ynuwara/spe_mcq_dataset · Datasets at Hugging Face

number int64 1 100	question stringlengths 21 1.02k	A stringlengths 1 137	B stringlengths 1 123	C stringlengths 2 142	D stringlengths 2 97	correct_answer stringclasses 4 values	figure imagewidth (px) 184 2.53k ⌀
1	Which of the following factors has the LEAST impact on casing seat selection?	Rate of Penetration	Pore pressure	Kick tolerance	Fracture gradient	A	Not supported with pagination yet
2	When considering calculation methods for survey points, the LEAST precise method is:	Circular arc	Minimum curvature	Radius of curvature	Tangential	D	Not supported with pagination yet
3	Which of the following is NOT a typical purpose for a BHA?	Assure casing can be run into a hole	Control direction and inclination in directional holes	Increase severity of doglegs, keyseats and ledges	Protect the drill pipe from excessive bending and torsional loads	C	Not supported with pagination yet
4	Which of the following is a typical characteristic of plug flow cement placement?	Reynolds number less than 100	Large cement volumes	High displacement rates	Short cementation times	A	Not supported with pagination yet
5	Which of the following is NOT a typical cause for a fishing job?	Cementing error	Differential sticking	Swelling zone	Use of oil-base mud	D	Not supported with pagination yet
6	Which of the following is NOT a component of the hoisting equipment for a drilling rig?	Crown block	Drawworks	Drilling line	Rotary table	D	Not supported with pagination yet
7	Which of the following is NOT a primary function of drilling fluids?	Cuttings removal	Frac proppant	Lubrication and cooling	Well control	B	Not supported with pagination yet
8	Which of the following methods is MOST likely to hydrostatically balance a well kick with only one circulation?	Concurrent	Driller’s	Toolpusher’s	Wait and weight	D	Not supported with pagination yet
9	Critical rotary speed longitudinally (rpm) is calculated by rpm = 258,000/L, where L is the total length of the drill string (ft). Which of the following is a multiple of rpm* at which secondary and higher harmonic vibrations will occur?	2	8	16	32	C	Not supported with pagination yet
10	Which of the following is NOT a colloidal polymer?	Xantham gum	Starch	Sodium carboxy methyl cellulose	Hydroxyethyl cellulose	A	Not supported with pagination yet
11	Which of the following is a major consideration for cuttings transport in horizontal wells?	Annulus size	Drilling Rate	Eccentricity	Rotary speed	C	Not supported with pagination yet
12	Which of the following is NOT a routine roller cone bearing package description?	Friction-ball-friction	Friction-ball-roller	Roller-ball-friction	Roller-ball-roller	B	Not supported with pagination yet
13	In comparing the API specs for L-80 and N-80 tubulars, which of the following statements is TRUE?	Minimum yield strength is different	Maximum yield strength is the same	Minimum tensile strength is different	Minimum elongation is the same	C	Not supported with pagination yet
14	Which of the following is NOT a typical separator type?	Horizontal	Slant	Spherical	Vertical	B	Not supported with pagination yet
15	Which of the following is NOT a typical casing hanger type?	Slip-weld	Nominal flange	Boll-weevil	Automatic	B	Not supported with pagination yet
16	The control pressure for a surface safety valve is most likely equal to:	Valve body pressure divided by actuator ratio	Actuator ratio divided by valve body pressure	Two times valve body pressure divided by actuator ratio	Valve body pressure multiplied by actuator ratio	C	Not supported with pagination yet
17	The material for sealing element when approaching 450 degrees F (232 degrees C) and 15,000 psi (103,422 KPa) differential is MOST likely:	Glass-filled Teflon	Kalrez	Nitrile	Viton	A	Not supported with pagination yet
18	Tubing elongation MOST likely occurs with:	Ballooning	Buckling	Reverse Ballooning	Temperature Reduction	C	Not supported with pagination yet
19	Which of the following is NOT an API classification for oil well pumps?	Tubing type with extension shoe and nipple	Tubing type, traveling barrel with bottom hold-down	Rod type, stationary barrel with top hold-down	Rod type, traveling barrel	B	Not supported with pagination yet
20	Which of the following has the LEAST volumetric efficiency for rod pumped wells?	High fluid level with no gas interference	Gaseous wells with fair downhole separation	Foamy liquid or gaseous conditions	Ample pump submergence with good separation	B	Not supported with pagination yet
21	A caliper survey has been run on a producing gas well. It shows that the casing is partially collapsed 500 ft (152.4 m) above the perforations. The well is starting to load up with fluid, so a decision has been made to install a small diameter tubing string with a packer set just below the partially collapsed interval to protect the casing from pressure, temperature fluctuations and other forces that could result in further collapse. What type of packer should be used in this application?	Weight-set packer	Tension-set packer	Rotation-set packer	Hydraulic-set packer	D	Not supported with pagination yet
22	A platform is producing surplus gas that must be sold into a nearby pipeline; flaring is not permitted. The gas has the following characteristics: gas gravity = 0.689 SG (Air = 1), ratio of specific heats = 1.206, molecular weight = 20, supercompressibility factor = 0.022. Wells on the platform produce a total of 18 mmcfd (509,703 m^3/d) dry gas (after separation and dehydration). Platform fuel use is 6 mmcfd (169,900 m^3/d). The gas is cooled after leaving the dehydrator to a temperature of 60°F (15.6°C). Pressure at the gas cooler outlet is 227 psig (1,565 KPa). Pipeline pressure is 1,050 psig (7239 KPa). What minimum horsepower, hp, would be required to compress the surplus gas from this platform for sale into the pipeline?	1,191	1,238	1,787	2,649	A	Not supported with pagination yet
23	What type problem does the below dynamometer card indicate that would cause an excessive number of rod parts in the lower portion of the rod string in this well?	Excessive friction	Overtravel	Plunger sticking	Fluid pound	D
24	A well is to be fracture stimulated down the production casing with the following conditions: Fracture propagation gradient: 0.95 psi/ft (2.19 SG) Near well pressure losses: 1,000 psi (6,895 KPa) Casing friction pressure losses: 1,600 psi (11,032 KPa) Surface piping friction losses: 300 psi (2,068 KPa) Stimulation rate: 65 bbl/minute (10.33 m^3/min) Perforations: 18,100 ft (5,517 m) MD/16,100 ft (4,907 m) TVD Fluid Density: 8.5 lbm/gal (1.02 SG) 50% Standby Horsepower on location Pump truck rated horsepower: 2,000/truck. Assume 85% Pump Efficiency How many pump trucks will be required?	11	14	16	17	C	Not supported with pagination yet
25	A 10,000 HP compressor bank is going to be added to a large pipeline compressor station. An inlet meter station is located 1,200 ft (366 m) away from the new compressor site. Pressure at the meter run is 60 psig (414 KPa). Gas from the meter station will be used for fuel. The gas pressure at the fuel line header inside the new compressor site is specified at 26 psig (179 KPa). The gas will be at 60°F (15.6°C). Assume fuel usage will be 240 scfd (6.8 m^3/d) per HP for the new compressors. What minimum diameter, in/(mm) fuel line should be installed to provide fuel gas to the new compressor site from the meter run?	1.5 (38)	3.5 (89)	5 (127)	6 (152)	B	Not supported with pagination yet
26	The following readings were made by a field gas technician at a dry gas sales meter. Static pressure: 800 psig (5,516 KPa) Differential: 15-in. (381 mm) H2O Temperature: 130° F (54.4°C) Gas Specific Gravity: 0.62 (Air=1) Meter run: 4.026-in. (102.3 mm) ID Orifice plate: 1.5-in. (38.1 mm) Neglect viscosity, super-compressibility and compression factors (assume each of these equals 1.0). The only impurities are 13 vol-% CO2 and 0.8 vol-% N2. Using standard meter tables Fb: 460.8 Fg: 1.27 Fpb: 1.0000 What is the daily natural gas flowrate, mcfpd (m^3/d), most likely to be on the gas purchasers’ statement using a 14.73 psi (101.5 KPa) pressure base and 60°F (15.6°C) temperature base?	1,152 (32,621)	1,328 (37,605)	1,341 (37,973)	1,458 (41,286)	A	Not supported with pagination yet
27	A gas well with 40 ppm H2S and 14 mole-% CO2 is planned to be produced up a string of tubing cemented in the well as a “tubingless completion” (i.e., the tubing is actually small-diameter production casing). Initial shut in pressure will be 12,000 psi (82.737 MPa). Initial flowing pressure will be 8,000 psi (55.158 MPa). Flowing pressure will decline to 2,000 psi (13.79 MPa) in less than six months. Surface temperature is 75° F (23.9°C). Static bottomhole temperature is 330°F (165.6°C) at 15,200 ft (4,633 m) TVD. Flowing surface temperature is 120°F (48.9°C). Both T95 and P110 tubing (casing) strings are available and will meet all required stress considerations. Your field foreman would prefer to run just one grade of pipe to avoid confusion on the rig. Of the possible recommendations below, what would you recommend to management with your concern being sulphide stress cracking (SSC) of the tubing (casing) string in this well?	The partial pressure of sour gas is not great enough to need T95 grade pipe	Run all P110 grade pipe. Fast pressure decline mitigates problem with SSC	Recommend running T95 to at least 4,348 ft (1,325 m) from the surface	Recommend running T95 to at least 6,250 ft (1,905 m) from the surface	D	Not supported with pagination yet
28	A plug has been set in a profile nipple below a packer in a well. To confirm that the plug will hold, it has been decided to pressure up on the tubing to 9,000 psi (62.1 MPa). The well is standing full of fresh water. The packer is set at 6,000 ft (1,829 m) and has a 3.5-in. (89 mm) bore. The pipe string is all 2 7/8-in. (73 mm) OD, 6.5 lbm/ft (9.67 kg/m) L-80, EUE, 8-round thread tubing equipped with a seal assembly that allows free travel inside the packer bore. A pressure of 1,000 psi (6.9 MPa) will be applied to the tubing x casing annulus. Ignoring temperature and ballooning effects, how far up the packer bore will the seal assembly travel, inches (centimeters), when the pump reaches maximum pressure?	54.7 (138.9)	33.1 (84.1)	28.4 (72.1)	4.6 (11.7)	A	Not supported with pagination yet
29	A tank is filled with produced water with a density of 8.6 lbm/gal (1.03 SG). A decision has been made to use the fluid for a workover, but the density is too low. Brine with a density of 10.0 lbm/gal (1.20 SG) is to be mixed with fluid in the tank until the contents have the proper density for the job. The brine is to be pumped through a nozzle on the end of a pipe to agitate the tank and ensure the fluid is constantly, thoroughly mixed. The nozzle has a diameter of 1/2-in. (12.7 mm) and a pump rate of 200 gal/min (0.757 m^3/min) has been selected. What pressure drop, psi (KPa) can be anticipated across the nozzle under these conditions? Assume a nozzle coefficient of 0.95.	147 (1,014)	188 (1,294)	597 (4,116)	956 (6,588)	D	Not supported with pagination yet
30	A pressure relief valve is needed to protect a petroleum storage tank from over-pressure. The relief valve will discharge into a low-pressure vent system with a constant pressure of 0.5 psig (3.4 KPa). The scrubber on this low pressure vent system cannot handle peak flowrates in excess of 6.0 scfm (10.2 m^3/hr). The relief valve is to be set to allow a 5 psig (34.5 KPa) buildup in the tank with a 1.6 psig (11.0 KPa) setpoint pressure before the relief valve opens. Gas in the tank has a specific gravity of 0.68 (Air = 1.0). The ratio of specific heats of the gas, k = Cp/Cv = 1.10. Assume the relief valve has a coefficient, K, of 5.212 × 10^-4. What diameter relief valve orifice, inches (cm), should be specified for this application?	6.4 (16.3)	6.0 (15.2)	5.8 (14.7)	5.5 (14.0)	B	Not supported with pagination yet
31	You are calculating the original gas in place using the volumetric method. Which of the following has the LEAST influence on the final result?	Connate water saturation	Initial reservoir pressure	Permeability	Porosity	C	Not supported with pagination yet
32	Which of the following is the LEAST likely source for water which encroaches into a reservoir as pressure declines?	Artesian flow	Compressibility of the rock in the aquifer	Expansion of the water in the aquifer	Water coming out of solution from the oil as the pressure drops	D	Not supported with pagination yet
33	Important characteristics of the production history of many coal-bed methane wells include:	Initial large and declining water cuts and low and improving gas production rates	Initial large but declining gas/liquid ratios and low but increasing water production rates	Stabilized gas/liquid ratios and decreasing gas rates	Stabilized gas/liquid ratios and increasing gas and water production rates	A	Not supported with pagination yet
34	There are known effects of gas on logging tool responses. Which of the following statements is correct?	Density log porosities are not affected by gas	Neutron log porosities are increased by gas	NMR log porosities are reduced by gas	Sonic log porosities are reduced by gas	C	Not supported with pagination yet
35	For decline-curve analysis to be accurate, several conditions must be satisfied. Which of the following conditions is not appropriate?	Drainage area of the well remains constant with time.	Skin factor of well is not changing with time.	Well is in transient flow regime.	Well produces at constant BHP.	C	Not supported with pagination yet
36	A pressure buildup test is run on a well producing dry gas. Current average reservoir pressure is about 3,012 psia (20.77 × 10^3 KPa) and the flowing bottomhole pressure at the time of shut-in was 1,126 psia (7.76 × 10^3 KPa). Which of the following statements about analyzing the test data using a semi-log method is most accurate?	A Horner plot of p vs. Horner time ratio will be required. ws	A Horner plot of p 2 vs. Horner time ratio will be required. ws	Bottomhole pressure must be converted to pseudopressure and then a Horner plot of pseudopressure vs. Horner time ratio will be required.	Semi-log analysis cannot succeed for analysis of a gas-well pressure buildup test.	C	Not supported with pagination yet
37	Volumetric estimate of original gas in place for gas reservoir A was 100 Bscf (2.831 × 10^9 std m^3). A material-balance estimate, using a p/z plot, was 50 Bscf (1.416 × 10^9 std m^3).	One or more producing wells intended to produce from Reservoir A is probably completed by mistake in another non-communicating reservoir.	Some of the mapped gas may not be in pressure communication with the producing wells.	The estimate based on the p/z plot cannot possibly be correct.	The reservoir almost certainly has water influx.	B	Not supported with pagination yet
38	In a low-permeability gas formation, the deliverability curve determined from a plot of Δp2 vs. q, using available test data from a four-point backpressure test with equal-length flow periods, will usually not be “stabilized.” Therefore, the ability of the gas well to deliver gas at a given backpressure will be:	About the same as predicted from the deliverability curve plotted using available test data.	Greater than predicted from the deliverability curve plotted using available test data.	Less than predicted from the deliverability curve plotted using available test data.	Uncorrelated to the value predicted from the deliverability plotted using available test data.	C	Not supported with pagination yet
39	The forecasted production between the current time and the estimated economic limit of a well using a well-defined decline curve is best regarded as	Proved developed reserve	Proved plus probable reserve	Proved plus probable plus possible reserve	Total resource	A	Not supported with pagination yet
40	Thermal oil recovery processes increase recovery largely because they:	improve vertical sweep efficiency to virtually 100% in most cases	increase formation water mobility because of increased formation temperature	reduce oil viscosity	reduce residual oil saturation to near zero in swept areas	C	Not supported with pagination yet
41	An oil reservoir was originally undersaturated and was known to have no water influx. The PVT properties as determined from a recombined fluid sample are shown on the attached curve. The field is to be waterflooded and part of the pre-flood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). Cumulative oil production to the bubble point is 250,000 stb (1,261 m^3). The reservoir oil formation volume factor follows the Bo plot attached. If the current reservoir pressure is 2,500 psia (17,237 kPa), what is the current oil formation volume factor, rb/stb, (res m^3/m^3) nearest?	1.460	1.450	1.440	1.240	B
42	A reservoir oil solution gas-oil ratio follows the Rs plot attached. The initial reservoir pressure was 3,000 psia (20,684 KPa). What is the bubble point pressure, psia (KPa) of the oil nearest?	3,000 (20,684)	2,160 (14,893)	1,000 (6,895)	Not enough information	B
43	An oil reservoir was originally undersaturated and was known to have no water influx. The field is to be waterflooded and part of the preflood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). At the abandonment pressure the oil formation volume factor is 1.20. Cumulative oil production to the bubble point is 250,000 stb (39,750 m^3). Using the above production information and saturations, assume Bob = 1.460 rb/stb (res m^3/m^3) and the Boi = 1.441 rb/stb (res m^3/m^3) and that rock and water expansion are negligible. What is the new bubble point solution gas oil ratio, scf/stb (res m^3/m^3), that would be indicated by increasing the reservoir pressure with water injection such that all the free gas was driven back into the solution.	465 ( 83)	512 (91)	816 ( 145)	935 (166 )	C	Not supported with pagination yet
44	You have the following information on a reservoir in Table 1. Original reservoir pressure was 2,500 psia (17,237 KPa). Well test information and log analysis indicate the presence of a gas cap however, the size of the gas cap is unknown. The reservoir has exhibited the following production performance during depletion in Table 2 The rock and water compressibilities can be assumed to be neglible. There is no water influx. What is the depletion drive index (dimensionless)?	0.9995	0.2255	0.2342	0.3454	D
45	Fractional Flow Curve	0.05	0.72	0.64	0.68	D
46	What is the original oil in place in stb (m^3) of a reservoir with the following parameters? Area = 80 acres, (323,749) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (m3/m3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf. (0.00449 m3/m3)	3,496,563 ( 555,954)	3,933,633 (625,448 )	6,206,400 ( 986,818)	300,000,000 (47,700,000 )	A	Not supported with pagination yet
47	Using the following parameters, what is the ratio of the gas cap to the oil rim, m? Area = 80 acres, (323,749 m2) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (m3/m3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf. (0.00449 m3/m3)	0.125	0.22	0.5	not enough information	A	Not supported with pagination yet
48	A density log in a shaly sand records a formation bulk density, ρb = 2.20 g/cm^3. The correction factor for mudcake and hole rugosity is Δρ = 0.05 g/cm^3. From measurements on cores and produced fluids it is known that the matrix and fluid densities are, ρma = 2.68 g/cm^3 and ρfl = 1.2 g/cm^3. What is the density log porosity, %?	27	29	32	36	C	Not supported with pagination yet
49	A producer-injector pair of wells in an infinite-acting reservoir has been producing two weeks. The distance between the wells is 500 feet (91.44 m). Assume that the injection and production rates are equal at 1,500 bpd (238.48 m^3/d) and that the rock and fluid properties are the same for both injector and producer. Reservoir Properties for this formation are: Permeability = 250 md Porosity = .22 Net thickness = 30 ft (9.14 m) Oil viscosity = .5 cp Water viscosity = .5 cp Total compressibility = 4E-5 psi (2.76E-4 KPa) Injector Skin = 10 Producer Skin = 0 Wellbore radius of both well is 5.5 inches (139.7 mm) Bo = Bw = 1.0 rb/stb Calculate the expected pressure drop, psi (KPa), in the production well.	26.91 (185.54)	98.78 (681.06)	239.98 (1654.60)	656.42 (4525.86)	B	Not supported with pagination yet
50	A gas well has been found to be declining exponentially. The observed production rate on 1 January 2004 was 0.6 Bscf/month (1.7 × 10^7 std m^3/month), and on 1 January 2005, it was 0.4 Bscf/month (1.133 × 10^7 std m^3/month). The economic limit for the well is estimated to be 0.003 Bscf/month (8.495 × 10^5 std m^3/month). Estimate the remaining reserves, Bscf (std m^3), for the well as of 1 January 2005.	21.5 (6.09 × 108)	17.69 (5.01 x 108 )	1.791 (5.07 × 107)	1.474 (4.17 × 107)	B	Not supported with pagination yet
51	Which of the following has the LEAST influence on drill pipe stretch?	BHA weight	Drill pipe weight	Mud density	Traveling block weight	D	Not supported with pagination yet
52	Which of the following is MOST LIKELY a descriptor for a diamond bit?	Crown	Journal	O-ring Seal	Shirttail	A	Not supported with pagination yet
53	Which of the following is NOT a description of fluid flow?	Laminar	Plastic	Plug	Turbulent	B	Not supported with pagination yet
54	Which of the following is NOT a key rheological property of drilling fluids?	Yield point	Plastic viscosity	Gel Strength	Funnel viscosity	D	Not supported with pagination yet
55	Which of the following has the LEAST influence on bit nozzle pressure drop?	Bit diameter	Flow rate	Mud density	Nozzle area	A	Not supported with pagination yet
56	Which of the following is NOT a typical section view for directional wells?	Double build	Double twist	S type	Slant type	B	Not supported with pagination yet
57	Which of the following is a conventional rotary shouldered connection size?	4-1/2” REG	5-5/8” REG	6-1/2” REG	7-1/2” REG	A	Not supported with pagination yet
58	Which of the following is a DISADVANTAGE of air drilling?	Differential pipe sticking is eliminated	Downhole explosions or fire may occur	Lost circulation may be reduced	Reduced thawing of frozen zones	B	Not supported with pagination yet
59	Which of the following is FALSE regarding leak-off tests?	Unpurged air can affect the shape of the leak-off test curve	There are two phases of fracturing a formation, initiation and extension	The pressure to initiate is usually less than the pressure to extend	The initial pressure increase vs. volume pumped reflects elastic rock deformation	C	Not supported with pagination yet
60	Which of the following is MOST LIKELY regarding cement flow regimes?	Laminar flow has the smallest displacement efficiency	Plug flow is very inefficient w/small volumes displacing low density mud	Turbulent flow gives low displacement efficiency	Turbulent flow requires the longest pumping times	A	Not supported with pagination yet
61	When backing-off a stuck drill string, which of the following would NOT be a typical step?	Twist the string one counter-clockwise turn per 1,000 feet of free string	Pull the buoyed weight of the string above the stuck point	Fire the shot after working the torque down to the tool joint to be backed off	Twist the string one clockwise turn per 1,000’ of free string	D	Not supported with pagination yet
62	Which of the following is NOT a typical contributing factor in axial friction forces?	Bending of the drill string in a dog leg	Buoyed weight of the drill string lying on the low side	Hanging up of drill string component on a ledge	Packing of the drill string in a cuttings bed	C	Not supported with pagination yet
63	Which of the following does NOT result in collapse of the tube?	Elastic Collapse Pressure	Plastic Collapse Pressure	Transition Collapse Pressure	Yield-Strength Collapse Pressure	D	Not supported with pagination yet
64	The primary function of the counter-balance system in rod pumped wells is:	Speed reduction of the prime mover to suitable pumping speeds	Store energy on the downstroke and release energy on the upstroke	Store energy on the upstroke and release energy on the downstroke	Supply the mechanical energy to transmit to the pump and lift fluids	B	Not supported with pagination yet
65	For bellows-type gas-lift valves, valve spread is:	The difference between opening and closing pressures	The difference between annular and bellow pressures	The depth difference between the top and bottom valves	The depth difference between adjacent valves	A	Not supported with pagination yet
66	Which of the following would be a typical path for gas through a separator?	Primary separation, liquid accumulation, secondary separation, gas outlet	Primary separation, mist extractor, liquid accumulation, gas outlet	Primary separation, secondary separation, liquid accumulation, gas outlet	Primary separation, secondary separation, mist extractor, gas outlet	D	Not supported with pagination yet
67	Which of the following is NOT a primary mechanism in separation devices?	Centrifugal	Gravity	Impingement	Radioactivity	D	Not supported with pagination yet
68	Which of the following is NOT a key assumption for matrix acidizing?	Acid penetrates uniformly and radially	Formation is homogeneous	Pore size varies widely	Reaction rate declines uniformly with decreasing acid concentration	C	Not supported with pagination yet
69	The fracturing fluid coefficient is a key factor in modeling an induced fracture. Which of the following is NOT a category for fracture fluids?	Conductivity-controlled fluids	Reservoir-controlled fluids	Viscosity-controlled fluids	Wall-building fluids	A	Not supported with pagination yet
70	Which of the following is NOT a typical class of pipe cutters?	Acid	Jet-shaped charge	Outside cutter	Tubing punch	D	Not supported with pagination yet
71	A pump is needed to move a high viscosity, heavy (high specific gravity) crude oil from a storage tank to a treating facility for processing. The tank is not insulated and it is located in a cold-weather environment. The field from which this oil is produced has a low reservoir pressure, and the oil is produced in slugs that re-fill the tank sporadically. The oil must be moved at a closely controlled rate to the treating facility to avoid overloading it. What type pump, based on service capabilities and cost, should be recommended for this service?	Centrifugal pump	Gear pump	Reciprocating (plunger) pump	Turbine pump	B	Not supported with pagination yet
72	A caliper survey has determined that there has been a uniform 65% wall loss in a 5-in. (127 mm) 23.2 lbm/ft (34.5 kg/m) T95 casing string. Neglecting axial/hoop stresses. What is the new burst pressure rating of this casing string in psi/(Mpa)?	5,550 (38.3)	6,350 (43.78)	10,340 (71.29)	14,300 (98.6)	A	Not supported with pagination yet
73	An electric motor is needed for a hoist. The motor is expected to provide a force of 744 lbf (337.5 kgf) at the edge of a 24-in. (61 cm) diameter pulley. The motor will run at 1200 RPM and the pulley will be attached to a gearbox to provide the correct line speed for the hoist. Assume the motor operates at 85% efficiency. What size, hp (KW), motor should be specified for this application?	170 HP (126.8)	200 HP (149.1)	340 HP (253.5)	400 HP (298.3)	B	Not supported with pagination yet
74	A recently drilled well is being completed. The well was drilled with 14 lbm/gal (1.68 SG) mud with no mud losses experienced while drilling the well. The 5 1/2-in. (140 mm), 15.50 pound/ft (23.06 kg/m) casing has been perforated from 10,129 ft (3,087.3 m) to 10,141 ft (3,091.0 m). A full string of 2 3/8-in. (60 mm) tubing has been run in the well to the top perforation. The well was being circulated on its third bottoms-up with 8.7 lbm/gal (1.04 SG) filtered water when the pump failed. The crew closed the blowout preventer and installed a closed valve in the top of the tubing string. Unfortunately, they left the valve on the annulus flowline to the pit open while the pump was repaired. Someone noticed that the well was flowing, and the crew closed the annulus valve. The pit had gained 10 bbl (1.6 m^3) of fluid. Stabilized pressures after 30 minutes are: Shut-in tubing pressure, 495 psi (3,413 KPa); Shut-in annulus pressure, 225 psi (1,551 KPa). The type of fluid most likely composing the kick is:	Natural gas	Oil	Saltwater	Drilling mud	C	Not supported with pagination yet
75	A well has ceased flowing due to a buildup of saltwater in the tubing. The well is standing full of produced fluid with a density of 8.9 lbm/gal (1.067 SG). A pumping unit is to be installed to lift the fluid from a depth of 10,000 ft (3,048 m). Expected produced water rate is 220 bbl/D (35 m^3/day). The pumping unit will be counterbalanced such that essentially all the sucker rod and fluid load will be offset by the counterweights. The pumping unit manufacturer requires a prime mover having 125% excess power to run the unit. What is the rated horsepower, hp (KW), of the prime mover needed to run the pumping unit?	15 (11)	20 (15)	35 (26)	40 (30)	D	Not supported with pagination yet
76	A recently-drilled gas well has been completed, but initial flowrates from the well are disappointing. The well has the following characteristics: The pay zone perforations are centered at 15,800 ft (4,816 m). The static reservoir pressure is 0.63 psi/ft (1.45 SG). The fracture gradient at the perforations is 0.95 psi/ft (2.19 SG). Skin = -20 psi (-138 KPa). The pay zone is a tight, highly-consolidated clean sandstone. Permeability is estimated to be 0.05 mD. What treatment technique would you recommend to stimulate this well?	High rate, high volume fracture stimulation	Low rate “matrix” hydrochloric acid stimulation	Sand control treatment to reduce sand collection in the wellbore	Scale removal workover	A	Not supported with pagination yet
77	A pumping unit is to be installed on a 5,000 ft (1,524 m) well. The foreman wishes to use 1-in (25.4 mm), 7/8-in. (22.2 mm) and 3/4-in. (19.1 mm) sucker rods to make up the string 8 so he can use his existing inventory and minimize the purchase of new rods. Unfortunately, he only has a limited number of 1-in. (25.4 mm) sucker rods and he will have to buy some of these. What total length, feet (meters), of 1-in. (25.4 mm) sucker rods must be installed in this well if a 2-in. (50.8 mm) pump plunger is needed to achieve the production rate required on this well?	1,435 (437.4)	1,635 (498.3)	1,930 (588.3)	2,260 (688.8)	A	Not supported with pagination yet
78	Three storage tanks are delivered to the site of a new producing well. The tanks appear to be unusual in size. No tank table was delivered with the tanks. The well is to be placed on production as soon as the tanks are set. The basic dimensions of the tanks are: Tank outside diameter: 15.0 ft (4.57 m) Shell thickness: 0.35-in. (8.9 mm) Tank shell height: 17 ft (5.18 m) Overflow line outlet: base, 8-in. from top of tank (203.2 mm) What is the usable storage capacity of the tank battery to the nearest barrel (cubic meter)?	509 (80.9)	1,527 (242.8)	1,539 (244.7)	1,593 (253.3)	B	Not supported with pagination yet
79	A producing gas well is to be treated with a scale removal chemical at a low pump rate. The well is equipped with a polished-bore receptacle above the production packer with a 20-ft (6.1 m) seal assembly that travels freely. Bottomhole temperature is 300°F (149 °C). Gas temperature at the surface is 120°F (49 °C). Once the well is at thermal equilibrium during the pumping job, the average temperature of the tubing string will be reduced by 25°F (-4 °C) over its length. The tubing is tapered with 2,560 ft (780 m) of 3 1/2-in (89 mm) tubing at the surface with 5,440 ft (1,658 m) of 2 7/8 -in. (73 mm) tubing above the seal assembly. The tubing is all N-80 grade material. How far, inches (centimeters), up the PBR will the tubing travel due to thermal contraction during this pumping job, ignoring pressure effects.	1.4 (3.6)	5.3 (13.5)	16.6 (42.2)	18.6 (47.2)	C	Not supported with pagination yet
80	A double-acting duplex pump is going to be used to fill a tank from a water pit. The foreman does not know the pump output, but he wants an estimate of the time required to fill the 500 bbl (79.5 m^3) tank with water. Each liner has an internal diameter of 5 1/2-in. (14 cm) and an overall stroke length of 14-in. (35.6 cm). The rod diameter for each plunger is 2-in. (5.1 cm). The pump is running at a speed of 65 strokes per minute. Assuming a pump efficiency of 80%, how long will it take for the pump to fill the 500-bbl (79.5 m3) tank?	1.00 hours	1.17 hours	1.25 hours	2.50 hours	C	Not supported with pagination yet
81	Which of the following statements is TRUE regarding undersaturated oil reservoirs?	The two phase and single phase factors are equal above the bubble point	The initial solution gas-oil ratio does not equal the solution gas-oil ratio at a specified pressure above the bubble point	Below the bubble point, the two-phase factor decreases while pressure decreases	Below the bubble point, the single phase factor increases while pressure decreases	A	Not supported with pagination yet
82	Which of the following is the LEAST likely characteristic of a reservoir fluid?	Compressible liquid	Gas	Incompressible liquid	Superfluid	D	Not supported with pagination yet
83	Reservoir simulators are well-suited to help us determine	Aquifer size and strength, remaining reserves, corporate overhead	Future water production, optimal infill well location, results of fracture stimulation treatments	Optimal well spacing in reservoirs, coning characteristics of wells, and optimal flood patterns in improved recovery projects	Unique reservoir description, optimal enhanced recovery method, good matches of reservoir history	C	Not supported with pagination yet
84	The factors that cause recovery factors to vary in uncertain ways in oil reservoirs do not include	distribution of permeabilities vertically and horizontally	presence and location of reservoir boundaries	presence and location of reservoir heterogeneities	unexpected variations in oil prices	D	Not supported with pagination yet
85	Each type of logging tool has special formation evaluation applications. Which of the following statements is FALSE?	Pressure versus depth measurements can be used to identify reservoir fluids and fluid contacts	NMR and density logs can be combined to predict gas-corrected formation porosity in gas-bearing zones	Resistivity measurements alone can be used to differentiate oil zones from gas zones	NMR fluid characterization logs can be used to identify low-resistivity pay zones.	C	Not supported with pagination yet
86	Given accurate test data, the exponent, n, in the Rawlins-Schellhardt gas-well deliverability equation should be:	less than 0.5.	between 0.5 and 1.0.	greater than 1.0.	between 1.0 and 2.0.	B
87	A reservoir produces gas at an initial gas/liquid ratio (GLR) of 20,000 scf/STB (3,561 std m^3/std m^3). After some period of production at constant GLR, the producing GLR begins to increase with time. Essentially all the produced liquids are gas condensate. The reservoir fluid is most likely which one of the following types?	Black oil	Dry gas	Gas condensate (retrograde gas)	Wet gas	C	Not supported with pagination yet
88	The proper ranking of average (typical, not exceptional) oil reservoir recovery efficiency (from lowest to highest) by drive mechanism is	solution-gas drive; rock-and-fluid expansion drive; water drive; expanding gas- cap drive	solution-gas drive; expanding gas-cap drive; water drive; gravity drainage drive	rock-and-fluid expansion drive; solution-gas drive; water drive; expanding gas- cap drive	rock-and-fluid expansion drive; expanding gas-cap drive; gravity-drainage drive; water drive	B	Not supported with pagination yet
89	Low-permeability or tight gas reservoirs ordinarily produce at economic rates because they are	Stimulated with long, highly conductive hydraulic fractures	Provided substantial tax and other economic incentives by governmental authorities	Drilled with very wide well spacing, often 640 acres (2.59 × 106 m2), and drain large areas efficiently with limited numbers of vertical wells	Completed in formations of massive thickness.	A	Not supported with pagination yet
90	You are designing a waterflood for a reservoir that is currently below bubblepoint pressure and shut-in. The initial reservoir pressure was at the bubble point with no gas cap. The oil reservoir has the following information: • Flood Pattern — 5-spot • Pattern Area — 80 acres (323,749 m^2) • Formation Thickness — 59 feet (18 m) • Porosity — 16.0% • Initial Water Saturation — 42.0% • Oil formation volume factor at Original Pressure — 1.337 rb/stb (m^3/m^3) • Primary Oil Produced — 450 mstb (71,542 m^3) • Oil Formation Volume Factor at Current pressure — 1.165 rb/stb (m^3/m^3) • Oil Viscosity at Current Pressure — 1.02 cp • Water Viscosity at Current Pressure — 0.60 cp • Oil saturation at Current pressure — 41.6% • Average Water Saturation in Swept Zone at Breakthrough — 66.0% • Water formation volume factor — 1.000 rb/stb (m^3/m^3) The fillup volume in thousands of bbls (mstb) (m^3) is most nearly:	0 (0 )	960 ( 152,640)	2,092 ( 332,628)	2,542 (404,178)	B	Not supported with pagination yet
91	A reservoir oil solution gas-oil ratio follows the R plot attached. The initial reservoir pressure was 3,000 psia (20,684 KPa). If the current reservoir pressure is 2,500 psia (17,237 KPa), what is the oil solution gas-oil ratio (scf/stb) (m^3/m^3) nearest?	375 (67)	779 (139 )	935 ( 166)	Not enough information	C
92	An oil reservoir was originally undersaturated and was known to have no water influx. The field is to be waterflooded and part of the preflood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). At the abandonment pressure the oil formation volume factor is 1.20. Cumulative oil production to the bubble point is 250,000 stb (39,750 m^3). Using the above production information and saturations, assume Bob = 1.460 rb/stb and the Boi = 1.441 rb/stb and that rock and water expansion are negligible. If the new solution gas oil ratio is 750 scf/stb (134 m^3/m^3), what is the new bubble point pressure, psia (KPa), nearest?	3,000 (20,684)	2,160 (14,893)	1,800 (12,411)	1,200 (8,274)	C	Not supported with pagination yet
93	You have a PVT analysis for a volumetric reservoir which was undersaturated at the original reservoir conditions of 6,258 psia (36,890 KPa) and 205 °F (96 °C). The reservoir has produced at a constant producing GOR until a marked decrease in the producing GOR was noted. At this point, the cumulative production from the reservoir was 231 mstb (36,729 m^3) of oil. The average oil saturation initially in the reservoir was determined from logs to be 80%. Assume that the field is operated at optimum separator conditions. Fluid and rock compressibilities are as follows: cw = 3.5 × 10^-6 psi^-1 and cf = 11.6 × 10^-6 psi^-1. Determine the amount of gas in solution, mmscf (m^3), if the reservoir produces 1,200 mstb (≈190.8 × 10^3 m^3) of additional oil and is abandoned at 900 psia (6,206 KPa).	287 (8.1)	464 ( 13)	1007 (29)	306 (8.7)	A
94	What is the breakthrough mobility ratio of an inverted 5-spot pattern undergoing waterflood with the average water saturation at breakthrough equal to 68% (Swbt = 0.68)? Use the following table of oil and water relative permeabilities to calculate your answer. Assume µ oil = 0.64 cp and µ water = 0.50 cp.	0.680	0.462	1.000	0.419	D
95	Using the fractional flow curve, what is the water saturation at the well at the time of breakthrough?	0.68	0.64	0.72	0.05	B
96	What is the original volume of gas cap gas in place in mscf (mm^3) of a reservoir with the following parameters? Area = 80 acres, (323,749 m^2) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (1.42 m^3/m^3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf (0.00449 m^3/m^3).	7,757,800 (219,768)	6,982,020 (197,791)	775,800 ( 21,977)	620,624 (17,581)	C	Not supported with pagination yet
97	A sonic logging tool recorded a travel time of 90 µs/ft in a loosely consolidated sand formation. From local experience it is known that sonic log travel times in this formation read too high because the formation is loosely consolidated. A correction factor, Cp = 1.2, should be applied to the Wyllie time-average equation to correct for lack of compaction. The matrix and formation fluid travel times are travel time times are, Δt matrix = 51.0 µs/ft ma and Δt fluid = 189 µs/ft. What is the formation porosity, %, predicted using the Wyllie equation with a compaction correction?	17	24	28	34	B	Not supported with pagination yet
98	From lab measurements on core samples from a zone of interest you are given the following Archie parameters: F = 26.0, and n = 2.3. From resistivity measurements on produced formation water samples, R = 0.05 ohm-m w at reservoir temperature. From log measurements, Rt = 10.0 ohm-m and φ = 0.20. What is Sw, %?	33	35	36	41	D	Not supported with pagination yet
99	A high-pressure gas reservoir had a discovery pressure of 10,000 psia (6.895 × 10^4 KPa). PVT analysis of the gas indicated the following variation in deviation factor, z, with pressure. p, psia z, dimensionless 10,000 (6.895 × 10^4 KPa) 1.47 8,000 (5.516 × 10^4 KPa) 1.30 Formation water compressibility was 3.5 × 10^-6 psia^-1 (5.076 × 10^-7 KPa^-1), initial water saturation 25%, and constant formation compressibility 2 × 10^-5 psia^-1 (2.901 × 10^-6 KPa^-1). Estimate the percentage, %, of original gas in place produced when reservoir pressure drops from discovery pressure to 8,000 psia (5.576 × 10^4 KPa).	9.54	14.6	20.0	85.4	B	Not supported with pagination yet
100	A gas reservoir has a reliable estimate of original gas in place of 400 Bcf (400 × 10^9 scf, 1.133 × 10^10 std m^3). There may be water influx into the reservoir from an aquifer. Estimate the cumulative water influx in reservoir barrels (RB) (or reservoir cubic meters, res m^3) if, after two years of production, average reservoir pressure has dropped from an original 5,000 psia to 4,000 psia (3.44 × 10^4 kPa to 2.758 × 10^4 kPa). Other information is summarized below. Time (years) \| Avg reservoir pressure (psia) \| (kPa) \| Bg (RB/Mscf) \| Bg (res m^3/m^3) \| Gp (Bscf) \| Gp (std m^3) \| Wp (STB) \| Wp (std m^3) 0 \| 5,000 \| 3.447×10^4 \| 1.0 \| 5.615×10^-3 \| 0 \| 0 \| 0 \| 0 2 \| 4,000 \| 2.758×10^4 \| 1.2 \| 6.737×10^-3 \| 66.7 \| 1.889×10^9 \| 40,000 \| 6.737×10^3 Assume water formation volume factor is 1.0 RB/STB (1.0 res m^3/m^3).	66.74 ×10^6 RB (10.61 × 10^6 res m3)	4 × 10^4 RB (6.36 × 10^3 res m3)	66.7 ×10^6 RB (10.6 × 10^6 res m3)	80 × 10^3 RB (12.72 × 10^3 res m3)	D	Not supported with pagination yet

1

Which of the following factors has the LEAST impact on casing seat selection?

Rate of Penetration

Pore pressure

Kick tolerance

Fracture gradient

A

Not supported with pagination yet

2

When considering calculation methods for survey points, the LEAST precise method is:

Circular arc

Minimum curvature

Radius of curvature

Tangential

D

Not supported with pagination yet

3

Which of the following is NOT a typical purpose for a BHA?

Assure casing can be run into a hole

Control direction and inclination in directional holes

Increase severity of doglegs, keyseats and ledges

Protect the drill pipe from excessive bending and torsional loads

C

Not supported with pagination yet

4

Which of the following is a typical characteristic of plug flow cement placement?

Reynolds number less than 100

Large cement volumes

High displacement rates

Short cementation times

A

Not supported with pagination yet

5

Which of the following is NOT a typical cause for a fishing job?

Cementing error

Differential sticking

Swelling zone

Use of oil-base mud

D

Not supported with pagination yet

6

Which of the following is NOT a component of the hoisting equipment for a drilling rig?

Crown block

Drawworks

Drilling line

Rotary table

D

Not supported with pagination yet

7

Which of the following is NOT a primary function of drilling fluids?

Cuttings removal

Frac proppant

Lubrication and cooling

Well control

B

Not supported with pagination yet

8

Which of the following methods is MOST likely to hydrostatically balance a well kick with only one circulation?

Concurrent

Driller’s

Toolpusher’s

Wait and weight

D

Not supported with pagination yet

9

Critical rotary speed longitudinally (rpm*) is calculated by rpm* = 258,000/L, where L is the total length of the drill string (ft). Which of the following is a multiple of rpm* at which secondary and higher harmonic vibrations will occur?

2

8

16

32

C

Not supported with pagination yet

10

Which of the following is NOT a colloidal polymer?

Xantham gum

Starch

Sodium carboxy methyl cellulose

Hydroxyethyl cellulose

A

Not supported with pagination yet

11

Which of the following is a major consideration for cuttings transport in horizontal wells?

Annulus size

Drilling Rate

Eccentricity

Rotary speed

C

Not supported with pagination yet

12

Which of the following is NOT a routine roller cone bearing package description?

Friction-ball-friction

Friction-ball-roller

Roller-ball-friction

Roller-ball-roller

B

Not supported with pagination yet

13

In comparing the API specs for L-80 and N-80 tubulars, which of the following statements is TRUE?

Minimum yield strength is different

Maximum yield strength is the same

Minimum tensile strength is different

Minimum elongation is the same

C

Not supported with pagination yet

14

Which of the following is NOT a typical separator type?

Horizontal

Slant

Spherical

Vertical

B

Not supported with pagination yet

15

Which of the following is NOT a typical casing hanger type?

Slip-weld

Nominal flange

Boll-weevil

Automatic

B

Not supported with pagination yet

16

The control pressure for a surface safety valve is most likely equal to:

Valve body pressure divided by actuator ratio

Actuator ratio divided by valve body pressure

Two times valve body pressure divided by actuator ratio

Valve body pressure multiplied by actuator ratio

C

Not supported with pagination yet

17

The material for sealing element when approaching 450 degrees F (232 degrees C) and 15,000 psi (103,422 KPa) differential is MOST likely:

Glass-filled Teflon

Kalrez

Nitrile

Viton

A

Not supported with pagination yet

18

Tubing elongation MOST likely occurs with:

Ballooning

Buckling

Reverse Ballooning

Temperature Reduction

C

Not supported with pagination yet

19

Which of the following is NOT an API classification for oil well pumps?

Tubing type with extension shoe and nipple

Tubing type, traveling barrel with bottom hold-down

Rod type, stationary barrel with top hold-down

Rod type, traveling barrel

B

Not supported with pagination yet

20

Which of the following has the LEAST volumetric efficiency for rod pumped wells?

High fluid level with no gas interference

Gaseous wells with fair downhole separation

Foamy liquid or gaseous conditions

Ample pump submergence with good separation

B

Not supported with pagination yet

21

A caliper survey has been run on a producing gas well. It shows that the casing is partially collapsed 500 ft (152.4 m) above the perforations. The well is starting to load up with fluid, so a decision has been made to install a small diameter tubing string with a packer set just below the partially collapsed interval to protect the casing from pressure, temperature fluctuations and other forces that could result in further collapse. What type of packer should be used in this application?

Weight-set packer

Tension-set packer

Rotation-set packer

Hydraulic-set packer

D

Not supported with pagination yet

22

A platform is producing surplus gas that must be sold into a nearby pipeline; flaring is not permitted. The gas has the following characteristics: gas gravity = 0.689 SG (Air = 1), ratio of specific heats = 1.206, molecular weight = 20, supercompressibility factor = 0.022. Wells on the platform produce a total of 18 mmcfd (509,703 m^3/d) dry gas (after separation and dehydration). Platform fuel use is 6 mmcfd (169,900 m^3/d). The gas is cooled after leaving the dehydrator to a temperature of 60°F (15.6°C). Pressure at the gas cooler outlet is 227 psig (1,565 KPa). Pipeline pressure is 1,050 psig (7239 KPa). What minimum horsepower, hp, would be required to compress the surplus gas from this platform for sale into the pipeline?

1,191

1,238

1,787

2,649

A

Not supported with pagination yet

23

What type problem does the below dynamometer card indicate that would cause an excessive number of rod parts in the lower portion of the rod string in this well?

Excessive friction

Overtravel

Plunger sticking

Fluid pound

D

24

A well is to be fracture stimulated down the production casing with the following conditions: Fracture propagation gradient: 0.95 psi/ft (2.19 SG) Near well pressure losses: 1,000 psi (6,895 KPa) Casing friction pressure losses: 1,600 psi (11,032 KPa) Surface piping friction losses: 300 psi (2,068 KPa) Stimulation rate: 65 bbl/minute (10.33 m^3/min) Perforations: 18,100 ft (5,517 m) MD/16,100 ft (4,907 m) TVD Fluid Density: 8.5 lbm/gal (1.02 SG) 50% Standby Horsepower on location Pump truck rated horsepower: 2,000/truck. Assume 85% Pump Efficiency How many pump trucks will be required?

11

14

16

17

C

Not supported with pagination yet

25

A 10,000 HP compressor bank is going to be added to a large pipeline compressor station. An inlet meter station is located 1,200 ft (366 m) away from the new compressor site. Pressure at the meter run is 60 psig (414 KPa). Gas from the meter station will be used for fuel. The gas pressure at the fuel line header inside the new compressor site is specified at 26 psig (179 KPa). The gas will be at 60°F (15.6°C). Assume fuel usage will be 240 scfd (6.8 m^3/d) per HP for the new compressors. What minimum diameter, in/(mm) fuel line should be installed to provide fuel gas to the new compressor site from the meter run?

1.5 (38)

3.5 (89)

5 (127)

6 (152)

B

Not supported with pagination yet

26

The following readings were made by a field gas technician at a dry gas sales meter. Static pressure: 800 psig (5,516 KPa) Differential: 15-in. (381 mm) H2O Temperature: 130° F (54.4°C) Gas Specific Gravity: 0.62 (Air=1) Meter run: 4.026-in. (102.3 mm) ID Orifice plate: 1.5-in. (38.1 mm) Neglect viscosity, super-compressibility and compression factors (assume each of these equals 1.0). The only impurities are 13 vol-% CO2 and 0.8 vol-% N2. Using standard meter tables Fb: 460.8 Fg: 1.27 Fpb: 1.0000 What is the daily natural gas flowrate, mcfpd (m^3/d), most likely to be on the gas purchasers’ statement using a 14.73 psi (101.5 KPa) pressure base and 60°F (15.6°C) temperature base?

1,152 (32,621)

1,328 (37,605)

1,341 (37,973)

1,458 (41,286)

A

Not supported with pagination yet

27

A gas well with 40 ppm H2S and 14 mole-% CO2 is planned to be produced up a string of tubing cemented in the well as a “tubingless completion” (i.e., the tubing is actually small-diameter production casing). Initial shut in pressure will be 12,000 psi (82.737 MPa). Initial flowing pressure will be 8,000 psi (55.158 MPa). Flowing pressure will decline to 2,000 psi (13.79 MPa) in less than six months. Surface temperature is 75° F (23.9°C). Static bottomhole temperature is 330°F (165.6°C) at 15,200 ft (4,633 m) TVD. Flowing surface temperature is 120°F (48.9°C). Both T95 and P110 tubing (casing) strings are available and will meet all required stress considerations. Your field foreman would prefer to run just one grade of pipe to avoid confusion on the rig. Of the possible recommendations below, what would you recommend to management with your concern being sulphide stress cracking (SSC) of the tubing (casing) string in this well?

The partial pressure of sour gas is not great enough to need T95 grade pipe

Run all P110 grade pipe. Fast pressure decline mitigates problem with SSC

Recommend running T95 to at least 4,348 ft (1,325 m) from the surface

Recommend running T95 to at least 6,250 ft (1,905 m) from the surface

D

Not supported with pagination yet

28

A plug has been set in a profile nipple below a packer in a well. To confirm that the plug will hold, it has been decided to pressure up on the tubing to 9,000 psi (62.1 MPa). The well is standing full of fresh water. The packer is set at 6,000 ft (1,829 m) and has a 3.5-in. (89 mm) bore. The pipe string is all 2 7/8-in. (73 mm) OD, 6.5 lbm/ft (9.67 kg/m) L-80, EUE, 8-round thread tubing equipped with a seal assembly that allows free travel inside the packer bore. A pressure of 1,000 psi (6.9 MPa) will be applied to the tubing x casing annulus. Ignoring temperature and ballooning effects, how far up the packer bore will the seal assembly travel, inches (centimeters), when the pump reaches maximum pressure?

54.7 (138.9)

33.1 (84.1)

28.4 (72.1)

4.6 (11.7)

A

Not supported with pagination yet

29

A tank is filled with produced water with a density of 8.6 lbm/gal (1.03 SG). A decision has been made to use the fluid for a workover, but the density is too low. Brine with a density of 10.0 lbm/gal (1.20 SG) is to be mixed with fluid in the tank until the contents have the proper density for the job. The brine is to be pumped through a nozzle on the end of a pipe to agitate the tank and ensure the fluid is constantly, thoroughly mixed. The nozzle has a diameter of 1/2-in. (12.7 mm) and a pump rate of 200 gal/min (0.757 m^3/min) has been selected. What pressure drop, psi (KPa) can be anticipated across the nozzle under these conditions? Assume a nozzle coefficient of 0.95.

147 (1,014)

188 (1,294)

597 (4,116)

956 (6,588)

D

Not supported with pagination yet

30

A pressure relief valve is needed to protect a petroleum storage tank from over-pressure. The relief valve will discharge into a low-pressure vent system with a constant pressure of 0.5 psig (3.4 KPa). The scrubber on this low pressure vent system cannot handle peak flowrates in excess of 6.0 scfm (10.2 m^3/hr). The relief valve is to be set to allow a 5 psig (34.5 KPa) buildup in the tank with a 1.6 psig (11.0 KPa) setpoint pressure before the relief valve opens. Gas in the tank has a specific gravity of 0.68 (Air = 1.0). The ratio of specific heats of the gas, k = Cp/Cv = 1.10. Assume the relief valve has a coefficient, K, of 5.212 × 10^-4. What diameter relief valve orifice, inches (cm), should be specified for this application?

6.4 (16.3)

6.0 (15.2)

5.8 (14.7)

5.5 (14.0)

B

Not supported with pagination yet

31

You are calculating the original gas in place using the volumetric method. Which of the following has the LEAST influence on the final result?

Connate water saturation

Initial reservoir pressure

Permeability

Porosity

C

Not supported with pagination yet

32

Which of the following is the LEAST likely source for water which encroaches into a reservoir as pressure declines?

Artesian flow

Compressibility of the rock in the aquifer

Expansion of the water in the aquifer

Water coming out of solution from the oil as the pressure drops

D

Not supported with pagination yet

33

Important characteristics of the production history of many coal-bed methane wells include:

Initial large and declining water cuts and low and improving gas production rates

Initial large but declining gas/liquid ratios and low but increasing water production rates

Stabilized gas/liquid ratios and decreasing gas rates

Stabilized gas/liquid ratios and increasing gas and water production rates

A

Not supported with pagination yet

34

There are known effects of gas on logging tool responses. Which of the following statements is correct?

Density log porosities are not affected by gas

Neutron log porosities are increased by gas

NMR log porosities are reduced by gas

Sonic log porosities are reduced by gas

C

Not supported with pagination yet

35

For decline-curve analysis to be accurate, several conditions must be satisfied. Which of the following conditions is not appropriate?

Drainage area of the well remains constant with time.

Skin factor of well is not changing with time.

Well is in transient flow regime.

Well produces at constant BHP.

C

Not supported with pagination yet

36

A pressure buildup test is run on a well producing dry gas. Current average reservoir pressure is about 3,012 psia (20.77 × 10^3 KPa) and the flowing bottomhole pressure at the time of shut-in was 1,126 psia (7.76 × 10^3 KPa). Which of the following statements about analyzing the test data using a semi-log method is most accurate?

A Horner plot of p vs. Horner time ratio will be required. ws

A Horner plot of p 2 vs. Horner time ratio will be required. ws

Bottomhole pressure must be converted to pseudopressure and then a Horner plot of pseudopressure vs. Horner time ratio will be required.

Semi-log analysis cannot succeed for analysis of a gas-well pressure buildup test.

C

Not supported with pagination yet

37

Volumetric estimate of original gas in place for gas reservoir A was 100 Bscf (2.831 × 10^9 std m^3). A material-balance estimate, using a p/z plot, was 50 Bscf (1.416 × 10^9 std m^3).

One or more producing wells intended to produce from Reservoir A is probably completed by mistake in another non-communicating reservoir.

Some of the mapped gas may not be in pressure communication with the producing wells.

The estimate based on the p/z plot cannot possibly be correct.

The reservoir almost certainly has water influx.

B

Not supported with pagination yet

38

In a low-permeability gas formation, the deliverability curve determined from a plot of Δp2 vs. q, using available test data from a four-point backpressure test with equal-length flow periods, will usually not be “stabilized.” Therefore, the ability of the gas well to deliver gas at a given backpressure will be:

About the same as predicted from the deliverability curve plotted using available test data.

Greater than predicted from the deliverability curve plotted using available test data.

Less than predicted from the deliverability curve plotted using available test data.

Uncorrelated to the value predicted from the deliverability plotted using available test data.

C

Not supported with pagination yet

39

The forecasted production between the current time and the estimated economic limit of a well using a well-defined decline curve is best regarded as

Proved developed reserve

Proved plus probable reserve

Proved plus probable plus possible reserve

Total resource

A

Not supported with pagination yet

40

Thermal oil recovery processes increase recovery largely because they:

improve vertical sweep efficiency to virtually 100% in most cases

increase formation water mobility because of increased formation temperature

reduce oil viscosity

reduce residual oil saturation to near zero in swept areas

C

Not supported with pagination yet

41

An oil reservoir was originally undersaturated and was known to have no water influx. The PVT properties as determined from a recombined fluid sample are shown on the attached curve. The field is to be waterflooded and part of the pre-flood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). Cumulative oil production to the bubble point is 250,000 stb (1,261 m^3). The reservoir oil formation volume factor follows the Bo plot attached. If the current reservoir pressure is 2,500 psia (17,237 kPa), what is the current oil formation volume factor, rb/stb, (res m^3/m^3) nearest?

1.460

1.450

1.440

1.240

B

42

A reservoir oil solution gas-oil ratio follows the Rs plot attached. The initial reservoir pressure was 3,000 psia (20,684 KPa). What is the bubble point pressure, psia (KPa) of the oil nearest?

3,000 (20,684)

2,160 (14,893)

1,000 (6,895)

Not enough information

B

43

An oil reservoir was originally undersaturated and was known to have no water influx. The field is to be waterflooded and part of the preflood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). At the abandonment pressure the oil formation volume factor is 1.20. Cumulative oil production to the bubble point is 250,000 stb (39,750 m^3). Using the above production information and saturations, assume Bob = 1.460 rb/stb (res m^3/m^3) and the Boi = 1.441 rb/stb (res m^3/m^3) and that rock and water expansion are negligible. What is the new bubble point solution gas oil ratio, scf/stb (res m^3/m^3), that would be indicated by increasing the reservoir pressure with water injection such that all the free gas was driven back into the solution.

465 ( 83)

512 (91)

816 ( 145)

935 (166 )

C

Not supported with pagination yet

44

You have the following information on a reservoir in Table 1. Original reservoir pressure was 2,500 psia (17,237 KPa). Well test information and log analysis indicate the presence of a gas cap however, the size of the gas cap is unknown. The reservoir has exhibited the following production performance during depletion in Table 2 The rock and water compressibilities can be assumed to be neglible. There is no water influx. What is the depletion drive index (dimensionless)?

0.9995

0.2255

0.2342

0.3454

D

45

Fractional Flow Curve

0.05

0.72

0.64

0.68

D

46

What is the original oil in place in stb (m^3) of a reservoir with the following parameters? Area = 80 acres, (323,749) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (m3/m3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf. (0.00449 m3/m3)

3,496,563 ( 555,954)

3,933,633 (625,448 )

6,206,400 ( 986,818)

300,000,000 (47,700,000 )

A

Not supported with pagination yet

47

Using the following parameters, what is the ratio of the gas cap to the oil rim, m? Area = 80 acres, (323,749 m2) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (m3/m3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf. (0.00449 m3/m3)

0.125

0.22

0.5

not enough information

A

Not supported with pagination yet

48

A density log in a shaly sand records a formation bulk density, ρb = 2.20 g/cm^3. The correction factor for mudcake and hole rugosity is Δρ = 0.05 g/cm^3. From measurements on cores and produced fluids it is known that the matrix and fluid densities are, ρma = 2.68 g/cm^3 and ρfl = 1.2 g/cm^3. What is the density log porosity, %?

27

29

32

36

C

Not supported with pagination yet

49

A producer-injector pair of wells in an infinite-acting reservoir has been producing two weeks. The distance between the wells is 500 feet (91.44 m). Assume that the injection and production rates are equal at 1,500 bpd (238.48 m^3/d) and that the rock and fluid properties are the same for both injector and producer. Reservoir Properties for this formation are: Permeability = 250 md Porosity = .22 Net thickness = 30 ft (9.14 m) Oil viscosity = .5 cp Water viscosity = .5 cp Total compressibility = 4E-5 psi (2.76E-4 KPa) Injector Skin = 10 Producer Skin = 0 Wellbore radius of both well is 5.5 inches (139.7 mm) Bo = Bw = 1.0 rb/stb Calculate the expected pressure drop, psi (KPa), in the production well.

26.91 (185.54)

98.78 (681.06)

239.98 (1654.60)

656.42 (4525.86)

B

Not supported with pagination yet

50

A gas well has been found to be declining exponentially. The observed production rate on 1 January 2004 was 0.6 Bscf/month (1.7 × 10^7 std m^3/month), and on 1 January 2005, it was 0.4 Bscf/month (1.133 × 10^7 std m^3/month). The economic limit for the well is estimated to be 0.003 Bscf/month (8.495 × 10^5 std m^3/month). Estimate the remaining reserves, Bscf (std m^3), for the well as of 1 January 2005.

21.5 (6.09 × 108)

17.69 (5.01 x 108 )

1.791 (5.07 × 107)

1.474 (4.17 × 107)

B

Not supported with pagination yet

51

Which of the following has the LEAST influence on drill pipe stretch?

BHA weight

Drill pipe weight

Mud density

Traveling block weight

D

Not supported with pagination yet

52

Which of the following is MOST LIKELY a descriptor for a diamond bit?

Crown

Journal

O-ring Seal

Shirttail

A

Not supported with pagination yet

53

Which of the following is NOT a description of fluid flow?

Laminar

Plastic

Plug

Turbulent

B

Not supported with pagination yet

54

Which of the following is NOT a key rheological property of drilling fluids?

Yield point

Plastic viscosity

Gel Strength

Funnel viscosity

D

Not supported with pagination yet

55

Which of the following has the LEAST influence on bit nozzle pressure drop?

Bit diameter

Flow rate

Mud density

Nozzle area

A

Not supported with pagination yet

56

Which of the following is NOT a typical section view for directional wells?

Double build

Double twist

S type

Slant type

B

Not supported with pagination yet

57

Which of the following is a conventional rotary shouldered connection size?

4-1/2” REG

5-5/8” REG

6-1/2” REG

7-1/2” REG

A

Not supported with pagination yet

58

Which of the following is a DISADVANTAGE of air drilling?

Differential pipe sticking is eliminated

Downhole explosions or fire may occur

Lost circulation may be reduced

Reduced thawing of frozen zones

B

Not supported with pagination yet

59

Which of the following is FALSE regarding leak-off tests?

Unpurged air can affect the shape of the leak-off test curve

There are two phases of fracturing a formation, initiation and extension

The pressure to initiate is usually less than the pressure to extend

The initial pressure increase vs. volume pumped reflects elastic rock deformation

C

Not supported with pagination yet

60

Which of the following is MOST LIKELY regarding cement flow regimes?

Laminar flow has the smallest displacement efficiency

Plug flow is very inefficient w/small volumes displacing low density mud

Turbulent flow gives low displacement efficiency

Turbulent flow requires the longest pumping times

A

Not supported with pagination yet

61

When backing-off a stuck drill string, which of the following would NOT be a typical step?

Twist the string one counter-clockwise turn per 1,000 feet of free string

Pull the buoyed weight of the string above the stuck point

Fire the shot after working the torque down to the tool joint to be backed off

Twist the string one clockwise turn per 1,000’ of free string

D

Not supported with pagination yet

62

Which of the following is NOT a typical contributing factor in axial friction forces?

Bending of the drill string in a dog leg

Buoyed weight of the drill string lying on the low side

Hanging up of drill string component on a ledge

Packing of the drill string in a cuttings bed

C

Not supported with pagination yet

63

Which of the following does NOT result in collapse of the tube?

Elastic Collapse Pressure

Plastic Collapse Pressure

Transition Collapse Pressure

Yield-Strength Collapse Pressure

D

Not supported with pagination yet

64

The primary function of the counter-balance system in rod pumped wells is:

Speed reduction of the prime mover to suitable pumping speeds

Store energy on the downstroke and release energy on the upstroke

Store energy on the upstroke and release energy on the downstroke

Supply the mechanical energy to transmit to the pump and lift fluids

B

Not supported with pagination yet

65

For bellows-type gas-lift valves, valve spread is:

The difference between opening and closing pressures

The difference between annular and bellow pressures

The depth difference between the top and bottom valves

The depth difference between adjacent valves

A

Not supported with pagination yet

66

Which of the following would be a typical path for gas through a separator?

Primary separation, liquid accumulation, secondary separation, gas outlet

Primary separation, mist extractor, liquid accumulation, gas outlet

Primary separation, secondary separation, liquid accumulation, gas outlet

Primary separation, secondary separation, mist extractor, gas outlet

D

Not supported with pagination yet

67

Which of the following is NOT a primary mechanism in separation devices?

Centrifugal

Gravity

Impingement

Radioactivity

D

Not supported with pagination yet

68

Which of the following is NOT a key assumption for matrix acidizing?

Acid penetrates uniformly and radially

Formation is homogeneous

Pore size varies widely

Reaction rate declines uniformly with decreasing acid concentration

C

Not supported with pagination yet

69

The fracturing fluid coefficient is a key factor in modeling an induced fracture. Which of the following is NOT a category for fracture fluids?

Conductivity-controlled fluids

Reservoir-controlled fluids

Viscosity-controlled fluids

Wall-building fluids

A

Not supported with pagination yet

70

Which of the following is NOT a typical class of pipe cutters?

Acid

Jet-shaped charge

Outside cutter

Tubing punch

D

Not supported with pagination yet

71

A pump is needed to move a high viscosity, heavy (high specific gravity) crude oil from a storage tank to a treating facility for processing. The tank is not insulated and it is located in a cold-weather environment. The field from which this oil is produced has a low reservoir pressure, and the oil is produced in slugs that re-fill the tank sporadically. The oil must be moved at a closely controlled rate to the treating facility to avoid overloading it. What type pump, based on service capabilities and cost, should be recommended for this service?

Centrifugal pump

Gear pump

Reciprocating (plunger) pump

Turbine pump

B

Not supported with pagination yet

72

A caliper survey has determined that there has been a uniform 65% wall loss in a 5-in. (127 mm) 23.2 lbm/ft (34.5 kg/m) T95 casing string. Neglecting axial/hoop stresses. What is the new burst pressure rating of this casing string in psi/(Mpa)?

5,550 (38.3)

6,350 (43.78)

10,340 (71.29)

14,300 (98.6)

A

Not supported with pagination yet

73

An electric motor is needed for a hoist. The motor is expected to provide a force of 744 lbf (337.5 kgf) at the edge of a 24-in. (61 cm) diameter pulley. The motor will run at 1200 RPM and the pulley will be attached to a gearbox to provide the correct line speed for the hoist. Assume the motor operates at 85% efficiency. What size, hp (KW), motor should be specified for this application?

170 HP (126.8)

200 HP (149.1)

340 HP (253.5)

400 HP (298.3)

B

Not supported with pagination yet

74

A recently drilled well is being completed. The well was drilled with 14 lbm/gal (1.68 SG) mud with no mud losses experienced while drilling the well. The 5 1/2-in. (140 mm), 15.50 pound/ft (23.06 kg/m) casing has been perforated from 10,129 ft (3,087.3 m) to 10,141 ft (3,091.0 m). A full string of 2 3/8-in. (60 mm) tubing has been run in the well to the top perforation. The well was being circulated on its third bottoms-up with 8.7 lbm/gal (1.04 SG) filtered water when the pump failed. The crew closed the blowout preventer and installed a closed valve in the top of the tubing string. Unfortunately, they left the valve on the annulus flowline to the pit open while the pump was repaired. Someone noticed that the well was flowing, and the crew closed the annulus valve. The pit had gained 10 bbl (1.6 m^3) of fluid. Stabilized pressures after 30 minutes are: Shut-in tubing pressure, 495 psi (3,413 KPa); Shut-in annulus pressure, 225 psi (1,551 KPa). The type of fluid most likely composing the kick is:

Natural gas

Oil

Saltwater

Drilling mud

C

Not supported with pagination yet

75

A well has ceased flowing due to a buildup of saltwater in the tubing. The well is standing full of produced fluid with a density of 8.9 lbm/gal (1.067 SG). A pumping unit is to be installed to lift the fluid from a depth of 10,000 ft (3,048 m). Expected produced water rate is 220 bbl/D (35 m^3/day). The pumping unit will be counterbalanced such that essentially all the sucker rod and fluid load will be offset by the counterweights. The pumping unit manufacturer requires a prime mover having 125% excess power to run the unit. What is the rated horsepower, hp (KW), of the prime mover needed to run the pumping unit?

15 (11)

20 (15)

35 (26)

40 (30)

D

Not supported with pagination yet

76

A recently-drilled gas well has been completed, but initial flowrates from the well are disappointing. The well has the following characteristics: The pay zone perforations are centered at 15,800 ft (4,816 m). The static reservoir pressure is 0.63 psi/ft (1.45 SG). The fracture gradient at the perforations is 0.95 psi/ft (2.19 SG). Skin = -20 psi (-138 KPa). The pay zone is a tight, highly-consolidated clean sandstone. Permeability is estimated to be 0.05 mD. What treatment technique would you recommend to stimulate this well?

High rate, high volume fracture stimulation

Low rate “matrix” hydrochloric acid stimulation

Sand control treatment to reduce sand collection in the wellbore

Scale removal workover

A

Not supported with pagination yet

77

A pumping unit is to be installed on a 5,000 ft (1,524 m) well. The foreman wishes to use 1-in (25.4 mm), 7/8-in. (22.2 mm) and 3/4-in. (19.1 mm) sucker rods to make up the string 8 so he can use his existing inventory and minimize the purchase of new rods. Unfortunately, he only has a limited number of 1-in. (25.4 mm) sucker rods and he will have to buy some of these. What total length, feet (meters), of 1-in. (25.4 mm) sucker rods must be installed in this well if a 2-in. (50.8 mm) pump plunger is needed to achieve the production rate required on this well?

1,435 (437.4)

1,635 (498.3)

1,930 (588.3)

2,260 (688.8)

A

Not supported with pagination yet

78

Three storage tanks are delivered to the site of a new producing well. The tanks appear to be unusual in size. No tank table was delivered with the tanks. The well is to be placed on production as soon as the tanks are set. The basic dimensions of the tanks are: Tank outside diameter: 15.0 ft (4.57 m) Shell thickness: 0.35-in. (8.9 mm) Tank shell height: 17 ft (5.18 m) Overflow line outlet: base, 8-in. from top of tank (203.2 mm) What is the usable storage capacity of the tank battery to the nearest barrel (cubic meter)?

509 (80.9)

1,527 (242.8)

1,539 (244.7)

1,593 (253.3)

B

Not supported with pagination yet

79

A producing gas well is to be treated with a scale removal chemical at a low pump rate. The well is equipped with a polished-bore receptacle above the production packer with a 20-ft (6.1 m) seal assembly that travels freely. Bottomhole temperature is 300°F (149 °C). Gas temperature at the surface is 120°F (49 °C). Once the well is at thermal equilibrium during the pumping job, the average temperature of the tubing string will be reduced by 25°F (-4 °C) over its length. The tubing is tapered with 2,560 ft (780 m) of 3 1/2-in (89 mm) tubing at the surface with 5,440 ft (1,658 m) of 2 7/8 -in. (73 mm) tubing above the seal assembly. The tubing is all N-80 grade material. How far, inches (centimeters), up the PBR will the tubing travel due to thermal contraction during this pumping job, ignoring pressure effects.

1.4 (3.6)

5.3 (13.5)

16.6 (42.2)

18.6 (47.2)

C

Not supported with pagination yet

80

A double-acting duplex pump is going to be used to fill a tank from a water pit. The foreman does not know the pump output, but he wants an estimate of the time required to fill the 500 bbl (79.5 m^3) tank with water. Each liner has an internal diameter of 5 1/2-in. (14 cm) and an overall stroke length of 14-in. (35.6 cm). The rod diameter for each plunger is 2-in. (5.1 cm). The pump is running at a speed of 65 strokes per minute. Assuming a pump efficiency of 80%, how long will it take for the pump to fill the 500-bbl (79.5 m3) tank?

1.00 hours

1.17 hours

1.25 hours

2.50 hours

C

Not supported with pagination yet

81

Which of the following statements is TRUE regarding undersaturated oil reservoirs?

The two phase and single phase factors are equal above the bubble point

The initial solution gas-oil ratio does not equal the solution gas-oil ratio at a specified pressure above the bubble point

Below the bubble point, the two-phase factor decreases while pressure decreases

Below the bubble point, the single phase factor increases while pressure decreases

A

Not supported with pagination yet

82

Which of the following is the LEAST likely characteristic of a reservoir fluid?

Compressible liquid

Gas

Incompressible liquid

Superfluid

D

Not supported with pagination yet

83

Reservoir simulators are well-suited to help us determine

Aquifer size and strength, remaining reserves, corporate overhead

Future water production, optimal infill well location, results of fracture stimulation treatments

Optimal well spacing in reservoirs, coning characteristics of wells, and optimal flood patterns in improved recovery projects

Unique reservoir description, optimal enhanced recovery method, good matches of reservoir history

C

Not supported with pagination yet

84

The factors that cause recovery factors to vary in uncertain ways in oil reservoirs do not include

distribution of permeabilities vertically and horizontally

presence and location of reservoir boundaries

presence and location of reservoir heterogeneities

unexpected variations in oil prices

D

Not supported with pagination yet

85

Each type of logging tool has special formation evaluation applications. Which of the following statements is FALSE?

Pressure versus depth measurements can be used to identify reservoir fluids and fluid contacts

NMR and density logs can be combined to predict gas-corrected formation porosity in gas-bearing zones

Resistivity measurements alone can be used to differentiate oil zones from gas zones

NMR fluid characterization logs can be used to identify low-resistivity pay zones.

C

Not supported with pagination yet

86

Given accurate test data, the exponent, n, in the Rawlins-Schellhardt gas-well deliverability equation should be:

less than 0.5.

between 0.5 and 1.0.

greater than 1.0.

between 1.0 and 2.0.

B

87

A reservoir produces gas at an initial gas/liquid ratio (GLR) of 20,000 scf/STB (3,561 std m^3/std m^3). After some period of production at constant GLR, the producing GLR begins to increase with time. Essentially all the produced liquids are gas condensate. The reservoir fluid is most likely which one of the following types?

Black oil

Dry gas

Gas condensate (retrograde gas)

Wet gas

C

Not supported with pagination yet

88

The proper ranking of average (typical, not exceptional) oil reservoir recovery efficiency (from lowest to highest) by drive mechanism is

solution-gas drive; rock-and-fluid expansion drive; water drive; expanding gas- cap drive

solution-gas drive; expanding gas-cap drive; water drive; gravity drainage drive

rock-and-fluid expansion drive; solution-gas drive; water drive; expanding gas- cap drive

rock-and-fluid expansion drive; expanding gas-cap drive; gravity-drainage drive; water drive

B

Not supported with pagination yet

89

Low-permeability or tight gas reservoirs ordinarily produce at economic rates because they are

Stimulated with long, highly conductive hydraulic fractures

Provided substantial tax and other economic incentives by governmental authorities

Drilled with very wide well spacing, often 640 acres (2.59 × 106 m2), and drain large areas efficiently with limited numbers of vertical wells

Completed in formations of massive thickness.

A

Not supported with pagination yet

90

You are designing a waterflood for a reservoir that is currently below bubblepoint pressure and shut-in. The initial reservoir pressure was at the bubble point with no gas cap. The oil reservoir has the following information: • Flood Pattern — 5-spot • Pattern Area — 80 acres (323,749 m^2) • Formation Thickness — 59 feet (18 m) • Porosity — 16.0% • Initial Water Saturation — 42.0% • Oil formation volume factor at Original Pressure — 1.337 rb/stb (m^3/m^3) • Primary Oil Produced — 450 mstb (71,542 m^3) • Oil Formation Volume Factor at Current pressure — 1.165 rb/stb (m^3/m^3) • Oil Viscosity at Current Pressure — 1.02 cp • Water Viscosity at Current Pressure — 0.60 cp • Oil saturation at Current pressure — 41.6% • Average Water Saturation in Swept Zone at Breakthrough — 66.0% • Water formation volume factor — 1.000 rb/stb (m^3/m^3) The fillup volume in thousands of bbls (mstb) (m^3) is most nearly:

0 (0 )

960 ( 152,640)

2,092 ( 332,628)

2,542 (404,178)

B

Not supported with pagination yet

91

A reservoir oil solution gas-oil ratio follows the R plot attached. The initial reservoir pressure was 3,000 psia (20,684 KPa). If the current reservoir pressure is 2,500 psia (17,237 KPa), what is the oil solution gas-oil ratio (scf/stb) (m^3/m^3) nearest?

375 (67)

779 (139 )

935 ( 166)

Not enough information

C

92

An oil reservoir was originally undersaturated and was known to have no water influx. The field is to be waterflooded and part of the preflood strategy is to determine the new bubble point for this state of depletion. The initial reservoir pressure is 3,000 psia (20,684 KPa) with an initial oil saturation; Soi = 0.90. The abandonment pressure is 1,200 psia (8,274 KPa). At the abandonment pressure the oil formation volume factor is 1.20. Cumulative oil production to the bubble point is 250,000 stb (39,750 m^3). Using the above production information and saturations, assume Bob = 1.460 rb/stb and the Boi = 1.441 rb/stb and that rock and water expansion are negligible. If the new solution gas oil ratio is 750 scf/stb (134 m^3/m^3), what is the new bubble point pressure, psia (KPa), nearest?

3,000 (20,684)

2,160 (14,893)

1,800 (12,411)

1,200 (8,274)

C

Not supported with pagination yet

93

You have a PVT analysis for a volumetric reservoir which was undersaturated at the original reservoir conditions of 6,258 psia (36,890 KPa) and 205 °F (96 °C). The reservoir has produced at a constant producing GOR until a marked decrease in the producing GOR was noted. At this point, the cumulative production from the reservoir was 231 mstb (36,729 m^3) of oil. The average oil saturation initially in the reservoir was determined from logs to be 80%. Assume that the field is operated at optimum separator conditions. Fluid and rock compressibilities are as follows: cw = 3.5 × 10^-6 psi^-1 and cf = 11.6 × 10^-6 psi^-1. Determine the amount of gas in solution, mmscf (m^3), if the reservoir produces 1,200 mstb (≈190.8 × 10^3 m^3) of additional oil and is abandoned at 900 psia (6,206 KPa).

287 (8.1)

464 ( 13)

1007 (29)

306 (8.7)

A

94

What is the breakthrough mobility ratio of an inverted 5-spot pattern undergoing waterflood with the average water saturation at breakthrough equal to 68% (Swbt = 0.68)? Use the following table of oil and water relative permeabilities to calculate your answer. Assume µ oil = 0.64 cp and µ water = 0.50 cp.

0.680

0.462

1.000

0.419

D

95

Using the fractional flow curve, what is the water saturation at the well at the time of breakthrough?

0.68

0.64

0.72

0.05

B

96

What is the original volume of gas cap gas in place in mscf (mm^3) of a reservoir with the following parameters? Area = 80 acres, (323,749 m^2) net pay thickness = 50 ft, (15.2 m) average porosity = 20%, initial water saturation, Swc = 10%, initial gas saturation, Sg = 10%, Initial Oil Formation Volume Factor, Boi = 1.42 rb/stb, (1.42 m^3/m^3) Initial Gas Formation Volume Factor, Bgi = 0.8 rb/mscf (0.00449 m^3/m^3).

7,757,800 (219,768)

6,982,020 (197,791)

775,800 ( 21,977)

620,624 (17,581)

C

Not supported with pagination yet

97

A sonic logging tool recorded a travel time of 90 µs/ft in a loosely consolidated sand formation. From local experience it is known that sonic log travel times in this formation read too high because the formation is loosely consolidated. A correction factor, Cp = 1.2, should be applied to the Wyllie time-average equation to correct for lack of compaction. The matrix and formation fluid travel times are travel time times are, Δt matrix = 51.0 µs/ft ma and Δt fluid = 189 µs/ft. What is the formation porosity, %, predicted using the Wyllie equation with a compaction correction?

17

24

28

34

B

Not supported with pagination yet

98

From lab measurements on core samples from a zone of interest you are given the following Archie parameters: F = 26.0, and n = 2.3. From resistivity measurements on produced formation water samples, R = 0.05 ohm-m w at reservoir temperature. From log measurements, Rt = 10.0 ohm-m and φ = 0.20. What is Sw, %?

33

35

36

41

D

Not supported with pagination yet

99

A high-pressure gas reservoir had a discovery pressure of 10,000 psia (6.895 × 10^4 KPa). PVT analysis of the gas indicated the following variation in deviation factor, z, with pressure. p, psia z, dimensionless 10,000 (6.895 × 10^4 KPa) 1.47 8,000 (5.516 × 10^4 KPa) 1.30 Formation water compressibility was 3.5 × 10^-6 psia^-1 (5.076 × 10^-7 KPa^-1), initial water saturation 25%, and constant formation compressibility 2 × 10^-5 psia^-1 (2.901 × 10^-6 KPa^-1). Estimate the percentage, %, of original gas in place produced when reservoir pressure drops from discovery pressure to 8,000 psia (5.576 × 10^4 KPa).

9.54

14.6

20.0

85.4

B

Not supported with pagination yet

100

A gas reservoir has a reliable estimate of original gas in place of 400 Bcf (400 × 10^9 scf, 1.133 × 10^10 std m^3). There may be water influx into the reservoir from an aquifer. Estimate the cumulative water influx in reservoir barrels (RB) (or reservoir cubic meters, res m^3) if, after two years of production, average reservoir pressure has dropped from an original 5,000 psia to 4,000 psia (3.44 × 10^4 kPa to 2.758 × 10^4 kPa). Other information is summarized below. Time (years) | Avg reservoir pressure (psia) | (kPa) | Bg (RB/Mscf) | Bg (res m^3/m^3) | Gp (Bscf) | Gp (std m^3) | Wp (STB) | Wp (std m^3) 0 | 5,000 | 3.447×10^4 | 1.0 | 5.615×10^-3 | 0 | 0 | 0 | 0 2 | 4,000 | 2.758×10^4 | 1.2 | 6.737×10^-3 | 66.7 | 1.889×10^9 | 40,000 | 6.737×10^3 Assume water formation volume factor is 1.0 RB/STB (1.0 res m^3/m^3).

66.74 ×10^6 RB (10.61 × 10^6 res m3)

4 × 10^4 RB (6.36 × 10^3 res m3)

66.7 ×10^6 RB (10.6 × 10^6 res m3)

80 × 10^3 RB (12.72 × 10^3 res m3)

D

Not supported with pagination yet

Datasets:

ynuwara
/

spe_mcq_dataset

SPE MCQ Dataset