 8482' 8696'- 8721' 8746'- 8806' 8935'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 9708'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 0151'- 10166' 0191'- 10206' Ala~ RECEIV£D Oil & Gas Cons. Anchorage TOP OF LINER @ 8806' 9-5/8" 40, 43.5,--//' @ 8920' DRILLABLE BP @ 9400' PBTD @ 9900'/ 7" 38# O 10690' 1 A DRILLABLE BP- 8850' ,, LONG STRING (POWER FLUID) 1) CIW HANGER (BUTT-DOWN, RUE 8RD-UP) · 32.00' ) 3 EA 3-1/2 9.2~ BUTT PUPS (3.44. 5,15 & 5.17) 23) 3-1/2' 9.2# N-80 TBG, BUTr W/ SP Ct. CPI. OS 4) 3-1/2 9.2# BUTT PUP ~ 6970,05' 2 o~ 3-I/2 ~.~# aurr Pups (2.10 a ~.oa) 7) 3-~/~ now aox x &RD PiN x-oven · 714~.0~' 8) KOBE 3" MODEL "B" BHA · 7141.87 SHORT STRING (PRODUCTION) A) C~ HANGER (BUTt-DOWN. RUE 8ED-UP) · 30,28' B) 3 EA 3-1/2 9,2# BUTT PUPS (3,50, 5,20 a 4.00) C) 3-1/2" 9.2# N-80 TBe. BUTt W/ Si3 Ct. CPLGS ii3-1/2" 9.2# N-80 TBG PUP · 7031.63' 3-1/.2" OTIS "X" NIPPLE .(4.00 OD x 2.75 ID) · 7036.83° 3-1/2 BUTt BOX x 2-3/8 EU 8RD PIN X-OVER ~ 7129.99' G) 2-3/8# 4.6~ N-80 EU &RD PUP · 7131.75' TA~_ ASSEMBLY 9) 3--1/2" EU 8RD BOX x 3-1/2" BUTT X-OVER · 7164.55' 10) 2 EA 3-1/2" 9.2# N-SO Burr PUP (s.oo' & 5o09') 11) 3-1/2- BUTt WIRELINE RE-ENTRY GUIDE · 7176.23' 'A,B,C & D" ZONE PERFORATIONS 5750'- 5770' SQZD 5795'- 5805' SQZD 5865'- 5875' SQZD 6215'- 6370' SQZD 6535'- 6935' SQZD "E" ZONE PERFORATIONS 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' ZONE PERFORATIONS 7525'- 7540' 7555'- 7565' 7715'- 7730' ZONE PERFORATIONS 7870'- 8010' 8200'- 8380' 8030'- 8080' 8425'- 8615' 8150'- 8170' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 959O' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' ADL 17595 WELL NO. 13 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-23-91 ~A.---~j~ STATE OF ALASKA ~ _ ' OIL AND GAS CONSERVATION COMi ,SION0 i~ l[~ APPL! ON FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend Operations shutdown Alter casing__ Repair well __ Plugging __ Change approved program Pull tubing X Variance 2. ,N, am. e of..,Op, er,,ator 5. Type of Well: un~on u,~ L;ompany of California I Development X J Exploratory --- 3. Address I Stratigraphic -- P.O. Box 196247, Anch, AK, 99519 I s.~o ~ 4. Location of well at surface Leg #2, Conductor #6, Baker Platform 1983' FNL & 589' FWL, Sec 31, T9N, R12W, SM At top of productive interval Top of "E" Zone at 7195' MD (6948' TVD) Re-enter suspended well Time extension Stimulate Perforate Other 6. Datum elevation (DF or KB) 764' FNL & 1427' FWL, Sec 31, T9N, R12W, SM At effective depth 8850' MD (8559' TVD) 614' FNL & 1165' FWL, Sec 31, T9N, R12W, SM At total depth 10691' MD (10357' TVD) 542' FNL & 805' FWL, Sec 31, T9N, R12W, SM 10,691' feet 10,357' feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 8,850' feet true vertical 8,559' feet Casing Length Size Structural 595' 20" Conductor 2012' 13-- 3/8" Surface 89'20' 9-5/8" 101' RKB above' MLW feet 7. Unit or Property name MGS State 17595 8. Well number Well No. 13 9. Permit number 67-49/91 -080 10. APl number 50-133- 20039 Intermediate 11. Field/Pool ,., ... ,.,M,i~l~ ~N'ound Shoal Plugs (measured) MAR - 9 1992 Junk (measured) Alaska 0il & Gas Cons. Commission A h0r ge Cemented Measure~§ept~ True vertical depth 1285 sxs 595' 595' 1900 sxs 2012' 1978' 1700 sxs 8920' 8635' Production Liner 1884' 7" 420 sxs Perforation depth: measured See attached perforation record 8806'- 10690' 8528'- 10356' true vertical 2II Tubing (size, grade, and measured depth) Long string: 3-1/2" 9.2# N-80 Buttress at 7176' TM Short string: 3-1 9.2# N-80 Buttress at 7142' TM Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal __ Detailed operations programX__ BOP sketch X_ 14. Estimated date for commencing operation [15. Status of well classification as: March 13, 1992 16. If proposal was verbally approved Oil X_ Gas Name of approver ~ Date approved Sewice 17. I hereby certify that the foregeing i,~ t/'u~ and correct to the best of my knowledge. S i~nZ~d Gary S. Bush//,~/~,Q,.,/~? Title R ogional D rillingManager Date .~~.~/~/ ~" '"{ I' //¥' FOR COMMISSION USE ONLY Conditions el~ approval: Notify Commis~on stp~presentative may witness Approval No. Plug Integrity __ BOP Test __ Location clearance __ / Mechanical Integrity Test Subsequent form required 10 - ~ /--/'~i!':,i::~"~',,',~;~:~ Copy ORIGINAL SIGNED BY Approved by the order of the Commission LONNIE C, ~,~ITH Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MGS 17595 %13 PEREOI~ATION RECORD (3-23-91) ZONE "B,C,D" "(I-2" CONDITION SQUEEZED SQUEEZED SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISO~kTED ISOLATED ISOLATED ISOLATED ISOL~kTED ISOLATED' ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED MEASURED OEPT~,,, 5750'- 5770' 5795'- 5805' 5865'- 5875' 6215'- 6370' 6535'- 6935' 7195'- 721O' 7240'- 7250' 7265'- 7275' 7280'- 7290' 7525'- 7540' 7555'- 7565' 7715'- 7730' 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- ~0110' 10260'- ~0275' 10480'- Z0495' 10520'- 10535' TRUE VERTICAL DEPTH'' 5518'- 5538' 5563'- 5573' 5632'- 5642' 5979'- 6034' 6297'- 6693' 6947'- 6962' 6992'- 7002' 7007'- 7017' 7022.'- 7032' 7272'- 7287' 7302" - 7312' 7461'- 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377"-,8482' 8696'- 8721' 8746'- 8806' 8935.'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 9708'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 1015~'- 10166' 10191.'- 10206' RECEIVED MAR - 9 1992 Alaska Oil & Oas Cons. Commission Anchorage 13-3/8' 54.5, @ 2012' TOP OF UNER @ 8806' 9-5/8" 40, 43.5, @ 8920' DRILL.ABLE BP @ 9400' PBTD @ 9900' 7' 38# @ 10690' 1 A 10, 11 DRILLABLE BP -- @ 8850' LONG STRING (POWER FLUID) 11CIW ~ {BUTt-DOWN, EUE 8RD4JP) O ~ 2) $EA 3.1/2 ~.2~ BUTT PUPS (3.44, S.15 & 5,17) 4) 3-1/2 9.2# BUTT PUP O 6970.05' 6) 2 EA 3-1/2' 9.2e BU'IT PUPS (2.10 & 7) 3-1/2 BUTT BOX x 81:O PIN X. OVER ~) 7141.09' 6) KOBE 3' MODEL 'B" BI-IA ~ 7141.az' SHORT STRING (PRODUCTION) B) 3 EA 3-1/2 9.2e BLrn' PUPS (3.5O. 5.2O & 4.00) D) 3.1/2' 9.2# N.a0 TBG PUP ~ 7031.~3' E) 3.1/2' o'ns ,x', N~PPLE (4.00 OD x 2.75 iD) ~ 703~.a3' F) 3-1/2 BUTT BOX x 2-3/~ EU &cO F~ X-OVER O 7129.m' G) 2-3/S' 4.~ N-S0 EU aRD PUP ~l' 7131.7S' TAIL ASSEMBLY 9) 3-1/2' ELI aRD BOX x 3.1/7 BUTT X. OVER ~ 71~4.S5' 10) 2 EA 3-1/2' 9.2# ~ BUTT PUP (5.00' & 5.09') 11) 3-1/2" Bu'rr WIREUNE RE-ENTRY GUIDE ~i~ 7176.23' "A,B,C & D" ZONE PERFORATIONS 5750'- 5770' SQZD 5795'- 5805' SQZD 5865'- 5875' SQZD 6215'- 6370' SQZD 6535'- 6935' SQZD "E' ZONE PERFORATIONS 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' 'F' ZONE PERFORATIONS 7525'- 7540' Alaska 0il & Gas Cons. 7555'- 7565' Anchorage 7715'- 7730' "G' ZONE PERFORATIONS 7870'- 8010' 8200'- 8380' 8030'- 8080' 8425'- 8615' 8150'- 8170' 8645'- 8755' RECEIVE MAR - 9 1992 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' sSion ADL 17595 WELL NO. 13 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-23-91 2. 3. 4. ?. BAKER WELL #13 PROCEDURE MIDDLE GROUND SHOAL MOVE RIG OVER MGS 17595 fl3, LEG#;., SLOT #6. RIH WITH WIRELINE AND PUNCH THE LONG STRING AT 7000' KInL THE WELL WITH COMPLETION BRINE. ~NSTALL BPV' S. REMOVE TREE. INSTALL AND TEST T~E BOPE TO 3000 D.~T. PULL AND STAND BACK TRR DI~AL HYDRAULIC COMPL~"TION. RENLACR TN~ HYDRAULIC PUMD. RUN THE DUAL 3-1/2tt HYDRAULIC COMPLETION TO 7150t. REMOVE BOPE. INSTALL THE TREE. TIME: 5 DAYS RECEIVED MAR - 9 '1992 Alaska Oil & Gas Cons, Commission ;Anchorage PLATFORM BAKER DRILUNG. STACK PITCHER NIPPLE- 16° ID WIIO° FLOWLINE ANNULAR BOP 'NL SHAFFER' t3 518' 5000 PSI BX-160 ASSY WT. 13,650 LBS. DBL GATE BOP "NL SHAFFER" · -'--' 13 5/8' 5000 PS1 BX-160 ASSY WT. 18,800 LBS. MUD CROSS- 13 5/8' BORE WI4' 5000 PS1 VALVES SCI... GATE BOP 'NL SHAFFER" 13 5/8' 5000 PSI BX-160 ASSY WT. 9100 LBS. RISER 18°0D 13 5/8'5000 FL{]. RECEIVED MAR - 9 1992 Alaska Oil & Gas Cons. commissie~ Anchorage LOWER RISER 11' ID WllO' 5000 PSI FLG (RX-54) STATE OF ALASKA ""~' 0 Al_A,. , OIL AND GAS CONSERVATION COMMIS,. ..N REPORT OF SUNDRY WELL OPERATIONS 16 IN 1. Operations performed: Operation shutdOWn __ Stimulate ~ Plugging __ Perforate Pull tubing __ Alter casing ~ Repair well __ Pull tubing __ 2. Name of Opera~TNOOAL ) .Il 5. Type of Well: Development x Union oil ¢_nmpany of California , ExploratoryZ 3. Address I Stratigraphic_ P. O. BOX 196247, Anch. , AK, 99519 i Service __ 4. Location of well at surface Leg #2, Conductor #6, BaKer t~±atf°rm [983' FNL & 589' FWL, Sec 31, T9N, R12W, SM At top of productive intervalTOp of "E" Zone at 7195' MD (6948' T%) 764' FNL & 1427' FWL, Sec 31, T9N, R12W, SM At effective depth 8 8 5 0 ' MD ( 8 5 5 9 ' TVD ) 614' FNL & 1165' FWL, Sec 31, T9N, R12W, SM 10691' MD (10357' TVD) At ~al depth 54 FNL & 805' FWL, Sec 31, T9N, R12W, SM Other __ 6. Datum elevation (DF or KB) 101' RKB ABOVE ML~eet 7. Unit or Propertyname MGS STATE 17595 8. Well number W~q_l No. 13 ~' {t. Per~rti~ n_u~~p_..j~)v;~l(~umber 10. APl nurr~ 3_200 39 50-- 11. Fieldll~.~lddle Ground Sho. 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 5 9 5 ' Conductor 2 012 ' Surface 8 9 2 0 ' Intermediate Production 1884' Liner Perforation depth: measured 10,691' f~t Plugs(measured) ~et 10,357' ~ Junk(measured) 8,850' ~ 8,559' Size Cemen~d 20" 1285 SXS 13-3/8" 1900 SXS 9-5/8" 1700 SXS 7" 420 SXS Measureddepth ~ueverticatdepth 595' 595' 2012' 1978' 8.920' 8635' 8806'-10690' 8528'-10356' true vertical See attached Long string: Tubing (size. grade, and measured depth) short string: Packers and SSSV (type and measured depth) None perforation record 3-1/2" 9.2# N-80 Buttress at 7176' TM 3-1/2" 9.2# N-80 Buttress at 7142' RECEIVED 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 719 5 ' - 8 7 5 5 ' Treatment description including volumes used and final pressure 5 0 3 2 ga 1 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure JAN 2 ? t992 Alaska Oil & Gas Cons. commisSio~ 7.5% HCL wi~C~h0~ xylene 7-5% ~CL. 4920 Dsi Tubing Pressure 15. 17. ~.J~' Gary S. Bush% Signed 8 (~(:~~'~ ' Form 10-404 Rev 06/15/8 Prior to well operation 1 0 0 /'" 1 8 5 0 0 177 -~ 22 718 Subsequent to operation Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations -..x. I hereby certify that the foregoing is true and correct to the best of my knowledge. Regional -~-"3~ ,,~ t~,.Title 16. Status of well classification as: Oil _~ Gas_ Suspended __ Service Drilling Manager Date SUBMIT IN DUPLICATE MGS 17595 ~13 PERFORATION RECORD (3-23-91) ZONE "B , C, D" CONDITION SQUEEZED SQUEEZED SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED MEASURED DEPTH 5750'- 5770' 5795'- 5805' 5865'- 5875' 6215'- 6370' 6535'- 6935' 7195'- 7210' 7240'= 7250' 7265'- 7275' 7280'- 7290' 7525'- 7540' 7555'- 7565' 7715'- 7730' 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 0035'- 10050' 0075'- 10090' 0100'--10110' 0260'- 10275' 0480'- 10495' 0520'- 10535' TRUE VERTICAL , 5518'- 5538' 5563'- 5573' DEPTH'" 5632'- 5642' 5979'- 6034' 6297'- 6693' 6947'- 6962' 6992'- 7002' 7007'- 7017' 7022'- 7032' 7272'- 7287' 7302'- 7312' 7461'- 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377'- 8482' 8696'- 8721' 8746'- 8806' 8935'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 970'8'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 0151'- 10166' 0191'- 10206' RECEIVED ,JAN 2 ? 1,99J~ AlaSka 011 & Gas Cons. CommiSSiOn 'Anchorage DATE BAKER #13 COILED TUBING ACID JOB HISTORY ETD COMMENTS 12/14/91 8823' CIRCULATED THE PUMP TO SURFACE. RIGGED UP SLICKLINE AND PULLED THE STANDING VALVE. PRESSURE TESTED THE SURFACE EQUIPMENT TO 3000 PSI. RIH WITH A 1.5" SWIRL NOZZLE ON 1.25" COILED TUBING TO 7100'. DISPLACED OIL FROM THE TUBING TO PRODUCTION. RIH TO 7500' AND CIRC. WASHED DOWN TO 8000' PUMPED A 5 BBLS XCD SLUG CIRC 45 BBLS OF KCl. CONTINUED TO WASH FROM 8500'-8650', NO INDICATION OF FILL. 12/15/91 8823' RIGGED UP THE PTS SURGE TANK AND RILLED IT WITH 225 BBLS OF 3% KCl. PLUMBED IN TO THE RIG GAS BUSTER. WASHED FROM 8650' -8823', ENCOUNTERED A HARD BRIDGE PLUG AT 8785' AND FELL THROUGH. DISPLACED THE PTS TANK WITH NITROGEN TO 3 PSI. FIXED LEAKING VENT VALVE. HELD SAFETY MEETING. PRESSURE TESTED THE LINES TO 5000 PSI. WASHED/SPOTTED 5032 GALS OF 7.5% HC1/MIXED WITH 20% XYLENE AT 0.75 BPM AND 10 FT/MIN FROM 8764' - 7180' TAKING RETURNS TO PRODUCTION. ALLOWED THE ACID TO SOAK FOR 2 HRS. FILLED THE. COILED TUBING WITH 7.5% HCl AND RIH TO 8764'. WASHED USING 3318 GAL HCl FROM 8764' - 7180' TAKING RETURNS TO PRODUCTION. RIH TO 8764' AND WASHED USING 5032 GALS OF 7.5% HCl FROM 8764' -7180' AT 0.8 BBL/MIN AND A 12 FPM RATE. SHUT IN THE FLOW LINE AND SQUEEZED ACID FROM 7180' AT 0.9 BBL/MIN USING 135 BBLS 3% KCl. RIGGED DOWN THE COILED TUBING UNIT. 12/16/91 8823' RIGGED UP SLICK LINE. RIH AND PULLED THE DUMMY PUMP. RIH WITH THE STANDING VALVE. CIRCULATED THE PUMP TO BOTTOM. RELEASED THE WELL TO PRODUCTION RECEIVED JAN 2 T 1992 Alaska 0il & Gas Cons. (~omm'mS~o" Anchorage STATE OF ALASKA "~: ALA~,~A OIL AND GAS CONSERVATION COMMIS~ON 'APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance 2. Name of _Oper,~t~NuL;Ai'' ) 5. Type of Well: Jnion Oil Company of california Development_,% Exploratory Add ress Stratigraphic __ 3'0 BOX 196247, Anch , AK, 99519 Service 4. Location of well at surface Leg #2, Conductor #6, Baker Platform .983' FNL & 589' FWL, Sec 31, T9N, R12W, SM Attop°fpr°ductiveinterva~op of "E" Zone at 7195' MD (6948' TV! Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension Stimulate Perforate __ Other __ 611~u/n ~°~%~B)MLWfeet 7yJ~t orf~J~l~ n~n~ 9 5 8. Well number Well No. )g. Permit number 13 764' FNL & 1427' FWL, Sec 31, T9N, R12W, SM ~effectivedepth 8850' MD (8559' TVD) 614' FNL & 1165' FWL, Sec 31, T9N, R12W, SM ~aldepth 10691' MD (10357' TVD) 542' FNL & 805' FWL, Sec 31, T9N, R12W, SM 12. Present well condition summary Total depth: measured true vertical 10,691 ' feet Plugs (measured) 10,357' feet Effective depth: measured true vertical Casing Length Structural 595 ' Conductor 2012 ' Surface 8920 ' Intermediate Production 1884' Liner 8,850' 8,559' Size 20" 13-3/8" 9-5/8" Junk (measured) ~et Cemen~d 1285 SXS 1900 SXS 1700 SXS 7" 420 SXS Perforation depth: measured 67-49/91-080 lO. APInumber 50-- 333-20039 11. Field/Pool IMiddle Ground Shoal m~ ~mmm m mm m ~ ~ ~mm ~m~ K I:IVI:U NOV 2 2 1991 Alas~ Oil & Gas Cons. commissiet~ ~ohoraoe Measured depth True vertical depth 595' 595' 2012' 1978' 8920' 8635' 8806'-10690' 8528'-10356' See attached perforation record truevertical Long string: 3-1/2" ~bing (size, grade, and measured ~9~'t string: 3-1/2" None PackersandSSSV(typeandmeasureddepth) 9.2# N-80 Buttress at 7176' TM 9.2# N-80 Buttress at 7142' TM 13. Attachments Description summary of proposal __ Detailed operations program ~L_ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification aS: December 7, 1991 16. If proposal was verbally approved Oil x__ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify-that the foregoing is true and correCt to the best of my knowledge; T~tl SignedGarV~-~ush 'e Reqional Drilling Mana~ ' - ~.~ ~ FOR COMMISSION USEONLY Conditions of appr~al: Notify Commission so representative may witness [ Approval Plug integrity BOP Test Location clearance I Mechanical Integri~Test Subsequent form required 10- ~c 4' ,~p~::~¢-,:;,'~o~.:~ ~ .......... Y ORIGINAL SIGNED BY ti- ~ q - q I LONNIE C. Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MGS 17595 ~13 PERFORATION RECORD (3-23-91) ZONE "A" "B,C,D" fl F" CONDITION SQUEEZED SQUEEZED SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED MEASURED DEPTH 5750'- 5770' 5795'- 5805' 5865'- 5875' 6215'- 6370' 6535'- 6935' 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' 7525'- 7540' 7555'- 7565' 77'15'- 7730' 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'= 9260' 9270'- 9340' 9470'- 9480' 9580'' 9590' 9760'- 9770' 10035'- 10050 10075'- 10090 10100'- 10110 10260'- 10275 10480'- 10495 10520'- 10535 TRUE VERTICAL DEPTH 5518'- 5538' 5563'- 5573' 5632'- 5642' 5979'- 6034' 6297'- 6693' 6947'- 6962' 6992'- 7002' 7007'- 7017' 7022'- 7032' 7272'- 7287' 7302'- 7312' 7461'- 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377'- 8482' 8696'- 8721' 8746'- 8806' 8935'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 9708'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 10151'- 10166' ~ 10191'- 10206' RECEIVED NOV 1991 Ala~ ~OiL & Gas Cons. , PROCEDURE: MOVE SLICK LINE OVER MGS 17595 #13, LEG #2, SLOT #6. RECOVER THE PUMP BY REVERSING THE POWER FLUID° RECOVER THE STANDING VALVE IN THE BHA WITH SLICK PLACE A DUMMY PUMP IN THE BHA TO PROTECT TIlE SEA[. BORESo RIG UP COILED TUBING UNIT AND TEST THE BOPE TO 3000 PSI. RIH WITH 1-1/4" COILED TBG AND SPOT 7.5% INHIBITED HC1 FROM 7].76' - 8770'. ALLOW TO SIT FOR FOUR HOURS. 7. RIH WITH COILED TUBING AND CIRCULATE OUT THE ACID AND PRECIPITATES. 8~ RIH AND SPOT 7~5% INHIBITED HC1, FROM 71.76' - 8770'. 9. PERFORM AN 8000 GAl, ACID SQUEEZE THROUGH THE COILED TUBING~ ALLOW TO SIT FOR FOUR HOURS. 10. RUN THE STANDING VALVE ON SLICK LINE~ 1~.~ CIRCUI. ATE THE PUMP INTO PLACE AND RETURN THE WELL TO P~ODUCTION. RECEIVED NOV ~ 2 1991 ~laska Oil & Gas Cons. C;u~tmiss~on Anchorage 13-3/8' 54.5, @ 2012' 1 TOP OF LINER @ 8806' · / 9-5/8' 40, 43.5, ,/ @ 8920' DRILLABLE BP ~ 9400' PBTD (~ 9900' 7' 38# @ 10690' 1 i A 8 KOBE BI-IA LONG STRING (POWER FLUID) 1) CIW HANGER (BUTT43OWN, EUE 8RD-UP) ~ 32.00' 2~ 3 EA 3-1/2 9.2# BUTT PUPS (3~44, 5.15 & 5.17) 3) 3-1/2= g.2~ N~D TBG, BUTT Wt SP CL CPLGS 4) 3-1/2 g.2~ BUTT PUP ~ [5') 3-1/2' 9.2# BUTT PUP ~ 7035.21' 6) 2 EA 3-1/2' 9.2# BUTT PUPS (Z10 & g.06) 7) 3-1/2 BUTT BOXx 8RD PIN X-OVER ~ 7141.1~' 8) KOBE 3' MODEL 'B' BI-IA ~ 7141.aT SHORT STRING (PRODUCTION) A) ClW HANGER (BUTT-DOWN, EUE IIRD-UP) B) 3 EA 3-1/2 9.2# BUTT PUPS (~.50, 5.20 & 4.a0) C) 3-1/2' 9.2# N-80 TBG, BUTT W/SP CL CPLGS D) 3-1/2' 9.2# N-IlO TBG PUP ~ 71331 E) 3-1/2' OTIS 'X' NIPPLE (4.130 OD x 2.75 ID) ~ 7036.83' F) 3-1/2 BUTT BOX x 2-,~8 EU 8RD PIN X.OVER ~ 7129.gg' G~ 2-af8' 4.6~ N-80 EU 8RD PUP ~ 71 ~1.75' TNL ASSEMBLY 9) 3-1/2' EU 8RD BOXx 3-1/2' BUTT X~3VER ~ 7164.55' 19) 2 EA 3-1/2' 9.2# N-80 BUTT PUP (5.1:X:)' & 5.0g0 11) 3-t/2' BUTT WlREMNE RE-ENTRY GUIDE ~ 7175.23' DRILLABLE BP ' @ 8a50' 'A,B,C & D' ZONE PERFORATIONS 5750'- 5770' SQZD 5795'- 5805' SQZD 5865'- 5875' SQZD 6215'- 6370' SQZD 6535'- 6935' SQZD ~~ 'E' ZON..E, PERF,ORATIONS 7195 - 7210 , ECEiV D 7265'- 7275' 7280'- 7290' N 0V 2 2 1991 -- "F" ZONE PERFORA~T, IQNS... - - 7525'- 7540" - ~las~a-u, & Gas Cons. 7555'- 7565, 7715'- 7730' 'G' ZONE PERFORATIONS 7870'- 8010' 8200'- 8380' x~x 8030'- 8080' 8425'- 8615' 8150'- 8170' 8645'- 8755' · , 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' ADL 17595 WELL NO. 13 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-23-91 TEXAS TO.OLS ;T, 84 TUBING STRIPPER/PA~R · $,O00 psi Working Pressure ~.~.. HsS Service L_.J" 1.00'Series DS322 1.25~.~eries DS323 phone: (7'13) 6206 .~ 9 5-0 1. Operations performed: Operation shutdown __ Pull tubing __ Alter casing __ ' I 2. Name of Operat(~ETNOCAL ) 5. Type of Well: Union Oil Company of California Devel°pment x Exploratory __ ' 3. Address Stratigraphic_ P. O. BOX 190247, Anch. , AK, 99519 Service __ 4. Location of well at surface Leg ~2, concl~iCt°r'' b, uaker Fiatfbrm 1983' FNL & 589' FWL, Sec 31, T9N, R12W, SM At top_ of productive intervalTOp of "E" zone at 7195' MD (6948' T~ 764' FNL & 1427' FWL, Sec 31, T9N, R12W, SM 8850' MD (8559' TVD) ¢~,%ff~cti~l~Pt~ 1165' FWL, Sec 31, T9N, R12W, SM 10691'. MD (10357' TVD) 5~t¢1~ & 805' FWL, Sec 31, T9N, R12W, SM Repair well--x Pull tubing __x Other /'"' STATE OF ALASKA ALA,~,,A OIL AND GAS CONSERVATION COMMIS,.,,,JN REPORT OF SUNDRY WELL OPERATION "" stimulate '~ Plugging Pedorate 6. Datum elevation (DF or KB) 101 ' RKB ABOVE MLWeet 7. Unit or Property name ~: ~ 1,7595 8. Well number Well No. 13 '.D~. Per~i~...u~pj.p.r_(:~ ~um be r 10, APl numl~%j 3_20039 50-- 11. Field/l~ddle Ground She 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural 59 5 ' Conductor 2012 ' Surface 8 9 20 ' Intermediate Production 1884 ' Liner Perforation depth: measured 10,691 ' feet Plugs(measured) 10,357' feet feet Junk (measured) 8,850' feet 8,559' Size Cemented 20" 1285 SXS 13-3/8" 1900 SXS 9-5/8" 1700 SXS 7" 420 SXS Measuredde~h ~ueverticaldepth 595' 595' 2012' 1978' 8920' 8635' 8806'-10690' 8528'-10356' true vertical See attached Long string: ~bing(size, grade, andmeasureddepth)short string: perfOration record 3-1/2" 9.2# N-80 Buttress at 7176' TM 3-1/2" 9.2# N-80 Buttress at 7142' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary None 14. Intervalstreated(measured) See attached history MAY 1 5 t99~, Treatment deScription including volumes used and final pressure Alaska 0il & Gas Cons, C0mtll[s$[0tl ..Representative Daily Average Production or InjeCtion Data OiI-Bbl Gas-Mcf. Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 200 Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 0 0 0 0 N/A 513 N/A N/A 16. statuS of well classification as: Oil ..z. Gas_ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'~ry S~ Bush Signed ~~~. (~~~ Title Service Regional Dri 1 ling Manager Date 5 - 7 - c) 1 ,al 'M SUBMIT IN DUPLICATE MGS 17595 #13 PERFORATION RECORD (3-23-91) ZONE Il A II "B,C,D" "F" "G- 2" "G- 3" CONDITION SQUEEZED SQUEEZED SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED MEASURED DEPTH 5750'- 5770' 5795'- 5805' 5865'- 5875' 6215'- 6370' 6535'- 6935' 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' 7525'- 7540' 7555'- 7565' 7715'- 7730' 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' TRUE VERTICAL DEPTH 5518'- 5538' 5563'- 5573' 5632'- 5642' 5979'- 6034' 6297'- 6693' 6947'- 6962' 6992'- 7002' 7007'- 7017' 7022'- 7032' 7272'- 7287' 7302'- 7312' 7461'- 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377'- 8482' 8696'- 8721' 8746'- 8806' 8935'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 9708'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 10151'- 10166' 10191'- 10206' uAY 1 5 t991 Alaska 011 & Gas Cons. CommissiOn Anchorage · ~-" STATE OF'ALASKA ' ~ AL~,,.,,O~ OIL AND GAS CONSERVATION COMMI,.....,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Suspend m - Alter casing ~ Repair well ~ Change approved program w 2. Name of Operator I 5. Type of Well: Union Oil Company of California (Unocal)! Development._.~ · . Exploratory 3. Address Stratigraphic P.O. Box 190247, Anchorage, AK 99519-0247 Service__ 4. Location of well at surface Leg #2, Conductor #6, Baker Platform 1983' FNL & 589' FWL, Section 31, T9N, R12W, S.M. At top of productive interval Top "E" Zone at 7195' MD (6948' TVD) 764' FNL & 1427' FWL, Section 31, T9N, R12W, S.M. At effective depth 9400' MI) (9091' TVD) 560' FNL & 1016' FWL, Section 31, T9N, R12W, S.M. Attotaldepth 10,691' MD (10,357' TVD) 542' FNL & 805' FWL, Section 31~ T9N~ R12W~ S.M. 12. Present well condition summary Total depth: measured 10,691 ' feet Plugs (measured) true vertical 10,357 ' feet Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension m Stimulate __ Pull tubing -.,w.- Variance __ Perforate __ Other __ 6. Datum elevation (DF or KB) 101' RKB above MLW 7. Unit or Property name MGS State ADL 17595 Effective depth: measured 9400 ' feet Junk (measured) true vertical 9091 ' feet Casing Length Size Cemented Structural 'Conductor 595 ' 20" 1285 sxs Sudace 2012' 13-3/8" 1900 sxs Intermediate Production 8920' 9-5/8" 1700 sxs Liner 8806'- 10,690' 7" 420 sxs Perforation depth: measured feet 8. Well number Well No. 13 9. Permit number 67-49 10. APl number 50-- 133-20039 11. Field/Pool Middle Ground Shoal true vertical RECEIVLD &!~ ~OjJ ,& Gas Cons. Measured depth ~en~ca~ oepm 595' 595' 2012' 1978' 8920' 8635' 8806'- 10,690' 8528'- 10,356' SEE ATTACHED PERFORATION RECORD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Long String: 3-1/2" 9.2# N-80 Short String: 3-1/2" 9.2# N-80 None Buttress at 9291' Buttress at 7640' 13. Attachments Description summary of proposal -x.- Detailed operations program BOP sketch 14. Estimated date for commencing operation March 11, 1991 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the for~j~l~,oing is true and correct to the best of my knowledge. .,,---) ( ~ ~ ' FOR COMMISSION USE ONLY Conditions of approval: Notify C~mission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL StGNEO B~ LONNIE C. SMITH Approved by order of th~ Commissioner Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil ~ Gas Suspended __ Date %- II-Ct ~ IApproval No. ¢/.... P~ ~ Commissioner Date "~ -tq-¢l ~ SUBMIT IN TRIPLICATE MGS 17595 #13 PERFORATION RECORD (3-].o-91) ZONE CONDITION MEASURED DEPTH "A" SQUEEZED 5750'- 5770' SQUEEZED 5795'- 5805' "B,C,D" SQUEEZED SQUEEZED SQUEEZED OPEN OPEN OPEN OPEN "E" OPEN OPEN OPEN "F" OPEN "G-I" OPEN "G-2" OPEN OPEN "G-3" OPEN "G-4" OPEN OPEN OPEN OPEN OPEN ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED ISOLATED "G-5" 5865'- 5875' 6215'- 6370' 6535'- 6935' 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' 7525'- 7540' 7555'- 7565' 7715'- 7730' 7870'- 8010' 8030'- 8080' 8150'- 8170' 8200'- 8380' 8425'- 8615' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' TRUE VERTICAL DEPTH 5518'- 5538' 5563'- 5573' 5632'- 5642' 5979'- 6034' 6297'- 6693' 6947'- 6962' 6992'- 7002' 7007'- 7017' 7022'- 7032' 7272'- 7287' 7302'- 7312' 7461'- 7476' 7615'- 7754' 7774'- 7824' 7894'- 7914' 7943'- 8119' 8164'- 8347' 8377'- 8482' 8696'- 8721' 8746'- 8806' 8935'- 8960' 8970'- 9035' 9157'- 9167' 9263'- 9273' 9440'- 9450' 9708'- 9723' 9748'- 9763' 9772'- 9782' 9931'- 9946' 10151'- 10166' 10191'- 10206' MGS 17595 #13 BHA REPLACEMENT (3-10-91) 1. MOVE RIG OVER MGS 17595 #13, LEG #2, SLOT #6. 2. KILL WELL WITH 3% KCL/FIW COMPLETION FLUID. 3. INSTALL BPV'S, NIPPLE DOWN TREE, NIPPLE UP 5M BOPE. 4. TEST BOPE AND CHOKE MANIFOLD TO 3000 PSI. 5. PULL AND STAND BACK DUAL KOBE PROD STRING (REPLACING DAMAGED TUBING). 6. CLEAN OUT FILL TO 9400' ETD (CEMENT RETAINER). 7. REPLACE KOBE BHA AND TAIL ASSEMBLY. 8. RUN DUAL KOBE PRODUCTION STRING WITH PUMP CAVITY AT 7180'. 9. REMOVE BOPE AND INSTALL TREE. 10. RETURN WELL TO PRODUCTION AND MOVE OFF. NOTE: SBHP ANTICIPATED TO BE 3600 PSI AT 9091' TVD WORKOVER FLUID WILL BE 3% KCL/FIW WITH NACL AS REQUIRED FOR WELL CONTROL 5" KILL LINE WITH TWO 3" 5M VALVES I d; KILL LINE FROM MUD PMP & CEMENT UNIT BELL NIPPLE 13-5/8"ANNULAR3000 PSI ! I I PIPE RAMS BLIND RAMS i Iii FLOWLINE 15-5/8" 3M FLANGE ADAPTER 5M x 5M 1,.3-5/8" 5M FLANGE I DOUBLE GATE 5M 1,.3-5/8" 5M FLANGE 4." CHOKE LINE WITH ONE REMOTE & 1 MANUAL 4." 5M VALVE CONNECTED TO CHOKE MANIFOLD (SEE MANIFOLD DRAWING) PIPE RAMS ! 1;3-5/8" 5M FLANGE SINGLE GATE 5M 1;3-5/8" 5M FLANGE RISER I I I 10" 5M x 15-5/8" 5M ADAPTER CAMERON 5M SPOOL 1,.3--5/8" DOPE 5M STACK BAK ER PLATFORM (TESTED @ ;3000 PSI) UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC APP'D: GSB SCALE: NONE DATE: 13-3/8" 54.5, O 2012' 8920' DRILLABLE BP ~ 9400' PBTD ~ 9900'/ 7" 38# ~ 10690' 1 A .mmmm m mm , TUBING DETAIL LONO STRING (POWER FLUID) 1) ClW HANGrR (BUTT-DOWN, rUE aRD-UP) · 32.00' ) 3-~/2 BUTT PIN(UP) x BUTT PIN(DOWN) PUP I~ 2=) a--1/2" 9.2# N-GO 'raG, BUTT w/se ct. C~LGS 4) 3-1/2 BUTT BOX x 3-1/2 rU BRO PIN X-OVER $) KOBE 3" MODEL "B" BHA O 71a0' SHORT STRING (PRODUCTION) A) ClW HANOER (BUTT-DOWN, EUE &RD-UP) · 32.00' e) 3-1/2 BUTT PIN(UP) x BUTT PIN(DOWN) PUP C) 3-1/2" 9.2# N-aO TaG, BUTT W/~ ~ C~GS t 3-1/2 BUTT BOX x 2-3/8 rU &RD PIN X-OVER 2-3/8" 4.6# N-BO EU &RD PUP (10') TAIL ASSEMBLY 6) 3-1/2" EU 8RD BOX x ;3-1/2" BUTT X-OVrR ?) 3-1/2" 9.2# N-a0 BUTT PUP (10') 8) ;3-1/2" BUTt WIRELINr Rr-ENI'RY GUIDr "A,B,C & D" ZOnE PERFORATIONS 5750'- 5770 SQZD 5795'- 5805' SQZD 5865'- 5875' SQZD 6215'- 6370' SQZD 6535'- 6935' SQZD IIGII "E" ZONE PERFORATIONS 7195'- 7210' 7240'- 7250' 7265'- 7275' 7280'- 7290' ZONE PERFORATIONS 7525'- 7540' 7555'- 7565' 7715'- 7730' ZONE PERFORATIONS 7870'- 8010' 8200'- 8380' 8030'- 8080' 8425'- 8615' 8150'- 8170' 8645'- 8755' 8985'- 9010' 9035'- 9100' 9235'- 9260' 9270'- 9340' 9470'- 9480' 9580'- 9590' 9760'- 9770' 10035'- 10050' 10075'- 10090' 10100'- 10110' 10260'- 10275' 10480'- 10495' 10520'- 10535' ADL 17595 WELL NO, 13 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-10-91 ~ _e~ni~t Dato~ Spud Date: Surf~oo Lo~oUom Subeuffao4 LOGatJon: Bovotlom HX).' Cootng.' Perforatlonl: inlUol PotenUol: InlUol SUmulaUon: Cored Interv. le: DST Intervals and R~ultm ~g Invantm'y: MIDDLE OROUND SHOAL ADL 17595 WELL NO. 13 KENAI & LOWER KENAI CONGLOMERATE PLATFORM BAKER I/I 1/67 ~ot e, Leg 2 188~. ~ sar PM. s,~ al. TON. n12w. s.u. TD - 84~ mL. 8o8. F~. ~ 31. To.. nt2w. s.u. 78.75 KB MSt. 10891' 6000' 20% 85f Codfl_g Nt at 805' wi~ 1285 mc oemont 13 3/B", 54~,f Codn. g ~t at 2012' with 1800 ex o~mant 8 ~/8",_ 40 (md 43.~f Caning Nt at 8820' with 1700 mc a~mont 7". 38Ji Uner Ht at 8808-10800' with 420 mc ~mant A: S780-577Q'0 Ir: 7825-7540' 05: 8085-0010' 8788-5805'e 7555-7505' 0035-0100' BCD: 5885-8878', 7715-7730' 0235-0280' 8215-8370'e 01~ 7870-8010' 8270-0340' 8535-0835', 02: 8030-8080' 8470-048'i~ E: 7105-7210' O3: 8100-8170' 9580-9500* 7240-7250' 8200-8380' 876O-9770' 7285-7275' 04: 8428-881~' 1OO38-1OO8O' 7280-7200' OS: 8848-8788' 10070--10080' · Cement Squeezed A zontt 842 BOPD. 428 BWPO. OOR 841, 120 TPF EFO zano: 1485 BOP1). 8 BWPD. OOR 402. 100 1PIr Completion Reoord _ Long SMflg: 1. Cameron 10" Dual OPAl Hanger 2. 3 1/2" ButtF~o tubing 3. 3 1/2' Buttr~l end 3 1/2" 8RD XO 4. 3 1/2" 8RD pup Jt 8. Kol~ ,¥' ~ 'B' Ca~lty o/h L-222 8. :3 1/2" 81~) ond :3 1/2" Duttlsee XO 7. 3 I/2" Buttre.e tubing tollptp4 8. Muleoho~ Short String: A. Sub nipple 2.78 IDCflooded to opaoe out) 0. 3 1/2' Buttrane tubing C. 3 1/2" Buttress ofld 2 3/B" 8RD X0 D. 2 3/8" BRD pup Jt 10100-10110' (~d nm 10/23/85) 10280-10275' 10480-10405' 10520-10535' BCD zoneo - 0240-0285', 6447-8465* EFO zofloo -- 7710-7738' 8004-0570': TO 38 bm, Roe 112 BF; 110 BO. 2 bbb mud. IHP 4300. liP 1280, FHP 4360, ~ 2520, no FSIP. 0080-10638*t TO 54 hrs, no FTS. DW. 106 BOCId, IHP 4847, IFP 97, F'HP 4847, ~ 1350. F~IP 3840. 6180-8895': TO 22 Jul, OTS 2 hm, flo fluid, 0P ~ of SW. JHP 2003. liP 24. FHP 3203. FFP 2704, FSIP 2485. e~t0-4OeOt TO 28.5 hrs. no OuJd to outface. 8 bblo mud, 30 bide water, IHP 3203. FP 24. ~ 3203. FFP 2407, FSL° 2405. 8105-0208': TO 24 hrs, no fluid to ourfoeo, Roo 77 BF, 8 rede mud, 80 bblo water & mud, 14P 3033, flq~ 72, Iq4P 3033, ~ 2084, ~ 2118. 0745*-e010*t TO 40 hrs, 013, 8 hr peod 403 Bit, 00ti BS&W, JHP 2703, I~ 018. FHP 2769. FFP 1882. F'SaP 2470, Prod ;G~ 72.7 BIPH, 220 IqP, 853 Id(:~, 474 Oor, 408I BS&W ..cpth 7630' 7631' d 7030* 7602' 7883' 0200' 0201' 33' 7820' 7630' 7840' P~D gO(X)' 30 10601' //////. 13 3/B~ /~dl CS~ 20 5750* 8033" 7188' 7200' 7825' 7885' 7718' 8755' Te9 at W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 November 6, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 . -File: TJZ-380-WF Dear Sir: Subsequent Notice MGS 17595 Well No. 13 Platform Baker, Cook Inlet, Alaska Attached in duplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for repairs made to Well No. 13. Very truly yours, . ~. ~. Smith Di strict Manager Attachments JCB/dds RECEIVED k ov 219 A~aska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA "'% ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P..O; Rn× 10077c~ Anchnrag~ Alaska 99510 4. Location of Well Leg 2, Slot 6, MGS, Platform Baker 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 7. Permit No. ~7-40 8. APl Number 50- 733-20039 9. Unit or Lease Name MGS 17595 10. Well Number 11. Field and Po I Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Hemlock :" I ./ I\L.~ ,--~lJ L ~.1 12. Check Appropriate Box lo/nchcate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [~ Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] [] 13. Describe Proposed or Completed OperatiOns (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Between September 22, 1985, and October 23, 1985, Amoco Production Company: le 2. 3. 4. Se e 7. 8. 9. Circulated and killed well. Nippled up BOP's and pressure tested. Pulled dual tubing string and bottomhole assembly. Pressure tested previously abandoned perforation intervals between 5,750 - 6,935 feet. Intervals 6,215 - 6,270 feet, 6,825 - 6,845 feet and 6,920 - 6,935 feet would not pressure test. Cement squeezed the above listed perforation intervals. Placed approximatley 50 sx Class "G" cement behind pipe. Drilled out cement. Pressure tested squeeze to 2,500 psi. Held. Drilled.out to 9,900 feet and ran Gamma Ray Log. Set bridge plug at 9,400 feet. Perforated the following intervals at 4 JSPF, 0.4" diameter: ECEIVED 8,510 - 8,615 feet 105 feet 8,645 - 8,755 feet I'10 feet l~!.©V 1 2~ 8,985 - 9,010 feet 25 feet 9,035 - 9,100 feet 65 feet ~,s~ oil & Gas Cons. ¢om~ 9,235 ' 9,260 feet 25 feet Anchorage 9,270 - 9,340 feet 70 feet 400. feet Total 14. I here~V th,~~~~the~,~y~~~~?~ best of my. Dikn°Wstriledge'ct Signed ~ /-,/ .? ~ ,~ ~' / ~ Title Manager The space below for Commission use (continued on Page 2) 11~/a~e6 / 8 5 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date __ iss%on Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SU [ RY T CF-S AND REPORTS OH WE .LS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of.Operator .... /~moco vroouctl.on Company 3. AddresSp. O. BOX 100779, Anchorage, Alaska 99510 4. Location of Well Leg 2, Slot 6, Middle Ground Shoal Platform Baker 1,989' FNL, 588' FWL, Sec. 31, Tg'N, R12W 5. Elevation in feet (indicate KB, DF, etc..) 79' KB J 6 . Lease Designation and Serial No. ADL 17595 " 7. Permit No. 67-49 8. APl Number 50- 733-20039 9. Unit or Lease Name MGS 17595 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock .- 12. Check Appropriate Box To Indicate Nature of Notice, Report, or )ther Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing 0 Perforations ~-1 Altering Casing f-I Stimu late [-] Abandon [] Stimulation [] Abandonment Repair Well Fl Change Plans F1 Repairs Made ]~ / Other [] Pull Tubing 1-'] Other [~ Pulling Tubing (Note: Report multiple completions on Form 10,407 with a submitted Form 10,407 for each completion.) 13. Describe Proposed or Completed Operations {Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Continued from Page I 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. Ran tubing and new bottomhole assembly. Nippled up tree and pressure tested. Placed well on production on October 11, 1985. Well sanded up. Bail sand out of tubing from October 14, 1985 - October 18, 1985. Rigged up coi 1 ed tubing and washed sand. Circulated and killed well. Nippled up BOP's and pressure tested. Pulled tubing. Ran casing swage to 8,814 feet. Washed fill from 9,310 - 9,400 feet. Reran tubing and bottomhole assembly-. Nippled up tree and pressure tested. Returned welt to production. RECEIVED Alaska Oit & Gas Cons. Commissior~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Di strict Manager Signed Title The space below for Commission use 0a,11/06/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Re~,. 7-1-80 Submtt "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager October 21, 1985 Mr. C. V. Chatterton, chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: ijZ-365-WF Dear Sir: Notice of Intent MGS 17595 Well No. 13 ~er, Cook I~let, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, in order to make repairS on Well No. 13. Very truly yours, / W. G. Smith District Manager AttachmentS JCB/'dds RECEIVED OCT 2 Alaska 0il & Gas Cons. C0mmissio~l Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] . OTHER [] 2. Name of Operator Amoco Production £nmpany 3. Address _ P.O. Box 100779~ Anchorage~ 41aska 99510 4. Location of Well Leg 2, S10t 6, MGS, Platform Baker 1989' FNL, 588' FWL, Sec. 31, TgN, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 67-49 8. APl Number 50- 733-20039 9. Unit or Lease Name MP-q 1 10. Well Number 11. Field and Poo[I3 Middle Ground Shoal Hemlock 9 I VD ~1'~1 I -/C:nC: IJ I,J~ Check Appropriate Box ~o~[n~cate l~lature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Referencing teleCon between Mike Minder and Jeff Blagg on 10/18/85 at 9:30 a.m., between October 17-20, Amoco performed the following work: I. Bailed sand out of tubing with bailer. 2. Washed sand out of tubing with coiled tubing unit. 3. Circulated and killed well. 4. Nippled up BOP's and pressure tested. 5. Pulled short string and long string. 6. Ran casing swage to 8,814 feet. Amoco proposes to continue operations beginning October 21 as follows: 7. Wash sand from 9,290 - 9,410 feet. 8. Rerun dual tubing and bottomhole assembly. 9. Nipple up tree and test. 10. Return well to production. RECEIVED. OCT 2 Z Alaska OiJ & Gas Cons. Commission Anchorage 14. I hereby cer~fy that the~oing i~e and correct tq the best of my knowledge. Signed Title District Manager The space below for Commission use Date 10/21/85 Conditions of Approval, if any: IItGINAL SI'GilED Approvedb¥, ' BY H'ItRY W. [UGLEII COMMISSIONER By Order of the CommiSsion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 90?-272-B471 May 20, 1985 File: TJZ-182-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent FIGS 17595 Well No. 13 Platform Baker, Cook Inlet, Alaska Attached in triplicate is State of Alaska Form lO-403,'Sundry Notices and Reports on Wells, regarding our proposed work on MGS 17595 Well No. 13. We pl.an to deepen the PBTD and Perforate additional pay in this well, along with replacing the bottomhole assembly. Yours very truly, District Manager Attachments JCB/d'ds RECEIVED MAY 2 2 191 5 AlasKa 0it & Gas Cons, Commission Anchorage STATE OF ALASKA r---,, ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Amoco Pr0ducti0n Company 67-49 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 5o- 733-20039 4. Location of Well Leg 2, Slot 6, Middle Ground Shoal Platform Baker 1,989' FNL, 588' FWL, Sec. 31, TgN, R12W Elevation in feet (indicate KB, DF, etc.) 78.75' KB 6. Lease Designation and Serial No. ADL 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock 12. (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In June, 1985, Amoco Production Company proposes to: 1. Circulate and kill well. 2. Nipple up BOP's and pressure test. 3. Pull tubing and bottomhole assembly. 4. Pressure test previously abandon perforation intervals between 5,750'-6,935'. 5. Deepen PBTD to 9,900 feet. 6. Run a gamma ray and cement bond log between 7,100'-9,900'. 7. Set bridge plug at 9,410 feet. 8. Perforate the following Hemlock intervals with 4 JSPF: 8,510'-8,615', 8,645'-8,7.55', 8,985'-9,010', 9,035'-9,100', 9,235'-9,260, 9,270'-9,340. Run tubing and new bottomhole assembly. Nipple up tree and pressure test. R r[:' ~ ~ I V ~D Return well to production. ge 10. 11. MAY 2 2 ]985 Alaska 0it & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing~js true and correct to the best of my knowledge. Signed ~~/ Title District Manager The space below for Commission use Dat~)5/20/85 Conditions of-Approval, if any: Approved by. COMMISSIONER By Order of the Commission Submit Intentmons ~nTr~phcate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 June 27, 1985 File: TJZ-243-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent MGS 17595 Well No. 13 Platform Baker, ..C. ook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to repair MGS 17595 Well No. 13. We propose to deepen the PBTD from 8,660 feet to 9,410 feet and perforate additional pay in this well. Please address any questions on this repair to Jeff Blagg at 263-2211. Very truly yours, W. R. Halvorson Acting District Manager Attachments JCB/dds RECEIVED JUL 0 1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLJ~[ 2. Name of Operator 7. Permit No. Amoco Production Compan.v 67-49 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 50- 733-20039 OTHER [] 4. Location of Well Leg 2, Slot 6, Middle Ground Shoal Platform Baker 1,989' FNL, 588' FWL, Sec. 31, T9N, R12W 5. Elevation in feet (indicate KB, DF, etc.) 78.75' KB I 6 . Lease Designation and Serial No. ADL 17595 12. 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~' Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ,~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1 1. 2. 3. 4. e 10. 11. n July, 1985, Amoco Production Company proposes to: Circulate and kill well. Nipple up BOP's and pressure test. Pull tubing and bottomhole assembly. Pressure test previously abandon perforation intervals between 5,750 -6,935 feet. 5. Deepen PBTD to 9,900 feet. 6. Run a gamma ray and cement bond log between 7,100 -9,900 feet. 7. Set bridge plug at 9,410 feet. 8. Perforate the following Hemlock intervals wi th 4 JSPF: 8,510 -8,615 feet, 8,645 -8,755 feet, 8,985 -9,010 feet, 9,035 -9,100 feet, 9,235 - 9,260 feet, 9,270 - 9,340 feet. Run tubing and new bottomhole assembly. Nipple up tree and pressure test. Return well to production. REC£JVED AlasKa Oil & Gas Cons. Com~ 14. I hereby ce[tif,,v,~hat t~efor_egoing ~s true and correct to the best of my knowledge. S~gned ~IJIQ~I l~t~q[,,/'O-'-~Az~/~ r~t~eActing District Manager The space below for Commission use Date06/27/85 Conditions of Approval, if any: ORit~!NALSIGNED ~v By Order of Approved by: vi II~,RRY W, Klli~L£~. COMMISSIONER the Commission ~pproved Copy Returned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent January 15, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-O62-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Report MGS 17595 Well No. 13 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for our work on MGS 17595 Well No. 13, Platform Baker, Cook Inlet, Alaska. Commencing January 1, 1982, we killed the well, pulled the tubing, set a packer between the abandoned 'BCD' zone perforations and the currently producing 'G' zones, and ran a new bottomhole assembly with a dual tubing string. The packer annulus was displaced with inhibited fluid. Yours very truly, L. A. Darsow Di strict Superintendent Attachment BFS/klt RECEIVED JAN 1 ]982 Abska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA ~ ,L AND GAS CONSERVATION CC,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING'WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Amoco ProductiOn Compan~v 67-49 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 733 200 3900 4. Location of Well Slot 6, Leg 2, Middle Ground Shoal Pla'tform Baker 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75' RKB 6. Lease Designation and Serial No. MGS 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). - January 7, 1982' January 1 1. 2. e Killed well and pulled tubing. Set packer at 7150' MD (between the abandoned 'BCD' zones and productive 'G' zones). Ran new bottomhole assembly with dual string completion. Displaced annulus with inhibited fluid. RECEIVED jAN ,,t ~ohor~Oe 14. I hereby certify that ~g is true and correct to the best of my knowledge. Signed ~/~/'~)~/"~~ Title District Superintendent The space below for Commission use Date 1/15/82 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 December 22, 1981 File' LAD-1357-WF Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Notice of Intent MGS 17595 Well No. 13 Platform Baker, Cook Inlet, Alaska Attached in triplicate for your approval is State of Alaska Form 10-403, Sundry Notice and Reports on Wells, regarding our proposed work on MGS 17595 Well No. 13. We plan to set a packer to segregate the "G" zones from the abandoned "BCD" zones and replace the bottomhole assembly. This well has a severe scale problem and we believe it is due to a small leak in the "BCD" zones. Very truly yours, L. A. Darsow .. Di stri ct Superintendent Attachment BFS:cm O~C£ ~ 1981 /ilaska Oil & 8as Cons. /inchorago " STATE OFALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL F~X 2. Name of Operator 7. Permit No. Amoco Production Company 67-49 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 5o-133_20039 OTHER [] 4. Location of Well Leg 2, Slot 6, Middle Ground Shoal Platform "B" 1989' FNL, 588' FWL, Sec. 31, TgN, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75 RKB I 6 . Lease Designation and Serial No. ADL 17595 9. Unit or Lease Name HGS 17595 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~]X Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details an~l give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). I . 2. 3. 4. Estimate date of starting: Kill well Pull tubing Set packer at 7150' Run tubing and new bottomhole assembly January 3, 1982 Subsequent Work ~Reported o. Form RECEIVED DEC2 ~ Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify tJZa/t~ng is true and correct to the best of my knowledge. Signed .~.~.. ~/~"~/'/,,/~,V"~ Title District Superintendent The space below for Commission use Date 12/22/81 Conditions of Approval, if any: Approved by BY LO!~IE C. SglTIt Approved op¥ Returned By Order of COMMISSIONER the Commission Date /~_~__~/~ ....... Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent August lC, 1981 File' LAD-910-WF Mr. Hoyle.H. Hamilton, Commissioner Alaska Oil and Gas ConservatiOn Commission 3001 Porcupine DriVe Anchorage, Alaska 99501 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 Dear Sir' SUbsequent Report of Work MGS 17595 Well No. 13 Platform Baker, Cook Inlet, Alaska Attached in duplicate is State of AlaskaForm 10-403, Sundry Notices and Reports on Wells, regarding repair of casi.ng leaks and a tubing stri.ng leak in MGS 17595 Well No. 13.' This work was completed August 4, 1981, and the well is currently producing. Yours very truly, L. A. Darsow District Superintendent Attachment BFS/klt ££C£1V£D Oil & Gas Cons. AnChorage O°rnraiSSioa STATE OF ALASKA '~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX-I OTHER E] ~ 2. Name of Operator 7. Permit No. Amoco Production Compan~v 67-49 · 3. Address 8. APl Number P. 0.. Box 779, Anchorage, Alaska 99510 50-133-20039 ~4. Location of Well Leg 2, Slot 6, Middle Ground Shoal Platform Baker 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75' RKB 6. Lease Desianation and Serial No. ADL 17595 9. Unit or Lease Name Middle Ground Shoal 10. Well Number 13 11. Field and Pool Mi ddle Ground Shoal, Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a su, bmitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment Other [] o [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Work initiated July 20, 1981 and completed August 4, 1. Killed well, pulled tUbing, and retrieved packer. 2. Tested 'BCD' zone perforations. Leaks found at 5750-5190', 6825-6935'. 3. Cement squeezed and tested leaking zones. 4. Ran tubing and bottomhole assembly for hydraulic pump (no packer). 5. Returned well to production. 1981. RECEIVED AUG 1 2 1981 Alaska 0il & Gas Cons. C0mrnis$i0n 14. I hereby certify that th~true and correct to the best of my knowledge. Signed ~. ~~~----~/~ TitleDistrict Superintendent The space below for Commission use DateAUgust lO, 1981 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 July 16, 1981 Fi le' LAD-812-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupi ne Drive Anchorage, Alaska 99501 Dear Mr. Hamilton' Notice of Intent MGS 17595 Well No. 13 Platform 'Baker, Cook Inlet, Alaska Attached for your approval is State of Alaska, Form No. 10-403 in triplicate. This is a Notice of Intent to repair a casing leak and a tubing leak in MGS 17595 Well No. 13. Verbal approval was obtained on JulY 16, 1981, for work to proceed starti.ng July 20, 1981. Very truly yours, L. A. Darsow Di strict Superintendent Attachment BFS'lp JUL 20 1981 Alaska 0tl & Gas Cons. C°rnn~lS$lor~ Anchorage ,---, STATE OF ALASKA ALASKA ,..,L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Compan~v 67-49 3. Address 8. APl Number P.O. Box 779, Anchorage, Alaska 99502 50_133-20039 4. Location of Well 9, Unit or Lease Name MGS 17595 Leg 2, Slot 6, Middle Ground 'Shoal Platform "B" 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 78.75 RKB 12. I 6 . Lease Designation and Serial No. ADL 17595 10. Well Number 13 11. Field and Pool Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment I") Repair Well [~ Change Plans [] Repairs Made . [] Other I'-} · Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including.estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). le 2. 3. 4. 5, Kill well, pull tubing and mill out packer at 7050'. Test casing above 7050' for leak(s). Cement squeeze leak(s). Run tubing and bottomhole assembly for hydraulic pump; tailpipe to be at 7850'; no packer. Return well to production. Su~e, quent ¥¢ork Ilepor~ecl on Form No. _/~'-q°~:~ Dated RECEIVED JUL 2 0 1981 Alaska Oil & Gas ~ons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , _ . Title Distri ct Supc. rint~ndent The space below for Commission use - Date 7/16/81 Conditions of Approval, if any: Ver_bal apprpval 7/16/81 per telephone conversation with B. F. Smith, Amoco. By Order of ¢~/ ~ Approved by OY L~]~E C.~1~ COMMISSIONER the Commission ate Form 10403 '. ~ , . S~m~t "Intentions" in Triplicate Rev. 7-1~0 and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent July 10, 1979 File: LAD-579-WF Mr. Hoyle H. Hamilton, ~ssioner Alaska Oil and Gas Conservation ~ssion 3001 Porcupine Drive Anchorage, Alaska 99501~ Dear Mr. Hamilton: Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 MGS 17595 Well' No. 13 Platform Baker, Cook 'Inlet, 'Alaska Attached in duplicate is State of Alaska Form No. 10-403. This is a Subsequent Report of reperforat~, g the referenced well in the "G" zone of the' H~mlock formation. Yours very truly, T,.A. Darsc~ District Superintendent Attachment DRR: sls 'ECEIV[!D JUL 1979 Alaska Oil & O.~rS I.:;n~. ~,ommlsslon An~horal, te Fo rm 10-403 /""~ Sul)mi t "I ntentions" in Triplicate REU'. 1-10~73 & '*Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do nOt use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) · O,L I'1 GAS I--I WELLLmY~I WELL g--I OTHER NAME OF OPERATOR Am~co Production ampany ADDRESS OF OPERATOR P. 0. Bo× 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 2, Slot 6, Middle Ground Shoal, Platform Baker 1989' k'SXlL, 588' F~, SOC.. 31, 2'~N, Pd.2W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 78.75' above MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON'* CHANGE PLANS 5. APl NUMERICAL CODE 50-133-20039 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ~oS State 17595 9. WELL NO. .13 10. FIELD AND POOL, OR WILDCAT . Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec.. 31, T9N, R12W, S.M. 12. PERMIT NO. )ort, or Other Data 'SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The following.work -w-as. ccaPleted, on MGS..Well.No- 13 :' 1. .Reperforate.Hem%lock C0nglctuerate ("G" .zone) thr0ugh:tub',~ng with 2 JSPF .at .the' follow~, g depths. 8425,8510' ( 85' ) 8200'838'0' ' (i80') 8040'70' ( 30" ) '7880'8000.'. · · (120') . 2. Ran .Pump'.~ng equipment and produced.well-" 16. I hereby certify tha~~ is true and correct SIGNED .~, U(, ~/~/'-y~{~l,/ TITLE Distriq~ :.Superintendent DATE .,July 10,. 1979 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side L. A. Darsow District Superintendent January 5, 1979 File: LAD-O22-WF Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Amoco Production Company --~~~ ~ Post Office Box 779 I 3 E,~'~~ Anchorage, Alaska 99510 '--~-~ 907 - 272-8471 Notice of Intent MGS 17595 Well No. 13 Platform Baker~ Cook Inlet~ Alaska Attached for your approval is State of Alaska Form 10-403 in triplicate. This is a Notice of Intent to'reperforate the Hemlock formation in the referenced well with through-tubing guns at 2 shots per foot. Yours very truly, L. A. Darsow District Superintendent Attachment DRE:sls For~ 10-403 RE~. 1~t 0-73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~:LLLr'~ GAS D OTHERWELL 2. NAME OF OPERATOR Amneo Prad.atinn Compnny 3. ADDRESS OF OPERATOR P. O. ~ox 779~ ~ehorage, ~as~ 995~ 4. ~OCATION OF WELL ~t surface LaS 2, Slo~ 6, ~dd~e ~Io~d. Shoal~ 1989~ ~, 588~ ~, Sec. 31, TgN, ~2W, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) ~ 78.75 v above ~fSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 15. APl NUMERICAL CODE 50-133-20039 6. LEASE DESIGNATION AND SERIAL NO. ADL 17595 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME MGS State 17595 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT lttddle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TgN, Itl2W, S.M. 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly State all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The following ts our proposed procedure to reperforate HGS Well No. 13c 1. Pull standing valve. 2. Displace well with dteeel. ¸0 K:LS up Sch/~erger and reperforaCe "G" zone vlth 2 JSPF vtth 2-1/8" semi-expendable throush Cubinl~ guns, aC the followtn~ depths: 8425-8510' (85') 8040-70' (30') 8200-8380' (180') 7880-8000' (3.20') 0 production equipment and produce well. 16. I hereby certify that the foregoing is true and correct Orlglnal Signed by SIGNED L.A. DARgO (This space for State~_ .se.,..... ~ APPROVED BY CONDITIONS O~P~OVAL, IF A TITLE District Suoarintendan~ DATE January 5s 1979 -- TITLE See Instructions On Reverse Side DATE Approved Return~.>~ Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Amoco Production Company P. O. Box 779 Anchorage, Alaska December 8, 1971 99510 File: JCS-689-WF Re: Sundry Notice MGS 17595 Well No. 13 Dear Sir: Attached are the necessary copies of the State of Alaska form P-3, Sundry Notice and Reports on Wells, for the Subsequent Report of Repairing Well on MGS 17595 Well No. 13. Yours very truly, J. C. Schillereff Supervisor in Charge Attachment Cl. Form P--3 REV. 9-3049 STATE OF ALASKA Submit "Intentions" in Triplicate & "S~bsequent Reports" in Duplicate 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].ICATION 'FOR [~EI-I~ViiT-~'' '/or such 'p[o~osal~.) . . 5. AP1 NUiVLF, KICA~ CODE 50-133-20039 6. LEASE DESIGNATION A_ND SERIA~ NO. ADL-17595 1. 7. IF INDIA_N, AI.~O'i"rl~l OR TRIBE NAME OIL ~] OAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FAIR2VI OR LF~SE NAME Amoco Production Company MGS State 17595 3. ADDRESS OF OPERATOR 9. ~fliILL NO, P. O. Box 779, Anchorage, Alaska 99510 13 4.LOCATION OF WELL At sur£ace Leg 2, Slot 6, Middle Ground Shoal Platform "B"; 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 78,75' above MSL Check Appropriate Box To I,ndicate Niat'ure of NOtice, Re 14, 10. FIELD A2%ID POOL, OR WILDCAT Middle Ground Shoal 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31~ T9N, R12W, S.M. 12. PERNI/T NO. 67-49 ~ort, or Other Da~a ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE [ J ABANDONs t Other) FRACTURE TREATMENT --~ ALTERING CASING SHOOTING OR ACIDIZINO , ABANDONMENT* (Other) (NOTE: Report results of multiple completiou on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Subsequent Report-of Repairing Well Rigged up on well on 10-17-71. Removed existing completion equipment and cleaned out fill from 8610 to 8656. Ran casing scraper to 6000'. Set drillable bridge plug at 5934 and set drillable retainer at 5686'. Cement squeezed "A" zone per- forations 5750-5805' with 150 sacks. Drilled out cement to 5925 and pressure tested cement squeeze and pressure bled off, Set drillable retainer at 5676 and cement squeezed with 400 sacks. Drilled out cement to 5910 and pressure tested squeeze job'and held okay. Drilled.out bridge plug and pushed to 8654. Ran casing scraper to 7200'. Set 9-~5/8 retrievable packer at 7120' and pressure tested annulus and held okay. Ran.Kobe hydraulic pumping system and set the pump. at 85~6~. Pump tested well.'- Operations completed 11-15-71. Final Report. DEC 1 0 1971 DIVISION OF OIL AND ~--I ,i ~,,-. ,~ /' · ,~ .~..~ ~ ...... 16. I hereby certify that the f~o~t~;~ue and correct TITLE Supervisor in Charge (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: DATE TITLE DATE December 8, 1971 See instructions On Reverse Side l, ot,.m ~o. P....,4 R,L'V. STATE OF-~ALASKA OIL AND GAS CONSERVATION COMMI'rI'EE SgBMrr IN I~IJ'PLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5 APl NI.~IERICAL CODE 50-133-20039 6 LEASE DESIGNATION AND SEHIAL NO. ADL-17595 1. 7. IF IlWDIA]~, ALOTTEE OR TRIBE OIL [~ GA. ~ OT~Z, W~LL W~LL 'J. NAME OF OPERATOR Amoco Production Comp,a.ny ~. ~nR~ss '~F"O~TO~ P. O. Box 779~ Aqchorage, Alaska '~./%cA~oN o~ wF_ia' ' ' 99510 Surface: Leg 2, Slot 6, Middle Ground Shoal Platform Baker, 1989' FNL, 588' FWL, Sec. 31, TgN, R12W, S.M. 8. L~IT F~ OR LEASE NAME MGS State 17595 g WELL NO 13 10. FIELD A.'qD POOL. OH WILDC~kT Middle Ground Shoal 5~. sec., 'r., ~.: i~.. ~so~6~ hoLE o~ Sec. 31, T9N, R12W, S.M. 67-49 "13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDLN'G DEPTH SET AN'D VOLUiVIES USED. PERFORATIONS. TESTS AND HESULTS FISHING JOB~ JUNK LH HOLE AND SIDE-TRACKED HOLE AND A.IqY o'rf-IER SIGNIFICANT CH.A. NGES IN HOLE CONDITIONS. SUMMARY OF OPERATIONS DURING OCTOBER 1971 October 18-21, 1971 - Removed existing bottom hole equipment and cleaned well out to 8656'. Ran casing scraper to 6000'. October 22-25, 1971 - Set drillable bridge plug at 5934' and drillable cement retainer at 5686'. Cement squeezed "A" zone perforations 5750' to 5805' with 550 sacks of Class G cement. October 25-27, 1971 - Drilled out retainer and pressure tested perfs to 950 psi. Drilled out bridge plug and pushed to 8654'. Ran casing scraper to 7200'. Set retrievable packer at 7120' and pressure tested annulus to 725 psi. October 28-30, 1971 - Ran dual tubing and Kobe cavity. Landed cavity at 8618'. Installed Kobe pumps. October 31, 1971 - Pump testing. .,.~/ ,. ,~ , ,.~ ....'~/! , , ' ......... , ~ ,,, ~; ~ ~- _ , , ' N~E --Report on this fora is required for ~ calendar ~th~ regardless of the status of operations, end must ~ filed in duplicate with the oil and gas conlervat~n commiflee bythe 15~ of the suecfldlng mn~, ~leM otherwise directed. Amoco Production Comp P. O. Box 779 Anchorage, Alaska October 6, 1971 File: JCS-542-WF Re: MGS State 17595 Well No. Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Attached is a Sundry Notice, Form P-3, furnishing you notice of our intention to repair the above referenced well. Yours very truly, ~~. C. Schillereff Supervisor in Charge Attachment BtYi~O~,',: OF OiL Ar,iD GAS ANC, HO~AG~ FOrm .. ~ Submit "Intentions" in Triplicate ~ , & "Subsequent Reports" in Duplicate STATE- OF ALASKA OIL AND GAs CONSERVATION COMMII'rEE SU'NDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dif£ierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1.' OIL ~WELLOAS ' ~] OTHER WELL 2. NAME OF OPERATOR Amoco Production Company 3. ADDtLESS OF OPE~iIATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATIO~I. O.F WELL At surface Leg 2, Slot 6, Middle Ground Shoal Platform "B"; 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 78.75' above MSL 14. Check Appropriate Box To I~ndi,c~te Nl~t'ure of N~ti'ce, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ~J ABANDONs REPAIR WELL X[ CHANGE PLANS WATER 8HUT-0FF FRACTURE TREATMENT SHOOTING OR ACIDIZINO (Other) '5. API NLrM. ERICAL CODE 50-133-20039 ADL- 17595 ?. IF INDIA.N, ,Ai~O'i"r~T3 OR TRIBE NA.M.E 8. UNIT. FAi:LIVI OR LEASE NAME MGS State 17595 9. w~:.,L NO. 13 10. Fr~r.r) A~iD POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PERNJ!~ NO. 67-49 ~ort, or Other SUBSEQUENT REPORT OF: ALTERING CASING ARANDONMEN'T$ (NOTE: Report re.ults of multiple completion on Well (Other) Completion or ReeomPletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent date,, including e, tim'ated date of starting an.y proposed work. TD 10,691', PBTD 7356'. Well is presently producing from the E-F-G zone on gas lift with packers set at 5745' and 7164'. We propose to cement off the A zone perforations (5750' - 5805') and install a Kobe hydraulic pump. Dual strings of 3½" tubing will be used for power oil input and production. The single pump will be set at 8.620'. W.ork will begin on about 10-8-71. Well is not capable of flowing production from the EFG. OCT 7 DIViSiON OF OiL AND GAS 16. I hereby.certify that-the SIGNE%~J fore~'ol.~?~ i.. true and corre~ (Thi~ .pace for State o~ce ~) TITLE Supervisor in Charge TITLE Chief ?e~roleum Engineevj See Instructions On Reverse Side Approved Copy Returned _/d- ~> ; '?/ _ Form P--3 HEY. 9-30-6? Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F AI_A~KA OIL AND GAS CONSERVATIONi ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this forra for proposals %0 drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR' PEKNIIT--" /or such proposals.) 1. 0IL ~ OAS ~--~ OTHER WELL ..... WELL 2. NAME OF OPERATOR Pan A-~rican Petrolm,m Carrier. eton 3. ADDRESS OF OPERATOR P. 0. Box 779 ,- Anahora_~e. Ala.ka qq~Ol 4. LOCATIO~I. O,F WELL At surface Leg 2, Slot 2, HGS Platform Baker; 1989' FNL, 588~ FWL, Sec. 31, TON, R12W, S. M. 13. ELEVATIONS (Show whether DF, ET, GE, etc. RRB 78,75' ~bove MSL ~4. Check. Appropriate Box To I~ndi'cate Niature o~ Ntoti'ce, Re NOTICE OF INTENTION TO: FRACTURE TREAT -- MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ARANDONs REPAIR WELL CHANGE PLANS (Other) 5. AP1 NI/ME/%ICAL CODE 50-133- 20039 6. LEASE DESIGNATION AX%ID SERLA/~ NO. AI~L- 17~g~ 7. IF INDIA/~, ALLO'r'r~:w. OR TRIBE NAMJD , 10. FIELD P L, OR WILDCAT M~,4,41~ ~,,~,,nel Rhea1 11, SEC., T.; R.[ ~I.; (I~OTTOM H~I2~ OBJECTIVE) . 6~-za EUBSEQUENT REPORT OF: WATER SIIUT-0FF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING ~iHOOTING OR ACIDIZING ABANDONMEN'T$ _ (Other) NoTE: Report results of multiPle completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an.y proposed work. The following intervals were perforated on 12/10/68: 7870-8010' 8030-8080' 8150-8170' 8200-8380' 8425'8510' D~¥~$~ON OF OH. AND ~A$ ANCE, Oa;'.~E SIGNED ~ S, HALF. Y T~TLEArea Administrative Supvr. D*T~ 12-27-68 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form No, P--4 REV. 9-30-67 STATE O'F ALASKA suBMrr nv DEPLZCA~ OIL AND GAS CONSERVATION COMMITTEE ~MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NA~VIE OF OPIIR~kTOR Pan American Petroleum COrporation 3, ADDRESS OF OPEi%ATOR P. 0..Box 779 - Anchorage, Alaska i. LOCATION O'F WELL Leg 2, Slot 2, MCS Platform Baker; Section 31, T9N, R12W, S. M. 99~01 1989' FNL, 588' FWL, ~.. API NLr~IEPLICAL CODE $0-133- 20039 6. LEASE DESIGNATION AND SE'RIAL NO. ADL- 17595 7. IF INDIAN, ALOTTEE OR TRIBE NA.%IE 8. U/%'IT,F.~q~M OR LEASE NAAIE MGS State 17595 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal I1. SEC,, T., R., M., IBOTTOM HOL~ OBJECTIVE) Section 31, T9N, R12W, S. M. 12. PEP,1VIIT INTO. 67-49 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-LA_NGES IN HOLE SIV--.E, CASING ~ CEMENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED, PERFORATIONS, TESTS A1VD P~SULTS, FISHING JOBS. JUNK IN HOLE A/~D SIDE-TI~ACI~ED HOLE AND A~qY OTHER SIGNIFICANT CtiAN.GES nv HOLIg COI~rDITIONS. 11/1- 11/28 PBTD 8660'. ~as lift tested. 11/29 PBTD 8660'. Recompleted as a gas lift oil well. D~mtO~ O~ O~ ^.0 OAS .... . AN~c~ stoa C: IC D!ETZ.~_ ~LEAsst. Area Admin. Supvr, DA'i','..December !.2, 1968 ,~ , NOTE--Report on this form is require~l for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding menth, unless otherwise directed. Form P--3 REV. 9-30-67 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE SUN!DRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "~%/~PLIC~TION FOR p~IT--" for such proposals.) 3. ADDRESS OF OPERATOR P.O' Box 779 5. API N~CAL CODE 50-133-20039 LEASE DESIGNATION A.ND SERIAL NO. ADL-17595 7; IF INDIAN, ALLO'I-r~E OR TRIBE NA1VIE 1. OIL ~ OAS WELL WELL OTHER 2. NA1VIE OF OPERATOR 8. UNIT, FA/~/i OR LEASE NAME Pan Americ~ Petroleum CorpOration MGS State 17595 9. w~L NO. I3 Anchorage, Alaska 99501 4. LOCATION. O,F WELL At surface Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' ~, SeC. 3!, T9N, R!2W, S.M° · 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 78-75' above MSL 14. 10. F/~D A, ND FOOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S~M.. 12. PEHA~-IT NO. 67-49 Ch~ck Appropriate Box To I,ndi'case Niature of NIOti'ce, I~eport, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDONs CHANGE PLANS Other SUBSEQUENT REPORT OF : WATER SIIUT-OFF REPAIRING WELL FRACTURE. TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABAND0NMEN'T$ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ,, ' 15. DESCRIBE PROPOSED OR C0.~iPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an.y proposed work. This notice sets forth' our intent to perforate the following additions intervals in the "E-F-G" Units of the Conglomerate zone: 7870 - 8010' 8080 - 8030' 8150 - 8170' 8200 - 8380' 8425 - 8510'. of o%t .~No G~S'- 16. I hereby certify that ~the for/e~oln~ ~ true a~d~ correct CONDITIONS OF APPROVAL, ~ DATE 12/6/68 DATE See l~nstructions On Reverse Side Is'ORM 470 2-57 PANAMERICAN PETnOLEUM C011POIIATION P. O. Box 779 Anchorage, Alaska 99501 November 21, 1968 File: FKK- 1247-WF Re: Packer Leakage Test M.G.S. 17595 Well No. 13 Mr. Thomas R. Marshall, Jr. Petroleum Supervisor Oil and Gas Conservation Committee Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: A test was conducted on November 4-7, 1968, to determine the integrity of the dual and single packers in M.G.S. 17595 Well No. 13. Attachment No. 1 is a graphical presentation of the data obtained from the test. Attachment Nos. 2, 3 and 4 are BHP reports and a pressure chart showing the data that was used in preparing Attachment No. 1. The wellbore diagram of the subject well is.shown in Attachment No. 5. The procedure used in conducting the test is as follows: 1. A BHP bomb was installed below a "PQ" plug and set in a "Q" nipple at 7172'. The "PQ" plug prevented the "E-F-G" zones from being in communication with the tubing and the bomb recorded the "E-F-G" zone pressure below the single packer. 2. The sleeves at 7160' and 5848' were opened to permit the "A" zone to produce and a BHP bomb was hung on wireline in the tubing at 7145'. The "A" zone was put on gas lift for 24 hours. 3. A pressure recorder was installed on the annulus, and the tubing was pressured to 1400 psi at the surface. The test indicates that both of the packers are holding since the "E-F-G" zones pressure continued to climb when the "A" zone was placed on production, and since neither the "E-F-G" zone pressure nor the annulus pressure showed a leak when pressure was applied to the tubing. Attachments Very truly yours, F. K. Krebill'~' Area Superintendent · ~:HKD. BY ................. DATE ..................... $.=v No ......... .4. ....... o~....../. ......... ~o~ ~o ................................................. ., o ' I IO I! · . tI 11 ti *l // /* .. IIECEIVEI) DIVISIOH OF 011. AND OAS ' . NO. ,~2~,~. 20 DIVI~--.ION$ PEn INCH I~OTI.'I WAYS. ISO BY ZOO I~I~ISl0N$. Box 937- Rock Springs, Wyo. 82901 Area Code 307 Tel. 362-6488 C. A. White Wire Line Well Service Box 156 Casper, Wyoming 82601 Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 Producing Formation Elevation (CHF, DF, KB, etc.) · Datum - subsea, or Tubing set at 71751 C~sing set at 10690 ' P,'oduction Packer at '5745 ~ 7164' SUBSURFACE PRESSURE SURVEY . Company P~ Amerieau Petroleum Corp. ( ) Lease 17595 Well No. 13 38' Field MoO'oS. ,. . State Alaska ' ~i-'4"-68' to 11-6-88 ( ) Test Date . Zero Point KB ,, 3'~t , GRD Imrforatioas 5760-5805 7995-8610 Subsurface Controls (Nipples, et¢3 B.V.-h06~ KBM%1852~ 3113, 4~.'~1, 4912, 5640, - Instrument Data XO sleevc-5741~ 5848, 71~ Q ~pple.717~ C.A. White Company Running Survey Element- Range & No. _ 5~0~ ~0~ Clock - Range & No. ' 1~0 h~. 7172 Calibration Date ~0-~-6 8 Static Pressure Data Pressure at Datum @ ) Shuit-in Time ) Pi at Datum Shut-in Tubing Pressure Shut-in Casing Pressure Top of Oil Top of Water Temperature at 7145 Date of Last Test Pressure @ Datum, Last Test Shut-in Time, Last Test lhh psig. hrs. psig psig °F psig Flow Test Data Choke Size in Period of Stabilized Flow hfs Stabilized Production Oil bbls~day Gas MCF/day Water bbls/day Flowing Tubing Pressure psig Flowing Casing Pressure psig Remarks: E.S. 7: 30 P.M. 11-h-68 On bottom 8:30 P.M. 11-h-65 Scfow jarred loose while, jarring'-"Q" Plug through XO sleeves and seating i.u "Q" nipple. whilch caused Stylus to hang slightly. Operator_ ~ynarcik Time Press., P, psig iP ;tatic Test A D ~radien 'ime .:3', Press. , ?~/)~ ft. l&'OO 1066 1290' 1593 1712 1712 1727 1770 1861 1861 1863 2018 2O23 At hrs. h 6 10 20 3o 36 ui! ' Box 937 Rock Springs, Wyo. 82901 Area Code 307 Tel. 362-6488 ~ C. A. White Wire Line Well Service Box 156 Casper, Wyon~|ng 82601 Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 Producing Formatiori Elevation (CHF, DF, KB, etc.) ,. Datum ,. subsea, or Tubing set at Casing set at P-eduction Packer at SUBSURFACE PRESSURE SURVEY 38' , ( ) 7175 ' 10690 ' ~5745' '4 7164' - eerrorations 5760-5805 7995-8610 Subsurface Con'trois (Nippl.es, etc.) B.V. -406, KPM-lB52, 3113, h121, h912, 56~o, xo s~cevu-5741s Instrument Data 5848, 7160, Q nip.-7172. Company Running Survey C.A. White Element- Range & No. , 6200g Clock Range & No. Calibration Date 10-23-6~ .... Static Pressure Data Pressure at Datum @ ) ~sig Shuit-in Time ) 2 firs. Pi at Datum Shut-in Tubing Pressure Shut-in Casing Pressure Top of Oil Top of Water Temperature at 7145 feet Date of Last Test Pressure @ Datum, Last Test- Shut-in Time, Last Test psig 900 ,, psig 144 psig Fl~>w Test Data Choke Size 124/64 , in Period of Stabilized Flow ~ hrs Stabilized Production Oil 6~ bbls/day Gas 50 MCF/day 35h bbls/day Water Flowing Tubing Pressure Flowing Casing Pressure ~00 psig 7ho psig Remarks: E.S. 9:00 P.M. 11-4-68 On Bottom 9:30 P.M. 11-4-68 Off Bottom 6:30 A.M. 11-6-68 D.S, 7:15..AT~M. 11-6-68 Operator_ My-narcik Company Pz~ Americam Pe,,roleum Corp. Lease, ' 17595 WellN0 13 Field !'{. ,:. S. A ~.'a s ka rest Date "11-h--6~ to' ll-6-S~r Zero Point KB 3~ GRD~ Time Press. P, psig Static Test Press. 71.~ ft. 1294 1071 lO99 1067 lO56 1037 1090 1062 1090 1111 10o9 1226 1090 1071 1034 1080 991 3561 2970 At hrs. . 1 2 lO 12 14 16 18 2O 22 24 0 2 Casing Press___._L trks Shut-ira Put?ed to 1400,~ surface .press. "%.; t f:-;.' Form No. 1:'-.-.4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION CO/MAAITTEE : SUBMIT IN DUPLICATE MONTHLY REPORT OF 'DRILLING AND WORKOVE:R OPERATIONS AP1 NUA{ERICAL CODE 50-133-20039 6. LEASE DESIGNATION AND SEHIAL NO, ADL- 17595 2. NAME OF OP]~ATOR P~n American, PetrOleum Corporation 3. ADDRESS OF OPEI{ATOR P. 0. Box 779 - Anchorage, Alaska 9~01 4. LOCATION OF WELL Leg 2, Slot 2, MGS Platform Baker; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S. M. 8. UNIT,FARM OR LEASE NA3~E MGS State 17595 g, WELL NO. 13 10. FIa;L,D A.ND POOL. OH WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. (BOI'TOM HOLE OaJF~mVE) Section 31, T9N, R12W, S.M. 1~-. PI~IVIIT NO. 67-49 13, REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/ND VOLU/ViES USED, PERFOP~ATIONS, TESTS AlXrD RESULTS, FISHING JOB~, JUNK IN HOLE A_ND SIDE-TRACKED HOLE AJ~-D A/~Y OTHER SIGNIFICAi%TT CILa~N~ES IN I~OL~ CONT)ITIONS. lOll- 31 PBTD 8660'. Gas lift tested. mGm~ ~'~',,, /'~/~ r~r~ Asst. Area Admin. Supvr.~A~ November 11, 1968 NOTE--Report on this form i~)required for each calendar month, regardless of the status of operations, ancl must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P---4 STATE OF ALASKA SuBMrr n~ ~UPLICAT~- OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F :DRILLING AND WORKOVER OPERATIONS ~. API NUA{ERICAL ~ODE 50-133-20039 6. LEASE DESIGNATION A,N'D SE1RIAL NO. ADL- 17595 2.NAME OF OPEB. ATOR Pan American Petroleum Corporation 3, ADDRESS OF OPERATOR P. 0. Box 779 - Anchorage, Alaska 99501 4. LC)CAT/ON OF WELL Leg 2, Slot 2, MGS platform Baker; 1989' FNL, 588' ~WL, Section 31, T9N, R12W, S. M. 8. LrNIT,FARM OR LEASE NA3~E MGS State 17595 g. WELL NO. 13 10. FIEI~ AND POOL. OR WILDCAT 11. SEC., T., P,,., M., (BO~FOM HO~ o~ Sec. 31, T9N, R12W~ S.M. ,. 1~.. PERMIT NO. 67-49 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE sIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLLVIVI]~ USED, pERFOP~ATIONS, TESTS A_ND RESULTS, FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CI-IA~-~ES IN HOLI~ CON]~ITIONS. 9/1 - 30 PBTD 8660'. Gas lift tested. RECEIVED 0 CT 15 1968 DIVISION OF MINES & MINERALS ANCHORAGE '~% , ill, , l 11 i4. I hereby eerti£y that the Iorggoin$ ~d correct smmm C~...~_.~/~' ~J~ ~wu~ ..Asst. Area Admin. Supvr. D,~ 0ctober..~14, 1968 NOTE--Report on this form j~equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed, Form No, P--4 REV. STATE OF ALASKA sus~rr ]]q DUPLICATE OIL AND GAS CONSERVATION COMMITTEE ~. AP! NUA~ERICAL ~0DE 50-133- 20039 6.LEASE DESIGNATION AXD SE"RIAL NO. MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS ADL - 17595 2. NAM]~. OF OP~TOR 8. LrNIT,FAP~ OR LEASE NAME Pan American Petroleum Corporation MGS State 17595 3. ADDRESS OF OPEB, ATOR 9. WELL P. O. Box 779 - Anchorage, Alaska 99501 13 4. LOCATION OF WELL Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 10. F~ AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC.. T., R., AI.. (BOTTOM HOL~ O~J-F~3TZVE~ Sec. 31, TgN, R12W, S.M. 12. P~IVIIT NO. 67-49 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN]) VOLUIVIES USED, PERFO.~TIONS, TESTS A/XFD RESULTS, FISHING JOB~, JUNK IN HOLE A.ND SIDE-TRACKED HOLE AaNT) ANY OTI-IER SIGNIFICANT CI-IAN-GES IN HOLE CONDITIONS. 8/1-31 - PBTD 8660'. Gas lift tested. fore~il%g is~te correct, ' SmNE~ %... v~, ~Asst. Area Admin, Supvr. hATE 9-12-68 NOTE--Report on this form i~ 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 15th of t~he succeeding month, unless otherwise directed. l, orm No. P--4 REV. 9-~-~7 APl NUAIERiCAL CODE 50-133- 20039 STATE OF ALASKA SUBMIT IN DUPLICATE O~[ AND GAS CONSERVATION CONVv%[TTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. N~E OF Pan American Petroleum Corporation 3. ADDRESS OF OPElq~TOR P 0. Box 779 - Anchora~e~ Alaska 4. ~OCA=ON OF W~UL 99501 Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 6. LEASE DESIGNA~ON AND S~IAL NO. ADL - 17595 7. IF INDIA~', ALOTTEE OR TRIBE NAME 8. LrNIT,FA/RAi OR LEASE NAME MGS State 17595 9. WELL NO. 13 10. FIELD AND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., ~O'I'rOM HOI~E om.mcrrv-~ Sec. 31, T9N, R12~, S.M. 12, PERMIT NO. 67-49 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING A/ND CEMENTING JOBS INCLUDING DEPTH SET AArD VOLUMES USED, PERFO~tATIONS, TESTS ANTE) RESULTS, FISH/bIG JOBS, JUNK IN HOLE A_ND SIDE-TRACKED HOLE A/ND A3~Y OTIiEI% SIGNIFICANT CI-IAN-~S IN HOL]!I CONDITIONS. 7/1-31 - PBTD 8660'. Gas lift tested. 14. I hereby cert~a~thee ~.~i~i re ing,~ e freer szamm~-/~./~ ~ Asst. Area Admin. Supvr. o.rr 8-8-68 NOIE--Repor% o, t~i~ form i~ r¢~¢~ for each oale.~ar mo.th, regardless o~ the status o( operation% and mu~% be (ilee in duplicate with the Division of Mi.es & Mi.eral$ by the 15th o( the $-cceedi.9 mo.th, u.les$ otherwise directed. Form. No. P--4 I~EV. 9-30-67 0IL WELL STATE O,F ALASKA OiL AND GAS CONSERVATIO.N COMMITTEE SUBMIT I/%T DEPLICATE A'IONT'HLY REPORT OF :DRILLING AND WORKOVER OPERATIONS APl NUA[ERICAL CODE 50-133-20039 6. LEASE DESIGNATION AND SEEIAL NO. ADL- 17595 ?.' IF IN'DIAN, ALOTTEE OR TRIBE NASIE . GAS WELL [] OTHER 2. NA/~E OF OPERATOR 8. Lr~'IT,FA!~M OR LEASE NAAIE Pan American Petroleum Corporation MGS State 17595 3. ADDRESS OF Ot~:I'~'~TOR 9. WELL ~'O. P. O. Box 779 - Anchorage, Alaska 99501 ~ 13 ~. LOCATION' O,17 W.~zaLL Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. t0. Fl~JJr) AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BO'I~rOM HOLE OBJECTIVE) Sec. 31, T9N, R12W, S.M. 12. PEPdViIT NO. 67-49 I3. REPORT TOTAL DEPTH AT END OF MONTI{, CHANGES IN HOLE SI~E, CASING A/WI) C~VIENTING JOBS INCLUDING DEPTH SET A1NI) VOLU/VIES USED, PERFO'~TIONS, TESTS A/ND RESULTS. FISHING JOBS, JLrNK LN HOLE A_ND SIDE-TI~ACKED HOLE AND A~IY OTHER SIGNIFIC;~NT CH3%NGES IN HOL~ CONI)ITIONS. 6/30 PBTD 8660'. Gas lift testing. 6/1 ConCluded DST f~l. Tool open for 25 hours total & had fair, weak blow throughout test until fluid reached surface. Reversed out 123 bbls of fluid. Top sample 86% oil, 14% mud, trace water. Middle & bottom sample 100% emulsified oil and mud with trace of water. 6 / 2- 3 Temporarily suspended. 6/4-6 Tested casing and set BP at 5980'. Set DST tool at 5709' to DST "A" zone. Gas to surface in 50 minutes. 6/7 DST #2: tool open 28 hours with weak blow throughout test. Reversed out 52 bbls fluid: 5 bbls gas & oil cut mud, 47 bbls fresh water. 6/8-9 Set BP at 5950' and packer at 5825', and squeezed with 125 sx cement at 1300 psi. Perforated 5750-5805'. Set DST tool at 5705'. Tool open 1:30 a.m. 6/8/68 and gas to surface in 40 minutes. Had continuous weak blow at 1-2 psi at surface. No gauge. Tool shut in at 8:00 a.m. 6/9/68 (open 30~ hours). Reversed out 48 barrels of fluid, recovered 1 bbl water and mud cut oil, 47 bbls mud cut water and water. Samples from top to bottom: No. 1 - oil cut 50% mud and water; No. 2 and No. 3 and No. 4 - mud cut water; No. 5 and No. 6 - water. Ca Ions 80 ppm, C1 ions 2650 and equivalent MaC1 4360. 6 / 10-11 Swabbed. 6/12 Acidized w/5500 gal regular mud acid & demulsifier at 1½ bbl/minute~ 6~0-800 psi. Displaced acid w/diesel and held 550 psi for 2 hours. Released pressure & flowed back 40 bbls diesel & died. 6 / 13-18 Swabbed. 6/19-21 Cleaned out to 8660' and scraped casing. 6/22-24 Set & pulled tubing; reran & set tubing at 7175' with packers at 5752' and 7172'. 6/25-$0 Gas lift testing. 14. I hereby SIGNED ~ '/~ ' ~'~" ~ TITLE Asst.Area Admin. Supvr. ~A','t 7-10-68 . r. ( -nrrrl~,'rn NOTE--Report on this form is reqz~l)ed for each calendar month, regardless of the status of operation~a~ ~llm;st[belfil~l i~ d~icate with the Division of Mines & Minerals b-y the 15th of the succeeding month, unless otherwise directed. JUL 15 1968 DIVISION OF MINES & MINERALS ANCHORAGE Form No. P---4 REV. 9-30-6~ STATE OF ALASKA SUBMIT IN DEPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPE;RATIONS OIL ~. CAS [] WELL WELL OTHER 2. NA~E OF OPm~TOR Pan American Petroleum Corporation ADDRESS OF OPEKATOR P.= O. Box 779- Anchorage, Alaska 99501 4. LOCATION' O'F WELL Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. ~. API NUMERICAL CODE 50.133- 20039 6. LE, ASE DESIGI%'ATION A%'D SE1RIAL NO. ADL- 17595 7. IF INDIAN, ALOTL~:k O.q TRIBE $. UIN'IT,F.kl~M OR LEASE NAAIE MGS State 17595 9. XVELL NO. 13 10. FIELD AND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOITOM HOLE OBJECTIVE) Sec. 31, TgN, R12W, S.M. 12. PElq~ViIT l~rO. 67-49 ]3. REPORT TOTAL DEPTH AT END OF MONTH, CI-IANGEs IN HOLE SIZE, CASING AND CEIViENTING JOBS INCLUDING DEPTH SET AN~ VOLLrNIES USED, PERFORATIONS, TESTS AND tLESULTS, FISHING JOB~, JUNK IN HOLE A_ND SIDE-TRACKED HOLE AND A_NY OTI-IER SIGNIFICANT ~ES IN I-IOL~ CONDITIONS. 5/31 5/14 5/15-17 5/18-29 5/30 Testing PBTD 10,638'. Rig up drilling rig to swab. Swabbing. Worked downhole equipment; then pulled tubing and all packers. Set retainer at 8660' and squeezed with 200 sx cement at 2500 psi. Set DST tools at 7130' for DST. RECEIVED JUL 15 1968 DIVISION OF MINES & MINERALS ANCHORAGE 14. I hereby ce th r~ ~ StoNED ' ~TL~ Ass ' t. 'Area Admin. SuPvr.DA','I 7- 10- 68 N01£--Report on this fOrm is re ed for each calendar month, regardless of the ~tatu~ ol operation% an~ must be file0 in duplicat~ with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ARCCO ' RECORDING CHARTS' ME-TER PLATE ,~ / J/ . REMARKS ~" !o~ lingeles, A.M. / ? 16 19 21 -I [ . 4 ?.~,' : .i · ___ FOI~M 4'J'O 2.57 PANAMERIC PETP OLEUM C01 ,po ION 1~. O. Box 779 Anchorage, Alaska 99501 April 18, 1968 File' FKK-496-WF Re: l~acker Leakage Tests MGS 17595 Well No. 13 Mr.. T. lq. Marshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 1Porcupine Drive Anchorage, Alaska 99504 Dear Sir: In order to conform to State regulations concerning packer leakage tests, we are herewith submitting for your approval, the data from the tests conducted on MGS 17595 Well No. 13. The data is presented in a graphical form to aid in following the procedure used in performing the tests. Due to the unusual nature of the completion technique, we have utilized this method of presentation, rather than the state form. You will also find attached, the appropriate surface pressure recording charts for the test' period, and also a well bore sketch for your reference. Attachments Yours very truly, F. K. Krebill Area Superintendent ~" I,,,,',c~ - Zro->-.q~- ': ,'~ ,'~. ~, :.:.' ~,'~ ~, u' -i '5"(- riO'l q tl'Z- I'o .© Form No. P--4 REV. 9-30-67 STATE O'F ALASKA SUBMrr IN Dn~L~CAr~ OiL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. API NUA~ERICA. L CODE 50-133 -20039 6. LEASE DESIGNAiION AND SERIAL NO. ADL-17595 7. IF INDIAN, ALOTTEE OR TRIBE NA.%IE OIL ~ GAS ~ OTHER WELL -- WELL 2. NANiE OF OPERATOR 8. LTNIT,FA/~M OR LEASE NA-ME Pan American Petroleum Corporation MGS State 17595 3. ADDRESS OF OPEP, JkTOR 9, WELL NO. P. O. Box 779 - Anchorage, Alaska 99501 13 4. LOCATION O'F WELL Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, T9N, R12W, S.M. 10. FIELD AND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., A'L, (BOq~POM HOI~E OBJECTnrE) Sec. 31, T9N, R12W, S.M. 12. PER/VIIT NO. 67-49 13. REPORT TOTAL DEPTH AT END OF MONTH, Ct-IA~'qGES IN HOLE SI:~E, CASING AND CE1ViENTING JOBS INCLUDING DEPTH SET AND VOLI3/VIES USED, PER/~ORATIONS, TESTS A/ND RESULTS, FISHING JOBS, JLrNK IN HOLE AND SIDE-T'RACKED HOLE AND ANY OTHER SIGNIFICANT CI-[A/~ES IN I-IOL]~ CONDITIONS. 1/1 Completed as dual zone, dual string flowing oil well. RECEIVED FEB 14 DIVISION OF MINES & MINERALS ANCHOP, AGE 14. ! hereby ee rrect smmm ~TLEAsst. AreaAdmin. Supvr. DA'~.~ 2/12/68 IIiii i' ! ~ 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 15th of the succeeding month, unless otherwise directed. ' ' <"l/../'~ ....... ~ ..... //~.? PAN AMERICAN PETROLEUM CORPORATION DIKECTIONA~ CO~TKO~ Direction ~ _..(co_r.) .... !..CO,U?,Sg. t Dep th Fact_or ,_ ~ TVD i Lat. .TV.D. ..... Fac.tot Def. Factor . /J /'V,,..? 7 " 'r I . y, ) .'T.. "'/"' ,... ( , ( ,7 f J, ', d',.'/' ., , I ,/./, J dg. -.bT / ,,o, 7,.,? , i d-'":, :: ' f' [ -" ~/ PAN AMERICAN PETROLEUM CORPORATION ~L: N~d~[E ,"'~...5 /, _, DIRECTIONAL CONTROL ' (Cor.) I Course Factor /k TVD TVD I Factor Factor ^ N L~x S A~x,' E z~ W S E I W Dog Le .... ~ ~ . ~ ....... , ~... ~ ....... ~,~ ,;. ~z.~.. 1,~:"' I' ~x~/~ _.! " . . . ,,.¢,~..,v:..>w; ~ . ." ..., IZ/'7,~ ~/~o, ~. t ~:, I ~",;.'~ .~/-~z'~ t Y ~'. 'z~x ~:"~ :~'/:~ .-:::::: -~-~,~ ~:~.~'~! ~-~'. ::,',~,~ /~;:,~::..~ ~z~.~ ~:-.~,n~ ~, ~.- ' -. ' , · ff~q,_.~n~ ~ ~ oJ ' 5":.A~,", '~ "L~'~ ..... ' '"'" . ,. ~ .. , ~ , .. :~ , . ,,, ~ , . ,~,,~ , ... ' . , ...... ~ ~ ' . ,~,' "k'~ · .... % ...... ~- ,. -v'..t (... · ,;'z- ~' _ ; . , _ . ,_ ,. ,, :,.t.] ....... _ _ ~ ?.. ~7.~ ~.~ .... , - ~ -.- ,,, ~. r ' ' ', ' ('? .... ' ' '-- ' ...... ' ..... '" .... PAN AMERICAN PETROLEUM CORPORATION DIRECTIONAL CONTROL .D. I Dev. [ (Cor.) I Course Factor , /~ :._._TVD ...... .TV. D_ ..... Fa.c,t°r,I Factor zx N ~ .S ~ ~' .... _~__W_ - S E W ~f~'~"~" I'/7 .'.'.)i ,4;/Z.5 ~" ""' ..... ' .... . .. - -. .- :, .................... .?.. ...... ~ ....... · ...... -- . ,-, ., o? i I · · ' i c:'~ ,,',,/', ,~ /? , I z/~:? e: -:-.--.' v.',. ': .' ,-:....,..- .-:..,...:.,, ..~ ,,, ,:.' · .-...-' . ...... . /?/. :.-,... I ,.:~.-..- ~/;4,.,7:0 ,. ,7 ?'..cZ,,.Y~, . :-,. :. ,.. - .... ' "" '- ' ..... , , ' ---, .... ' · ' ::..'", , ',' ' -' .... ' '- ...... "' "';' A.'~z '-'>' .... '~'~' ' ' ' "5:-~'~" '"":' 0 'S t) '.-'.-', i.~,,~ f,.v-.-.'~ ,.~.:.:~ ,.>,. ,..z... ....:,,,,.. "-/7~/la :.-,--:-. ~..-, .-.,~-., ........ . i :... ...... ~,~,z? ,.,.. x, ....... I I .. :... .'-- .,. , -. >-'--' - ,,-' .'-.' ~, ...... , ,~'~,~7 -'...' :-~".l ,"?--/ .... ?,~.:, ,~>-.~7~ II2~ ,;',.' t.~¢~,1'~ J ,",'~?.'~ (r~ /~ /..~0~ ~ ....., -:.~-., ...... ...,, .... _. _-.~,~., . .. .... ,:. , ,.-,_ .......~ ....... ,.. .... - ,.._, . .. ~- ,._ . . -'._ , ~ . , ,... ~ .o. .. ~.., -..., .... , ~ .~, ~, ~i ~. ~~ ~ ~1 I , , ~, .... , ...t- ' 1~ '~ , _.:~1~ .t.'~ 1] ~ , '~- _ ' '" ~-' - ' ~ ..... " ' ' , , ' ..... ~ " ' ' - ~ '" -- .~ ~ ~ ~ ' --- ' ~. , ~ , 4~ N %~ 5 ~ q~.~,~ ~ ~o.~'~4 c..:,~"t.-:;".'~ "~.~ ~.o~ .... ~.'~ .. ! o.~: . ~-4.~.a.osl.' ~...,,~..~.~,:~. o..~.~ · ~ ~ , , ',~ ~.~ · ,~ I .... _/ .L ~ ~ ' : , ' , ~ ~ ' , ' .... _. ~ ,~ ,~ , - ..... ~ ...... ~ .... ~" '," - ~ ' ' . ..... .- ~ - - ~3..i ~ ~,4~ · '~ ,, . , '": , · ,. '-' :-' · · -, - ..... ,' ..... '~- .-.;~:"': , , , , . ," ,.., ,.; ,:ZE~ ~,-, ., -.~:~ ................ __: ..... -' ' . ... . . .. z.. ' : , ~ .............. . , · - ." '.. ,' ' ,, , , -,n , , ~ ~ ' - ...... ' ' ' , '" ' , " ' ' ""' ~:" ' ....... ' ' ' ' '" ' '' ..... '~ .... """ ' '"" ' PAN AMERICAN PETROLEUM CORPORATION DIRECTIONAL COI~TROL ' Def. Factor .- d.~.. ~r' 'z, Z'/ J ~ '"' I / ~ ~ ~ '"-:' ~ - - " oa A~ OAS CO~S~~:: ~O~tE~.' ' '--~ .'- i 50- ~3~-20039 WELL C0UPLETION OR RECOMPL~IION REPORt. AND LOG ..... i; ' ~-'~7595 ' -1~. 'TYPE-' OF WELL: on, ~ -~' WELL ~ GAS -.- b. TYPE OF COMPLE~ON: nAC~ n~SVR. . (Other EN · OVER ~ ~% ~.~ ~ ~ 2. ~,~ o~ o~o~ -. - ' ~ ~a~e t7~95 ~o. P~L, OR W~T - . .... h ~:, ~:-~ ~:! ; ~, '~.. Pta~;fom~B~i¥::: :__._1989' · t ,0~ ~,o~. ,.t~,,~,-.o.t~.,,~ow-t~ ~' secuion ~, ~a, :S!~', At total d:~ ~, .~ti5i~ ~, ~ectia 31 :TgN,-:~Ri~, ,-~ ~; '-~. ~ - .- - -/ _ : " ~'" [] ~ '12. P~IT NO. ;:" ~2' F~,-' 805! ~ Secti~ 3I~· TgN:~ RI~;. '8.M · ' : ..... - - ' 67-49 18. T~.D~H, '~ & TVD[9, PLD~, ~, MD.& ~l ~'~LT~ ~L., '!-~i. ' ' : '}-NTERYALS '~aiLL~D BY . :-10. 691" ~, . I;' -:- ,:10.~8' ~: ,[ :.; '~ ~. PRODUCINg' ~V~[S),.OP':~S ~!-ETi~N~T~, ~DM,' N~E' (D AD ~)/ ; ' [~. W~ DI~ON~ , '- t ' ' t, :'I1-~ -'~ Fit ., , 26. ~ 'i( : - ::' .... C~G RE~ (Re~ all-strings set,in w!!i) A/VIOUNT.pULLED C'I~'T~N-G PJ~ COi%D .- 12aS 'ax. - 1 ~00 sx 17an ~ -TUBLt~G : SIZE DEI~I~ SET 'iMD) PACICER S~T (iVI-D) LINER I:~EC(~P~D': TOP (A~D) > BOTTOM (ireD) 8806''" 10.690, (Inter~al. size and number) :See Attached Perforation S~hee-t FRODUOTION ~ · . :"-- I ;~-],iz"-I rossi, .! 7].:].:t, & STST, DI~-~rII.~VAL (MD)- 69t5.6370~ r, 6215- ~70 ~ · \ 475 sx D~.~E FIRST,PF~ODUCTI~)N [ PI~ODUCTION i~IE'I'HO,D (Flowh~g, gas lii;'~, pump~g~size and type of p~P) IWELL ST*WS <~oduc~ or " 1 '- 6 ' 'r - " . ' I shut-in) - 2/25/ 7 -. ~A~; O~ T"ST. IHo~s T~ 'I~OXE S~E IPROD'~ F°R OI~B~L. "'~A~CF. WA~B~. I GAS-Om ~O l" t .' "/ i I i ........ ' ~OW, ~B~G I~S~G .~SS~ [CAL~~ OI~BBL. GA~. WA~B~. [OIL GRAVITY-~ (C~.) ~S. I ' I2!-HOUR ~ ;I ~ ' ~-- ' ' I . L-12~, 8-100 I . ] > ~'I~ltS'i07qrL'6~,$'900] L'!, S-40 i~-~.S°. S-33.9° 31. DISPOSITION OF GAS (Sold, used lot fuel, vented, etc.) ~TEST WITNESSED BY '. 82, LIST OF ATTACHMeNtS ....... i'% :' 3~. I hereb~ dertif~ ~ the f~r~8 ~attached information is co~lete.~d correct asdetermlned trom all:available records :~'~,,,:~,",: "~a~(See Instructions and S~ces f6~: AdditionaI Data on Reverse Side) INSTRUCTIONS General: This form is designed' for submitting a~compl, ete and correct well completion report, and Iog":.on all types of lands and leases irl Alaska. ~",: "~ .... .: ' " _ . - Item: '16: Indicate which elevation is 0sed as reference (where not otherwise shoWn) for 'depth.:fi~easu'¢e .... ments.given in other spaces on thi's form and in any attach'ments. Items.20, ~,nd 22:: If this well is completed for sepafatb'~ pf'bCl'uction from more than one interval zone · (multipl.e completion), so state in item 20, and in itbm: 22 Show the prc.ducing interval, or:- intervals, 'top(s), bottom(s) and name (s) (if any) f6r_only the interval:: reported in item 30. Submit a ,:separate repor~t (page) on this form, adequately identified, for each adctiti.onal interval to be seperately produced; show- lng th;~ acfditional data pertinent to suc~h interval. ' Iti~m26:. "Sacks ':Cement": Attached'i. supplementa! r,~cb'i'dS.[b'i;"t-his Well should" ......... show the details of any'-mu'l; tiple stage cementing, and the location of the cementing fool." Item 28: Submit. a separate completion report on this form for each interval to be separately· pr°du¢~l~ (See instruction for items 20 and 22 above). · - -- · . . _ ' ~4. SbMMARY OF FO~'VIATION TF. STS INCLUDING I NT'EFIVAL TF-,STED, P~RE DATA'~ ~O~ 0F oIL G~. 24, ~ 3205, ~P 2704, FSlP 2455. ' ' IT ~4-6510'6995'; TO 26% hfs, no' fluid' to surface., Rev. 29:: bbls ~, 8'.bb.ls m~.,.: 30 bbls water', ~P 3283, IFP 24', ~P 3203, ~P 2~07, FSIP" 2~55.~ ~*'~5~6195-6208'; ~ 24 hrs, no fluid to surface, Rev. 77 BF-' 8 b s m~, 69. .. s water & mud, IMP 3033, ~P 72, ~P 3033,. FFP 2094, FSIP 2118. 5-57~5-6~16'; TO 40 hfs, ~, 6 hr prod 403 BF, 5~. BS&W, :I~ ":2793, ~ 276~, ~P 1662, ~8I~ 2670. Prod.rate 72.~P~, 220 ~T~, 853 ~, ~'74 ~1 - 626~65~; 88, gry to bm, ~-CG, ~ sre, tfto.to poor por'~ a~e siderite, calcite cmt, good yllw fluor, good cut. CHRONOLOGICAL WELL HISTORY MGS STATE 175 95 NO. 13 9/11/67 - 9/12/67 - 9/13/67 to - 9/18/67 9/19/67 to - 10/30/67 10/31/67 to - 11/17/67 11/18/67 to - 11/27/67 11/28/67 tO - 11/30/67 12/1/67 to - 12/4/67 12/5/67 to - 12/10/67 12/11/67 to - 12/13/67 12/14/67 to - 'i2/15/67 12/16- - -20/67 12/21- - -28/67 12/29/67 - 12/31/67 - Spudded. · Drilled 12~" hole to 620', opened to 26" and set 20" casing at 595' with 1285 sx. Drilled 12%" hole to 2393', opened to 17~" and set 13-3/8" Casing at 2012' with 1900 sx. Drilled 12%" hole and cored from 2393' to 8928'; logged and set 9-5/8" casing at 8920' with stage collar 6902'', cemented first stage with 875 sx and second stage with 825 sx. · Drilled 8%" hole 8928' to i0 691' logged and ran DST No 1 Set 7" liner 8806' to 10,690' with 420 sx. PBTD 10,638'. Perforated intervals between 10,035' and 10,110' and ran DST No 2 Perforated 6215-25' 6245~70' and. 6330-70' and ran DST No. 3. Set retainer at 6174' and squeezed perforations 6215-6370' with 200 sx. Drilled retainer and cleaned out to 7000'. Perforated intervals 6535-45', 6570-80' 6825-45', 6920-35' and ran~DST No. 4. Set retainer at 6516: and squeezed perfs 6535' to~6935' with 250 sx. Reperforated intervals 6215-25 6245-70' 6330-70' and ran DST No 5 Set retainer at 6200' and squeezed perforations 6215' to 6270' with 100 sx. Perforated intervals from 5760' to 5910' and ran DsT No. 6. Drilled retainer at 6516'. Cleaned out to 6200' and set re- tainer at 6165' and resqueezed perforations at 6215-70' with 100 sx. Drilled cement retainers 6165-7000'. Retainer set at 6985'. Resqueezed 6825-6935' with 75 sx. Broke down formation with 1000 psi and resqueezed perforations 6535- 6580' with 150 sx. Perforated intervals 7195' to 10,535'. Ran dual string tubing and installed tubing hanger. Flow tested. Rig released. 1/1/68 - Completed as a dual flowing oil well. LIST OF PERFORATIONS MGS STATE 17595 NO. 13 ~5760-70', 5795-5805', 5865-75', 5900-10',~7195--~210' /~; ~ss~-~', ~o-2o', ~¢so-so', ~o-~ooo', , , , , ', s~-~q, ~30-3~, s~so-~o , s~20i~ , 834~-~-°, 8370- ~ .¢~ ~...~~ , 9085-95', "9245~ -~55', 9275-'~0', 9320-35', 9470-80', 9580-90', 9760-70',~ ~o,o3~-~o', ~o,o~-~o', zo,~oo-~o,~o', ~o,2~o-~', 10,480-95' and 10,520-35', all with 4 jspf. SUBMIT IN DEPLICATE -5. AP1 NUAiERICAL CODE Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVE:R OPERATIONS 50-133-20039 6. LEASE DESIGNATION AND SERIAL NO. ADL- 17595 1. 7. IF INDIAN, ALOTTEE OR TRIBE NASIE O,L ~ GAS ~-~ 'WELL WELL OTHER 2, NAME OF OP~TOR 8. ~'IT,F~M OR LEASE N.~ME Pan American Petroleum Corporation MGS State 17595 ~'~ ADDRESS OF OP~TOR 9. %VELL NO. P. O. Box 779 - Anchorage, Alaska 99501 4. LOCATION C~F WELL Leg 2, Slot 2, MGS Platform 'B'; 1989' FNL, 588' FWL, Section 31, TgN, R1ZW, S.M. 13 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOq~I'OM HOLE OBJECTIVE ) Sec. 31, T9N, R12W, S. Mo 1~,. PEI:LMIT NO. 67-49 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SI~E, CASING AND C~--WIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFOP~ATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHiER SIGNIFICANT CIiA/~ES IN HOL~ CONDITIONS. tz/31 Released rig and flow tested. lZ/1-z lz/3-4 12/5 lZ/6-7 12/8 1Z/9-1t 12/12-14 12/15 lZ/16-ZO 12/21-29 Perforated intervals between 6535' and 6935' and ran DST #4 with packer at 6510'. Perforated intervals between 6215' and 6270' and ran DST #5 with packer at 6195'. Set retainer at 6200' and squeezed with 100 sx at 1000 psi. Perforated intervals between 5760' and 5910' and ran DST #6 with packer at 5745'. Set packer at 6165' and squeezed perforations 6215-6270' with 100 sx. Drilled retainers and cement to 7000' and scraped 9-5/8" casing to top of 7" liner at 8806'. Pressure tested perforated intervals between 6215' and 6935'. Set retainer at 6765' and squeezed perforations 6825-6935' with 75 sx at 1300 psi. Set RTTS packer at 6497' and squeezed perforations between 6535' and 6580' with 150 sx. ]Broke down formation at 1800 psi, final squeeze pressure 2000 psi. Pressure tested at 500 psi for 5 hours. Perforated intervals between 7195' and 10,535'. Ran, set and tested dual tubing strings and packers. 14. I hereby certify that the foregoing is ~ co/feet ' smmm ~'~ '/~. ~'/2)//~Z'-~: =r=Ass't-ireaAdmin. Supvr~,.,.~ 1/5/68 , i' , ~ ' - - ~['~' NOTE--Report on this form is re~,~ed for each calendar month, regardless of the status of operations, and must be filecJ i~ duplicate, with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No, P---4 i%EV, 9-30-67 STATE OF ALASKA SUBMIT IN DEPLICATE O~L AND GAS CONSERVATION COMMITTEE tMONTHLY REiPORT OF 'DRILLING AND WORKOVER OPERATIONS ~. API NUAIERICAL CODE 50-133-20039 ADDRESS oF OPERATOR P. O. Box 779 - Anchorage, Alaska 99501 6. LEASE DESIGNATION AND SERIAL NO. ADL- 17595 1. 7. IF INDIAN, ALOTTEE OR TRIBE NAME OIL I~ GAS ~-~ WELL WELL OTHER 2. NAME OF OP~I~ATOR 8. U-NIT,F.kl:LM OR LEASE N.~ME Pan American Petroleum Corporation MGS State 17595 9. WELL NO. 13 4. LOCATiON O'F Leg Z, Slot 2, MGS Platform B; 1989' FNL, 588' FWL, Section 31, T9N, R1ZW, S. 10. FIELD AND POOL. OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. ~BOT~i'OM HOLJg ' OBJ~CTrVE ) Sec. 31, T9N, R12W, S.M. 12. PER/VIIT NO. 67-49 13. REPORT TOTAL DEPTH AT F_2XID OF MONTI-I, CHANGES IN HOLE SI~E, CASING AlkrD CE!VIENTING JOBS INCLUDING DEPTH SET A/XED VOLLTiVIES USED. PERFORATIONS, TESTS AND RESULTS, FISYIING JOBS. JLrNK IN HOLE AND SIDE-TRACKED HOLE AND A-NY OTHZEt{ SIGNIFICANT CI-IAN~ES IN HOL~ CONDITIONS. 11/30 - PBTD 10, 638', Testing. 11/1-11/3 11/4-i!/6 11/7- it/J6 11/17 11/18-it/zi n/zz-n/z7 11/28 11/29-11/30 Drilled 8-5/8" hole 9123-9579' and logged. TD 9579'. DST ~1 8904-9579'. Drilled 8-5/8" hole 9579-10, 69:1' and logged. TD, 10,691'. Set 7" liner 8806-10,690' with 420 sacks. PBTD 10,638'. Cleaned out cement, perforated intervals between 10, 035' and 10, 110' for DST #2. PBTD 6400'. Set ]BP at 6400', perforated and~ran DST ~3 6160-6400'. 9-5/8" casing was cut at 1042' by worn drill pipe. Cut 9-5/8" casing at 1074' and reran 9-5/8" casing to surface, joining casing with a lead seal overs]~ot type patch seal and tested to 800 psi. PBTD'6400'; squeezed perforated intervals from 6215' to 6370' with 200 sx. PBTD 10,638'. Drilled and cleaned out to 7000' and lost BP at liner hanger. Recovered same; prepared for DST ~4. 14. I hereby certify that t e f going ' true and correct S~NED ~. ~. ~g.o..~. .... T~Tn~Ass't. AreaAdmin. Supvr~A.,.~ 12/11/67 NOTE~Report on this form is required for each calendar month, regardless of the status of operations, ancJ must be fJle~ in IJuplJcat¢ with the Division of Mines & Minerals by the lSth of the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 ~o ~rr,c-_ Anchorage · L[~ Nu~8~ ADL - 17595 L~ aR ..N,, N~MGS State 17595 ';~' LESSEE'S MONTHLY REPORT OF OPERATIONS C6rrected Report s,~, ........... A~._~_s_k_~ .............. ~__ ~oro,~, ................. __K._.e_~_~_ ............. ~,~ ..... ._M_.~.d.d.~.e..._p_r_.o_.~.~..d..p...h..o.~..t_ ..................... TAe followin~ is a coercer report of Operations and produetior, (ir~eludin~ drillir~ and prod~ein~ wells) for tke month of ............... _O..c_.t..o__b...e._r_. ............ 19_.6.7__ .............................................................................. .~I~er~', addre,~ P.O. Box 779 Comnan, Pan American ~etroleum Co'rp. · - ....................................................................... r ~ ............. ('~ -2~~ ~ ~' ................. f ..... ~ ................. .............................. 'd ' " ' / ~ ........... ........................................... _ _A_ _n_ _ _c_ _h_ _o_ _r_ _ _a_ g e ~ Alaska $~...n, ed ............ ___-rr~____Z.%_'.._~_~__~._~.~_ e~o,~, ................................ g.?_A-.g_~__7__~__ ................................. .~,,~, ~ ,~a, .b_.~.~..t__._.Ar_e_~_A~..m..~._~__.s..~r.~: BHL: SW N . . SEC. AND WELL D~eS Baa~ELS Or Om O~Amtr Cu. Fr. or Oxs OALLONS OF BARREm O~ REMARKS ~ Og ~ - TWP. RANGE ~ NO. Paov*c=v (~ thomaS) OASOLINE WATER (If (If ~llinz. depth: if shut down, RECOVERED none, so state) ~te ~d r~ult of t~t for g~ol~e '~ aon~t of .......... . .... ~ 30 9N [2W 10 3 96 37 27 0 0 Produced from Units, Kenai Sar G Unit conglome 10131 - PBTD 11 403', jar~'ing on packer. / , 10/ I2 - PB~YD 11 403', mox'e on workover ~ig. 10/14-1~/ 30, pul.ed short a.nd intermediat{~ strings and attempted to Pull lcng string. 0 0 o 0 o 0 10/31 -TD 8976 , drilling. .. 10/1-10/29 drilked to 892 ~'; lo~[ged and s,et 9-5/8" casing at 8920' witt 1700 sx. 10/30 - dri.!ed out below 9-5/8' casing. ......... NE NW 9 See NOTE.--There were .P...r..0..d...u...c..t..i..o...n.....P...a.g.e. ..... runs or sales of oil; ................... NO. ...................... M cu. ft. of gas sold; ........................ ..N..0.. ............................. 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 &F and e be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, un~s~t~er[~i.~ ~}, [~ directed. I\ Lk~ L/ V . - . . NOV 9 1967 DIVISION OF' MINES & MINEtb~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE LAND ~,~E Anchorage ~, ~EA~N,,~ ~L- 17595 175~ L~^s~ o~ uN,~MGS State LESSEE'S MONTHLY REPORT OF OPERATIONS BHL NE State .............. _A__l__a__s___k__ _a_ .............. Bi, rough .............. __K_?. _ .n_._a__J: ................ Field ...... M~ ~_~ ~___9_~ ?~_~ _ .~_~_~ ~ 3_ ..................... T]~e followin~ is a eorreot repor~ of operations and production (inel~din~ drillin~ and prod~ein~ wells) for tke montk of ........... ......... ,19_6__7_ .............................................................................. ................................................................... Company Pan American Petroleum Corp. ......................................... .............. ..... Pl~one .............................. _2__7_2._.-__8__4__7__1._ ................................... Jl~ent's title Ass-~--X~-ea kdr~-:--~-~-~'~'-. ., eEC. AND BARRELS OF OIL (~RAVIT¥ OA$OLINE WATER (If (If ~lHng, depth; If shut down, oa~; ~ Or ~ TwP. RANGE WrLL DaYs Cu. FT. Or GAS GA~ONS OF BARRr~ Or RE~ARKS No. Pao~c=~ (~'tho~) RECOVERED none, so s~te) da~ ~d r~ult of trot for g~o~e oon~t of ~) lW 31 9N [2W 13 0 0 0 0 0 0 AP1 50-133-2003 10/1 - TD t,445', coring. 9/~ - 9/11 ~- SFudded and drill,~d to 620';'set 20" casing at 595' ~ith 1~85 sx. 9/]2 - 9/lt - [)rilled to ~015' md set 13-3/8" caling at 2)12' ~'ith ]900 sx. 9/]7 - 9/3C - [)rilled 2015' to 5445'. . --_ See Pa e 1 No NOTE.--There were ....................... .g ...................... runs or sales of oil; ................................................ 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 filed in duplicate with the Division of Mines & Mi~rall.s~y[~,h., ~t~ [~f [~e succeeding month, unless otherwise directed. [~ [~ ~' [~~ . Page 3 of 3 P. O, Box 779-' Anchorage, Alaska 99501 ""-':-September.12, 1967 .. · -_ .-. ~ :' : ,- · ... File: FKK- 1213-WF . · Re:." Spud NeW Well MGS State 17595 Well No 13 Director Division of-Lands' State of Alaska .a~_oen~ of Natural:Resources 34.~ ~ +~ o ~ Avenue Anchoraze Alaska - :. Dear- Sir: ~qis is to notify you that the subject well was spudded State Lease ADL-t7595:at 1930 hours on September 9, 1967. surface location of ~this-well is at SW/4 NW/4, Sec. 31, T 9~. R- 12-W~ S.M. :-- . . We oian to drill this:'Well directionally to a bottom hole location of NE/4 ~%Z/4, Sec'. 31, ~T-9-N, R-!2-W, S.M. Very truly yours, ~ ~F. K, Krebill .. Area Superintendent :' . FORM ~470 PANAMERICAN PETROLEUM CORPOP. ATION 1~. O. Box 779 Anchorage, Alaska 99501 September 7, 1967 File: FKK-1177-WF Re' MGS State 17595 #13, API 50-133-20039 Mr. Thomas R. Marshall, Jr. Division of Mines & Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: Enclosed is a corrected drawing of the surface location, Leg 2, Slot 6, from which MGS State 17595 Well No. 13 will be drilled. Oar original drawing showed Leg 2, Slot 2. Yours very truly, C. K. Dietz Ass't. Area Admin. Supvr. Attachment RECEIVED SEP 8 l~§l" DIVISION OF MINES & MINEJitAL$ ANCHORAGE ~--.. ~ % APT 50-.133.-20039 NO APPLICATION FOR PERMIT TO DRILL; DEEPEN, OR' PLUG;BA~K, ~',,:~, ',~. ~ ' la. OIL ~ OAS ~ SINGLE WELL Lt.t_l . WELL OTHER ZOI~E NAME OF:'O~E~A~E~ , ~ . :.~ ~ ... :'~;' f~- ?'.< f'. Pan American Petroleum Corporation P. O. Box 779, Amchorage, Ala~skwg-950~l ....... ~ .... 4. LOCATION,~OF WEI, r,- (Report location cica.rift, and in accordance .with~anY-State .requirements.* ) At surface 1989~,~FNL,-,588' FWL Sec.-31 .TgN ~R12W SM ............. ~.~ At proposed prod. zone 660' ~NT. ~650' FWT. ~ec- .3] TON R]?W SM 14. DISTANCE IN- M~]~S AND DIRECTION PROM NEAREST TOWN OR POST OFFICE* 20 Miles NW of Kenai 1~. DISTANCE FROM PROPOSED* LOCATIO~ To NEAREST 3630' East to ADL . PROPERT]~ OR LEASE LINE, PT. (Also to nearest drlg. unit llne~ if any) 18747 Ia. DmTANCE PROM PROPOSED LOCATION* 1256' South TO NEAREST WELLi DRILLING, COMPLETED, OR APPUED FOR, OH THIS LRASE, I~f~ 718 ' .West to MGS 21. EL~VATIONS (Show whether DF, RT, GR, etc.) MULTIPLE ~ 8. FARM oR .LEASE'iNAME ZONE '-~ MGS state"17595~ 9..W~,~NO. ' .......... I0.- ~E~V'~ A~ 'PoOr,,'~Oa ~iddle ~OUnd Shoal 1~. SEC., T., R.,. M., OR ELK. BHL: Sec. 31 TgN Ri2W S~ 16. NO. OF ACRES IN LEASE 5106 19. PROPOSED .DEPTH State 9800 12. B. ORO'UGH Kenai 17. NO. OP ~C~S ASSIGNED THIS W~LL 80 20. ROTAB¥.'OR 'CABLE ToOLs Rotary 13. STATE Alaska 17595 ~A4 I 22~. APPROX. DATE WORK WII~L START o 78.75' above MSL Aug. ,8, 1967 23. pROPosED, CASING AND:., bEMENTING PROGRAM sIZE OF HOLE SIZE OP CASING SETTING DEPTH ~UANTITY OP C~MEN~, 20" 13'3/8" 9-5/8" WEIGHT PER FOOT 85.01~) 54 ~A 40f/ & 43~/ 600 200O 9800 CircUlate to surface circulate to surface Minimum of 500' above shoe; Additional cement may be used d~pending upon electric log interpretation. Reason for deviation: To reach BHL from. permanent platform There are no affected' operators. Intervals of interest will be perforated and may be stimulated. BOP arrangement attached. IN ABOVE SPACE DESCRIRE PROPOSED PROORAM: If 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 vdrtical depths. ' Give blowout preventer program, ff any. Asst. Area Admin Supvr. (This' space for Federal or State office u~) DATE' August ~2!~, 1967 APl 50-133-20039 *See Instructions On Reverse Side Au6 2 4,1967 I~IVI$10N OF MINES & MINEIba~ dim enSion$_ -¢ . 2" Check Valve Spool ~ ! I 't"s. _ z ~.-~.u Valve / Plug or Gal;e .Valve --+---Pipe Rams tga~e valve 4" plug vaive 4" line w/shop made swae~ w/no more chart 45° 'bend lank t-2" Plug Valve on side ouc t'et . Equipment below ~his point___ furnished by Pan ~n. ~ 2" choke plug valve ~ 2" line i. All preventors to be hydraulically operated from an accumulator which will open and close hydrit au l'e'ast three times ~withoug recharging. 2. All equipment thru which bit must pas's to have at lea'~'~ as l'arg'~--~D-"~]"-iasi, ng bein~ dr-,~ ].~ed through. 3. Kelly cock to be on Y. eily from time of spud. 4. Drill pipe safety valve equivalen~ to Shaffer' Mo~. 55 or OMSC0, with proper connections, ~o ba on rig floor ac all gimes o 5. All equipment mentioned above co be 5000~ WP or stronger. 6. All connections to be flanged. 7. Operating manifold to be in easy reach of drillers sgation w/~ remo=u operating sga~iono · R ECEIVED 4.1967 l)1¥151ON OF MINES & MINEIJAI~ ANCHORAGE LocA--TI o D.~ P AUG DIVISION OF MINES & ANCHORAGE
