Horizontal San Andres Play
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1 Horizontal San Andres Play Russell K. Hall Presented at the CO 2 & ROZ Conference Dec 5, 2018 Midland, Texas
2 CO 2 Recovery Conference Permian Basin Trends Horizontal San Andres Play
3 PERMIAN BASIN TRENDS Economic Return is Key Driver of Drilling
4 POSTED OIL PRICE
5 600 PERMIAN BASIN RIG COUNT TOTAL PERMIAN BASIN HORIZONTAL RIGS VERTICAL RIGS
6 PERMIAN BASIN RIG COUNT Midland and Delaware Basin Drilling TOTAL PERMIAN BASIN HORIZONTAL RIGS VERTICAL RIGS
7 100% 90% 80% PERMIAN BASIN HZ RIGS 9 OF 10 RIGS DRILL HORIZONTAL WELLS 70% 60% 50% 40% 30% 20% 10% 0%
8 PERMIAN BASIN TRENDS Economic Return is Key Driver of Drilling Stimulation Costs Have Risen Substantially
9 PERMIAN BASIN TRENDS Economic Return is Key Driver of Drilling Stimulation Costs Have Risen Substantially Drilled Uncompleted Wells Not As High As Typically Reported
10 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (1) 100 2, , , , , , POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR)
11 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (2) 100 2, , , , , , POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR)
12 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (3) 100 2, , , , , , POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR)
13 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (4) 100 2, , , , , , POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR)
14 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (5) 100 2, , , , , , BUILDING INVENTORY 0 (DRILLED UNCOMPLETED WELLS) POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR) 200
15 POSTED OIL PRICE ($ PER BBL) WELL COUNT (PER QUARTER) PERMIAN BASIN TRENDS (6) 100 2, , , , , , BUILDING INVENTORY 0 (DRILLED UNCOMPLETED WELLS) POSTED OIL PRICE HZ PERMITS HZ SPUDS HZ COMP (SHIFTED 1 QTR) 200
16 PERMIAN BASIN TRENDS (7) The number of drilled, but uncompleted (DUC) wells in the Lower 48 U.S. states seven most productive basins/plays rose by 3.3% from September to October. The increase occurred despite three of the seven areas reporting a drop in DUCs, according to the November issue of the Energy Information Administration s Drilling Productivity Report (DPR). The DPR reveals 269 DUCs were added to the September total of 8,276. The new total is 8,545, as of Oct. 31, Kallanish Energy reports. The biggest increase by far from September to October was in the Permian Basin, up 249 drilled, but uncompleted wells, 6.9%, to 3,866, from 3,617. The Anadarko was the closest basin/play to the Permian, up 41 DUCs, or 3.9%, from September to October, to 1,084, the DPR reveals. The three drilling areas which recorded a month-to-month drop in DUCs were Appalachia (the Marcellus and Utica Shale plays), Bakken and Niobrara, down 19, 20 and 14 DUCs, respectively, to 623, 797 and 401, respectively. The Eagle Ford play saw a 25-DUC increase, to 1,571, while the Haynesville Shale recorded a seven-duc increase, to 203.
17 PERMIAN BASIN TRENDS (8) The biggest increase by far from September to October was in the Permian Basin, up 249 drilled, but uncompleted wells, 6.9%, to 3,866, from 3,617.
18 PERMIAN BASIN TRENDS (9) The biggest increase by far from September to October was in the Permian Basin, up 249 drilled, but uncompleted wells, 6.9%, to 3,866, from 3,617.
19 PERMIAN BASIN TRENDS (10) PERMIAN BASIN HORIZONTAL DRILLING FROM 1/1/2009 THROUGH 9/30/2018 SPUD WELLS 23,344 COMPLETED OR PRODUCING WELLS 20,763 TREATED WELLS (PER IHS) 485 DRILLING WELLS (RIG COUNT) 493 CORRECT DRILLED UNCOMPLETED WELLS 1,603 DATA EXCLUDES PILOT WELLS
20 Why Is Industry Reporting DUC Wells Incorrectly? PENDING WELLS
21
22
23
24
25
26
27 WELL PRODUCED 80 BARRELS IN 9/2018
28
29 NO COMPLETION REPORT ON FILE
30 AN UNCOMPLETED WELL (DUC)???
31 Operators Sometimes Wait Several Months to File a Completion Report
32 DRILLED UNCOMPLETED WELLS (RKH CORRECTED TRRC DATA)
33
34 Horizontal San Andres Play
35 Horizontal San Andres Reservoir Is Complex!
36 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept
37 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept Diagenetic Changes May Be More Important Than Depositional Environment
38 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept Diagenetic Changes May Be More Important Than Depositional Environment Controlling Frac Growth Is Paramount For Successful Oil Production
39 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept Diagenetic Changes May Be More Important Than Depositional Environment Controlling Frac Growth Is Paramount For Successful Oil Production Gas Content Strongly Influences Recovery Efficiency
40 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept Diagenetic Changes May Be More Important Than Depositional Environment Controlling Frac Growth Is Paramount For Successful Oil Production Gas Content Strongly Influences Recovery Efficiency Not All Areas Are The Same
41
42
43 SAN ANDRES PLAY NORTHWEST SHELF CENTRAL BASIN PLATFORM 49,300 WELLS 3,000,000 + ACRES 6.49 BILLION BARRELS CUM OIL
44 HZ WELLS (1)
45 HZ WELLS (2)
46 OIL PRODUCTION (BARRELS PER DAY) GAS PRODUCTION (MCF PER DAY) Well Count 100,000 HZ SAN ANDRES PRODUCTION (ALL) 10,000 10,000 1,000 1, GAS PRODUCTION OIL PRODUCTION WELL COUNT
47 OIL PRODUCTION (BARRELS PER DAY) GAS PRODUCTION (MCF PER DAY) Well Count 100,000 CENTRAL BASIN PLATFORM PRODUCTION 10,000 10,000 1,000 1, GAS PRODUCTION OIL PRODUCTION WELL COUNT
48 OIL PRODUCTION (BARRELS PER DAY) GAS PRODUCTION (MCF PER DAY) Well Count 100,000 NORTHWEST SHELF PRODUCTION 10,000 10,000 1,000 1, GAS PRODUCTION OIL PRODUCTION WELL COUNT
49 HZ SAN ANDRES OPERATORS JULY 18 OIL PRODUCTION APACHE 1% CONCHO 2% HADAWAY 1% MACK ENERGY 2% OXY 1% WISHBONE 9% OTHERS 13% LIME ROCK 9% PACESETTER 1% PARALLEL 2% WALSH 6% RILEY 10% STEWARD 24% SHERIDAN 5% RING 13% SABINAL 1%
50 PLATANG FIELD
51 Typical Well Performance (1)
52 Typical Well Performance (2) Depressurizing Near Wellbore
53 Typical Well Performance (3) Increasing Oil Cut
54 Typical Well Performance (4) Stabilized Oil Cut
55 OIL PRODUCTION (BARELS PER DAY) GAS PRODUCTION (MCF PER DAY) WELL COUNT 1,000 NORTHWEST SHELF PLATANG FIELD 1 MILE LATERALS NORMALIZED PRODUCTION 10, , TIME (MONTHS) 1 MILE LATERAL OIL PRODUCTION 1 MILE LATERAL GAS PRODUCTION 1 MILE WELLS
56 BARRELS OF OIL PER DAY Oil Performance 1, DAYS OF PRODUCTION P10 P50 P90 WELL COUNT USED
57 Oil Performance/1000 Lateral Length Platang Field Using 1-Mile Laterals -2 P2 Lognormal regression Input data samples 128,093 P5 P10 P10 / P90 SLOPE = 2.88 P20 P30 81,973 75,494 P42.1 P40 P50 P60 P70 P80 44,494 P90 P95 Swanson's Mean P98 1,000 10, ,000 1,000,000 EUR (barrels)
58 Oil Performance/1000 Lateral Length Platang Field Using 1-Mile Laterals -2 P2 P5 Lognormal regression Input data samples 128,093 P10 P10 / P90 SLOPE = 2.88 P20 P AVG EUR 67,900 BBL/1000 FT 81,973 75,494 P42.1 P40 P50 P60 P70 P80 44,494 P90 P95 Swanson's Mean P98 1,000 10, ,000 1,000,000 EUR (barrels)
59 OIL PRODUCTION (BARELS PER DAY) GAS PRODUCTION (MCF PER DAY) WELL COUNT 1,000 NORTHWEST SHELF PLATANG FIELD 1.5 MILE LATERALS NORMALIZED PRODUCTION 10, , TIME (MONTHS) 1.5 MILE LATERAL OIL PRODUCTION 1.5 MILE LATERAL GAS PRODUCTION 1.5 MILE WELLS
60 OIL PRODUCTION (BARELS PER DAY) GAS PRODUCTION (MCF PER DAY) 1,000 NORTHWEST SHELF PLATANG FIELD - 1 MILE VS 1.5 MILE LATERAL NORMALIZED PRODUCTION TIME (MONTHS) 1 LATERAL OIL PRODUCTION 1.5 MILE LATERAL OIL PRODUCTION
61 OIL PRODUCTION (BARELS PER DAY) GAS PRODUCTION (MCF PER DAY) 1,000 NORTHWEST SHELF PLATANG FIELD - 1 MILE VS 1.5 MILE LATERAL NORMALIZED PRODUCTION MILE LATERALS REQUIRE TIME TO DEPRESSUREIZE 1 ENTIRE WELL BORE TIME (MONTHS) 1 LATERAL OIL PRODUCTION 1.5 MILE LATERAL OIL PRODUCTION
62 COUNTY LINE AREA
63 OIL PRODUCTION (BARRELS PER DAY) GAS PRODUCTION (MCF PER DAY) 1000 COUNTY LINE AREA 1 MILE LATERAL NORMALIZED DAILY PRODUCTION TIME (DAYS) OIL PRODUCTION GAS PRODUCTION
64 HZ San Andres Performance 5% to 10% Oil Cut 10% to 30% Oil Cut OIL CUT
65 TYPICAL WELL COUNTY LINE AREA SA P1 SA P2 SA P3 SA P4
66 SA P1 SA P2 SA P3 SA P4
67 GR LOG SA P1 SA P2 SA P3 SA P4
68 PE LOG SA P1 SA P2 SA P3 SA P4
69 POROSITY LOGS SA P1 SA P2 SA P3 SA P4
70 RESISTIVITY LOGS SA P1 SA P2 SA P3 SA P4
71 PE CURVE PARTIALLY DOLOMITIZED SA P1 SA P2 SA P3 SA P4
72 PE CURVE SA P1 FULLY DOLOMITIZED SA P2 SA P3 SA P4
73 PE CURVE SA P1 DIAGENETIC FACIES CHANGE SA P2 SA P3 SA P4
74 PE CURVE SA P1 DIAGENETIC FACIES CHANGE THIS IS LOWER / HIGHER IN SA P2 EACH WELL SA P3 SA P4
75 POROSITY LOGS DIAG 10% PHI
76 POROSITY LOGS DIAG 10% PHI
77 POROSITY LOGS LOWER POROSITY LOWER PERM DIAG 10% PHI
78 POROSITY LOGS LOWER POROSITY LOWER PERM DIAG HIGHER POROSITY HIGHER PERM 10% PHI
79 DIAG WHY IS THIS INTERVAL MORE DOLOMITIZED?
80 DIAG MORE VOLUMES OF SWEPT WATER (DIAGENESIS)
81 DIAG WATER MOVEMENT SWEPT LIGHTER HYDROCARBONS (METHANE)
82 DIAG THEREBY REDUCING DISSOLVED GAS (STORED ENERGY)
83 DEPRESURIZATION TARGET DIAG
84 PICKETT PLOT
85 HIGHLY DOLOMITIZED INTERVAL
86 SLIGHTLY DOLOMITIZED INTERVAL
87
88 GAINES COUNTY ANDREWS COUNTY
89 OIL PRODUCTION (BOPM) 10,000 CENTRAL BASIN PLATFORM SELECTED OPERATORS NORMALIZED OIL PRODUCTION 1, TIME (MONTHS) PARALLEL (9W) LIME ROCK (75W) PACESETTER (13W) RING (68W)
90 GAS TO OIL RATIO (SCF / STB) 1, NORMALIZED GAS-TO-OIL RATIO TIME (MONTHS) PARALLEL (9W) LIME ROCK (75W) PACESETTER (13W) RING (68W)
91 OIL CUT 40% 35% AVERAGE OIL CUT 30% 25% 20% 15% 10% 5% 0% TIME (MONTHS) PARALLEL (9W) LIME ROCK (75W) PACESETTER (13W) RING (68W)
92 ANDREWS COUNTY WELLS (1) OIL EUR (BBL) GAS EUR (MCF) 1ST YR OIL CUT WELLS PARALLEL PETROLEUM 286, , % 9 LIME ROCK RESOURCES 183, , % 75 PACESETTER ENERGY 235, , % 13 RING ENERGY 165,000 56, % 68
93 ANDREWS COUNTY WELLS (2) OIL EUR (BBL) GAS EUR (MCF) 1ST YR OIL CUT WELLS PARALLEL PETROLEUM 286, , % 9 LIME ROCK RESOURCES 183, , % 75 PACESETTER ENERGY 235, , % 13 RING ENERGY 165,000 56, % 68
94 PARALLEL PETROLEUM COMPLETION PROCEDURE (1)
95 PARALLEL PETROLEUM COMPLETION PROCEDURE (2) EVENLY SPACED PEFORATIONS
96 PARALLEL PETROLEUM COMPLETION PROCEDURE (3) PERFORATIONS TARGET SIMILAR ROCK
97 PARALLEL PETROLEUM COMPLETION PROCEDURE (4) HIGH FRAC INITIATION PRESSURE
98 PARALLEL PETROLEUM COMPLETION PROCEDURE (5) HIGH FRAC INITIATION PRESSURE FRAC GOES ONLY INTO THESE PERFS
99 PARALLEL PETROLEUM COMPLETION PROCEDURE (6) HIGH FRAC INITIATION PRESSURE FLUID IS PUMPED INTO FEWER PERFS THAN PLANNED AND FRAC GOES OUT OF ZONE
100 PARALLEL PETROLEUM COMPLETION PROCEDURE (7) HIGH FRAC INITIATION PRESSURE FRACTURE COMMUNICATES WITH UNDERLYING INTERVAL (LOW GOR, HIGH WATER CUT)
101 HZ San Andres Completions Fracs Tend Towards Downward Growth (Path of Least Resistance) Permeability Increases with Depth Deeper Formations have Higher Water Saturation? Deeper Formations have Lower GOR? Stimulations Out of Zone Make LOTS of Water
102 ROZ Depressuring
103 Gas to Oil Ratio (GOR) After Producing 1 Year
104 Gas to Oil Ratio (GOR) After Producing 1 Year PLATANG AREA SHAFTER LAKE AREA
105 Gas to Oil Ratio (GOR) After Producing 1 Year AVERAGE GOR 1,139 scf/stb AVERAGE GOR 429 scf/stb
106 PRIMARY RECOVERY FACTOR (percent) 25.0 RECOVERY FACTOR vs INITIAL GOR RESERVOIR ASSUMPTIONS POROSITY 10% PERMEABILITY 1 md OIL SATURATION 75% WATER SATURATION 25% ORIGINAL BHP 2,200 psia DEPTH 5,000 ft RESERVIOR TEMPERATURE 115 THICKNESS 50 ft INITIAL GAS TO OIL RATIO (scf/stb)
107 PRIMARY RECOVERY FACTOR (percent) 25.0 RECOVERY FACTOR vs INITIAL GOR , INITIAL GAS TO OIL RATIO (scf/stb)
108 PRIMARY RECOVERY FACTOR (percent) % RECOVERY FACTOR vs INITIAL GOR INITIAL GAS TO OIL RATIO (scf/stb)
109 PRIMARY RECOVERY FACTOR (percent) 25.0 RECOVERY FACTOR vs INITIAL GOR INITIAL GAS TO OIL RATIO (scf/stb)
110 PRIMARY RECOVERY FACTOR (percent) 25.0 RECOVERY FACTOR vs INITIAL GOR % INITIAL GAS TO OIL RATIO (scf/stb)
111 Reservoir Fluid Properties Change in GOR (1,139 to 429) Results in 11% Drop in Recovery Factor However GOR Change May Have a MORE PRONOUNCED Effect Due to ROZ Depressurization Source Melzer
112 Horizontal San Andres Reservoir Is Complex! Data Strongly Supports ROZ Concept Diagenetic Changes May Be More Important Than Depositional Environment Controlling Frac Growth Is Paramount For Successful Oil Production Gas Content Strongly Influences Recovery Efficiency Not All Areas Are The Same
113 Thank You Russell K. Hall, P.E. Russell K. Hall and Associates, Inc. Midland, Texas
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